TREX-41 559

TREX-41 559

flyfl

Applied Adam

Bourgoyne

Professor

of Petroleum

Keith

Miliheim

ManagerCritical

Martin Senior

KS

Drilling

Engineering

Jr Engineering

Drilling

Facility

Louisiana

Amoco

State

Production

Chenevert of Petroleum

Lecturer

Young

President

Engineering

Jr

Woodway

Energy

Co

First Printing

Society

of

Richardson 1986

Petroleum Engineers

TX

of Texas

Co

Dedication This book

is

Copyright reserved

dedicated

1986

This

by

book

the or

to

the

Society parts

publisher

ISBN 1-55563-001-4

many

of

students

Petroleum

thereof

cannot

who

were

Engineers be

forced

to

in

Printed

reproduced

in

study

the

from

United

any form

trial

States

without

drafts

of

of

this

America

written

work

All

consent

rights

of

the

Adam

Jr

Bourgoyne

and

Petroleum

and

MS

in

degrees

troleum

in

the

as

both

Dept

petroleum

Accreditation

and

was

and

mittee

student

and

member

of

of

faculty

sponsor

Panel

He

PhD

has

member served

also

Com

Manpower

Education

SPE

an

is

and

He

Engineering

198083

the

Texas

of

the

BS

Pe

the

holds

also

Bourgoyne

Advisory

chairman

Drilling

of

chairman

the

chapter

Review

member

He was

197783 from

Offshore

where he earned

State

engineering

during

engineering

LSU

director-at-large of

petroleum

Engineering

degree

Louisiana

at

Engineering

of

Professor

Campanile

is

Accreditation

and

Committee

A.T

Bourgoyne

Jr

Keith co

Millheim

Production

OH

Marietta in

petroleum

1984

nual

Keith

197884

1983

served

and

198082

Millheim

Executive

Editor

of

SPE

an

is

BS

the

Technical

Program Committee

of

of

the

SPE

SPE

1981

the

and

was

An mem

Forum

Drilling

Review

Committee dur 198687

for

Lecturer

both

Member

National

of

Directional

Editorial

Distinguished

is

for

chairman

the

from

Oklahoma

1965

the

served

as

Amo

Distinguished

and

winner

for

degree

Facility

earned

Millheim

member

the

Drilling

He

from

degree

He was chairman as

ing

and

is

Engineering

Drilling

Miliheim

Cherievert

troleum

engineering

degrees

in

um

sionalism at

the

tee

of tee

Chenevert

text

Annual

Cherievert

bility

short

course

on

professor

at the

Farrile

Jr

Young

petroleum

U.S.A

an

is

Young

Jr

He

has

operational

from

hibits

He

pe PhD

of

the

Profes sponsor

Commit member

as

Commit

Technical

Sta

Wellbore

SPE

joining

the

Co

was

the

as

videotape of

an

Texas

associate

con

his

of

president

member

was in

and and

mechanics

the

registration

SPE

and

is

the

PhD

served

Long in

1975

the

Review for

the

has

also

the

publications

registered

of

petroleum

tech

on

the

the

professional

field

the

197578 in

1978

Subcommittee

on

Committee

dur

during

Advertising

Review of

Inc

engineer

196971

Offshore Technology

Monograph in

of

Nominating

Committee

research

Co

committee

that

Planning

first

served

Cementing

in

de

equip

drilling

Energy

member

as

Range

Editorial

He

Woodway

the chairman

in

Industries of

Co

in the

engaged

application

of

consult

Exxon

for

instrumentation

degrees

chairman

numerous

Young

as

and

Div NL to

president and

Young

Welfare

May 1969

Committee

MS

worked

engineer

monitoring

the

and

of the

staff

and

gas operator

Young

relative

is

and

oil

Baroid

for

Texas

of

has written

Texas

served

and

rig

worked

Committee

197475

ference

and

senior

assignments

the

was

Young

Before

and

Textbook

Fluid and

Research

of

and

faculty

served

also

author

the

Previously

was

also

Professionalism ing

He

Drilling

is

independent

of computerized

Investments

He

Education

the

19777

the

Fluids

Oklahoma

nology Young currently in Houston He holds BS ing

and

Exxon

by

engineer

where he

velopment

and

of

and

Technology

SPE

the

Drilling

employed

of

Drilling

MS

BS degree in petrole is member of the

student-chapter

is

197578

1975

Lecturer

firm

sulting

ment

since

Petroleum

Chenevert

chairman

has presented

was

and

during

Meeting

courses

Chenevert

ing

He was

holds

also

Committee

Series

member

1971

He

Centennial

where he earned

Texas

State

Committee

Texas

was

the

of

engineering

Author

Pirson

The Sylvain the

from Louisiana

Technical of

and

is

at

petroleum

engineering

Distinguished

F.S

Critical

Tulsa

Award

winner

Technology

Drilling

the

in

Millheim

Engineering

Paper

Martin

Martin

and

ber during in

Co an MS

engineering

Drilling

Graduate

manager of

is

Research

Con Ex

Committee

drilling

engineer

and

in the

and

rock

State

of

Acknowledgments The authors would

like

to

help of

the

acknowledge

and

individuals

in the

companies

and

that are too gasproducing industry numerous to mention Without of so many this hook would not have been possible In particular the

American

um Inst

the

Extension

of

of Texas

the

several

Assn

Intl

of

were

Contractors

Drilling

of

tremendous

and

assistance

in

the

Petroleum

the

providing

oil-

unselfish

help

Petrole Service

material

background

for

chapters thanks

Special

Committee

are

due

the

during

numerous decade

past

who

individuals

for

have

help and

their

served

SPE

the

on In

understanding

Textbook large

particular

who served for several was made by Jack Evers of the of Wyoming years Textbook Committee as senior reviewer and coordinator for this work Finally

contribution on

the

the

authors would

who

tor

like to

constantly

the

recognize

Dan Adamson

of

contribution

authors

the

prodded

finish

to

SPE Executive

Adam When of

the

accepted

my

free

holidays

and

vacations

my wile

for

the

would

mc

with

like

our

would

it

Warren

the

and

typing

of

and

to

thank

John

this

the

not

were

it

me

Sinor for

this

doubt

Allen

and

and

research

the

effort

could

staff in

is

impossible

in the

and

had

numerous

to

would and

me

for

of

with recall

also

Tommy

Co

Production

Tulsa

that

for

with

helped

drafting

preparation

sessions

helping

completed

Keith

It

even

Valerie

in

have

Dunbar

Amoco

examples

much

and

monumental task

dedicated

his

how

thank

or editing

complete

for

of

idea

weekends

evenings

correcting

Jr

Bourgoyne

no

Warren Winters Mark

II

problems

textbook

had

textbook

in letting

Allen

to

Horeth

with

of

part

If

this

were many

writing

patience

gratitude

textbook

the

of

part

There

was busy

my

assistance

write

to

when

extend

like

their

permission

consumed

be

understanding to

part

also

for

of writing

challenge

would

time

Direc

book

the

to

my

my

list

drilling

For

their

particularly

many

the

part

like

of

this

whom many

industry

associates

am

assistance to

to

The

people

book

thank

am

period

span

for

their

discussions of

assistance

and

years and

work

are

too

thankful of Texas

the

indebted

meetings

Miliheim

and

SPP

for

their

encouragement

support

Martin

The from

Society the

of Petroleum

Shell

Companies

Engineers Foundation

Textbook and

the

Series

SPE

is

E3FIE IE Fct jrditjc.-

made

Foundation

possible

in

Chenevert

part

by

grants

SPE Textbook The Textbook of

action

petroleum

tee as

of

one

in

members

the

use

for

the

or

of

in

The work

Society-wide

book

the

Below of

involved

others

is

with

and

the

of

listing

book

this

in areas

by

clearly the

Many

Textbook

those

others

who

Textbook Editors Jack

Evers

David

of

Pye Union

Wyoming Div

Geothermal

Textbook Committee Medhat Jack

Kamal chairman

Evers

Steve

HM

Pye Union Staggs

Kent Fred

Blevins

Neuse

Co

of

California

Chevron

Hudson

Co

Petroleum

Colorado

School

of

Mines

U.S.A

ENSERCH

Hoyer Exxon

Co

Gas

Oil

Phillips

Schenewerk

Wilmer Steve

Oil

ARCO

Thomas

Flopetrol-Johnston

Wyoming

Poettrnann

Theodore Philip

of

1984

Exploration

Production

Consultants

Inc

Research

Co

as

members

been as

1972

by

of high-

being

Textbook

Committee have

in

availability

identified

Societys

contributed

book

the

established

ensure

to

committees through

standing

Editors

intended

is

directed

is

was

Engineers

Series

courses

undergraduate field

preparation

final

The

The Textbook

Editors

of Petroleum

Society

of Directors

engineering

evaluation

volved

Board

more than 50

Textbook

cal

of

Series

SPE

textbooks

quality the

the

Series

within

Commit designated

provide techni most

Textbook

closely

in

Committee

Preface This

book

lum The lowed

was

written

by

science is

primarily

petroleum

engineering

cements

are

in

material

Because

the

course pies

allow

Chaps

that

are

the

be

chapters

important

illustrated

basic understanding

petroleum

in

freshman-

aimed

are at

or

to

drilling

engineering

in

drilling-fluids

course Chap course

at

en

introductory

sophomore or junior level

more advanced

in

use

of

level

book

the

sophomore-level for

fol

first

The

an introduction

as

designed

the

drilling

covered

through

intended

curricu

engineering

fundamentals

fundamentals

these

proceeds

and

are

science

the

Chaps provides

senior

level

program

was designed

anyone with

and

senior-level

could

one

as

text

and

in

involving

material

course

for

of previous

Also

and

text

advances

course

masters-degree

independent

applications

as

suitable

textbook

present engineering

foruse

laboratory

through

or

is

college to

descriptive

suitable

It

additional

as

gradually

gineering

and

use

example engineering

engineering

Chap

for

was organized

material

with

general of

for

use

in

enabling

concepts

are

more than one an

instructor

developed

numerous examples background wide

range

in

of

from

These

select

topics

fundamental

principles

and

the

physical

engineering

problems

engineering

drilling

course each

to

or

chapter for

use

is

in

scientific

examples sciences and

largely single

princi should to

gain

solutions

Contents

Rotary

Drilling

Drilling

Team

5.3

Bit

.2

Drilling

Rigs

5.4

Factors

.3

Rig

1.4

Power

Hoisting

.5

1.6

System

1.8

12

5.7

Factors

The

System

17

5.8

Bit

Rotary

Control

System

.9

21

System

Cost

Drilling

Analysis

Exercises

27

Formation

32

Fracture

Tests

Tests

2.3

Water-Base

2.4

Inhibitive

2.5

Oil

Muds

Pore

53

6.4

Methods

for

Fracture

Pressure

82

3.3

of

Composition

Cement

Portland

Cement

Testing

Standardization

of

3.4

Cement

Additives

3.5

Cement

Placement

Cements

Drilling

Casing

Hydrostatic

4.2

Hydrostatic

Pressure

in

Gas

Hydrostatic

Pressure

in

Complex

Pressure

85

7.3

API

86

7.4

Casing

Design

89

7.5

Special

Design

90

Exercises

Control

Operations

Buoyancy

4.6

Nonstatic

4.7

Flow

4.8

Rheological

Models

4.9

Rotational

Visconieter

4.10

Laminar Flow

4.11

Turbulent

4.12

Initiating

4.13

Jet

Bit

Pump

Jet

in

Flow

Bits

Nozzle

and

of

Annuli

and

Pipes

the

Annuli Well

Size Selection Schedules

for

Due

and

Directional

Drilling

Well

Drilling

5.2

Rock

Control

for

351

Directional

the

353

Trajectory

8.5

Directional

119

8.6

Deflection

122

8.7

Principles

of

127

8.8

Deviation

Control

129

Exercises

the

the

Trajectory

Trajectory

Kickoff

of

Well

362

and

366

Change Drilling

Measurements

377

402

Tools the

BHA

426 443 453

137

Development Non-Newtonian

144

Rotational Viscometer

154

Appendix

Bingham

Plastic

Power-Law

of

Equations Liquids

for

in

Model

474

Model

476

Well

Appendix

Development Approximations

164

for

Bingham

of

Slot for

Non-Newtonian

173 Plastic

Power-Law

Bit

Reasons

Planning

183

5.1

339

and Deviation

Drilling

Definitions

Vertical

Exercises

Rotary

330

Considerations

8.4

162 to

Velocity

Slip

305

Properties

Criteria

Calculating

156

Operations

Movement

Particle

Performance

8.3

135

Pipes

in

302

Casing

131

Circulation

Pressures

Surge Pipe

16

Conditions

Pressure

Control 15

Well

Through

114

115

4.5

4.14

Columns

Well

During

301

Casing of

348

Planning

113

Pressures

of

Casing

Directional

8.2

Columns

Annular

Design

Standardization

in

Columns

Fluid

294

7.2

Hydraulics

4.1

4.4

287

Exercises

8.1

4.3

285

Estimating

Manufacture

110

Liquid

Resistance

103

Techniques

Exercises

Drilling

Fracture

7.1

Cements

3.2

252

Pressure

Formation

75

Exercises

3.1

246

Pressure

Estimating

6.3

72

Muds

for

42

54

Muds

Water-Base

and

Pressure

Pore

Pore

Pilot

236

Resistance

Methods

Fluids

2.2

221

240

Formation

Diagnostic

Rate

Exercises

6.2

2.1

220

Penetration

Operation

37

Drilling

219

Run

26

Marine Equipment

Special

Wear

Bearing

Bit

Affecting

214

Wear

Tooth

Affecting

Terminating

System

Well-Monitoring

1.10

Factors

209

Evaluation

Affecting

5.6

Circulating

The Well

.7

5.5

System

and

Selection

Model

Model

Flow Annular

Flow

Fluids

477 481

Bits

Types Available Failure

Mechanisms

190

Author

200

Subject

Index Index

484 486

Chapter

Rotary

The

objectives

student

with

dent

to

of

this

are

chapter

the basic

rotary

to

cost

drilling

familiarize

introduce

to

the

equipment

drilling

procedures and

operational

Process

Drilling

the

reasonable contract

stu

on cost per foot to and cost per day beyond

evaluation

and

plan

Team

Drilling

drilling

The

large

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made

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on

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the

certainty

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APPLIED

Fig

1.1

Texaco Lafitte

drilling field

barge

Gibbens

on

location

in

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ice

Canadian

platform Arctic

DRILLING

deep

in

area

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water

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SERVICES COMPANIES

CONTRACTOR

ACCOUNTING DEPARTMENT

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CREW

Fig

1.3Typical

drilling

rig

organizations

DRILLING FLUIDS

DRILLING

1_CEMENTS

of

ROTARY

PROCESS

DRILLING

Nose

Ppe

Bell

Nrpple

Blowout Preventer

Emergency Lrne Flow

Pipe

Drill

Conductor

Cosing

Eortherr Pit

Doll

1.5Classification

Fig

1.4The

Fig

rotary

process

drilling

derrick

full

1.2 Drilling Rigs Rotary drilling done today process

sketch

bit

turned

is

drillstring using

downward

the

illustrating

all

drilling

rotary

drilling

in

the

Generally

almost

for

Fig 1.4 The hole is to which downward force

bit

rotating

used

by

rotary table

force

is

bit

applied

is

the

rotating the

at

to the

applied

entire

and the

surface

by using sections

of

heavy thick-walled pipe called drill collars above the bit The cuttings are lifted drillstring surface

by the

through the

circulating

shown

classified

main

drilling

fluid

1.5

as

broadly

features

of land

operating

depth

conventional

land

design

many well of

these

and

are

as

and

1.6

then

suitable

for

mounted

on the

rig

The is

rig

can

as

portable

hoisting

location

In

after the

However be

close

because

modern land moved easily are

skid-

and

in

or

on

the

using

water

the

the

rig-hoisting

wells

which

usually

trailers

machinery

with

that

engines

is

is

in and

are

depths

and

location

barge

allowing

After

the well

production

to

it

of

by

be moved

to

on

water

depth

supported

can

1.8 The jackup

On and

rig

mobile is

location

the

platform

are

type

jackup

Fig

with

the

lowered to

up

above

legs

the the

action

an inland in

bottom-

ft

by means of hydraulic jacks Semisubmersible rigs that can be flooded

wave

using

When

common

the

jacked

is

by

ft

easily

350

is

legs

40

done

is

towed to location the

built

surface

on the seafloor

most

rig

the

the operating

moved

The

be

the

about

usually

about

be used

of bottom-supported

location

built

be

can

than

less

is

rigs

the next

cases

drilling

that

Once

barge

from

to

mat

entire

pumped

support

some

shell

rigs

to

extended

Offshore exploratory self-contained

the

for

severe

towed to

is

platform must

In

been

has

used

20 ft The

flooding

are

rigs

not

is

and the unit

and

to

operation

are

action

is

equipment

depth

of

generally

the water

welihead

extended

marine

depth

wave

completed

is

the

protect

water

sunk

mast

portable

then

than about

less

completed

is

drilling

to

barges

where

rigs

on the unit

water

assembled on the barge

is

rig

floating

mersible

most

drill

Fig rigs

1.9

few

engines

can

extend

water

depth

are

rigs

rig

over

greatly

the

Some of

these

modern

semisub

more

expensive

rigs

mostly

bottom

on

similar to

bottom as well as

are used

for resting

the

on

usually

semisubmersible

to position

This

are

and thus

great

semisubmersible

hole

resting

However

position

rigs

too

depths

can

barge

than jackup

cantilever

ground

Fig 1.7 or

and

bottom

quite

units

mast

trucks

the

moved

unit

drilling

built

jackknife

moderate-depth wheeled

and

components

assembled

drilling

water

elevated

can

be

Submersible

and

features

maximum

drilling

telescoped

pistons

design

and

inland

of drilling many

most

derrick

various

raised

The

the

main

rotary

position

by hydraulic

portability

be

The

of

the hole

were

construction

the

easily

equipment

corporate

of

that

Fig

over

vertical

resting the barge

can

rigs

on

built

was developed

The

so

left

surface

derrick

the early days

so that

reused

connected

pins

cost

is

be

are

marine rigs

The

derricks

field

built

mounted

derrick

In

standard

the high

rigs

derrick

completed

together of

the

cases is

must

rig

between

are portability

rigs

the

to the

cuttings

drilling

or

rigs

maximum

the

in

drillstring

space

The

at

rotary

land

the

annular

drillstring

Fig

in

the

up

the

from the

separated

As

and

bit

and

hole

down

fluid

by

drilled

unit The

single

to the

height

The are

rigs

shown

is

as

raised

is

of

anchored rigs

the hole

water

over

employ

the large

dynamically

maximum can be

in

At present

used

operating in

water

APPLIED

depths

as

rig

of

greatly regardless in

use is

areas

6000

as

great

semisubmersihie

as

type

of

dampen

to

wave

direction

North Sea

the

such

The

ft

tends

of

shape

This

the

motion

wave

allows

where wave

its

action

severe

few

the

is

drilling

much

are

they

Fig than

costly

designed

to

being

be

1.10

in

offshore

Drillships

semisubmersibles

positioned

planned

up to 13000

depths

used

vessel

floating

drillship

less

driliships

water

turret

using

will

ft

be

dynamically able to

Some

are designed

areas

in

with

thrusters

the

Offshore from

fixed

rig

on

location

in

Port

Hudson

rotated

is

that

indicates

ship

more platforms

to

rig

it

is

usually

drilling

After

the exploratory

construction

Melon offshore

of

presence

justify

from which

area

faces

always

wave

usually

motion

limited

many

is

mast

being

transported

sufficient

1.9A

semisubmersible

location

in

the

Eugene

Louisiana

drilling

rig

one

directional wells

field

Fig

done

costs

--

1.7Portable

to

drilling

Louisiana

Fig

on

the central

not severe

the

petroleum reserves or

is

mounted

about

the

driliships

development

Island

1.6Jackknife

so

action

platforms

1.8Jackup

Fig

of

use

where wave

program

operate

anchoring system

ship

incoming waves This helps to dampen

are

unless

and The

turret

However

second

usually

equipment

rig

central

ENGINEERING

DRILLING

on

location

ROTARY

can be

drilled

platforms

reservoir

barge

all

be

used

which

operation

When

cost

water

derrick

The

next

and

quarters

The

for

less

some

the

tender

rig

anchored

living

on

combination

to

the of

many

and

time

rig-up

platform/tender

be

may

time

operating

weather

severe

Platform

usually

located

platforms

be

However

during

the

self-contained

are

Fig 1.12

will

cost

operating

of

use

vessel

the

components

rig

lost

small

contains

in

out

develop

platform/tender

floating

platform the

for

is

the

components

Fig 1.11

platform can

allow

rig

can

platform

The

location fanning

on the platform

can place

platforms

wellbores

various rig components few large modules that

into

quickly

Large

The

fully

rigi.e

the

on

placed

so that

from

are integrated

and

built

are

are placed

directions

all

PROCESS

DRILLING

rises

Fig

very

depths

with

rapidly

are too great

water

for the

1.10An

offshore

drillship

depth

economical

use of

development platforms the development wells be drilled from floating vessels and the wellhead

can

equipment

on

installed

completion

the

technology

ocean

is

Underwater

floor

still

new

relatively

and

experimental Although

drilling

differ

rigs

outward

in

greatly

and method of deployment appearance all rotary have the same rigs basic drilling The equipment main component of parts rotary rig are the power

system

circulating

system and

well

smaller

is consumed by the hoisting and fluid systems The other rig systems have much

used

so

simultaneously form both functions

drilling

were

rigs

However

because of

portability

the

steam-powered

Modern

and

engines

diesel-electric

the

on

rigs

used

are

used

are those

to

to

teristics

and be

motors

electric

wired

to

transmit

which

in

generate

as

plug-in

the

use of

The

In

relatively

driller

cable of

flexibility

better

distribution

rig

offshore

on

location

Louisiana

to

can

simple apply

and

rig

systems

charac

for the hoisting

can

be

There

is

placement and

power

flexible

can

connected

connectors equipment

electric

power

rig

components

rig

that

utilization

space

addition

main

Electric

speed-torque

The

units

portable electric

considerable allowing

platform area

through use motors can be

well-suited

operations

circulating

with

Island

type

power

electricity

of

range

are extremely

packaged

self-contained

Eugene

the

as

direct-drive

Direct-current

wide

give that

1.11

impractical

to the various easily power is transmitted where the required work is accomplished of

Fig

systems

rig

Diesel-electric

engines

lack

required

plants

internal-combustion

the

method

and

subclassified

or

for early

steam

by

become by

generally

type

the various

boiler

powered

per

The

consumption

have

rigs

are

rigs

depending

large

not

can

requirements

primarily

fuel

are

engines

3000 hp

to

powered of high

generally

power

1000

the

Fortunately

same

the

Total

from

are

rigs

diesel

control

monitoring system

requirements power and circulating systems

hoisting

of

fluid-

well

power

rig

circulating

most

system system

rotary

Power System

1.3 Rig Most

hoisting

system

weight

allows

control

the

system

smoothly to various

rig

Fig

1.12A

tendered

platform

rig.12

in

the

APPLIED

minimizing shock

thus

components

ENGINEERING

DRILLING

and

vibration

problems Direct-drive

from

TABLE

HEATING

1.1

Fuel

Type

VALUE

OF VARIOUS FUELS

the

chains

belts

motors

The

system

Density

clutches

rather

cost

initial

of

Btu/lbm

7.2

19000

gasoline

6.6

butane

4-7

20000 21000 24000

drives

of

reduce

the

shock

increases extend

suited

designed with

engine

to

Frjctjonless

converters

Pulley

on

also

greater

allows

the

conditions

running

than

rather

used

to

the internal

use

of

torque

now

are better

that

The

selection

problems of which are

of

ranges

applications

per

Hydraulic

output are

load

of

the

greatly

characteiistic

over

drilling

that

system

that

so

and

power

development

converters

output

the speed-torque

combustion

The

vibrational

system Torque

rapidly

than

less

improved

and

gears

direct-drive

of power

type

drives

hydraulic

generators

system

has

this

the direct-drive

using

than

considerably

is

drives

hydraulic

formance

diesel

engines

of

diesel-electric

transmission

power

combustion

Value

Heating

methane

and

generally

comparable Ibm/gal

accomplish

rigs

internal

of

torque based

engines

con

starting

ditions

Power-system

torque

LH

speeds

performance

are stated

generally

and As

illustrated

of the angular

of

terms

Fig

in

characteristics

output for

consumption

fuel

by an

developed

in

1.13

horsepower

various the

engine

shaft

power from the product of the shaft and the output

engine

is

velocity

obtained

torque

PwT rev/mm

1.1

The

overall

fuel

consumption

heating

power

2rN

Fr

energy

of are

engines

input

to

at

Wf

values

combustion

the

determines

efficiency

given various

shown

engine

engine

the

rate

fuels

for

in

Table

.1

can

be

of

The

speed

internal

The

expressed

heat

by

2rrN 2irrN

Q.wfH Since

------

defined

2irrNF

Fig

1.13

Engine

power

the

overall

1.2 power

as the energy

output

system

efficiency

per energy

input

E1

E1

output

1.3 Qi

Added

Ready Hole

Fig

is

then

1.14

Making

connection.12

to

ROTARY

DRILLJNG

PROCESS

the overall

Thus 1.1

Example

1740

of

fuel

diesel

ft-lbf

at

an engine rate

consumption

output

and

power

engine

31.5

w2r1200

is

torque

rpm what

gal/hr

velocity

If is

of the

engine

given

by

rpm

can be computed

33000

E1

using

Eq

the

and

Ibm/gal Table

fuel

hp

397.5

is

the

diesel

heating

1.1 Thus

the

fuel

the

value

is

density

7.2

Btu/lbm

19000

consumption

is

rate

wf

is

of

strings

and

wf31.5

7.2

gal/hr

1bm/gal_

routine

drilling

system

by

total

Eq

heat

energy

consumed

by the engine

is

given

1.2

wH 3.78

lbm/minI

9000

33000

1695.4

Btu/lbm779

ft-lbf/Btu

downhole

hp

Fig

1.15Pulling

back

to

dull bit

The

to

out of the hole are

change

Derrick is

to

shown

or Portable

Mast

the

vertical

provide

raise

sections

hole

The greater the height

out

of

the

hole.12

of

to the process

bottom

usually

1.4.1

drilipipe

described

is

process

to

refers

joint of

hole

the

coming

derrick

ft-lbf/fl1ifl/hp

This refers

connection

new

in

Fig

removing of portion

from the hole to change and then assembly lowering

drillstring

drilistring

adding

the

connection

making

Making

the

Two

with

performed

called

of

trip

of the hoisting

drawworks

the

trip

casing or out

substructure

operations

deepens

Making

and

provide

into

equipment

and

are

to

is

drilistrings

components

derrick

process

the hole

system

raising

principal

making

the

or

tackle

hoisting

the

The

and

14

hoisting

subsurface

the

the periodic

Ibm/mm

3.78

other

are

block

as

the

lowering

hole The

and

hour

of

function

means

of the

ft-lbf/min/hp

System

Hoisting

ft-lbf/min

type

O.234or23.4% 1695.4

1.1

system Since

1200

at

engine

397.5

the

The

1740

the

the

1.4

7539.8

Eq

by

given

is

rad/min

7539.8

output

output

1.200

overall efficiency

Solution The angular

The power

of

speed

was

an

gives

of

efficiency 1.3

of

pipe

from

or

trip

steps

in

involved

function

height lower

the longer

the

made in

1.15

Fig

The

is

of the

required

them

into

the section

to the of

APPLIED

ENGINEERING

DRILLING

nF1

Trove

ng

Block

n8 Anchor

Indicator

Arrangement block

and

and

that of

hole

The

and

27

most

30

called

of

joints

1.16Schematic

In

addition to

according

and

loads

wind

with

the

When

chored

masts

by

pressure control

also

API

usually

placement

must

of

D104

load and supportable

the in

the

only

other

usually local

been

designs is

are

governed

by

conditions

soil

is

An

portable

API

has

Tackle the

The

crown

and

block

tackle

the

block

is

traveling

the drilling line The arrangement and block and nomenclature of the block and tackle used on rotary

shown

are

rigs

the

in

and

block

Fig

16a

tackle

is

which

loads

The

tackle

is

simply

the

block

divided

drawworks

F1

mechanical of

large

block

and

handling of

advantage

load

function

principal

provide

easier

permits

mechanical

The

to

supported by the traveling the load on the imposed

by

MW

1.4

specifications

weight

large

the rotary the corner load

at

The with of

pieces rating

can be pipe

table

set

weight

irrespective

loading

each

the

according

that

maximum

the

derrick

capacity

pipe

derrick

suspended

Wind

derrick

floor

blowout preventers

above

elevated

is

recommends

load-supporting

maximum

called

substructure

not

weight

Bull

and

height

and of

advantage

derrick

the

comprised

of

resting

of small

below

space

valves

on

support the

dealing

and

loading

Institute

derrick

with

usually

moment

Block

1.4.2

rated

point

leg of

rating

Petroleum

working

provide

the derrick

each

many

of design

have

types

non-API

of

the derrick

wind

substructure

three or

overturning

that

at

three

addition

1-3

ratings

To for

wind

the

American

blowout preventer

are

in

overturning to

sections

the hole

an

assuming

this

attached

standards

published

as

increase

to

The

the derrick

The choice

the derrick

in

platform

computed

wires

guy

are used

and

to

applied

available

loads

in

sections

in

between

compressive

wind

drillstring

standing

is

same direction

the

the

pipe-racking

must be

ratings in

is

Allowable

In

respectively

withstand

to

tackle

4A1

long

capable

derricks

height

standing

drillstring

the

moment

loads

drillstring

the

against

orfourbles

ability

both with

are specified

two

and

Standard

is

be

to

block

adopted

handle of

said

are

their

their

can

of

from the

faster

drillpipe

that

thribbles to

the

removed

or

composed

drillpipe

doubles

pulling

are

in

used

Derricks

which

stands

four

commonly

long

ft

and thus

can be inserted

pipe

block

nomenclature

handled

be

can

string

diagram

crown

tackle

Fig

pipe

of

block

of traveling

of

Free body

Freebodydiagram

Load

capacity

corner

ground

level

substructure its

load

but

equipment

The the

load

The

from

in

to

the

pulleys

in

the

throughout

can

be

of

setback

maximum

Also

in

API

analysis

body

shown

that

the block

force

free

substructure

back

on the drawworks

mechanical

ideal

friction

the

imposed

the tension

is

in

line

fast

in

direction

Fig

the

can

tackle

of the traveling of

diagram 1.16b

tension

which

advantage and

If in

Thus

the

there

the

force

assumes no

be determined block

traveling

no

is

drilling

balance

Consider block

friction line in

is

the

in

as

the

constant vertical

yields

nF1 where

is

the

number

of

lines

strung

through

the

ROTARY

DRILLiNG

PROCESS

L1

Derrick

Deod

TABLE 1.2 AVERAGE EFFICIENCY FACTORS FOR BLOCK.AND.TACKLE SYSTEM

Bi

Leg Line Lines

Number

of

Lines

Efficiency

S..

.5

0.874 0.84 10

to

Block

0.8 10

12

0.770

14

0.740

Line traveling

block

tension

the

in

expression

and

line

Eq

in

this

Solving

fast

1.4

for

relationship

the

the resulting

substituting

yields

Win which is

indicates

equal

to

crown

between

Fig

in

the

lines

1.16 The

crown

use

block

of

Eight

and

10

or

lines

lines

drilling

on

floor

rig

are

block

then

the tension

com

is

of

1.17Projection

the

lines

traveling 12

Fig

advantage between

strung

block

traveling

the

mechanical

ideal

number of

and

block

shown

that

the

in the

fast

line

is

mon

depending on the loading condition The input power of the block and tackle to the drawworks load Ff times the velocity fast

line

is

1.7

equal

of the

Eq

vj

1.7

can

However

1.5

The

The output power block

traveling

times

line

causes

hook power

or

load

block

traveling

wear and

line

PF1v1 is

the

equal

to of

velocity

the the

vb

be

the tension

PhWvb

fast

size

allow

to

the block

the derrick

As shown

the

in

used

in

the

is

Fig

1.16c the

and

tackle

be greater

sum of

F5

deadline

and

to

the load

hook

load

the tension

1.6 block

frictionless

movement of

since the tends

to

crown

each

shorten

and

block

the unit

power

and the

then

distance

WnF1

tackle

fast

of the

line

lines

unit

by

by only

the ratio

v1/n of output

1/n

of the

to input

power

WiEn values

Pi

block are

and

shown

tackle in

line

given

for

efficiency

there

is

Approximate

always values

for roller-bearing

The of

sheaves

Table 1.2 of

Knowledge permits

system

friction

to

the

calculation given

block

the

at

Since

the

tackle tension

power

four

on

one

tension

the

at

sheave

Eq

in

in

first

fast

efficiency in

the

efficiency

side

derrick

fast

which

legs it

the

sheave

Ffvf

fast

F1n

is

Also

the

is

attached

as

in

1.17 For

1W

distributed

two

only

line

The

drilling

is

affects

of only

lines

line

posed

by

share

and the

this

the load

Leg

view of the

arrangement imposed

would

tension

in

rig

the

floor

the

dead

the four

leg

full

line

shown

in

and in

load

The

to are

Legs

by the tension the

in

the

usually

derrick

assume

over

located

the tension

floor

over

..l.8b

equally

drawworks

dead

the plan

to

these

line Substituting

the

of the derrick distributed

line

drilling

1.8agives

not

Since

fast

motion

deadline

is

would

Wujin

is

load legs

the

resisting

En

derrick

line

Fig

Fv

last

derrick

arranged

by

Wvb

the

Win

forFandF5

total

all

fast

and

of the actual

load

and

line

from

by pulling on the is

En

actual

an

in

due

the sheaves

in

FdW--1EEn\

F1v1

loss

power

fast

hoisted

being

is

friction

frictionless

nFfvfin Of course

load

the

line

1.8a

times

unity

is

the

If

increases

Thus

Vb

Also

distance

between the

strung

block

traveling

implies that

system

in

Fj

line

Fd WF1F5 For

for

conditions

on

the derrick

line

drilling

be

used on

imposed load

to

select

should

loading

arrangement

the load

applied

the

to

factor

shock

than the hook

Fd

used

safety

the

im load

10

APPLIED

TABLE

13

EXAMPLE

OF DERRICK LEG LOAD

CALCULATION

Load Load

Source

hook

fast

Total

Load

load

Win

deadline

TABLE 1.4 NOMINAL BREAKING CLASSIFICATION WIRE ROPE WIRE-ROPE

LegB

W/4

Wi4

STRENGTH OF BRIGHT

19

UNCOATED

Diameter

Mass

in

distribution

Note

1/2

0.46

9/16

0.59

5/8

0.72

3/4

1.04

7/8

1.42

Improved

define

Six

Extra

Steel

Improved

Plow

lbf

the

For

103400

159800

3/8

3.50

167000

192000

factor

1/2

4.16

197800

228000

230000 266000

264000 306000 348000 396000

304000 344000

strands

having

19

wires

per

also

derrick

entire

four

to

fails

times line

drilling

it

any

if

leg

convenient

is

Fde load

leg

shown

arrangement

to

load

maximum

the

greater

is

Since

derrick

equivalent

Fig

in

1.9

parameter sometimes drilling

7.39

Leg

n4

138800

6.50

on

Fde__W

2.89

7/8

the load

1.17

1/4

5.67

Table

in

calculated

on the other three legs

equal

is

113000

4.88

been

has

leg

EO.5

for

the usual

2.34

3/4

_____________ WEn-t-2I4En

tnaximun

1/8

5/8

W/2En

for each

that

which

Steel

lbf ___________ 26600 33600 41200 58800 79600

23000 29000 35800 51200 69200 89800

1.85

W/2En

the load

fails

Plow

W/4

WEn2/4En

Nominal Strength ________________________

lbm/ft

LegD

_______________

W/4

1.3

WIRE INDEPENDENT CORE IWRC7

Approximate

Leg

__________

W/4

-t-4I4n

than

Nominal

Derrick

LegC

Win

Wn

OR DRAWN-GALVANIZED

Leg_A

Each

on

W1En

line

ENGINEERING

DRILLING

130000

to

defined

factor

ficiency

load

Eq

by

given

For the block

and

Table

derrick

the

The

lines

normal

in

drillstring

crown

in

and The

to

hole

the

to

rather

with

the

and

block

the

rig it

below

well

the

service

to

of

the

and

the

drilling

of the

loss

important to keep the nominal breaking is

in

line

drilling

breaking

severe Failure

injury

Thus

keep

nominal

to

operations

result

tension

line

strength

subject

is

damage

personnel

dition

the

in

given

increases

between

tripping

can

line

drilling

values

efficiency

efficiency

strung

line

drilling

drilling

tackle

block

traveling

during

ef

derrick

Enl1 En4

En

of

load

maximum

the

1.9

de

number

derrick

For

1EEfl\1 Fd

1.2

efficiency

is

strand

Ed

various

derrick

of the actual

equivalent

load

equivalent

evaluate

to

the

is

as the ratio

maximum

the

used

arrangements

line

strength

con

good

new

for

one

of wire rope commonly used for drilling line is shown in Table 1.4 for various rope diameters The type

Correct diameter

way of

measure

to

wire

the

rope

Incorrect diameter

way of

to

wire

measure

rope

the

method

correct

illustrated

Drilling its

Fig

1.18

Measurement

of

wire rope

length

in

for

line

measuring wire

does

not tend

The most severe

diameter.7 in the

points of the

the

sheaves

line

or the

when

the weight

ports

in

rapid

and

sheaves

drawworks

drilling

rope diameter

The

that

at

to

the lap points

pickup

are

on

wear uniformly

wear occurs

points

the

of the

the rotary

table

of

drilistring

during the

is

over

pickup

on the drum

are the points

top of the

the

at

crown

bottom of the traveling block

acceleration

is

1.18

Fig

lifted

from

sheaves its

tripping operations

heavy

drilistring

in

block

causes

sup The the

ROTARY

DRILLING

PROCESS

most severe

stress

the points

the

of

wire

in

the

from

line

and the

involves

reel

storage

removing drawworks and cutting

the

cutting

be

not

between

maximum wear the

next

the

line

has

amount

of said

is

when

the

parameter

order

to

Devices

that

vibrational

ton-miles

of

90 46.3

will

vary

the rock

/1

to

types are

1.2

rig

drawworks

of

The

tofi this

the

block

ton-miles

rock

soft

as

arranged

shown

in

hp

Eight

and the

stores

the

The

to

and

the floor

rig

the

help

Eq

power efficiency The tension

have

the

the

the

is

fast

given line

is

as 0.841 given

1.7

used

braking

F1

En

445901bf

The maximum hook

by

PhE.pE0.841 The

maximum

available

500420.5 hoisting

speed

by two

opposing

given

by

supplied

changing

traveling

block

catheads

attached

In

being

The

dependent

on

of

to

also

impelled

drum

and

is

provided of

the

of

speed

excitation

the heat

developed

and

must ends

in

In the

magnitude

system means

provides

direction

both

brakes type

external

liquid cooling

Power

are used generated

auxiliary

braking

transmission the

heat

of the

both types

by

and

stop

lowering

brakes

of

fields

amount

the

the

For the hydrodynamic

electrical

is

to

hydrodynamic

type

magnetic

braking

move

to

when

of

types

to the rotation

fields

must be dissipated The drawworks easily

hp is

is

drum

The

capacity

amount

the

type

electromagnetic

current

horsepower

the

provided by water

is

magnetic rotation and

0.841

brakes

or

required

hole Auxiliary

are

opposite

the

300000

pro

the derrick

imposed

large

Two

braking

commonly

for in

of

weights

great

dissipate

direction

1.2

line

drilling

pipe into

during

type

The

the

for hoisting

required

must

brakes

is

Solution

Table

1.19

catheads

the

the electromagnetic

in

drum

the

the length

load

.17

Fig

also

string of

the

are

the torque

the

derrick

load

that

drawworks

transmission and

sustain

available

derrick

Fig

the

impending

the actual

drawworks

and

braking power required to raise the heavy strings of pipe The principal parts

traveling block in

The

Drawworks the hoisting

transmits

block tension

static

is

0.849or84.9o 450000

to

power

500

as

crown

Assume

factor

300000

It

equivalent

efficiency

of

input

as high

speed

hoisting

load

an

the

is

Typical

1.4.3

the

factor

efficiency

382090

Fde

wear

line

derrick

Ed-

drilling

the

system

450000 lbf

300000

The

and

determined

be

hoist

between

Eq

by

given

is

range from about to about 2000 for

line

provide

load

equivalent

in

of the

must

Calculate

maximum

derrick

maximum

1.9

lines

line

line

maximum

lbf

program

more rapid

when upward motion maximum hook horsepower fast

0.8418\

service

of

of

relatively

drilling

can

tackle

strung

traveling

1W

the ton-miles

hard

usually

drilling

1.8b

En

382090

conditions

must

Eq

by

given

the

maintained

drilling

In

is

for

or lower

and

load

1300000

vide

are

En

/10.841

to

simplicity

be

derrick

drilling

number

with

cutoff

375-in.-diameter

lines

actual

Fl

cutting

U.S

accumulate

and

500 for l-in.-diameter

the block

1.9mm

ft/mm

The

of

evaluate

slip-and-cut

The

experience

between

Example lbf The

ft

require

0.8418

number

must

would

stand

is

the

program to

for

the

problems may cause

than when

90-ft

pull

Care

length

ton-mile

that of

available

field

To

Fde

diameter

line

through

Note

automatically

are

in

moved

satisfactory

between cutoffs drilling

one

records

employ

of service

line

ion-mile

has

independent

is

Ton-mile

strung

the

is

block

mile

of

the

cut

is

when

taken

equal

slip-and-cut

rendered

traveling

distance

in

of

multiple

parameter adopted

have

to

line

The

it

lbf

ft/mm

46.3

between lap points

service

line

be

section

adopted

The

lines

before

line

must

care

cut

of the distance

API18

line

to

the

slip

line

from the

line

points

lap

times

300000

pickup points and

the

the

hp

service

drum

of

33000

by

pickup points Otherwise points shifted from one sheave are just

Likewise not

multiple

drilling

to

drilling

the

section

changes

several

slipped

taken

distance

line

off

changes

line

sometimes must

the

from

line

in

line

hp

Slipping

dead

the

new

the

Cutting

the

Slipping

program

of

feet

ft-lbf/min 420.5

Vb

condition

good

loosening

few

are

layer or lap

drawworks

the in

points

lap

new

slip-and-cut

placing

volves

end

of

maintained

is

scheduled

drilling

anchor

where

drum

the

The

points

line

drilling

line

Drilling following

these

at

on

begins

11

be

speed

of

transmitted

of the

for the to

drawworks

12

APPLIED

Friction

and

moving turns

of

type of

to

drillpipe

1.19Example

drawworks

used

in

rotary

drilling

of

being

available

as

type

1.5

Circulating

rig

and

other

mud to

fluid

the

of

the

the

The

Fig

1.20

Friction-type

the

to

to

the

to

With types

backward

to

being

pump

cathead

is

used

Both triplex

pumps

triplex

pump pumps are

pumps

as

great

lighter

their

and

on

only

output they

are

reasons the majority

into

of

the

are of

operation

the

laden

ability

with

of

range

abrasives

and

pressures of the

highability

of operation

ease

particles

positive-

move

to

and

pump

flow

liners

and pistons Example duplex shown in Fig 1.24

and

to operate

ability

by

rates

compres and

triplex

are

overall efficiency

product

of

the

of

to be

90

mud-circulating

mechanical

efficiency

Mechanical

efficiency

of the prime mover shaft

reciprocating

are the

the diameters

assumed

drive

not

reliability

wide

volumetric to

have

that

Triplex

placed

fluids

large

sion cylinders

chain

ex

several

pistons

The

For these

pump

mud pumps

by

of always

pumps

are

mud-

pits

duplex pumps generally are pump on both forward and

that

than duplex

advantages

over

powered

to

design

changing

Tongs

back

three-cylinder

strokes

operate

maintenance

1.21

and

The

pulsations

solids-content

Fig

pumps

strokes

piston

The

The

exception

piston

displacement

the

and

contaminant-removal

are single-acting

more compact

triplex

to

the

between

circulating

rig

mud

the

pumps

new pumps

of

the

through

the

mud

common

are

cheaper

tanks

drillstring

space

positive-displacement

double-acting

pressure

the

surface

of

and

duplex

two-cylinder

and

drilling

steel

equipment

mud pumps

perimental

forward

clay

through

bit

the

The

of

called

pump

to

typical

suspension is

is

drilling

1.23

Fig

the annular

hole

as

from the

from

up

equipment

generally

are

tongs

system

hole

in

travels

components

equipment

pumps

air-

tank

reciprocating

cathead.12

or also

illustrating

connections

and

principal

mixing

by

1.22

Fig

water and

in

and

include

system

of

joint

powered

the

through the contaminant-removal the suction

be

un

or

conventional in

the

can

screw

devices

shown

drillstring

bit

drillstring

shows

tongs

commonly

surface

through nozzles

1.21

diagram

drilling

high-pressure

to

from

is

mud mud pump

the

the

most

materials

The

needed

shown

cuttings

system

is

pull

between

the fluid-circulating

schematic

circulating

drilling

of

rock

progresses

the

System

function the

of

provided

Hydraulically

to is

or

number

cathead

torquing

tong

of

located

with

and

power

force

Fig

alternatives

One

major

torque

lifting

tension

friction

cathead

spinning

remove

the

pipe

the

powered

of

the

con

turn

in

The

the

generally

tightened

from

chain

Fig

the

provide

assist

floor

rig

controls

1.20

Fig to

drum and

cathead

sections

screw

the

housing and

drawworks

in

used

on the

on

rope

operator

second

used

be

can

equipment

the

by

shown

catheads

tinuously

ENGINEERING

DRILLING

and

itself

Volumetric

is

and

efficiency

related

to

the linkage

efficiency

of

pump and

is

the

usually

the efficiency to the

pump

pump whose

ROTARY

PROCESS

DRILLING

suction

is

1O0Vo

adequately

Most

tables

EL

two

be rate

Em

efficiency

efficiency

Generally

can

charged

manufacturers

mechanical volumetric

13

of

as

high

100%

of

circulating

pumps

are

used

on

on

installed

the rig

For the large

hole

portion

of

both pumps can be operated

parallel

to

the

deliver the

deeper

sizes

the

rates

required

well

only

one

the

second pump serves as pump maintenance is required

when

the shallow

flow

large

of

portions

and

needed use

most wells

as

pumps using 90% and

in

On

pump

is

for

standby

schematic diagram the showing valve and operation arrangement of double-acting pump shown in Fig 1.25 The theoretical displacement from double-acting function of pump is the is

rod

piston

diameter

stroke

length

pislon

the

volume

the

dr On

L5

liner

the

diameter

forward

displaced

given

is

d1 and

stroke

of

the each

by Fig

on the backward

Similarly

volume

displaced

is

stroke

of

1.22

Drillpipe

tongs

each piston the

by

given

BULK

df2dL Thus cycle

the

volume

total

by

STORAGE

pump

displaced

complete

per

two cylinders

having

is

given

Fp__2Ls2dl2_dr2Ev

pump

by

1.10 duplex

where The

EL

pump

called

the

the

is

volumetric

displacement

pump

cycle

is

each

by given

cycle

is

the

pump

commonly

factor

For the single-acting displaced

of

efficiency

per

triplex

piston

during

the

volume

complete

pump

pump one

by EARTHEN PITS

d1 L5

Thus

the

having

three

pump

factor

cylinders

for

single-acting

pump

becomes

NNULUS

3ir

FLEd12

1.11 triplex

The

Fig flow

rate

of

Duplex

the

pump

is

obtained

1.23Schematic

by

tor liquid

design

of

example

drilling

Triplex

Fig

1.24Example

mud

circulating

pumps

rig

fluids

design

circulating

system

APPLIED

14

Discharge

ENGINEERING

DRILLING

Discharge

Discharge P2

dL -I dr

Suctian

ar

Inlet

duplex design

Double-acting

1.25Schematic

Fiq

the

pump

factor

unit

time

In

multiplying cycles

per

terms

cycle

Suctian

Suction

and stroke

of

often

valve

number

of

usage

the

field

are used

of

operation

the

by

common

triplex design

Single-acting

and

single-

pumps

double-acting

for

fluid

Example 1.3 Compute

the

pump

barrels per

duplex

3-in.-diameter

passage

circulation

to

the

drillstring

interchangeably

to refer to

one complete pump revolution Pumps are rated for hydraulic maximum pressure and maximum the

inlet

of

the

the

pressure

pump

increase

through the pump pressure The

moving the

of

pressure

mospheric

the

the

pump

flow

In

the hydraulic

is

essentially

in

fluid

hydraulic

power

hp

units of

field

developed

If

at

pressure to

equal

power

to the discharge

equal

is

rate

rate

approximately

is

discharge

power flow

output times

pressure

psi and

for

18-in

rods

factor

pump

in

6.5-in

volumetric

and

strokes

of

units

having

90%

of

efficiency

Solution The pump factor for determined using Eq 1.10

pump can

duplex

be

p2LsEv2d

given

is

2.5-in

liners

gal/mm

by the pump

stroke

by

j-l80.9

Apq

1.12

11

1714

For

given

discharge

allow

will

but

pressure

maintenance

The

to

higher

to

Recall

U.S

that

there

gallons

in

desired

units

field

in.3

are 231

U.S

U.s

in

Thus

barrel

and

gallon

to

converting

42 the

yields

equipment

above

pressures

by

smaller

obtain

Due

rate

varied

size

liner

operator

be

can

rate

and

lower

problems

flow

conduits

about

3500

and

The

kelly

the

in

fluid

drilling

chamber

in.3/stroke

1991.2

in.3

gal/231

bbl/42

gal

by line

discharge

line

provide

the

of

and

circulation pipe

allows

valve

the

the to

The

the

that

permits

The

swivel

the

drillstring

to

started

is

vertical

contains

the

fluid

loss

The

steel

allows

formation

The

kelly

which

test

rotated

It

normally has

lost

and

rock

cuttings

pit

sometimes

pits

but

some

are

dug

in

the

more commonly are made reserve

is

is

pit

used

during

provided

and

fluid

drilling

also

produced

to

contain

drilling

for

for the

and

any well-

ing operations

Dry mud additives are

not

event

formations this from the surface pits

mud

earthen

This

and

bubbles

the

in

volume

cuttings

gas

Also

by

suction

fluids

surface

rock

finer

underground

to

bulldozer large

This

entrained

contaminated or discarded

of

section

of

replaced

with

that

cross

is

settling

earth of

is

fluid

drilling

of the

settling

separated

mechanically

an excess volume

for holding

surface

the

at

release

load

in

the

for

mud

time for

seal

hexagonal be

to

allows

are required

pits

drilling

rotating

pressure

through the swivel or

The

valve

rotary hose

drillstring support

rectangular

and

connection

rotating

surges

relief

pump

standpipe

surge

pump

pressure

the event

in

rupture

bearings

drillstring fluid

contains

of

from the

pressure

positive-displacement

flexible

movement

the

Mud

The

diaphragm

dampens

also

closed

against

roller

flexible

bbl/stroke

0.2052

and contains

1.26

separated

is

to or

to

pump

swivel

which

4-

floor

rig

Fig

see

portion

greatly

developed

prevent

chamber

by

the

on

hose

rotary

upper

the

connecting

located

surge

mud pumps

the

chamber

surge

pipe

manifold

standpipe

connecting

include

heavy-walled

pump

is

the

at

drillstring

6-in

gas

flow

rate

seldom are used

psig

the

stroke

in.3/stroke

1991.2

maximum

the

level

power

and

pressure the

changing liner

hydraulic

2.52

added

manually

often to

are stored

the suction

in

pit

sacks using

which mud-

ROTARY

DRILLING

PROCESS

hopper

mixing

mud

Liquid

from

However on many modern rigs bulk mud mixing is largely automated

and

used

is

storage

15

additives

agitators often

can

added

be

Mud

tank

chemical

mounted

are

or

jets

on

the suction

to

the

pit

motor-driven for

pits

auxiliary

mixing The contaminant-removing equipment includes mechanical devices for removing solids and gases

mud

from the

removed

are

one

mud

which

the

shale

shaker

Additional

in

in

solids

in

can be removed

they

much

to

liquid

and

finder

at

consists

the

the

through

fall

imparts

tornado

like

thrown

apex

heavier of

rotating

attached to conveyor cone creates centrifugal

heavier

moves

conveyor

the

to

particles

the

Most

The

housing

separated

Example

pulsation

dampener

1.29

throws

that

1.26

has

Rotation

interior

Fig

the

vortex

Fig

drum which

force

outer

and

of

the

centrifuge

its

mud

the

hydrocyclone

cone-shaped

screw the

in

through

exit

motion

fluid

bottom

decanting

cone-

is

solids

the

the

at

particles

The

top

of

The

of

great

decanting

1.28

whirling

housing

lighter

the

too

by hydrocyclones and

shaped housing that

the

amount

the

Fig

1.27

from

mud becomes

the

hydrocyclone

centrifuges

are

When

DIAPI1RAGM

is

over

Fig

gases

FLEXIE

hole

the

in

and

pit

settling

screens

from

shown

solids

cavings

shale shaker

vibrating

is

of

The

returns

it

operation

the

ground

finely

as

and

cuttings

shaker

more

or

passes

separation

occurs

rock

coarse

the shale

by of

composed

mud

The

of the

screw to

particles

the

discharge

When

amount

the the

leaving separated

settling

shown

is

on

from

chamber

surfaces

flat

allows

Mud

reduced

gaseous

and

of

as

gas

may

countered

volume

of

together

hole

that

and

gas

to

foam

than

with

production

foam rate

of

rock

in

operation

foam-type

mud

or

the

and

improvement second procedure

water-producing

zone

than

is

As cost

and

water

fluid

the

rate

of

often

encountered

solved

by

into

Drilling air

is

is

of

the

used to

the

rates

but greater water

maintaining offsets

VORTEX

stick

from the

be

eventually

that

to

can

with

FJNDER

en

are

tend

VORTEX

with

significant

blown

easily

drilling

less

increases

also increases

formations

surfactant

of

are generally water

be

mud

compared

as

CHAMBER

FEED INLET

higher

penetration

producing

somctimcs

use

most

drilling

in

cuttings

can

longer

mixture

make

with

no

the

gas

when

However

problem

injecting

with

The

much using

difference

are capable

water

This

shaker

high

drilling

in

obtained

is

obtained

mud

drilling

1.27Shale

the

have

when

results

than

rate

be

Fig

more

when

used

bit

low permeability fluid

rocks

be

the

by

order-of-magnitude

rates

by the

from the mud

can

fluid

drilling

penetration

which

layers enlarged

line

an extremely

sedimentary

thin

gas

inclined

at through the chamber about mud jet located psia by

of

encountered

strength

pump the

across

been

separated

drilling

formations

in

have

that

be

to

vacuum removes

flows

be

chamber

drawn

is

pressure

the discharge

mud

chamber

the

in

pressure

easily

An

The

gas

can

it

vacuum

chamber

the

the gas bubbles

reduced

in

of

top

formation

too great

1.30

Fig

in

mounted the

entrained

becomes

degasser

using

degasser

of

pit

seal

-UNDERFLow

the

drilling

when off the

Fig

1.28Schematic

of

hydrocyclone

OPENING

APPLIED

16

ltnt

fl...l

nn

C.nnfngnl

High

Pool

Con.oIl.d

L.o.I

Of

Ln

fly

On.flo

Pofl

Solids

D.nho9

of

decanting

D.nhog Adsob.d

Liqo.d

1.29Schematic

Fig

An

cp..d

WPh doltqnid

CoIl

Sn.n

tonn. Howl

Cnnn.yon

D.nnn Sl.gbtly

ENGINEERING

DRILLING

1.30Schematic

Fig

Only

vacuum

of

chamber degasser

centrifuge

Al

FLOW

HAMMER

HAMMER

UP

POSITION

Fig

Schematic

1.31

zone The

permeable plugged

of

silicon

tetrafluoride

plastic

causes

contacts reacts in

the

the hot with

the

the

pore

isolated

for

sufficient

catalyst

gas to

formation

of

the

fluid

the

tetrafluoride

Best

results

by use of must

pressure

it

gas silica

are

packers

be

used

ob is

Also exceed

to

reserve is

formation pressure Since this technique requires expending considerable amount of rig time the cost of isolating numerous water zones tends to offset the rate

Both

air

An

fluids

improvement and air

natural

allows

standpipe

at

circulating

the

1.31 The

that

the

ft/mm water

the

used

injection

minimum

or

natural

surfactant

are

be

to

for

air

An

is

pumps the

as

drilling

pressure into

the

example

rig

is

usually

velocity

small

gas

drilling

pressure

into

used

injected

pressure

annular

Also shown and

been

gas

desired

system

Fig

have

compressor

regulator

pit

used

at

line

to

an

is

shown chosen

about

used

discharge

to

in

so

Even

drilling

rig

floor

gas

seals

from spraying from

returning

is

the

Small

explosion with

of

amounts

compressed

end of

must be taken

care

used

the

at

continuously

if air

hydrocarbons mixed

air

formation be

can

quite

dangerous The air

is

drilling

subsurface used for drilling with equipment used for normally the same as the equipment in few areas where the with mud However

rock tool

the

cutaway

bit

device tool

is

shown

the bit

percussion break

inject

of

350

psia the

to

tool

hammer

concrete

hammer

Fig

in

The

of

in

an

high

example

Gas

repeatedly

similar

flow

in

percussion

through

tool

operation

causes

1800

the

on an anvil

by construction normal operating about

above

drillstring

1.32

percussion

formation

the

strike is

used

Under the

used

view

hammer

causes

above

be

extremely

is

strength

may

percussion

3000

line

burned

is

the

air

line to the through blooey ft from the rig If natural gas

200

least

in

the gas

prevents

vented

is

the blooey prevent

below

floor The

rig

usually

it

compressive gas

and

used

tool

installed

the kelly

through the annulus then

the

drilling

head

rotating against

the

formation

water-producing

injection

be

when

solidify

and precipitates

rock

injection

with

1.32 Percussion

Fig

or

plastics

Silicon

formation water

drilling

can

injected to

begin

air

zones

low-viscosity

plastic

spaces

when

tained

water-producing

of

use

by

for

system

circulating

DOWN

POSITION

to

the

crews

to

pressure the

blows/mm

bit

to in

ROTARY

PROCESS

DRILLING

17

HOSE SWIVEL KELLY

BUSHING

KELLY

ROTARY

DRILL

DRILL

TABLE

PIPE

COLLARS BIT

1.33Schematic

Fig

addition rates

proved

normal

the

to

in

of

im

been

tool

this

whipping motion that crown

the

block

The Rotary

The

rotary system achieve

to

rotary of

drive

rotary

main

swivel

table

parts

and

drillpipe

and

swivel

is

the

attached

gooseneck

The swivel

kelly

outside to

Torque

first

to

is

kelly

possible

of

Rotation

of

to

fit

inside

to

crooked

the

hose

kept

bushing

causes

the

must bit

opening

is

and new

be

from turning

joint

when

tongs

Power

for

provided

as

in

some

hydraulic

and

kelly

the

on

the

kelly

rubber

mounting

in

The

1.36

Fig

the

accepts

kelly

for passage of the enough hole The lower portion of

the

of

on

pipe the

pipe

driving

by an cases

in

that

contoured to accept slips that grip the from falling it into the hole prevent

backup

of

table

large

run

lock

drillstring

of

is

inexpensive

wear

for

place

the

relatively

prevents

rotary

be

to

drillstring

through

as straight

kelly

for

pipe

operation

right-handed

to

in

while the

square

easily

kelly

the master

must be

is

kelly

gripped the

bushings

capacities

pipe

of the

be

opening

the

down

of

in is

on the upper end to of the drillstring

between This

provides

threaded

rotation

used

is

and

of the drillstring

thread

left-handed

drillpipe

wear on

unnecessary swivel

bushings

kelly

swivel

example

keep the kelly centralized is shown example rotary table

the

largest

below

and

protector

block

rotary

load

their

transmitted

bushings which the rotary table The

provides the

section

it

of

bail

the traveling

swivel

cross section

permit

kelly

of

for

according the

is

hexagonal

turning

the

of

connection

are rated

The

hook

of

weight

The

rotation

the

to

the

supports

permits

ward-pointing Swivels

1.34

of

section

threads

kelly

sub

saver

joint

short

An Fig

swivel

drillstring

or

normal right-hand

collars

The

and

1.33 The

are the

rotary

1.35 The

permit kelly

in

line

kelly

in

first

of

large part

and

kelly

shown

diagram

nomenclature of the

arrangement shown in Fig

system

used

equipment

schematic

and

is

system

the rotary

drill

of the

all

rotation

bit

the

illustrating

of

Fig on the lower end and

System includes

results

drilling

throughout

connections

view 1.6

view

1.34Cutaway

Fig

Penetration

have

formations

by use of

significantly

action

rotary

hard

extremely

system12

rotary

is

the

power

is

taken

added

being

rotary rotary

without

table

the

the use

usually

is

drive

from the

between

to

the table

prevents

unscrewed

independent

transmission

is

rotary

However drawworks

the rotary

table

and

AP1UO

18

Fig

TP

1.35W4ew

ef

keIW

aid

keIy

HtG

bis

375

Fig

1.3- xamst

rGtay

ta

jg

1t3Y-

ampIe pwr

sub

ROTARY

PROCESS

DRILLING

19

TABLE 1.5 DIMENSIONS

per Foot

of

Outer

Diameter

21s

4.85

1.995

1.437

6.65

1.815

1.125

6.85

psi

psi

psi

6850

11040

13250

16560

11440

15600

18720

23400

1.875

2.441

1.187

2.151

9.50

S-135 psi

10470

12560

15700

12110

16510

19810

24760

110

350

16840

23570

30310

237

323

452

581

8600

12040

15470

231

323

415

10830

15160

19500

285

400

514

7900

11070

14230

270

378

486

25160

12350

12820

14.00

3.340

2.375

11350

14630

17030

41/2

13.75

3.958

3.156

7200

8920

41/2

16.60

3.826

2.812

7620

10390

12470

10910 15590

4/2

20.00

3.640

2.812

9510

12960

15560

19450

16.25

4.408

3.750

6970

8640

10550

19.50

4.276

3.687

7390

10000

12090

15110

6970

21.90

4.778

3.812

6610

8440

10350

12870

24.70

4.670

3.500

7670

10460

12560

15700

9/16

19.00

4.975

4.125

4580

9/16

22.20

4.859

3.812

giio

25.25

4.733

3.500

6%

22.20

6.065

6Vs

25.20

5.965

6%

31.90

5.761

shown

standard

often

and

17690

242

331

463

595

17560

22580

302

412

577

742

7770

10880

13980

328

459

591

9500

13300

17100

290

396

554

712

6320

610

12 060

15500

321

437

612

787

7260

9900

13860

17820

365

497

696

895

5640

5090

950

267

365

5480

6740

6090

8300

317

432

6730

8290

7180

9790

369

503

5.187

3260

4020

418

4010

4810

4160 4790

307

5.000

6540

685

881

4.625

5020

6170

6275

8540

minimum

are

6160

values

with

7210 9200

6430

no

safety

twist-offi.e

swivels

or

swivel

bushings

achieved

and

swivel

Excessive

One

greatly reduces if

torque

often

torque

torsional

subs

power can

be

the will

due

failure

factor

S-i35

used

to

to

or

below

for

The

of

the

replace

the kelly rotation

devices

and

speed sub

power

seamless

diameter

torque in

of

has

Drillpipe

is

hot-rolled developed

specified

by and

per foot steel grade dimensions and strength of API and S-135 are shown in

grades

Table

1.5 Drillpipe

length

ranges

is

furnished

APi

the following

in

joint

drillpipe

of

joint

pipe

must

allow

The

the

631

tool

joint

joint

by

The

by

walled

male portion

of

walled

smaller

drill

collars

subs

Fig

assist

in

30

the

to45

and

well

of

recorded

depth

terms is

are

of

fastened

called

together

tool joints

the

is

Fig

called

pin The

of

the

pipe

given

weight

this

the

in

of

the

is

pipe

volume

diameter

string

of

knowledge by the

often

contained

Stabilizer

drill collar

centralized

or displaced

capacity

purpose and the

borehole

the hole straight

to

thin-

relatively

for

it

the

drill collars

area

apply

used or per

the is

drillstring

to

refer

annulus unit

the capacity

to

ex

length of

pipe

by

each to

Afd2

1.13

during

in

the

1.38 The box and

the

portion

term

units

of

to use

operations in

cross-sectional in

to

is

are thick-

collars

of the

tool

rotated

is

drillstring

rotary

used

are used

the

drilling

contained

pressed

keep

the

facing

wear of the

drillstring

drill

between

often

keeping

many

the

The

too great

helps to

1.39

the

tendency

clearance

38

the length

is

drillpipe

The

when of

buckling

was

in

hard

carbide

tubulars

steel

22

total

the tool joint is

The

was

failure

on the outer surface of the

collars

drill

heavy

the bit

Similarly

means

portion

of

to

operations joints

section

lower

composed

thread

concentrations

stress

the abrasive

wall

borehole

the

to

each

diameter the pipe is said to rounded-type thread is used

the

reduce

the pipe achieved

is

designs but thread

of

to

of

thickness

has

provide

to

portion

extra

manufactured

is

attached

is

drillpipe

thicker

tungsten

box

27

carefully of

because

the

U.S Standard

The

pipe

required The

unique length

measured

drillpipe

drillstring

female

has

be

determination

drilling

489

463

joint

of

the

drilipipe

root

volume

Since

This

the internal

early

sometimes

In

tool

rest

If

upset

18

most commonly

used

the the

joint

drill

in

thread

In

Lengthft

is

the

now on

to

Range

Range

359

steel

an internal upset

used

of

composed is

weight

The

length

use

API

tubing

for drillpipe

specifications

than

stronger

frequent

are

shown

is

is

drillstring

common

in

drilipipe

walls

called

have

Drillstring

of rotary of

type

just

sub These

power

thicker

is

motor incorporated

hydraulic

major portion

drillpipe

11770

standard

which

to

drillpipe

1.37

outer

9150

are

by decreasing

installed

table

rotary

wide range

for

combinations

This

excessive

drilistring

through

power

used

stuck

the subsurface

conventional

range

5530

only

prevents

becomes

in

pierced

209

13760

is

result

its

7.940

9830

strengths

drillstring

The

13

12540

for information

drive

loadings

drilipipe

120

27850

drilipipe

rotary

Fig

386

489

10310

available

245

300 272

20130

the

190

214

380

8410

in

136 157

194

16770

is

249

272

12300

kelly

194

199

1.750

Power

138

24840

2.937

in

176

101

17140

3.476

break

137

19320

2.602

shock

98

13340

11.85

the

70

800

15.50

tensile

18900

520 10

and

10500

17830

15140

yield

lbf

29750

21170

in

lbf

23140

12110

internal

lbf

13870

16940

used

Ibi

psi

9910

10040

API

1000

psi

16530

14110

grades

1000

12120

10350

Collapse

1000

15470

1.875

Jot

1000

11350

2.250

51/2

S.135 S-135

14700 21660

2.764

8330

Strength

psi

psi

2.992

51/2

DRILLPIPE

Pressure

ij

13.30 31/2

Yield

Internal

Upset

in

10.40

21/s

Pressure

Full

in

Ibf

2% 2%

UPSET

INTERNAL

Tensile Collapse

At

Internal

Coupling

in

SEAMLESS

Diameter

With

Diameter

API

Internal

Weight Size

AND STRENGTH OF

of

the

of the inner

the capacity

and

outer

A0zddf

of

an annulus

diameter

A0

in

terms

is

1.14

APPLIED

20

The

often

term displacement

cross-sectional

volume

of

units

of

of

area

section

steel

of pipe

is

is

given

used

to refer to the

the pipe

length

unit

per

in

The

displacement

consider steel

more exact

using

fluid

displaced

the tool joints or calculation

displacement

SIZES

AND

DIMENSIONS

3/2 Dimension

FOR

Drillpipe

_________

Inches

Symbol

3/

4% 430 40/32

is

mm

Inches

92

4/i

9/

1.38Cutaway tool

joint

Table

1.6

Range

gives

average

drilipipe

displacement tool

including

joint

displacements

6%

121 11

523/32

view

tables

1.4

10

and

ID

drill

collars

Assuming

that

compute

to circulate

drilipipe

the

number

mud from

of 7000 ft composed and 500 ft of 8-in OD

when the of

pump

the surface

Inches

5/ 32/4

159

63/s

17

.531

55%

145

mm 13C 95 162 13 150

10

for

example

254

iig

1.39Example

stabilizer

remains

in

cycles required

to the

178

254

9.875-in

drilling

borehole

Drillpipe

83

dimensions

gauge

is

drilistring

19.5-lbm/ft

DESIGN

t78

241

5-in

borehole

manufacturer

119

.672

115

of

by 2.75-in

When

needed

mm

3%

not

by the thicker

couplings

41/2 Drillpipe _________

165

LB

do

1.15

XTRAHOLE

GRADE

54

Fig

Eq

by the tool joint or coupling

provided

used for

Example

calculated

at

be

values

1.15

the additional

sections

can

by

A_dd2 Displacements

in

expressed

ENGINEERING

DRILLING

bit

and

from

ROTARY

DRILLING

PROCESS

21

TABLE 1.6AVERAGE Size

DISPLACEMENTS

of

Nominal

Diameter

Weight

in

Tool-Joint

6.65

internal

flush

internal

flush

2/8

10.40

Type

31/2

13.30

full

15.50

0.23 0.36 0.34

263.0

0.00379

hole

13.90

197.6

0.00506

0.46

hole

13.40

204.9

0.00488

0.44

flush

13.80

199.2

0.00502

0.45

flush

16.02

171.5

0.00583

0.52

15.10

181.8

0.00550

0.50

15.10

176.1

0.00568

0.51

full

hole flush

17.80

154.3

0.00648

0.58

xtrahole

18.00

152.7

0.00655

0.59

slimhole

17.00

161.6

0.00619

0.56

17.70

155.3

0.00644

0.58

21.40

128.5

0.00778

0.70

hole

21.30

129.3

0.00775

0.70

hole

20.50

134.0

0.00746

0.67

full

2000

hole

flush

xtrahole full

slim infernal

Solution For

0.00251

0.00397

10.40

internal

to

398.4

internal

16.60

of the hole

6.90

21.20

129.5

0.00772

0.69

22.82

xtrahole

24.10

114.0

0.00877

0.79

32.94

xtrahole

36.28

19.50

xtrahole

20.60

25.60

xtrahole

26.18

42.00

xtrahole

45.2

the

surface

flush

the

if

ft

Stand

bbllft

ft/bbl

10.90

internal

0.1781

bbl/90

lbmft

internal

14.00

41/2

DIsplacement

Air

hole

slim

is

PIPE

251.9

slim

bottom

DRILL

Weight

Ibm/ft

2/g

factor

RANGE

Actual

Outer

in

the

FOR

0.01320

1.19

133.3

0.00750

0.68

107.4

0.00932

0.84

0.0165

1.48

75.7

60.8

pump

bbl/cycle units of

field

feet

and

barrels

Eq

bbl

12

dH

1.13

becomes CAPACITY gal

un

/1

OF

PIPE

in p_

\231in.3/\42gal/

ft

CAPACITY

iT

OF

ANNULUS

dd

bbl/ft 1029.4/ Table

Using

drillpipe

the

1.5

Ibm/ft drilipipe

DISPLACEMENT

is

inner

in

4.276

diameter

thus

5-in

of

the capacity

OF

PIPE

19.5

of the d2

is

4.2762

0.01776

bbl/ft

10294 and

the capacity

of the

drill collars

Fig

and

1.40.Capacity

displacement

nomenclature

is

752

0.00735 bbl/ft 1029.4 The The

mud

number of pump to the

bit

is

cycles required

to circulate

new

pump

by

given

70000.0326

0.00735

Similarly given

circulate is

mud

given

from the

by

500bbl

500bbl 0.1781

719 cycles 0.1781

to

cycles required

bottom of the hole to the surface

bbl/cycle

bbl/cycle

the annular

capacity

outside

the

drillpipe

2858

is

cycles

by

9.8752

_52

1.7 0.0704

and the annular

The capacity

outside

9.8752_82 1029.4

the

drill collars

is

flow the

0.0326

The Well Control System

bbl/ft

1029.4

bbl/ft

fluid

well of

control

bt penetrates pressure

exerted

system prevents

formation

by

the

in

fluids

from

permeable excess

drilling

of

the

fluid

the

the

uncontrolled

wellbore

formation that hydrostatic

formation

When has

pressure fluids

will

22

APPLIED

ENGINEERING

DRILLING

ItlU1

L_J FMG

PERMEU Kick detection

1.41

Fig

during

operations

drilling

1.42Two

Fig

alternative

detection

begin flow of

formation fluid

drilling

system well

the

mud

blowout

to

increase

under

from

away

system

formation

fluids

the worst

results

and

rig

disaster

equipment

flow is

can

.that

of

the

in the underground reservoir and environment near the well Thus the

system

one

is

of

more important

the

drilling

Both

that

devices

transducers

The

active

by

High-

turn

on

and

increases

or

increase

in

mud

mation indicates

surface

fluids that

may

be

drilling

of

means

low-level horns

decreases

volume

entering fluid

is

flow

illustrated

increase

well

in

that

over

floats

in

pneumatic

the

volume

alarms

can

when

the

indicates

that

well

being

or

on the

significantly

the

each

rig

of be pit

An for

decrease

lost

to

an

un

derground formation

Mud

flow

indicators

the

to

help

detect

kick

fluid

paddle-type In

the rates

If

rate

the

level

into

the flow

are

used

to

in is

on

panel

and

out

different

warning will be given While making trip circulation

in

used

counter

well

rate into

are

level is

stroke

the

appreciably

devices pit

sensor

pump

addition

floor displays

rig

well

of the

gain

or

loss

volume

significant

into

do

of

pipe

the hole

keep

the hole

Kick

to

replace

detection

measure

the

during

the

hole the

progress Small

volume

the

If

volume

of

pipe

required the hole

fill

removed the

alternative

With

maintained

full

Periodically

The

pump

either as pipe

the top

tank

trip

of

is

is

be

in

of

Two

markers illustrated

from

is

well

mud

the

tank

trip

in

hole the

using

type

less

is

usually

the

refilled

gravity-feed

tanks

are

arrangement withdrawn

to fill

means

best

arrangements

trip-tank

1.42

is

to

may

kick

Trip monitoring hole fill-up volume hold 10 to 15 bbl and have 1-bbl gauge

ac

is

indicator

volume to

hole

pumped removed

indicator

fill-up

fill-up

provide

be

the

operations

hole

required

pipe

tanks

trip

of

volume

mud

from

must

tripping

the

accurately

mud

full

and

stopped

is

removed

is

complished through use of The of the hole purpose

must

to prevent mud lower than the bell nipple slightly The required from being lost to the flowline fill-up the volume is determined by periodically checking

be

fluid

level

installed

in the

on

the

tank

trip

rig

hole

determined by counting hole not

are used

operations

operation

used to sense the flow

Fig

device

indicates

and

lights

volume

an

employ

recording

device

pits

the

is

usually or

pump

usually

to

recording

to

from

by the

indicators

devices detect

can

returning

connected

are

indicator

of these

circulated

being

operations

pit-volume

is

similar in

flowline

than

during

mud

of

volume

preset

the

Thus

can cause

well much

the

an

in

called

is

Blowouts

operations

The operation

electrical

all

the

1.41

Fig

floor

under

well

drillstring

control

perhaps

is

by use of

indicator

pit

of

detection

which

closing the

flow

the

on the rig

achieved

Pit

flow

drilling

control

Kick

the

dicators

control

gas reserves

systems

in

well

drilling

life

damage well

the

This

during

and

oil

well

kick

the

moving diverting

of

uncontrolled

of

somewhat

for kick

arrangements

tripping

more quickly The more commonly

and equipment

Failure

loss

well The

the presence

formation fluids and

the

remove

the

in

The

circulating

and

personnel

occur

the

detecting

density

pressure

kick

surface

to

pressure

into the well

called

is

from

fluid

drilling

fluids

permits

at

the

the

displacing of

trip-tank

during

large

is

be to

filled

used

The

level

since

provide

the

When fill-up

pump in

strokes

pits

accuracy

tank

are

is

should

each

one of the active

active

sufficient

trip

volume

time

pits

not be the

should

normally too

ROTARY

PROCESS

DRILLING

23

Th0r

T-

-J

H-

iz--

io

__--___-i

ti

C-

N-

-L

_-___

--

T-

---

---__-0_

ii

-i Fig

The flow

of

by

stopped

of

special

are

referred

The

BOP

must be

the

well

under

without

In

several

An

ram preventers

Ram

Pipe rams

match

the

pipe

be

when Blind

closed

with

stop pipe

have

the

the

when

only

failed

well the

Shear

well

the

pipe

all

Ram

pressures

rams and

of

2000

synthetic

The

stop

flow

rubber

that

pipe

rubber in

the

screw-type

to

element

Modern

hydraulic

for

developed example

at

and

maximum

psig

are

annular are

preventers

available

5000

10000

for

pump

and

oil

characteristics

The

parts

packing

hole

sometimes from

the well

contracts

conforms

Most

called

annular

in

to

bag-type

using

the the

fluid

ring of

passage of

the

also

will

shape

preventers

pressure

and

must

the

necessary

to

strip

pipe

lower

closed into the hole If it is best to strip back circulation

of the

has

the of

accumulator

good

non-

point

The

lubricating

with

synthetic

pressure-

vary

the

closing

important when

is

fluids

with

taken

bottom

formation

power

is

with to

pipe

kick to

gal

3000

system

ability is

or

independent

compatible

preventers

120

secondary

have

be

or

usually

equipped

is

The

Ac

low freezing

of the well-control

system

BOP

operator

use fluid

should

also

the

maintained by

is

stand-by

with

oil

accumulator

on

that

An 1.45

reserve

1500

of

the

those

sufficient in

40 80

of

so

accumulator

hydraulic

hydraulic

have

immediately

maintained

The

supplying

accumulator

For safety

power

BOPs to

Fig

in

of the units

pressures

times

close the well

to

of all

still

operating

common The

corrosive

rubber

and

all

pressure

systems

shown

is

fluid capacities

at

well

control

fluid

to close

once

the

an

The

the rubber

accumulators similar

capable

is

fluid

once

used for closing

systems

accumulator

least

are

on

closed

are

closed

aircraft

accumulator

high-pressure

ability

working

fails

system so that

drillstring

fluid

vertical

source

closed

the

are high-pressure

pumps

are

hydraulic

are designed

contacts

small

BOPs

annular

hold the preventer

helps

This will

the

if

preventers

The

and

for

psig

10000

In

preventer

nular

rams

and

ram

available

and

addition the ram preventers have device that locking can be used to close

regulating

preventers

preventers

the

cumulators with

IS000psig Annular

Both

blind

the hole

2000 5000

hydraulically

the

are

preventers of

when closed rams

preventers

Annular pressures

rig

in

Shear

of

normal

are

hole if of cross section necessary annular preventer is shown in Fig 1.44

open

stop

rams

drop

to

an

tyne

of

blind

not

one

stack

inadvertently will

close

preventer

of

preventers

called

the hole but

drillstring

drillstring

from

flow

working

the

size

designed

are if

are

size

one

Rams

hole

each

they

the

ram

on

which

which

drillpipe

in

drillstring

by using

toward

than

stack the

flatten

pressure

openings

additional

in

is

will

shear

more

If

fluid

elements

moving

for

to

preventer shown in Fig

is

ram must match

BOP

pipe

rams

to

cause

allow

packing

sizes

from

allowed

accomplished

by

pipe

hole

the

in

no

from

flow

designed will

the

used

rams

of be

should

semicircular

of

use

in

in

is

close

the

have

the pipe

currently

must

pipe

two

close

diameter

Thus

drillpipe

the

should

preventer

have

that

other

designed

the

and one annular

preventers

sides

opposite

flow

When

stack

are

ram

of

example

1.43

usually

in

stack

terminating

through the well annulus under

objectives

used

conditions

pressure

BOP

is

called

BOP

movement

hole

well

addition the

circulation

These

the

releasing

occur

of

drilling

ram-type blowout

kick

BOPs as

collectively

capable

all

in

is

drillstring

to

by

devices

BOPs Multiple

blowout preventers series

pack-off

to flTi

T-_

1.43Example

from the well caused

fluid

use

--

to

it

is

the preventer during allow

trip efficient

from the well The

24

APPLIED

1.44

Fig

Example

blowout

annular-type

of

application preventer

accumulator

Example

much

too

during

closing

stripping

1.46

reduce

the hydraulic until

operations Stripping annular

closing

there

is

accomplished

is

preventer

usual

pressure

during

when

the

is

to

stripping

of well

easily

the

rapid

procedure

most

However

to

causes

leakage

slight

blowout

pressure

fluid

using surface

the well

is too great stripping must be done using two pipe ram preventers placed far enough apart for external tool joints to fit between them The upset

pressure

and

upper

lower

rams

must

be

alternately as the tool joints are

between

Space operations

is

also

spools

are

the annulus

used to

from

line

kill

the

or simply

must

large

string

the

of

casing

to

BOP stack BOP stack

The casing

braden

head The head

is

the

in

possible

to

pump

Conduits

flowline bore

enough be

place

attached

to

high-

stack These to

The

One

used shown

casing

welded

the

to

the

first

string

of

stack for

of

BOP

the

of formation pressures

type

of

pressure

well

this

purpose

is

for

uses

and

Note

that

spool

The

casing

head

and

the

and

head

up

RSRRA

with

ram

drilling

ram preventers

defined

proceeding

in

to

spool series

above above

an

the

drilling

bell

the

the

at

the

nipple

use

attached the

an ram

starting

denotes

preventer

typical

denote

denote

to

on the

by

arrangement

to

is

the

and

working

denote

to

letter

Arrangement stack

the

letter

arrangement

shows

15000-psi

letter

on

recommended

1.47

Fig

10000-

the

used

several

stacks

the

the area

in

con

varies

depends

procedures

presents

BOP

of

preventer

casing

control

service

preventer

two

arrangement

API

operator

BOP

clearly

arrangement

stack

used

magnitude

spools

casing

BOP

The

the

the

should be marked

used

panel

arrangement

nular

the

stack access

siderably

line

called

of

BOP

floor for easy

operating

the derrick

on

kind

nomenclature

using

well Also

the

Fig 1.46

an

casing

head sometimes

in

release

removing

for

panel

placed

is

by the driller The controls and with the identifiably

Thus is

control

usually

the

next

seal

pressure

in

strings

arrangements

the

without

pressure

arrangements

drilling

permit

provide placed

strings

that

the

choke

operating

provided on the casing head to release any accumulate between casing might

outlets are

with

to

must

It

casing

into

pump

into

used

All to

in

put

of

from the annulus

annulus may include

diverter line

have

it

used

conduit

called

is

point

make

Drilling

attachment

permit

fluid

spool

for

panel

preveriters

well

the

in

for subsequent

The

used for stripping

drilling

given

or release

closed

nulus

by

flowlines

high-pressure

fluid

provided

opened

lowered through

preventers

flowlines to

pressure

BOP

ram

and

closed

cemented

control

remote

Example

system

operations

wear of the sealing element The

ENGINEERING

preventer

Fig

1.45

Fig

DRILLING

to

of the

ram preventer drilling

spool

ROTARY

Fig

PROCESS

DRILLING

surface stack

1.47Typical

blowout and

for 10000arrangements pressure service

and

annular

an

In

some

cases

annulus

this

done

is

Rotating

when

air

well

or

heads

very

However

this

must

be

in

the

drilling

known some

to

When be

can

the

Several

to

.49

cock

formations unless

the

in

gained

this

Ellenberger

in

is

stop only

additional

valves

the

hole

the

flow

can

be

the drillstring

left-hand

having

and

lower

blow

placed called

practice

is

formation

in

BOP

the

from the

used

These

the

to

valves

stack

aririulus

include

lower

operations

149

addition

Fig should

position

the

if

internal

drillstring

1.50 be

if

the

begins

in

stuck

is

that

also

is

is

are reqiured accessible

in the

in

hole with

used

can be placed

flowing

similar as

to

the

This drillsl

during

the valve

an

checLvalve

are available placed

not be

cock

type

tripping

preventer

BOPs

the

in

are an

open

mud

permit

the

reaching

when

installed

open

drilistring

Once

position

be

can

circulating

operations

normally

closed

the

or the dart

choke

from

from

and

the

on

control

choke

shown

well

The

kick

through is

floor

rig

are

panel

well

the

The adjustable

remote panel

choke

1.51

Fig

in

for

used

system

shown

is

circulated

is

adjustable

An

example 1.52

Figs

in

an

controlled

1.53 Sufficient pressure must be held against the so that the bottomhole pressure in well by the choke above the formation the well is maintained slightly and

formation

Otherwise

pressure

to enter the

Mechanical flow

of

volumes frequently stresses

on

system

can

The

rapid

accompanied Thus care should available against

flexibility

in

reaction

the piping

required The

of

weight

abrasion

the

bends than

resistant

bend API8

created

number

required sharp

target

at

severe

when

release

of large

surface

piping

extreme vibrational

be

taken

from

all

valves

use

some

the wellhead

and

members

the lines

all

Also

thrust

and

to

anchor

to

to

supported on structural are not

the

by

and

pipe

high-

emergency quite

pressure

through

fluid

securely

stresses

the be

is

strongest

con

would

fluids

well

stresses

kick

handling

rather

is

after

drilistring

the valve

high-pressure

In

drilipipe

installed

is

control

BOP

BOPs BOP

or dart

will

it

released

The

internal

by screwing

the valve

BOP

in

internal

ring before

the

because

into the top of

with

shown

internal

of

in

the

needed

pressure

kel

down

Internal

be

be

dart-type

cocks

might

valve

is

well

can

kelly

drilistring

valves

Ball

also

Two

kelly

the

the hole

in

pumped

be

tinue

kelly

threads

right-hand

lower

blowout

rotating

bottom of the well

flow

prevent

above

placed

is

having

The

valve

down BOP

kelly

Fig

cock

kelly

emergency

An

threads

the kelly

dri//stein

because

the

the

entering

experience

to

also

low permeability

very

from

Fig

employed They

dangerous

has

in

and internal blowout preventers Shown in Fig is an an upper kelly Generally example kelly cock

cocks

an

are

fluids

is

the

in

when

Texas

drillstring

from inside

ly

safe

of west

used

fluid

area For example

local

the

are

low-permeability

established

be

areas

commonly

formation

drilled

around

shown

is

drilling

practice

formation being This

BOP

as

from

slowly

pressure

seals

hack

stripped

on

stack must be used

most

used

is

gas

used when

be

BOP

the

rotating-type

1.48

can

slight

ers

conduct

to

surface

head which

rotating

the top of

at

kelly

with

desirable

of

view

working

the rani prevent

be

may

it

operations

drilling

the

above

preventer

1.48 Cutaway

Fig

preventer

15000-psi

fittings

so that

is

should

bending

piping Because of fluid of bends should be minimized in

the

should

be

turns the point

of

or

sweep-turn have

fluid

an

bends abrasion-

impingement

in

the

presents

several

recommended

choke

26

APPLIED

ENGINEERING

DRILLING

CD

Body

PARTS

stem

LIST

Item

Part

Sub

Plain

CD

Sub

Sealing Setting

Tool

Spider

with

Spring

Assy Guide

________

Dart DC

Rubber

Dart

CD

16

spring

I-told

Down

Base

Stand

Bar

Pin

Releasing

11

Tool

Setting

ruDe

I-ta

SB Parts

extra

Suggested

each

Spider

/Guide pr

rig

Dart

Shaffer Blowout

Rubber

Inside

Preventer Holder

ri

Wrench

1.49

Fig

manifold

10000 have

15000

to

these

selected of the

magnitude well

in

Fig

controlled

choke

In

from

in

operate panel

so

that

continue

in

the

of

in

normally

can

would

event

be

the

during

mud BOP

the

kick

from

solids

controls

operated

allow

one

API

closed

drilling

on

operator

stack

system The

placed

and

the area

alternative

is

that

control

Two

easily

circulation

of the adjustable

1.8

of the

and

gas

rnation

gases

so that

the

reserve

well

ptt

fracturing

separator to

permits

be vented fluids

to

can

prevent

shallow

Also be

any

formations

to

easily

pressure

below

short

the

from casing

String

The down

shown

line

permits

drilling

fluid

to

be

pumped

the

annulus from the surface This procedure is used only under special circumstances and is not part of normal well control operation The kill line most frequently

is

causes

needed

when

subsurface

an exposed formatioll

pressure to fracture

hook

thc

well

upper

of

such

record

mud 12 level and 14

hazardous

In

mud

addition

of

to

some

housed provides

detailed

in

the

fluids

as well

of

inspects at

describing labeled

and

further

regular their

cuttings

by

their

the

various

can

system

the

and

The

and

paleontologist

unit

formation to

the

the record

mud

logger

from the shale

maintains

Additional

depth

This

circulated

taken

aid

personnel

as centralizing

intervals

to

pit

detecting of

also

about

being

appearance

according study

rock

in

Fig 1.55

parameters

drilling

13

well-monitoring

information

and

keeping

gas content air

supervisory

used

mud

drilled

carefully shaker

and

is

density

records

operation

centralized trailer

driller

historical

drilling

cases

the

assisting

engineering

in

of

content

rate

rate

good

the

geological

being

flow

problems

drilling

gas

is

display

torque

rotary

mud pump rate pump pressure mud temperature 10 mud salinity 11 of

station or

penetration

speed

rotary

problems

drilling

drillers control Devices

depth

as

load

constant

require

detect

to

1.54

Fig

parameters

during to

of

in

surface kill

the

System

considerations

An example

quickly

In

are arranged

diverted

excessive

for

produced

valves

from

fluid

drilling

preventer

hole

efficiency

monitoring

aspects

mud

taking

blowout

internal

dart-type

Well-Monitoring

Safety

to

chokes

fails

kick

rapidly

portion

the

hydraulically

BOP

prevent

The

on

the

by

begin

Example

operators

based

the

the

choke

BOP

the

chokes

adjustable

one

valve

are

5000

designs

arrangement

to

the

valve

this

be

used

separates This

operations settling

must

is

this

valve

manifold

drilling

well

optional

procedures 1.51

arrangements

3000

formation pressures

control

Shown

other

many

arrangement

2000

1.50

Fig

working pressure systems In

recommendations

developed

the

psig

cock

kelly

for

arrangements

and

addition

Example

cuttings are

saved

The

log are for

iden

ROTARY

of

tification

in

geologist

drilled

analyzed

27

the microfossils

the

assists

being

PROCESS

DRILLING

mud

the

The

chromatograph

cuttings

formations

from the mud

logger

are

using

of

presence

the

the

removed

Gas samples

by

in

present

correlating

gas

hydrocarbon Separator

reservoir

often

be

can

detected

by

this

of

type

analysis

have

there

Recently subsurface

been

These

systems

and

systems

are

direction

in

monitoring hole

surface

sends

involves

information

pressure

valve

bypass

mud

to

coded

contained in

illustrated

annulus

of

by means

fluid

Fig

to

that

pulser

in

the

1.56 uses

create

needed

the

signal

pressure

1.9

the

to

telemetry

the dHllstring

of

drilling

One system

drillstring

use

in

One

wells

for data in

the surface

to the

in

pulses

the

useful

especially

the most promising techniques from subsurface instrumentation

in

data-telemetry

nonvertical

of

the

advances

significant

well-monitoring

Marine Equipment

Special

and procedures equipment are required when from floating vessel The special equipment

Special drilling

New

Nigh

required

is

the vessel

usually

from one

rapidly

because

The

of the

derrick

withstand

location

derrick

special

200

as

1.51

Schematic ing

of

system

example

for well

high-pressure

control

circulat

operations

However

action to

designed

is

with

tilt

driliships

by wave

often

drillship

much

Fig

can be moved

must be used for

motion caused

tilting

against

next

to the

design

of

as

and

expensive

Formation

lateral

action

semisubrnersible

less

Pressure

Permeatte

the

problems are more severe

for

are

over

for the vertical

caused by wave

motion

than

drillship

location

on

vessel

compensate

Vessel

driliships

the

movements

tilting

for

hold

and

borehole

and

to

Mod

load

full

of to

the

in

standing

drilipipe

Also

derrick

special

pipeCD

equipment

handling

This

equipment on

quickly than

supported

also

used

is

rack

tripping

to

doubles

be

block

the

traveling

down

laid

or thribbles

derrick

prevent

weather

rough

during

drillpipe

in

the

in

to

permit

CD

safely

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pipe

to

necessary

be made

to

operations

is

rather

guide

track

block

from CD

in

swinging

Most

floating

When

anchors conventional

cemented is

containing the

turret

stern

so

is

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anchor

location

by

the

in

rig

The

which

ship

rotated

is

in

incoming to

designed

choke

manifold

hand-adjustable

or

adjustable

choke

showing

and

15000-psi

15000-psi

CD

remote

choke

been CD

turret

about

bow

the

1.52Example

most

the

central

mounted

Fig

vessel

has

drillship

always faces .are

driven

floor

from

The

thrusters

systems

are

moored from

be

drilling

it

ocean

hard for

too

is

piles

anticipated

can

using that

on

bottom

the direction

facing

the

held

CD

weather that

are

ocean

boreholes

in

designed

vessels the

anchors

moored

severe

weather

rough

and

waves Most

restrict

horizontal CD

movement

vessel

the

most

the

water

depth

95%

perienced are

weather

severe

used

in

of

for

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the

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depth for

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10%

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restricted

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10

common

Several

system

ex

anchors CD

CD

anchor

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Positioning

are

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have

drilling

in

large vessel

placement The large

Fig

1.57

thrust

on

technique

units

location is

capable without

called

of

an

dynamic Fig

fuel

consumption

required

for

.53Example

control

panels

for

remote

adjustable

choke

28

APPLIED

ENGINEERING

DRILLING

1p Iji

Fig

1.54Example

dynamic

positioning

when

frequent

the cessive

lengths

Also

be

can

is

of

the

the

used

depths

water

position

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wear on is

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3000

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hole use

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to

the

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if

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ship

type

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monitoring

line

that to

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to

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from the ocean

fluid

The

The

type

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tension

straight

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drilling

beacon

uses

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indicator

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may be

inclinometer

acoustic

dual-axis

running from the welihead

cable

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the

system uses

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in

and

type

mechanical attached

ft

result

common

in

is

times Excessive

the

well

Example

ex

dynamic

reference

all

over

continuously

for

1.55

Fig

or

that

generally

with at

are

conditions

limited

than

less

monitored

the subsea

not aligned

of

of

only

required

required

positioning

of the vessel be

lines

are

weather

more

is

Dynamic

in

of

unit

feasible

changes

anchor

range

sustained

control

economically

location

positioning

The

drillers

acoustic-type

floor

position

on the ocean

transmitters

floor

and

on the ship Doppler sonar may be hydrophones used also This system is more accurate than the tautline

SHOCK

Part

WAVE

of

the

IL_LOl.R

1.58

LOG

DEPTH

RIG

FR

DISPLAY

movement of the vessel

the

the

vessel

NY

PASS

Vents at

mud

creating

Won

small ta

pneumatic can

be

sections

riser

system

The

quantity the

sad

of

secured

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at

lateral

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at

placed

by

Fig from

allows

to

the

The

system

reduced

movement

vertical

is

vessel in

Aflex joint

vertical

riser

for the

fluid

drilling

joint

slip

tensioning

PORT

on

the

shown

is

riser

The

by

of

vessel

marine

requirements to the

the

drilling

the

of the marine riser The by

depend

compensate

operations

of

allowed

is

to

conducts

riser

floor to

bottom

not

movement

drilling

marine

ocean

the

used

vertical

normal

during

the DAT

and

does

the vessel

equipment

SIGNALS

URE rL1 MITTER ItER

STAND

link with

horizontal

and

water

deep

in

system

mechanical

adding

of top

vessel

tension

buoyant

can

drilistring

be

Annulus

absorbed

Shack

bumper sub between

by

drill

collars

this

arrangement

causes

the

relative

to

However

entire

length

to the casing bit

vary

many

since

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when

weight

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to

movement reciprocate

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vessel

drillpipe

hole

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problems

vertical

of

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is

Surface

motion-compensating equipment called heave been developed in order to eliminate compellsators have this

problem

traveling

The

This

on

1.56

Example

subsurface

well

monitoring

system

necessary

such to

load

is

maintained

device pneumatic tensioning as shown in Fig 1.59

stack the

ensures

weather Fig

block

BOP

placed

hook

constant

use of

through

for

that as

floating floor

ocean

the well

can

hurricane

disconnect

the

drilling

below be

the

marine

even it

the

operation

marine

closed

when

on

in

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riser severe

may become

riser

Also

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ROTARY

DRILLING

Symmetric

Symmetric

Six

PROCESS

lIne

nine-line

29

6s

Symmetric

9s

8s

eightline

Synimetric

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tenline

RIG

FLOOR

RIG

PISTONS EXTENDED

PISTONS CONTRACTED Symmetric

12s

twelveline

450

900

Ba

eighIIine

Fig

600

3Q0

Fig

eightline

8b

1.57 Example

FLOOR

1.59Operation

of

heave

compensator

19

lao

spread

mooring

patterns.17

JOT C-

CD

HEAVE COMPENSATOR

PNEUMATIC TENSIONING

RAM PREVENTER

FLOATING DRILLING VESSEL -SLIP

JOINT SEA

LEVEL

UNITIZATION\ STRUCTURE

-N

CHOKE AND KILL

BALL VALVES

SUBSEA

flOP

STACH

LOOP

BUMPER DRILL

SUB

COLLARS

BIT

Fig Fig

1.58Schematic operations

of

equipment

for

marine

drilling

-1.60Example subsea

blowout

preventer stack

30

APPLIED

would and

be

slip

annular

assembly

often

stack

makes

An

This

above

stack

example

to

are used

the existing

BOP

subsea

marine

withstanding

hydraulically

above

possible

it

design of

capable

Identical

pressures

connectors

BOP

difficult

extremely

joint

to

and add

one

in

stack

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1.60 The

high

are attached

the

BOP

additional

emergency shown

in

kill

and

line

to

the

of views cutaway marine riser equipment

operate

Fig

attached

integrally

are

the

The

BOP

stack

to

cable

attached

choke

line

to

the

marine riser Shown

are

operated

below on an

riser

ENGINEERING

DRILLING

with

hydraulic side

valves

guide

They

lines

and are

CONNECTOR

TIE

UPPER PACKIN ELEMENT

TENSIONER SUPPORT RING

TELESCOPIC JOINT

KILL

TERMINAL CONNECTIONS ii

MARINE

RISER

JOINT

MARINE

RISER

SINGLE

BALL

FLEX JOINT TYPE II

FLEX

LOWER RISER

MARINE PACKAGE

Fig

1.61

Cutaway

view

of

upper

and

lower marine

riser

equipment

1.61

and lower upper the choke and kill lines

REMOVABLE

AND

stack

Fig

example

FLOW DIVERTER ASSEMBLY

CHOKE

BOP in

to

required connectors stored

and

ROTARY

DRILLING

handled direct

lines

used

for

cumulator store

an

th

at

bottles

distributed the

ocean

much

floor

faster

for

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1.63 is

ocean

the hole

Two guide

base

guide

base

allow

the

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are

the

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floor

head

When

away

The

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the

subsea

from

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pressure

exerted

The large

opposite

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deployed

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use

1.64

of

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piston

for

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the

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The

device

piston Hydraulic

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They

counterweights

tensioning

obtained

on

of

illustrates

pneumatic is

have

drilling

the

Fig

tensioning

bundle

air

the

on

fluid

dampen

to

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in

for

shown

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in

the

cables

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side

of

to

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desired

The

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one

camera

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without

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first

stack

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on

used

formation in

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the guide

on

rides

when

over

fluids

Hose

lowered into the hole

attached

to

the

Bundle

Hose

Bundle

hose

bundle

Reel

emergency with Fig

wellhead

replaced

tension

into position

marine

the surface

at

diverted

floor

cable

devices

floating

desired

lowered

equipment

television

drilled

have

largely

the be

can

BOP

The

BOP

in

application

into

then

and

casing

wellhead

the

latched riser

tensioning

principal

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the

Pneumatic

the

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diagram

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assembly

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into

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The

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1.62

is

on

actuate

to

approach

Four cables

then

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the

initial

tension

Equipment

lines

The

one

valves

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Fig

oil

and

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latched

to oil

landed

are

all

with

place

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the guide

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in

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have

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constant

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the

of

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wellhead

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Ac

that

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into

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designed

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power

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acoustic

the power-oil

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subsea

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hydraulic

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Fig

Smaller

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stalling

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back

assembly

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on the subsea

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The

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the various

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seafloor

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water

power

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ft

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300

used

31

vessel

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about

the system oil

drill

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less

the

on

PROCESS

top

1.62 Cross

The

indirect

section

of

control

for

an

system.17

JOINT MARINE

FLEx

I41

RETURNS TO

SEA

4BOP 11L

VESSEL ON LOCATION GUIDE

JOINT

STACK

GUIDE

ASSEMBLY

FLOOR

POSITION

INSTALL

KILL

LINES

Hull rtii

RISER

HCFI0KE

III

CONDUCTOR PILE

CONDUCTOR

BASE

CASING

CONDUCTOR PILE AND CONDUCTOR CASING HOLES AND INSTALL CASING DRILL

DRILL

STRING

BIT

INSTALL MARINE Fig

1.63

Example

subsea

equipment

installation

procedure

BOP

STACK AND

RISER

32

APPLIED

tors the be the

cost

formation

the

was

bits

Tension

trip

time

at

operated

attainable

for that

program

performance

Drilling

performance

for

thick

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hours

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gives the

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Assume

the

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Determine which

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Pressure

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Reducing

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1.5

Example prepared

the

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bit

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problems such

Pressure

the cost

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Cables

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ENGINEERING

DRILLING

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the

per foot

cost

bit Mean

Bit

Time

1ime

Rate

hours

hours

ft/hr

Cost Bit

1.64 Schematic

Fig

of

pneumatic

tensioning

device 800

action

of

the

stroke

piston used

on

the

Pneumatic

wellhead

main

function

recommend successful

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bit

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the

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to

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1.10.1

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1.16 For

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The

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490040057.70.47

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cost

drilling

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In tract

such

as

detailed

per

being

risk

fac

of

upon

Bit

using

available

estimate

is

proposal

for

cost estimate

may

well

cost

depth of

depends The

and

location

other

cases

new well on

primarily

daily

more

of

the

well

well

an For example operation from experience that operating

govern

the

moving

operating

location

will

cost operator

find

rig

will

offshore

Louisiana

about

average

daily

operating

crew

boat

cost

rentals

requires

$30000/day are

work

such boat

rig

of

drilling

lease

ap

an

only

In

be

of

required

the welisite

the

lease

drilling

location

preparing

for

are

can

evaluation

required

be

the cost of

decisions

the

as

engi

drilling

predictions

economic such

cases

The

to predict

These

location

land

cost

in

Drilling

and

called

sound

that

some

proximate

the

is

given so

required

given

Cost Predictions

Drilling

frequently

the cost

per unit

type

in

are

formula large

well

complete

drill

the

cost

bit

the cost

Bit

14.8

13.8

Crz

1.10.2

Formula

for each

drilling

that

evaluated Since

drilled

Eq

in

evaluated

drilling

trip

sum

drilled

Cr

time

foot

80040014.80.17

en

1.16 Cf

per

using

is

cases

CbCrtbttt where

cost

rig

pump

problems In

expenses

Cost

of

the efficiency

the time

10.2

must

routine

into

being

Drilling

application

drilling

0.5

The

Similarly

and

safely

engineer

any

to

The usual procedure

operating

of alternatives

evaluating

95.8

computed

per foot

neer

common

12.6

4500

the

in

treatment

equation

costs

is

result

as

operation

drilling

drilling

well drilling

fluid

drilling

the

will

concerning

drilling

these

dependent

0.4

corn

engineer

that

The

selection

the

and

costs

surface

are

lines

guide

drilling

of

break

to

of

recommendations

use

often

Cf

the

as possible

such

is

of

completion

operations

the

on

procedures

drilling

inexpensively

make

and

shorter

devices

the various

13.8

0.1

57.7

packing of

use

tensioning

14.8

4900

Cost Analysis

Drilling

The

the

the

for the drillstring

pensators

1.10

lubricate

system allows

marine riser

the

subsea

and

piston

block-and-tackle

Penetration

Connection

Rotating

on

things

as

rentals

in

rig

may given

expenditures Included

to

the

that this

rentals

helicopter

ROTARY

PROCESS

DRILLING

33

TABLE

AVERAGE

1.7

COSTS OF DRILLING AND EQUIPPING SOUTH LOUISIANA AREA

1978

THE

IN

Dry Holes

WELLS

Mean Depth

Number

Interval

ft

of

Oto 1249 1250to2499 2499to3749 3750to4999 5000 to 7499 7500to9999 10000tol2499 12500to14999 to 17499 15000 17500to19999 20000 and more

well

rentals routine fluid

treatment

well

will

An

of

presented

and

by area

association

Louisiana

taken

area

costs

Drilling

is

often

tend

when

Thus and

depth

11280 13659

16133

21

18521

crew

housing drilling

The depth of

are

published

data

the 1978

for

the

increase

of

fit

about

the

21000 lx i05 Shown

about

ft

south

Table

in

cartesian

south

can

For

ft

dollars in

Fig

more cost

needed

cost

with

data

made

such

as

casing and

of

the

supervision

and

drill

of

time

rig-up

time

Trouble such

time

as

the

The

time

time

pipe

time well

of

drilling

penetration

The

rate

penetration

with

exponentially

conditions the penetration

depth

not

depth can

rate

be

by

1.18

e_23o3a2D

where

and

required

to

to

and

time td

drilling

be

depth can

given

variables

separating

The

constants

are

a2

drill

obtained

integrating

by

Separating

gives

dt

Integrating

e2.3o3a2DdD

and

for

solving

yields

td

2.3O3a2K

As

experience

from

of

Plots

drilling

time to

given

can

this

be

past

also

type

procedures

accurate

obtained

from

time

drilling

new

evaluating drilling

vs

more

area

time

drilling

depth

an

in

gained

is

of

predictions

be

time

for

always

eiven

based

the

The

Example 1.6 the

South

are

by

drilling

used

in

to reduce

designed

depth

rotating

for

this

the

use

of

in this

for

area

Eq

using 1.19

in

well

Table

rate

penetration

time

evaluate time

vs

of depth

plots

records

bit

Sea are shown

China

Solution are

shown

and

semilog

drilled

1.8

for predicting

in

Make

depth

paper

vs

Also drilling

area

area

The

plots

Fig

obtained

1.66 The

using

divided

by the change

in

depth

per

2.303 on

0.00034

2.303a2 770

of

formation

the

bit

and

constants

records

a2 can determined using the plot of depth vs penetration rate on semitog paper The value of 2.3O3a2 is 2.303 in

be

operations

can

1.19

e22o3a2D_l

td

casing

problems

expenditures

time

in

to

basis

borehole

hole

data

rate

the

operations

tripping

estimate

rig

trouble

on

spent

other

required

on

and

and

control

etc Major for drilling and

The cost

time

trip

is

plan

costs

estimated

time

drilling

includes

stuck

is

arc required

interest

to

plotting

estimated

costs

formation evaluation

completion

time

rental

others

decreases

are

penetration

the surface

be

can

time

An

related

the

lithology

equipment

accurately

mation fracture

historical

these

operations

well

well

preparing

rig

well

i0

prediction

transportation

and

costs

complete

placement survey

of

rentals

of

value

2x

detailed

operations

drilling

considerations

equipment

of

tends

strength

unconformities

major

subsurface

usually

to

conventional

cost

of tangible

the cost

When

Under

data ft

same correlation

this

drilling

cost

well

of

more

can be predicted

usually

day

from

The

the

on

of 7500 has

is

and

strength

rock

least-square

value

based on

analysis

be

location

it

between

completed

data

1.65b

of

is

range

has

accurate

must

per

these

and

Also

dt

primarily

.65a

depth

rock

the

of the higher depth of burial because caused of the by the weight

the

in

present rate

both compressive

with of

pressure

variables

Louisiana

20810

strength

be

by

depend

for

1.7

representation

When

by

exponentially drilling

Fig

in

11

1614422 2359144 3832504 5961053

joint association

relationship

and

Shown

16036 18411

increase with

1.17

location

curve

to

49

inversely

257341

950971

17

overburden

annual joint

the

is

varies shear

confining

data

drilling-cost

costs

662

td

where the constants

given

the

well

the

complete

CaeD well

091

3052213 5571320

must be penetrated

depth

given

419097 614510

110

equipment

assume

to

4347 6097 9070

1269210

curve-fitting

convenient

cost

to

47

13414

survey Approximate cost estimates drilling based on historical data of this type depth

20

276087

201416 212374

125

historical

from

199397

1832 3138

117

that

1.7

20

165

drilling

Table

in

65921 126294

426336

54

Cost

64289

664817

etc

to

Wells

11255

services

well

on

survey

Shown

of

Depth It

228

drilling

the time required source

of

21207

the lithology

excellent

API

147

supervision

rig

govern

and thus

11

Number

Cost

1213 1542 3015 4348 6268 8954

43

monitoring

maintenance

Mean

Depth ft

Wellsn

Wells

Completed

Th

ronstant

is

rcmenient

log

cycle

34

APPLIED

MILLION

DOLLARS

CURVE 1.65

Fig

semilog value the

paper

of

From

Eq

1.19

of

vs

completed

well

rate

penetration rate

penetration values

of

plot

and

a2

line

The

total

with

depth

Eqs

bit

Fig

by this equation 1.66 Note that the

line

with

the

over

on

plotted

agreement

record

bit

also

has

gives

values

in

an

of

predictions

vs

of the time required to component drill well is the trip time The time for required tripping operations depends primarily on the depth of

major

the

well

the

followed

rig

The time required operations

drilling

and the

used

being

to

be

can

practices

drilling bit

change

and resume

approximated

trip

time

can

handle

minutes

obtained

well

planned

1.20

Solution given

to

than

for the does

usually in

Eq

1.20

needed The per

to

depth given

The

not warrant Historical

causing

depth

analysis

equation

of an the

of

a2

casing

for

and

program ft The

7500

ft

required

by

hours

10.5

and

2.7

Eq

per

round

at

trip

1.20

D0.00l 90

The

approximate the

greater

additional of

9150

time

given

the

rig

of

2.7/60\

from

is

is

Also

500 2000

at

of

the

and

difference

this

rig

that

Eq

1.21

of each

depth

casing

280

ln

0.00034

are

trip

Eq

and

program

can 1.21

be

obtained

The

of

use

gives

term

interest

bit

tends

the

number

of

trips

between

bit

the

also

life

is

the depth next

the time In

depth

single

drilled

of

shows

by

approximate 1.18 between D1 depth

for

linearly with

increment

the

the

the use data

average

collars

is

time

of the drillstring

drill

depth

life

if

time

the values

vs

depth

Sea area

lO.5eO.00034Di

determine

drilled

footage

the

and

bits

the drilistring

stand

to handle

increases

footage

of

of the drilistring but

rest

previous

trip

stand

change

the

is

tr

of one

length

time required

to

required

operations

handle one

the average

The

time

trip

drilling

required is

the

is

resume

set

The

depth

1.6

Example

in

for casing

calls

Use

depth

plotting

average

bit

average

interval

is

more accurate

approximate

an

total

using

operations

China

in

the

depth

by

drilling

an

vary

changed

As experience rig

obtained

South

stand

Assume an

the entire depth

the

using

be

Construct

90-ft

given

and

a2

from past

for the

plot

are

type

particular

time can

data

1.7

trip

relation

where

tb

using

trip

time

to

drill

of

area

will

generally

bit

used to estimate

be

can

tb

and

size

to

entire

Example second

1.21

required

good

the

range

depth

bit

been gained

data

time

rotating

as the

and

1.20 time

trip

represented

1.21

e2.303a2D

in

gives

Louisiana area

south

the

in

ft

2.303u2

estimated

The

7500

below

for wells

at

lO.504eO34D

td

costs

ln2.3O3a2Ktb

of

these

REPRESENTATION

CARTESIAN

logarithms The

common

depth

Substitution

1978

of

fit

the value

to

equal

surface

on

based

is

is

K280

curve

Least-square

DOLLARS

MILLION

FIT

ENGINEERING

DRILLING

to

trips

of

trip

can

the

to

required

known

with

with

trip

the

the

first

bit

will

drill

will

occur

predicted selecting

and

following

is

is

as

shown

in

the smaller

Col

and

if

Eq

0.9996e342

ln

first trip

drill

be estimated

last

The

depth

Integrating

gives

the

addition decrease

increase

to

2941

required

obtained

from

the

Table

1.9

first casing depth Thus 500 ft Subsequent trips are

1.9 Col

Table

is

of the two depths

Eq

obtained

shown

obtained

using

by summing Col

using

planned have

at

obtained

is

the cumulative

the

to

been

Eq

1.21

casing plotted

and

1.20 and

Col

program The in

Fig

in

1.67

is

by Cols

Col Col

obtained results

of

ROTARY

PROCESS

DRILLING

35

TABLE 1.8

RECORDS FROM SOUTH CHINA SEA AREA

BIT

Total

Mean

Depth

Time

Rate

No

ft

ft

hours

hours

ft/hr

473

237

1483 3570 4080 4583 5094 5552

2527 3825 4332 4839

18.5

24.5

8.0

32.5

5323 5723

14.0 11.5

5998 6212 6414 6640 6899

9.0 11.5

10

6321

11

6507 6773 7025 7269 7506 7667 7948

15 16 17 18

20 21

22 23

In

some

well

the

cases too

is

was

convenience

as

required

round

per

1000-ft

interval

1000

is

trip

ft

times

done trip

Thus

number

the

in is

the

approximately

PENETRATION

of

trip

equal of

trip

per

15.00

113

12.25

64

12.25

72

12.25 12.25

32

12.25

72.0

30

12.25

81.0

23

12.25

92.5

19

12.25 12.25

110.5

30

12.25

9.5

120.0

27

12.25

8.0

128.0

31

12.25

15.0

144.0

15

8.5

12.0

156.0

13

8.5

14.0

170.0

20

8.5

8.0

178.0

29

8.5

10.5

188.5

21

8.5

11.0

199.5

20

8.5

.7.0

206.5

18

8.5

10.0

216.5

21

8.5

11.0

227.5

17

8.5

number depth time

of

can per

bits

be

required

per

1000

1000

ft

by the average

ft

Nb

at

given

the

by dividing

approximated

bit

life

drilling

for that

interval

depth

time

Nb

over

per

1000

73

46.5

per

round

ft

The

The

drilling

can

be

Ft/Hr

RATE

202

9.0

with

time required

to the time

trips

6.0

21

drill

The

constant

relatively total

to

1.7

15.00

101.5

the use of

individually

Example

473

9.0

depth interval

required

trips

7.0

in

1.0

7.0

8858 9053

given

each

treat

5.0

7147 7388 7587 7808 8064 8292 8516 8692

require

drill

number

to

great

strength

to

1.0

978

8179 8404 8628 8755 8960 9145

19

high

Size

Time

14

bits

Hole

Depth

13

number of

Penetration

Out

12

Formations with

Average

Drilling

Bit

5893 6103

greater

Bit

time required

obtained

using

to

Eq

drill

e2303a2lJ

td

from

1000

to

1.19 1000_Il

2.303a2K

e23O32D__1 2.303a2K

11111

2000

4000

Ui

6000

8000

10000

CUMULATIVE

Fig

1.66 Example Sea

area

DRILLING

drilling-time

plots

TIME

for

78910

Hrs South

CUMMULATIVE

China

Fig

1.67

Example area

trip-time

20

30

TRIP

plot

for

40

TIME

South

60 80

200

100

hrs

China

Sea

APPLIED

TABLE 1.9EXAMPLE FOR SOUTH

No

Trip

Trip

ft

hours

500

COMPUTATION

TRIPTIME

hours

3.2

5.7

4.1

9.8

5256

5.3

19.8

5711

5711

5.7

25.5

6.1

31.6

6105 6452

11

7043

7.0

51.9

12

7299

7.3

59.2

13

7500

7.5

66.7

7721

14

7721

7.7

74.4

15

7.9

82.3

8.1

90.4

9150 9150 9150 9150 9150 9150

8779 8923

9150 9150

21

7926 8118 8298 8467 8627 8779 8923

7926 8118 8298 8467 8627

22

9061

9150 9150

23

9150

8.3

107.2

8.6

115.8

8.8

124.6

8.9

133.5

9061

9.1

142.6

9192

9.2

151.8

to

simplifies

6762 7043 7299 7534

98.7

8.5

From

1.7

Table

the

1.9

time

trip

1000

per

ft

is

showntobe e2303a2

1.22

l33582.351.2hours

2.303a2K number

Multiplying

the

the time

round

trip

of

bits

yields

1000

per

ft

time per

trip

by ft

1000

In addition

___________________________

1.8

Compute

South

China

the

Sea

Use the conditions

time

trip

requirements

between

area stated

in

8000

Example

and

1.7

for

to predicting

and

drilling

ft

7500

7500 7500 7500 7500 7500 7500 7500

44.9

e23o3a2D

9000

7500 7500

3205 4057 4717

38.1

19

the

4057 4717 5256

2.5

6.8

20

for

2000 7500

0.5

2.0

6.5

18

Example

Depth

ft

2299 3205

0.5

4.7

Casing

6762

17

per

Next

Depth ft

Time

10

16

equation

Trip

2000

6105 6452

This

Time

ENGINEERING

CHINA SEA AREA

Cumulative Depth

DRILLING

other

planned These

estimated

be

can

usually

the time

additional

broken

requirements also

operations

drilling

into

be

must

operations

drilling

the

for

requirements

time

operations

tripping

of

categories

general

preparation rig movement and rigging formation evaluation and borehole surveys

wellsite

Solution

The

Eq

1.20

using

average

can

time

trip

mean depth

for

of

be

8500

estimated

up

ft

8500

8.5

-The ft

is

hours

drilling

time iequired

Eq

to

drill

from 8000 to 9000

1.22

164.6

hours

ft

number of

required

between

8000 and

required

casing costs

primarily

to

on

must

and

include

and

6.15 Multiplying required

the

trip

cementing

the

equipment

surface

perhaps

10.5

tb

running and

rig

changing

accommodate time

per

trip

by the number of

ing

the well

and

this

the

the

depends

or

is

formation

the type often

cost

of

strings

foot

These for

required rigging

casing

up and

size

collar

cost of

of completion

made by

to

tests

the casing

test

per

drill

the

required

strings

The

hole size

on

the

casing

time

each

drillpipe

new

cost estimate

the casing

on

move

of

run the logs and

weights

the

depends

of

time

rig

run cement and the number of

depths diameters also

plus

fluid

drilling

cost

number and

the

wellsite

location

is

64.6

trips

the

time

on

with

distance

The

used

rig

on

rig

the

terrain

and

completion

associated

the

scheduled

tests

depends bits

of

depends

and

cost

moving

the

type

evaluation

The

0.00034280 the

the

condition e0-34

td

and

logs

e-348 Thus 9000

on

primarily

determined using

and

preparation

90

The

problems

drilling

22.7/60

--

well

placement

casing

sizes

to

complet used

the production

yields

engineer

8.56.15

52.3

On many wells large fraction of the well of unexpected drilling may be because problems

hours

as

This

compares between 7926

favorably

and

8923

with ft

the

trip

computed

time in

required

Example

mud

drillstring

These

cost

such

lost contamination circulation stuck broken drillstring ruptured casing etc

unforeseen

costs

cannot

be predicted

with

any

ROTARY

DRILLING

of

degree

an

in

then

problem

include

long-range

program

drilling

well

average

in

due

costs

Required

and

drilling

about

one-half

one-third

to

Shown

breakdown to

drilled

an

of

to

time

spent

.About

bits

Louisiana

platform

the

0.19

348

0.17

103

ft05

surveys

total

problems

Drilling

and

Mud

conditioning

was

Well

control

spent

0.10

211

0.10

450

0.22

143 12

operations

152

operations Severe weather

to

tripping

time

199

placement

Well completion

well

drill

and

evaluation

borehole Casing

Rig

from the hole

drillstring

up

Fishing

and

drilling

0.17

tender

rig to

351

388

Formation

detailed

is

required

of

of the

parts

1.10

Fraction

Tripping

only

needed

me

Ti

hours

Drilling

Rigging

time

for

time

total

offshore small

the

was

the

Table

in

using

well

this

fishing

ft

36

Only about complete change

for

10000

of

low

is

account

may

tripping

well

the

finish

formation strength

Operation

Drilling

problems where

RIG

significant Total

concerning

should

TIME ANALYSIS

RIG

TENDERED

FOR

for additional

However

decisions

TABLE 1.10 EXAMPLE

cases are not included

Requests

encountered

areas

time

some

in

estimate

whenever

spent

to

37

must be submitted

area

drilling

In

cost

is

economic given

and

accuracy

original

funds

PROCESS

97 20

repairs

26

Logistics

1.00

2050

Total

Exercises The

1.1

engine

data

following

were obtained

on

diesel

prony brake

in

operating

Fuel

Speed

Engine

Torque

rpm

on

Consumption

static

1200

1400

25.3

crown

1000

1550

19.7

Answer

800

1650

15.7

600

1700

12.1

block

1.6

Compute the brake horsepower at each engine Answer 319.9 295.1 251.3 and 194.2 hp Compute the overall engine efficiency at each

driller

Answer

speed

engine

0.235

0.278

and

0.297

0.298

Compute

the

fuel

consumption

in

gallons

are

strung

12-

driller

Compute

1.2

500000

lifting

between

strung

drawworks

load

can

hp

the traveling

to

derrick

lines

the

Calculate

impending Calculate

load Answer

input

dead

line

tension

in

the

is

of

power

block

anchored

line

648

speed

An

when

load

Answer 244691 /bf the maximum

upward

motion

equivalent

derrick

the derrick

factor

efficiency

Compute

10-hp

cable

minimum

engine Answer

1.5

strength

the

1.25-in of

anticipated

drilling

138800 on

Answer

line

has

hook job

required

to

the surface

to

mm

/51.5

lbf

casing

time

lbf/ft

weighing

and

the heat

reel

If

and

block

2.0

the

traveling

are required

how hard

line

of

lines

eight

for

the

can

the

pipe Answer

stuck

load

of

200000

from

lbf

seconds

Compute indicator Answer

load

nominal breaking of 500000 lbf based

of

of 56.25

is

lowered

the

load

201242

drum

in

the

tains

to five

has

diameter .25-in of

the

and

line

of

30

in line

drilling

the

to

first lap

drum dimensions

in

given

50000 lbf com drawworks torque when the drum is almost the drawworks torque when the drum con 1.9

fast

Consider

of

65lO4ft-lbf

empty 85938

triplex

pump

6-in

the

of

volumetric

liners

and

and

cycles/mm

3000 psig

pump

factor

efficiency the

having

120

at

operating

pressure

Compute

tension

laps

strokes

Compute

line

Answer

laps

with five

1.11

of

Compute

by the brake cooling

and contains

For the drawworks

1.10

distance

brakes

46213 Btu

approximate length Answer 368.2 ft

discharge

is

lbf

drawworks

must be dissipated

that

Calculate

pare

400000

drawworks

width

using

load

factor

free

in

hook

the

system Answer

100%

safety

of

drilling

the strength

lbf

396000

crown

the

lbf

and

lbf

The

drillstring

maximum

500000

drilling

using the auxiliary

ft

11-in

10000-ft

ft/mm

load

1.8

90

ft-lbf

0.874 1.4

on

empty

280000 Ibf

Calculate

shown

Exercise

in

the derrick

is

accelerates

rig

point hoisting

to

trying

60

to

1.9

when

hp

maximum

of

the

and

stuck

51200

factors

safety

drillpipe

1.7

zero

The

Fig 1.17

fast

used

/bf

lbf

200000

Answer 24691 lbf maximum hook horsepower

the

ft/rn

of

be

can

that

Supporting

load of

tension

in

pull

impending

Answer

Calculate

the

lines

block

between the crown

and

static

12

and 54 113 /bf

load

required between the

is

lines

166667/hf

when

line

traveling

one side of the v-door

is

Calculate

106.9

and

block

are strung

fast

10 and

maximum

block

the

motion

available

crown

hoist

on

leg

Calculate

the

for

provide

800

Ten

in

74316 61728

and

swer

lbf

must

rig

upward

tension

the

Answer 95347 1.3

the

of

between

and

derrick

day for an average engine speed of 800 rpm and hour work day Answer 188.4 ga/ID

is

drillpipe

on

pulling

strength

the

per

is

derrick

has

block

2.0

of

block

traveling

capable

is

equivalent line

and

number

10

derrick

speed

of

conditions

loading

Determine the minimum

gal/hr

ft-lbf

flow

in

units

of gal/cycle

Answer 4.039 rate

in

gal/mm

at

gall cycle

Answer

484.7 gal/rn/n

Compute

the

energy

exnencled

by

eah

njcirn

APPLIED

38

each

during

Answer 1.12

3000

at

mud

The and

20

and

pump

power

20

was

Compute and

the

pump can

discharge

For

pump

this

for various

pressure

liner

this

pump

number

lip

Liner

Size

pump

by the

the rock

the

1917

7.25

2068

7.00

2229

arranged

6.75

2418

stroke

6.50

2635

1.17

using

possible cartesian

coordinate

paper

combinations

horsepower this

Repeat

using

nearby

log-log

below

19.5-lbm/ft

drillpipe

ID Compute

3.0-in

having

of

Capacity

9000

of composed and 1000 ft

is

drillstring

the

of

drill

5-in

collars

in

if

Capacity of the

drill

mud

surface

time

trip

with

and

strokes

Answer

85/s

0.0065

of the

1164

bbl/ft

collars in

Loss

of

the

64

drill

collars

Interval Drilled

in Answer

8.0

level

0.0534

the

in

well

of

the

in

casing

bbl/ft

if

10

without

the

hole

collars

fluid

in

level

the

without

pulled

is

stands the

10.05

in

well

one

if

of

hole Answer

the

filling

stand

108 ft

wide after

ft

pulling

10 stands

in

Change

1.15

The

in

The

calcium

acetylene

strokes

acetylene

an

shale

drillstring

in 19.5-Ibm/ft having

ID

places

shaker is

drillpipe

of

2.875

the

is

the

in

2.5

an

tank

trip

tank

made form

to

by

gas

4500

pumping of

9500

and 500 ft of in The pump

drill is

ft

of

5-

collars

double-

are

If

gas

plugging

treatment to

used

cost

$1000

the average fluid

one water

zone

water

five

1.20

rig

of

The the

about

$150/ft

profitable

Do

the

of

per

junked

if

best

alternative

The

mud

using

life

cost

drilled

1000

per

for both

is

25

Determine

drilling ft

is

the

used

bit

hours

lowest

if

and ft

assumptions

average

$5/fl

$Sotft

an

On

the

expended

of

would

operations

operating

Answer

the well

borehole

fishing

the

interval

of

20 average to recover 200 ft

sidetrack

to

interval the

from

$30/ft

foot

and the cost of abandoning approximately

The

$60/hr

fluid

per 1000 encountered

must be

cost

redrill

is

rig

$200/hr

average

recovered

value time

hours of

is

drilling

is

the time

$63.80/ft

being

has

pipe

gas

of

of

operation

when

the

are

zones

and

Pipe

hours

en

zone

cost

an additional

time

yields

25

drilling

The

trip

ft/hr

water

encountered

is

Answer

$35.80/ft

air

the

and

The

sealing

cost

operating

drilling

and

requires

Regardless

hours and

each

and

foam

gas

ft/hr

the

for

cost

is

using

off

$2000

complete

of

bit

average

if

is

foaming agents normal

The

ft/hr

sealed

is

normal operating use of

rates

10

be

must

borehole

calcium

mud

area

countered

drilled

trip

is

detected

afler

composed

filled

is

of

connection with

ft

Answer3.6f1 sample

when

The

3-ft

from

is

pit

the hole

Answer

drillpipe

reacts

the

if

3-

filled

carbide

the

at

The

logger

that

in

is

of

pit

drillpipe

level

hole

drillstring

gas

detector

of

10 stands

mud

the

in

assuming

fluid

the

the

in

level

long

that

pulling

carbide

fluid

$183.13/ft

respectively

which

Change and 20

assuming after

in

$160/hr

in

Time

hours

106

penetration

are required

filling is

mud

in

Rotating

ft

Bit

The

1.19

The

bbl/ft

in

ft

Loss drill

is

the

An

joints

drillpipe are pulled

ID

The

Answer

tool

bbl/ft

in

drillpipe

neglects

Answer

and is

below

shown

Bit

cost

time

connection

Cost Bit

of

efficiency

cycles

fluid

thribbles of hole

The

12000

at

drilling

$1

is

rig

62

Displacement of

OD

gives

from shown

are

encountered the lowest

cost of the

rotating time

bits

153

Displacement

swer

three

for

prepared

records

912

volumetric

is

piston allowed

is

being

is

program

8000

at

10-ft

movement

The pump is duplex double6-in liners 2.5-in 16-in rods

operates

taut-

device

has

performance

hours

10

is

the

in

bit

operating

to the bit

pump

acting

bit

shale section

thick

for

and

415

to

to

drilling

and

joint

tensioning

wells Drilling records

Answer

required

bit

pneumatic

joint

4000

cycles

from

the

marine

this

pump

pump

are

feet

expelled

from

slip

ship

700

of

and

ft/hr

40 ft

bit

using

7bbl Number

of ball

1.64

vertical

recommended

cluded

in barrels

collars

20

is

gas

sub

device Answer

bbl

159.8

shaker

how many

travels

riser

Answer

barrels

bit

required

shale

ft

Fig

in

How much

this

the hourly

the

items

these

drillpipe

of

ft

bit

riser

Determine which

ft

1.14

shown

new well

for

using

paper

the

functions

pneumatic as

3153 rate

the

cycles

the

to

inclinometer

7.50

flow pump pressure maximum hydraulic at

pump

of

device bumper

tensioning

18 Plot

the

Answer

the bit

formation

17.2

marine

to

cycles required

to

bit

rate

by

Answer

Discuss

of

the

before

bit

pump

cycles/mm

60

is

destroyed

surface

line

6.00

speed

equipment

psig

efficiency

slip

gas

the penetration

If

of

number

the

move the gas from Answer 3100 cycles

the

Pressure

in

and

rods

volumetric

surface

to

drilled

Discharge

the

neglects

cycles

1.16

Maximum

from

the gas

Estimate

the

is

sizes

the

by

maximum

the

Estimate

2-in

liners

at

of SO/c

1400

volumetric

at

operates

flow

developed

operate

and

wide

0.82 274.9

ga//cycle

pump

strokes

move

ft

volumetric

horsepower

7.854

is

6-in

duplex

14-in

with

in during

18

fall

factor

6.5-in

with

acting

operated

mud

return

which

pit to

pump

90/u

of

efficiency

the

was

10 minutes

for

from

hydraulic

1000-hp

13

strokes

suction

observed

nswer

pump

18-in

hp with

pump

cycles/mm

the

in

long

efficiency

and

developed

848

duplex

isolated

pit

level

ft

period

the

rods

psig

suction

the

the

double-acting 2.5-in

liners

and

cycle

77 754-/hf/cyc/e/cy/inder

ENGINEERING

DRFLLING

cost

is

is

be

appear $500/hr

junked hole would fishing

and

the

be best

ROTARY

PROCESS

DRILLING

Assume

1.21

that

C1

for

wells

varies

approximately

that an

the

represents

mean depth

to

drilled

39

D1

and

with

exponentially

34

8060

35

8494

36

8614

35.1

12.0

37

8669

19.0

12.0

38

8737

29.7

39

8742

3.4

8.5

40

8778

8.5

8.5

41

9661

179.3

8.5

cost

average

that such

depth

expression

aebD be

can

used

and

to

curve

we define

If

observed

fit

residual

values

error

of

n1

is

possible

the

deterniine

to

Nobserved

sum

of

the

Derive

of

values

residuals

and

and

for

such

that

and

that

65.0

43

9973

30.0

44

10016

11.8

45

10219

64.7

8.5

46

10408

57.2

8.5

47

10575

61.2

8.5

48

10661

36.1

8.5

vs

rotating

in

Plot

depth

1.22

south

the expressions

Appiy 1.21

to

Table 1.23

1.7

south

Louisiana

given

plot of

cost

curve

7500

following

Table

1.7

for

derived

curve

cost

time per stand

per

vs depth

data

in

of

the

given

in

fit

ft the

dry holes

vs

cost drilled

Bit

in

vs depth on

set fit

these

data Answer

well

The

bit

following

drilled

in

Maverick

records

County Texas

Depth Bit

No

Two

Out

ft

doubles

The In

is

Time

the tripping well of

Size

available

One

of

plot

of

an

at

time

trip

total

trip

and

35

other

both

rigs

10 hours

2000

for

is

pull

one stand

all

ft

Answer

and casing

bits

be

best

for

bit

average

life

500

of

depths

setting

Thribble

about

is

the cost of

only

an

can

and 2.303a2

would

rig

$151200

rig

in

only

but

$1000/hr ft/hr

which

for

well but can

200

to

bit

for

$12000

drilling

$800/hr

7000 ft Assume

to

of

cost

Considering

operations

drilled

$24000/D

costs

rigs

area

34

Bits

of

costs

rig

for

vs

$181400

500

2.0 15.0

17.5

2526

14.9

17.5

2895

20.2

17.5

3177

26.3

17.5

Spec

For

Steel

3452

23.2

17.5

Spec

For

Portable

for

Rotary

17.5

References

3937

29.7

17.5

Spec

4286

27.3

17.5

1979 for

Selecting

Aug

17.5

11

5171

19.4

17.5

Spec

12

5298

15.9

17.5

API

13

5424

15.9

17.5

14

5549

15.7

17.5

15

5625

13.8

17.5

16

5743

15.8

17.5

17

5863

18.9

17.5

16.2

17.5

18.4

17.5

20

6340

27.3

17.5

21

6602

29.8

17.5

6783

23.9

17.5

23

6978

26.4

17.5

24

7165

27.3

17.5

25

7292

21.5

17.5

26

7386

20.5

17.5

27

7528

26.5

17.5

28

7637

22.8

17.5

29

7741

23.8

17.5

30

7795

17.2

12.0

31

7855

26.4

12.0

32

7917

26.9

12.0

33

7988

26.8

12.0

Casing

for

Performance

Rotary

April

APi

11 12

Petroleum

and

of

ed

Lessons

in

Primer

API

Pipe

Drill

Spec

Casing Tubing

of

Drilling

Inc

Prentice-Hall

Rotary

5A

and

Jan

Dallas

SAX

and

Well

Pipe

Drill

1976

Prevention

and

Texas

third

Drilling

Well

Equipment

Cliffs

Unit

and

P.L

Moore

Completions

Eitglewood

of

Drilling

Oil

Bull

Dallas

Engineering

Gatlin

May

Equipment

Drilling

Feb 1976 Drilling Operations Manual F.W Cole and eds Petroleum Publishing Co Tulsa 1965 10

1967

Dallas

March

Dallas

Systems RPS3

1967

DallasMarch

Sid

1975 Spec for Wire Rope Spec 9A API Recommended Practices For Blowout Bull

Dallas

1976

Properties

5C2 API

4A APi 4D API

1973

Tubing

March

Dallas

Std

Equip

Drilling

Dallas

17.5

31.3

6158

Masts

DlO API

28.2

19

Sid

Derricks

Procedure

4621

22

make

this

1925

18

t0.00148

records

The time required

4973

10

this

area

plot the

minutes

0.0004

and

in

of

minutes

Bit

hours

for

thribbles

pull

Answer

are

rigs

California

thribbles

.17

on

can

rig

$3000 for Bit 34 and bit 35 Answer S565/ftanc/$679/ft

pull

$59400

were obtained

bit

pull

depth

of

curve

in this

of

1.25

0.000096 1.24

the

1.19

vs depth Compare the performance Assume daily operating cost

southern

cartesian paper on sernilog paper of constants and of Eq

time

time

cost

using

trip

1978

in

Determine allow

and

the in

of cost vs

plot

well

below

depths

Complete data

leastsquare

completed

for well

depth

that

obtain

Louisiana

average

Using

and

for

the

that

Assuming

rj2

Eq

the use of

Evaluate

Exercise

8.5

8.5

well

of

value

8.5

the

value

result

8.5

9874

using

minimum

has

squared

expressions

minimum

the constants

12.0 12.0

42

as

r-

it

25.8 270.0

fourth

NJ

1960

Lesson

II

of

editions

Texas 13

14

16

Pub New

Well

Design

Intl

Handbook

Drilling

Palmer Oil

FL

Moore

ed

Petroleum

1974

Manual

Rotary

of

17

Tulsa

Assoc

of

Drill

Con

Brantly

ed

Oil Well

Dallas

tractors

15

Co

Pushers

Tool

Manual

Practices

Drilling Publishing

Drilling

Oklahoma for

sixth

edition

J.E

York City Technology

Press

McCray

and

Cole

eds

Norman

Reliability

in

Deep

water

Floating

Drilling

APPLIED

40

L.M

Operations Tulsa

IS

ed

Harris

Co

Publishing

radius

1972

Recommended

Practice

Wire

Oil-Field

Rope

for

on

and

Woodall-Mason pensators

to

RP 9B API

Service

JR

Tilbe

Use

Dallas

drum

rj

of

Dec

r1

tb

Value

Pet

Drilling

Floating

and

Care

Application

1972 19

Petroleum

of

Heave

Aug

Tech

1976

Spec

API

radius

residual

error

rotating

time

for

and

Drilling

March

Well

Servicing

Std

Structures

connection

4E

total

drilling

Nomenclature

vs a2

used

in

curve-fitting

drilling

time

of

of

used

of

section

in

pipe

curve-fitting

Vb

depth

depth

of

interest

ft

during

handle

to

tripping

operations

stand

one

operations to

required

bit

V1

velocity

of

block

velocity

of

fast

line

volume interval

per

of

cost

depth fixed

drilled wells

n1

mass drilled

mean

to

of

rate

fuel

load supported

D1

consumption

by

block-and-tackle

system

density

of

cost

operating

rig

unit

per

time

angular

velocity

diameter d1

inner

diameter

of

annulus

d2

outer

diameter

of

annulus

d1

diameter

of

liner

dr

diameter

of

rod

in in

Subscripts annulus

pump

cylinders drilled

initial

of

drilled

natural

run

bit

mean

of

wells

interval

depth

of

depth

of

depth

base

also

fast

run

logarithm

hydraulic inner

in

F5

fast

maximum pump force

in

force

equivalent

static

line

value

of

length of

stroke

length

to

of

stand

on

of

drillstring

SI

brake

prony

Conversion Factors

Metric

pump

advantage

bbl

of

advantage

frictionless

bbl/ft

Btu/lbm

system of

block

lines

and

between

strung

traveling

number of wells

crown

ft

included

in

average

number of cycles per unit number of bits per 000 number of cylinders

used

time

in

pump

power

power

from

m3/m

2.326

E03

i/kg

3.048

E01 134

gal

3.785

412

E00 E00 E03

hp

7.460

43

R0I

kW

in

2.54

cm

lbf

4.448

E0O E00 E00 E02 E03 E00

fuel

consumption

222

1.488

164

Ibm/gal

1198

264

Ibm/nun

7.559

873

psi

6.894

757

rate input

rn3

E--0l

818

lbrn/ft

power

heat

E01

119

ft

pressure change

flow

873

1.355

ft-lbf

cost

1.589 5.216

1.917

ft/bbl

block

computation

input

stroke

base

one

arm on

level

mechanical

number

stand

overall

fuel

logarithm

length

ideal

input

volumetric

mechanical

M1

ideal

rig

static

average

L5

indicated

pipe pump

derrick

on

constant natural

mean

mechanical

line

factor

heating

In

fuel

hook

force force

drilling

equivalent

cost bit

during

drum

derrick

mean

efficiency

F1

block

bit

pump

depth

Fde

such

velocity cost

drilling

cost

mean

to

required

tripping

change

constant

cost

run

torque

displacement

C1

bit

during

life

drillstring

time of

capacity

Cr

average

bit

1000

per

bit

constant

C1

time

average

cost

depth

vs

run

bit

during

time

time

drilling

1974 tb

constant

observation bit

time on

nonrotating

938-

as

Dallas

for

on

Corn

946 20

ENGINEERING

DRILLING

Cosversion

tactor

is

exact

m/m3 m3

kg/rn

kg/rn3 kg/s

kPa

Chapter

Fluids

Drilling

The purposes

this

of

used

procedures

has suitable

properties

the

desirable

properties

present the

whether

the

is

additives

used

under various

not discussed

detail

in

in

formations used

fluid

drilling

obtain

to

well

in this

but

chapter

is

and

The

the

the water

the

lowest

used

presented

expensive

and

Chapter

fluid

clean

the rock

them

carry

the

casing

and

lubricate to

should of

the

cause

or

and

equipment The

drilling

selection

and

for the

fluid

does

listed

above

the

fluid

Drilling well

mud to

it

of

perform

fluid in

broad Fig 2.1 drilling

fluids

drilled permeability

drilling

is

fluid

with

$1

either directly

in

muds

react

and

to

good

such

main

factors

are the

drilling

governing

the types range

and pore

solids

of fluid

of

mud

in

to

gravity

which

therefore

on

single

water-base

called

and

times

This

is

the solids

mud

is

in

in

lbm/gal

the selection

of

composition

be

tinuous

phase

droplets

are emulsified

formations

temperature

to

strength

pressure exhibited

by the

oil

and

the

added

water

to

phase

maintained as small discontinuous droplets mixture is called an oil-in-water of fluid

shown

is

specific

type

the

fluids

into

are called in

analyses

muds Any

emulsified

limits

the water

and vary

of fluid

drilling

complicates the

The

activity

desired

degree solids

Most

clays

the

between

inactive

at

condition

at

chemicals

do not react with

significant

The

of

restrict

certain

maintained

be

solids

solids

control

all

water

solids

are hydratable

allowing

inactive

expensive

at

when

used

dissolved as active

to

mud

the

to

thereby

to

properties

emulsion Fig

of

added

chemicals

chemicals

the

be

to

im

and

producing

and

phase

are referred solids present

the active

and

specialist

on duty

the water

functions

maintain

quite

with

therefore

other

abandon

limited

is

the composition of Fig 2.2 shows typical 11mud Water-base muds consist of lbm/gal water-base of solids and mixture liquids chemicals with the continuous water being phase Some of the solids

The

to

can

of

capable

or

by water-base

fluids

drilling

usually

encountered

are

rates

use

formations

adversely

mixtures

Gas/liquid

more control

formations are competent

few formations

significant

Their

hot

extremely

are affected

the

permeable only

large

are generally

muds

water-base

The use of gases as where

areas

to

more stringent pollution

drilling

that

drilling

the

If

million

fluid

kept

fluid

drilling

the

be

can

the

to

formations

cost

classification

The

best

required

drilling

drilling

the

necessary

exceeds

frequently

the

of

adequately

some areas

possible

formation pene

related

is

condition

good

cost often

engineer

maintain

lowest

in

the use

limited

is

of

the

become

could

the

problems

drilling

well Also the additives

drilling

deep

not

In

fluid

to

concerned

is

fluid

drilling

bit

tubulars

maintenance

most

cool

techniques

corrosion

engineer

to

the until

drilling

detrimental

upon

any

subsurface

job The

or indirectly

the

evaluation

effects

into

and

drillstring

properties

cause

formations

open hole and

functions

formation

any adverse

trated

rotating

have

not

planned

sufficient

flowing

the

in

and

bit

borehole

drilled

these

serving

exert

from

fluids

newly

the

subsurface

against

to

process

from beneath

can be cemented

steel

drilling

surface

formation keep

addition

the

pressure

prevent

well

the rotary

in

fragments

to

hydrostatic to

used

is

muds

Oil-base

require

than

procedures Drilling

ecological

However

fluid

fluids

drilling

procedure

and

composition that yields the cost in an area must be determined by Waterbase muds are the most commoniy

error

of drilling

evaluation

considerations

drilling

drilling

and

trial

formation

quality available

environmental

extent

the

conditions

mathematical modeling of the flow behavior fluids

the test

performing these j1nctions

for

common

to

fluid

drilling

determine

to

and

are

chapter

of the

primary frnctions

of

fluid

2.3

shows

the

mud

oil-base

is

to

composition

water-base is

called

muds

instead

oil

into

of

muds

Oil-base

of

the

water-in-oil

similar the

except water

oil

11-

typical are

and

phase

emulsion

This

in

con water type

Another

42

APPLIED

for

required

Fresh

water

The

flow

funnel

This

Fig

2.1Classification

of

for

fluids

drilling

difference

inactive

because

that

is

all

are

solids

do not react with

they

the funnel

Diagnostic

The

American

drilling

Tests

recommended These

fluids engineer

at

and

and

correct

by the API

determining

for

rotational

and

viscomeler

apparent

viscosity for

press

filter

solids

student

struction

on

the

consists

sample for

and

to

of

should

be

balance

to

The

of

used

water

degassed ensure

for

on

report

of

marsh

than

mud 2.6 fluid with

Marsh

sample is

to

rapid

The

the

constant

nomenclature

used

the

2.5.2

Fig

speed

speeds

use

the

at

before

being

placed

accurate

test

mud

consists

sample

The

through the

to

The

are possible

mud

inner

bob

on most models

the

dial

reading

300

At

rpm

in

other

rotational standard

two

rotor to

equal

rotor

given

is

is

centipoise

for

the

apparent

in

the

time

where rotor

0N

apparent

by

0N

the

is

2.1 dial

The viscometer logical

the

At

API

Bingham

called fluid mally

the

where

fluid

parameters of model are reported

mud

that

fluids

model These and

in

are

of the

point

nor

centipoise

using

the

is

at

2.2

dial

03

sq

ft

is

normally

the dial

the

rpm

300

at

operating

lbf/lOO

with

reading

600 rpm and

the viscometer

fluid

The

with

point

yield

computed

is

viscometer

reading

using

mud

Marsh

then

of

for

funnel of

filling

Fig

drilling

the funnel

measuring the

time

2.3

O3y3ILp third

non-Newtonian

the gel strength

by

some static

the

the

noting

in

rpm of

is

of lbf/lOO

maximum after

the If

turned

mud for

has

on the API mud report

is

to 10

If

the

mud

is

for

remain

seconds when

as the

the

speed

static

allowed of

called

obtained

when

obtained

reported

form

is

remained

is

period

deflection

on

ft

low rotor

at

mud

the

sq

deflection

dial

turned

is

time

dial

parameter

rheological

units

viscometer

the

maximum

viscometer

in

viscometer

period

on

follow

parameters

yield

viscosity

the

Two param

report

O0

0600

the

rheo

to determine

flow

viscosity

plastic

is

non-Newtonian

characterize

to

plastic

computed

operating

in

the

drilling

plastic

The is

used

rheological

are required

the

be

describe

present

plastic

standard

eters

that

and

degrees

minute

per

also can

parameters

in

reading

revolutions

in

speed

rotational

required

of

speed

the

speeds

field

chosen

are

rotor

at

outer

variable

designed

and

the at

an

the

Only

dimensions of the bob

that

and plus

with

2.7

Fig

of

sheared

is

speeds

available

viscosity

The den

drilling

measurement

consistency

essentially

and

an

in

rotational

meaningful

characteristics

The

standard

Newtonian

required

fluid

calibration

The

of

usually

treatment

The

more

funnel

are

shown

The

so

Six

setting

viscometer

by adding lead the end of the scale

Ibm/gal

flow test

Thus

calibrated

is

Funnel

rates

drilling

tests

mud

Viscometer

between

rate

Isp

mud

with

cup

exhibit

flow

most

appropriate

the rheological

sleeve

quite

area

in

the

drilling

be

can in

8.33

an

this

the

rider position

chamber

is

of

results

the

filling

the

mud

drilling

with

wells

in

equipment

test

the

less

behavior

provide

mud

usually The

2.1.2

can

behavior

detailed

API

shown

is

balance

calibration is

this

information

balance

The

fresh

of

different

additional

an

Rotational

The

Bin gharn

for

involved

Balance

for

still

and

contents

Ref

for future

essentially

Water usually sity

this

determining

balance

shot

before

measurement

sand screen

mud

to present

everyone

at

meter

analysis

to

used

planning

Mud mud

The

pH

the standard

is

Also

when

describe test

characteristics

Information presented

tests

by almost

operations

mud

water

use

proper

Fig 2.4 form usually

diagnostic

2.1.1

referred

is

in

helpful

consistency

viscosity

determining

pressure

kind

oil

fluids which at

the

in

become

to

and

rate

high-

mudcake

apparatus for chemical

used

rates

filtration

concentration sand content

determining

determining

is

strength

high-pressure for

and

temperature

for determining

report

gel

shear

mud

press

and

rate

elevated

Shown

balance

Marsh funnel

various

at

determining

filter

filtration

The

mud

tests

consistency

characteristics

temperature

titration

diagnostic

determining

funnel

can detect an undesirable

viscometer

made

300

mudcake

for

for

of level

Unfortunately

fluid

viscometer

rotating

problems early The test

density

results

s/qt

changes

prescribed

to

time

rig

the

fluid

drilling

is

possible

include

fluid

drilling

checking

fluid

By running these

drilling

perform

to

mud

the

help

often

of

loss

2.1.3

drilling

drilling

is

potential

needed

recommended for

it

liquid

to

the

properly

serious

prevent

equipment

devised

intervals

has presented

testing

whether

functions

its

regular

identify

for

were

tests

determine

performing tests

practice

API

be

be

can

Petroleum Inst

test

26

considered

the oil

must 2.1

the

quart

per

fluid

the

funnel

funnel

non-Newtonian

exhibit

while

changing

size

cup

measurement

the

viscosities

tube

The

seconds

marsh

the

from

flow

viscosity of

non-Newtonian

apparent

given

fluids

major

causes

of

ENGINEERING

to

mud

funnel

the

of

for

meaningful different

has

during

because

sample

the units

from

rate

significantly viscosity

in

75F

at

the

into

reported

is

viscosity

of

quart funnel

full

initially

DRILLING

the

initial

gel

allowed

to

DRILLING

FLUIDS 43

VOLUME

VOLUME FRACTION

FRACTION

WATER RANGES

PHASE-ALL

SALINITY

DIESEL

CHLORIDE

CALCIUM DIESEL OIL OR FOR LUBRICITY FILTRATION CONTROL

LEASE AND

GRAVITY

SPECIFIC SOLIDS FOR

VISCOSITY

LOW SPECIFIC GRAVITY SOLIDSDRILLED SOLIDS HIGH

SPECIFIC

LOW

CONTROL

ICLAY SAND LIMESTONE MUD ADDITIVES ETC

SPECIFIC

of

HIGH

SPECIFIC

11-Ibm/gal

typical

mud

water-base

Fig

of

2.3Composition

MUD

11-Ibm/gal

typical

NO

REPORT

19_

IfIL SPUD

DEPTH ACTIVITY

PRESENT

DATE ...._......j

IPERATOR

CONTRACTOR

REPORT WELL

FOR

REPORT

NO

NAME AND

OR

FIELD

BLOCK

RIG

FOR

ASSEMBLY

TYPE

SIZE

JET

CASING SURFACE

SIZE

SET PIPE

TYPE

LENGTH

TYPE

LENGTH

COUNTy

PARISH

PIPE

INTERMEDIArE

COLLAR

LENGTH

SIZE

SIZE

CIRCULATING

VOLUMI

MAKE

LIMP

MODEL

IFT/MINI

CIROJLATIOR

STORAGE

WEIGHT

PRESSURE

ABLISTK

STK/MIN

.AUD

TYPE

FS

BRLJMIII

MUD

PROPERTIES

OsiLOPIT

TOTAL CIRC TIME MINI

GAL/MIS

PROPERTY

WEIGHT

DELOPIT

PSI

BOTTOMS UP MINI

SPECIFICATIONS

VISCOSITY

FILTRATE

T.mperatua

RECOMMENDED DRYlY

TOUR

TREATMENT

TI

pp

W.gflt

Funnel

Vscestn

PlatEr

Pofl

oP

lb/tOO

API

Vt

Iom/aO

HTHP

Cake

Sp.S

API/F

115/I/F

STtaTQth

Filtrate

Ib/0u.tt

/R.acIqtI

Viscosily

VOId

5.ElO

10

iiz

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32nd

/F

tBmfl.I

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API/RTHP 1111III

ContenT

VT

by

Vol

ca/cARted

111II

roVed

OUWatar

Metlrylena

PH

RIDe

Mud

Ou.ter

Altan.t

Alkalinity

IP/MtI

Filtrate

IF/F

OPTIONAL

mg/LI

Chloride

Total

1Pm

Ftltrale

Alkalinity

zii

CtPOcitfl

OSIrip

Alkalinity

OPTIONAL

mmnj

Filtrat

Thokness

Solid

Hardness

ai Calcium

1mg/Li

d4VENOR

EQUIPMENT

RECEIVED USED

OPTIONAL

LAST

bR

DAILY

rdUErunSlnV

COST 24

VEL

SdntploT.A.n

FIOwIn

24

ASSUMED EEc

IN

MUD

APi

DATA

ANNULAR

IN

FT

SET

Tom

ON

CIRCULAT ttJUP

FT

ROSUCTIONORLITOCR

Splapo

TOWNSHIP

STATE/PROVINCE

AREA

IBBLI

PITS

OrAL

INTERMEDIATE

SET

IZE

HOLE

OR OFF-

FT

SET

IZE

MUD VOLUME

NO

SECTION

NO

WORE DRILLING

DRILL

GRAVITY

SOLIDS

CONTROL

OPTIONAL

BILL

CHERT

SOLIDS-

tORILLING

BILL

SOLIDS

I-DO

2.2Composition

BIT

GRAVITY

INACTIVE

GRAVITY

DENSITY

WATER

ACTIVE

1.00

Fig

SODIUM

CRUDE

LOW

FOR

OR

CHLORIDE

EMULSIFIED

CUMULATIVE

COST

LAST

En

OPTIONAL

Fig

2.4Standard

API

drilling

mud

report

form

COST

RANGE

oil-base

mud

44

APPLIED

300

scIfw

28

300

cp

28

300 use of

Similarly

Eq

for the

2.1

ENGINEERING

DRILLING

600-rpm

dial

reading

gives

46

300

23cp

600 Note

that

constant This

mud

2.5Example

Fig

the

essentially

The remain

as

other

detail

for

static

deflection

in

is

10

minutes

reported

as

the

non-Newtonian Chapter

diagnostic

it

view

indicators

gel These

dial

that

is

sufficient

these

must

that

parameters

be kept

within

The

yield

the rotor

behavior

remain

not

speed

is

is

increased

shown

by

muds

drilling

viscosity of

mud can

the

be

computed

2.2

4628

18

computed

using

O6_O3

in

the

all

plastic

Eq

as well

parameters are discussed

However

student

beginning

maximum

the

JO-mm

using

as

non-Newtonian

of

type

balance.2

does

viscosity

apparent

but decreases

point

be

can

cp

Eq

2.3

10 lbf/100

sq

as

2818

03OOPp

certain

ft

ranges

viscometer gives

and

dial

Compute rotor yield

equipped

dial

reading

speed

sample

with

of

28

apparent

in

standard

46 when

of

reading

the

2.1.4

mud

2.1

Example

when

torsion

operated operated

viscosity of

Also compute

rotational

the

the

plastic

at

spring

600

at

300

mud

at

viscosity

pH

Determination

the

express

aqueous

rpm

2.1

for the

300-rpm

dial

reading

is

2.6Marsh

funnel

per

product 10

Fig

pH

defined

is

used

ions

in

to

an

by

2.4

and

moles

Eq

is

term

hydrogen

log

pH

each

where

gives

pH

solution

of

rpm

point

Solution Use of

The

concentration

liter

constant

mol/L

the

At

room

of waler

Thus

Fig

hydrogen

ion

concentration

in

the

ion

temperature has

value

for water

2.7Rotational

viscometer

of

1.0

DRILLING

ftUIDS 45

2.1RELATIONS BETWEEN pH IN WATER SOLUTIONS

TABLE

AND

pH

pOH

1.0x100

0.00

1.0x1O

1.00

1.0x102 lOx lOx l.0xlO5 l.0xlO6

1.0x104 1.0x1O3 1.Ox102

2.00

i0 iO

6.00

lOx 10-11 lOx 10-10 1.0x109 1.0x108

7.00

1.0x10

3.00 4.00 5.00

l.0x107 1.0x1O8

8.00 7.00

11.00

1.0x102

12.00

1.0x102

13.00

1.0x10 lOx

Nleutral

6.00 5.00

iO

14.00

Acidic

9.00

10.00

1.0x1013 lOx 10-14

12.00

10.00

lOx 10-s lOx 10-10 1.0x1O1

9.00

13.00

11.00

1.0x106 1.0 iOlOx 1.0x103

8.00

Reaction

14.00

4.00 Alkaline

3.00 2.00 1.00

100

0.00

28_Two

Fig

methods meter

pH

1.0x1014

Solution The concentration

pH

given

For pure

water

pH

the

solution

to

equal

Since

product

an

increase

is

colors

on

is

pH

or

exposed

of

which

paper with

the

paper

When

saltwater

should

be

exercised

solutions

present

erroneous

values

The

meter

pH

of

an

of

has not contacted color

mud

the

solution

force

formulated pirically

to

solution buffered

be

The

membrane

paper

that

almost

pH

solutions

of

must

known

been

with

linear

meter

be

14

p1-I

the

the

l0b05_

to

increase

l0

14

3.l6lxlO4mol/L

the caustic

of caustic

has

molecular

required

per

liter

of

weight

of solution

40 is

test

l0

403.161

0.0126

the weight

by

given

g/L

produce

the

the specially

em

found

pH

required

by

given

is

The

paper

calibrated

concentration

10.5

to

1i

caution

to

OH

in

from

of the

determines

across

has

the

Since

used

pH

of

by

EMF generated

glass

The change

The

measuring the elec tropotential generated between special glass electrode and reference electrode The elec tromotive

10pH

paper

compared

is

with

are

using

the

side

upper

provided

muds cause

pH

of

the color

the

an instrument

is

aqueous

strip

the

chart

when

may

be

and

of varying

After

sample

at

10pH

exhibit different

short

the color

standard

p1-I

that

to solutions

determined by placing

paper stabilizes

to

determined using either meter Fig 2.8 The pH dyes

solution

i0

in

Table 2.1

be

impregnated with

when

the surface

test

in

can

fluid

pH paper

special paper

of

said

is

in

and

acidic

pH

between

relation

summarized

is

be

to

which

The

pH

The

pH

solution said

is

in

and

left

io4 ____

l.0x1014

requires

OH

of

l.Ox

aqueous must remain

in

which solution

paper

by

given

any

in

decrease

corresponding

alkaline

in

is

l0

1.0

is

the

constant

pH

OH

H2OH

and

pH

measuring

for

right

of

the

using

API

2.1.5

The

filter

press

filtration

rate

the rate the

ditions

The

is

given

to

paper

is

after being

flow

of

by

mud

Darcys

filter

penetrated filtrate

increases

standard

of

the

rate

at

on

con

test

which

by the deposition

of

by the bit

through

law Thus

the

and

paper

thickness

under

indicative

The

Filtration

determine

standard

formations are sealed

mudcake described

test

Static

used

is

mudcake

the

filter

This

permeable

pH

2.9

through

which

at

standard

Press

Filler

Fig

the rate

mudcake of

is

filtration

by

kAp Example required molecular

2.2 to

raise

weight

Compute the

pH

the

of water

of caustic

is

40

amount from

of to

caustic

2.5 dt

10.5 The where

46

APPLIED

100

ENGINEERING

DRILLING

PSIG

VALVE

MUD

SAMPLE

LOS MUD CAKE BUILDUP FILTER PAPER

GRADUATED

MUD

d/dt

Fig

2.9Schematic

the

filtration

the area

of

of the

the

filter

press

filter

mudcake

darcies

The

standard

and

is

The

cm2

paper

drop across

mudcake

to

mud

of the

to

equal

the

during the

in

filtrate

filter

volume

of

the

mud

cp and

that

the square

root

collected

filtrate

mud cake cm

filtration

that

solids

the

has

process the been filtered is in

deposited

the

the

API

water

often

of

wherefsm

andf

is

is

the

the

volume

volume

fraction

fraction

of

of

solids

solids

in

in

the

mud

the

cake

or

the

fschmc4

fsmUmc4Vf

hmc

The

AUscfsm

best

Vvs

_______

.2.6

this

expression

for

hm

V-dV

into

Eq

2.5

and

kA fsm

1L

method

water

the

filter

fsm

for determining

to

loss

spurt

to zero time

the

press

because

the

Pressure

usually

to

standard

is

shown

as

API

standard

has

the

decrease

with

remains

essentially

to

plot

in

Fig

in

press

the

Thus be

to

212F

one-half

the

doubled

volume

filtpr

of

filtrate

reporting

nrp

reduced rate

tends

Jjin an

of

the

as QhCluIn

API in

2.7

elevated

when

filter

paper

1-ITHP

the standard collected

to

Eq

boiling

high-pressure

the area of

is

However area

used

filtration

mudcake

prevent

The

before

An eyimn1p HTT-TP

on

and the term

constant

elevated

temperature

filtrate

effect

high-temperature is

with

the

press

at

commonly

is

the

of

required

above

filter

must

pressure

is

used

of little

permeability

filter

of operating

capable

viscosity

because

press.

2.7

is

used

2.8

temperature and pressure also The filtration rate increases

operating

or

2.7

loss

spurt

to

loss

and

Eq

should be

equation

extrapolate

addition

pressure

A2_ipt .fm

filtrate

loss

Viand

smaller

integrating

Vf

However of

and

stabilizes

as

volume

2.10 In

fsm Inserting

volume

porosity

significant

7.5-mm

common

is

filtrate

the

the half

V302V75VV

Therefore

f_V

water

cake

If

It

volume

loss

before

filter

Thus

receiver

filtrate

spurt

following

the

extrapolate

API

the

applicable

observed

the

Eq

about

filtrate

30-mm

the

observed

is

permeability

becomes

of

used

mm

30

period

that

proportional

is

should be

the 7.5-mm

when

loss

mm

after

Fig 2.10

in

filter

fsc1lmc4

7.5

twice

time

Note

volume

cm2

45

100 psig

30-mm

in

of

atm

of the time period

the capacity

shown

an area 6.8

water loss

filtrate

after

to report

exceeds as

the

collected

filtrate

cake fsm Vm

collected

as the standard

indicates

practice

At any time volume of solids

volume

filtrate

of

pressure

data

press

press has

filter

at

filter

the

atm

the thickness

API

operated

reported

2.7

the viscosity of the

2.10Example

Fig

is

the pressure

hmc

VT

FILTRATE

cm3/s

rate

the permeability

API

of

vs

CYLINDER

in

filter

30 mm

water

Pi

loss 11

DRILLING

FLUIDS

47

2.11HTHP

Fig

filter

press

Both 2.3

Example using

HTHP

an

the

Using

following

data

press determine

filter

obtained

the spurt

loss

and API waler loss

low-temperature and under are operated

presses

mud

the

is

takes

Volume

Filtrate

mud

cm

ruin 1.0

have

cake

Solution The

spurt

extrapolating

to

loss

zero

of the

time

cell

can

using the

flowed

is

be

obtained

two

data

by

points

is

14.2

6.5

6.5

the

API

standard

twice

the

cross-sectional

area

press

the

corrected

loss

V30

of

period

thickness

cake

static

the the

is

deposited

than

are higher

rates

time

that

being

is

the

in

filtration

Thus

filtration

Eq

integrating

2.9

volume

spurt

of is

filter

the

has

press

HTHP

filter

414 cm3 The

can be computed

using

Eq

30-

2.8

filtration

the

V75

214.22.07 for the

effect

2.07

of

filter

an API water

area we

obtain

elevated

temperature

and

26.33

cm3

pressure

of 52.66

cm3

of the test

at

the

have

rates

the

the weilbore

remains

been

quality

no

and

predict during

Analysis Standard

various

for the concentration

static

of

reliable

dynamic

quantitatively various

drilling

questionable

for

developed of

been

the

are

static to

not

filtration

there

ability

has uses

test

testing

correlating

Our in

rates

Chemical

centration

mud

characterize

for

guidelines

2.1.6

to

filtration

Field

Unfortunately

operations

press cross-sectional

loss

test

mud

filtration

dynamic date

to

developed

filtration

Adjusting

does

it

dynamic

p.hmc

since

filtrate

it

wherein

have

standard

mm

as

model

to

designed

process

V1

7.5

However

cake

filtration

kA Apt

cm3

2.07

been

given

as

constant

With

have

that

as

remains constant fast

as

filter

conditions

filtration

that

after

thickness

eroded

2.5 we

given

that

shown

the

presses

dynamic-filtration rates

the

API

high-pressure static

presses

past

Such

mudcake

14.2

Other

apparatus

past the cake

flowing

more accurately

wellbore

6.5

7.5

not

is

place

model Time

2.12Titration

Fig

ions of

present

OH

chemical

Cl

in

analyses the

con

the

mud

Tests

and

Ca

determining

are

APPLIED

48

TABLE 2.2NTERNATQN4L

Atomic

Atomic

Symbol

Number

Woight

Ac

89

ALUMINUM

Al

13

ANTIMONY

Sb

Element

ACTINIUM

2697 12176

51

ARGON

39.944 74.91

ARSENIC

As

33

BARIUM

Ba

56

137.36

B3

209.00

BERYLLIUM

Be

BISMUTH BROMINE

Br

35

CADMIUM

Cd

48

CALCIUM

Ca

20

Ce

58

140.13

Cs

55

132.91

COPPER DYSPROSIUM

34

PROTOACTINUJM

150.43

Er

68

167.2

Eu

63

152.0

23

21

Se

34

Si

14

SILVER

Ag

47

SODIUM

Na

11

22.997

38

8763

126.92 193.1

Fe

26

55.85

Kr

36

83.7

La

57

138.92

Pb

82

207.21

LITHIUM

Lu

71

Mg

12

24.32

MANGANESE

Mn

25

54.93

MASURIUM

Ma

43

MERCURY

Hg

80

of

standard sample with and concentration The

of

liter

of

gram the

are

milligrams by

of

solute

weight

solute

grams of solution

THALLIUM

TI

81

204.39

THORIUM

Th

90

232.12

THULIUM

of

of

11

8.70

24

23

TITANIUM

Ti

22

47.90

34

TUNGSTEN

74

183.92

URANIUM

92

238.07

VANADIUM

23 Vi

87

224.0

XENON

Xe

54

131.3

YTTERBIUM

Yb

70

17304

Yt

39

Zn

30

Zr

40

YTTRIUM

these

volume

the

that

weight

would

per liter

per

of

number

of

of

the liter

per

gew

is

with

terms

many

more

even

is

are

used

are

used

to

unfortunate

by

inconsistently

petroleum industry For example is used in million sometimes per

parts

with

2.4

milligrams

liter

per

of

the

one

ppm

and

1.0835

g/cm3

solution

and

even

at

high

shown

and

to

2.2 Thus

The be

water of

density

solution

Express

the

has

density of

milligrams

of the

nor

molarity

molality

At

0.9982

concentration

per million

per

liter

by weight molecular

40.08

and

the molecular

235.457

of

weight

35.457 weight

solute 40.08

prepared cm of

100

has

68F

at

is

to

resulting

parts percent

CaCI2

water

using

mality

Solution

of

the

g/cm3

million

grams number of

of

temperature

this

solution

CaC12

11.11

by adding

the

grams

terms

91.22

the

in

terchangeably

Example

the

gram-moles of

solution of

term

the

88.92 65.38

concentrations

kilogram

react

of

people

so It

35

place

per million

liter

ion

that

concentration

some

many

the

unfortunate

is

It

express

46

50.95

VIRGINIUM

ZIRCONIUM

from

solute

the

13

169.4

volume

taking

246

50

report

normality

equivalent

per

of

per

number

the

the

159.2

69

molality

solution

n/lI/grams

127.61

65

Sn

the concentration

gram-mole of hydrogen parts the number of grams of solute of solution

known

of

reaction

of

substance

known

determined

solution

gram equivalents

solution of

be

chemical

molarity per

mud

concentration

to describe

gram-moles

52

Tb

Tm

12

perform

of

solution

can

in

Te

TERBIUM

that

the reaction

then

TELLURIUM

246

TIN

212

Fig

involves

substance

to

32.06 180.88

23467

drilling

used

apparatus

16 73

ZINC

API

the

complete

107.880

Ta

174.99

200.61

2806

34

24

MAGNESIUM

246

7896

TANTALUM

1357

6.940

Li

Sr

SULFUR

13

77

solvent

STRONTIUM

72.60

53 Ir

of

23

3468

45.10

Sc

SELENIUM

156.9 69.72

Sa

85.48

SCANDIUM

SILICON

4.003

IODINE IRIDIUM

Sm

SAMARIUM

1.0080

the

RADON

62

104.76

used

226.05

162.46

49

of

231.0

88

66

In

terms

91

Re

Dy

INDIUM

knowledge

Pa

RADIUM

101.7

164.94

tested

14092

59

Pr

44

67

in

39096

19

PRASEODYMIUM

Ru

H3

100

210.0

RUTHENIUM

HYDROGEN

per

84

12

He

percent

Po

63.57

HELIUM

weight

POLONIUM

29

HOLMIUM

nuniber

195.23

102.91

178.6

shown

24

78

37

72

Titration

35

Pt

24

24

30.98

Rb

Hf

titration

15

RUBIDIUM

Cu

35

2348

16.000

35

41

197.2

to

106.7

92.91

Cb

79

form

46

186.31

32

required

Pd

45

Au

LUTECIUM

190.2

Rh

58.94

Ge

LEAD

76

RHODIUM

27

GOLD

LANTHANUM

Os

23

Co

23

58.69

PLATINUM

1357 236

346

14.008

PALLADIUM

1357

Valence

20.183

222.0

GERMANIUM

KRYPTON

28

75

31

IRON

10

Ni

86

64

HAFNIUM

Ne

Re

52.01

Ga

solute

144.27

Rn

35.457

24

Gd

number

60

RHENIUM

17

GALLIUM

given

Nd

19.000

GADOLINIUM

Several

95.95

POTASSIUM

CI

FLUORINE

being

42

PHOSPHORUS

Cr

ERBIUM EUROPIUM

Mo

OXYGEN 35

40.08

CESIUM

COLUMBIUM

Weight

MOLYBDENUM NEODYMIUM NEON

OSMIUM

12.01

COBALT

Numbe

NITROGEN

112.41

CERIUM

is

35

79.916

CARBON

CHLORINE

Atomic

Symbol

NICKEL

10.62

CHROMIUM

Atomic Element

9.02

Bi

BORON

tests

35

18

ATOMIC TABLE

Valence

2270

ENGINEERING

DRILLING

111

Ca and

respectively of

CaCl2

is

Cl in

are

Table

DRILLING

FLUIDS

For of

49

water

of

density

the solution

g/cm3

0.9982

the molality

filtrate

API

is

11.11

igmol

and

P1

100 cm3

0.9982g/cm3 1.003

The the

volume

water

and

solute

The

11.11

of

be

can

and

solvent

solution

volume

solution

acid per cubic

from

computed the density

of

the

pH

added

to

100

of

of

1.0835

g/cm3

the

The

is

are

tests

hydroxyl

of cubic

sulfuric

0.02

to

establish

aqueous

of

phase

of

is

originally

and

complete do

solution

in

pH

at

At

to water

essentially

present

Thus

car

mud

the

hydroxides

the

and

bicarbonate

bicarbonates

to

reported

are designed

8.3 the conversion

in

sample

of the

in

of

The

respectively determination

normality

M1

bicarbonates

of

8.3

HUH

0H

cm3

102.38 1.0835

values

All

not enter the reactions

99.82g

11.11

ions

of

carbonates

CaCl2

density

bonate

the

centimeter

P1 and

M1

include

0.02

concentration

the solution

Since

gave

kg

mol/kg

of

of

mass

solution

lug

Mf

of

centimeters

and

A/f

tests

diagnostic

3m

l000g

the

called

is

g/cm and

Thus

the molarity

of the solution

11.11

gmol

cm3

1000

As

cm3

102.38

CO

is

Since

mol

0.5

of

CaCI2

of

rnol

would

CaCI2

hydrogen

the

the solution

to

react

gram-equivalent

half the molecular

is

tend

given

concentration

of

in

CaCl2

parts

million

per

as is

by

mud

the

the

pH an

lbm/bbl

million

99.82g

of

in

CaCl2

milligrams

1000mg

per

liter

1000

Thus

the concentration

of

CaCI2

as

by

percent

is

100

wt%

10.02

mixture

to

to

mud

of

and

P1

respectively

only

dissolved

alkalinity reduce

The

the

includes

the

refers

the

methyl

pH

and

with

an

acid

to

the

refers

to to

orange

the

4.3

pH

the

The

mud

of

The of

amount

the

8.3

to

phenolphthalein

filtrate

is

called

lime

free

the

Converting field

of

units

lbm/bbl g/L

P1

by 0.26

given

is

volume

the

is

fraction

2.5

of water

the P1 test includes and salts while the

of salts

both

amount the

of

methyl

alkalinity

of

and

dissolved

The

methyl acid

orange the

orange

required

to

endpoint

mud and

mud

mud

drilling

CaOH2

The

alkalinity

determine

the

amount

required

to

cm3

of

of

mud

the

in

reach

the

H2S04

known

cm3 1.0

cm3

required

to

H2S04

content

required

is

suspension of

Solution

go

into

to

reach

Compute the if in the mud

reach

the

mud

methyl

both

Since

carbonates alkalinity of

same

the or

7.0

hydroxides

filtrate

of

free

has

The

free

is

indicated

mainly due

lime

in

of

lime

total

and P1 M1 value an absence

is

any

cm3

phenolphthalein

the

bicarbonates

the

with

that

so

solution

amount the

the

is

and

diluted

is

is

H2 SO4

lbm/bbl

to

in

solids

10

proximately

of

can

lime

of

in

filtrate

endpoint

cm3 of mud orange endpoint When cm3 water before titration 50 of suspended

to

lime

mud

of

phenolphthalein

is

contain

to

conducted

are

undissolved

H2 SO4

0.02

using

is

tcsts

mud When

the

in

endpoint

the

The bases

effect

and

bases

suspended

ability

reduce

alkalinity

lest

the

endpoint

phenolphthalein

of

refers to react

alkalinity

required

effect

the

titrated

Alkalinity

phenoiphthalein acid

0.35

gew

Example

1.1

or

stabilize

expressed

lbm/bbl

suspension

99.82g

Alkalinity

solution

to is

Nto

from 0.02

37.05

gew

wheref

11.11

2.1.7

tend

mg/L

108517

11.11

suspended

is

cm3

cm3

Finally

and

solution

reserve in

limestone

concentration

lime

lL

11.11

weight

and

the

As the

alkalinity generally

concentration

0.26

Concentration

102.38

indicate

and

ions

test

yields

0.02

ppm

100153

M1

l0g

ll.llg 11.11

reserve

equivalent

CaOH2

into

go

will

This

the

solids

the lime

reduced

is

affect

results

suspended

other

filtrates

that

test

of the

55.5 in

The

P1 and

alkalinity

l.955gew/L

many mud

in

acids are present

solution

cm3

l0218

1000

then

carbon

HUH

CO2

Unfortunately The

gew

acid

form

to

and water

organic

cm3

the

4.3

to

ions

bicarbonate

of of

normality

is

11.11

the

HCO3

with

weight

The

weight

reduced

further

is

with

dioxide

mol/L

0.978

pH

the

111

reacts

CO3

ap

have of

any

Thus

the

the presence is

given

by

APPLIED

50

O.26

O.26Pm

9000mgCV/L

lbm/bbl

1.59

NaCI

the

and

Concentration

Chloride

contaminate

mud

the

drilled

the

weilbore

The

mined

by

causes

the chloride

with

titration

AgC1

as

white

saline

chloride

to

formation water

enters

concentration

deter

silver

solution

nitrate

removed

be

is

This

from the solution

amounts

precipitate

C1

AgC1 of

endpoint

after

orange-red

has

Ag

from solution

form

to

using

excess

removed

been

chromate

the

The

indicator

Cl

all

with

reacts

detected

is

Cr04

Ag2

Ca2

contaminate

standard

cannot

form

permanently

usually

used

is

of

weight the

value

small

very

AgC1

of

precipitation

is

the

in

has

3546

is

given

Cl

the

the

V1f

of

the

endpoint

used

NaC1

volume

lLJ35

the

NaC1

of

cubic

per

The

with

is

Ca

the

Disodium

EDTA

The

solution

Sodium of

capable

structure

ring

with

forming

Mg

and

removes

can

Mg2

and

contains

compound

organic

chelate

solution

EDTA

are

and

titration

solution

Ca

anhydrite

formations

Ca2

by

and

stable

quite

from

Mg

and

acid

ethylenediaminetetraacetic

plus calcium

ad

In

EDTA

the

yields

chelate

ring

in

0C-0-Na Na-0-C0

the titration

in

Cl

chelate

essentially

by

k1 0.0282

is

to

equivalent

the concentration

mg .looo where

the

until

concentration

Since

gew

mg/L

latter

CV

the

AgNO1

0.0282

the

mixture

reduced

for the titration

Cl

filtrate

Ag2CrO4

than

when

the

in

fluid

calcium

total

Versenate

Versenate

Versenate an soluble

less

is

The

determined

is

0.02

standard

mud

hard

as

present

drilling

contains

mud

the

are often

the

large

known

is

CaSO4.2H20

also

Cement

drilled

concentration

precipitate

AgC1

enter

can

containing

ions

the

in

use

gypsum

or

an

2Ag Cr04Ag2CrO4I Since

for

available

CaSO4

Water

Mg2

and

contaminants

These

water

titration

chromate

potassium present

the

Ca2

of

dition

The

Hardness

Waler

2.1.9

wafer

Ag

mg NaCl/

14850

formations

salt

by

given

is

and

enter

can

when

system

when

and

are

Salt

concentration

V11l65O9

1650 2.1.8

ENGINEERING

DRILLING

1000

AgNO3

of

content

mud

is

CH2

N-CH2 -CH -N CH2

to reach

mud

of

ions are

the

CH2

V11

required

centimeter the Cl

lf

-gew

46

filtrate

produced

by

Ca2

CH2

0COH

H0-C0

determined by

the relationship

2335.46g

NaCI

mg/L

35.46

l.65

0C0-Na Na-0-C0

NaC1

mg/L

Cl

C1

1000

CH2

CH2

2W

V11

N-CH2 -CH2-N 1650

2.10

V-

CH2

CH2 since

the

molecular

Example

molecular of

weight

2.6

solution

are

required

titration

as

indicated

indicator present

Also

expressed

assuming

in

ion The

V11

Cl

the per

only

filtrate

cm3

Nine the

is

the

of

AgNO3 of

of

Cl

sodium of

of per

Cl liter

chloride the

filtrate

liter

is

the

chromate

concentration

salinity

titrated

endpoint

potassium

the

concentration

1000

and

23

given

by

was in

0C

0C0Ca Eriochrome

dye

both

Ca2

Black is

Versenate

plex After the low level the Versenate the

magnesium

Mg2

ions

the color

of

has

been

the

presence

calcium

reduced

forms

to

complex of

depletion

the

containing

the

of

com very with

available

from the dye Eriochrome Black causes from wine-red to the solution to change

The

total

concentration

amount

of

of

solution

to ensure

is

Ca2

in

and

included

the proper

present

used

Versenate of

Mg2

amount

is

in

forms

then

ions The

blue

no Mg2

titrated

first

with

complex

solution

If

Mg2

and

the

dye

this

wine-red

form

ions

Magnesium

mud

milligrams

that

compute milligrams of NaC1

1000

by the

is

35.46

is

reach

to

Compute

present

Solut

of

AgNO3

0.0282

using

chlorine

One cm3

sodium

of

weight

the

in

color

sample

depends

Mg the

on the small

dye

action

in

indicator the event

DRLLING

FLUIDS

51

2.13Sand

Fig

The

mud

hardness well

as

indicates

mud

well

as

the

as

of

performed

is

mud

The

filtrate

calciuff

the

on

hardness

suspended

in solution

calcium

the

in

This to

or

then

is

obtain

filtrate

used

filtered

clear

then

for

that

so

the

can

go into

the

the

The

filter

hardness

total

using

from

filtrate

calcium

solution

hardened

through The

filtrate

obtained

is

undissolved

any

compounds

magnesium

mixture to

water

same

of

the

is

0.02

volume

titration

Versenate

centimeter

mud

of

cubic

in

solution

centimeters

required

cubic

per

filtrate

test

amount of excess CaSO4 present in suspension To perform the hardness test on mud small sample of mud is first diluted to 50 times its original volume distilled

where

still

indicate

the

with

2.14Mud

Fig

made on gypsum-treated muds

is

usually

mud

amount

the

apparatus

sometimes

test

the

as

Content

paper of

Example

2.7

centration

of

of CaSO4

mud

mL

10

if

to

required

Compute the

Solution The

0477

procedure

0.02

filtered

CaCO3

total

concentration

0.47710

Vim

solution

was

that

had

given

by

above

described

as

per barrel

mud

of

sample

con

calcium

pounds

as

Versenate

1-cm3

this

total

expressed

of

titrate

been diluted and

the

is

lbm/bbl

4.77

low-

low-temperature

API filter press apparatus Since the mud was diluted to 50 times the original volume 50-cm3 have to be titrated sample would to determine the pressure

and

calcium

magnesium

The usual procedure the

multiply hardness sulfate

CaSO4 barrel

to

often

is

reported

68.07

is

as

The

an

field

the of

mud and

The

mud

equivalent

equivalent

units

of

sample

five

by

Converting to

l0-mL

titrate

volume

concentration

from 0.02

tration

is

titration

cm3

in

present

calcium of

weight

concen

CaSO4 pounds

mass

measured

read

to

volume

Sand

system

and

of

and

sieve

abrasive

to

the

used

apparatus

mud

of the

shown

is

to

in

of

fluid

usually

the

mud

is

tube

glass

the percentage

directly

is

desanders

standard

content

sand content

sand

by

circulating

are

maintain the sand content

to

necessary

The

200-mesh

when

used at

determine

low level the

sand

213

Fig

yields

2.1.11 0.35

gew/L

0.02

68.07

lbm/bbl

used

g/gew g/L

and

lbm/bbl

0.477

the

per barrel 0.477

total

given

is

concentration

in

pounds

mass

The

timeters

of

pounds mass 0.477

the

0.02

centimeter

V1

are

fraction

Fig

retort

fraction

mud

distilled

of

the

of is

2.14

oil

in the

placed

into

mud

is

water

graduate is

deter

by

Cf

is

mud

calibrated liquids

solids

fm Vim

the

then

The volume

by

wheref where

the

mud

in

cup

mined

Retort

determine

solids

retort

CaSO4

Mud

The

to

cylinder

Thus

cubic

Content

using

calibrated

The

per

Sand

2.1.10

titration

Versenate of

mud

per barrel

is

volume solution

sample given

by

The

cubic

in

cen

required free

CaSO4

per in

lected

tion factor

The

is

the

in the

of

to

volume

fraction

volume

Cf

the

oil loss

of dissolved

correction is

fraction of

distilled

water

col

cylinderf0 is the volume frac and Cf is the volume increase

graduated

distilled

due

2.10

fo

obtained

applied

salt to

during

the

from Tables

retorting

distilled

water

2.3

2.4

and

52

APPLIED

TABLE 2.3DENSITIES NaCI

Percent

Weight

by

Specific Gravity

of

1.0053

Gallon

SOLUTIONS

NaCI

Added

per

Cubic

Foot

0.00

8.33

62.32

1.01

Gallon

68F

AT

PoLnds

of

Solution

Water

Solution

9982

OF

Weight

NaCI

of

Water

to

Volurne

per

Foot

Cubic

ENGINEERING

DRILLING

bbl

Barrel

1.000

8.39

62.76

0.084

0.63

3.53

1.003

1.0125

2.04

8.45

63.21

0.170

1.27

7.14

1.006

1.0268

4.17

8.57

64.10

0.347

2.60

14.59

1.013

6.38

8.69

65.01

0.531

3.98

22.32

1.020

8.70

8.81

65.92

0.725

5.42

30.44

1.028

0413 1.0559 1.0707

10

11.11

8.93

66.84

0.925

6.92

38.87

1.036

1.0857

12

13.64

9.06

67.78

1.136

8.50

47.72

1.045

1.1009

14

16.28

9.19

68.73

1.356

10.15

56.96

1.054

1.1162

16

19.05

9.31

69.68

1.587

11.87

66.65

1.065 1.075

1.1319

18

21.95

9.45

70.66

1.828

13.68

76.79

1.1478

20

25.00

9.58

71.65

2.083

15.58

87.47

1.087

1.1640

22

28.21

9.71

72.67

2.350

17.58

98.70

1.100

1.1804

24

31.58

9.85

73.69

2.631

19.68

110.49

1.113

1.1972

26

35.13

9.99

74.74

2.926

21.89

122.91

1127

Final

volume

of

solution

after

adding

specified

TABLE Percent

quantity

CaCI2

Solution

sodium

chloride

2.4DENSITIES

OF

Weight

byWeightof

Specific

of

fresh

of

waler

SOLUTIONS

CaCI2

Added

per

Water

Gallon

0.00

8.33

62.32

Cubic

Foot

Gallon

68F

AT

Pounds

0.9982

Gravity

bbl

to

of

Solution

of

to

CaCl2

Water

Cubic

Volurne

per

Foot

bbl

Barrel

1.000

1.0148

2.04

8.47

63.35

0.170

1.27

4.17

8.61

64.40

0.347

2.60

14.59

1.008

1.0486

6.38

8.75

65.46

0.531

3.98

22.32

1.013

1.0659

8.70

8.89

66.54

0.725

5.42

30.44

1.019

7.14

1.004

1.0835

10

11.11

9.04

67.64

0.925

6.92

38.87

1.024

1.1015

12

13.64

9.19

68.71

1.136

8.50

47.72

1.030

1.1198

14

16.28

9.34

69.91

1.356

10.15

56.96

1.037

1.1386

16

19.05

9.50

71.08

1.587

11.87

66.65

1.044

1.1578

18

21.95

9.66

72.28

1.828

13.68

76.79

1.052

1.1775

20

25.00

9.83

73.51

2.083

15.58

87.47

1.059

1.2284

25

33.33

10.25

76.69

2.776

20.77

116.61

1.084

1.2816

30

42.86

10.69

80.01

3.570

26.71

149.95

1.113

1.3373

35

53.85

11.16

83.48

4.486

33.56

188.40

1.148

1.3957

40

66.67

11.65

87.13

5.554

41.55

233.25

1.192

volume

of

solution

after

adding

specified

cuantity

TABLE 25NaCI CONCENTRATIONS AS wt% ppm AND mg/L wt/n

Salt

0.5

ppm 5.000

10000 20000 30.000 40.000 50.000 60.000

of

calcium

chloride

bbl

to

of

fresh

waler

TABLE 2.6TYPICAL

CATION EXCHANGE OF SEVERAL SOLIDS

CAPACITIES

of

Milliequivalents

mg/L

Blue

Methylene

5020

Solid

per

100

of

Solids

10050 15

attapulgite

20250 30700 41100 52000

gu

chlorite

10

mbo

20

shal

10

illte

kaoline

62500

montmorillonite

70

sandstone 90.000

of

Solution

1.0316

Final

of

Solution

10

100000

107100

11

110000

118500

12

120000

130300

13

130000

142000

14

140000

154100

to to to

25

40 40 40

to

15

to

150

to

shale

95000

to

to

TABLE 2.7DENSITY

OF SEVERAL

20

MUD

ADDITIVES Densit

Specific Material

Gravity

Ibm/gal

Ibrnfbbl

15

150.000

166500

16

160000

178600

attapulgite

2.89

17

170000

191000

water

1.00

8.33

350

18

180000

203700

diesel

0.86

7.2

300

19

190000

216500

2.6

21.7

910

20

200000

229600

2.63

21.9

920

21

21 0.000

243000

22

220.000

256100

2.6

21.7

23

230.000

270000

4.2

35.0

24

240.000

279500

1.96

16.3

686

25

250.000

283300

2.16

18.0

756

26

260.000

311300

bentonite

clay

sand average

barite

CaCl2 NaCI Highly

water

1011

drilled

solids

API

24.1

soluble

Ido

not

assume

ideal

mioing

910 1470

DRILLING

FLUIDS

Example

2.8

and

found

53

the chloride

If

6o

content

of

79000

fraction

of

the

chloride

mud

mud

the

Assume

have

what

water chloride

the

is

mud

the

retorted

is

distilled

to

/L

Cl

mg

mud

4Wo

and

oil

shows

test

mud

saltwater

12-Ibm/gal contain

to

solids

sodium

is

material

organic

0.01

using

/1

Cl

mud

with

NaCI

has

Cl

content

mgNaCl/L

content

of

methylene

The

mg/L

of

salinity

NaC1

Eq

has

volume

Table

solution

factor

1.045

of

of

From

The

discussed

before

dition

to

gravity

specific

determine in

the

these

and held

is

changed

cutting loosely

The

compounds

other

morillonite because

in

to

mud

mud

titration

is

change

capacity

centimeter If

of

other

the

niuci

pounds

certain

to

to

reach

is

The methylene

is

done

rather results

the

than

42

an

not

are

for

volume

gal

mL

3785

gal

ig

mL

350

Thus

of

adding

material

Ibm

adding

to

equivalent

to of

350

niL of

material

fluid

bbl

to

is

of

fluid Pilot

of

generally

is

assumed

of

the

i.e

component

of

densities

calculations

mixing

ideal

is

sum

to the

equal

in

evaluation

and

concentrations

given

mixture

resulting

involves

frequently

testing

mixtures

It

the

that

volume

total

is

volumes

in

used

2.11

for

ex

the

cubic

per

cubic

Also

in

content

of

it

frequently

is

volume

of

given

mass

given

by

to

and

mass

its

of

to

necessary

added

solids

of

knowledge

endpoint present

times

five

of

units

gives

bbl

lbm

pounds

tests

pilot

centimeters

g/cm3

to

when

are

density

an additive

the compute from

mixture

The

volume

having

V1

of

density

2.12

the cation pi

blue

can

test

tendencies results

per

cubic

started

is

The

for

used

will cost

used

system

volume

for

454

bbl

exchange capacity

the adsorptive

Ibm

1.0

is

are

the montmorillonite barrel

clays

cation

solution

materials

per

mont

hydrogen

the

equal

blue

required

on

used

reported

that

numerically

sample

and

weight

system

methylene blue per

so

methylene

quantities

in

of

barrels

commonly

used

possible

commonly

fluid

drilling

mixture

mud

most

Converting from lbm/bbl

ex

material The

is

meq

for

blue

other

with

and

the

mud small

using

the lowest

at

the active

active

most

ex

methylenc blue

treated

of

measure

the

weight

grams

qualitative

some

adsorb

0.01

adsorptive

significant

and

is

is

the

is

only

of

evaluated

that

results

potential

Alternative

organic

methylene blue solution

is

of

and

test

is

capacity

usually

centimeters

sodium

and

most of the organic

The

The

approximate

test

will

usually

weights

mud

ml of

the

The

exchange

milliequivalent

increase

replaces

blue

for

to

montmorillonite

treatment

units

treating

to

good

certain

of

sample

diagnostic

detect

to

cause

be

ensures

present

methylene

readily

also

sample

cation

and

material

to oxidize

peroxide

ions

determine

content

the

structure

methylene

organic

present

100

in

The

muds

drilling

capacity

dye

low

is

clay

other

the

The

must

the desired

2.1

their

API

the

uses

Section

identify

then

measure

clay

mud

the

ad

desirable

hydrated

to

organic

cations

clays

the

3H20

18N3 SC1

changeable

The

for

of

monimorillonite

carrying in

often

easily

In

Clays

fraction

is

added

often

readily

C16H

it

of

Sodium

clay

viscosity

ion

solids

amount

solids

hydratable

volume

the

determining

of

mud

of

is

specialist in

This

provide

Capacity

content

fluid

drilling

samples

Exchange

centimeter

the cation

centimeters

lbni/bbl

problems and

l0.741.045

0.167

Cation

cubic

the cubic

ap

is

capacity

exchange

blue solution to

equal

is

content

the cation

Nmethylene

per

25

treatments

2.1.12

an

reach

to

2.2 Pilot Tests

tests

0.06

Compute the the mud if

of

needed

is

titrated

is

has

solution

2.10

-f Cff0

used

55.0

12

2.3

increase

0.01

the montmorillonite

NaC1/L

I30350-mg

From

l2Wo

for

solution

I3O350mg NaC1/L From Table 2.5

then

content

montmorillonite times

five

proximately

exchange capacity

79000

1.65

solution

endpoint

Since

CL

1.65

79000 mg

of

sample

blue

approximate montmorillonite 50 cm3 of methylene blue

Solution Solution

present The

100

are

mL

also

be

of various reported

mud

of

used

to

When

solids

per

Table

100

26

Typical

densities

drilling

fluid

of several

determine this

density

of

solids

lists

typical

obtained

mass

mixture

be

can

and

total

are

shown

computed volume

density

is

materials

in

Table

from

added

given

to

often

2.7

knowledge the

present

The

in

mixture

of the

total

mixture Thus

the

by

m1m2...m Example using sulfuric

50

2.9 cm3 acid

One of

and

cubic

centimeter

distilled

hydrogen

water

of

mud

and

peroxide

is

treated to

oxidize

with

any

iIi

v2

diluted

where

the

volume

puted using

Eq

of

2.12

the

solid

2.13 components

is

com

APPLIED

54

2.10

Example

API

of

25

Ibm

and

bbl

Table

Solution Using

API

and

of

density

LJ

of

barite

volume

the

Compute

mud composed

ENGINEERING

DRILLING

barite

are

910

respectively

The

total

of of

bentonite fresh

the

2.7

volume

clay

water

densities

lhm/hbl is

Ibm

60

of

and

1470

given

by

and

clay

Ibm/bbl

VVV2V3Q 25

60

l.0683bb1 23

The mixture

density

From Table 2.7 Thus

the

is

the density

the mixture

density

of

water

2.15

Fig

is

3502560

solutions

valid

The

solutions

for

obtained

ty

to

CaCI2

water

Example

2.1

brine

composed

fresh

water

that

the

solution

ideal

if

calculated

is

NaC1

and

2.3 and

and

lbm of NaCl

110.5

densi

fluid

of

Tables

in

Determine the volume of

not accurate

is

weights

shown

From Table 2.3

and

and

mix

ideal

2.4

density

and

bbl

the

density

mixing

9.85

is

lbm/gal

the

assured

is

volume

total

is

enhances

the

ability

cuttings

hole

sizes

to

an

shown

value

in

water

with

favorably

results

test

mixing

in

test

which

the is

amount

of

sample period and

aging should

same

as

be

taken

order

to

and

dry

When

drilling

petent

formations

more

important

this

the

chemical

sample

in

representative be

used

or

be

add

barrel

chemicals

should

solution temperature

to

under the

to

be

Also and

sample Care

temperature

sample

used

the

the

sample

field

mud

in

the

conditions system to

when

possible

the

period

used

are observed

losses

may be When

effects

effects

removing to

com

hard

in

beneficial

continually

increases

fluid

holes

can be used of

and

rate

penetration

drilling

has

the rotary

as the

drilling

finely

divided

for

the

prevent

mud

2.3.1

hydrate clays

Encountered

Clays

number

of

readily

clays enter to

In

and

mud

as

added

cuttings

as

clay minerals

the high-swelling

general

contaminants or

all

large different

widely

Not

control

filtration

the

with

are

Fluids

Drilling

nature

water

in

desirable

and

viscosity

referred

in

are present

are

in

minerals

clay

to

the

The

and

mud

for

low-swelling

and

cavings

are

solids

drilled

using

added

aging

the alone

water

on

undesirable

capable

natural

properties the

solution

used

agitation

manner

whether

in

than

Equipment must

the

these

case water

in

small

relatively

the

in

effects

pressure of

content

they

if

drilled

clays

reduction

the

with

readily

upon obtain

the order

on

added

solid

the

to

ability

depend

are

Chemicals normally added the

The

can

chemicals

added

material

results

extent

some

to

used

permeable

the surface

at

desirable

as

frictional

the clay

the true

hydrate

added

are

hydrated

well

when

fluid

dependent

procedures

representative in

are

of

as

mation of

the

by also

particles

opposite

the formations

in

process

solids

Pilot

often

presence

increase

is

will

that

clays

available

undesirable

lbm/gal compare Table 2.3

larger

effects

lbm/bbl

not

the

developed

clay

on the hole wall

the

carry

in

velocity

low The

viscosity

to

especially

annular

relatively

in

fluid

drilling

Note

of

density

increase

surface

the

mudcake

1.1462

does

is

the

greatly increase the

and

This

en

formed Some

is

1.113

bbl

1.1462

the

water

become

solids

mud

water

of

fluids

natural

of water the amount formations This greatly reduces the hole wall and helps to prevent loss to these zones from caving into the hole Because of these beneficial

756

401.76

value

to

where

pump

in

mud

the

drilling

the

drilled

natural

water

of

form

350110.5

This

of

viscosity

most

using

begun area As

readily

rock

of

component

viscosity

The

---

corresponds

or 9.57

the

in

drilling

volume

This

the

in

are not present

1.0

V2

V1

are

clays hydrate

of

volume

total

trained

the

by

given

wells

available

110.5

V1

on

Muds

the basic

is

Many

of

68F

at

Solution bbl

are

of

volume and

total

various

by adding fresh

mixtures

resulting

sometimes

CaC12

or

The assumption

for

only

NaC1

of

fluids

in drilling

usually

is

concentration

clay

WaterBase

Water

ing

water.3

bbl

2.3

are used

of

tresh

97 lbm/gal

or

Concentrated

Effect

lbm

407

1.0683

WEIGHT

BY

SOLIDS

lbm/bbl

350

is

45

42

25

PERCENT

volume

per unit

mass

total

pilot

should

2.3.

Commercial

drilling

fluids

increase defined

the as

are

Clays

viscosity of the

number

Commercial

according

graded

water

of

The

barrels of

to

clays used their

ability

yield

of

clay

mud

that

can

in

to is

be

DRILLiNG

FLUIDS

produced

55

using

viscosity

parent

rotational

15

when

used

about

to

clays

mud of

l5

Note

ficient

the

has

in

bentonite

was

Montmorillon for

usually

applied

to

France

The

HO

but

magnesium

cations

Mg2

satisfied

excess

mineral

clay

Na

of

and

the

model

are

OCMA

Wet-screen

moisture

10

Maximum

on

No

200 sieve

API

water

22.5

lbm/bbl

26.3

lbm/bbl

H20 H20

Minimum

yield lbrn/bbl

Minimum 22.5

wt/o

of

negative

dial lbnifbbl

2.5

wt%

3xplastic

H20

viscosity

reading 600

rpm

H20

30

of

refers

is

to the

is

either

with

and

water

them

Polar

between

unit

This

spacing

of

photomicrograph water is shown

In

to

are

morillonite

mineral

group

name

reserved

member naming The

fibrous

when

of

the

group has

applied

of

the

commercial clay

clays to

Attapulgite

The clay is

been

water

called

salinity

name

is

name mineral

in

recent

accepted

montmorillonite

2.16

in this

clays

to

attapulgite great

attapulgite

found

approximately

has

aluminous

greatly affects

too

mont

including

widely

adopted

This

text the

ability

hydrate can

for

be

used

of

the

originally

was

near

Canons

HO

sub

other

name

predominantly shown in Fig

smectite

mineral

water

become

fflanqeabIe

for Al3

However

the term

the

convention

the

smectite

platelike

Mg2

group

as

has

and

for

salinity

the

in

particles

the

the

structures

years the name smectite the

swells

many

Thus

used

is

of

lattice

possible

often

specific

been

which

through

Note

the substitution

montmorillonite

stitutions

many

enter

interlayer

of the particles

addition

the

the

or

2.l7

between can

montmorillonite

Fig

in

sheets

are stacked

water

increase

hydrates

central

cations

as

mechanism

the

sodium

of

tetrahedral

held

and

for

drilling

Table 2.8

structures

such

layers

is

in

l6

silica

loosely

rnontmorillonite

character

has

sheetlike

the

in

Fig

in

molecules

the

listed

are

use

of the structure

sheet

These

side

for

acceptable

shown

is

Materials

specifications

use

Attapulgus

represented

by

the

Fig

Wt0/o

l5mL

point

by

cation

2.5

15OmL

the associated

held

tonne

wt%

loss

the

charge

m3 10

analysis

residue

22.5

16

structure

Companies

Oil

specifications

alumina octahedral

GA

Maximum

bbl/ton

ap

some

from

91

yield

Si02

replacement

This

certain

set

representation

montmorillonite

of

reserved

is

replaced

This

loosely

near

silicates

montmorillonjte

the

have

that

These

fluids

as

now

with

cations

European

OCMA

bentonites

in

found

being

electrons

which

in

Minimum

ion

API Assn

on

mud further

the montrnorillonite

causes

by loosely held The name sodium

water

with

formula

the

water

A13

Mg2

term

by

cations

by to have an

rapidly

mineral

aluminum

A13

suf

l5-cp

aluminum

represented

A1203

Fig

once

of composed primarily The name montmorillonite

hydrous

proximately

type

an

in

Values

API

is

montmorillonjte

originally

Specified

content

clay

Wyoming

FOR BENTONITE

of

and

clay shown

is

obtain

increases

TABLE 2.8SPECFlCATjONs

native

concentrations

clay

to

of

yield

for

comparison

water of

is

100

expensive

has

high-yield

added

viscosity

increases

sodium

been

about

less

clay

from various

regardless

in

fluids

of

yield

uncommon

pure

ap

an

most common

drilling

bbl/ton

10

in

clay

that

clay

iuud

than

bentonitc

native

example

The in

water

not

is

has

measured

has

It

pure

obtained

viscosities

Wyoming

use

high-yield

It

less

yield

for

with

bbl/ton

45

rpm

600

bentonite

commercial clay called

when

cp

at

mud

the

if

clay

mined

clay

Wyoming

bbl/ton

of

of

viscometer

commercial called

ton

2.16Structure

of

sodium

rnontrriorjllonite.4

56

APPLIED

decreases

eventually of

breakage

through

the

material

to

The

the

with

formula can

be

diffraction

of

800F

to

has

written

have

offset

attapulgite

magnesium

been

established

rheological

at

the

crystalline

up

exhibit

sepiolite

wide range

over

properties

X-ray micro

temperatures

from

prepared

high-

idealized

electron

that

stable

is

silicate

as

nHO

Si12Mg8O32 and scanning

mineral

this

Slurries

favorable

new

proposed for attapulgite The

techniques

studies

structure

be

can

of

sepiolite

texture

substitute

temperature

mechanical

to

This

system

fibrous

scope

fibers addition

mineral

clay

ENGINEERING

due

are observed

long

periodic

the

DRILLING

of

temperatures

2.3.1.2

Low-Swelling

drilled

many and

system

are

mechanical Various

of

of

capacity

mud

the

montmorillonite tahedral

sheets

The

2.19

that

2.3.2

Cation

loosely

Fig 2.17Transmission

electron

micrograph

were introduced

clays held

structures

cations

for

being

some

pairs of

by

replaced

photomicrograph Fig 2.18 is

thought

tapulgite

molecules

The to

the

fibers

of

due

viscosity

clays

However

to

rather

longer

build

with

water

attapulgite

than of

shown

between

hydration agitation

attapulgite continued

is

than

is

electron

at

water

required

with

agitation

2.lBTransmission

the

of

change

reactions

because

the

the

during

to

Fig

sheets is

the

of

the

clays lattice

clay deposition

Smectite

in

on

in

of

ability

ability

of

the nature

centrations other

cations

the

is

depends greatly on The

in

to build viscosity

interaction

period

with

Fig

in

attapulgite

ability

he

cation

trivalent

single

of

4H20 but cations 2Mg2

Mg5Si3O20

magnesium

within

located

other

reaction

change

with

such

ability

well-known

solution

OH24 OH2

Exchange have the

in

to

oc

The

Clays

exchange readily the

between

the

sheetlike

of

montrnorjllonite

formula

ions

similar

alumina

tetrahedral

silica

difference

different

sheets

smectite

and

exchange

are very

have

they

by

mud

the

cation

clays

that

major

of

presence

These

in

mud

hydration

enter

clays total

are

mud

the

the

chemical

the

to

enter

throughout

and

low-swelling

contributes

formations

minerals

dispersed

crushing types

which

As

Clciys

different

when

of

The

fluids

drilling

the

clay

the loosely

the

to

in

the

held

and

cations

same

the

water are

another

will

ion

ex

Ion

ex

important to

cations

their

aqueous

the

particles

replace

cations

common

present

of

softening

in

of

application

cation

one

present

hydrate present

depends

relative

con

replace

each

concentration

in

this

order

to

smectite

Al3

viscosity

micrographs

of

Ba2 Mg2 Ca2

attapulgite

left

and

sepiolite

right4

Na

DRILLING

FLUIDS

However

57

order

this

concentration

changed

the weaker

of

also

compounds

organic

be

can

sheetlike

clay

2.12

the

adsorption

dard

test

adsorb

As

discussed

siructures

the

for

of

between in

blue

methylenc

cation

Many

present

will

exchange

the

Section the

is

STRUCTURES

CLAY

the

by increasing

cation

stan

of

capacity

KAOLINITE

Sihco

TetrahedfjL

n9/r

urn

On

thc

mud

2.3.3

on

Effect

cause

Since

high

the

water

density

used drilled

solids

crease

buildup

in

low

of

specific

be

yield

MgAl

barite near

gravity mixture

the clay/water

mixture

lhf/100

sq

00mTE

in

to

Mg-AI noctuhedron Silica Tetroriedron

to

ft

The

suspension

compute

20

viscometer

an

rpm

600

at

operated

in

having

measured

as

cp

provided

mud

of

density

of

viscosity

the data

Using

rotation

each

of

2.19Typical

obtain

The

20-cp

Fig 2.15

arc

by weight

solids

percent for

each

bentonite

Wyoming

Low-yield native

well

6.3 12.6

clay

native

clay

the

fraction

clay then

and the

clay of

drilling

size

used

water

is

is

let

basis

as

fraction

can

be

are

l00lx

21.7

8.33

computed

above

the

by the units

bit

first

The

large

per hour

by

for

where the

V5 expressed

volume

solids

as

entering

the

the

bit

of

rock

fragments

mud formation porosity and

diameter

dD

lOOx

equation

shown

generated

casing the

2.14

the weight

represent

100

and

size

dD

irlqSd2

the

this

hole

the

drilling

of

string

in

8.33

the average

Using

the

relatively

consistent

in

follows

V1V2

in

often

is

fragments given

each

reduction

Several

di

density

________

Since

well

on

of rock

drilling

Muds

be cemented

to

complete

to

progresses

requires

approximately

is

fresh

Ibm of mud

100

we choose calculation

of

density

may have

subsequent

volume

43.5

the density

and

the density of

11.38

casing

successfully

of

From Table 2.7

as

steel

operation

bit

Low-yield

If

clay

Control for Unweighted

Solids

strings of

wtio

bentonite

High-yield

lbm/gal

8.67 9.03

clay

in

2.3.4

lbm/gal

Ibm/gal

Clay Type

to

required

Density

20 cp

at

the three

of the clay types given

Clay Type

Al

muds

drilling

Mud

apparent

Solids

21.7

in

follows

as

and

Fig 2.15

Wyoming

mud

found

clays

High-yield

Solution

added

teen

has

Mg

rotational

in

for

means

MgAll

4-

removed

been

shown

clay types

AISiI

Tetrahedron

Fig

the

TE

LI

ctror L1hc3

has

Exczmple2.12

-fAtSi

progresses

Also API

about

of

higher can

yield

drilling

clay/water

However strength

gel

as

density

any

barium sulfate

the

natural

MONTMOHILLCNITF

Tetrahedron

Silica

riaIIIi

with density

having

lower

AIi

the

2.6

having

mud

Mg-

Octuihedror

LA

viscosity

clay

with

caTetrahe

viscosity

given

mud

if

having

to

the density

have

must

used

fluid

mineral

added

be

the clay

mud

the

in

inert

of

as

Solids drilling

near

is

clays

all

the

in

mixture

clay

the desired

can

4.2

of

If

cases

Drilled

well

as

density

used

desired

many

provides

dense

be

desired

is

is

in

of

yield

must

yield

near

hold

clay/water

on

depends

in

gravity

specific

of

density

increase

an

the

and

Solids

Density

Fluids

Drilling

fluid

Montmorillonite

of

values

following

the penetration

for

mud

weight densities

The

first

gulf

coast

and

is

average given

few

thousand

area

drilled

usually in

feet

has

excess

formation

approximately

rate of the bit

of

porosity

by

of hole

drilled

diameter 100 of

of

in

ft/hr

Thus

0.25

V5

U.S

the

about

15 for

would

in an be

58

5l52 4231

From Table

2.7 the

results

100

of

density

lbm/bbl

At

drilled

16.4

this

bbl/hr

cC

ibm

bbl

Thus The

volume

solids

hydrate

sand

The

The

these

density

sidered

undesirable

frictional

to

the surface

is

thick

and

the

in

The

solids

to

There

four

concentration

of

undesirable

stuck

the rock

and

thin

forced is

stream

drilling

can

settling

are

shown

made

This

allows

the

API

200-mesh

openings

microns

diameter

will

screen Screen

sizes

used

with

in

The too

API

natural

low for as

Fig

1.29 are used

the

used

being

arc

to

and

The

particle

forced

cut size

point at

discarded

common

The

are

usually be

Since

the

about used

with

80

weighted

centrifuges force

cut

points in

are

range

microns

muds

of that

of

is

size

several

of

2.9

API

and

barite

the active

mud

they

mud

are

of

treatments

and

in

stream

of

separation

the

of

the

by

reduced

by

of

mud

of

all

is

to device

from

device Chemical

rather

one-step

The cost

solids

control

mud

components

clay

increase

their

arranged

cycling

to

up

introduced

is

is

are

removal

size

treatment

separation

of

small

density

clay/water

hydrocyclones

processed

large

the

by

cost

kept

dilutions

water

Each

the

dilution

mud

of

created

be

of

small

previous

the desired

to

keep

of

some

requires

in

mud

before

order

Dilution

thus

used

various

The

capacity

discarding

To

unweighted

made downstream

removed

be

should

rapidly with

efficiency

newly

not

storage

the cost

frequent

decreasing

clogging

in

brought

discarded

223

prevent

larger

particles

accomplished

Dilution

content

an

Fig

into

clay

discussed

requires

arrangement

for

in

limited

Also

than

be

can

clay

is

can

must be

increases

example

be

solids

mud volume

dilution

equipment

can

addition the new

In

water

the

less

the

of the additives

should be

of dilution

is

the

chemical

low

after

the

the reserve pit

of

of

settling

portion

the addition

prevent

than

the

cause

agglomerate

pits dilution

to

discarding

arranged

cen

The less

particles

that

Flocculation

of

forced

Because

An

centrifuge

2.3.5

Section

in

or

is

of

in

bowl

the

solids

clay

separation

concentration

the input

hydrocyclones unless

detail

dilution

in

contains

or

by settling

dilution

than

developed

downstream

separated

agglomeration

achieved

Old mud

been

solids

be

operate

contoured

contoured

active

fine

flocculate the

easily

density

have

adding chemicals

by to

shown

unweighted

Table

in

diameter

in

Once

of the

the to

primarily

removal of

been

mud

solids

overflow

that

have

systems

The

of

length

finer

allows

The

mud

hydrocyclones

screening

both

hydrocyclone

particles

shown

particle-size to

with

has

bowl

conical

unweighted

the path

dilution

devices

centrifuges

of

2.21

of

much

is

1.5 At present

half the

be

cost

the gravitational

devices

rated

hydrocyclones

Fig 2.22 cannot

Fig

which

the

Thus

high-speed

settling

200-

the solids

and

1.28

increase

74

cannot

solids

drilled

effective

see Sec

particles

as

of be

to

Fig

hydrocyclones

hydrocyclones

muds the

pits

of with

and

more

has

about

typical

mesh

because

rate

settling

settling

on the

200

barite discarded

such

acting

below

muds

weighted the

replacing

through

pass

creases

more

pass

screen

than

less

small

units

API

the

particles

200-mesh

Particles

mesh

the

the

particles

commercial

for

of

screen

inch

per

97o

that

of

on

use

before

solids

size

specifications

barium sulfate require

200

of the the

to

5090

LI

common solids found muds after Ref

for

minute and

per

than

rather

for

facilitated

screens

fine

bowl

the

equipment

extremely

reduced

SO

10

screen Centrifuges

revolutions

The

mud

the annular

screening

removal of most

been

particles

through

in

range

water-base

with

in series

high

at

the

by screening 2.20 Screening

Fig

size

unweighted

microns

both

mud and

the

220Particle

Fig

trifuge

and

for

processing

the use of

possible

to

increasing

rejected in

developments

has

size

harite

first in

in

he

the

prevent

flocculation

solids

that

IN

SOLIDS

MINUTE

PER

CI

Dl

used

screening

range

undesirable

applied

to

are

chemical

Recent

have

These

range

particle-size

used

mud from

the

in

SANDJ_

ORILLEO

OF

FEET

solids

relatively

pipe excessive pipe torquc and poor cement bonding

particle-size

and

desirable

their

solids

level

The

always

RATE WATER

the

cuttings

on many

bearing

methods

basic

settling

dilution

and

F0U/

MILLED

SETTLING

do not

but

system

than

direct

OESANOERI1 BEACH

_J

carry

rather

This has

are

forced

JBDERFLOW

SMOKE

con

are

increase

formed from these

cake

filter

usually

drag loss of circulation the formation

an

TOBACCO

increase

to

UNDO BELOW

DESILTER

OVERFLOW

as

With

barite

They

fluid

the

ability

problems including

is

minerals

used

is

mud

in

permeable

impermeable

to

of

components

API

MESH

do not

that

such

and

inert

drop

pressure

greatly increase

and

other

which

barite

MESH

DO

include

feldspar

OISCARO

either

as

are those

with

SHAKER

MESH

classified

are

0005SF

be

must

that

68SE

mud

ONE

SILT

large

quite

solids

react

API

of

be

solids

limestone

silt

tons/hr

SANOSANO

solids

often

inert

inert

the exception the

drilled

mud

or otherwise

mud

the

of

in

4I1

2000 Ibm

from the mud can

or active

inert

7.5

hr

the

removed

ton

16.4

bbl

10000

JNT

is

solids

in

910-

1000

468

bbl/hr

16.4

average

910

approximately

CR ON

SE

in.3/gai42ga1/bbi

l0012in./ft

ENGINEERING

DRILLING

APPLIED

back

to to

normally

equipment

59

FLUIDS

0RILLING

TABLE

0COMMON

2.1

DEFLQCCULANTS

USED

POINT AND GEL STRENGTH

TO LOWER YIELD

Approxmate

pH

Maximum

of

Optimal

Deflocculant

Solution

an

Phosphates Sodium

Hated

HydrocYclOfle Size

Cut

in

microns

4.8

hexa

Sodium

6.8

metaphosphate

40

75

acid

pyrophosphate

Point

Temocrature

pl-1

OF HYDROCYCLONES

CUT POINT

29_TE0

TABLE

Eflective

Mud

1OwH/a

ix

Detlocculant

Sodium

7.5

tetraphosphate

20 sodium

Tetra

10 10.0

pyrophosphate

38

Ouebraclio Alkaline

tarinate

Hemlock

OVERFLOW

IN

250

ti.s

Tannins

tannin

Desco

300

Liqriins

400

Processed 4.8

lignite

970/

/0

900/

Alkaline

lignite

Chrome

lignite

9.5 10.0

0/ ro

r_J

30

500/o

5O%

300/

70

CUT

POINT

95%

50/

350

10.1

Lignosulfonates

700/

Calcium

lignoeulforrate

7.2

Chrome

ligriosulforrate

7.5

LU

00

LU

lOO%

Zero

60

UNDERFLOW

iN

HTM1

SEPARAT1ON Not

40

U-

DIAGRAM Scale

to

20

Jci 2.21Solids

Fig

and

distribution

removal

cr

using

LU

00

hydrocyclones

60

40

20

Fig

2.22Solids

00

80

120

DiAMETER

SIZE

PARTICLE

distribution

and

40

Microns

removal

using

hydrocyclones

of

hydrocyclone

mud

weighted collect

was

mud cup

13

Evample

qt

of

ejected

water

being

ejected

the

to

mass

of

one

process

were

un to

of the slurry

balance solids

cone

an

required

The density

mud

using

Compute

ibm/gal

slurry

under

placed

seconds

Thirty

determined

is

used

being

to

and

be

volume

17.4

the density

and these

of

values

desilter

fraction

can

The

density

be

of

the slurry cjected in

expressed

of low-specific-gravity

m5

terms solids

of

the

of

water

is

above

the

from the

for

the

17.4

Ibm/gal

Substituting

yields

fS

volume

8.33

8.33

equation

17.421.7f8.331

by the cone per hour

Solving

Solution

in

fraction

of

solids

gives

0.6784

volume

21.78.33

by Since

p5 V5

the

the slurry

mass

rato

of

is

being

solids

ejected

at

rate

of

is

fr Using density

the of

values

given

in

low-specific-oravity

Table solids

2.7 is

the 21.7

average

Ibm/gal

qt

gal

21.7

lbm

0.6784 30

seconds

qt

gal

qt/30

60

APPLIED

FLOCCULATION

AGGRE GATION Sceen

FDCE

Shake

EDGE

FACE

ID

ENGINEERING

DRILLING

FSC

IC

EDGE

EGGE

EQ

Deekter

Do

low

isCard

DEFLOcCULATION

DISPERSION

SuCilor

2.23Schematic

Fig

ment

3600

arrangement

for

like

of water

ejected

is

on

chance the

q__

1.00.6784

gal

30

9.65

that

to

mud

the

9.65

make up

to

the gradual

prevent of

gal

water

the water

for

loss

must be

ejected

of

water

added this

by

from

mud

hour

yield

each

causes

and

Chemical are

solids

diluting

to

the active

keep

However

after

IJnweighted

by

primarily

and

required

of

solids

control one or more of the mud properties may be at an undesirable value and selective ad require

pH

commonly

additives

control

are used

and

control

viscosity

NaOH

pH

mud the

rate

pH

for

muds

maintained

is

pH may

higher

be

Flocculation to

platelets in

is

begin

The excess

link

at

up

to

electrons

many

pH

the the

most

An

10.5

of

considered

even

mud due

the

and

surface

mud

allowed

to

form clay

con in

particles

an

abnormally shear

fluid

the high the

rates

The

behavior

affected

greatly

plastic at

high

by

floc

to

the

low of

rate

house platelets

and thus

the

different of

of

remain positive clay

cards

normally net

shown

the

negative

clay static

and

platelets

structure have

surface

drop

mud

without

of

strength during gel

The

progressive than

an

charge

2.3.5.1

that

The

flocculate render

will

of

number types culants

the

of

ability

the

clay

the

reduce

listed

are

in

totally

Table

to

link

time

to

and

thinners

thought located

thus

None against

mud

of

on

is

.A

The of all

are to to the the

destroy

together

are available

effective

excessive

formation

with

are

charges

2.10

gel

solids

applied

cause

tendency

and

platelets

platelets

of defloeculants

arc

the

positive

the

The

Fig 2.25

gel

deflocculants

ineffective

an

Deflocculants

Deflocculants

materials

could increases

gel

of

the

be

to

for

cause

of

However pressure

afragile

frictional

to

settling

and

moving

fluid

desirable

edge

pump

large

fracture

prevents

operations

tripping

the

stopped

is

range

the cuttings

descriptive

is

pump

clay/water

carry

enough

strength

the

mud

the

to

often

ft

sq

point

yield

increasing

annulus gel

when

requires the

the

in

behavior

mud

of

drop

pressure

unweighted This

rates

the cuttings

aftŁcts

30 lbml 100

holes

ability

at

low shear

the

frictional to

for

acceptable

the

of

greatly

of

range

measured

cp

annular

large-diameter

enhance

12

an un 120F

for

viscosity

plastic to

and

and

the

clay

unbalanced

on the edge

very

of

are

platelets

by

in

will

start

associations

caused

is

is

active

destroyed

descriptive

is

mation fracture

of

of

in

point

muds

of

the annulus

capacity

yield

the

anticipated

thickening

charges

hydrated of

H2S

is

edge-to-face

the

electrical

to

and

9.5

arrangements of

When

sheared

negative

to

Flocculation

charges

platelets

if

high electrolyte

At high is

not

from

is

point

in

pressure

addition

for

The

additives

yield

carrying

less

and

These

2.24

Fig

electrical

or

refcrs

edge-to-edge

Mg2

between

used

alter

to suppress

In

environment

viscosity control

organic

to

embrittlement and

hydrogen and

favorable

is

used

is

desirable

is

Ca2

of

solubility

high

always

mud pH

high

corrosion

almost

The

are

by

describes

range

mud

filtrate

control Caustic

normal

present

is

Chemical

justment

The

concentration

methods

available

all

using

The

inert

weighted

when

the proper

at

clay/water

removing

bentonite

adding

solids

in

will

flocculate

flocculated

structure

is

overcome

to

platelets

culation

Additives

controlled

tends

to

clay

temperature

of

usually

the

negative

do not have

platelets

clay

strength

gel

which

rates

and

high

primarily

cards

of

keep

flocculation

high

detected

point

shear 2.3.5

of

to

mud

of

concentration

viscosity

muds

particles.3

positive

that

between

and

is

house

cone

single

of the clay

concentration

The Note

clay

tends

Anything

tendency

centration

gal/hr

local

forces

the

solids

s/hr

this

The

up

link

repelling

common

qt

x3600

of

repel

the edge

to

crease

seconds

charges dispersed

platelets

charges rate

2.24Association

Fig

Since

441.6 hr

volume

the

equip

ibm

seconds hr

and

of solids-control

mud systems.5

unweighted

large

common defoe

the

causes

of

DRiLLING

FLUIDS

61

TABLE

pH

OF 10% AQUEOUS SOLUTIONS OF CHEMICALS COMMONLY USED IN WATER BASE MUDS

2.11

BY WEIGHT

uJ

I-

pH

-J

Chemical

iJ

Calcium

lime

Calcium

20

l0

30

40

TIME

50

Fig

2.25Fragile

70

Scdium

flocculation

Since

and

acidic

must

be

only used

of

many

with

the

soluble

slightly

in

are

form

they

increase

to

the

pH

be

mud

of

Any

the deflocculants

and

excessive

unweighted

also

caused

by

Ca2

remove

the

Ca2

are or or

much

up the ions ion Sodium for

muds

M2 Mg

The

sequestering

and

used

exposed to

high

temperature flocculation

ions

The

use of

depth posed

to

phosphates

and

cleflocculants

at

Tannin

acid

tree

the

flocculants

are

used

depths

high

or

rather

in

ex

to

than

tannins

temperature-stable

from used

are

most

of

place

However

caused

by

but

not

trations

moderate

used

well at

at

for

are

effective

since they

perform

Ca2

of

are

soluble

more than

as

9.5

high

11

or

North

Lignites

in

called

the

remove

lignite

can

Concentrations

functions by is

lignite

since of

it

also

lignites

The as

also

tends

above

to 10

At

liberated

is

reduced

the

reducing

as

temperatures

pH

to

as

of

low

deflocculation

degradation degrade

they

contamination

small

in

be

CO2

are

effective

11 The

below

lignosulfonate

produce

with

because

more

are

can

They

paper

product.They

and

pH

of

sulfite

complexed

waste

muds

greatly

time

of

period

pH

2.3.5.2 additives

Mud

of

over

and long

above

350F

H25

When

certain

mud

quantities

Additives

mud

enter 2.11

affect

they such

lists

the

pH

of

the

additives

fluid

contam above

the

humic

The

reduce

lbm/hbl

acid

more

cement the

of

either

the surface

at

an

imbalance which

fluid

taminants

are

in

can to

problems

drilling

of

or

to

the

The drilling

through the wellbore

the chemical

cause

serious

The

develop

calcium

sulfide

Contaminants

contaminants

chemical

equilibrium

of

rheological

or

common carbon

magnesium

con

dioxide

and oxygen

in

deflocculant

against

Removal

Chemical

2.3.6

produces

mined

precipitation effective

filtration

economical

are

lignites

carbonate

cause

or Cl

pH

mineral

leonardite

calcium

processed

contamination

from

obtained

Dakota

contained

acidic

are

they

spent

of

lignites

from

causing

Lignosulfonates

hydrogen Lignites

manufacture

values

at

without

action

addition

250F

cement

at

to

from

obtained

than

lignites

concen

above

against best

the

during

flocculation

electrolyte

temperatures

are

However

and

tree

thinner

high

used

is

complexes

Quebracho

against

concentrations

perform

also

quebracho

lignite

caustic

complexing

detrimental

the

sulfonated

basically

system Table

effective

are

especially

Tannins

the

add

the

some

in

are used

still

deflocculants

as

commonly

Tannins

ination

At

revert

pyrophosphates

extracts

hemlock

do

more

before be

parts

by

stability are

enters

sometimes

zinc

are

obtained

by

cement contamination

treating

in

generated

they

con

would

175F

of

phosphates

greater

sodium

l950s

excess

lignosulfonates at

mud

the

become

The

phosphates

was

in

the

thophosphates

lignites or

Lignosulfonates liquor

Lignosulfonates

must be discontinued

which

temperatures

temperatures

cases

at

obtained

heavy metal

and

expensive

lignosulfonate-treated

reached

is

to

temperature

chrorie

same time

The

add

The

excellent

reduced

is

to

six

Also

are

removed

mud pH

chrome

to

undesirable is

lignite

chromates

of

more

is

it

calcium

if

of lignites Alkaline

one part caustic

when

Chrome

with

intended are

of

used

complex

cement

by are

be

place

form

can

gel

control

or tying

is

blend

is

can

lignite in

rigid

12.9

high concentration

separately

phosphates

SAPP

ions

the excessive

the

against

caused

Ca2

by

for

by sequestering the formation of

flocculation

treating

yield

caused

is

are not

pyrophosphate

tamination

to lower

are

that

effective

like

acid

used

and

concentrations

Phosphates

be

flocculation

phosphates

clay/water

salt

high

The

solids

can

when

strength

gel

soda

used

lignite

11.1

NaOH

hydroxide

having

and

point

the

not

CO3

Na2

ash

caustic

deflocculants the acid

NaOH

caustic

strength.3

6.0

carbonate

soda

gel

2H20

gypsum

60

Minutes

progressive

12.0

CaSO4

sulfate

Sodium and

CaOH2

hydroxide

slaked

of

Solution

pH

should

sodium

montmorillonite

montmorillonite and

eventually

Thus chemical

When

Calcium

2.3.6.1

it

is

often

which

calcium will

of

desirable

treatment

to

the

the to

produces

first

aggregation

enters convert

mud

calcium

flocculation

montmorillonite

remove

the calcium

by

62

APPLIED

Calcium forms water

soda

adding

soluble

calcium

hard-

from

the system

which

forms

in

If

well

to

calcium

as

SAPP sodium sodium

or

acid

SAPP

When

added

such

In

NaHCO3

cases

as

eiLher

P207

Na2 H2

added

is

usually

the

removed

is

side

left

of

the

the

produce

removed

is

calcium

caustic

addition

decreases

If

Ca2 the

total

hardness

test

then

be

and

can

described

the hardness

can be

is

hardness

removed test

computed and

removed

the

in

mud

can

bicarbonate

be

Sec

magnesium removed

and

removed

first

CO2 The

listed

above by

pH

the

and ash

that

of

has

sodium

chemical bicarbonate

additive ions

content

in

when

known

to

of

the

the

at

to

The

surface

prevent

harm

or

steel

to

products

mud

sulfide enters the

hydrogen

sulfide

hydrogen

removed

are

HS

the

using

Mg2

ions

establish

pH

the

If

H2S the

total

usually

formations

when

mixed

filtration

drilled

with

the

C032

removed

drilling

and

corrected

basic zinc

penetrates

forms pockets

is

of

become

to

to keep

pH

the

NaHS

bisulfite

H2

brittle

and

until

the

from the

foul

method of

drop

to

zinc

to

sulfides

revert

to

deadly

remove

to ions

the

the sulfide ion

mud

the

in

is

form

by of

carbonate

that

fluid

can

cessive

produce

fluid

normal

rings

and

pipe

is

and of

of

loss

such

the rates

ex

adverse

determined by use of

the

in

corrosion

tool

of

joints in

placed

probes

the

the stand

floor

rig

and

can

operation

the

sulfate

This

is

sodium

sulfite

at

In

mud

the

enters

equipment

remove

the

in

oxygen

of

Detection

usually

by galvanic

oxygen

inspection

to

metal

placed

Rate of entrainment

surface

of

pitting

of

of

presence

an acceleration

conditions

on the

Most

causes

amounts

drilipipe

pipe

The

Oxygen

2.3.6.5

in

reduced

be

of

it

the

accomplished

by

the suction

surface

of the

02 -t-2Na2SO3--2Na2SO41

may

mud

from

oxygen

the

greatly

mud-stirring

some cases

carbonate and

mud

the

and

smelling

S2Zn2ZnSi

and

gelation

by

allowed is

addition

corrosion

produces

methods

ion

and

steels

Na2S

is

which

then

the

Mg2

ions

be

hydrogen

NaHSNaOH-Na7SH10

ion

Ca2

the

between The

Many

cannot

the

NaOH

excess

HCO3

such

that

common not

is

first

carbonate

are

be

must

it

working

sulfide

drilling

difference

that

When

Sulfide

mud

and thereby form sodium

high

to

10.5

concentration

Ca2

unacceptable

characteristics

water-base

in

been

has

expand and cause the pipe fail One method of treatment

treatment

the water

2.1.9 The

to

to

thus

obtained

Mg2

pH

HOH HCO32W CO

presence

level

ion

over

most operators

H2SNaOHNaHSH20

as

of

content

dioxide which

ions

preferred

is

and

as the

produce

calcium

in

by the addition

therefore

carbonate

the high-strength

gas that

the

CaCO3

repeated

The

Dioxide

carbon

contain

calcium

was and

ion

S2

ions These

bring

the soda

can

from the water

Carbon

removed

of

ppm

calcium

the carbonate

is

embrittlement

corrosion 2.3.6.3

75

Hydrogen the

thought

is

into

NaOH

by treating with

alone

concentration

hardness

of

to

to

Raising

of

Mg2

and

to

HS

2Na

added

ash

solubility

refers

are

is

removed

the effectiveness

known

or

usually

hydroxide

is

is

soda

of

the

the

calcium

Magnesium

then

Calcium

10.5

creases

magnesium

mud and

the

sodium

of

ion

carbonate

the

H2SH

calcium

as

Ithrd water

NaOH MgOH2

Additional

the

term and

treatment

Mg2 ahoui

The

unwanted

by the addition

of

and

calcium

in

to

ions

problem

produced

montmorillonite

by chemical

50

case

previous

presence

of

where

personnel

It

ions

The

hydrogen

NaHCO3CaCO3lNa

Water

containing

the

are

side

precipitate

water

ions

carbonate

CaOH2-CaCO32NA

in

the presence

four

OH H20 Hard

calcium

of

muds

equation

20H

2.3.62

the

carbonate

the carbonate

case

enters

Ca2

carbonate

hydroxide

bicarbonate

precipitates

by the addition

2.3.6.4

and

When

reaction

converts

removed

are

calcium

2H20

to

this

this

cause

two hydroxyl ions on the right sodium bicarbonate is added

In

that

removed

maintain

calcium

on

Note

usually

Na2H2P2O7Ca2P2O71

2OH

ions

reduced

pH

the

hyciroxyl ions

pyrophosphate

-I

reaction

hydroxyl

because

ions

of

20H

added

is

40H

2Na this

been

bicarbonate

2Ca2

In

levels

have

mud

into the

gets

pH

calcium

CO 2Na

Na7CO3CaCO

unacceptable

bicarbonate

ions then

insoluble

as

carbonate

cement or lime

and

the

raises

carbonate

2Na 2OH rises

carbonate

from the mud by the addition which

removed

is

Na2CO3

ash

The

different

flows

lime

20H

Ca2

many

in

saltwater

gypsum

or

additions

mud

the

enter

cement

most cases calcium

In

by

can

soft

ENGINEERING

DRILLING

the

be

pits

by proper and other necessary

as

sodium

addition

mud pumps

of

DRILLING

FLUIDS

63

TABLE 2.12QUANTITY OF TREATING NEEDED FOR EACH

AGENT PER BARREL

TREATED

Ibm/bbl

OF CONTAMINANT

PPM

Amount Agent Contaminant

Ion

Contaminating

soda

Gypsum

or anhydrite

Ca2

calcium

Ash

SAPP

SAPP

Ca2

calcium

Ca2

calcium

Mg2

magnesium Hard

SAPP

OH

hydroxide

sulfide

Hydrogen

S2

sulfide

keep

pH

lime

bicarbonate

0.00147

Ibm/bbllmg/L

to

soda

0.000535

lbm/bbl/mg/L

0.000397

ibm/bbl/mg/L

10.5

pH

0.00116

ash

bm/bbllmg/L

0.000928

above

basic

if

lbmlbbl/mg/L Ibm/bbllmg/L

soda

ash

Ibm/bbl/mgfL Ibm/bbl/mg/L

0.00147

add

gypsum

CO3 2_

carbonate

dioxide

0.00147

high

Ibm/bbl/mg/L

0.000971

caustic

soda

Remove

to

bicarbonate

bicarbonate

zinc

Carbon

too

pH

or

then

Ca2

0.000971

sodium

water calcium

0.000928

high

or

sodium

Lime

okay

too

if

Treating

mg/L_Contaminant_lbmlbbl

pH

bicarbonate

sodium

OH

hydroxide

if

pH

if

sodium

Cement

Remove Add

To

of

Add

to

if

pH

10

Ibm/bbl/mg/L

and add

carbonate

0.00123

Ibm/bbi/mg/L

Ibm/bbl/mg/L

pH

okay

0.00100

too

low

0.000432

lbm/bb/mg/L

0.000424

lbm/bbl/mg/L

bicarbonate

HCO3

2.3.6.6

Concentration

Removal

tamination that

certain

mud

and

the

basic chemical

weights

of

the

added final

If

denotes

mole/L

that

is

agent

for

in

in

equivalent

denotes

of

the

of

weights

per

treating

treating

mud

involved This

prepared agent

valences

Contaminant

reaction

was

expressed

has

as

required

for various

valence

Using table

Table

concept

amount

of

from

mg/L

2.14

mud

drilling

engineer his

plans

1500-bbl

centration

soda ash each

he

determine desired

to

100

add

to

mg/L

50

should of

the

add

calcium total

calcium

soda ash the

Determine each

present

mass

of

shown

has of

reduce

to

The

reaction

of

i0 gew/L

interest

is

and given

the

concentration

of

soda

Na2 GO3

10

is

barrel in

the

ash

amount of

calcium

needed

z5 l0

to

for

The

Also

and

in

have

equal

to

yields

gnole/L

of

mud

mud

to

gew/L

with

jCO3

con

calcium

the

for

Solving

the

molecular

16

12

gm/eq

The

bbl or

316

Na

Thus

needed

that

mL

of

weights

respectively

Na2CO3

350 shows

GO32

agent

that

The mud

.1223

2.2

treating

2.15

Eq

by

bbl

treatment

Table

ion

CO2CaCOI

Ca2

Recall

Solution

the concentraf

present

test

mg/L

enough

system

to

mg/L

titration

contains

two

I02

5.Ox Example

of

the

this

remove

to

contaminants

exhibited in

the

1000 mg/g

of

respectively

lists

of

is

normality

5.Ox

are the effective

and

chemical

Ca2

Since

agent

concentration

2.15

V0 and

by Agent

Thus

I0 gmole/L

2.5x

mole/L

in

two

of

equivalent

the concentration

to

valence

contaminant concentration

in

I.Omg/L __________

to

con

1/11V0 where

change

mg/L

complete

takes

it

expressed

equal

the concentration

and

contaminant

of

is

40 and

of

weight

desired

i.e

step

volume

unit

2.12

the

for

40 g/g mole

contaminants

volume

entered

molecular

add

also expressed

contaminant

in

of

treating

unit

per

be

to

principle

removal

centration

chemical

to

agent

chemical

determined

has

evaluated

Con

for

been

has

it

contaminant

been

has

how much

decide

of

type

agent

treating

Chemicals

of After

chemical

lime

2.5

is

mole

g/g

one equivalent

is

10

2.65 barrel for

given

are

by

23 12

concentration

concentration

Na2CO3 lbm/bbl

and the

of

mole/L 10

g/L

pilot

testing

expressed

is

in

64

APPLIED

035 2.65xl03

Humic

g/L bbl

eq

0.000928

bbl

g/eq

acid

containing

structures

with

carboxylic

acid

calcium

Thus

mud

of

barrel

centration already

mg/L

mg/L

per

2.12

1500

of

Na2CO3

con

value

this

reduce

is

mg/L

100

increasing

2.15

Example pit

tests

ions

also

mud

in

The

Ground

reduce

to

or

fluid

and

several

determine

to

the

9.0

lbm/gal

10

cp

lbf/sq

point

90

ft

pH used

are cake

to

reduce

characteristics

are related the

cannot

mers

also

be

are

Since

used

and

rate

aid

The

common

the effective

creasing

unlike

Starch water

salinity

muds

with

exposed to

pH

Sodium used is

at

less

ppm CMC in

and

Sodium stable

to

clay this

be

high

the

limitations

these

it

is

with

and

modified

also

or

thinners

and

products

are

can

above

CMC

be but

and

order are

more

yield

of

it

of

is

low

above

0.5

Both

subbitumjnous The humic acid which

control

and

when

using

salinity

used

control take

not

hard

Lignites

lignite

between

active

well-defined

and as

Lignite

of

the

ex

molecules peat

component

and is

chemically

active

25

lhm/bhl

excessive

Common or

arihydrite

while

salt

absence

cement In

is

of

of

flocculated

possible

sodium

Since

acid

deflocculant

low

tion to

as

The

reduce

0.5

and

the

pH

ce gases absence

indicates

probable

indicate

results

test

would

be

the

presence

the bottoinhole

to

of

of the

treating

be

effective

treating this

at

pilot

tests

con

is

suitable

low This

concentrations

cement

deflocculant

contaminated

mud One

these

temperature

would

be

for

nature

pH

the

that

perform

to

for

suitable

known

the high

SO42

indicates

high

con

CV

and

acid-forming

gases

lbm/bbl

acidic

of the concen

electrolyte

Nat

and

salinity

pyrophosphate is

the temperature the cause

cement or lime contamination

prescription

taminants

as

to

defloccularit

using

montmorilloriite

high

and

of

roughly

is

contamination

the

due

and

salt

abnormally

lime

or

con

or

electrolyte

Ca2

acid-forming

summary

clay

concentration

Thus

are

gypsum

the

an

floc

content

high

Ca2 and OH H2S and C02 The low of

that

for of

addition

sources

mud

the

in

causes

sodium

In

probably

is

mud

range

solids

clay

excessive

not

is

the fact

in

by the

methylene blue capacity

ment

have

extensively

advantage

coal

or

agents

of

of

additives

viscosity

been

major is

mud

centration

lbm/bbl

active

electrolyte

the to

not

flocculation

and

calcium

minimum

stability

rank

the

high

temperature

equivalent

in

common

the

viscosity

solids

normal

The

high

indicates

to

sensitive

flocculant

is

agent

mud

to

mud

the

Thus

plastic

inert

point

yield

mud

verified

is

within

are

is

of

this

is

density

high

which

technical

and

normal

high

unweighted The normal

the concentration

centration

are

temperature-

extremely

at

filtration

temperature

yield point

show

given

abnormally

an

for

excessive

culation

low con

at

an

flocculated

mud

50000

polymers

In

grades

temperatures

designed

not

the

results

test

filtrate

is

tration

is

have

API

indicates

of

increase

lignitcs

and

viscosity

plastic

viscosity but

plastic

is

muds

strength

gel

even

is

filtration

high

of

The

Solution

mud

used

300

clay

grades

control

above

at

ranges

be

polymer

type

All of

Lignite

of

kept

acceptable

and

used

CMC

loss

but

he

Refer

thermal

Also

be

saltwater

concentrations

at

must

in

viscosity

filtration

the test prescribe any additional recommended mud performed or for normal to Figs 2.30 and 2.31

be

treatment

unweighted

water

CMC

added

as

cellent

must

At low concentrations

solids

ness

to

polyacrylate

than

act

and

by

used

cannot

temperatures

lowers

thus

effectiveness

calcium

it

concentrations

number

in

creasing regular

200F

deflocculate

to

addition

available

must

tends

and

centrations

salt

145

temperature

of

results

should

in

by

Since

to approximately

up

the

that

sodium loss

unaffected

carboxymethylcellulose

at

test

11.5

temperatures

Estimated bottomhole Using

primarily

is

saturated

above

effective

point

It

high

in

120

Temperature

poly

starch

water

relatively

action

except

with

is

about

to

200

blue capacity

Methylene

water-soluble

concentrations

at

bacterial

preservative

muds

salt

thickness

3/32

viscosity

hardness

begins

muds

subject

water

clay

or

high

degradation in

reduce

Polymers

33

in

Chloride ppm

When

control

water-soluble

em3

filtrate

Cake

clay particles

control polymers used for filtration are sodium carboxymethylcellulose and polyacrylate

mud

problems usually

filtration

11.5

API

materials

improve

of the active

effectively

substituted

types of

filtration

flocculation

to

deflocculants

clay

Several

filtration

The

problem

CO3

Yield

Control

in

diagnostic

follows

as

are

Plastic viscosity

Filtration

loss

mud

freshwater

unweighted viscous

performed

results

Density

2.3.7

as

chelate

sulfonated

tised

are

such

can

viscosity

too

appears

are

test

lbm of Na2

acid

chromium-treated lignites

heterocyclic

groups

to

of

l500100--50 69.6

and

Humic

groups

polymer-reacted without

high-molecular-weight

functional

many

magnesium

causticized

the 0.000928

or

of

aromatic

Ca2

the

mud from

bbl of

per

Ca2

in

that

To

the addition

requires

of

change Note

Table

in

Ibm

0.000928

indicated

is

given

concentration 50

of

treatment

mixture

is

polymers

ENGINEERING

DRILLING

contamina also tends

mud

filtra

DRILLING

FLUIDS

65

TABLE 2.13COMMONLY

USED

LOST

CIRCULATtONJ

Co Material Nut

Type

shell

Plastic

granular

Limestone

granular

Sulfur

granular

504510-100 50/o1O-100 50/otO-100

Nit

granular

5Cx/x_l0.l6

SO/u10-100

Cellophane

laniellated

Sawdust Prairie

hay

fi

Bark

seed

Prairie

hay

hulls

Cellophane Shredded

wood

Sawdust

tion

control

API

the

also

loss

may

This

20

0.25

mesh

40

0.12

mesh

20

0.12

20

0.12

60

0.10

mesh mesh mesh 0.10

particles

10

0.10

bra us

1/2-in

fibers

10

010

3/R-in

fibers

granular

fine

fibrous

3/s-in

particles

lamellated

1/2-in

flakes

fibrous

1/a-in

fibers

be

can

t/6-in

required

be

Lost

material into

Circulation

added

is

highly

filter

cake

additives

must

provide

base of

list

is

or

can

be

bridge

using

used

common as

Note

that

may

be

must be sealed

that

the

sealed

using

The

twice

that

special

Clay

often

are not

and

degree

additives fracture

mud

of

formations

low-permeability velocities

sizes

and

manner which

2.3.11

mercial decrease

in

much

used

In

separate

The viscosity

linking

The

available

differences

in

Also

adsorption or

their

hard

of

flocculants

are

can

be

sodium mont for

much

thought the

on The

easier

to

of

greatly

weight

vinyl

effectiveness

and

polymers is

it

com result

as

of

degree

act

reduced

Howvr

and

particles

performance

through

reduces

turn

in

that

hydrolyzed

the

in

act

this

of

polyacrylates

nnt

with

the can

biopolymer

annular

flow

permits

beneath

the

biopolymer be

used

is

grade

substitute

The

structure

much

amounts

are

of

like

thinning shear

filtration

on-

additive

rate

such

the

also

obtained

as

starch

is

much

This

shear action control

solids

The

and can

salinity

used

but

Since

giving

smaller

asbestos

low

muds

have

unless

CMC

muds filtration is

used

as

produces

low viscosity

solids

or

as

entanglement

Asbestos

low

clay tangled

relatively

Concentrations

used

as

build

fibers

mechanical

is

of rates

efficiently

greatly by

attapulgite

most

shear

water

by salinity

Like

as

the apparent

cleaning

more

required are

in

observed

hydraulic

asbestos

characteristics

rates

at

is

such

representative higher

allows

salt

by

polymer

the drillstring

in is

asbestos

commonly

affected

At

affected

viscosity primarily not

rates

operate

not

fine

lbm/bbl

and

bit

saturated

in

increase

large

better

to

the

phenol also must As little as 0.5 lbm/bbl

shear

viscosity

thinning

of for

bactericide

conditions

apparent

strain

substitute

chlorinated

or

at

of

as

Since

conditions

representative

equipment

used

biopolymer

observed

developed

particular

bacteria

cause

viscosity

lower

recently

by widely

by

readily

in

greatly i.s

at some

produce

example

muds

low-solids

in

used

other

increase

to

clay

varies

molecular

water

water

equipment

are

polymers

since

as

solids

control

by adsorbing them together

hydrolysis

brackish

serve

flocculated solids

high viscosity

extenders

yield

the

com large

certain

clay

the

increasing

polymers

vinyl

To obtain

he

of of

cause

concentration

extenders

clay

using

mercially of

to

can

easily

must

grades

polymers called

addition

solids

clay

becoming

is

water

achieved

capacity

an

produced

paraformaldehyde be

carrying

viscosity

is

when

polymers

and

Substitutes

Clay

tacked

larger hole

annulus

apparent

electrochemical

Polymers

annular

clear

In

common

rate

drilling

lower

vinyl

morillonite clay

the

of

increase

to

clay

the

in

the

usc

pump

are not

viscosity

competent

high

fluid

drilling

velocities

The

When

This

are the partially

CyflocTM

the

particles

mud

the

characteristics

hard

by the

the

improve

to

fluid

drilling

as

annular

effective

increased

soluble

developed

used

is

high the

at

be

can

frequently

filtration

same

Larger

techniques

drilling

con

using

the

Certain

increase

aggregation of

viscosity

clay

when

required

rpm

between

forces

bacteria

Good

Extenders

600

fresh

in

approximately

obtained

having

Fioccubnts

Clay to

biopolymer 23.9

be

also

is

mud at

extenders

clay

rate

would

measured

added

built

in

using

filtration

which

2.3.10

be

largest

API

commercial clays such

of

yield

bentonite

clay/water

viscosity

openings

0.25

is

Before

can

double the

to

water

tractive

cake

0.02

Wyoming

circulation

circulation

lost

2.13

opening

openings

the mtid

Table

fractures

lost

0.05

mud

of

fractures

the large

across

circulation loss

natural

deposited

which

upon

commonly

in

given

Lost

control

to

permeable sandstones formations and induced

cavernous

mud

Control

mud

to

0.06

12

20

ventional 2.3.8

0.07

0.04

reduce

to

determined

10 10

0.05

particles

tests

pilot

mesh

1/a-in

fibrous

additive

filtration

25

bra us

bra us

Cotton

in

flakes

3/4-in

Sealed

Fracture

Largest

20

mesh

5C/o/ni-lO

granular

perlic

ion

mesh

500/o_10.100 Expanded

ntrat

lbm/bbl

mesh

50/oAs-t0 50%10-100

granular

shell

rice

Description

ADDITIVES

it

is

shear at

high

high

API

control

Acbetrw

66

APPLIED

muds

tend

to

but

settle

species

of

asbestos

are not

used

2.3.12

Density

remixed

are

However

ing or stirring

PBP1

pump

by

easily

must be noted that certain

it

are regarded

as

and

carcinogenic

is

the

Additives

primary additive

muds

clay/water

can

ibm/gal

be

used

Barium

to increase

Densities

obtained

sulfate

the density

from

ranging

mixtures

using

2.16

19

the weight

to

alternative

Recently

Fe203

hematite

and

5.3

to

as

in

are

conventional

to

the

they are harder

the circulating

problems that ibm/gal never

dense

75

of

gravity

can

mud

require

for barite

materials

would

having

specific

greater

pore

excess

operations

of

19

since

and of

determination material

of

the

specified

capacity require

not

is

of

mud V1

of

of the

to the desired

mud

old

and

given

The

In

viscous

quite

19

the

is

weight

sorbed

VB

V1

requiring given

increase

Sec

2.2

water

tends

to

weight

mud

storage will

case

it

is

V2

the

V2

Solving V1 and

Pi these

mB

wet

to

up

has

the

volume

water

the expression

for

per

total

the

the

including

minimum

mass

volume

water

material

weight

water per to

viscosity

unit

of

jQL/

preventaii Including

VWB

barite

yields

mB

VB VVi

expression

the additional

gal of

influid

of

achieve

mixture Thus

sufficient

usually

is

increase

unacceptable

V2V1

the

of

ad

particles

to

the

of

only

surface

with

water

disadvantage

because

of approximately barite

the

material

density

add

for

an

fluid

drilling

by adding water

the density

the

the

has

adsorb

mBVWB

PB

mass

of

water

in

the

mass

gives

P2

mud

of

mass

and

weight

V2

Solving

product

and V1

m9

simultaneous

equations

for

V1

rnBpWmBVWB

material these

1B

simultaneous

equations

for

unknowns

yields

unknowns

yields

\f

2.19

pp1

2.16 and

and

mBV2VlpB When final

mud

in

can

finely divided

weight

desirable

addition

Łquired

the

in

become

to

barite

V1

total

V1

is

barite to the

fluid

and

make

of

APi

API

water

free

to

to lower

to

Likewise

must sum to the desired density-volume P2

of

area

solution

this

lbm of API

in

of

additional

often

required

The

finely

must

PB Likewise

barite required

drilling

divided

surface

the surface

on

However

VB

material

The

material

in

mixing the

ideal

11.5

2004235

problem can be overcome

the

the

the

cause

amount

this

API

of

amounts

large

can

fluid

be discarded

should

For

weight

new volume

mud

of

addition

balance V2

35.0

204.255

V1

significant

increase

V2

by

than

of

barite

volume

6255 lbm

lbm/gal

excess

the weight

2.17

V2

the

and

density

material

adding weight

volume

When the

portion

volume

proper

before

Eq

Using

This

volume

of API

final

35.0-11.0

P2

PB

pressure

allow

mud

of

using

204.255bb1

large

material

weight

specific

density

discarding

of

amount

available

Eq

the

2.18

PBP1 200

about

in

presented

density

Compute

limited

2.7 the density

Using

extremely

present is

calculations

to obtain

required

having

These

not

is

the

lbm/gal

by

drilling

this

fluids

galena

11.5

required

From Table

Ibm/gal

less raises

density

the addition

muds

barite

increase

to

the

hardness

special

in

weight

drilling

describe

accurately

sum

of these

for

mixing calculations

ideal

clay/water

the

hard

as

as for barite

The

given

requirements

formation

the

mud

normal

used

weight of the minerals earths crust The hardness

same

is

drilling

average the

35.0

from

significantly

mineral

be

However

requires

during

is

as

system

PbS

Galena

twice

than

be

will

rate

to

mud

volume

final

API

of

Solution

specific

densities

attrition

the question

with

weight/volume

However the increased of how abrasive these

barite

such

ranging

about

than

in

The

barite

desired

is

have been introduced

11

and

The increased

barite

Since

gravity

particle-size

be

specific

agents

FeOTiO2

heavier

decrease

will

mud

the

specific

from 4.5

materials

materials

with

It

11-ibm/gal

barium

of

an average

density-control

ilmenite

gravity ranging

These

has

barite

of

about 4.2

gravity of

4.9

API

fluids

bbl

API

clay and water The specific gravity of pure barium sulfate is 4.5 but the commercial grade used drilling

200

of

of

sulfate

in

2.18

PB -P2

Lxample Control

ENGINEERING

DRILLING

the

final

volume

volume

volume can

be

by rearranging

2.17 of

mud

calculated

Eq

2.16

is

not

limited

from

the

mB

PB

PBVWB

V2V1

2.20

the

initial

Example

2.17

It

is

desired

to

increase

the

density

DRILLING

FLUIDS

800

of

bbl of

gallon

API

of

of

will

barite

to

the

discarded

the

The

gal/ibm

needed

prevent

volume

mass

water

The

14

Ibm/gal

each

100-ibm

to

with

excessive

volume

and

Solution

added

be

mud

final

Compute

mud

12-ibm/gal

water

mud

0.01

67

of

of

old

of

API

800

mud

should

mBV2Vl_VpR

be

VVB

of 12-Ibm/gal 2.19

and

is

mud

2.18

Example is

For

desirable

14

to

operations fraction

14.0

0.03 is

18.330.011120

Thus

99.47

barite

mud

of

API

adding any

API

bbl bbl

should

barite

needed

Eq

Using

discarded

before

the

2.20

800700.5342

135.00.01

with

water

but

bbl

mud

final

adequate

original

mud

amount

of

The

that

should

volume

be

API

and

water

to

mud volume of

the

800

bbl

is

amount

of

and

the

should

be

discarded

barite

volume

from 0.05

present

Compute

drilling

the

solids

low-specific-gravity

by dilution

1000

resuming reduce

to

it

95-ibm/gal

that

added Solution

The

needed

can

be

volume

of

volume

initial

computed

800

bbl

mud

9.5-ibm/gal

2.21

For

final

by

given

is

V1

of

Eq

using

0.03

ibm

108312

of

well

the

of the

before desired

is

in

casing

the density

of

mass

by

given

is

be

cementing

ibm/gal also

It

considered

35.00.01

700.53

After

increase

to

final

mud

18.330.011 135.00.01

2.23

added

for barite

volume

2.22

PB

the

desired

is

that

computed using Eq of 800 bbl V1 is given by

volume

bbl

barite to be

be

can

of

thickening

requirement

initial

One sack

480bb1

V1800 0.05

The volume 0.01

of

water

added

to be

with

the barite

is

520

Thus

discarded

m11l083ga1or25.79bb1

bbi

35.0 Considerable treatment

the

costs

mud

total

system

reduction

in

less

expensive

the

mud

that

volume ideal

new

is

mud

be

not just

volume

of

mass of weight

combined

mud V2

does

can

to

be

For

obtain

The

much

is

made

is

dilution

the proper

and

given

by dilution

dilution

during

mixing calculations

volume

concentration

the conversion

water

new

of

as

possible

When

should

mud

in

because

mixing

mud

old

material desired

the

total

on

the

mixing

procedure

requires

balance

volume

amount

of

of

can on

be

the

obtained

by performing

low-specific-gravity

in

low-specific-gravity

terms

solids

solids can

be

fractionf1

mud

V1V21 id

equations

simultaneously

yields

is

ibm

the

junction

with

capacity

of

shaker

mud

in

and thus

It

is

below the

alone

used

falls

point

shown

as

are

used

to increase

15

suited

best

can

on

Fig

in

con

in

rate

series

screen

for

muds

fine

is

of

solids

handled

be

the

in

the flow

The

Ibm/gal

screen

is

barite

by

defloccuiation

At higher densities

remain

API

removal equipment and shaker hydrocyclorie

through

and

screen

cleaner

density

pass

be

barite

lowsize

solids

of

arrangement

API

effort

particle

the

cut

sometimes

they

the

their

and

clay

undesirable

their

cannot

be

weighted

possible

of

range

of the

range

However

called

size

because

systems

the

before

by screening

Hydrocyclones

particles

every

remove

the

can

of

active

Thus

The

lowers

that

solids

water

to

Muds

density

composition

is

within

efficient

2.21

ideal

made

solids

dilution three

needed

barite

Weighted

formation

material

weight be

for

for increasing

inert

clay/water

moderate

v2 these

API

of

mass

Control

The

that

Solving

8.33

17l4235.0219000

solids

tolerated

2.26

of the present volume the desired new volume fractionf2

f2

of

particle-size

fl1B

third equation

and

Solids

addition

weighted Pi VI

expressed

2.3.13

reduced

balance

the

2.23

800480

gravity

mass

480

by

should

PB

The

Eq

m8

inert

by

mB

Similarly

be

contain

determined using the

ideal

should

precedes

V1

volume

35.0

given

bbl

bbl

171

Using

1000

initial

80035.09.5

14.0

Vw

mud system if the low as possible and

concentration

before

operations

dilution

m3

solids

barite

weighting

V1

is

discarded

API

any

achieved

from an unweighted to system done with the low-specific-gravity

minimum

the

at

be

weighted held

is

conversion

weighted solids

for

volume

initial

can

savings

the

adding any water or barium sulfate 2.22 the volume of water needed is

Eq

Using

of

before

Much

of

the the

the liquid stream bypass

the

mud coarse

cleaners solids

are

exiting the top

screen Also

much

less

the

mud

of the

unit

in

dilution

requires

68

ENGINEERING

DRILLING

APPLIED

Discord

MICRON

loam

OI

01

100

BAR

468

iF

___

ITE

1cm

O000 468

1000

468 iii

ILow

Water

O\\0S

BENTOFJITE

Suction

2.27-.-Schernafic

Fig

-J

ment

50UR SAND

IRE lFSAAD

SILT

for

solids-control

of

arrangement

mud systems

weighted

equip Ref

after

AVEL MESH SHAKER DISCARD

ym__

k-

MESH

5Q

MESH MUD

IN

DISCHARGE

SO MESH cENrRIFuGE

ENTRIFUGE

1OBACCO

UER

TER

OVERFLOW

LOW WATER

ESANDER

SMOKE

qMU1D q01

BEACH

MILLED

p01

WATER

SAND

BARITE

AFI

SETTLING

68F

RATE

WATER

OF

DRILLED

FEET

PER

SOLIDS

2.26Particle

size

discarding

become often

the

are

employed

sizes

that

and

extremely

fall

slurry

An

discarded weighted

of

the

the

the

mud

must

Also are

from

the

amounts required

has been

density

of

API

be

with

baritc

and

mud

slurry

underflow

p1

enter

the

built

of

than

additional order

determine

to

and

mud

that

the

the

containing

while low-density the low-specific-gravity solids

centrifuge the

API

slurry

and

the

Fig 2.28 and barite

p0

rate

is

given

by

pqp rate

out

of

the centrifuge

is

q0p0

q0p5

continuous

the

operation

mass

centrifuge

must

centrifuge

Equating the expressions

and

of the

2.24

mass

total

out

rate

mass

out

rate

equal

the

mass

into

the

out

of

the

mass

rate

rate

rate

for

in

gives

qp5

q1p1 Substitution

Eq

and

2.25

of

the following

flow

Dilution highexits

the

containing

most of the water

rate

from

mud

flow

2.25

q0p0

2.24

overflow

for the

in

rate

underflow rate

for the

gives

equation

Pm

qm

Eq

solving

This equation

in

sum

into

by

given

the

clay chemicals

Consider

rate

into the centrifuge

rate

inq1

rate

material

barrel of

the

is

flow

drilled

less

in

water

underfiow

the

mass

Similarly

centrifuge

Analysis shown centrifuge

for

be

will

to

and

volume

constant

reconstruct

to

and

the

small

made

solids

depleting

barite

undertlow

fine

mass

For

chemical

the overflow

and

rate

less

total

mass

bentonite

overflow

Centrifuge

diagram water

API

the

the

the

can

processed

2.3.13

of

flow

for

system

and

prevent

mud volume

total

calculation

proper

in

to

is

usually

the

New

of

of

maintain

water

some

with

mud processed new mud must be

volume

balance

added

be

since

the bentonite

used

is

mud

Fig 2.27

in

mud

overflow of

rate

centrifuge

of

q0q5q1 q0 The

The

active

removal

shown

is

discarded

is

discarded

reclaimed

volume

of

centrifuge

chemicals

mud

muds

the

slurry

solids

example

three-fourths

content

solids

low-density

clay/water

About

to

the

diagram

the

exits

the flow

high-

Ibm/gal

23.0

returned

is

the

overflow

and

lbm/gal

Thus

centrifuge

mud

the

low-density 9.5

having the liquid

manner

this

into

slurry

and

system

In

and chemicals

can

centrifuges

from

2.28Flow

Fig

with

particles

range

approximately

slurry

high-density

mud

solids

fine

the

barite

in

dilution

situation

separate

approximately

density

when

to

of

MUD our

PU

MIXING

5990

found

barite

the cost

this

API

the

in

divided

is

In

high

39

solids

API

of

mud and

old

quite

stream

volume

large

of

portion

common muds

for

range

WD

CLAY ADDITIVE

10

water-base

weighted

IN

MINUTE

.01

Fig

TR

IN

UERFLOW

Po q1p0

allows

the calculation

knowledge rate

the water

and

densities

of

2.26

of

of the

water

into the centrifuge

mud the

entering

the

the centrifuge

underflow

and

underflow

flow

rate

and of

densities

and

overflow

the slurries

exiting the centrifuge

The

reconstruction

underflow

occurs

of in

the nit

mud from downstreim

the centrifuge of

thi

n

FIUDg

DRILLING

trifuge

from the

It

desired

is

the

69

mixing

be

volume

knowledge

of

water and

API

barite

the calculations with

the

the desired

final

of of

rate

and

rate

into

the

mud

the

stream

stream

to

water

and

be

fumfuw

mud

stream the

Furthermore

mud

feed

then

the

consist ratio

fB

and

diluted

of

as

and

existed

The

volume

PC of material

rate

exiting the mixing

by

density these

and

WB

simultaneous

unknowns

for

equations

yields

dilution into

PB W-I P1

PC

should

the

in

water

PB

PB WCl

centrifuge

underfiow

the

in

Pm

PB

mixing of

perfect the

q2

of

underfiow

2.32

PB

same

From

the centrifuge

and

assumption we obtain

this

fuwfum Also then

since can

.fUB

wBql7_qU_qW2__--

2.28

be

fractions

volume

the

all

PC

one

to

by

expressed

qi

2.29

219

Example

2.27

and

forf andfB

expressions

fm

for

solving

Eq

into

dilution

gives

2.30

PBP

flow

barite

to

The

the

of

the

is

of composed defloc

etc

sufficient

only

of

portion

the

Compute

mud

to

the

mud

and

the

contains

lbm/bbl

which

at

mixing

of

density

The

Wyoming API barite

and pit

to

maintain

the

constant

properties

given

The

by

Eq

flow

rate

of

underflow

the centrifuge

2.26

10.579.38.33

16.5316.29.3

23.49.3

stream of of

composed

pit

is

the

at

mud

the

Solution

7.36 gal/mm

the old

The

fraction

by

given

added

the

water

deflocculant

be

rate

at

of the centrifuge

bcntonite the

8.33-

additives

required The fraction mixing

are

bentonite

additives

Thus

are

pit

from

stream

mud

control

remaining

from the mixing

undertow

should

while

Ibm/gal

9.3

with

the centrifuge

respectively

Wyoming

has

filtration

treat

qfB

API

and

water

underflow stream

the

concentration

desired

dilution

the centrifuge

and

already

culants

mud

mud

old

from

pit

fraction

mud

old

of

qufm

by

given

rate

is

enters density

lbm/gal

Wyoming

deflocculant

bentonite The

23.4

is

lbm/bbl

22.5

The

entering

is

along

gal/mm

which

water

overflow

centrifuge

16.53

gal/mm

10.57

underfiow

PB

PRPm

of

rate

mud

16.2-Ibm/gal rate of

at

centrifuge

lbm/gal these

Substituting

Pi

i1

V.

sum

must

fum

uB

to

mass

of

fraction

the

in

in

water

going

given

is

Solving

barite

assume

mud

feed

mud and

feed

they

we

if

the

Similarly

q2

are the

dilution

exiting

2.27

API

water and

dilution

rate

by

additional

PuPmfunPwfuwPJUB where

PB

mud

of

by

expressed

flow

total

expressed

WB

simplifies

composed

mud

the discarded

from

he

be

can

dilution

pit

dilution

The

mixing pit

pit

density

mud

reconstruction

for

exiting the

mixing

mud

feed

feed

underfiow

in the

underflow can

of the

the

flow

feed

properties

mud

barite stripped

mud

fraction

Consider the underflow old

the

density

required

mud

final

to

addition

to

equal

obtain

equal

In

centrifuge

should

to

pit

is

given

by

of

Eq

old

mud

in

undertlow

the centrifuge

2.30

qufum

35.023.4

fm

0.324

10.57

If

is

of

the desired

additive

given

additive following

the

in

added

be

must

in

concentration

mud

per

stream

the

to

pounds

mixing

then

time

and This

mass rate The

are

which

volume

of

water

the density

of

the

the

same density

as

the

determined

mass

also

can

be

2.31

barrels

used

to

commercial clay should

tain

be

in

expressed

through

and

mud mud

API

barite

leaving entering

balance

of

the

per

unit

obtain

the

be

main

mixing

at

material

pit

of

clay

using

Eq

2.31

The

water

entering

Eq

2.32

flow

deflocculant

can

be

gal/bbl

22.50.3377.58 xO.337

and

7.360.3241

42

can

the centrifuge

rate

22.5116.53

added to

needed the

35.08.33 16.53

The

computed

expression at

the

rate

mass

35.016.2

this

at

pit

wjcjqplfcjq77qf where

barrel

2.02 rate

Assuming

Ibm/mm Ibm/mm

into

the

density

clay deflocculant

mixing of

pit

21.7

is

given

lbm/gal

by for

70

APPLIED

12

II

MUD

the

and

clay

and

deflocculant

for the weight

ibm/gal

WEIGHT

2.29u_SoIids

Fig

both

13

material

20

14

ppg mud

vs

content

of

density

35

gives

FROM

MUD

to

be

-1

/35.0

7.581

2.021

because be

water

gal/mm

rate

maximum

21.7

35.08.338.23

given

yield

of

given

mass by

rate

Eq

API

of

barite

into

the

mixing

pit

is

2.33

to

2.02/ 35.0

and 17.4

ibm/mm

API

mud

barite

of

plastic

API

the

balance

based

is

generally

of

The

increases

with

causes

cost

solids

of

in

an

reducing

mud

solids

From

considerations

the

interpretation

content

and

data

retort

of

content

the proper

tests

on

must

that

densities

both the low-specific-gravity

part

diagnostic

The

density

density

of

essential

harite

barite

the

2.31

mud

mud

API and

viscosity

viscosities

and

viscosity

of

high-specific-gravity

an

is

2.30

API

of

plastic

with

mud-treatment

with

the higher

addition

increases

the

Figs

and

viscosity

plastic

decreases

obtain

determination

The

21.7

21.7

in

viscosity

16.537.368.23--_

in

to

prescribed

possible

acceptable

point

suggested

because

density crease

7.58

WB

of

is

plastic

the larger quantity

suspended

maximum The

lowest

the

ranges

mud

reasonable

usually

point

yield

at

Typical

have

still

treatment

and yield points are shown

/35.0

\21.7

and

Mud

filtration

cost

muds

maintained

properties

116.5335.0_16.2_7.3635023.4

BALANCE

freshwater

for

weight

achieve

q2

ENGINEERING

DRILLING

mass

analysis material

balance

we

have 2.3.13.2

Solids

established

and

maximum in

given

Fig amount

optimal

the

Lowering gravity rate

quantities of

at

solids

content

of

2.29

Within

the

of

solids

is

conccntration

the of

same

expensive

deflocculants

Empirically

on the recommended

would

time

to

inert

requires

mud nrrnit

shown

limits

difficult

of

minimum muds are

freshwater

determine

penetration

discarding

additives

hichr

the

low-specific-

and

improves hole cleaning

solids

but

Determination

Content

guidelines

large

Also

the

solids

rontnt

use

PmPw1wP1gfPBPJo where

mud density

is

Pm

the fraction

of

low-gravity

solids

gravity is

the

volume

the density

of

fraction

oil

JHnr

of

the

is

the density

fraction the in

oil

the

water

density

is

present p7 is the density of the is the volume fraction of low-

water

solids

is

2.34

of

in

API

the

of

the

barite

mud

in

andf0

API baritefB the is

mud the

p0

is

volume

mud

relqtionhir

Pr

DRILLING

FLUIDS 71

SUOGESLED

SANGE

PLASTIC

FOR

SUGESTED

VISCOSITY

RANGE

FUR

YIELD

DC-I

b/go

POIN

C-

MUD

C-

Fig

2.31Typical

of

range

acceptable

yield

for

points

muds.5

clay/water

C-

WE

a-

0-

FLOGcULA

DISPERSION MUD

Fig

2.30Typical

be

can

of

range

acceptable

viscosities

for

written

pf1

JofwPPJopm PB

Ca

kSTART

2.20

Pig

described Recall of

Calculate

API

and

the water

dissolved

salt

is

1.0857

is

Eq

Using

for

2.8

the

Assume

fraction

of

the

oil

corrected

mud

is

and

Eq

2.7

densities

and

Pm18.33

lime

treatment

metric

units

becomes

2.36

fig4.22.6Y 4.2I

and

2.3 the

oil

2.7 the water gravity

specific

133l25Pm1833

specific

Also

0.06

.08570.773

shown

0.7734.2

to

be

2.29

Fig line

tolerated

in

0.095

line

by

specified

maximum amount

the

provides

recommended

the

is

This

muds

freshwater

removal methods

solids

8.33

in

solids

experience

12

2.6

UO.5fi

0.86

is

maximum

0.860.06

during

additives

Table

in

mud

clay/water

effect

2.35

fig

of

mud

the

listed

oil

diesel

for the

2.32Behavior

For

low-gravity

12-lbm/gal

Fig

0.773

Solution From Tables gravity

the fraction

barite

Example

in

that

TREATMENT

ME

2.35

solids

AGGREGATION

Ca

fig

Example

ON

No

b/gal

muds.5

clay/water

2.34

WEIGHr

are

of

field solids

before

major

undertaken

and 2.21

Example

lB

1fig

-fo

reported content

0.7730.06

0.095

of

32

0.072

yield

sq ft

Is this

should

muds

is

to

possible

determine

that

the

do not contain volume

fraction

oil

of

recommended

is

determined with

Fig

2.29

the

mud balance

determined

is

using

The

Eq

equation

2.34

and

well

below

that

the

not

the

exceed

relationships

28

of

15

steps

reduce

of

From Fig

the

total

solids

solids

is

2.30

mud

26.5

we

see

should

viscosity reported

plastic

excess

maximum

the

mud

14-ibm/gal

high

the presence to

see that

we

reported

cp The

30

in

the be taken

120F

at

not what

If

is

solids

120F

at

l4-lbm/gal

viscosity for

plastic

confirms

2.29

for

solids

low-

using Fig 2.29 after the total solids are determined using the mud retort and the mud weight gravity

mud

good

From Fig

it

solids

measured

measured

point

total

taken

be

Solution any

have

to

viscosity

plastic

cp and

and

oil

mud

freshwater

14-Ibm/gal

no

contain

28

of

lbf/100

For fresh water

to

Steps

content

to

should

26.5

1-f and

18 where

1s

fig is

mud Thus

2.3.13.3

Quality

volume

fraction

been

the

volume

using

Eq

fraction 2.34

ki_Pg5 PB

Pw

of

all

solids

in

the

active

gives

clay

Sec 2.1.12 2.36

can the

of

determined

proximate

be

used

cation

low-specific-gravity is

it

fraction

and it

was

desirable

of

what

to

Solids

of Low-Gravity

these

fraction noted

assist

this

exchange

to

know

low-gravity is

inert

drilled

Once solids

what

the has

ap

solids

is

solids

In

the methylene blue test determination Recall that canaritv is renrrtd in that

72

APPLIED

TABLE 2.14SPECIFICATIONS

FOR BARITES

TABLE

5THEORETICAL

2.1

OF Ca2 Property

Wet

screen

No

API

Values

4.2

4.2

Minimum

No 350 sieve Maximum residue 350

Maximum or

calcium

barife

cp

of

is

600

gypsum

in

the

of

arid

rpm

encountered

to

are

and

when

shown

The

cation

reported

in

dicted

from

pacity

of

solids

following

the

drilled

per

of the

ben

solids

the

fraction of

and

this

of

the

mud sample

of of

the

cation the

clay

can

For

be

pre

ca

exchange bentonite the

fractionfdS

gravity

drilled

using

the

Pd

are

26 g/mL

approximately

0.08

mud

yields

0.027

fraction

lbm/bbl

0.053

of

the

0.027

bentonite

is

24.6

9100.027 which 2.31

is

lbm/bbl for

high

little

such

suggests

above

mud

15-Ibm/gal

claim

since

the

Figure is

point

yield

maximum recommended value

the

inhibitive of

from

the identity

fc

active

readily

forf

during

the of

of

to

the

through

Inhibitive

water-

con

controlled

mud

Thus

by

electrolytes

also

they

contaminants

subsequent

partially

drilled

the

by

also

solids

small

extremely

They

the

reduced

formation

shales

clay/water

deflocculants

been

the wellbore

formed

are

in

has

into

mud

and

clays

are

highly

encountered

operation

drilling

2.37

the

direct

determination

from the methylene of

mud

knowledge

bentonite

of

the

total

of blue

clay and fraction

the

ben

effects

the

of

discovered

largely

analysis

of

muds

by accident

muds

Lime-treated

muds

inhibitive

calcium-treated

drilled

at

The high

as

result

beneficial

pH of

were

cement

contamination of

low-

solution retort

first

titration

The

mud

Muds

Calciurn4reated

were among

properties

great extent

2.22

prevent

which

one

Zvd

fraction samples

muds

the portions

and/or

yields

hydrate

entering

hydrated

is

to

clays

disintegrating

and

muds

base

mud

water-base

Inhibitive

stabilize

Muds

Water-Base

Inhibitive

An

to

solids

Example

solids

the

in

clay

ability

allows

and

0.08 Eq 2.37

in

volume

in

content

2.41

solids

bentonite

2.69110

slightly

reduces

2.6Zv

on

fraction

drilled

solids

Zvrn__2.61/gZVdc

results

volume

the

fraction of

sq

total

0.027

resistant

clay

value

this

tamination

2.37

the

7.82.60.08i0

easily

Eq

plastic

lbmil00

Determine

sufficient

is

has

20

of

sam

of

indicates

meq/100

mud

point

solids

volume

there

91

of

120F

at

the

Using

particles

tonite

solids

The

yield

low-gravity

re

2.6fcZvrfdsZVdc

and solving

and

cp

From Fig 229fig

greatly

11g

drilled

Solution

mud

exchange capacity of

drill solids

and

equation

.fds

titrations

mL

meq/lOO

29% and

of

content blue

mL

both

Substituting

32

whether

2.4 Since

10

measured

100

equation

100

0.0001

being

Zr

common

several

capacity

mL

cation

and

sample

it

by

methylene blue per

for

knowledge

the

ZVdc

0.0013

solids

clay and

meq/lOO

ftg

exchange

the bentonite

fractionJ

of

of

meq

meq/100

bentonite

of

2.6

Table

in

indicates

zero Methylene

of

of

ZVSc

the cation

exchange capacity

results

Typical

ap

is

analysis of

use

accomplished

on

tests

cation in

barrel

solids

the

is

sample

These

of solids

mud

of bentonite

montmorillonite per

mud refine

data This

are reported

suits

0.1300

exchange capacity simple rule of thumb is often

this

desirable

used

being

0.1000

mol/L

the cation

forming methylene blue tonite

13.0

viscosity

methylene blue per

mass

performing

capacity

of

equivalent

pounds

times

when

sometimes

meq

that

mud

application

exchange

0.0316

of 7.8 at

viscosily

weights

five

proximately

sufficient

0.0130

12.5

1.0x104 1.0x103 lOx 102

mud

125

with

of the

While

0.0100

content

of

pIes

after

mud and

oil

an

2.5-g/mL

apparent

milliequivalent

content

12.0

freshwater 0.1

ft

of

0.0032

250 wt/o

solids

suspension

mL

1.3000

11.5

1.0x105 1.0x105

15

ppm

contamination

100

0.0010

metals

soluble

Performance

Water

sieve

soluble

Maximum

1.0

sieve

residue

No

0H12

wt%

on

on

p11

molt

PJL

residue

200

OF

lCa2

gravEly

analysis

Maximum on

_______

specific

SOLUBILITY

FUNCTION

OCMA

Specified

Minimum

AS

ENGINEERING

DRILLING

15-Ibm/gal

into

an

When aqueous

of

mud depend

calcium-treated

on the amount of calcium Ca2Th solution

and

OH

they

react

ions to

to

that

enters

are

introduced

form

into

CaOH

DRILLING

The

73

FLUIDS

product

solubility

value

of

about

the

of

the

that

Ca2

the

ion

product

we repre

If

then

by

amount to

using

pilot

using

about

lbm/bbl

2S and

1.3x10

S2S2

S1

The

of

solution

The

rnol/L

ions

2S

is

given

lo138

in

saturated

102

l.38x

This

changing which

pH

the lime

altered

be

by

greatly

For conditions

solution reaction

solubility

function

pH

of

The

complicated because

of

function

of

Ca2

addition

pH

If

we

As

lime-treated

mud

platelets

and

of

shown

called

aggregation

stack

to

and

with

and

the

deflocculants

wellbore

temperature greatly aids

and will

during

and the

accomplish

culation

Quebracho

the

in

are the

variety

chrome

as

the is

of the

viscosity associ aggregation

the concentration

to

the

is

in

of

about can

lignosulfonate

made

The

Lime mud at

deflocculants

for

gypsum

at

70F

is

by

the

in

maintained between

above

one be

hard

between

reaction

mud

the

degrade good 2.4.2

as

12

of

amount

mud

lbm/bbl

used relatively

well

has

tolerance

that cir

used

calcium

high

and

calcium excess

of

300

lignosulfonate often

is

used

be

can

and

the

Inhibitive

by

adding

thinner

in

this

purpose

type

to

Chrome sodium at

of

high

mud

of

effec

lignosulfonate chloride

and

temperatures

concentration

above

chrome

as

are the primary because

temperature

temperatures

with

275F

concentrations

both

for

the

at

in

clays

polymers

Muds formed

lignosulfonate this

However

reduces

quickly

and

above

deflocculate

will

In

cannot be maintained

low cost

tiveness and

high

trip

water-soluble

common for

is

formed by

calcium

the

Deflocculant

or ferrochrome

deflocculants

requires

after is

deflocculant

are

the

usually

temperatures

that

temperatures

also

pH

at

cement

caustic

properties

muds

in is

temperatures

circulation

Lignosuifonate-Treated

water-base large

the

at

rapidly

filtration

used

high

rigid

addition

In

he

At

to begin

pH

of

easily

lignosulfonate

experienced

is

gelation

pressures

values

the

in

the

10.5

cannot

275F

value

offers

altered

and

used and

9.5

muds

about

annular

Chrome

often

most

deflocculant

high

caustic rate

mud

gypsum-treated

not

is

this

mud

lower

at solubility

12.3

approximately to

low

of

of

p1-I

reduce gypsum-treated

calcium

clay/water of

2.15

solution

Chrome

generally

operations

conversion

the

process

conversion

added

of

hydrate

and

thinning

environment

pressure

the

mud

mud

drilling

chemical

deflocculant

and

lime

to

not

subsequent

Ca2

of

solubility

to

extreme cases

Ca2

by

This

in

time

together

by

change

depends on the temperature

conversion

closer

marked

of the

flocculation

does

mud

the

replaced

proceeds

is

the

Table

High-lime

the

by

montmorillonite

reaction

ated

and

lime

which

in

lime

particularly or anhydrite

gypsum

reaction

solubility

required

However

solubility

mud

begins

are

clay

sodium

The magnitude

The

the

controlled

montmorillonite

mud

solids

of

At the same

reaction

are

l05and

in

be

progressive

thicken

the

begin

exchange

Thus

be

than

muds

Ca2

advantage more

is

the However mud still remains

clay/water

exchange

cation

mud can

formed using

are

rather

massive

drilling

represent

lime

Table 2.15

solution

clays

as

NaOH

flocculate

as

in

an aqueous

enters

Calcium

Ca2

mud

of

to

equal

l0 4.9x i0 mol/L

lime-treated

of the

lime

extensively

clay

of

in

the

cations

cations as

presence

Ca2 to

Na

the

of caustic

cation

clay

that

in

When begins

than

of

content

the

1412

of

solubility

tabulated

of

Ca2

of

solubility

of

has been

chemistry

dilution

lime

barrel numerically

per

muds sometimes

The

l.3x 10-6

the

relation

the

l0

would this

for

S.S2.4

pH Using

maintain

concentration

mud

and

desirable

is

at

predominant

is

l0

l.3x

Ca2

of

solids

An

polymer

mud

the

in

made

is

caustic

SO CaSO4

Ks

product principle implies

solubility

by

12.14

can

the

to

is

pounds

formations

Ca2

102

of

lbm/bbl

present

CaSO4 .2H20

by

Ca2

of

the

lbm/bbl

Gypsum-treated

given

pH

solubility

in

well-suited

OH

of

lime

depletion

practice

mud

average

formation

by

gypsum

1x104

pH

the slow

prevent

in

determined

is

conversion

and

lime

deflocculant

usually

theP

gives

6.89x l0-

lime

to

corresponds

of

mud

and

caustic

lbm/bbl

CaIium-trcated

concentration

solution

The

deflocculant

frequent

the solubility

for

Solving

lime

the

improve

to

the

stabilize

the conversion

tests

amount

to

the

of

make

added

excess

and

ap

added

is

usually

polymer

all

are

lignite

circulation

second

properties

The

70F

at

remain constant

must

solubility

10

states

principle j2

filtration

1.3

processed

water-soluble

during

volubility

and

lignosulfonate plicable

j2

sent the

has

CaOH2

K0 The

reaction

this

10

1.3

2OH

Ca2

for

Kcp

in

degradation of

300F

chrome Lignite

lignosulfonate

in

74

APPLIED

PRESENT

TABLE 216IONS

20

ENGINEERING

DRILLING

SEA WATEF1

IN

Concentration

ppm

Ion

Cations Na

16550

Mg2

1270

Ca2

400

C-

300 Anions

I0

18970

CI

SEA

WATER

Br

ll

Seawater

2.33

Fig

Viscosity

obtained

Wyoming

bentonite

permit

muds and

calcium filtration

because

Ibm/bbl

of

water

ssline

conversion

to

complished simply chrome

greatly

deflocculants

ferrochrome

or

emulsifiers of

not

is

or

the

maintained

be

muds

or 5/s

in

as

oil

can

be

justified

muds

weighted

and of

content in

lignite

the

mud

Note

Wyoming

mud

the

control of

also

some

and

environmental

oil-in-

of the

or titanium are

they

not

solids

effective

as

Their

lignosulfates

use

become

the use of be

chrome

restricted

mud

the

be

or

in

or

and

The

not

temperatures

low-

greater

AgNO3

The

seawater

inherent

problems of

result

of

effects

Inhibitive of

excess

Saltwater type

of

problems can high

1/s

by weight

muds

usually

mud

inhibitive

muds

arise

and

maintenance

and

concentration are are

presents as

water make-up from the combined

salts

called

capable

hardness NaCI

of

saltwater

formed

Calcium-treated

and

water

the

in

temperature

muds having

contamination treated

treatment

contaminants

mud

Severe

for

Salt

of

from

muds another

tolerating

muds

lignosulfonate-treated

in

salt

lignite-

muds

all

Ca2

are

as

Ca2 used

and

to

to

form in

sequestering

by chelation

the

thinner and

can be

high

salt

such

as

attapulgite

required

to

obtain

in

of

is

and

ac

many

other

shown

present

in

in

mud

reduce

the

detrimental

depends

the

saltwater

calcium-treated

by treating with through

precipitation

on

the

Mg2

and

of

effect

the type

phosphate with

often

NaCI

mud They mud removed

treating of

Table 2.16

seawater

the

as

salts

concentrations

to

ions

of

more

shows

is

with

However

significant

ions

determined

concentration

ppm

seawater

as

expressed is

of seawater

titration

seawater

Mg2

Mg2

and

tolerated

dition

of

present

analysis

used

improves

characteristics

extremely

NaCI

35000

detrimental

method

before

retains

the clay

usually

equivalent

to be

typical

The

seawater

from the

analysis

NaC1

than

prehydrated

is

deflocculant

concentration

about

is

detailed

Muds

High..Salinity

of

NaCI

stoichiometrically in

appropriate

like

properties

salinity

equivalent

be

of

that

behavior

different

and

clays

may

clay

mud

than

deflocculant

At

20

various

essentially

concentration

tests

saltwater

sepiolite

the

greater

case

of

salt

pilot

of

filtration

amount

using

concentrations

fcrrochrome

250F

2.4.3

The

increases with

ceptable

chrome

may at

of

and

Shown

by adding

bentonite

this

hydrate

salinity

behaves

hydration

characteristics

not

is

cake

filter

water

to

with

In

bentonite

and

obtained

entirely

treated

of

degree

viscous

more

as potassium iron on the market However

as

muds

low-weight

moderate

an

strength

gel

does

salinities

Wyoming

and

the

acceptable

of

moderate

bentonite

increased

is

salinity

determined

such are

lignosulfates

pollution

techniques

may

Other lignosulfates

future

oil

water

required

world

lignosulfates

of

the

the

if

fresh

the effectiveness

regulations the

throughout

stringent

ferrochrome

stringent

reduce

can

formation evaluation

As

than

more

requires

procedures

observed

for

that

However

solid

inert

an

bentonite

bentonite

seawater

unweighted

resulting

viscosity

presence

viscosities

Wyoming

salt

number of well-logging

for

The

of even

are the

salinities

using

The

2.33

Fig

of

hydrate

effectively

Dry water

salinity

increases

cuttings-carrying-capacity

in

significantly

instability

mud on in

for

mud

maintain

to

the

mud

to

control

loss

lbm/bbl

emulsion may decrease the adverse effect the formations However the presence

water

fluid

characteristics

increased

borehole

15/s

as

high

added

is

presence

the

are not

in

clays to

required reduces

used

be

can

that

Bentonite

is

can

and

muds

the

into

level

encountered

lignosulfonate

and

oil

treatments

properties

salt

active

of

problem

Chrome are

of

mud contamination

if

becomes

mud

in

concentration

easily

chemical

of

salt

introducing

to

through

increases

Also

ability

primarily

hole

saltwater

subsequent

the

of the deflocculants

conditions

drilling

However

beneficial

mud

concentration

the

depends on

to the desired

lignite

reduces

by

used

are

where

available

readily

in-gauge

relatively

contamination

and

inhibitive

fully

The

economically

The

and

not

is

muds

saltwater

through

ac

is

the concentration

by increasing

water

affected

tools

mud

lignosulfonate

lignosulfonate

many areas

used

chelate

improve the mud

and

ions

magnesium

to

ability

characteristics

The

In

its

fresh

muds

saltwater

marine areas

in

formations After conversion 20

by adding

of

form

to

are used

often

drilling

further

inhibitive

of

Saturated

ppm

to

muds

source

80000

65

commonly

used

are

40000

NoCI

2650

so42-

of can

the

mud be

through

or reduced in

ad

from

the

lignite

Ca

The

DRILLING

FLUIDS

75

OIL

WETTING AGENT PRESSURE

Fig

2.35Effect

in

present chemical

2.34Schemalic

Fig

of

an

droplets

by

can

carbonate

in

such

exchange

active

divalent

ion

thought

to

permits

The

to

it

added

to

carnallite

can

with

and

and is

are

fluids

composed

viscosity

is

in

treatments

called of

used

oil

muds

for the

the continuous

phase because

of

and

flammability

TABLE 2.17ADVANTAGES Advantages

high

More

properties

low

AND

oil

higher

recent

been

proven

Many

costs

muds

oil

fluid-loss used

to

mud

oil

conventional

the in

and

subnormal

costs

often

pore

oil

muds

enough

and

cost

modified

mud

successfully

improve

is

torque

pipe

back

buy

or

at

as

temperatures

Higher

in

the field

drilling

the

mud known oil mud

oil

U.S

mud

This

compared

rate

gulf

coast

area

cost

irirtiat

iohihitive

than

agaiost

Superior

lubricating

mud

all

water

iohibitive

types

of

base

muds

corrosioo

characferistcs

densities

as

low

as

7.5

lb rn/gal

Requires

wore

Reduced

effectiveness

striogeol

Remedial

treatment

Detection

of

solubilily

gas in

for

Kicks

diesel

pollutioo-cootrol of

ol

some

losr

is

the

lowcolloid

OF USING OIL MUDS

DISADVANTAGES

to

cuttings

rate

newly

years

by

drilling

high stuck

drilling

suppliers

discount

at

C02

the use of

mud

initial

for

damaged

control

of

overall

the

salt

shale

H2S

or freeing

hot

deep

or

easily

applications

less

drilling

500F

Effective

Permits

the

relaxed

has its

reduce

can

offset

problems

DrsadvantageS

rheological as

For these

the

much

used

active

where

holes

oil

of

The most common

or

formations

weak

pressure

as

No

hydrocarbon

oil

low

if

slim

control

containing

preventing

high

using

drilling

corrosion

drilling

disposal

liquid

characteristics

Good

or

In

phase

usually

directional

often

K2C03

Na2 CO3

muds

problem

neutralized

KC1

waterbase

of

are

formations

producing

drilling

solids

cause

Because

300F

potash

mations or formations

used

Drilling

diesel

for

anhydrite

agent

the

and

2.17

include

mont

deflocculant

and

muds

to

of barite

muds

for

bit

preferentially

Otherwise droplets

they

water-base oil

mud

the

pollution

temperatures

be

weUabiliy

Table

muds

oil

formations

deflocculant

KOH NaOH

and

cost

initial

water

permits

disadvantages in

application

stronger

muds When

and

out of the

reversal

in

the

prevent

by the

settling

which

is

Muds

Oil

is

of

as

as

is

been

has

KC1

muds

are substituted

any water-softening

25

KCI

as

for

agent

seawater

sometimes

used

frequently

than

size

manner

concentration

is

with

ion

bentonite

same

that

associated

of the

lattice

since

Lignite

control

filtration

the

in

as

smaller

its

higher

also

water

summarized

are

mont

much

than

to settling

destroyed

by the water

advantages

muds

solids

and eventual

viscosities

and

the rock

the

rather

oil

absorbed

be

added

be

chemical

make

ability

the

Prehydrated

higher

often

of

the

to

by

will

must

in

easily

added

The

sodium

potassium

almost

silicate

However

required

KOH

with

the

muds

contaminant be

of

is

viscosity

in Fig 2.34 water form of an emulsion

emulsifier

The

emulsify

causes

which

reduces

hydrate

structure

muds

will

to

of

swelling

of in

of

result

KCI

with

NaC1

converted

effectiveness

enter

solu

sodium

than

and

presence occur

to

clays

and

wet

effective

to

presence

be

morillonite used

is

The

morillonite

mixing

NaOH

as

the hydration

reaction

montmorillonite

the

more

is

minerals The

clay

cation

such

mud

the

Na2CO3

as

suppressing

active

of

base

strong

Potassium chloride chloride

before

accomplished

with

treating

ble

be

the

shown the

in

from coalescing

originally present seawater

As is

emulsifier

emulsion

mud

oil

on

pressure

oil

mud

oil

an

and

temperature

rubber

for

solvency

water

of

diesel

of

PSI

circulstioo

more

difficult

procedures tools

toggiog

is

more

because

difficult

of

gas

has with

and

76

APPLIED

ENGINEERING

DRILLING

VAPOR WATER

MOLECULE

SVLT

MOECLjLE

WA UNLU

TA

OLwnON

MEMBRAA

2.36Osmosis

Fig

of

water

semipermeable

through

membrane

Texas

Since

modified

the

by

colloidal

mud

oil

the

material

formulation

the

reducing

thermal

been

has

concentration

of

the

also

stability

is

compromised 2.5.1

Phase

Oil

diesel

oil

have

oils

addition

In

weathered

been

the

to

crude

used

oils

the

as

oil

to

solve

help

flash

above

vapors fire

point

sustained be

the

In the

requirements aromatic

140F

above point 50Wo

are

by volume The

cloudy

such

of

solvent

aniline

The

ceptable

viscosity

peratures

and

The

of

viscosity of

No

mud

Water tends

same

in

oil

mud

mud volume mud

the water highly less

it

content

used

some

the

water

when no

the

drilling

water

is

content

oil

in

the

low

added

5OtVo

to

of

of

sections

often

concentration

as

contents

is

the

which

shale

to

the chemical

to

shale These

muds

are

the

be

electrolyte

been

electrolyte

neither

involve

water

used shale

have

will

swell

adding of

phase

the water

in

the the

of the water

potential called

muds

oil

shales are

can

exact

potential of

also

important

the

in

techniques

CaC12

and

troublesome

Techniques

given

retains the

of

active

determining

or

an

is

increase

an

the chemical

equal

cost

the chemical

or seawater

water

These

NaC1

so that

mud

balanced-activity

in oil

muds 2.5.3

Balanced-Activity

of

given

Oil

and

Muds

function

is

system

the pressure

moles

n1

The

of the

free

energy

temperature

of each

component

present

The

change

in

..

p2 free

energy

and

with

n1

is

given

by

---dnj

T

the as

In

expression thermodynamic have the following meanings

3G

3G

volume op

to

and

at

increases the

3G chemical on

2.38

On1

op

entropy

possible

mud

this

derivatives

content

in

at

muds

properties

However

the

dehydrate.68

mud

phase

water

require of

oil

formations

muds When

fresh

for

developed

sufficient

water

phase

concentration

viscosity

to the

the

water-base

water

the high

corrosion Thus

the inhibitive

problem

nor

phase of

subsurface

the

of

decrease

desirable

is

gradually

Water

the subsurface

contact

as

when

even

of

less

cost

water it

water

to

GfTpn1

an

much

mud

has

as

water

the

slight

total

as

excessive

content

on

of

because

oil

affecting

not

the well

mud

is

the

necessary

usually

operations

of

ac tem

muds However

oil

is

applications

even

during

in it

an

causes

high

for

power

water

shale

by

are tolerated

desired

is

emulsified

well

as

Fig 2.35

water

as

factor

the

in

in

also

It

decreases

contents

However

surface

materials

pressure

emulsified

to prevent

In

becomes

other

exhibit

shown

are

aniline

NH2

range

and

Since

also

mud

of

containing

encountered

solids

maintain

the

be

increased

is

l2o

to

with

composition

can

oil

The

the viscosity of the

have been

weighted

than

should entire

density

oil

Water

density

also

oil

inert

fluid

than

expensive

an

as

The

an aniline point

many

the

The

increase

to

the

free

the solvent

to

temperature

Phase

manner

increase

over

diesel

the

oil

water

of

frequently

content

flammability

which

for

The ability

for

relatively

C6 H5

powers

pressures

effects

2.5.2

below

aniline

selected

oil

open The

which

at

acceptable

are related

rubber

as

an

have to tendency blowout preventers and

considered

to 5/c

to influence

which

above

Oils having

the temperature

is

selected

which of the

parts

equipment

drilling

be

water

marine

flame

by

2.37Adsorption

oils

safe at

of

zero

pollution

in

phase

the

to

should

oil

oil

range

of dilution

temperature

addition

that

These

Oils having

the vapors

hydrocarbons

the rubber

other

of

the

ignited

minimum

the

is

muds

oil

temperature

be

can

combustion

maintained

soften

oil

oil

diesel

Fig

muds

oil

developed

are considered

minimum

the

is

point

200F

above

point

fire

been

the potential

with use of problems associated environment Safety requires that has low flammability relatively cup

for

phase

Recently several mineral oils have have lower toxicity than No were developed

commonly used No and various refined

potential

the

partial

DRILLING

FLUIDS

At Points

77

and

for

thermal

for

mechanical

condition

closed

in

equilibrium

is

T1

equilibrium

for chemical

solution

system the condition and

T2

the condition

P2

is

of

equilibrium

the

Similarly

component

is

the

hydration

mechanism

then

vapor

and

liquid in

2.36

of

through the

water

potential

separated

is

to its

equilibriuLm

the water

must be the same of

system

with

in

potential of

vapor phase

the

water

in

The

the

change

osmotic pressure pressure

2.36

prevent

to

pressure

movement

water

sufficient

if

in

Piston

using

called

is

Fig the

through

membrane the pressure difference existing across the membrane would be the osmotic pressure For this to occur

the chemical

either

side

that

requires

be

salinity

is

of

effect

given

the decrease

offset

in

exactly

2.39

be

chemical

due

potential

to

chemical

in

hydraulic

pressure

on chemical

pressure

This

equal

the increase

by

on

the liquid phases

by the imposed

external

Eq

by

of

potential

membrane must

the

caused

potential

The

of

potential

For an incompressible

we

liquid

have

VdpVpITV

V dpz__dp dn

wP

p1

For

Vdp where

2.39

the

is

vapor

the

terms

in

molar

partial

phase

expressed

volume molar

partial

of

vapor

water

of

volume

pressure

the

using

to

the

counterbalance

due

potential

For

to

chemical

in

change

requires

salinity

lIIVRT1n

be

can

Pw

ideal

the

for

Solving

law

gas

For example

were applied

to

pressure

vapor

low vapor pressure

salinity

hydraulic

is

with

by

a2G

the

in

membrane permeable is

the chemical

water

pure

by

water

similar

Consider

which

in

the

If

chemical

given

osmosis

solution

alone

somewhat

is

membrane

saline

water

shale

the

to

semipermeable shown in Fig from

of

high

salinity

of high

iLi

he

low

of

solution

osmotic pressure

yields

in---

ij

2.40

2.42

Pw where where

the universal

is

of

potential solution

saline

of

of

pressure

partial

the

water

above

phase

Eq

phase

can

be

as molecular

chemical

above

vapor

jt

potential

the

pure

2.40

into

the

wal Eq

can

be

2.39

When there

shale

The

swell the

to

exposed

is

adsorptive

osmotic

lowers

the

and

where

osmosis

the

the

is

2.41

also

cell

in

is

of

pressure the

on

with

equilibrium the

chemical

water

pure

liquid

each

vapor

its

the

at

side

Eq

of

potential

of

of

fewer

solution

above

molecules

saline

Eq

the

2.41

solution

of

physically

fluid

as

to

water

in

liquify

pressure

vapor Note

are

vapot

that

to

2.42

of

would

be

true

the vapor

the chemical

if

potential

semipermeable

make

Thus

apply

it

for

is

/f

by

saline

of

activity

in

potential of water

vapor

the chemical

potential

the

be

ratio

used

ratio

also

/f7

Thus or

of pure

value

Eq

in

nonideal the

water

is

of

2.42

system

p/p

is

called

the

is

the

shale

in

term

the

fugacity

imaginary

to

solution

is

pressure

system To apply

to

component

the

to

pressure

systems

solutions

The

the

P2

the

accurately

nonideal

into

Fig 2.37

adsorptive

Basically

have

to

Similarly

the adsorptive

in

ideal

would

water

to

considered

confining

nonideal

solution

of

chemical

compared

given

to

by

the positions

were altered without

no

in

pressure that

the

adsorption

be

to

The

introduced

component

replaced

above if

eeri

For example Fig 2.36

the

pressure

is

concepts

was

of

chemical

applied

shale

shown

for an

to

the

is

water

to

difference

was derived

be

in the

the

pressure

mem

potential

than

can

considered

causes

water and

for water

platelets

term p0

applied

the pressure

same

vapor

in

such

changing of

the

the

liquids

tend to remain unchanged Water still would move from low salinity to high salinity The from reauirerl to water pressur prevent

through

the

the

would

moving

fluid

for

there

through

dilute

to

vapor

by

analogous

is

chemical

2.41

the

fresh

shales

less

For the arrangement

exceed

Eq

be

of water

is

ii

pressure

the

if

be

term

to

of

vapor pressure

the

Eq

shale

adsorptive

to

move

shale

also can

pressure

equal

pressure

the

Thus

to

liquid

semipermeable

the shale

causing

pressure

the

if

the saline

in

than

that

the

present

and

Pistons

manner

This

the

less

is

water

increase

solution

saline

was

and

water

membrane

semipermeable

2.42

shale

of

of

water

into

the vapor

Eq

fraction there

the

of pure

fugacity

pure

shows

for

tendency

mole

Since

volume

unit

solution

above

the

to

solution

per

the pure

in

than the

pressure

the

in

in

of

tendency

escaping

proportional

is

component

water

the

solution

component that

water

of

pressure

tendency

shale

the

liquid

each

the

adsorption be

Since

expresses

phases For an ideal

2.41

pw

vapor

in

potential

1f

temperature

the

divided

adsorb water

shale to

pressure

the escaping

water

given

of

weight

source

to

for the

tendency

is

branes The attraction

iRTln

Va

volume

molal

evaluated

density

the chemical

to

by substituting

the

the potential

the

is

The

vapor in

water

relative

vapor

obtained

the

the

and

constant

gas

membrane from

tRT1na For water which

not

the

to

2.43 and

enter

confining

drilling

the

the shale

must be equal

The

activity

of

activity

of

the

swell

pressure the

water

shale has

water

in

the

been in

the

formation relieved

mud

mud and

and

in

in

by in

shale

78

APPLIED

DRILLING

ENGINEERING

TABLE 2.18-.-SATURATD SOLUTIONS FOR CAUBRATING ELECTROHYGROMETER Salt

Activity

ZnCI2

0.10

CaCl2

0.30

MgCI2

0.33

CaN032

0.51

NaCI

075

NH42S04

0.80

Pure

water

CO

cc LU

20

SALT Fig

2.38Electrohygronieter

apparatus.3

2.39Water

Fig

activity

chloride

cuttings

measured

is

trohygrometer the

sample

the

probe

present

is

directly

Sodium

to

to be

is

water

2.23

Example

drilled

by

an

of

calcium

mud the

shown

are

The

with

the

water

The

vapor at

at

naturally that

acids

Fatty

are

of

activity

Solution

of

have

the

Using of

tration

to

chloride of

quite

are the

the water

soluble

In

0.69

concentrations

The

the

atoms are especially

it

resulting

NaCI

of

and

mud

unbranched

fats

Fatty

reaction

of

reaction

of

acid

fatty

of is

activity

of shale

sample determined

of the

calcium

by weight

be

to

cut

acids

350x 137.5

lbm/bbl

that

oil in

present

have

acid

soaps

are

acids

with

acid

fatty

mud

structure

this

is

chloride

needed

to

concentration

give

in

the

18

formed

salts

base

with

or

carbon

animal and vegetable by

For example

caustic

the the

sodium

yields

salt

-CFI2

-CONaOH OH

CH3 -CH2

to

equal

12 14 16

with

0.69

fatty

-CH20 acid

-COHOH

soap

ONawater

concen an

ac The

tolbm/bbl

When water oil/water

chain

hydrocarbon

long

portion

0.282

oils

common

fatty

CH3 -CH2

molecule

gives

acids

by

shale

Converting

fatty

for

-CH2

CH3 -CH2

the

addition

The

additive

Fig 2.39

28.2%

magnesium

an emulsifier

salts

in

allowing

wide range

the

sodium

OH

Determine the concentration needed in the water of the phase

chloride

order

or as

organic

and

fats

occurring

be represented

can

used

solutions

Fig 2.39

oil

muds

and

chloride

temperature

calcium is

Weight

instrument

saturated

activity

activity

an

of

of

Emulsifiers

soap frequently

electrohygrometer

in

tivity

is

over

in

acid

conducted

is

calcium the

for various

activity

CaCI2

over

calcium

in

room

by

Table 2.18

inexpensive

relatively

2.5.4

vapor

resistance

amount

mixture

in

and alter

varied

elec

electrical

using

Calcium chloride

activity

elec

the

is vapor pressure to the volume fraction of water

shown

chloride used

generally

an

of

at

Percent

water

vapor

activity

using

probe

always

the

calibrated

is

known

tings

test

pressure

air/water

normally

mud

the

the

to

proportional

the

of

sensitive

Since

The

tested

field

The

the equilibrium

in

placed

being

mospheric

in

is

the

in

238

Fig

trohygrometer

30

CONCENTRATION

tends of

the

soap the

is

be

to

molecule tends introduced

soap

molecule

interfaces

with

of

portion

soluble

in to

to will

the

oil

be

and

soluble

mixture

the

soap

the

ionic

in

water

of

oil

accumulate

at

water-soluble

and the end

DRILLING

FLUIDS

79

Hydrocarbon Ionic

.Group

Hydrocarbon Chain

ci

the water

in

residing in

MONOVALENT

the oil

the

This

emulsion

the

at

and

acid or of

have of

terface

tends

to

of

While

the

of

emulsion

ions

such

Of

also

present

soaps

They

have

oil

soap can

be

used

organic

are

soaps

ring

soaps

of

depends

the

upon

water

degrade

of

given

high

of

suitability

test

and

Also some

oil

by

The

treating

con

primarily

and

ring

from organic

used

silica

water

emulsifier present

emulsifiers

tend

emulsifier

for

to the

However given pilot

oil

tests

if

water-in-oil

placed cover

the

on the

surface

solid

drop The shape the strength

When

Control

Wettability

surface that

of or

the

drop of liquid

is

it may spread to stable may remain as

solid it

drop assumes depends upon of the adhesive forces between molecules

minerals

causing

solids

also

control

The

agents

wetting

One end

soluble

in

the

affinity

for

the

ing

toward

surface

solid

the

oil

soaps to

they

do

usually

available

An

added

not

operations for

the

mud

tends

loose

oil

test

conduct emulsion

be

high

accumulate point the

changes

water

to

prefer

handle

to

special

test

stability

will

has

also

agents However

fast

during

the

to

emulsifiers

as

enough

fast

Several

This

by

wetting

more effective

electrical

narattis

act

serve as

solids

water-wet

emulsion stability which

to

extent

some

wet

mud

similar to

effectively

from being preferentially wet by oil entially The

wettability

phase of the

the oil-soluble end

solids

function

settling

water-in-oil

molecule

This

phase

to

formation of

the

than

oil

by

wet

agglomerate

The molecules

with

interfaces

through

and

phase while the other end

oil

oil/solid

to

problems

the

The

introduced

surfactants

of

the

occupy

measured

tend

the

the

the surface

to cause

to

are

agents

emulsifiers

the

added

are

surface

surface

viscosities

these

the

Thus

and

are

solids

tend

water

preferentially

high

To overcome

emulsion

90

emulsion rather

oil-in-water

an

the

emulsion

in

of

For example silica

silica

solids

to

nonwetting

other one

oil

wets

are

strong equal

simultaneously

the

than

less

water-wet

water

is

by

the

preferentially

natural

Water-wet

wet

with

is

that

has

angle

to wet

under

spread

contact

When

weighting 2.5.5

to

angle

each

tend

water

preferentially

angle

influx of

are not available

and

Fig 2.41

in

wet the solid

preferentially

is

the

brought with

in

defined

is

be completely

to

and

solid

in

Most

contact

are

liquids

oil

tends

contact

at

mud

can be determined using

data

the

electrolytes

temperatures

particular

application

previous

alkalinity

are

than acids

fatty

chains

organic

phase

at

Napthenic

economically

soaps

sap

from coal tar

the

acids

effectiveness

will

position

the

tree

rather

formed

The

the

common

pine

structures

mud

in

two

shown contact

the

said

is

with

both

with

structures

chains

addition

When

while

small If

of

wettability

liquid

given

angle

exhibits

liquid

The

phases

to

tendency

the

rosin

acid-type

produced

than

180

solid

surface

the contact

wetting

water

Rosin

In

of

almost any type Calcium naphthenic

of pine tree sap components tains branched hydrocarbon amines rather

terms

liquids

relative

most

arc the

can be formed economically

hydrocarbon

straight

given

interface

and

liquid solid

Ca2

muds

made from

aromatic

the

contact

influence

oil/water

at

the liquid

in

soaps

of

Fatty

favors

the

course

soaps

common

acid

the

and

surface

oil

used

and

soaps

also are

in

as

molecules

liquid that

in

oil/water

an

at

acid

fatty

emulsifier

oil-soluble

rosin

shown

chains The packing

convex

water

As

emulsion formed

type of

acid

and

oil

stable

soap molecules to form concave oil

oil-in-water

emulsion

water-in-oil

energy

type of

this

molecules

soap form

of

formed from monovalent

tends

an

soap

residing

formation of

two hydrocarbon

type

of

of

acid

fatty

end

chain

CATION

DIVALENT

of

the surface

the

soaps

interface favors

this

type

the oil-soluble

formed from divalent

soaps

MgZ

amounts

and

packing

an oil/water

surface

2.40Orientation

hydrocarbon

single

Fig 2.40

Fig

permits

acid

Fatty

have

ions

CATION

greatly reduces

and

interface

Wq

Oil

Water

Oil

drilling

large or

mud

surfactants

are

wetting is

used

indicates current often

to the

in is

indicate

voltage

at

the

test

ap

due

to

the

80

APPLIED

NONWETTING

WETTING LIQUID

LIQUID

t8O0 SOLID

WATE

CAKE

ROCK

SURFi2tCE

241Contact

Fig

ENGINEERING

DRILLING

angIe

FR

OIL

EFFECTIVE

AREA FORM AT ION PRESSURE 2.44Mechanism

Fig 2.42Relative

Fig

WETTABILITY AGENT

of

decrease

in

need are

for

water-wet

solids

emulsion

stability

in

The

solids

have

when

swirls

also

tend

shaker

adhere

and

screen Viscosity

tends

to

mud

Further acli1jnc

to

the

to

the

mud

in

less

rings

to

or

the

lesser

to

as

well

extent increase

can

nhu1t

Some go

of

into

or

shale

be

nI

water as

lower

the

soaps

viscosity

achieved iu-

by

PIPELAX

OIL 2.45Cracking

the

are the

solution

in

molecular-weight

easily

disperses

2.5.7

Filtration

phase

in

filtrate

suitable water

This

act

only

property

drilling

invasion

excellent

as

Control

mud

oil

for

mud

additives

solids

colloidal molecules

make

to

Highthe

in

present other

solids

wet by oil The amine-treated bentonite in oil muds to form colloid

preferentially

an

oil

control

viscosity

polar

probably

asphalt

by

OiL

hydrocarbons present in asphalt the mud The less soluble com

carried

are

mud cake

of

main

heavy

feeling

emulsified

viscosity

bentonite

ponents

present The cuttings

gummy

viscosity

th mud

also

water-wet

become

will

other

tend

of

dispersion

The

To

also

the

observations

mud

are

each

may have

cost oil

increases solids

solids

gradual

indicates

presence

apparent

to

time

Visual

oil

Fig

water

free

with

Control

increase

total

added

less

reversal

or

the

of an

water-wet to

2.5.6

the

emulsifier

determining

surface

and

shiny

sticking

OIL

2.43WettabFlity

more

useful

pressure

REVERSAL

DIESEL

presence

differential

wettability

WATER

Fig

of

In

filtration t-.-.i

Since the

oil

makes

formations

addition properties .-1-If--

oil

oil

is

the continuous free

phase

is

oil

muds

to

easily

damaged

muds

usually

and

form

especially

rarely

by have

require

..k

DRILLING

FLUIDS

ditional

fluid

polymers

2.5.8

be

barite

is

condition

2.5.9

of

the lower converted

API

the

pH

When

8.5-10.0

large

of

The

in

sulfide

of

range

the

methyl

when

desirable

2.5.10

Control

of

on

economically

devices

Screening control cutting

the

to screen

mesh

The

the

water

maintained

water

Evaporation

addition

emulsion stability when

excessive

It

the

continually

when

and

where

the

outer

as

Eq

Oil

of

application against

called

oil

mud

the

wellbore is

Muds

This

for

muds cake

is

by

problem

differential

is

removal or borehole

formulations are

designed

available

volume

of

oil

The

large

the

of

mud

sufficient

in to

pipe such

as

to

prevent

to

friction

for

shape

fill

the

oil

these

and

following

force

is

U1

the

is

d2

mud

Thus

muds

and

thin

cake

area

effective

area

causes

greater

with

coefficient

high

ef

low density

having

mud

slick

zone

permeable

effective

greater

which

diameter

density

permeable thick

greater

causes

tend

wellbore

mud

high in

sand

causes

factors

high

pressure

or gas

which

cake

low best

are

pressure

Also

sticking

for

pipe

and several drill collar important factor have been developed to decrease the

tendency

grooves

These

include

square

drill

upsets and middle and on each

external

the

reduce frequent

the

The

effective

mud

oil

drill

collars

the

in

2.44

and it

cut

insufficient oil

mud

stuck

pipe

displacing region

is

pipe

shown

thought in

pressure better

Fig 2.45

with

drill collars

collars

All of

with these

for

by cracking

to

upsets designs

contact

the

equalize

characteristics

stuck

freeing

mud

Cracking the mud cake

differential

lubricating

drill

technique

work

to

collars

end

of

area

soaking

held

distinguish

annular

mud cake

the

collars

than with

Fig

pore

differential

an

is

spiral

freeing

involves to

loss

discard

rather

that

area and

configurations

Several

collapse

of

drill

be

to

pressure

sticking

specifically

pipe

the

by unnecessarily

which

the

drillstring

illustrated

technique

caused

by dilution

Pipe

hydrostatic

d2

hJ

sticking

mud cake

sticking

freeing

pressure

from other causes of stuck ting

for

an in-gauge

for

borehole

the

formation thick

of

indicates

depleted

fective

in

have

will

density

Stuck

Freeing

the

by

thickness

the

formation

e.g

In

saturated

the

increase

to

in

2.5.11

of

2.44

low

mud volume

total

is

diameter

diameter

is

be

mud

the

diluting

that

of

h1

which

against

is

col

d2hmc

d1

preventing

mud

2.44

drill

hmc

prevent

decrease

content

the

thickness

the

shown

be

Eq

in

of

the

2.45

be

must

to

is

mud

increasing

fine

as

cannot

replaced

accomplished more economical

is

solids

significant

of

between

for

required

be

becomes

water

This

oil

by

usually

also

cause

increasing

usually

of

be

can

It

expressed

with

formation

A2h1 _h

water

The

viscosity

oil

can

salts

is

contact friction

portion

by

multiplied

permeable

held

are

of of

volume

mud temperature

activity

solution

saline

of

precipitation

decreased

and

salinity

the

if

collars

pressure

the

be

Fig 2.44 pressure

pressure

permeable

is

are very

it

level

will

will

must

see

imbedded

the

inhibitive

stream

muds

oil

When

evaporation

losses

the

changing

of

limits

series

solids

dilution

content

within

high

portion

desired

of

the

used

of contact

area

length

borehole

be

used

of

are

screens

mud

pipe

expensive

means

in

screens

by screening

be

quite

and

limited

area

the

is

and

wellbore

andfis and mud cake

effective

low

the

the effective

is

zp

force

freeing

Content

be discarded

muds

oil

the returning

When

maintained

usual

may

significant

also

is

is

several

Using

possible

since

Since

disintegration

effective

Water cannot

economical

only

muds

oil

and

stuck

differentially

the coefficient

chord

the

anticipated

is

phase would

Dilution

is

of

muds

liquid

mud

mud

the

cm3

the

between

even

The

of

of 2.0

centrifuges

oil

the expensive

The

hydrogen

zones

alkalinity

Solids

and

Hydrocyclones

the pipe

the

oil

pipe

2.44

is

mud cake

drill

value

CO2

or

an

free

to

and

the stuck

opposite

pressure

cases

isolate

hydraulically

by

differential

contain

drilling

bearing

orange

H2S

makes

to

water-

migration

some

In

free

is

the

F1_pAf

that

an

to

ability

when

dioxide

and

corrosion

H2S

annulus

used

is

with

premature

prevent

the

required

formation

level

expected

lime

mud

water

given

lars

The

10 cm3 however

0.5 to

these

used

is

are

force

where

or

will

applying

the pipe

density

equal

tip

tester

alternately until

the

if

the emulsifiers

CO2

as

undissolved

carbon

or

control

the well

mud

of

then

torque

oil

maintain

to

mud

oil

lower the wellbore

aggregate

acceptable

from

ionization

of

to

to

in

oil

formation

and

tension an

mud

the

an oil-wet

to

used

is

an

such

gases

alkalinity

superior

Lime at

use of

and

stuck

is

pipe

is

settle

to

performance

upon

reserve

tendency

needed

is

the best

acids

higher

with

severe

will

particles

muds

oil

formation

form

is

used

is

Also

completely

Control

alkalinity of

200

as

density

strengths

gel

barite

their

Alkalinity

obtain

of

mud

more

is

well

as

also

low

barite

not

greatly increasing

high

API

muds

oil

carbonate

relatively

of

Settling

because

API

to

in

main

the

is

the

compression

is

muds

the

barite

used

Calcium

when

required

where

asphalt

amine-treated

base

API

additive

muds

sometimes

desired

and

The

ControL

control

water-base

is

oxide

used

Density

density

control

loss

manganese

can

lignite

81

cake

allows

Undoubtedly of

the

oil

mud

as

the the also

help 2.5.12 of

and

Oil

diesel

oil

cement

Muds and

for

Lost

bentonite

sometimes

is

Circulation or

used

diesel

to

seal

mixture oil off

bentonite fractured

82

APPLIED

formation

diesel

used

are

oil

as

The

is

the

lbm/bbl

involves

pumping

mud

while

drilistring

pumped down the annulus The diesel slurry and mud come together in the formation and set to consistency is

About

two parts

The

displacements

required

using

two

cementing

slurry

and

the

pump

slurry

one

to

are

the

is

8Oo

the

Answer

volume

API

between the mud properties and the diagnostic tests

the relation

for

test

of

of the

moles per

pH The

of

102

The

Answer The

MgOH2

for

Mg2

of

moles

in

per

saturated

solution

MgOH2

of

Mg

of

hole

API

is

drilled

water

moles per

in

to

mud

the

4000

of

depth

of

loss

the ft

mL

10

is

Construct barrels

would

time

vs

occur

42.4

bbl

in

2.14

Do

you

31.6

of

the 2.6

API

press of

loss

saline

solution

of

solution

liter

g/cm3

0.9982

NaCl

in

terms

normality per

alkalinity

Answer Discuss

One and

8.3

percent

saturated

on

2.16

per of

and

pounds

318

3.00

of

P1

of

solution

of

Na2

CO3

between these and contains

P1 and

.0

of

Compute

per

the

of

barite

API

and

barite

mud Answer

and

low-specific-

of

montmorillonite

Answer

mg/L

that

add

to

of

SAPP

enough

concentration

to

system to

SAPP

mud

The

1000-bbl

his

mud

drilling

calcium

of to

plans

lbm/bbl

25

shown

has

test

blue methylene mud Determine

has

mL

barrel of

per

Ibmbbl

sodium

mud

the calcium

mg/L

30

must

that

be

to the

of

high 2.20

10.7

mud of the

measured

M1

Answer

NaOH 2.21

ibm

mud

11.8

of

Ibm/gal

of

density

CaCl2

brine bbl

to

mixed of

by

water

lbm/gal and

the desirable

Compute raise

the

150

Discuss

Answer

water

Answer

3.00

the theoretical

API

of

Answer 0.068

the

in

85.5

meq/l00

150

adding

alkalinity

of

to

Determine

dition

difference

found

is

7o

pounds

in

mud

of

titration

bbl

CaOl12

in

2.18

phenolphthalein

solution

determine

2.17

2.19

cm3

0.02

volume

the

mud system Answer 116.5 Ibm mud mixed by adding Compute the density of 30 lbm/bbl of clay and 200 lbm of API barite to

of

61.5

mud vol

barite

and

approximate

added

molarity milligrams

of

0.85

is

fraction

Determine the amount

density

mL If

solids

API

100

Na2H2P2O7

NaC1

mud and

of the

fraction

solids

the

freshwater

reduce

and

0.179

engineer

mm

concentration

million

theoretical

and liter

per

the

values 2.9

of

molality

15.7

the

175.5

the

Answer

of

cm3

per

Ca2

of

0.5

16.2

volume

the

solids content

content

and

mud

of

the weight

and

the

Compute

4.15

mL

Answer 5550 and

freshwater

0094

2.15

cm2

90

of

water

water

0.69

area

10

the

10

CaSO4 Answer 218

and

gravity

during

in

API

in

concentration

low-specific-gravity

0.209

is

article

observed

175500 is

an

CaCl2

standard

Answer

hardness

the

in

content

mud Answer

200

test

the well

collected

is

Using express

solids

Compute

in

of

0.02

free

11.4-Ibm/gal

contains

was

water

per barrel

capacity

loss

Find

contains

weight

of

157024 What

in

Answer

of

9.62

in

Answer

of

required

respectively

low-specific-gravity

hours

water

an

cm3

parts

liter

barrel

2.8

API

Hint

loss

water

24

after

having

0.5

of

Compute

zone for

rate

solution

5.55

of be

5.0

require

Compute

conditions

operations

filter

An

drilling

dynamic filtration filtrate volume of 5cm3

spurt

2.7

bbl

the

feel

in

0.25

of the invaded

con

for

total

and

that

drilled is

An

hours

assuming

representative drilling

were

porosity

the

in

the

the

in

concentrations

equivalent

have

loss

hours

24 hours Answer

after

Part

filtration

to 24

hole

the radius

Answer

ft/hr

24

after

inches

Repeat

the

Assume

Compute Part

estimated

hours

in

if

stantaneously

swer

of

plot

was

water

was present

per million

solution

pounds

shale

in

NaCI

hardness

for the

filtrate

fraction

liter for

10-6

8.9

AgNO3

saline

contains

approximate

versenate

solubility

mud

Determine

would

the

parts

Titrations

mud

10.4

15-in

in

4770

liter

3OWo of the lithology Approximately is per meable sandstone and the rest is impermeable

2.5

of

milliliters

total

Express

is

2.13

11.0 Answer

of

The

Mg

of

l0

1.3x

pH

The

K5

for

the

in

the

in

l-mL sample

Determine the following

solubility

Answer

in

and

solution

titration

having

10-12 0.00398

2.51

product

solubility

8.9

2.4

Answer

11.6

solution

5.0

ap

MgCl2

many

versenate

of

the

lime

0.0282

salinity

solution

of

How

OH

and

of

an aqueous

liter in

4.77

and

fluid

drilling

Determine the concentration

pH

of

mL

Cl

1000-mL

2.12

API

the

in

functions

2.3

mL

titrate

to

required

mud

determined

value

Determine

11.6

lbm/bbl

1.154

20

of

cm3

7.7

give

0.7

of

mgIL assuming only NaCI 20000 and 33000

Discuss

in

mud

value

centration

2.2

Answer

M1

on

tests

Alkalinity

2.11

Exercises

2.1

and

P1

of undissolved proximate amount mud The volume fraction of water

mud

for

of

and

stiff

part

each

2.10

is

accomplished

one

trucks

values

lost

being 300

as

high

technique

down

slurry

fluid

drilling

concentrations

commonly the

which

to

Bentonite

ENGINEERING

DRILLING

undesirable

aspects

of

viscosity

the

yield

of

Ibm/bbl

35

apparent

cup

that

clay clay to

viscosity

Fann

in

59.3

of

of

viscometer

ad

requires

bbl water at

of water to

600

15

rpm

bbl/ton is

placed

under

one

cone

to

cp

of

DRILLING

FLUIDS 83

hydrocyclone

unit

unweighted

mud

to

required

and

solids

20

of

qt

being

ejected

available

only

has

fluid

drilling

of centration be

and

remove

water

soda ash

Ca2

the

and

0.84

lbm/bbl

has

solids

minimum

added

to of

The

density

8.8

is

ibm/gal

barite

The density be

The

be

of

desired

must

and

API

222500

add

2.34

bbl

also

must

by dilution

with

solids

volume

the

of

900

volume

of

and

the

amount

should

be

add

mud

257.6

bbl

of

and

discarded

0.01

is

volume

fraction

mud

made

Answer and

increase

Also

that of

derive

mud volume

in

barite

and

mcnt

of

the

water

gal

Ml09ooo

mud

per

100

an

error

an

advantages

the

of

Assume sack

of

amounts

2.39

upon

for

the

adding

water barite

p2p1/28.08p2

in the

reuuire

Answer

2.40

be

will

and these

29.6

gas

is

of

2000 the

thickness

phase

is

of

shale will

being

psi

depleted of

having

0.5

an 3O7o

barrel

per

98.7

oil

lbm/bbl

mud wet

wetting fatty

acid

mud

drilled

The

greater

that

an

of

contain

CaCI2

activity

sand

water

CaC12

emulsifier

balanced hole

fresh

barrel of

oil

by with

contact

water

of

T70F

psi

Answer

lbm/bhl

terms

saline

developed

in

13665

how much

preferentially

pressure

of

of

CaCI2

0.5

mud

oil

required

depleted

has

the

If

volume

by

the

hydration

0.8

of

per

to

the

if

emulsified

pounds

inhibit

to

wcllbore

of

of

Answer

added

be

6.125-in ft

in

across

developed

pressure

activity

containing

the

Compute

soap and

mud from

used

is

2.36

fraction

T70F

agent

to

types of

disadvantages

Fig

in

the adsorptive

mud

Define

and

pressure

weight

having an

mud

bentonite

0.44 0.30 or assume 1000 8500 and 22500 psi

of water

added

be

has

Compute

of

three

muds

oil

Compute the osmotic membrane shown

water

bbl

191

expression

expected

in

the

Answer

solids

Name

prehydrated

Discuss

activity

the

and

muds

muds

mud

of

solids

mud

high-salinity

oil

total

solids

0.0547

water-base

should

unnecessarily

should bbl

2.38

the original

was

$16697

the density

crease

the

for determining

water

an inhibitive

shale

mud

of

determining

much

expressions

barite

in

0.0198

Define

assume

cost of

sulfate

of low-specific-gravity

how

discarded

barium

the value compute in Problem 2.27 If

and

0.0745

the

low-gravity

drilled

the

clay

Determine of

of

why

blue

bentonite

CECm of meq/ of75meq/l00gandaCEC

fraction

Discuss

fresh

32.5o

of

indicates

volume

Answer

of $lO.0O/bbl

cost

is

weight

Methylene

mud

bentonite

an

and chemical

clay

samples

solids

fraction

0.10

2.37

ft

sq

16-Ibm/gal

of

and

water

mud

content

fraction

water

water

viscosity

treatment

zero

of

the

is

added Answer of

2.36

that

lbf/100

the

volume

using

mud

original

bbl

2.35

volume

of

meq/lOO

inhibitive

ibm of barite

mud

tO

2.33

barite

16-lbm/gal

0.030

to

mud

barite that

discarded

of

be

of

volume

of solids

content

15

bbl

The

oil

mLaCEC

API

Ibm/gal

an

100

bbl

20

What

analysis

indicates

of

should

19.05

retort

mud

How

barite

has

mud

ibm/gal

mud

con

800

to

that

of

of

17

be discarded

$0.lO/lbm

Derive

mud

low-specific-gravity

Assuming

the

bbl

from 0.055

409

Discard

API

17.5

casing

plastic

of

point

increasing

upon

drilled

Ibm

3.01

of

weight

freshwater

120F

at

and

be

mud must

limited

old

Discard

to

Compute

that

17.5

and

of

and

water

29o

of

yield

will

92800

using

weight

900

final

cp

titrations

of barite

of

water

of

the

increased

reduced

barite

14-Ibm/gal

is

of

Answer

density

fraction be

volume

and

28000 Ibm

of

Ibm/gal

volume

the

required

must

bbl of

14.5

to

discarded

The

to

constant ibm/mm

Intermediate

content

and

recommended

2.32

barite

the centrifuge

mud

and

Ibm/gal

15

barite

an acceptable mud volume is not limited

800

mud

total

sack

per

API

using

in

set

measured

mud must

121bm/gal

Ibm/gal

required Answer

of

increased

Compute

bbl of

14

final is

32

of

gal/mm

predicted

solids

of

water

water

The

is

has

the

API

2.7

clay

which

and

properties

of

drilled

being

is

been

just

mud

and

7.4

lbm/bbl

10

of barite

well Ibm/gal

the

total

bbl

1000

at

2.31

mud

reduce

to

volume

by

mud

maintain

to

much

229

4o

600

of

gallon

sistency

2.28

required

system

mud

ibin/min

the

The mud

at

of

cen

the

rate

water

downstream

the

6.8

deflocculant

flocculation

increased

One

Answer

Yes

added

be

maintain

to

of

What

ibm/gal

maintained

be

allowable

The density be

should

ions

Answer Discard 544 hbl add 544 bbl of water Name the three common causes of flocculation Also name four types of mud additives used to control

2.27

be

to

must

mud

freshwater

9.5

would

content

volume

2.26

of

density

treatment

2.25

bentonite

and

the

at

while

ibm/gal

bentonite

Compute defiocculant

of

Ibm/gal

9.5

of

ibm/gal

density

is

lbm/bbl

25

deflocculant

8.34

the centrifuge

23.8

of the overflow

density

by

The is

at

centrifuge

with

enters

gal/mm

10

Ibm/mm

1000-hhl unweighted

which

undertlow

contains

would

NaC02

of

NaCI

2.24

the

Mg2

and

of

rate

entering

is

along

gal/mm

water

trifuge

for

that

20

of

dilution

per

present

NaOH 2.23

cone

of

ibm/hr

Would any other undesirable Answer 0.46 lbm/bbl

precipitation be

mass

mud

16.5-Ibm/gal rate

900 ppm and Determine the con

ppm

caustic

to

the

by 47.6

of

2.30

of

400

of

required

still

source

the

J/0.0009IMB

M8/4200

an

were

slurry having

Compute

hour Answer 852 Ibm/hr and 222 The

process

seconds

ejected

Ibm/gal

water

to

Twenty

collect

of

density

used

being

through pressure

than

sand in and

100in

the

the formation

The

mud

coefficient

cake of

84

APPLIED

0.10

of

friction

If

the 4.75-in

stuck

differentially

over

terval

what

collars

free Answer

would

force

be

become

collars

the

entire

in

pull

the

to

required

1129000

sand

viscosity

osmotic

II

ENGINEERING

viscosity

apparent plastic

DRILLING

shale

pressure

adsorption

pressure

lbf density yield

point

References porosity Standard

Drilling

Mud

Drilling

Fluid

Testing

C/ar

MR

1313

Houston

1954

Magcobar

Div.

Baroid

Dresser

In

Superscript

1972 McGraw-Hill

Minerafogr

Flu/d.c

Drilling

Chenevert

ME

Shale

Continuous

Muds

Pet

AIME

Co

Book

New

York

Technologs

Co

Exxon

U.S.A Subscripts

Control

With

Oct

Tech

Oil-

Balanced-Activity

970

l309I3I6

Trans.

agent

API

H.C.H Pet

1969

July

l.C New

Mondshine in

Laboratory

Tech

Shale

Oil-Well

for

SpecilJcations

Trans

883--892

and

Oil

of Borehole

Investigation

AIMF.

Determines

Technique

Drilling

Ca.c

ds

Salinity

drilled

solids

formation

filtrate

API

contaminant

clay

70

1969

Materials

Drilling-Fluid

bentonite

246

Oil-Mud

14

July

barite

Stabili

Spec in

component

1979

Dallas

component

pure

signifies

249

Darlcy

13A

R.P

1974

Houston

Needs

API

1968

Annis

ty

FILlids

Drilling

Manual

Tegineering Houston

RE

Grim

NL

Book

Data

Inc

dustries

City

Ow

Procedure

1974

Dallas

low

Ig

specific

mixture

gravity

mud

Nomenclature

mc

activity

area

mud cake

tnt

agent

treating

rock

C1

C1

correction

cation

is

member

ith

used

factor

account

CEC

of

of

alkaline

methane

for

C2

series

solids

for

etc

ethane

for

used of

loss

exchange

on salt

water

traction

during

to

retorting

sc

solids

in

mud

srn

solids

in

mud

Sp

spurt

loss

si

stuck

pipe

time

titration

capacity

diameter if

depth

Irn

force

cake

titration

volume

titration

volume

per

unit

volume

of

filtrate

per

unit

volume

of

mud

underfiow

volume

fractional

fugacity

coefficient

of

friction free It

mixture

overflow

oil

contaminant concentration

e.g

for

total

energy

urn

mud

ow

water

uB

API

thickness

in

underflow

in

unilcrflow

barite

in

underfiow

water

permeability

KD

solubiiity ion

constant

product

product

constant

of

water

SI

Conversion Factors

Metric

mass methyl moles

orange

bbl

alkalinity

present

number of

revolutions

phenolphthalein pressure pressure

vapor

1.589

cp Cu

per minute

Cu

ft

in

alkalinity

pressure

partial

pressure

differential

rate

lbf/100

at

viscosity

00

E0l E01

cm

00

kg/rn3

Ibm/gal

1.198

264

02

kg/rn3

sq

viscometer

l.0

Conversion

factor

03 E01

Pa kg

kmol/L

dm3

qt

9.463

529

ft

9.290

304

in

6.451

00

cm2

ton

1.0

00

Mg

speed potential

2.54

010

sq

chemical

uc

03

2.853

angle

rotor

412

cm3

lbm/bbl

volume

Fann

E01

1.8

924

mol/L

reading on

706

4.535

sq

volume

dial

1.638

Pas m3

Ibm

temperature

contact

02

026

ft

time

molar

685

rn3

4.788

gas constant solubility

2.831

3.785

gal

E01 E-03

F32 in

flow

873

1.0

is

exact

02

m2

Chapter

Cements

The purposes primary

of

procedures used

the

desirable

ditions

and

cement

at

the

mathematical cement

Cement

the

fluid

hardencd cement

the

pumping

that

close

cement

desired

by

it

favorable

the

set strength

of

placement

technique

well

pressure

cemented

must

may

require

desired after

location

cementing

desired

so

several

casing

before

place

long

location

designed

so

cement

column

that

that

after

the

However enough Also

each

the density results

in

will

be

can

be

each

achieve in

placed

must

placement

cement and

to

cement

the waiting

allow

to

for

cement

the

well

length

sufficient

job of

job an the

period

remain to

must

the be

the unset subsurface

which

to

blend

burning basic

wells

of

in

Joseph

cement

cement

Portland

he

stone

off the coast

of

This

and

by

for

The

name

inventor

the

produced

the

on

use

hardens

its

thought

quarried

the

is

concrete

ideal

is

easily

chosen

because

Aspdin

water

ex

made by

making

environment

was

resembled

solid

in

con

cements

drilling

clay

in

pumped

be

must

be

will

cement

and

used

underwater

an

portland

all

artificial

limestone

can

it

while

subsurface

cement

the

cement

portland

because

of

almost

in

an

of

type

slurry of

of

Isle

England

schematic for

process oxides

of the

temperature

where

sold

Cement

in

the

cement

feel

that

of

rigid

heat

and

especially

The chemical

or

the hydration equations

or

C2S

4CaO

and

Al203

hydration

of

aid

are

C3A

considerable

generates

crystalline

form or

C3

aluminoferrite

The

to

or

3CaO.A1203

C4AF

or

to

strength

Si07

3CaO

2CaO.Si02

Fe2O

in

added

These

silicate

exothermic

is

ultimate

structure

silicate

tetracalcium

in

aging

the grinding

to

hydrate

dicalcium

aluminate

After

is the barrel company 94-Ibm sacks

tricalcium

tricalcium

taken

extreme

resulting

there are four

the clinker that

formation

the

2800F

increase

Ibm or four

376

chemists

compounds in

the

by

contains

is

Fig 3.1 The

in

react

CaSO4.2H20 and

time

to

manufacturing in

cooling

clinker

gypsum

setting

unit

which

Si

2600

the

shown

is

and

kiln

the seasoned

storage

The

cement

cement clinker upon

of

mills

of

representation portland

Ca Al Fe

of

Cement

of Portland

3.1 Composition

retard

formation

The

being

minimizes

and

strings

cement

the

the

application

abnormally high

soon This

with

composition

required

successfully completed and placement technique

strength

pumpable

in

properly

chosen

be

adequate

each

for

encounters

composition

cement

best

that

and

drilled

the

concerned

is

engineer

drilling

fluids

fluid

Consideration

composition

main ingredient

same

of pore

fracture

portland cement

balls

selection

deep

is

the

to

taminating

posed The

movement

the

formation

is

and

characteristics

The

given

hydraulic

Thus

becomes

slurry

an

slurry

cement

location

exhibits

into

fluid

and

powdered

cement

solid

rigid

of

well

and

reacted

causing

be

readily the

outside

space

movement

mixing

the

not

is

to

prevent

formations

surface

or

but

chapter

casing

the

by

to

of the

operation

drilling

the

of

well

displacement

this

the

The

well

behavior

through the annular

portion

the

at

in

place

the

in

con

well to

control

to

pressure

in

the

fractured

the

in

water

in

stop

abandoned placed

used

Chap

in

used

of

or

various

location

support

casing

vugular

under

discussed

not

is

is

and

movement

for meeting these additives used to obtain

techniques

desired

in detail

protect

cement slurry and

modeling of the flow

slurry

presented

test

properties

properties the

the

present the

the

if

common

the

to

cementing

determine

suitable

objectives

are

chapter

of

to

cement have

set

this

objectives

reaction

is

quantity

of

C3A

representing

the hydration

86

APPLIED

These of

are valid

equations

M203

to

C3A

Calculate

standard

long

is

the percentages

Oxide

CaO

Silica

Si02

Manufacture

3.1

Sulfur

of

the

cement compounds when

water

are

they

mixed

are

with

Solution

Eqs

using

23CaO.5i026H20

1.9 1.8

0.7

ratio

through

5.8/2.82.07

is

3.4

Thus

yields

-3

3H203CaOH2

3CaO2SiO2

2.8

SO3

A/F

3.1

Percent

5.8

or

loss

The

follows

as

of

22.2

orA

Fe2 03

trioxide

Ignition

C2

analysis

65.6

MgO

Magnesia

C3

Weight

or

Ferric oxide

cement

of Portland

of

oxide

or

Alumina Al203

Hg

ratio

0.64

than

cement

portland

Lime

ENGINEERING

the weight

as

greater

from the following

C4AF

and

as

Fe2 03 present

3.1

Example

DRILLING

C3

6.725.8

7.622.2

4.0765.6

1.432.82.85l.8

22CaO.Si024H20

-3

slow3CaO 2SiO2

3H2

50.16% Ca01-12

C2S

4CaOA1203 Fe203 10H202CaOH2 slow6CaOAl203 Fe203 12H20

12H20CaOH2

3CaOA1203

main

cementing

products

is

C4AF 3.042.8

8.51%

size

surface all

gel

The

and

thus

attractive

and

crystals

Excess

water

makes

the

and

called

area

them

bind

Strong

together

reduces

cement

fine

adsorb on

to

gel

hydrated

the

reaction is

extremely

surface

causes

not

is

the

which

an

large

particles

that

and

strength

has

gel

forces

in

3H20

3Ca02SiO2

tobermorite particle

compound

cement

porous

and

contributor

to

more

permeable

C3S strength

C2S

especially very

the long term

the

first

before

the

slowly

and

C3A

controls

portion

of the

first

28

of

days

contributes

hydrates

the

physical

chemical

generally

is

the rapid

cement

sulfates

containing

on

The

major

during

strength

grinding

water

effects

the

API1

very

to

rapidly and

also

in

terms

is

C3A

of

attacked

readily

C4AF

has

only

of

the

cement

properties of

composition

given

hydration

of

portland

oxide

minor

analysis

The

drilling

in

the

rheological

characteristics

cent

of

for

equations

the oxides

calculating

compounds

the weight

from the weight

and tensile

fluid

However

per

understand the nature terpret

it

of these

cement specifications

of

and

deter

tur

the

cement of

testing

done

for the

imperative

is

for

and

routine

not

is

set

testing

and compressive

autoclave

cement

testing

per

of the

strength

the fineness

slurry normally

rate

cement

an

for determining

drilling

con

thickening

bidimeter

per

present

the

the

of

rate

slurry

the

the permeability

for determining of

the

molds

test

includes

tests

slurry

specimen

The

for determining

the

cement

crystalline

the

are

always

filtration

cement mining the soundness of

Unlike

the

of

cement machines

of

for determining

meameter

the

determining

well

given

the slurry density

viscometer

properties

for

help

cement

tests

perform the API

to

rotational

sistometer

the

almost

standard

aJulter press for determining

amounts of the four

of

for

testing

to

given

for determining

balance

the slurry

computed

cent

suitable

these

devised

if

specifications

of

needed

mud

ent are

the following

be

will

terms

procedure for were

tests

determine

Cement

conditions stated

These

personnel

composition

relative

crystalline compounds pres from the oxide analysis API uses

recommended

cements

strength

cement

Testing

presents

drilling

curing

mainly

most of the heat of hydration observed during few days The gypsum added to the clinker

The C3 by

be

to

thought

hydrates

produces

Cement

3.2

equipment

is

1.692.8

10.64%

3CaOA1203 10H20Ca504.2H20 3CaOA1203 CaSO4 12H20 The

0.75450.16

C3A 2.655.8

-3

CaOH2 l2HO

fast3CaQ.Al203

2.8722.2

25.89%

at

drilling tests

if

reported

the

the site

rig

engineer

he

to

is

test

to

in

results

properly

C3S 4.07C

7.6S

6.72A 1.43F2.85S03 3.1

C2S2.87S0.754C35

C3A2.65A C4AF3.04F

3.2

The

same drilling

1.69

3.3

34

mud

viscometer

balance used

equipment fluids

for

filter

cement

described

However

to

remove

The

in

when

of cement slurries entrained difficult

press

and

rotational

testing are basically the

air

Chap

for

testing

measuring the density in

the

pressurized

sample

mud

is

more

balance

CEMENTS 87

TORQUE SPRING

CONTACT

PtN

ROTATI NB SLURRY CUP

Of

Courtesy

Halliburton

SAMPLE

TUBULAR

HEATER

REVEL

Services

Pressurized

3.2

Fig

CEMENT

PINION

mud balance BEVEL

shown

3.2

Fig

in

of the entrained

Cement

3.2.1

shown

are

in

150

at

rpm

defined the

in

terms

of

the

is

sluriy

relation

given

enclosed

withstanding well

in

exerted

torque

The

slurry

consistency

The

test

the

container

chamber

slurry

ce

consists

all

of

and

testing

slurry

assembly

capable

cylindrical

in

apparatus

pressures encountered

The

during

cement

slurry

The

paddle

chamber

and

operations

ing

effect

pressurized used

cylindrical

stationary

pressure

temperatures

33

Fig

rotating

with

equipped

The

consistometers

in

of

essentially

minimize the

to

Consistometer

atmospheric-pressure

ment

be used

can

air

cement is

rotated is

consistency

on

the

between

paddle

by and

torque

by

T78.2 3.5

20.02

where

Tthe

slurry

consistency

on

torque

The thickening

by time value

is

to

felt

ing

during

time

for

of

the

schedules 31

present

to

designed

for

simulate

in

Table

the

to

making

simulate certain

rheological dent shear

since rate

of casing

at

the

various

the

publishes

recom

viseometer

available

conditions

average

At

followed

for

also

encountered

the sample

ft

is

on of

consistometer

history the

of

and

sluriy

slurry

cement

cement thickens

temperature

and

for

with

frequently

pumping

For

slurries

is

before

example

are

time

time The

pressure before

the

depen

history

of

measuring

is

water

of

of

that the

at is

will

test

the

minutes

the

at

of

80F that this

The free sample

will

from

content the

and

amount of

result

water of is

tests stirred

atmospheric the

period

consistency

water

and is

amount of mixing in

these

In

slurry

content

cement end

the

schedule

consistometer

consistometer

water

of

result

250-mL

of

in the

first

20

30

The

maximum minimum nor

the

content

per sack

content

pouring

determine water

of

terms

in

consistometer

The minimum

of

cement

the

rotational

using

properties

specified

placed

water

sistency

end

to

free

period

mixing

be

using

mal

10000

theological can

used

is

pressure

given tests

cement

Schedule

of

depth

high

pressure consistometer

during

operations

of

atmospheric-

API

3.1

properties the

meaningful

are

schematic

consistometer

thicken

consistometer

schedules

The atmospheric-pressure used

the

consistometer

pressure

schedule

the

concerning

and

with

cementing

during the cementing

shown

use

published various

simulating

with

Cement

3.3

of

limit

upper

pressure

data

operations

the

This Fig

the

he

to

field

as

100

pressures encountered

cementing

mended

of

of

designated

defined

is

slurry

and

results

test

and

units

must be given

test

reviews

temperatures

the

the

g-cm and

consistency

temperature

the

periodically

types

time of

representative

The

pumpability followed

be

in

paddle

consistency

reach

to

required

the

API

in

con

in

The normal per sack 11

at

of the

determined

consistometer

into

by

88

APPLIED

TABLE

EXAMPLE

3.1

Schedule

CONSISTOMETER

specification

Surface

temperature

Surface

pressure

Mud

FC

kg/LI

Ibm/cu

1214

ft

89.8

kglcm3/m

psi/Mft

Bottomhole

temperature

Bottomhole

pressure

Time

to

reach

623 0.144 144

62

kg/cm2

psi

36

Pressure

Time

psi

Temperature

kg/cm2

1250

13 12 14 16 18

20 22 24 26 28 30 32 34 36 temperatse

134

87

31

2300 2600 3000 3300 3700 4000 4400 4700 5100 5400 5700 6100 6400 6800 7100 7480

162

91

33

183

94

34

211

98

37

mL

operate

of only

100

at

101

38

260

105

41

281

108

42

309

112

44

330

116

47

359

119

48

380

123

51

401

126

52

429

130

54

451

133

56

478

137

58

499

140

60

be

that

and

own

to

the

from

tea/er

completion

tent

Fig

amount

the

is

that

free

over

defined

will

consistonieter

pressure

of

slurry

content

of cement

atmospheric

62 of

respectively

noting

per sack

with

constant

separates

water

properties

144

held

kg/cm2

psi0

The max

conjunction

rheological

should

cylinder

free

232

526

pressure

amount of water

2.5

in

29

1900

and

2-hour period

27

84

water

supematant

80

113

graduated

glass

88

1600

sod

2Fn id

within

7480526

bottom minutes

minutes

the

27

80

125088

density

Ibm/gal

Final

cement

test

kg/cm

psi

ENGINFFRING

SCHEDULE1

3050 mcasing

10000.ft

DRILLING

as

result

the

determination

and

water

of

the

form of Darcys

appropriate

assembly

150

rpm

cement

520

is

to

g-crn

hold

slurry

an

where

the paddle

md

mL/s

rate

cp

viscosity

cm

sample length

consistometer

Compute

using

law

3.6

content

required

in

stationary at

rotating

torque

the

AZp

water

The

of

qpL

flow

3.2

computed

is

kl4700---

to

permeability

Example

the length

across

then

permeability

used

frequently

differential

pressure

The

permeameter

in

designed

is

given

core

Cement

3.4

sample cross-sectional

the slurry

pressure differential

cm2

area

and

psi

Consistency

The

time

curing

sample

usually

and

temperature

are

pressure

with

reported

the

of

the

cement

per

meability

T-78.2

52078.2

20.02

20.02

3.3

Example

22

consistency

flow

only

permeameter

Perineameter used

recommended permeability

mined

by

by of

in

the

API set

is

schematic

cement shown

cement

measuring the flow

core rate

of

permeability in to

Fig water

3.4 is

the test

4O/o

0.00345

differential

the

mL/s

0.0345

20

of

differential

pressure

Cement

of

rate

silica

cured

mL/s

of

of

when

placed

similar to

flow

Compute

water

under

con

core

manner

under

the

length

allows

second

psi

in

water

200 psi

having

cm

of 2.865

diameter

Linits

taining

3.22

cement core

Class

cm and

of 2.54

allows

pressure

permeability

of

two cement samples

The deter

through the core

at

Solution defined

Using by

lcq

Darcys 3.6 gives

law

for

linear

flow of

liquids

as

89

CEMENTS

TABLE 3.2 WELL SIMULATION

SCHEDULES

TEST

TerrtperatureFtC

_______________________ D8Pth

Schedule Humber

tt

10

1000

310

2S

2004

610

35

4000

4S

10008

113

02

20

83

03

38 41 47 52 56 02 67 73 82 84

94

3500

211

106

3000

21

116

211

126

2440

3000

3050

3506

211

133

143

75

12008

3660

3.000

211

8S

14000

4270

3000

211

153

OS

16000

4880

3.000

211

164

lOS

18000

5490

3000

211

179

115

20008

6100

3000

211

184

The at

lest

the

Schedule

tIle

speormons

as

following

or

limlIs

the

3S

Suheduies

118

through

shall

13

Cal

temperature

First

110

124

oo

138

64

154

78 87

179

85

29

hO

30

97

38 45 53 61 72 50

98

37 46

13 128

142 161

and

of Heat

Application

115 131

47

555

120

139

04

158

75 59

167

31 38 49 59

87

55

Pressure

103 125

147 168

82 97

180

31 39 52 64 5t 99

89

70

408

3.30

2.30

192

155

33 41 54 68

179

82

205

89

91

105 130

34 42 07 72 88

93

109 135

152

140

43 60

170

77

110

200

93

103

230

ItO 127

180 218

35

95

220

104

233

1112

206

119

260

103

223

108

236

113

250

121

263

1128

277

135

290

143

206

97

248

125

254

123

250

127

272

133

284

140

205

147

308

320

160

227

tOO

277

135

302

150

307

153

315

157

324

162

333

153 172

350

177

235

113

288

142

340

181

356

380

193

169

in

piaood of

slOG

the

ps

1600

o200

psi

3003

0500

451

99

210

the

vessel

pressure

188 216

and

93

171

344

206

173

355

177

351

167

341

186

373

069

maintained

period

curing

kgote2

56

kglcnr2

14

113

kg/our2

o35

211

2C

3F

loarriluroed

ire

173

duration

800

2S

98

55

148

29 38 43 51 55 68 92

84

42 49

131

from

130

34

120

Time

Clapsed

28

108

are

tS

Schedule

First

as soon

applied

within

pressure

3iueo

be

shell

pressure

si

oo

50

1600

1830

000

65

800

1220

6000

OS

kcm

p09

tr1S

SPECIMENS

STRENGTH

FOR CURING

lire

ihrouahoui

rereairrder

at

the

carol0

period

for

2.54

0.03451.0

lOmd

14700

contact

2.8652 20

3.3

is

observed

permeability

the addition

after

of

silica

by

given

has

0003451.0

2.8652

md

0.1

intended

defined

Table

in

are

standard tensile

the

ASTM

used

are

of

force

required

the

by

for

average

cementing

basis

the

in

3.2

The

12

any

given

soundness

strength of

or contraction

expansion

under

autoclave

hours

for

The fineness of

the

cement

of

cement is

particle

surface

cement

is

expressed

particles

turbidimeter

manufacture

cement

the

frequently

after at

curing

pressure

changes

in

of

an

the

casing

or

per

from

finer

during

terms

in

greater

of

gram the in

the

measure of the

is

rate

kerosene

cement

the

of

is

surface

size

grinding The

calculated of

be

of

percent

The time

total

The

cement settlement

area

and

the

well

specifications

rate

displacement 7.0-in.-OD

3.5

Fig

in

time

after

water percent

each

weight

is

be

The

representative to

has

cement shown

relation

and

ft/mm

cu

ft/mm

cross-sectional

assumed For

required

cementing

the various

mixing of 50 cu

having

casing

in to

the

increase

the

and

depth for

cement mixing time of 20

sq

reduce

weight

for

be

will

to

that

wto

0.2

content

these of

mix

practice various

displace

of of cement cement volumes used in are the Also plotted depth recommended minimum thickening the determining

volumes

been

field

as

of

which

conditions

current

and

Also area

plotted

function

time

of

Wagner

in

ground

added

for each

of

Table

bentonite

Wyoming is

the

type in

As

class

specifies

wto

between

shown

is

felt

each

cement slurry to

API

provide

specify

normal water

cement

the

5.3

added

in

assumes

are

the

as

samples

shown

ratios

of

classes

barium sulfate added

relation

used

with

section

to

to

necessary

barium sulfate

increased

bentonite

33.57 to

or

density

slurry

of

295

dimensions

to

added

is

slurry density

classes linear

to

the

next

and

physical

To

specifications

water-content

of

the

cement

to

mixed

be

to

The

types

and

3.4

is

it

water

sometimes

HSR

various

of the various

API

to

the

sulfate-resistant

3.5 apply

testing

water

in

eight

Class

Table 3.5

in

are referred

API

discussed

tensile

the percent

poorly

achieved

suspended

The

Thus

cement

the

area

calculated

bond

to

particle

fineness

fineness

the

is

steam that

the

is

reported

observed

saturated

upon curing may tend form cracks

is

cement

the

Fable

cement

the

than

time

curing

in

in

of

3.6 often

Table

Table

according

These

the

requirements in

amount

or

for

are given

uniformity

three

The to

sulfate-resistant

in

given

given

prepared

content

schedules

test

of

greater

on

types of

are given

strength

times

are

periodically

The

1982

Test

based

arc

updated

data

Jan

corn

specimens

different

in

are

the

sample

schedules

field in

the compressive

The

psig

current

compressive

at

strength

These

and

RP lOB

about

usually

only

of

the test

encountered

operations

published

of

com

The is

also

cement divided

the

strength

API

by

conditions

cement

crush

area

curing

recommended

cements

set

to

cross-sectional

schedules

on

the

115

Class

designated

high

physical

cement

in

published

and

151

The

The

strength

fineness

drilling

strength

pressional

compressive

109

API

by

pressive

190

Tests

Fineness

and

soundness

strength

latest

cement

for

tests

and

and

wells

in

for use

classes are of the various meanings 3.3 The three types specified are

and

requirements

Soundness

Strength

are

requirement

classes

Cements

moderate

MSR

chemical

3.2.3

the

is

rapid

classes

standard

eight

ordinary

200

more

the

of Drilling

cement

types of specified

The

2.54

defined

standard classes

14700

and

water

process

Standardization

API The

with

hydration

during

available

ConstructiOn

3.3.1

The is

majority

used

in

of

Cement

Industry the

cement

construction

produced

with

only

Designations in

about

this

country

5ko

being

go

APPLIED

TABLE 3.3STANDARD

CEMENT

CLASSES DESIGNATED

Class

Intended

Available 150

use

for

when

depth

only

environmcnt

from

surface

special

6000-ft

tc

are

properties

ordinary

in

characteristics

slurry

BY API1

type

1830-ni

net

similar

ASTM

to

At

cement

the be

can

Type

Intended

for

from

use

when

deplh

sulfate-resistance similar

Class

for

150

both

in

Type

and

ll

almost

to

Available

into

from

surface

conditions

in

and

Ill

high

and moderate

ordinary

Type

6000-fl

to

require

high

Intended

use

for

1830-

high

moderately Available

early

additives

strength

ASTM

to

similar

resistant

Class

use

for

under

and

temperatures

moderate

and

Intended

depth

from

and

moderate

high

and

Intended

used range

of

tions

other be

from

retarders

well

and

temperatures

depths

than

calcium

and

blended

or

both

fit

be cleared

basis

cement

ttie

cement

both dur

clinker Available

sulfate-resistant

of

When

Intended

used

wide

ditions

depth

of

well

is

of

weight

than

manufacture moderate

sulfate

blended

Class

of

or

with

additive

the weight

of

computed

is

the mixture

in

is

cement

of

as

expressed

intended

the

the additive

put the

by multiplying

by the weight

percent

of liquid additives given by 100% The concentration sometimes is expressed of cement as gallons per sack sack of cement contains 94 lbm unless the cement of

cement and some

of

the

slurry

ratio

in

gallons

cement

water

as

blend content

is

can

ad

No

both

or

often

reference

the

is

as

weight

other

sometimes per sack

used

is

water

for

The term

percent

content

expressed sometimes

mix

percent

as

expressed

material

is

and

cover

water the

cement

sulfate-resistant

to

and to

and temperatures

calcium or

surface

retarders

that

weight

percent

just

that

usually

cement

expressed

and

of an

or

percent

unit

is

to

industry

most of the confu

out

up by pointing

mixtures

cement mixture

the

product

manufactured

as

depths

interground

from

thus

classifications

in

types

cement

basic

accelerators

other

be

ing in

with

range

shall

as

2440-m

8000-ft be

use

for

and

cement additives

However

concentration

the

The water Class

of

the student

to

sion can

be

addi

or

the

Some

job

purpose of

one

they receive

cement

by the petroleum

used

the concentration

meaning

wide

No

because

one

ad

special

two categories

first

to

can

or

additives

and The

every

more than

nomenclature

express

in

water

or

more

control lost

control

additives

than

subdivided

above

The

weight

cover

to

with

Class

of

high

sulfate

high

surface

manufactured

and

interground

moderate

cement

as

under

types

accelerators

manufacture

ing

sulfate-resistant

depth

serve

would

3050-to

in

use

additives

filtration

almost

be

can

control

problems

on

additives

confusing

Available

pressures

both

extremely

The

extremely

to

types

of

be meet

to

density

most important

the

consideration

tiigli

in

16.000-ft

conditions

basic

of

Available

10000-to

as

2400-m

with

shall

use

for

3050-

14000-fl

sulfate-resistant

under

temperatures

to

conditions

pressures

tugh

use

for

4880-rn

8000-ft

sulfate-

high

are perhaps

shown

10000-

from

depth

4270-rn

Class

and

types

Intended

Class

moderate

of

time

control unusual

for

depth

pressures

available

additives

viscosity

conditions

and

become

has

groups

setting

circulation

types

10000-ft

to

under

temperatures

both

in

6000-

depth

additives

functional

1830-rn

sulfate-resistant

from

3050-rn

to

cement

site

can

additives

economically

specifications Class

cement these

ditives

Class

job

or

well

popular

sulfate-

high

any

modified

of

the

the job

at

and of

are

blended

dry

to

it

Classes

high

moderate

be

can

the usc

through

easily

additives

water

1830-ni

The

use

when

150

6000-ft

moderate

types

Intended

depth

to

reouire

Available

ASTM

to

resistant

surface

conditions

mixing

cement

the

present

either

subsurface

any

these

transporting

the

in

of

all

that

before

dispersed

modificd

Class

powders

free-flowing with

required

almost

for

Essentially

ENGINEERING

DRILLING

weight

percent

Thus

dur

clinker

Available

only

typo

water

mix

percent

weight

100 cement weight

The used

in

for thc

of

gas

construction in

working

construction

in

foreign

designations

3.7

Table

some

Note

cases

ASTM for

Five

basic

is

similar called Class

3.4

modified to

API

high

various

moderate

cement

called

similar

Typo

Type

similar

to

2.2 of

to

is

III

Chap

dissolved

minor of

properties ideal

The

yield

not be point

components

of

of

the

with

the

yield

confused fluid

as

can

mixing

components

needed

discussed

in

cement yield in

of

have

Physical to

perform 3.8

Table

per sack

be are

Many

and

volume

are given

is

Sec

in

of the cement

slurry obtained

the

called

is

the

slurry

calculations of

outlined

low concentration

on

cement

mixing

of

phase in

effects

volume

should

water

are used

slurry mixture

Ideal

fluids

more

or

the

procedure

drilling

one

the

in

components

used

for

unless

of

same

using the

assumed

very

volume

theoretical

calculated

the

II

resistance

ASTM is

the

and

Type

sulfate

cement

Class

early strength

of

cement

This

term

clay or the

Chap

API

cement

Cement

Today

for

types

in

cements are

five

ASTM

normal ordinary or common cement is API Class cement ASTN4 Likewise which

true

classifications

these

be

marketed

espccially

is

commonly

used

that

may

it

normally This

countries

are

The

industry

international

in

industry

cements

portland

shown

wells

cement products

to usc

necessary

when

and

oil

Example Additives

more than

API

classes

40

chemical of

cement

cement additives to

arc used

provide

with

acceptable

3.4

It

is

containing

desired

3o

to

mix

bentonite

slurry

using

of the

Class

normal

as API Table mixing water specified by 3.6 Determine the weight of hentonile and volume of

CEMENTS

91

TABLE 3.4CHEMICAL

REQUIREMENTS

OF API CEMENT TYPES1 Cement

Class

Type

Ordinary

DEF

Magnesium Sulfur Loss

Modemte

mum

max

0/g

0/u

/o

maximum

residue

Tncalcium

maximum

maximunt

ignition

lnsolub

0/

5.00

5.00

3.50

450

3.00

3.00

0.75

3CaO -Al203

aluminate

maximum

Type MSR MgO maximum SOs maximum

0.75

/o

15.00

Sulfate-Resistant oxide

Magnesium Sulfur Loss

SO3

tnoxide on

MgO

oxide

trioxide

on

maxImum maximum

ignition

Insoluble

residue

Tricalcium

u/u

07u

3CaO

silicate

o/u

s/u

SiO

5.00

5.00

5.00

5.00

5.00

3.00

3.50

2.50

2.50

2.50

3.00

3.00

3.00

3.00

3.00

0.75

0.75

0.75

0.75

0.75

o/u

maximum maximum Tricalciuni

aluminate

Total

content

alkali

Na20 Htgh

3CaO-A1203 maximum maximum

equivalent

Sulfate-Resistant

Loss

Insoluble

max

maximum maximum

residue

Tricalcium

s/u

0/

5.00

5.00

3.50

2.50

2.50

3.00

300

300

3.00

0.75

0.75

0.75

0.75

5.00

48.00

3CaOA1203 maximum aluminoterrite 4CaOAl203 Fe203 the tricalciurn alum nate 3CaOAI203

twice

3.00

o/u

alkali

Na20

3.00

24.00

content

as

expressed

maximum

equivalent

sodium

24.00

jndness

Pree

autoclave

expurs

specif

wuer

xi

surface

maximum

content

mum

sax

minimum mL

3.00

24.00

24.00

0/e3

0.60

REQUIREMENTS

OF API CEMENT TYPES1 Cement

Fineness

3.00

oxide

TABLE 35PHYSICAL

So

0.60

0/u

aluminate

maximum Total

0.60

65.00

Tetracalcium plus

8.00

3.00

maximum Tricatcium

8.00

5.00

urn

iii

48.00

8.00

oxide

/b

3CaOSi02

silicate

8.00

HSR

Type

ignition

8.00

58.00

48.00

Wo

MgO maximum SO3 maximum 0/

trioxide

on

sodium

oxide

Magnesium Sulfur

as

expressed

/o

58.00

iv

080

80

Cm2/g

1500

080

1600

Case

080

080

080

080

080

2.200

25

35

Scheduh Curing

Number TubS

Comoressive

emperature

CF

RP100

Strength

Cunng Pressure

CC

psi

Minimum

kg/cm

Compressive

Strength

psi

kg/cm2

rest 100 8.Hour

tS

Curing

35

3S

me

38 35

tOO

OS

290

9S

330

800

so

230

8S

Atmos

110 143

14

20C

300

21/

56

3000

211

3000

211

2.000

211

000

18

250

1.500

SLID

106

1500

/35/

500

/35

21

35

50/3

Schedule

Number

csmpressixe

ulure

RP1GB

Tes 24

Temper

Table

Strength

Cu

Curing

ins

Pressure

13

psi

kg/cm

mum

Mm

Compressive

Strength

psi

Hour tOO

cur

ng

me

Atmos

38

t0

2000

211

6S

230

ltD

3.000

211

OS

290

143

3.000

211

9S

320

16

7/

15

Simulated

7.2

000

1000

Mn mum

000

2440

0.000

3050

4.000

0270

Iii

ken

ton Mdximr

ye

250

mL me

ng

rvrb

are

you

csesiSicn

Greeng

ILl

me

iecyu

vinier

90

thickening

Time

/minutes

90

too

vohei is

35

01

per

enr

rerorred

herb

Iv

154 90

uSpM

in

nrL

irs

of

poises is

210

Fineneuu

Peer/and

ceo-or

bi

is

ru

mir

einr450nr

ADTM

Joys

is

values

us

00

too

30 ursrrihed

based

remer

9_s

90

90

sIi

ii

90

90

313

uppururi

vorceomuge

remenis

90

too

4880

mere

vclvme coil

3D

1830

0.000

lOused

/70/

09

Ut

310

6000

Wagner

/70

/141/

mg

Per

/m

It

Tct

by

1.000

2000

me

ned

70

000

141/

1030

Stir

Depth

5\i0//

RP100

Demerm

70

000

2000

ivliriule

Number Table

kg/cm2

141/

ency

Test Schedule

Thick

2.000

Consist

lion

eruture

106

500

Maximum

ms/u-

Temp

127

211

Wet

Pressure

1800

us

rrirules

he

rolul

cement

ng

times

bserved

ii

Inc

Gus

C5

survey

plus

25

safer0

Cr

yr

5rnrduryrs

Purl

/10k

APPLIED

92

3.6NORMAL WATER CONTENT RECOMMENDED BY API

TABLE

ENGINEERING

DRILLING

OF

CEMENT

Water Class

API

by

Water

1u of

It/eight

An

gal

clussIsU

Cement

Cement and

and

sack

per

sack

per

46

5.19

56

6.32

19.6 23.9

38

429

162

44

4.97

18.8

tentativel

As

recommended

Note

The

water

be

water

be

added

ter

added

is

manufacturer

bentonite

or

tt

Ctass

which

toO

addition Increased

ampte

the

by

each

sturry

bentonlte

In

att

APt

an

require

amount

classes

increase

cement

of

ratio

ES

046

0/

waer/cement

in

_____

TI

ot

3/s

that

purposes

water/cement

basing

witt

esting

the

that

requires or

bentonite

tO/s

cement 34/a

cement

to

recommeoded

IS

to

TOES

ratio

619 CEnrurs

Note

rhe

addition

be

increased

wales

ot

water

be

normat

kg/L

ment

or

ratio

by

halIte

to

ban/c

03

rotio

addition

cemrrrrt

generatty

recommended

is

tt

each

water/cement

2.2

tt

added

of

6005

of

For

036

at

and

for

resting

weIghted

barite

mitt

an

require

2/o

1346

increase

43

haorng

storry

t6 tbn/gat

Is

amount

that

purposes

cement

eoampte

the

fiat

requires

tbm/cu

water/ce

in

35 fl1

50

to

Our

PM

iN

Ire

iS/fl

sIlil

55ff

water

mixed

be

to

Also

compute

the

with

one

94-ibm sack

mix

percent

and

yield

of

2Osli

cement 20

of

density

40

50

50

the

100

TIM

ITO

140

ISO

200

ISO

MINUTES

slurry

sack

of

0.0394 The

2.82

to

be

blended

for Class

5.3

bentonite

is

mix

the percent

for

10.7

gal/sack

748

gal/cu

The

is

6I.9o

35.3

of the slurry

yield

1.43

46o

must be added

water

Thus

cement

the

46

API cement

of

94

cu

ft/sack

ft

of

density

the slurry

volume

total

is

2.82

the

is

total

volume

water

cement 0.6

is

given

1994

to

added

be

The 3.14

8.336.98

of

sack

per

of

Class

3.4.1

gal

ibm/gal

the slurry

is

cement

of

bentonite

3.8

Table

respectively given

and

The

are

volume

ibm

lbm

2.82

fracture

cases

the density

148.33lbm/gal 6.98

gal/sack

2.658.33lbm/gal 10.7

be

gal/sack

TABLE 3.7BASIC ASTM Type

International Designation

API Class

ASTM

too great will

it

of

cement with

be

the

the

to

Typical

C3S

C2S

53

24

modified

47

32

high

58

16

26

54

Composition

C3A

C4AF

normal

CC

ordinary

common

or

III

RHC

IV

LHC

early

12

strength

SRC

low

heat

sulfate-

resisting

yet

12

the

not

so

cement higherthe

into

high

formations

cement

lower

the

prevent

flowing

In

slurry obtained

normal amount

CEMENT TYPES2

Common Name

to

for the formation desirable

of

density

operations the weaker

of

cause

mixing

enough from

high

cementing

during

by

be

formations

pressured

The

Control

Density

slurry must

gravities

2.65

94

Ibm/gal

10.7

ibm/sack

specific

and

by

by

6.98 8.33

divided

mass

or

14.48

The

relationship

classes.1

with

The

content

time

cementing

definition

in

is

Ibm

3.6 However percent

bentonite

cement

normal water

Table each

of

weight

Class

and

depth

used

Solution The one

Well

3.5

Fig

fracture the

of

water

strength slurry

well as

to

most by will

and

density

CEMENTS

93

Reducing overall reduced adding

the

cost by

the

also

cement

using

are available

lower

LitewateTM

2.8

is

the

The

is

reduce

density ratio

both

or

solids

having

Trinity

gravity of

reduce

to

Slurry

water/cement

higher

cements

tends

slurry

low-specific-gravity

nonstandard

specific

cement density of

hydrocarbons

which

has

it

popular low-density

very

When

zolan

gravity

may

ficiently

cement

column

TABLE

3.8PHYSICAL

PROPERTIES

be

Ibm/cu

ft

front

cement

the

of

this

slurry

MATERIALS5

3.6a Absolute

Gal

gal/Ibm

Volume cu

ft/Ibm

API cements

94

3.14

94

0.0382

0.0051

Ciment

Fondu

90

3.23

97

0.0371

0.0050

cement

90

3.20

96

0.0375

0.0050

Lite-Wate

75

2.80

75.Oe

0.0429

0.0057

14

1.57

47.1

0.0765

0.0102

135

423

0.0284

0.0038

60

2.65

79.5

0.0453

00060

56.4

1.96

58.8

0.0612

0.0082

50.5

1.96

58.8

75

2.70

81.0

0.0444

0.0059

40.3

1.63

48.9

0.0736

0.0098

43.0

1.30

39.0

Lumnite Trinity

Activated

charcoal

Barite

gel

Bentonite

Calcium

chloride

Calcium

chloride

tlake1

powderb Cal-Seal

cement

gypsum

CFR-1

CFR2b

126.9

.06 12

.0688

0.0082

0.0092

DETA

liquid

59.5

0.95

28.5

0.1258

Diacel

Ab

603

2.62

78.6

0.0458

16.7

2.10

63.0

0.0572

0.0076

29.0

1.36

40.8

0.0882

0.0118

liquid

51.1

0.82

24.7

0.1457

0.01 95

liquid

53.0

0.85

25.5

0.1411

0.0 188

50

1.07

32

0.1122

0.0150

37.2

1.22

36.6

0.0984

0.01

39.5

1.31

39.3

0.09 16

Diacel

LWLb

Diacel Diesel

No No

Oil

Diesel

Oil

Gilsonite

HALDAD9 HALDADi4b Hematite

193

HR4b HR7b HR12b HR-L

Iiquidb lime

Hydrated Hydromite LA-2

Latex

liquid

LAP-i

Latexb

LR-1

Resin

NE-i

liquid

liquid

Perlite

regular

Perlite

Six

with

solution

22

0.0239

0.0032 0.0103

46.8

0.0760

1.30

39

0.0923

.0

23.2

1.22

36.6

0.0984

0.0131

23

76.6

1.23

36.9

0.0976

31

2.20

66

0.0545

0.00 73

68

2.15

64.5

0.0538

0.0072

68.5

1.10

33

0.1087

0.0145

37.5

0.0960

0.0128 0.01 26

.25

.01

30

79.1

1.27

38.1

0.0945

61.1

0.98

29.4

0.1225

0.0 164

40

1.30

39.0

0.0923

0.0123

2.20

66.0

0546

0.0073

0.0499

0.0067

0.0487

0.0065

74

2.46

74

47

2.50

73.6

0.0489

0.0065

71

2.17

65.1

0.0553

0.0074

77F

at

fresh

water

6/u

0.5

Ibm/gal

0.0384

0.005

2%

1.0

Ibm/gal

0.0399

0.0053

1.5

Ibm/gal

0.0412

0.0055

Ibm/gal

0.0424

0.0057

0.0445

0.0059

18% 24/u

2.0

Saturated Salt in with

3.1

Ibm/gal

solution fresh

140F

at

water

saturated

3.1

Ibm/gal

Sand

Ottawa Silica flour SSA-1 Coarse silica SSA-2 Tuf

31

.01

1.56

8c

NaCI

dry

168

006

30

38

Pozmjx Pozmix Salt in

150.5

0.0

35

50

NEPb

Salt

5.02

0.0458

0.006

100

2.63

78.9

0.0456

0.006

70

2.63

78.9

0.0456

0.006

2.63

78.9

0.0456

0.0061

100

No

Additive

1.23

36

0.0976

0.0130

Tuf-Plug

48

1.28

38

0.0938

0.0125

Water

62.4

1.00

30

0.1200

0.0160

Equivalent

When

Fnr 075

to

less

Enr

Ibm 38 Ibm

one

than of

Ibm

322

94-Ibm 5/n

ferlrte of

Penile absolute

sack

used

is

regular

We gal

use

of

these use

cemeni

in

volume

chemicals volume

volurrrn

may of

ot

2.89

1.43 gal

be gal at

omitted at

veru

zero

from pressure

pressure

calculations

without

srgnificant

error

poz

are present

slurry density

In

case can

to

solid

and

formations

reduce

used

sodium

earth

perlite

fracture

Absolute

Gravity

to

possible

prevent

Weight Specific

weak

extremely

to in

expanded

OF CEMENTING

Bulk

Weight Material

not

bentonite

diatomaceous

montmorillonite

Also

specific

cement

or

include

density

slurry

commonly

solids

low-specific-gravity

be

the

suf

mud

aerated

AFPLED

94

TABLE 3.9WATER

REQUIREMENTS MATERIALS4

Malerta Class

arid

API

Class

cement

API

Class

lowers

Requiremanls

70

girl

undesirable increase

Waler cements

API

OF CEMENTING

cu

1/94-Ibm

sack

gal

84

Cu

lt194-lbm

sack

gol

58

Cu

lt/94-lbsi

sack

the

its

addition of

because ability

water

higher

ENGINEERING

since

slurries

The

density

because

much

of

cement

in

viscosity

slurry

and

gravity use

for use

slurry

DRLLING

and

cements

concentrations

API

Class

cement

API

Ciass

cement

CHsm

Comp

Ciment

67

gal to

cement

cemenl

HLC Lile-Wate

Trinity

cement

Cu

gal

60

eLi

gal

60

cu

t09

gal

lt/94-Ibm p/94-Ibm

sack

creases

It194-lbm

sacs

charcoal

cu

lt/75-lbm

none

24

Boots Bentonits

cu

174

gal

chloride

cement

of

sack

ft/100-Ibm

cu

cemenl

in

ft/25is

about

of 64

gal

cu ft/00lbrn

3.61

none none

reduction

Diacel

none

Also

LWL

Diacel

none

10

1.0

2.0

HALAD

267

gal

none

-g

up to

cement Discel

cu

to

Ibm/cu

-t4

cement

at

over

none

Hematite 0-4 0-7

none none

HR-20

none lime

Hycrated

cu

13/tOO-Ibm

sack

LA-2

Lates

LAP-i

latex

powdered

batch

1111

should

cu

Perlite

Six

6.0

Pozmix

NaCI Otlawa Sour

SSA-t

silica

SSA-2

Tuf Plug

00-Ibm

11/165

Diatomaceous

3.4.3 cement

in

diatomaceous

535

Ibm/cu

to reduce

gal

80

cu

11/38

Ibm/cu

lower

gal

48

cu

ft/74

Ibm/cu

cu

ft18

be

the

used

of

However

significantly

data

are

needed

same

materials

the

cementing

in

Earth

earth

also

is

special

used

permits in 20

gal

cu

cement

in

Il/356o

higher

diatomite

in

of

grade

cements

portland

to reduce

where

areas

high

extremely

hydroxide

none

produces

none

and

released

40o

as

the case

in

of

slurry density

Slurry

lower

using

water

commonly

used

content

sand

additives

The

increased

is

gravity

Table

in

various

is

the by

solids

include

barium of

diatomaceous

Table

sulfate

selected

3.8

cement

The

additives

are

water

shown

34.4

in

Solid

montmorillonite viscosity

has

same

additive bentonite

sometimes

of

clay

for

building

been

clay

tor

use

discussed mineral

is

treated

use

for

with

an

sodium

bentonite

drilling in

previously used

cement

lowering

marketed

is

density

organic

in

fluid

coal

without

greatly

addition

of

has

and

than

other

much types

obtained

cements are shown

in

of

slurry

no

on

effect

cements higher

The slurry

obtained

compressive

cements

low-density

with

lowdensity

content

water

low-density

have

properties

reducing

almost

asphaltite

extremely

as

the

increasing

gilsonite

gilsonite

Example

for

solids

time

thickening

used

are

and

gilsonite

Class

Table 3.12

Chap

extensively

in

various

shown

are

an

Gilsonite

Hydrocarbons

sometimes

strengths

The

increased

with

earth

the

as

3.11

specific-gravity

using

Bentonile

diatomaceous

and

time

is

obtained

properties

of

concentrations

and

39

3.4.2

slurry

Example

concentration

used

been

reduced

are

it

age

concentrations

cement have

cement

earth

with

the thickening

bentonite

the

earth

and

sets

high-specific-

slurry density barite

specific

for the

requirements

usually

high-specificgravjty

shown

are

pressure increase

to

or adding

increase

to

pore

necessary

density

ilmenite

hematite and

be

The

solids

gravity

formation

may

further

pressure

of

calcium

cementitious

of

by weight

the

in

the

cement

portland

becomes

Diatomaceous

temperature

high

as

that

gel

resulting

contained

with

has

and

3.8

without

silica

chemically

earth

Table

ratios

addition the

Ibm

none

hydrostatic

the

it

diatomaceous

bentonite

water/cement In

reacts

strength nitrogen

than

gravity

water

free

The

slurry density

specific

none

As

This

will

that

3.10

vary

using

of

effect

sack

cement

as

Table

to

exact

in

the

11/Ibm

none

1.5

No

Additive

In

conducted

be

mixing water

gal

32 Coarse

with

found

When

strength

properties

Table

in

the use of

operations

of

227

230F

various

on

been

batch

to

of the

the permeability

above

shown

time

the resistance

none reguar

Silica

Cu

cu

galrsack gal

F-P

020 40

to

Perlite

Sand

gal

increases

are

have

results

from

and

gal

high cause

will

thickening

lowers

content

concentration

cement

tests

53

Hycromite

Tuf

048

and

none

HA-t2

Salt

10

gal

and

strength

water

also

cement

in

of retrogression promotes time Typical data showing

Class test

36

the addition

with

cements

ft

SC/

HALAD

is

However

cost

At temperatures

bentonite of

is

of

ratio

prehydrated

slurry density

bcntonite

higher

bentonite

55/o

gal/sack

each

slurry properties

slurry

cement

in

the

slurries

ft/50

for

bentonite

The

bentonite

to

to lowering

of

cement

set

5/ or

gal

the

be

in

higher

obtained

water

mixing

lowers

sulfate attack

to

75/o

gal/t

cxcepl Gilsorxte

see

Cerrroril

up to

cement

in

gal/tOO/s

Wt

the

be

dry

can

it

sac/r

CFR-2

lu

cement

blended

is

Much

when

comparable

for

hentonite

percentage

LI

usually

can

added

blended

dry

CFR-t

Diacel

content

in

addition

In

none

hemihydrale

Gypsurri

032

gal

gel

Calcium

water

bentonite

Ibm/sack

at

of

weight

water

mixing

bentonite

prehydrated

sacs

by

bentonite

the

in

in

percent

sack

The

257o

as

high

as

used

the

Bentonite

concentrations

cement before mixing with water but

prehydrated

maximum voted

Act

the

sack

gai/87-Ibm

03

with

sack

gal/94-Ibm

to

sack

p194-Ibm

cii

84

gal

Fondu

Lumrrite

been

have

specific

permits

daily

retardedl

to

bentonite

lower

its

hydrate

to

tends

it

of

as

an

However

drilling

fluid

polymer that

is

3.4.5

Expanded

raw

ore

Penile

small

containing is

expanded

where the temperature

Perlite

amount by is

of

is

introduction raised

volcanic

combined

water into

to the fusion

glass

The kiln

nnint

of

CEMENTS

95

TABLE 3.10CLASS

CEMENT

WITH

BENTONITE4

Maximum Water

Bentorrite

Requirements

gai/sk 5.2

bm/gaI

Volume

Slurry

Ibm/cu

Cu

ft

ft/sk

0.70

156

117

6.5

0.87

14.7

110

7.8

1.04

14.1

105

1.55

101

1.73

9.1

1.22

10.4

13.5

1.39

TimeHours

Thickening

Weight

Slurry

cult/ak

13.1

1.36

98

1.92

Minutes

Pressure-TenporatureThickeningTime_Test API

Bentonite

04

Casing_Tests

6000

4000ff

Compressive

API Squeeze 8000ff

tI

2000

4000

ft

Tests

6000

tt

300

225

140

214

225

132

101

148

134

225

234 235 244

129

157

132 122 124

226 216

118

231

128

056 058 056 058

145 150

126

ft

Strengthspsi

mmPmure Bentonite

Wa

80i

Diacel

0F

1905

615

1905

2610

1280

365

1090

1.520

3595 2040

1015

1380

3.11

5130

55

455

20

220

375

780

225

750

15

85

245

500

85

360

730

925

15

50

155

310

60

265

510

610

CLASS

1035 635

CEMENT WITH

DIATOMACEOUS

EARTH4

Water

Weiglrt

TABLE3i2

TIL

Slurry

Volume

10.2

13.2

20

13.5

12.4

30

18.2

11.7

25.6

192

gal/sk

API

4000

ft

336

3.12

11.0

6000 241

2.14

20

400

300

238

30

400

300

300

40

400

300

300

0.70

15.6

117

1.18

0.72

15.1

113

1.27

10

5.4

0.72

14.7

110

1.36

12.5

5.6

0.75

14.4

108

1.42

15

5.7

0.76

14.3

107

4.19

5.7

0.76

14.0

105

1.55

25

6.0

0.80

13.6

102

1.66

50

7.0

0.94

12.5

9.0

the the

At

ore

high

875

2305

3850

4690

280

620

1125

1435

gallons cu

295

660

1215

190

635

45

of

ft

2.17

85

3.18

become

Expanded The

7285

7090

1430

2140

2210

530

905

1895

1860

245

820

795

perhte fines

shown

the

perlite

is

material

Ibm of pozzolanic

of

that to

structure

used

cements

in

approximately

the slurry cause

4.5

saturate

pressure

in

in

struc

cellular

completely

will

water

thin-walled

if

this

the

loss

the slurry

to

variety

of

pump

to

perlite

blends

is

under

perlite

marketed

term regular

with

this

perlite

not included

is

to

mixed

and

enter

are required

expanded water

cellular

when

have

tests

too viscous

unbiended 5965

1010

95

94

combined

the

temperature

pressure

slurry water

blends

72 Houra

40

of

this

of water

additional

20

11.3

expands producing Mixing water will

ture

--_..12_

10

1.20

ore

24 Hours

3535

1.47

20

Laboratory

20

it/ak

5.4

10

140

Cu

6.2

under

40

Weight

Slurry

Ibm/cuff

159

300

20

Slurry Weight ________

Ibm/gal

ft/ak

8000ff

ft

400

10

GILSONITE3

Teats

Casing

10

Dracel

Cu

2.42

HoursMinutes

ft

Ratio _________

..

Ibm/ak

100

Diacel

CEMENT WITH

15.6

10

___

CLASS

Water

Gilsorrite Slurry

5.2

40

120F

80

82

Time

80F

/a 24 Hours

13

TABLE

Bentonite

50

Hours

12

Thickening

0F

100F

Blends 30

ibm

in

usually of of

is

13

waste

Ibm of expanded material

also are

applied

Ibm

the

expanded

volcanic perhte

common

to

glass

with

30

APPLIED

96

TABLE 3.13

CEMENT WITH

CLASS

EXPANDED

PERLITE

Pressure

rry

Bentonite

Sack

Cement

Water

Weight

galisk

Ibm/gal

Cu

1T2

Patch

Oil

ft

8.5

1301

97

12.70

11.7

Cement

cuff

Patch

Oil

psi

Slurry

Volume

Slurry

Volume

Weight

Ibm/gal

ft/sk

lCu

ft/ak

Regular

10.8

Sack

3000

Pressure

Slurry

Cu

ENGINEERING

DRILLING

13.84

.78 1.95

1.68

13.43

1.84

12.44

2.11

1310

2.00

12.29

2.24

12.90

2.14

Regular

10.6

11.91

2.20

13.20

11.7

11.74

2.28

12.90

2.16

1.99

12.8

11.60

2.54

12.83

2.32

13.7

11.50

2.66

12.50

2.45

TABLE 3.14CLASS Mixture%

CEMENT WITH Water

Water

POZZOLAN3

Ratio Slurry

Pozmix

Portland

Weight

Cement

Solids Ratio

lbm/sk

100

gals/ak of

cu

Mix

94

0.46

5.20

of

Weight

Slurry

ft/sk

Mix

Ibm

Ibni/gal

0.70

117

89

0.56

5.98

14.55

109

50

84

0.57

5.75

0.77

14.15

106

1.26

60

40

82

0.58

5.71

0.76

14.00

105

1.25

75

25

79

0.63

5.97

0.80

13.56

101

1.29

commonly

recommended

0.80

CEMENT WITH

FIEMATITE3 24.HoUr

Slurry

lbm/sk

gai/sk

Cu

raise

the to

of

its

ments are

for various

shown

in

densities

obtained

pressure

of

elevated being

pressure forced

panded

calcium

1.18

18.0

6290

4275

4.65

1.24

19.0

5915

5575

used

with

results

the

of

the

water

require

are

water

water

the slurry

and

pressure

from

to

peniLe

and

perlitc

density

cellular

and

the slurry because

Also shown

The

perlite

surface

bentonite

above

atmospheric

psi

expanded

the

at

approximate

3.13

increase the

in

structure

of

the

slurry the

ex

Pozzolans

mineral

cement

possess

example

of in

has

are

substances

formed form

to

cementitious

which

ground

finely

in

of

specific

gravity

pozzolans

can

density

pozzolans

be

achieved

densities

slurry

and

with

the

about

this

possible

the

same

the water

as

for

reductions

slight

only

dust

specific

than

less

slightly

is

Thus

flue The

plants

cement

portland

cements

portland

only

ash

fly

power

is

of

of

requirement

or

pumice

coal-burning

gravity

of

at

at

to

produced

The

material

con

various

using

in

range

3.14 Because

one type of pozzolan is shown in Table of this relatively low cost considerable

cost

can

centrations

of

savings

be

achieved

through

the

of

use

pozzolans

hydroxide

portland

used

4.6

46

The

Pozolan

alumjnous

as

into

4090

28

float

at

4125

6425

perlite

3.4.6

earth

3000

6965

17.0

concentrations

Table

290F

16.25

1.08 1.12

Without

low density

psi

260F

4.55

is

and

3000 Ibm/gal

12

separation

viscosity separate

psi

Pressure

Weight

ft/sb

4.5

Curing

Slurry

Volume

Water

cement

tends

Compressive

Strength

No.3

water

1.29

blend

Hi.Dense

generally

ftsk

1.18

75

Hematite

minimize

CU

It

25

TABLE 3.15 CLASS

Bentonite

CU

15.60

5Q

Mosl

to

Volume

in

the

calcium

pozzolan

discussed

However

cement

and

siliceous will

properties

been

marketing

that

react

with of

hydration

that

silicates

Diatomaceous previously the term

additives

is

an

pozzolan

usually

refers

3.4.7

5.02

having

powders been

rapidly

When

specific

hematite can

cement

have

Hematite

Hematite

Fe203

slurry having tried

unless

ground

be

to

used

as

as

specific

were enough

iron

of

to

19

gravity than

ground to

out of

of

Metallic hematite the

slurry

extremely

prevent

ore

the density

ibm/gal

settle

oxide

approximately

increase

to

were found

they fine

gravity

high

higher but

reddish

is

settling

fine the

CEMENTS

97

TABLE 3.16CLASS WITH

CEMENT

or

TABLE 3.19 Bentonite

Water

Slurry

lbmIsft

No.2

Water

Cement

gal/skI

Cu

15.6

1.20

5.2

1.25

5.2

1.31

CLASS

17.0

CEMENT WITH

ibm/sF

Cu

gui/skI

Slurry

ft

5.8

6.5

14.7

1.36

7.8

14.1

1.55

hoursrninutes thickening-time

test

45 83

40/0

20/

2000

0/s

4000

It

Bentonite

Bentonite

Bentonite

2000

It

4000

ft

2000

It

4000

It

225

320

225

346

234

130

104

200

130

241

203

047

041

056

110

152

200

336

/psi/

Pressure 000

lboursminutesl

t6 25

Psi

260

290

300

6965

4.t25

24

55 108

Casing

ressi en

Curing

Casing Schedule

Ibm/gall

08

22

t4.gOC

Weight

111561

45

1.18

Tests

Chloride

Strength

Time

Thickening Slurry

Voume

ft/sk

15.6

pressure-temperature

BARITE3

Comp

Water

Time

Thickening

18.0

34 Hour

Burte

Cu

5.2

Calcium

317

Volume

Slurry

16.0

API

TABLE

Weight

Ibm/gal

gal/ak

Ibm/gal

1.18

5.2

22

CHLORIIJE4

Weight

tt/sk

5.2

39

Slurry

Volume

Slurry

Requirement

llmenite

HiDerse

CEMENT WITH CALCIUM

CLASS

ILMENITE3

API

Compressive

00/r

Bentonite

Strength

pail

00

4.440

4.225

Calcium

18

2.28

4.315

4.000

Chloride

190

6OF

8OF

1.15

3.515

650

/n

Opsi

Opsi

Curing

and

Temperature

95F 800

Pressure

110F 1600

psi

140F 3000

psi

psi

Hours Not

TABLE 3.18 RETARDED Ottawa

CEMENT WITH

OVater

Volume

Slurry

Cu

gal/skI

45

2060

1220

2680

355

960

1195

1600

3060

llbmlgal/

t.08

20

1625

10

45

28

4.5

125

1700

51

4.5

t.39

1759

79

45

150

1800

increased

below

water that

14

for

1650

has

cement

centrations

lower

no

requires

same

little

on

effect

The

various

gravity

and

increase Like

of

concentrations

on

the

of

the

24

slurry of

composed

discussed

the

cement

slurry

considerably

of

density

extensively

as

The higher

2950

3170

80

580

800

1120

555

1675

2310

2680

3545

705

2010

2500

3725

4060

375

1405

1725

2525

3890

970

2520

3000

4140

5890

1105

2800

3640

4690

4850

615

1905

2085

2925

5050

1450

3125

3750

5015

6110

1695

3080

4375

4600

5410

ilmenite has

strength

of the

additives

the

com

at

in

various

drilling

increasing

water than

fluids

This

Table

the

requirements for

hematite

also

density for

or

for

been

has

mineral

barite

cement and

dilutes

of slurry

The range

of

concentrations

barite

decreases

required

the

The

the other

densities

barite

chemical

possible

shown

is

large

compressive

in

using Table

3.17

is

sometimes

be

are

ilmenite

the

since to

to

increase

plug

whipstock hole The

Sand

the slurry

cement surface to to form in

tool

range

be

of

an open used of

the

relatively

hard

to

though of

no

change

slurry

little

2.63 This

additional

has

has

effect

is

water

on the

but causes the cement hard Because of the

cement hole

it

about

slurry density

sand requires

or pumpability

tendency

even

gravity

specific

used

is

added

strength

form

of

low

relatively

sand

Ottawa

Sand

3.4.10

using

barium sulfate

or

ibm of

2.4 gal/lOU

water

has

compressive possible

shown

is

it

about

ilmenite

or

densities

about

requiring

hematite

hematite

hematite

Chap

in

for

2350

of

provides

ilmenite

use of barite

previously

1650

amount

specific

to

increasing

1490

Hours

possible

The

450

of

3.16

Barite

3380

Hours

con

range

has

than

time

thickening

range

mineral

4.67 Although

water

concentrations

strength

0.36

the

at

The

2890

1750

concentrations

that

oxygen

specific

density

various

black

is

and

additional

slurry

parable

using

approximately

slightly

used

730

1250

l2Hcurs

water

hematite

minimal

be

445

1230

Table 3.15

Ilmenite

titanium

of

gravity

in

The

strength

generally

possible

shown

is

Ilmenite

iron

to

hematite

slurry densities of hematite

found

been of

of

effect

compressive

265

300

densities

slurry

approximately

is

The

and

time

thickening

in

hematite

with

hematite

ibm hematite

gal/lOU

results

requirement

possible

requirement

used

585

945

VVeiht

Slurry

ftlsk

18

3.4.9

260

655

Hours

cement

/lbmlslr

of

115

190

Sand

2040/

3.48

Set

OTTAWA SAND3

as

sand

often

base the

densities

for

is

used

to

setting

direction possible

of

the

using

tt

98

APPLiED

various

of

concentrations

sand

shown

is

Table

in

3.18

with

care

setting

water

3.5

Example

It

cement

Class

amount sack

of

hematite

ibm

17.5

that

the density

be

water

blended

with

requirements

cement

and

of

Compute

Ibm/gal

should

The

Class

increase

to

to

slurry

cement

of

gal/94

desired

is

0.36

swampy

the

each

ibm

sack

of

cement

slurry then

the

The

in

slurry density

total

water

Calcium

3.4.12

terms

of

the

drous

grade

the

Expressing

less

____94x8.344.5Q.0tJ36x

3.4.13

Sodium

4.50.0036x

this

expression

hema

ibm

18.3

yields

Maximum

acceleration

by

and

develop

and

seal

exact

sufficient

off or

drilling

completion

monly

used

is

has

Farris6

was

in

shown

off the lower

bond

good

to

required behind

that

value

of

pressive

121

and

40-

When

be

so that

celerators

and

has

higher

hydration When reduce

setting

persants properties

used

commonly

API

C1A

time

However

also

cement

Class

to

content

used

to

ac

the

oratory

of

for

water

for

API

the

sodium Class

at

used

should

always

in

obtained

to

with

seawater

where

l60F

exceed

counteract

made

as

Table 3.21

placement

not

be

the

Typical

the

temperatures

higher

and in

present

slurry properties

do

he

can

when

cement

magnesium

cement

temperatures

tests

of

shown

are

time

adequate

retarders

of

accelerators

cement

on

fresh

seawater

when

effect

mixing

cement

as

thickening is

shale

inhibiting

the concentrations

at

seawater with

sen more

is

before

effect

but

lab

this

type

of application

is

agents

control

must

water

ground rapid to

dis

rheological be

hemihydrate cement time

at

hydrates

func

chosen

Gypsum

3.4.14

and

is

are used

ratios

the dispersant

of

be

promote

friction-reducing are

Cement

The

sodium

The

act

bottomhole

sodium

and

fineness

low water/cement

sometimes

cementing cement

gypsum

time

all

formations highly

purpose

strength

used

is

chlorides

salt

are

Table 3.20

about

cement

chloride of

at

wells

the

after

period

composition

For example

content

is

often

this

an are

chloride

for

for

than

cements

psi

accelerate

waiting

are

com

of

low-temperature

to

calcium

cement

psi

correspond to

1200

aiid

This

chloride used

His

reached

ratio

in

offshore

compared

usually

40

as

usually

strengths

480

effects

movement

being the

strengths

silicate

the

low

as

Since

hemihydrate form Cement setting

sodium

finer

of

the

The

shown

that

ac

chloride

rather

through

justified

is

of

an

as

sodium

Potassium

sodium be

chloride

chloride

formations

on the compressive is

seawater

Clark.7

by

cementing

can

an

is

concentration

retarder

sodium

to

strength

is

concentrations

at

sodium

as

water

cost

Seawater

the hole

cement

for

and

chloride

calcium

act

shale

than

additional

cement

to

fresh

to

effective

some

drilistring

fluid

bonding

psi

shallow

are

chloride

The

strengths

necessary

minimized

through

loading

and junk

casing

tensile

100-psi

the

subsequent

the

investigated

tensile

cementing

may

of

to

strengths

hydration

tion

100

strength

compressive

of

obtained

maximum

about

for

significant

tensile

with

acceptable

However

during

possible

is

was

casing

primarily

and

drilling drillstring

joint

not

is

by few

of

shock

used

sitive

cement

chloride

low

Saturated

Saturated

hydration

work

weight

the

to

is

tend

accelerator

com

psi

of only

the

conditions

prevent

the

show

data

is

it

The

needed

500

strength

support

must be given

operations

drilling

of

Experimental

tensile

to

by the rotating

imposed knock

practice

that

also

value

before

resumed

strength

but

laboratory

consideration

it

field

be

set

the casing

the casing

can

compressive

sufficient

under

casing

if

of

must

support

behind

activities

determine

to

to

cement

in

the

on

mixing water for cements At concentrations above

of

reduced

is

solutions

The

strength

movement

fluid

amounts

difficult

psi

Control

maintain

chloride

Sodium

occurs

bentonite

no

celerator

SettingTime

absorbs

it

to

in

anhy

an

anhydrous

Class

in

of

weight

effectiveness

the

3.4.11

The

easier

API

used

about containing

ibm cement

tite/94

and

because

calcium

Chloride

when

accelerator

5.028.34

available

is

chloride use

of

strength

It

in

used

is

bottomhole

having

chloride

is

of

chloride

Table 3.19

in

94

Solving

to

sample

commonly

125F

and

effect

compressive

gal

L314834

in

Calcium

general

readily

The

storage

shown 175

especially

water

using

wells

in

than

less

more

in

is

yields

totalmasslbni

volume

the

important

is

by weight

77% calcium 96% calcium

grade

moisture

total

of

per regular

4%

to

accelerator

cement

grade

of

time

Chloride

up

temperatures

hematite

requirement

by 4.S0.0036x

given

ts

of

pounds

often

it

as

in

present

cement

the

such

from the location

taken

as

represent

Thus

be

may

mixing

measure cement thickening

concentrations

hematite

Solution Let

retard

4.5

are

gal/100

for

locations

to

Organic dispersants

already

lignins

available

tend

dispersants

cement

the

and

tannins

many

since

of

ENGINEERING

DRILLiNG

used

to

regular

at

of

cement

used to

grade

range

sacks

various

gypsum sack

gypsum

with

portland

low thickening

with

These

materials

on

depends

temperature

full

for

blended

should

not

the gypsum temperatures because not form stable set The maximum

cement

gypsum/20

of

grades

be

high

may

grade

used

produce

can

low temperatures

working gypsum

Special

cement

varying

180F of

for

blends

the

from the

from

of

grade

140

for

the

high-temperature as

little

as

sack

cement to pure gypsum have been The water requirement applications

hemihydrate

is

about

4.8

gal/l00-lbm

CEMENTS

99

TABLE 3.20CLASS

CEMENT WITH

o/

Weight

Salt by

Water

Hequirements

Cu

gal/sk

of

Slurry

sat

Time

Thickening

and

Weight

Slurry

lbm/sk

Water

ft/sk

of

cement

Volume

Ibm/cu

Ibm/gal

070

5.2

CHLORIDE4

Salt

Dry

Weight

SODIUM

Cu

tt

ft/sk

15.6

117

1.18

2.17

15.7

117

1.19

10

433

15.8

118

1.20

15

6.50

15.9

119

1.21

20

8.66

16.0

120

1.22

16.1

120

1.27

140F

16.12

Compressive

Strength

Thickenuig

Salt

Chloride

hours minutes

10 15

1140

490

1065

sat

715-f

sat

500 Cement

4000

000

50F

psi

of

for 30

3.4.15

336

for

8000

ft

API

10000

4000

ft

Squeeze

Cementing

6000

ft

8000

ft

Salt

132

101

044

ft

110

050

108

133 308

118

143

030 034

314

259

100 115 245

110 148 300

219

Water

0.4

300

300

Water

Salt

205

an

rapid

surface

113

147

236

136

300

applications short

chloride

blend of

at

For

is

be

can

water

example

strength

when

over

develop cured

at

Sodium

silicate

containing

is

used

only

as

It

is

34.16

used

in

042

concentrations

an

diatomaceous

discussed

cement

called

thinners

up to about

found

been

on

thickening

cements

at

lignosulfonate

retard

These

common

be

very

time

various are

shown

of

the

by

effective

drilling

also

are

Iigno

deflocculants as

and

3.22

of

setting

cement

Laboratory

Class

Table

organic

as

Calcium

mud

concentrations in

the use

materials

dispersants

the to

at

the

to

of for

low concentrations

retarder

very

Most

Chap

slurries or

of

one

sulfonate

in

tend

detlocculants

portland

has

Retarders

Cement

compounds fluid

hemihydrate and Ibm of salt

will

earth

123 212

weight

setting

gypsum

cement of

150

300

development

sodium

90 Ibm

022 015

200

extremely

cement

021

055 207

135

Water

strength

of

125

202 300

300

200 300

and

portland

133 217

300 300 Salt

amount

cements

gal/ak

114

130 205

Silicate

5.2

159

229

compression

Water

1955

2450

1570

225

0.2

gal

290

Cementing

ft

minutes

Sodium

accelerator

Casing

6000

ft

153

wells

4.8

Retarder

930

15

50

hoursminutes

0.0

where

with

set

Salt

02

mixed

not

HR-4

With

_______API

0.0

Ibm of Class

2200

20

20/o

10

4650 4480 3820 3495 3155

1235

1605

0.4

when

3775 4015 3075 3175 2390

1925

148

380

0.2

of

2515

965

945

0.0

blend

1630

231

lS%

laboratory

1050

300 313

10%

gypsum

3230 4815 4350 5465 4730

20

0.0

with

2240 3920 3990 4530 4150

1735

0%

used

925

700

Class

11UF 1600 psi

psi

2000 2060

301

Sb

with

305

800

15

HR-4

small

149

230

Thickening_Time

desired

1365

Hours

95F

1600

psi

415 140 230 10

API

For very shallow

800

24

iF

95F

psi

Strength

Hours

Test

Casing

Sb

low temperatures time combined

Compressive

Time 2000 ft

Calcium

of

data

Class calcium

APPLiED

100

TABLE

TYPICAL

3.21

EFFECT

ratio

5.2

HoursMinutes

water

159

435

3230

117

520

4105

water

259

216

1410

147

120

2500

Seawater

The

addition

found

to

of

of

of

the

be

uniform

used

also

this

been

be

be

found

to

difficult

the

use

addition be

to

than

less

of

O.3Vo

obtain

The

use

during

of

have

that

shown

pumping

calcium

effect

organic

strength

Class

of

of

are

used

in

the of

reduce

to

for

to

viscosity

TABLE

AND CLASS LJGNOSULFONATE

Cass

Cement

Pozmix

or

of

used

is

in

data of

ft

Casing

2000 6000 10000

Cementing

CMHEC

are

CEMENT

Circulating

Calcium Ligriosulfate

Time

hours

Primary 110

to

170

91

to

113

to

10000

170

to

230

113

to

144

0.0

to 0.5

to

to

14000

230

to

290

144

to

206

a5tol0

to

0.0

to

6000

to

0.0

to

Cementing

Squeeze 2000

to

4000 8000

to

4003 8000 12000

to

API Class Casing

Static

110

to

140

98

to

116

140

to

200

116

to

159

0.0

to 0.5

to

200

to

260

159

to

213

0.5tol.0

to

0.0

to

Cement

Cementing

4000

to

6000

140

to

170

103

to

113

6000

to

10000

170

to

230

113

to

144

0.0

to 0.3

to

10000

to

14000

230

to

290

144

to

206

0.3

to 0.6

to

14000

to

18000

290

to

350

206

to

300

06

to

Squeeze

2000 4000 6000 10000

compressive

1.0

Cementing to

4000

110

to

140

98

to

116

to

6000

140

to

170

116

to

136

0.0

to 0.3

to

0.0

CMHEC

to

to

10000

170

to

230

136

to

186

0.3

to 0.5

to

to

14000

230

to

290

186

to

242

0.5

to

1.0

to

and

retardation

more commonly with earth

but

cement shown

in

it

is

portland

all

on the thickening Class

Thickening

Depth

detrimental

cellulose

essentially

Approximate

CF

early

diatomaceous

Cement

Temperature

the

tests

the

increasing

cement

Hfl-43

Halliburton API

strength

concentrations

CLASS CALCIUM

3.22

WITH

Laboratory

compressive

entrainment

air

It

retarder

as

cements

for

both

containing

effective

been

hydroxyethyl

control

loss

cements

high

has

lower

fluid

of the

cement

used

is

in

one-third

Laboratory

to

the

high

borax

reduces

on

deflocculant

the

deep

increase

optimum

about used

addition

borax

the

time

of

be

delloccularit in

organic

the

in

The

to

thought

Carhoxymethyl

cement

the

lignosulfonate

slurry having helps

found

when

lignosulfonate

bentonite

calcium-sodium

produce mixing and to

been

has

lignosulfonate calcium

to

superior

found

is

can

of

large

needed

be

borax

especially

where

is

concentration

of

in

time

concentration

the

effective

rctardcrs

as

thickening

ad

the

decahydrate effectiveness

the

wells

commonly

concentrations

2575 3085

tetraborate

temperature

cement Calcium-sodium

psi

4025 4670

enhance

to

deflocculants

at

the

the effectiveness

that

case

The

best

When

used

extent

greater

alone

Sodium

been

improves

to

slurry

extent

has

characteristics

increases

may

In is

has

the

it

blend

lignosulfonate acid

to

acid

calcium

the

also

It

lignosulfonate

the organic

retarder

would

the

to

2TM

HR-i

retarding

of

properties

calcium

dition

acid

organic

temperatures

high

rheological

an

excellent

give

extremely

140F 3000

psi

ScheUue

Halliburton

lignosulfonate

than

1O Csig

RP

1600

24 hours

Cement

API Class

API

110F

50SF

225 133

Seawater

Fresh

ft

at

Strength psi

Compressive

O00

ft

Cement

API Class Fresh

TIME

gaUsk

Time

Thickening

6000

ON THICKENING

SEAWATER

OF

water

ENGNEERING

DRILLING

time at

Table

and

various

3.23

CEMENTS 101

3.4.17

Lost-Circulation

defined the

as

well

detected annulus

the

loss

Additives Lost

of

to

subsurface

at

the surface

is

than

less

the

occurs

permeability

formations

bed

fractured of

can to

the

drilling

material loss

of

desired

are

classified

the

to

to

In

The

are

perlite materials

5.2

0.70

15.6

117

1.18

contain

cellophane

in

used

during

cement

and

include

Js

materials

24 0.05

24 0.10

24 24

severe

stopping while

circulation

the

in

to

mud

the

The placement

lost-circulation

operation

since

fluid

being

circulated

often

used

for

they

this

zone

are not while

Time

The

the

mixtures

FiltrationControl

filtration-control additives

mud

of

of

to

0.05

cement

0.10

the

most

However

filtration

in

loss

Class

water

formations

1000

increases

act

as

zones while

The

CMHEC

It

from

single

latex

and

the

cement

commonly

include

cm3

and

reduce

and thus in

has is

6700 7250

7200

8450

9150 6100 9200

6200 7400

8600

allow

much An

the

remove

to

in

polymers

filter

limit

the

permeable of

shales

for

which

bridges

pressure

high-pressure

of

cement dehydration abandoned perforated

bentonite

with

organic

It gal/sk

140

104

328 423 400

230 235 332

400 400

in

cm3/30

by

mm

1000-psi

14000

through

pressure

of

one

325-mesh for

differential

of

the

HALAD9TM

Halliburton

perforated

additives

polymers

The

rates

organic

in

Class

Table 3.24

in

to

reduce

less

chance

rate

pumping

fluid

drilling

cement

is

contamination

Shown

turbulent velocity

cement The

with

required with

Table

in

and

commonly

include

3.25

without

the

used

organic

and

is

for

in

the

thus

and

the lower

at

indicates less

when

achieve

to

It

required

flow

evidence

displaced

be

reduction

fracture

turbulent

in

Some

be

gradient

formation

placed

will

will

pressure

the

at

placement

viscosity of the slurry

pump horsepower there

Untreated

viscosity

cement

the effective

of

be

effective

during

frictional

slurry can

ditives

Additives

high

placement

smaller

less

have

present

so that

ditive

dispersant

slurries

desirable

the

filtration-control

various

shear

annular

operation used

5.2

Viscosity-Control

cement

cement placement

longer

Water

12000

0.20

shown

is

3.4.19

prevent

plugging

Depth

232 412

concentrations

cement

cement

hydrostatic

Tests

Well

higher

API

hydration

dangerous

into

various

untreated

slurry to

5650

10000

0.15

rate

caused

screen

as

no

containing

desirable

the

rate

Cement

30-minute

formation of annular

pumping

intervals

muds

potentially

and

intervals

have

water-sensitive

packer back

holding

9000 6400

and

discussed

slurries

slurry viscosity during the

prevent can

additives

minimize

to

in

8300 3600

bentonite

same function

clay/water

filtrate

mations containing

the

additives

cement

of

excess

of

than

rates

slurry of loss

serve

cement

control

filtration

850

7700

gypsum

bentonite

Additives

filtration-control

Chap

6750 7200 7050

LWL

Diacel

filtration

the

8800 6700

Thickening-Time

__________

slurries

include

oil

3.4.18

6.850

hoursminutes

Pressure-Temperature

special

merely additives

gunk and mixtures diesel oil bengum

and

290

6375

4925

of these

requires

drilling

purpose

hemihydrate cements diesel

for

260

6950 8525

1750

problems encountered be remedied lostby adding

cannot

additives

cements

are available

30 6350 7950 5850 8125 5100

lost-circulation

that

drilling

slurries

gal/st

200

0.20

include

psi

4.3

5450 8400 3500 8350 2025 8200

0.15

flakes

flash-setting

Temperature

3000

hours

shells

14000

053 207 224 304

Water

0.00

and

ga/sk

psi

Time

shredded

fibers

400 400

20

LWL

Yhickoning

and

224 337 400

24

Lamellated

mica

352

Curing

The

walnut

nylon

0.10

Curing

com gilsonite ex

crushed

128

Diacel

and

granular

include

12000

134

ressirength

high-permeability

be effective

to

10000

in

or

fibrous

4.3

0.05

ti

It

Depth

Water

LWL

0.15

additives

fractures

additives

tannins

Semi-solid

Tests

Thickening-Time

______

lost-circulation

experiments

plastics

and

hoursminutes

and

wood bark sawdust and hay However the use of wood products can cause cement retardation because they

Time

fluid

granular

effective

are found

granular

Fibrous

1.06

material

lost-circulation

simulated

additives

panded

123

created

drilling

the

ft/ak

16.4

Pressure-Temperature

drilling

placing

Cu

ft

0.58

Thickening

formation

ensure

laboratory

beds

used

however

Volume

Slurry

Ibm/cu

4.3

cement slurry to minimize the

fibrous

additives

lamellatec

the

reducing

troublesome

as In

granular

Density

ibm/gal

ft/ak

Diacel

while

CMHEC4

WJTH

as

or

lost-circulation

cases

to

location

lamellated

gravel

or

and thus

the

Cu

Slurry

pressure

occurs

adding

fluid

cement

cementing

monly

wellbore

by

added

is

Requirement

gal/sk

Lost

such

or

CEMENT

Well

some

In

density

Water

high-

limestone

encountered

usually

overcome

encountered

or vugular

TABLE 3.23CLASS

is

from

extrcmely

are

is

excessive

circulation

be

cement

into the well

rate

when

formation

because Lost

pump

bed

oyster

circulation

or

formations This condition is when the flow rate out of the

circulation

gravel

fluid

drilling

that

the

mixing and thus the

is

flow

pattern

comparison

turbulence

of

Class

viscosity-control viscosity-control deflocculants

is

of

such

ad ad as

APPLIED

102

TABLE

CEMENT

CLASS

3.24

WITH

CONTROL

FILTRATION

ENGINEERING

DRILLING

ADDITIVE3 Slurry

HA LA

D-9

Water

Salt

/o

gai/sk

0.0 0.6

to

Requfternent

1.2

Weight

Skirry

cuftsk

Volume Cu

Qbm/cuft

fljm/ga

ft/sk

5.20

0.70

15.60

117

1.18

5.64

0.75

15.26

114

1.24

Loss Tests

Fluid

mm 325-mesh

cm3/30

screen

1000-psi pressure

HALAD.9 0/o

calcium

long-chain

cement

viscosity

should

0.8

52

84

1.0

38

62

12

24

36

sodium

as

polymers

are

without

the

in

same

for

well

manner

that

available

or retarding

accelerating

However

act

as

Other Additives

slurries

not discussed

include

which

thinners

tamination

mud

used

used

placed

easily

used

after

more

pounds

which

cement

begins

flow

to

to

occurring

be

known

evolve

small

desirable in

cement

for

an

the to

that

to

high-

the lower

oxygen

and

make

to

gas bubbles

12

the

as

of

volume

the

bubbles

when

there

newly harden

cemented There

TABLE

in is

ficiently

cement

been

when

API Class

Pipe

Hole

Size

Size

in

in

with

more shallow

FOR

TURBULENCE3

Water

Ratio5.2

gal/sk

Slurry

Weight15.6 Neat

index

Critical

may

reach

Ibm/gal

Dispersant

0.30

0.67

0.195

0.004

Velocity

flow

1.0/o

Critical

Flow

Rate

bblmin Without Dispersant

With Dispersant

Without

With

Dispersant

Dispersant

9.2

2.61

13.6

3.85

41/2

77/s

8.6

2.13

20.9

5.18

51/2

7V8

9.1

2.54

16.9

4.70

8.6

2.17

23.3

5.85

9.6

2.96

15.5

4.76

11

9.1

2.54

24.4

6.90

12/4

8.5

2.05

37.0

9.05

121/4

9.0

2.41

29.6

8.08

41/2

/2

/a

9/8

in

weilbore

the

RATES

Properties

consistency

loss

accompanied

gas

nflowbehavior

to

solid

hydrostatic

it

begins

pressure

to

Equations ap are developed later in Sec

this is

treme case

FLOW

Cement

to

begins

progressive

ability

by

pressure

to

transmit

cement can

slurry

fall

suf

permit gas from permeable high-pressure to enter the annulus The semirigid slurry

communicate

several

CRITICAL

3.25

is

fluid

created may not be able to withstand the higher stresses when gas begins to flow Gas flow may increase and

of gas

danger

borehole

have

Slurry

the

If

reduction to

liquid

phenomenon

pressure

formation gas

this

when

fluid

cemented annulus

the

Chap

hydrostatic

com

special

to

plicable

of

part

completed structure

As the cement slurry goes

transmit

to

gel

much more

from

ability

is

it

struc

gel

Later as the cement

fluid

drilling

static

drilling

becomes

gel

transition

lose the

the

in

stopped

is

of

through

radioactive

nylon

small

than

cement has been

the as

drilling

stronger

the

of

shortly

However

semirigid

cement placement

as

stop

cannot

occur

understood of

to

procedures

gas blowotits

fully

occurring

cement

set

not

formation

that

movement

which

by is

control

hours

gas flow

difficult

particularly

well

soon

as the

to

be

the formation

that

begins

similar

given

harden of

cement begins

such

resistant

slowly

formation

thought

the

impact

form

corrosion

where

fibers

special

from the

cementing

Initially

chromatc

hydrazine

control

to

and

cement con

of

to

permeable

determine

to

cement

The

less

used

is

applications

scavenger

sodium

effect

deflocculants

which

flour

and

stable

tracers

and

the

counteract

by organic silica

temperature

is

to

categories

can

several

annulus

were completed

operations

casing

be

is

additives

the previous

in

paraformaldehyde are used

more

Miscellaneous

the

conventional

ture 3.4.20

cementing

the

through

The mechanism

cement

the

flow

gas

because

organic

as

of

outside it

act

Certain

will

after

discussed

deflocculants

that

cases

reduce

as

fluids

drilling

thinners

as

and

chloride

Deflocculants

polymers

remembered

be

retarders

Salt

192

Chap

in

previously

10/o

72

lignosulfonate

certain

Salt

0.6

formation the surface

In

an

ex

CEMENTS

103

sc

CEUEN1

sro

CAsIN

.1-B0REHOLE

-z_LINER

CEMENT

CEMENT

__

SOLD

Ic

CEMENTING

CGSING

STRINGS

CEMENTING

LINER

STRINGS

1iL OLD

CEMENT

OLE CE

CEMENT

SETTING

Common

3.6

Fig

di

PLUGS

cement

SQUEEZE

MENT

CEMENTING

placement

requirements

3.7

Fig

Conventional cementing

Volume solid

reductions

be

can

traced

while

occurring

the transition

making

from two

to

cement

the

to

slurry

liquid

sources

is

rigid

volume

small

casing

to

surface

the

tached

to

place

Cement

casing

before

used

small

well Cement

Much

abandoned

in

current

larger

volume

the

to

The of

water

loss

cement

process desirable unit

the

as the

because

volume

pound

that

of

it

cement

volumes

to

can

high

The

due

volume

by the cement of

the

hardening

introduction

is

loss

pressure

per

com

of

form small gas bubbles harden will greatly increase to

of

the

be

increased

cement

Cement

by blending

the

cement permits

of

creasing

the potential for gas flow

methods

for reducing

reduce

the

columns in

to

blocking

and

filtrate

include

cementing to

water

cements

pumping

is

use of

reduce

of

build

that

and

Different

cementing

techniques

are used

squeeze

cementing

of gel

harden

cementing

applications

are

cement

of the gel strength

hydrostatic strength

more

pressure

quickly

after

setting

These

placement

casing

strings

cement plugs

in

types

Fig

The

lower

in

or of

portion

the

zones

or

leaking

movement

fluid

casing

composition

station

where

powder

and

is

it

psi

casing

air

with

in

water unit

and

unit

mixes

be

through

just

moved

pneumatically

is

The

cement

unit

and

When ahead

to

pumped

is

The

for

land

under

the

plug

is

nozzle Dry

the

on

units

cementing

head

cementing

special

high

cement

dry

from the bulk

pump

is

The

operations

of the

into the top

screwed

cementing

the wiper

of

cementing

downstream

slurry enters

plug container

rubber

cement

water by pumping nozzle and loading

hopper

is

When

unit

the slurry

through

cement

cement

cemented

for offshore

pressure

fine

vessels

units

truck-mounted

is

usually

the

aerating

pressurized

transport

special

skid-mounted

jobs

bulk to

of

blending

The blended

pressure in

for

Cement

bulk

at

between

method 3.7

Fig

moved by

ready

is

string

in

blended

is

cement

to the job

transported the

is

blowing

30 to 40

under

conventional

described

the desired

cases

different

illustrated

in

hole

open

perforations

Casing

or

of casing

joint

begins the bottom from the plug container

operation

released

cement slurry This plug wipes the mud ahead of the slurry to minimize the of

contamination

and

at

cemented

from the casing

rapidly

Techniques

cementing

strings

after

additives

shorter

equipment for

in

well Other

control

loss

is

liner

into lost-circulation

squeezed

cementing

cementing

larger

flow

Cement

3.5.1

small

greatly

the

into

the effectiveness

liner

much

without

filtration

3.5 Cement Pbcement

and

lost

filtrate

transmission

stopped

cementing

be

the potential for gas

volume

the

to

the

ex

casing

of

in

placed

cemented zone to stop undesired

mixed

mixing high-compressibility

that

in

top

previously

abandoning

casing

com

cement slurry during

volumes

the

casing are

plugs

is

for

walls

compressibility

small

gas with

nitrogen

possible

per unit

stages

give

loss

begins

also

of

early

react slowly

compressibility

loss

primarily

with will

filtrate

will

pressibility

the

during

be

to

the borehole

to

controlled

is

compressibility

are thought

filtrate

is

0.3%

to

of the pressure

magnitude

filtrate

reduction

on the order of reductions

of

loss

volume

this

practice

being

used

technique

liner

while

subsurface

reduction as measured in the soundness test occurs due to the cement hydration reaction For most cements

generally

from

differs

string

tends

placement casing.5

3.6

of

into the casing the

the

cement with

slug of liquid called

cement

volume

of

the casing container

before

from the slurry

top

mud

cementing been

wiper

The top plug

plug

to

fluid

drilling

has

the

mixed is

differs

mud

prejiush

In

assist

in

After

the

and

released

some

pumped

is

isolating

desired

pumped

into

from the plug

from the bottom plug

APPLIED

104

that

in

plug

TOP

CEMENT

slug

PLUG

is

fluid

top

MUD

FILM

completion

plug

When

the casing

drilling

behind

the

the

i-caches

plug

in the plug the diaphragm cement slurry to be displaced

float

ruptures

allowing

through

the guide

and

counting

pump

the top

plug can be

The

float

cement

be

can with

the

the

cement

bond

because

the

pressure

when

cement

in

and

used also plug

not

is

it

good

the casing is

while

released to

sufficiently

form

plugs

be

the top

on

dis

prevent

movement

the pressure

diameter

to

can

place

Fluid

pressure

the

the

increase

casing Top

in

of

and

of

valve

However

fluid

may change with

latch

collar

excessive

hold sets

the

by holding

end

pressure

check

Hy

position

times

all

the

as

up and

float

displacing to

at

into

act

seals

at

excessive

an

can

prevented

the casing the

down

slowed

to

approximate

determined

prevent

pressure

practice the

be

collar

addition

the

the surface

at

operation

displacement

strokes

from backing

have

that in

to

the

the top plug reaches

increase

pressure

of

the

can

the

end

signifies

When

annulus

the

into

bottom plug

placement

SLURRY

into

bottom

cement

by pumping

casing

fluid

the

bottom

the

The

the

pump

CEMENT

the

while

diaphragm

rupture

down

displaced

rubber

solid

is

thin

collar

the

FILM

plug

or

shoe

MUD

the top

contains

ENGINEERING

DRILLING

small

break

annular

channel Not

all

solid

plug

slurry float

Fig

3.8

Cement

collar

with

without bottom

plug

plug

is

not

was of

some

was stopped the

completing contamination

there

mistakenly

Also

used

bottom

use

operators

Indeed

cementing

have

been

placed the

below

first

plug

displacement

however

the

cement

FLUID

LLDSINS

PLUS

CEMENT

tL-1-ri

STAGE

CEMENTER CLOSING SEATED

CLOSING PLUG SEATDRILL ABLE

r.J

I.IPoRTs

CLOSED

FORTS OPEN

OPENING PLUS SEAT IDRILLANLE

BOMB SEATED

1W olt44

PLUG

PORTS LOCKED CLOSED

1W

SHUT-OFF BAFFLE

DR LLABLE

FIRST STAGE BOTTOM BY-PASS PLUG BAFFLE BOTTOM

-CLOAT

1W

FOR PLUG

UI

COLLAR

SHOE

JfI-GUIDE

Fig

3.9

Two-stage

cementing.5

the

not

the

cement

designs

When does

DISPLACING

..I PO5

when

up by plug fragments

cement

when

plug

cases

the

before bottom wipe

all

CEMENTS

105

mud

the

from

contaminated

shown

as

the

in

the

the

which

the

entrapment may result from

through

The

simplest

ports

of

action

shoe

guide

slurry

be

achieved

function shoe

joints

guide are

the

cemented

zone

exit

above

on the outside

of

the

the

center

remove

of

the

hole from

the

others

casing

to

when

and

float

available

used

slurry

side port

cement

Equipment

ports

for

time

borehole

Some

walls

by reciprocating for cleaning

are designed baskets

DRILL

in

help

are used

to

by help

into

Fig

dropped

is

in

placed then

is

above

also

available

is

of

and

was the

extremely

uses

float

landed

and

than

equipped

of

collar

TOOL

hydraulically

the

the

inner

casing

with

modified

tubing sealed

or

Fig 3.10Conventional

The

drilipipe

When

backpressure

the

or

tubing

float

valve

collar

or

techniques

for

cementing

liner

joint

technique

cement

TOP PLUG LANDED

DISPLACING EM NT

cementing

with

or

placement

three-stage

drillpipe

COLLAR

LANDED

this

first-stage

The

PLUG

INSTALLATION

string

the shoe

in

casing

shoe

or

permits

left

the

TOP PLUG

SHOE

set

the

open

Inner-string

reduce

cement

large-diameter

down

displaced rather

to

developed

amount

which

adapters

is

Cementing

Inner-String

TOOL

FLOAT

to

through

for

INSTALLATION

FLOAT

After

the casing

the

after

operation

3.9

pumped

the annulus

also can

flow

gas

PIPE

BOTTOM

It

cementing

side

to

for

frac

cause

formations

potential

cement

and

have

the casing

would

normally

tool

staging

side port

cementing

used

in

second-stage

3.5.3

are

the

bomb

hardens

for

help hold

reduce

to

the

are placed

that

of the

one

is

cement column

using

The first stage of the cementing cementing is conducted in the copventional manner

from

for cleaning

Cement

be

annulus

the

multiple cementing

cementing

permit

one or more subsurface

hole

Scratchers the

the

serves

Centralizers

packer

are designed

casing while

devices

the casing

mudcake

scratchers

rotating

These

of

ture

Stage

to

developed

in

height

cementing

tubing

cementing

Cementing

Stage

procedures

port

collar

shoes are

of

portion

35.2

include

These

reverse-circulation

delayed-setting

method modified

several

are

inner-string

through

cementing

and

exposed

situations

special

cementing

the

also

packer

lower

float

Float

or

in

points

at

slurry

are

placement

there

casings

cementing

stage

cement

the

formations

the conventional

to

used

annular

The

side

addition

cementing

techniques

circulation

shoe

float

desired

containing

isolating

up

through

and

shoe

shoe

annulus

the

bottom

easily

shoe

guide

both

of

on

resting

is

more agitation

to create

circulated

more

the

in

openings

collars

be

is

Circulation

end of the guide

designed

the casing

wall

the borehole

in

through the open

side

cement

the

Should

the

the casing The shoe contaminated mud or the wiping

for

string

scratchers

open-ended collar type with or without nose The guide shoe simply guides the casing

established

slurry

of of

irregularities

can

centralizers

at

of

weight

where porous or weak

collar

the

is

molded past

float

shoe or float shoe

guide

plug

includes

operation the

the

in

the

support

top plug

used

is

below

casing

outside

cementing

top

design

often

cementing

the

on for

the

in

In

of

joints

baskets

cement

no

up

results

of

front

in

that

shoe joints

joints allow

This

casing

bottom of the casing and

and

as

being

casing

more

called

the

built

equipment

conventional or

of

3.8

Fig

Subsurface

one

wall

zone

sealing to

then

be is

string

or

shoe

latch-down

APPLIED

106

the inner

plug after

3.5.4

used to

DRILL

PIPE

OR

TUBING

to

the top of

bring

3.5.5

or

of

the

the

of

3.11

Placement

technique

used

for

setting

plug

when

wiper

the has

extremely

or

shoe

slurry

mud

back

been

bottom

of

of

well

as

3.5.7

special

consists

having

good

before

running

down

lowered

is

method

also

lower

method

cementing

nervous

strong

Cementing

liner

cementing

The

to

liner

hundred and

for

well

and This

multiple-string

made

being

The

delayed-setting with

engineer

drilling

of

casing

so

that

the

supported

and

The

by

liner

from

the

liner

tool

attached

is

the casing

between

without the

liner

down

pumped

is

several the

liner-setting

passage

cement

separated

The

of

fluid

displacing

is

tool

with

the top

of

liner

liner-setting

position

between

the

3.10 The

Fig

special

the

and

method

conventional in

to

overlap

sealing

drillpipe

is

slurry

the

displacement

using

hydraulically

casing

from

lowered of

to

mechanically

placement

up the annulus

cement

illustrated

actuated

is

slurry

wellbore

the

in

removed

Liners The is

bottom

the

then

is

cement

the unset

requires

This

technique

and

string

drillpipe

feet

mud using

system

3.5.8

attached

uniform

Cement

modified

be

of

possible

retarded

drillpipe

cement

the

through

is

can

is

placement

casing

into

with

cementing

than

properties

the

then

drillpipe

casing

into the

ft

Delayed-setting

more

placing

the

300

least

Cementing

filtration

accomplished The

of

to

The

shoe

cement

conventional

method

difficult

is

it

method

this

the probability

from the annulus

displacement the

at

obtain

to

hole

the

displacement

enhance

to

the

at

used

is

used

overdisplaced

is

Delayed-Setting

cementing

be

for

as

use

to

cement

the

the casing

cement job

good

cannot

of

in

used

low-strength

bottom

the

required

is

plugs

end

the

cement usually

HaUburtor

Reversethe

pumping

method

near

collar

assembly

detect

of

of

cement Since

Courtesy

inside

packers

displacing

This

casing

float

wellhead

which

in

Cementing

cementing annulus and

mations were present special

more

the

to

method

the This

string

casing

instances

some

casing

using

set

that in

tubing

alternative

consists

the

through

Fig

outer

Reverse-Circulation

the

method of

strings

an

are

strings

circulation

down

Multiple-string

multiple-completion

tubing

cement

placed

completion

an

is

completion

larger-diameter

3.56

two casing strings hole It usually is

open

Cementing

use

through

casing

several

cementing

conventional

cement

the previously

multiple

is

without

type

the

repair

to

Mulilple-Siring

cementing involves

PLUG

and

This

Tubing

Through

pumping

annulus between

the

in

the surface

hole

CEMENT

of

between the casing

or

HOLE

Cementing

consists

run

tubing

immediately

cement

the

Annuhtr

technique

withdrawn

be

string can

displacing

ENGINEERING

DRILLING

the

by

Servicos

latch-down Fig

3.12

Bridge plug

special top

of the

wiper

plug

wiper

plug

This in

cement column

plug

reaches

latch-down

the

the

liner-setting

reaches float

actuates

plug

tool

the liner

collar

after the

When

pressure

the in-

CEMENTS

crease

107

the surface

at

displacement from

the

The

of

the

must

then

and

tool

liner-setting

end

the

signifies

drilistring

be

withdrawn

cement released

before

the

cement hardens volume

Usually the

past

of

top

of

the

cement

liner

sufficient

extend

to

When

displaced

is

the Ui

top of

withdrawn

is

drilistring the

lincr

cement

hut

out

drilled

forced

the

method which large

are

pump

applying

are actuated the drillpipe the

basis

the

cement

displacement

cedure

There

until

moved

be

in

the

annulus

liner-setting

After

drilling

tend

the

hydrocarbon

but

If

casing

not

liner of

liners

set

used

to

bottom

and

in

an

locate

the

an

open

be be

will

the

bridge

hole

When

plug

portion also tools

drilling

of hole

the

the

the

in

or

space

are

balanced

slurry inside

the pipe

pump good

balanced

or

drillpipe

columns

the

tubing

is

good

open-ended

until

continued

is

annulus

indication drillstring

during

when

of

As shown

technique

minimized by

and

behind

To

pulled

used

can be plugs

dump

bailer

depth

the

the the

or tubing

from the cement slurry

Fig

displacement fluid

then

takes

After

to

an

the time

from while

on

required

is

is

to

or

plus

filled

with

wireline

at

The

After

the

first

used set

during long

can

be

drilling

catcher

Cement called

the desired

cement

dump

batch

is

or

being

is

plug

device

bridge

second batch

set

seldom

drillpipe

the pipe

valve

of

cement

the slurry into the hole

bottom

front

in

the

wireline

setting bailer

empty

initial

bailer

The

of the pipe string

using

the well

reaches

dump

bottom set

dump

into

designed

backflow

be

can

slurry

backpressure the

at

also

water

completely

prevent

special

contamination

of

slug

cement

the

Mud

method

placing

almost

displaced

is

has been technique placement and Coins9 as an alternative

balanced-column

the

is

bailer

in

plug

by Doherty5

to

fluid

the

i.e have the same height of and

pressure

The

4Squeeze-cementing

improved

in

placed

is

forming

An

described

tubing

tubing

cementing

sometimes

assist

be

slurry has

annular

When

to

drillpipe

below

bridge

to

to

Centralizers

cement

up

off

used

lowered

the

3.1

Fin

tubing

bottom section of

down

Fig 312

be

can

the section

The

or

placed

is

hole

the

tubing

or

plug

displacement

siowly

fluid

Plugs

drillpipe

the

on

move

to

cement

are

lower

in

set

prevent

plug

of

form

drillpipe

cement

be

can

to

seal

hydraulic

provides

stub

repair the top

to

caliper log

pumped

the

slurry

casing

3.13

up the hole

the well

using

opposite

to

the

of

When

placed

is

into

opposite

the

SLURRY

tieback

well

portion

can

tendency

below

NEW

be

to

is

called

is

for directional

hole

in-gauge

and

causing

liner it

plugs

part

3.11

Cement

natural

Cement

are placed

Fig

the pipe that

tubing

the

primarily

upper

the

in

scratchers

plugged

V.ALUE

ex

to

called

the surface

seat

plugs

shown

CIRC

commercial

the well

is

casing Plugs are set between an abandoned

sidetrack

to

CEMENT

OLD

limitations

desirable if

and

casing

are used

provide

Cement as

in

and

the well

be

surface

extend

to

Cementing

Plug

open hole or communication

are

of

to

liner

liner

leaking

of

may

it

found

is

used

way

the

allows

some

imposes

the

to

type

is

the

all

Stub

3.5.9

well

deposit This

completed liner

the

liner

selected

tool

back

liner

pro

the

improve mud removal

to

This practice

the

on

setting

This

on

dimensions

liner-cementing

toward not

cementing

devices

set

by lowering

set

annular

and

rate

while

balanced

for

device

must be selected

tool

cement displacement

after

to

chart

pressure/time

by drilipipe and then set by

or plug

weight

trend

is

ldeahzed

3.13

Most

available

is

rotation and

liner

Fig

are actuated

liner-setting

of

TIME

be

pressure plug

The mechanically

drilipipe

not

is

must

or hydraulic

ball

pressure

by

tools

devices

set

cement

cement

ESO

START

or

drillpipe

Sec 3.5.10

in

by dropping

the

squeeze-cementing

mechanical

The hydraulically rotation or

using

the

at

bottom This

to

fall

liner

liner-setting

either

collects

\Vhen

sets

discussed of

not

using

the

area

is

variety

with

set

of

top

this

into

out

cement

the

after to

displaced

does

generally

washed

he

can

cement

this

and bailer

when of

the

cement

placed because

The of

plug

columns is

pulled

3.5.10

Squeeze

consists

of

forcing

Cementing Squeeze cementing cement slurry into an area of the

APPLIED

108

well

or formation

The

pressure

form

zone squeezed pressure

the

filtrate

severe

repairing

annular

caused

previously

valve

culating tions

and

slug

of

be

lowered water

above

the

opened

and

before

of

zone

circulating

is

used

is

mud

prevent

of

the

usually

is

plugging

valve

is

slurry

water

to

mud

zone

the

squeeze

of

pressure

common

squeeze

pumping

periodically

or hesitate

This

buildup

against

the

culating

valve

In

the

up

first

stop

nodes

the

cement This

surface

the desired

If

the

operation of

cir

The

the excess

to

batch

low-

to

cake

filter

out

obtained

for the

of

final

the

the squeeze

during

perforations

drillpipe

reversing

not

addition

bridge

the section

below

plug

squeeze is

pressure

blowout

squeeze repeated

is

cement

take

to

an

below

producing

the

Cement the

bridge

the

well

block zone

in

by

required

usually

is

and

called

and the the

consists

above

squeezing

separate

cases

used

closing

is

of

and

through

steps

Volume Requirements cement

other

squeeze

In

addition

to

and placement composition must determine the engineer

technique the drilling volume of cement slurry needed volume

necessary

by perforating

interval

been

by placing

plug

method

This

intervals

perforated

selecting

nor

squeeze production

In

the perforations

against

isolating

have be

may

it

below the perforation

packer

held

squeeze-cementing

techniques

instances

preventers

bradenhead

3.5.11

conventional

modified

certain

In

isolate

neither

the

to

several

developed

both

or

practice

opened and

is

With

set

method to

then

waiting

initial

assists

called is

is

formation

pumped is

it

the

until

interest

obtained

is

pressure

after

assembly.5

cement

slurry

and

just

valve

into

pressure

packer

the

zone

set

pumped

process

Squeeze

is

packer

pumped

is

3.15

The

the

opposite

slug of

cement

the

perfora

circulating

and

of the slurry

interest

process

Fig

The

packer

the

or tuhing

after

desired

CATCHFR

placed

is

the drillpipe

after

above

drillpipe

most of the leading water slug has been annulus The cement then is into the

closed

JUNK

on

the squeeze

interest

the

contamination

or

casing

cementing is and cir

packer

placed

well

preflush

of

down

the

either

for squeeze

are

the

and then

zone

displaced

SLIPS

into

or

above

and cemented

previously

squeeze

Fig 3.15

squeezed

are

perforations

of

method

3.14

Fig

in

the

cement

placed

conventional

shown

is

formation

zones

in

failure

by

placed

cementing

squeeze casing

leaks

is

low-pressure

the

to

forced

out against

plate

lost-circulation

plugging

The

of

abandoned

casing

to

the

In

is

the process

The

lost

is

slurry

the slurry

If

squeeze

applications

plugging

FMFNTS

is

process

pressure

pressure

cement cake

as

Common

Fl

the

cement

breakdown

the

low-pressure

formation

ACKFR

the

sufficient

using

breakdown

the

squeeze formation

causes

squeeze

SLIPS

to

is

and

welibore

formation

whole

than

called

to

the

fractured

less

using

ASSEMBLY

hydraulic

cementing

placed

is

slurry

the

called

is

high-pressure

VALVE

applied

squeeze The pressure required formation and allow rapid slurry

the

placement

into

an

squeeze

high-pressure

fracture

to

the

If

fracture

to

of

of

between

seal

hydraulic

called

means

by

purpose

ENGINEERING

DRiLLING

is

based

for

on

the

past

job

The

experience

CEMENTS

and

109

regulatory

300

of

ft

casing

hole

experience

the

in

theoretical

determined

estimating

hole

usually

area

hole

more accurate

Ett

the

by

on prior the

to

applied

is

TRANSMITTER

enlargement

based

factor

entire

include

to

indicated

of

volume

slurry

RECEIVER

or caliper

size

E4M

can

Example 3.6 illustrates one method of volume for con requirements

slurry

ventional

cementing

casing

BONWNG

POOR

as

deep

the

cases

than

excess

little

relatively

necessary

volume When

cement

logs are available be

is

because

Thus an

drilling

some

in

slurry

size

area As

the

behind

usually

It

more

theoretical

used

However

cemented

is

considerably

while

been

has

strings

annulus

in

requirements

fillup

operation

GOOD BONDING Example3.6 Casing ID

an

of

2500 float

in

12.415

ft

shoe

40-ft

and

collar

500-ft

column

of

of

casing

The

thc

by

flake of

5.2

to

be

filled

by

of

ratio

bit

size

Solution

if

Table

of

the

brine

is

to

108.4

Table

2.3

for

The

brine

CaC12 of

to

CaCl2

column

is

2.4

of

Volume cu

2000

slurry

2102

1.75

volume cu

will

require

cu

mixing

sacks

901

1.88 of

gives

ft

The tail

volume slurry

is

of

each

component

in

Volume

cu

Component

94 ______

Cement

0.4797

43.4

1.88 0.7025

brine

62.4 1.182

Yield

The

0.0910

and

cement 40-ft

for

required

column

in

the shoe

joint

is

I2.4152

559.2cuft 2.334

Yield annular

given

1.7633

water

in casing

is

40

0.60065001.75

4.7

.027962.4

The

cuft/sack

capacity given

for the

17-in

cu

hole

ft/sack

and

13.375-

This

182 cu sq Total

13.3752

volume

559.2cu _____

by

172

slurry

slurry

will

mixing

require

ft

473

sacks

of

cement

ft/sack

volume

then

will

be

l44sqin 0.6006sqft

2l02cuft

559.2cuft

column

annular

500-ft

2.6562.4

Salt

ft

62.4

3.14

CaCI2

the high-strength

by

givcn

0.4797

108.4

excess

ft/sack

31462.4 0.1694

an is

ft

1.0329

Bentonite

and

ft

required

2l02cuft

94

Cement

volume

gravity

weight

1.88

the slurry

1.75

_____________ ____________

gravity of 1.0329 CaCI2 brine specific The volume of each component in the low-density of cement is lead slurry per sack given by

Component

This

2.334

8.34 for

of

06006

0.0415

specific

l.88/43.4

factor

Interpolating of

ibm

43.4

wells

The

made by adding

is

cased

in

2.65

94

lbm

brine

travel

2000

of

length

is

must be

Chap

water

of

Table

in

0.0415

in

energy

1.75

cement

bentonite

4.7

NaCI

gives

Class

2.4

Acoustic

in

17

fraction

weight

4.7

of

and

8.34

lbm

Interpolating

fraction

2.3

made by adding

94

water

is

316

Fig

volume

annulus

of the brines

gravity

specific

NaCI

lbm

sodium

slurry

is

of

gravity

specific

NaCl

1.0279

_______________

Using

using Tables

of

the

of

gravity

specific

3.8 The

4.7/108.4

is

water/cement

in the

the hole

drill

to

and

factor

ratio

Class

and

bentonite

Compute

determined

in

slurry of

cement

the excess

used

The

and

3.14

16o

RECEIVER

chloride

of the annulus

ft

low-density

with

composed

is

calcium

water/cement

2000

upper

weight

requirements

The

The

gal/sack

13

and

place

bottom

the

at

slurry

2o

of

depth

between the

used

slurry

using

cement

at

TRANSMITTER

in and

13.375

desired to

is

high-strength

with

mixed

chloride

It

high-strength

of

weight

gal/sack

cement

shoe

cement mixed

of Class

be

will

joint

the guide

of

cemented

be

to

OD

an

having is

2661.2cuft

by

APPLIED

ENGINEERING

DRILLING

110

sacks

total

the

and

for the job

cement required

of

will

wellbore

sacks

1374

473

901

cement

job

always

Time

Cementing

3.5.12

slurry

of

one

is

time

the

previously

engineering

the

cement

and

more

accurate

made

based

may

used

for

Also

problems

of

is

it

conventional

and

prudent

time

for

be

can

pumping allow

to

one

illustrates

subsequent he

can

acoustic

evaluating

the

When the

and

pipe

3.7

truck

cementing

of 0.9674

lead

slurry

Each

sack

volume

of

cu

blended

with

16%

bulk

901940

and

factor

pump

mixed

be

to

473

2%

with

and

the

sacks

lead

5%

and

bentonite

bentonite

given

is

cement

However

3.8 Thus

mixed

be

has

will

the

for

calcium

salt

and

the additional

and

ft

volume

of

3.2

four

that

hydrate

the

chemical Identify

cementing

ingredient

crystalline

phase

attacked

will

the

given

is

Lime

CaO

Silica

Si02

Alumina

Calculate

ft

by

the top

required the

float

to

plug

displace

collar

is

at

the top of the

the top

given

plug

before

casing The

from

time

the surface

12.415

API

maximum

minutes

minutes

flow

cementing or hours

time

is

83.8

35.6

the

Cementing

operations

are

Evaluation

complete

and

the

After

cement

cementing left

in

the

psi

The

weight If

strength

the of

water

water

the

content and

content

36

diameter

cement

14.5

tensile

string

cement 200 psi

is

do

sample

slurry

the

length

allows

under

placed

water pressure of

permeability

md strength

of

the

is

having

cm

of 2.865

Compute

psi

paddle

Bc

mIis when

20

the

consistometer

What

g-cm

800

is

hold

to

cement

in

Answer of

perform

to

minimum free

cement core

0.05 of

An

cements

required

rpm Answer

Class

cement

C3S

of

cement

content

cm and of

needed

drilling

content

150

at

the

in

0079

equipment for

fraction

weight present

0.083

stationary

rate

3.8

SO3

0.9

torque

consistency

2.6

2.7

the following

The

rotating

the 3.5.13

4.8 or

1.2

C4AF

water

differential

119.4

21.1

theoretical

water

assembly

600.9674 total

follows

as

loss

tests

Define

3.7

the

readily

66.5

trioxide

the

List

of 2.54

Thus

is

MgO

0.103

0.666

3.6

by

35.6

Identify the

Percent

Al203 Fe203

swer

to

250040

7r

cement

or

C2S C3A

3.5

placing

main

sulfates

or

and

normal period

each

the

products

or

the

standard

for the time

is

cement

forms reaction

Show

of

Weight

Magnesia

minutes

accounts

product

by water-containing

3.4

mixing time

that

Oxide

to

20

The

portland

hydration

portland

The oxide analysis of

3.3

respectively

1374301

83.8

the

for

in

in

water

with

tail

56.4 time

portland

be

47394002

mixing

when mixed

that

The

solids

of

phases

crystalline

the reaction

Ignition

total

manufacture

the

equation

Sulfur

The

logging

through the

primarily

and bulk approximate weight bbl and in one cement sold in

portland

71

cu

sound

the

is

Name

cement

901940.05

301

both

to

early

acoustic

the

by

Ferric oxide

60

for

sack

by

16

available

acoustically

travel

in

steps

What

volume

chloride

of

In

temperature are

strong

tail

chloride

calcium

Ibm/cu

56.4

slurry

salt

received

sound

four

List

901

is

cement has an approximate bulk

of

60 71

are

Table

of

slurry

ft

of

weight

flake

and

ap

pump

rig

the

hydration

Fig 3.16

phase

blended

be

will

The

the

one

if

of

capacity

used

strokes/mm

volume

for the

slurry

is

for

3.6

Example

in

ft/stroke

cu

Solution The sacks

time

cementing

mixing

ft/mm

60

at

operated

the

described

having

20 cu

proximately be

Estimate

operation

behind

Exercises

operation

3.1

cementing

in

tools

formation

be

will

cement

present

bonded

not

is

the

device indicating

of the

the

between the cement and the pipe

bond

cement

the

is

increase

an

logging

in

survey

completing

the exothermic

to

It

cemented

anticipated

temperature

cement

cause

will

addition

cement Example

When

the

The top of the cement

after

hours

liberated due

heat

reaction

casing

requirements

10

to

the

that

accomplished

pressure

by making

out

ensure

to

pressure-test

operations

drilling

displacement pipe

to

subsurface

drilled

been

maximum

located

from

well

have

practice

the

to

reflection

unforeseen

time

cementing

cases

all

time

always

Example

casing

in

3.7

well

average

volume

cementing

estimating

the various

for

cementing

slurry

The time

cementing

applicable of

the

in

properties

and

represent

cementing

operational

method

be

not

estimation

extra

slurry

depth

3.5

Fig

on the actual

be

to

some

the

well

cement

variables

good

the

been

evaluated

is

objectives

is

casing

discussed

the

place

to

important

the specifications

in

see

classes

conditions

rates

of

between

by the API

used

required

morc

design

relationships

As

Requirements

have

usually

cementing

of

portions

equipment

cementing

be

with

along

casing

known

to

you think

to

required is

estimated

have

support to

be

compressive

the casing

could

be

CEMENTS

111

supported

17

3.9 standard

and

types with

ASTM

the

and

Compare

cement

three

these

classes

used

types

the

in

composition different from

high-sulfate-

standard

of

5.19

gal/sack

defined

that

cf/sack

2.09

3.14 earth

and

3.15

3.16

cement of

weight sack

of

with

each

and

of

water

sack

the

is

Repeat

Answer

cement

of

Compute with

3.16

using

Ibm/sack

1.30

the

an

slurry

cement

Neglect

and

3.19

common

two

List

320

the

List

used

ditives

three

cement

and

common

four

3.22

Describe

cement

in

give

Class

hole

cement

of Class

HALAD-22A

on the

Answer

16.3

permeability

in

length

sand

instead

pressure flow

accelerators

rate

torque

of

38.2o

viscosity

for

density

slurry

for

Class

References

one example

Spec/ficalion

ad

lost-circulation of

Spec

Jan

Sandards

on

What when

or

3.24

in

is

to be

to

sack

place of

of

cemented

at

borehole

between the

float

2500

Class

OK

cementing

string

Sales

setting

collar ft

joint

in

deep

of

cement

is

and

shoe

of

is

Cements

Manual

Genent

cemen

of

ft

will

be

in

the

mixed

shoe

It

is

annulus with

Testing

t3

Part

Cementing

1-lalliburton

Services

Duncan

and

Cementing

Service

Tables

Haltiburton

Services

Duncan

Catalog

Halliburton

Services

OK

Duncan

Waiting-on-

Segregating

Formation Oil and Gas .1 195351 173 in the Gulf Coast Area Doherty \V.T Oil-Well Cementing Bull API Sec 4601933 Production Operations Oil- Well Goins W.C Jr Open-Hole Ptugback States API New York City Cementing Practices in the United

ID

an

API

Fluid nearing

13300

joint

the guide

be

Why

cementing

in and

depth

cement will

Well

for Minimum Determining R.F Method AIME 1946 165 175-188 Cement Time Trans of Casing Cement for Ctark R.C Requirements

used

9.625

40-ft

for

Farris

shoe

plug

OD

an

having

12.25-in

desired

important

no bottom wiper

Casing

8.535

of

purpose

especially

joint

Halliburton

for

cementing

squeeze

the

is

liner

on

Testing

1982

OK

the conventional

used

cementing

string

cement plug and 3.23

your own words

Data

Technical

and

Materials

for

Dattas

10

ASTM

each

filtration-control additives

techniques

placement

casing

Each

log

in

slurry consistency

PhiladelphiaI975 List

used

the

slurry

retarders

of

types

cement

in

3.21

in

yield caliper

increase

slurry

of

water

area

type

of

the

gal

474 sacks

cf/sack

cement

job

2.0-in

flour

5.8

of

the

fill

with

silica

slurry if

of sacks

of

then

liner

cement

Class

shoe

of

of the

effect

volume

1.51

lbm/gal

the

and

weight

the

slurry required

and the number

density

by

desired

is

mixed with

be

density

washout

average

needed

the

given

cf/sack

cement

salt

of

each

for

barite

the

18Vo

It

35ko

containing will

containing

What is the 294 slurry Answer 44.3% of

yield

space

cement

be

used

be

the

opposite

to

and

casing

shoe

in annulus

is

hole

Problem

in

the will

joint

and the guide

HALAD-22A

Compute

tn

between

shoe

in

an 8.5-in

described

as

ft

ft

Nomenclature

requirements

and

Class

l.2Wo

15300

preflush

annular

1.09

Class

of

blended

strength

of

will

blend

Ibm/gal

ID of 6.276

an

overlap

collar

ft

16.7

salt

not

additives

the density

using barite

common

two

List

cement

be

105%

cf/sack

pozzolan

cf/sack

40.6

2.21

and

Problem

3.17 barite

total

of

40-ft

float

1000

The

at

of

rate

at

1.5

the

mixed

be

minutes

13300

at

300-ft

diameter

gal/lO% diatoma

of 3.3

should

mix

percent Ibm/sack 1.26

set

of

the

and

thus does

arid

having

depth

desired

is

volume

lbm/sack

diatomaceous

following

the

is

liner

at

factor

the

slurry

required

Answer 159

sacks

and

use

of

What

9.3

using

Ibm/sack

maximum

the

3.18

that

Compute

Casing

Using and

the low-specific-gravity

as

Use the water

cement

3.9

3.13

Ibm/gal

barite

cement Table

17.5

to

1092

the

displaced

phase

cement

dry

significant

cement can

that

excess

no

blended

Compute

of

yield

and

the water

to

cemented

the

the weight

compute

increase

to

use an

7.0-in

shows

perlite

desired

is

cement

slurry Answer

the

and

3.25

to

Class

bentonite

of the slurry

yield

19

sacks/mm

has

of

weight he

will

density

cement

of

20

the

liner

slurry

sacks

additive or

by

salt

clispersant

the

time Assume

added

3.24

156

and

of

Class

requirement

Answer

expanded

It

cf/sack

blended

Exercise

Identify

gilsonite

of

class

of water

the

of

tween the

3.9

of bentonite

water

earth

ceous

of each

the density

for

be

the

of the

Repeat

this

yield

of

cf/sack

4.97

l02.9ko

instead

solid

should

Compute

mix

1.17

by adding

Table

in

but

slurry

of

with

for

gal/sack

through

density

to reduce

lbm/gal

given

percent

be

Answer

normal amount

the

requirements

bentonite

each

and

Classes

12.8

bentonite

6.32

Classes

and

yield

with

desired

is

water

cement

and

API Answer

by

to

cement

the

mixed

for It

of

be

Compute

cement when

3.13

content

preparation

slurry

for

gal/sack

water

Class

for

Ibm/gal

in

Classes

for

4.29

gal/sack

the

used

cement

class

Class

API

the normal

List

cement

cementing rate

of

quantity

the

18%

added

is

small

on

bbl/min

3.11

as

the

density

portland

cement

3.12

with effect

which

to

water

number of

the

is

of

gal

waler API cement

cement

resistant

tensile

industry

How

3.10

Yes

classes

standard

eight

types of

construction

Answer

psi

the

List

Why

cement

the

by

strength

4.3

1959 10

Sutton Flow

1984

193-197

DL. After 84

Sahins

Cementing

and

92

and Oil

Faut rind

Preventing Gas

Dec

tO

Annular

Gas

Dcc

17

and

APPLIED

DRILLING

ENGINEERING

112

SI

bbl

cp cu cu

ft

ft/ibm ft

gal gal/cu

ft

1.589

873

1.0 2.831

685

6.242

796

F32

EOi

m3

E--03

Pas m3

E02 E02 E0l

3.048

8.345

gal/Ibm

Conversion Factors

Metric

412

E-03

1.336

806

E02

dm3/m3

4.535

ft

psi

rn

3.785

ibm

ibm/gal

rn3/kg

m3

2.54

ibm/cu

sq

xc

1.8

in

ft

Conversion

factor

is

exact

E00 E00

drn3/kg

cm

1.601

846

E0i E0i

1198

2ft4

E02

kg/rn3

6.894

757

EI-00

kPa

9.290

304

E02

m2

E-00

cm2

6.451

sq in

404

924

kg kg/rn3

Chapter

Drilling Hydraulics

and

Chaps

In

provided

and properties

tion

this

and will

the

chapter

the

of

be

drilling

between

hydraulic

the

coinposi

and cement

fluids

relation

subsurface

about

information

the

forces

slurries

in

the

well

developed

Subsurface

science

of

mechanics

fluid

is

to

the

pressures

are

very important

well

depth

in

engineer

created

in

of

presence sidered

these

the

chapter

surface

mon

fluid

condition

pipe

tral

string

which

the

string

and

which through

the

complicated

ing

muds and

the

relations

on

While

in

this

was not

it

posed

in this

of

transport fluids

to

in

of

the

subsurface

at

the

cross-sectional

the

is

forces

hole of

in

the

on

force

above

fluid

considering

vertical

depth

for

with

given

fluid

by

area of

the

on

element

the

element

there the

by

is

an

force

upward

below

fluid

the

ex

by

given

in

p.A

F2

in

listed

of

drill are

chapter

rock

fragments

surface by

In

the

addition

downward

weight

of

gFven

by

force

the

fluid

element

is

exerting

the

selection and

parallels

the

carrying

in

which

concepts

best

the

serves

engineering

the

development

mechanics

needs

given of

hydrostatic

the

of blowout

due

of

the

drilling

ex

fluid

is

the

is

shown

at

specific

rest no be

must

in

shear

weight forces

of

exist

the

fluid

and

the

Since

three

the

forces

equilibrium

pipe

pA

fluids

fluid

This approach

students

where

presented

fundamental

chapter

beginning

tend

nozzle

vertical

are

FVAiD

preven bit

to

applications

in the

fracture

slurries

capacity

of

or

F3

include

pressures

tubulars

aspects

drill

applica

applications

pressures

surge

the

developed

more important

cement

of

displacement

all

fully

concepts

These

well

the

several

formations

illustrate

the

detail

or collapse

movement The order

to

fundamental

several

of

burst

tion size

included

the

the

presented

calculation to

behavior

erted

down

conditions

third

fluid

by

the

The downward

by

times

for

4.1

easily

pressure

pA

F1

pipe

operation or

of

area

exerted

Likewise cen

the

central

up

element

obtained

be

Fig

diagram

an

pressure

can

most of

variation

In

operation

the

moved

being and

Also

feasible

of

chapter

are

ing

down

tripping

is

formation

applications

tions

and

element

com

three

Liquid

determined

are

The

column

fluid

cross-sectional

sub

the

include

circulating

and

con

be

in

fluid

drilling

ing

for

fluid

non-Newtonian

governing

immiscible

well

the

The second

cements

The

determine

to

pumped

string

the

cement

conditions

well

rest

annulus

by

pipe

must

developed

both

being

pipe

fluid

are

and

are

central the

at

are

fluids

up

These

which

in

be

tubular

encountered

problem

needed

will

pressures

or

pressures

well

every

and

mud

drilling

relations

well conditions

static

wellbore

subsurface

almost

in

of

presence

fluid

large

slender

long

the

by

strings

this

the

Extremely

pressures

ponditions

free-body

acting drilling

well

static

the

The

Pressure

Columns

properties

fluid

present

4.1 Hydrostatic

ot

Expansion

of

ment volume

the

AD

second

term

and

division

by

the

ele

gives

drilling

dpFdD

4.1

APPLIED

ENGINEERING

DRILLING

114

DO

4.1Forces

Fig

acting

element

fluid

on

ANN ULUS we

If

are

fluid

water

salt

Eq

of

Integration

such

liquid

as

be

4.1

considered for

an

mud

drilling

constant

with

incompressible

depth gives

liquid

pFDpo where

the

face

4.2a

Pc

pressure well

is

closed of

weight

of integration

constant

D0

pressure

zero

is

and

the

or

and

negligible

is

compressibility

can

weight

specific

with

dealing

unless

in

liquid

blowout

the

well

the

is

is

field

units

of

Thus 4.3

the

specific

and

is

is

foot

Thus

per gallon

Eq

in

weight

the

fluid

4.2a

in

pounds

field

is

given

by

4.2

4.2h

p0.052pDp0

In

many

gas important

equation

is

determination

the

The

density

fluid

cient

density

each

permeable

pressure of This

to

umn

in

the

mation

the

depth

leak

the

the

in

in

fluid

some

the

the

to

of

than

fluid

is

column

opposite

umn

pore

well

enter

the

is

because

the

defined

the

fluid

prevent pore

can

for

fractured

in

static

static

above

fluid into

the

gas

col

liquid

with

changes

other

fonna

changing

be

described

using

the

real

gas

4.4

pVznRTzRT

the

frac

where

volume of

gas

universal

Calculate

flow

from

the

static

permeable the

formation

mud

density

stratum fluid

Eq

is

at

required

12200

8500

ft

absolute

constant

if

mass

gas

of

gas

molecular deviation

weight

ibm/gal

gas behavior gas

is

one

in

deviates which

are

of

measure

is

from

there

and

factor

The gas deviation factor

8500

0.0a212200

gas

temperature

psig

4.2b

P-------------13.4 0.052D

depth in

in

absolute pressure

pressure of

Using

than

while

subsurface

col

gas Solution

surface

by

moles

the

the

from

is

gas

some cases

In

formations

gas

to

from well

well

pressure

tured formation

Example 4.1

psig

operations

the

density

gas

equation

the

of

more complicated

drawing

well

wellbore

Gas Columns

in

of pressure with

variation

gas behavior

the

to

lbm/gal

the

atmosphere

completion

portion

in the

may

gas

The

of suffi

the

least

injected

cases tion

at

The

drilling

from

into

circulation

and

drilling in

schematic of

the

fluid

Pressure

stratum

any of

to

open

mud

permeable

fracture

the

rapidly

be

well

the

density

cause

to

must

greater

in the

fluid

pressure

drilling

proper

well

be

However

allow to

hydrostatic

pressure

sufficient

drilling

would

fracture

in

illustrated

is

the

of

to

formation

Fig 4.2

to

the

cause

must not be

exposed

column

stratum

problem

shown

of

application

is

no

Hydrostatic

present

An

is

13.4

least

at

formation

mass

pounds

units

well

the there

of

be

must

density

flow

the

per square

in

density

mud

the

when and

per

system

fluid

specific

by

FO.O52p

inch

well

the

prevent

where

4.2The

Fig

surface

preventer

given

is

sur

the

static

flow The

to

trying

to

equal

the

Normally

that

no

of an

ideal

attractive

how gas forces

much

An

the

ideal

between

DRILLING

HYDRAULICS

molecules

gas have

been

and

petroleu00

assist

of

in

be

can

natural

available the

chapter will

more

gases

function

as

of

be

made

on

the

drill

4.4

is

ft

in

pressure

given

of

depth

at

4.2b

Eq

by

annulus

the

14.74695

P2 0.0529.0lO000-lThe pressure Eq 4.6

in

time

at

tubing

of

depth

psia

10000

ft

is

given

by function

as

expressed

Eq

10000

simplifying

generally easily

The

Solution

in the

developed

being

rearranging

gas density

for

readily

this

focusing

concepts

density

gas

pressure by for

In

are

gas behavior

student

the

factors

experimentally

pressure and I3

ideal

hydraulics

The

deviation

literature

assumption

ing

Gas

determined

temperature

to

115

this

Solving

of

1610000

equation

yields

l000e

Pt

Thus

pM

154411460140

1188

pressure difference

the

given

is

psia

by

4.5a zBT

from

units

Changing units

P2Pt 469511883507 consistent

units

common

to

field

gives

which

is

below

considerably

the

psi

collapse pressure of

the

tubing

The be

pM p-

of

density

the

approximated

in the

gas

Eq

using

at

tubing

4.Sb

the

could

surface

follows

as

4.Sb 80.3zT

100016 where pounds

is

expressed

per

square

in

mass per gallon

pounds

inch

and

absolute

in

is

It

length of

the

tion

for

used

incompressible

highly

pressured

within

the

the

and

4.3

of

pM

0.052

dp

be

4.5a

Eq

taken

not

is

into

can

ac

short

or

with depth

Us

the

variation

account

0.0520.33

which

is

we

great variables

can

within

treat

the

gas

column

constant

as

equation

not too

is

this

in

Eq

using

the

density

10001172

of

psi

the

psia

obtained

answer

4.6

Separating

of

in

of

sections

with

pressure

well

the

operations

drilling

different

depth

column

fluid

The

densities

fluid

type of complex

in this

column must be determined

fluid

yields

Pressure

Columns

Fluid

several

variation

by separating

the

effect

segment For example consider the com in Fig 4.3 If the pressure at plex liquid column shown the of Section is known to be then the pressure top

dD l544zT

P5

16

Eq

many

contains

of each

P1

use of

the

ll0000

Hydrostatic

Complex

the above

in

within

more complex

4.3

dD

in

that

gives

During If

note

to

interesting

obtain

we

zT

80.3

is

4.2b

be

in

loss

gas density

the

equa

4.2b

much

column

the gas

variation

and

great

hydrostatic

by

without

gas column should

Eqs 4.1

ing

4.5b

However when

curacy

given

not

is

the

psia

liquids

Eq

with

together

column

gas

1000

above

is

gas pressure

the

Ibm/gal

degrees

Rankine

When

0.331

80.31600

in

is

at

the

fluid

bottom

of

Section

0.052

p1D1

be

can

D0

computed

Eq

from

4.2b of

Integration

this

equation

gives

Pm

MD

D0

The

l544zT

4.6

Poe

pressure to

equal

the

interface

the

Example 4.2 gas ft

contains

tubing

filled

with

in

methane

vertical molecular weight 16 to depth of 10000 The annular space is filled with brine 9.0-lbm/gal ideal

Assuming which

the

terior

140F

behavior

pressure on at

pressure

000

is

If

will

pressure

gas

exterior

tubing

pressure

psi

well

and

psia

the collapse the

tubing

10000 the

compute the

tubing ft

mean of

resistance

collapse

if

due

to

the

gas the the

the

amount

exceeds

the

surface

high

is

of

at

any the

the

at

of

the

capillary

reasonable

at

weilbore

the

essentially

Even

be

if

would

geometry can

top of

--D10.052p

0.052p2D2

is

pressure

of Section

bottom

pressure

Section

top of Section

the

an be

Thus

expressed

Section

1D1

D0p0

by

in

tubing

temperature tubing

P2

present

for

pressure terms

bottom

the

pressure

is

negligible

at

D0p0

In

general

can

be

the

pressure

expressed

any

vertical

distance

depthD

is

8330

external

at

by

pp6O.052

pD1D1

4.7

116

APPLIED

po

Do

DLg

ENGINEERING

DRILLING

atmospheric

p0

pressure

7000

feet

9pp Brine 8.5

.c

and

D4

the

in

change

known

the

4.4---Viewing

hydrostatic

when

pressure

feet

feet

added

is

the

to

moving up through the

and

negative

is

subtracted

is

1700

manometer

as

pressure

hydrostatic

D1 D1

section

well

conversely

pressure

feet

bOO

I67p1

Fig

300

ppg

from

in

change

known

the

pressure

PaPO0M52 on 4.3A

Fig

complex

column

liquid

Since

the

known

Pa266 It

is

desirable

frequently

shown

in

at

pressure terior

Fig 4.3

usually

view

to

represented

is

when

the

by

fluid

for

the

and

and

of

side

right

balance

written

be

unknown

the

usually

in

represented

is

manometer

the

then

can

annulus

the

hydrostatic

he

Eq

pressure using

the

by

ing

given

during

normal

pressure

to

helpful

4.7

equivalent

This

mud

tains

on the

An

4.3 in

bottom

The

mud

300

of

ft

12.7-ibm/gal 16.7-ibm/gal cement brine

be displaced

will

Calculate

displace

the

more

if

easily

sections

moving

well

The

pressure to

the

down

and point

through

moving of

the

Pe

which

is

the

so

by

that

ft

of of

ft

The equivalent at

is

written

through

unknown

section

is

Fig by

always

density

should

be

referenced

depth

specified

complete Example 4.4

system

mud

9-ibm/gal

to

casing

fluid

the

calculating

defined

an

at

high-strength with

casing

manometer

as

by

accomplished

to the

to

open

annulus

1000

and

the

the

1700

pressure required

pressure balance

hydrostatic

known

complex viewed

is

sometimes

4.8

10000

after

The

that

is

column

0.052D

of Solution

fluid

fractur

con

placed

is

dcsigned from

flush

cement

cement from

the

mud

from

pump

well

column

density

It

operations

complex

for

that

without

be

to

well

string

is

displaced

cement

high-strength

The

is

withstand

guidelines

density

Pe

be

will

is

string ft

the casing

8.5-Ibm/gal

filler

casing

10000

operation

cementing

10.5-ibm/gal

of

depth

mud when

10.5-Ibm/gal

by

ly

intermediate at

place

will

drilling

single-fluid

allows

maximum mud

depth

compare

equivalent

Example

the

often

area

given

for

at

mosphere

cemented

in

developed

mations

Concept

Density

Equivalent

the

pressure

known

terms of

then

psig

is

psig

Field experience

of

side

4.3.1

to

manometer

Po

pressure

in

drillstring

left

0009.0lO000

16.71

system

solving

The

well

in the

point

well

the

manometer

as

given

700

12.71

Calculate for

cement

the

Example has been

equivalent 4.3

for

displaced

4.4 at

starting

pressure is

The

well

casing

Solution

At

depth

of

10000

ft

When positive

pO.0529OlO000

12665946

psig

depth

conditions

completely

the

fluid

at

density

static

understood

the various

D1 Di

the

ft

from

the

HYDRAULICS

DRILLING

Eq

Using

117

4.8

where

5.946

for

Pe

11.4

Ibm/gal

units

field

Eq

in

mean density

4.3 and

of

weight of

substitution

the

this

with

combining

gas

expression

Eq

4.1

yields

10000

0.052

molecular

average

common

For

_____________

the

is

D2

pN.RT

P2

dp

4.12

0.052p1MN 4.3.2 in

Effect

For

gases

mud the

from

through

the

of

contact

do

lhe the

influence

calculation

is

given

forma

or

the

Eq

in

supported

be

corn

with have

that

in

of

mean

of

Sec

of

several

4.9

i1

the

for

as

long

ponent tire

of

length mixture

the If

one

the

presence

depth real

with

be

is

the

gas

to

cut

of gas

with at

Thus

term

of

mud

gal

given

the

low said

to

of gas

drilling in

the

fluid

are

to

the

at

volume

column

is

given

use of

dispersed the

having

of 50

given

in

the

or

frac

4.10

Eq given

Thus

at that

gas density the

effective

density

point of

is

the

defined mixture

by

material

zN1RT

this

can

be

pressure

density

of 0.7

while

of is

move of

9.0 ideal at

the

the

The

Solution

at

and

that

both

same annular solids

drilled

hydrostatic

mud would

depth

of

is

that

the

is

F9.87521 4.11

being

the

rock

cut

as

the

mud

The

4144

60/

3.31

gas

lbm/gal

by

psia

rate

of

/7.48\ ------

501

mud has

the

exerted

at

mean water

be

drilled

in

formation

that

pl4.70.OS2I4l2O00875l formation

of

gas and

velocity

21.9

ft rate

change

drilled

assume

the

head

the

and rate

at

at

formation

the

03

12000

circulated

the

by

Also

that

drilled

Assume

iiiud

lbm/gal and

being

Calculate

caused

the

is

being

drilling

620R

is

bit is

fluid

sandstone of

saturation

water

9.875-in

entering

temperature

The

pfMNp

In

4.2b

is

by

PPffgPgfg

4.11

low-permeability

0.20

pressure

hydrostatic

14-lbm/gal

the

of

drilling

gal/mm

density

zNRi

4.5a

varia

the

ignored

Eq

by

gas/liquid

in hydrostatic

change

Eq

saturation

with

14-lbm/gal

behavior

by

NVRT

addition

the

massive

4.5

ft/hr

tings

In

and

porosity

methane gas

350

cut

through

fluid

but

drilling

gas

made

be

point

constant

pressure

hydrostatic

can

density of

due

given

the

elevation

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long

be

pressure can

computed using

Exarnple

density be

constant

not very

an

for

with

if

the

of

density

the

gas

be

and

density

used

pressure

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pressured with

be

must in

change

column

mixture

the

Eq

procedure the

fluid

highly

is

4.13

en

the

constant

pressure

moles of

average

remain

not

have is

solids

can

of

P2 appears within This means that

pressure

com

the

throughout

divided

finely

does

If

gas equation

constant

decreasing

determination in

liquids

As

the

in

of gas density

assumed

density

respectively and

essentially

of gas bubbles

associated tion

will

measured

is

The

column

the

also

are

essentially

component

decreases that

is

component

gas

component

components

density

volume

that

calculation

gas-cut

case

of

fraction

4.15

unfortunate

is

tion

volume

4.14

components

mixture

and

4.13

bNKr

Chap

i1

mass

4.12

and

computed using

determination

the

con

Eq

of

Integration

pfMN

a0.052

set

pV

are

column as

where

iterative

andf

treated

D2D1P2I21

logarithmic1

where

and

values

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over

great

be

can

gives

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i1

too

not

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they

the

by

rn

and

grain-to-grain

by

be

interest

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effect

4.2b

of

of

stants

the

as

variation

length

settling

pressure

can

mixture

the

prcssurc can

discussed

of

solids drilled

fluid

particles

mixture

procedure

and

velocity

hydrostatic

ideal

density

the

density

arc

bit

are

the

rock As long

by

However

and

not

The average

the

terminal

liquids

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in the

or

cements

dividcd

finely

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up

fluid

fluid

of an

and

hydrostatic

the

the

density

pure

fluids

also

suspended

mixture

the

of

out

with

and

annulus

on

by replacing

density tled

water

their

at

materials

foreign

drilling

contained

are

fluid

deal

broken

were

materials

puted

of

in the

rock

that

fluids

foreign

the

both

mixture

drilling

solids

Gases If the

example

primarily

tion

and

Solids

seldom

engineers

Drilling

The

Entrained

of

Fluid

Drilling

gal/mm

12000

ft

of

APPLIED

ENGINEERING

DRILLING

118

DENSITY

AVERAGE

OF GAS

CUT

MUD

Ibm

/aI

4.14

Eqs

Using

and

4.15

gives

Il

a0.052 160.00023110.7312 2000

and

620

4000 4.7

79

000

37 39

6000

blo.00023 1413

Since

the

well

8000

must

be

assumed well

5Annular

Fig

Drilled

solids

are

density

added

being

for

plot

water

is

fluid

drilling

P2P1

psia

0.7312

Thus

added

the

to

fluid

drilling

The

of

density

and

water

the

drilled

11946 11878 11900

the

fluid

drilling

after

addition

the

of

the

be

due

4.5

entering

mainly

the

to

drilling

fluid

at

rate

of

3.3l0.20.70.464

the

Assuming approximately

gas

8751

is

to

drilled

the

given

by

psi

the

that

the

leaving

density

was due

resulting

from

to

fluid

the

as

theoretical

surface

ample 4.5

is

in

given

that

4.11

by

was

caused

the

drilling

of

density

This

of

lowering

entrained

gas the

pressure on

hydrostatic

density

Eq

by

usual

is

understood

not

the

surface

would

be seen

approached

it

mud

fluid

expanding

rapidly

decrease

the

of

head

hydrostatic

confusion

surface

the

at

in

drilling

was

The

lowering

well

the

the

this

past

severe

loss

of

personnel

by

drilling

added

being

In

drilling

ibm/gal

is

due

mud

the

contamination

negligible

fluid

gas

head

hydrostatic

indicates

normal

to

many

3502.650.2

4.5b

100.37

material

Example

would

solids

ly

Methane

12046 11978 12000

100.34

in

change

D2D1

Pi 100.43

gal/mm

143502l.92.6590.2

14.057

the

to

P2

p871687Sl3S

3.310.20.30.2

were

forp2

was equal

at

of

rate

values

ln

15.72

8750 8700 8716

at

gal/mm

being

iterative

an

various

P2 manner

pressure

ft

P2

fonnation Formation

in

D2

calculated

12000

bottomhole

4.13

below

table

the

of

depth

rateof

3.3110.22.65

the

Eq

from

surface

the

atmosphere

the

The

psia

4.5

Example

the

to

in

until

to

open

14.7

estimated

As shown 0000

is

is

pressure Pt

11.5

The

Ex

in

as

gal/mm

ideal

is

psia

and the

the

gas

/5

formation

pressure

given

density

is

14.7

l0.00023180.3620

Eq

by

is

7.9

lbm/gal

875116 2.8

As one

Ibm/gal

80.31 .o0620

past

Thus

gas mass

the

rate

entering

the

well

given

is

the

by

driller

would

sity

drilling

surface

0.08

rnol/min

not he

16

As

shown

mud Since

gal/mm

the

mud the

is

moles

being

circulated

of gas per gallon

at

of

rate

mud

is

of given

350 by

the

tor

N.O.OOO23l

mol/gal

from

fear

4.5

The

to

the

the

117.6

the

gas

its

the

in

In

this

in

at

of

part

with

by

fac

For

the

volume size

off

annular

density

decreases

unit

should

shallow

pressure

of the

pump

the

pressure doubles

original

on

blowout

that

annular

the

density

observed

decreases

volume

causes of

mud den

in

excited

with

relatively

hydrostatic

psia

one-eighth

flow

will

loss

potential

shows

increase

rapid

350 to

of

the hydrostatic

increasing

decrease

in

get

increase

significant

only

because

two when

14.7

4.5

Fig

to

mud was

clearly

well

the

occur

occurs

ample

0.081

in

density

of

gas-cut

of

unless

annulus

depth

practice

Example

done

to

when

because

However

2.80.464

fluid

amount of

monkey

even

was common

it

this

remarked

cause

ex

surface

of gas

to

HYDRAULICS

DRILLING

119

PUMP

4.6Schematic

Fig

of

control

well

operations

Fig

4.7Scbonatjc

of

well conditions

initial

control

well

during

operations

Annuar

4.4

Pressures

Well

Control

One of

the

pressure

more important

when

the

into

well

the

shown

weilbore

to the

well

the

Fig 4.6

in

above

the

tional

of

that

formation

to

profile

for

in

helps

the

trol

circulated

is

annular

the

the

addi

by

of

just

slightly

vs

pressure an

total

of

frictional

used

rates

can

calculations

behavior

C3

are

well

con

made

be

if

on

of

pit

gain

kick

the

kick

fluid

is

zone

can

and

the

Vk

well

diameter

the

is

volume

pit

smaller than

is

the

be

an

the

preventer

by

opposite

Lk

volume

ascertained

blowout

volume

as

closing

from

expelled

kick

easily

Fig 4.7

in

be

recorded

is

after

shown must

the

closing

annulus

the

kick

kick

is

drilling

If the

most annulus

the

conditions

present

before

the

estimated

fluid

usually

Assuming

we

and

collars

drill

in

expressed

annular

capacity

con

approximately

obtain

4.16

LkVkC3 where

Lk

of

kick

the

length of and

zone

kick

the

C3

the

is

collars

drill

the

volume

the kick

If the

annulus

the

kick

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using

the

is

zone

V3

annular as

expressed

is

the

volume of

the

length per

unit

capacity

volume

losses in

kick

pit

well

initial

equipment

hole opposite

contingency

pressure

circulating

most

by

kick

appropriate

not

are

used of

of

capacity of

the

of

observed

pressure

calculations

procedure

entered

gain

length

terms of

volume

the

annular

is

fluid

the

monitoring

the

bot

fluid

kick

volume of

pit

control the

kick

the

of

The

will

the

preventer

volume

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well

determine

The

the to

pressure

often

plan during

density

the

annular casing

the blowout

into

the

from

of

schematic

the

However

estimated

that

density

slug

he

known

not

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annular

of well

purpose

gas or liquid

assuming

stant

called

adjustable

for

specified the

generally

calculation

predominantly

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in

flow

that

maintained

the

using

be for

operations

can

pressure

The density

from

pressure

stratum

so

control fluid

drillpipe

nulus

results

proper

choke

knowledge

prior

at

remain

weaker

uncontrolled

pressure

control

annular

operations

hydrostatic

is

The

pressure

preparation

small

generally

well

the

well

Since

plans

Thus

in

com

hydraulic

the

kick

The

prevent

often

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surface

today

operators

the

high-pressure

occurs

Although

required

the

surface annular

fluid

drilling

which

in

adjust

the

to

is

flowed

fracturing

stratum

the

surface

to

composition

well

actual the

However

of

and

made

calculations

Kick

ning

circulating

times must

all

fluid

danger

from

formation of

plot

at

the

at

an

higher surface

pressure

maintained

must

composition

pressure

fluids

operations

have

formation

exposed

pressure of the

well the

exposed

fluids

is

tomhole

of

an

stratum

strategy

above

is

blowout

underground

fractured

the

is

well

illustrating

that

choke

formation

also

of

Fracturing

the

followed

removed by

be

an adjustable

factor

plicating

fluids

must

pressure of

pore

influx

stratum

Formation

pressure of

control

the

well-control

during

generally

through

bottomhole

schematic

must be

Kick

annular

The flow of formation

kick

paths

of Well

into

bottomiole

pressure

hydrostatic

procedures

flowing

constant

choke

the

operations

begin fluid

called

is

of

determination

emergency

fluids

drilling

flow

hydraulic

the

to

formation

displacing

nular

control

well

pressures during refer

tam

applications the

is

relationships

operations

During

Operations

opposite

zone

Lk

is

larger

the

is

given

the

than

collars

drill

total

then

capacity

the

of of

length

by

pressure equations

L3\ 4.4.1

Kick

Identification

The annular pressure well

control

of

composition causes is

higher

kick

pumped lower

to

and the

hydrostatic

the

will

be

to

large

fluids

pressures

gas kick must surface

that

depends

kick

annular

because

true

liquid

profile

operations

In

observed

liquid

on gas

kick

lower density

allowed

to

of

factors

in the

during

extent

general

than

has be

Both

pressure

4.17

LkL3Vk__jC2 C3

these

annulus

expand

to

where L3 the

This

expressed

than as

result

Thus

the

kick

it

on is

is

the

given

in

main-

is

annular

Pc

as

initial

the

length

of

of

the

hole

per

unit

total

capacity length well

system

the

drill

volume

fora

collars

opposite

uniform

the

drill

C3

is

pipe

pressure balance

mud

density

by

O.O52

and

PmTlPctp

Pm

APPLIED

120

520

blowout zone

be

can

thus

ft

2.9

C0

2.9

C0

ft/bbl

amount of

37

Mud-Gas 20 bbl 25.5

Mixture

Gas

of

bbl

Mud

of

28.6

C0

4.6

ft/bbl

8.5

bbl/min

rels

of

the

are

closed

are

of

the

nular

After

720

of

4.8Schematic

4.6

Example

for

example 900

the

this

for

expression

the

of

density

kick

the

Pc

4.18

If

assumed

capacity

kick

fluid

in the

may

of

slug should

the

kick

viewed

as

with

volume

be

can

the

formation that

estimated

was

using

the

of

be

density

achieved fluids

detection

is

drill

collars

ft

of

is

The

fluid

28.6 total

bbl

130

is

kick

the

the

illustrating

The

geometry

total

this

of

capacity opposite

is

hbl

mixed

the

Fur

quan

than

less

drill

collars

ft/bbl

572

the

28.6

as

the

slug

total

then

annular

Thus

ft

the

of

density

kick

the

fluid

is

given

by

fluids

720520

Pk96

2.9

Ibm/gal

0.052572

as

should

results

If

it

is

be

assumed

mud pumped

that

while

as

interpreted

fluidi.e

kick

density

indication

an

of low-

gas the

the

kick

fluids

was

well

are

mixed with

the

flowing

bbl8.5

bbl/min3

min45.5

hhl

Eq

4.17

density mixed

The

length

of

mixed zone

is

given

by

as

mud

can

be

Lk90045531.Sl29lO8l

ft

expression Using

flow

bbl

Eq 4.18

Vk20 kick

The minimum kick

entered

fluids is

Eq 418

volume of mud

the

20

Lk

The

density

estimate

known

with

dif

accurately

the

fluid

annular

significant

of

kick

the

the

4.19 the

of

Fig 4.8

kick

opposite

read

solids

computed using

accuracy if

is

not

mud

drilled

represented

rough

in the

do

the

that

of

Hole

length

effective

than

mixed with

is

small

is

kick

Vqt where

900

calculation

often

the

of entrained

only

Some improvement calculation

Also greater

often cannot

and

Thus be

slightly

fluid

kick

the

mud

volume

kick

the

in the

pressure gauges

because

drillpipe

that

Using

determination

pressures be

densi

kick

indicate

errors

large

when

the

low

at

The an

ft/bbl

indicate

liquid

cause

the

addition

thermore tity

make

gas and

should

lbm/gal

can

should

Ibm/gal

predominantly

density

density

about

predominantly

can In

is

about

factors

accurately

mud

fluid

is

than

less

than

fluid

capacity

129

ft

volume

the

greater

annular

is

the

initial

casing

ft/bhl

is

it

0.052

density

initial

Pdp

_______

Pm

The

period

an

stabilized an

of

bar

preventers

drillpipe

density

31.5 28.6

ficult

is

of

rate

3-minute

and

psig

recorded

the

collars

drill

yields

washout

the

that

depth

at

blowout

the

pressures

drillstring

in

mud

over

pit

and

520 are

the

given of

ft

900

Pk

the

schematic is

the

in

of

psig

the

Solution

of kick

volume

flow Twenty

to

begins

stopped

opposite

Compute

capacity

Fig

is

capacity opposite

ft/bbl

Several

the

if

enters

vertical

at

9.6-Ibm/gal

well

gained

pressure

casing

drilled

being

is

the

pump

pressure of

kick

Since

gas

mixture

predict

circulating

when

mud

before

well

while

ft

drillpipe

the

formation

of

density

even

occurs

mixing

when

the

bbl

10000

ty

natural

to

equations

low

too

Exaniple

that

related

mixture

the

ft

Cdp

kick

be

then can

using

fluid

pump is not operating well Eq 4.20 tends to

9.Sppg

P1

4.20

mixed zone

the

kick

significant

Pk

using

mean density of the kickcontaminated be computed using Eq 4.18 The mean density

to

of

ft/bbl the

Solving

kick-contaminated

the

the

allowing

zone

Dl0000

estimated

VGqt

720

3500

The volume of

preventer

ENGINEERING

DRILLING

rate

time before

of

the

stopping

pumps the

and

pump

td

and

is

the

closing

kick the

given

Eq

418

the

mean

density

of

the

by

720

520 6.04

0.052t081

Ibm/gal

mixed zone

is

HYDRAULICS

DRILliNG

Since

column

the

under

mixed zone

fluid

of

density

density

is

mean

the

high pressure

kick

the

of

121

using

1081

only

density

can

be

for

the

equations

long and

ft

related

to

the

Similarly

3500

of

ft

9.613.56

ibm/gal

0.0523500

2Op 25.59.6 After of this

for

equation

kick

the

fluid

density

hole

yields

1.5

This

The indicates

that

kick

the

fluid

is

true

kick

the

ditions

above

will

the

gas

of

the

this

region

the

When

bottom

of

gas kick

must be

remains to

of an

ex

to

annulus

the

is

This

density

the

hole and

determined it

using the

usually

is

continuous

as

the

1677

Again

to

real

this

bottom

of

that

does

the

gas

bottomhole

formation

the

region

ample 4.6 well

and

shut-in

of

hhl

and

mud

kill

50

psi

use of an

through is

conditions

that

the

while

at

formation

casing

than

the

volume

gas

can

region pressure

as

an

for

slip

Ex

For

ideal

at

depth

5200.0529.6l0000

the

20

51214.7

bhl

the

3244 of

length

of

mud

pressure

density is

given

required

to

gas

overcome

the

______________ 0.05210000

9.6 10.6

ibm/gal

the

gas

is

given

by

33.9

hbl

14.7

gas

region

is

given

by

ft

gas

is

given

by

Eq

4.5b

324414.716

pM

by

80.3zT psig

this

the

Lg33.912943 The density of

8ft31460

140

ibm/gal

formation

The

by

5200.0529610000

ft

the

140F

1.08 The

the

higher than

the

and

of

5512

psi

from

psig

volume of

the

behavior

gas

Pg Phh

50

is

the

pressure

Assume

given

computed is

at

pumping

choke

is

gas

bottomhole

temperature

ideal

pressure

after the

the

The pressure

be

which

contain

will

pressure of

500.05210.62687

equivalent

formation

surface

constant

the

seat

kill

seat

casing

compute

maintaining

adjustable

gas behaves

The

Solution

at the

higher

methane gas

at the

Also

in

to

density required

density

would occur

that

pressure

kick

equivalent

well

density

300

Compute

the

mud

the

by

given

is

mud

9.6-ibm/gal

0.0529.6l 677 3244

kick

not

described

con

will

pressure

5512

Pg

equa

the

the

annulus

was displaced from

that

of

of

gas

that

kick

the

bbl

130

is

ft

in the

approximate

compute

This pressure occurs

consider

the

by

10000268716775636 Example

of

ft

the

The

fluid

point

length

assumed slug

of

length

above

in

mud

the

given

mud mud

new

the

The

region

needed

requires

of each

the

involved

is

of 9.6-ibm/gal

methane gas

known

and

bbl

L213012.9

the

between

relative

in

130

The

convenient

point

the

slightly

operation

pressure

length

volume

the

bottom

capacity

driuistring

90017o3l.5l2.92687

drillpipe

to

con

well

value

the

total

bottomhole

the

at

usually

is

it

estimate

to

various

operations

the desired

the

For simplicity

region

for

constant

hottomhole

only

region

tion

at

of

interest

control

used

approach

used

pressure through

known

the

knowledge

he

can

the annulus

Thus

pressure

terms of

also

maintained

choke

adjustable

region

be

formation

the

press

in

well

During

pressure

fluids

any point

at

pressure

pressure balance

hydrostatic

the

at

bbl

since

length

tain

Prediction

the

The same identify

Pressure

annulus

is

The region above Annular

mud

10.6-ibm/gal

in the

gas

is

L1

4.4.2

of

bbl

mud

ibm/gal

20

also

300

pumping

i0.6-ibm/gai

300130170

6.0445.59.625.5 Pk

which

depth

720

45.5

Solving

seat

casing

by

Pe 604

the

effective

mixtures

incompressible

given

is

at

density

equivalent

520

__________ 0.05210000

region

above

the

gas

contains

9.6-ibm/gal

mud

Thus we can compute the pressure at 3500 ft from of 3244 psig at 5636 ft using known pressure

p3244O.O52l

.08437

0.0529.656364373500

2371

psig

the

APPLIED

122

SURFACE

OF

LIQUID

which

7__7_y7

indicates the

to

equal

the

that

weight

the

of

buoyant

upward

used

first

Archimedes mersed

relation fluid

in

of

understanding

sidered an the

F2

rest

to

Ib

PRISM

IRREGULAR

BODY

sum of

the

of

weight

forces

49.-HydrauIic

on

acting

of

system

body

foreign

of

The equivalent given

density

this

to

corresponding

is

pressure

by

mersed

The 371

in

13.0

is

Buoyancy

the

our

on

attention

to

the

and

strings

created the

well

are

the

tension

axial

The

net

as

on

posite

side

fluid

The

shown

side

of

an

equal

the

at

fluid

most

the

equal

to

the

same argu

this

the

is

of well

immersed

equipment

by

of

weight

well

the

and

in air

equipment

force

buoyant

Archimedes

Using

im

body were

foreign

4.21

the

is

also

of

the

relation

force

buoyant

is

given

by

4.22

FbQpfVpf PS

in the

point

of

where Pf and

is

4.22

is

the

the

Eq

into

fluid

density

volume

fluid

4.21

is

the

of

density

steel

Eq

of

Substitution

displaced

yields

con

be

will

the

at

pnsm

hydraulic

prism

force

is

F2

the

times

depth

is

F1

any

the

vertical

given

the

by

given

of the

cross-sectional

4.23

is

the

bal

The

steel

of

density

65.5

is

lbm/cu

490

approximately

ft

or

Ibm/gal

op

exerted by

force

bottom

the

on

force

of

WeWl_f2

prism

pressure

depth

acting

net

resultant at

foreign

buoyancy

Hydraulic

pressure

acting

force

called

for

easily

on

acting

is

Fig 4.9

in

prism Thus

of the

on

downward

pressure

F1 the

acting

prism

hydraulic area

feet of 19.5-lbm/ft drillpipe Example 4.8 Ten thousand off drill collars are and 600 of 147-Ibm/ft suspended ft

bottom

hook Fi

body

weight

moment

determination

The

pressure

well

in the

one

top and

the

given

at

In

in others

while

needed

is

at

equipment

pressure

submerged body

understood

is

the

by

at

this

our

turn

or bending

force

of hydraulic

effect

anced

the

will

well

hydrostatic

desired

is

on

immersed

Buoyancy

acting

the

the

same

the

the

that

Note

to

equal with

first

material

such

to

or compression

force

resultant

sidered

due

pressure

submerged equipment the

subsurface

focused

pressure

we

section

this

have

hydrostatic

the

resultant

by hydrostatic

we

chapter of

In

on

that

some cases only

this

calculation

forces

attention

pipe

the

in the

points

given

Fh0 of

sections

previous

to

at

the

fluid

the

Wi

weight

defined

if

be acts

is

zero and

WeWFbo where

In

in

partially

effective

fluid

fluid even

applied

lbm/gal

0.0523500

4.5

be

only

must

equal

con Since

surface

bodyi.e

the

fluid

the

liquid

be

must

an

irregular

be unchanged

body and

force

by

displaced

that

in the

fluid

foreign

occupied

the

ment could

the

upward

net

region

weight

on

an

imaginary

fluid

The surrounding

forces

experiences fluid

the

the

forces

contained

the

force

buoyant Fig

by

vertical

For

surface were

this

drawn

surface

contained

element

fluid

of

ease

im

body

shape

its

body would

not present and

imaginary

i.S

relation

B.C

consider

the

Fh0

This

foreign

of

fluid

in

body were

the

for

more general

surface of

the

at

pressures

valid

is

250

about

regardless

the

immersed

body

if

Archimedes

by

force

fluid

displaced

F1

was

ENGINEERING

DRILLING

load

mud

15-lbm/gal

in

that

must be

supported

the

Calculate by

the

effective

derrick

p1AF.DA Solution the

Similarly pressure

at

force

upward of

depth

on

Dh

the

prism

times

the

is

given

by

The

weight

of

the

driuistring

in

air

is

given

by

the

19.510000

cross-sectional

147600 283200

Ibm

area

F2

Thus fluid

Fb0

p2A the

on

the

The

FDhA resultant

prism

given

weight

computed using force

buoyant is

effective

Fh0

by

exerted

by

Eq

Fw5ADFe.vAh

drillstring

in

15\ We

wl 218300

Is

the

the

F2 F1

FAD

of

4.23

283200 65.5

mud

can

be

DRILLING

HYDRAULICS

123

MUD

DRILLING

DRILL

PIPE

FT

OAl

F1

dc

I-

O%2

Fig 4.10Effect

of

4.5.1 In

Determination

Example on

pressure

some

cases

stress

at

the

is

4.8

axial

tension

area of steel

mined

the

hydrostatic

chimedes

cannot

the

idealized

Consider

the

drilistring

per

portion

downward until

by

of

the

cross-sectional

collars

area

the

sider

pressure

drill

collars

free

is

of

body

Fig

The

lOb

be

A2

P2

hydrostatic

Fb

force

Point

at

pressure

sider

the

free-body

cross-

drilistring

deter

requires

tension

axial

of

diagram

Fig

As

lOc

in

the

the

before

con

drilipipe

upper

of

portion

system

the

equilibrium

that

the

Ar

and

drilistring

lower

portion

while the

To

W2F1 F2Fb

FTWI

FTwdxW2pIA2Al

of

P2A2Fb

up

4.24b

apply

the

pipe

The

much

to

A2

cross section in

the

the

For

the

A2

the

A1 of

portion

ystem

drill

the

at

collars

drill

lower

of

and

drill

in

drillpipe

of

to

collars

the

the

air drillpipe

point

of

in

and

hydrostatic

Pt

of

the bottom

Point

at

pressure

top

To

con

jaltrss the

is

obtained

the

by dividing

axJjnslin

by

cross-sectiojiaLarea_oLsteel

the

be

to

terest

that

foot

from

top of

the

Note

per

distance

Xdp

than

greater

weight

Wdp

sup

is

string

cross-sectional

bottom

the

lowered

is

drilistring

area

of

and

where the

is

FT

drill

the bit

to

applied

To determine

axial stress

of

dnllpipe

the

diagramfor

body

in

of

drilipipe

hole

applied

diagram

must

collars

of

the

tension

free

drillstririg

op

drill

the

against

axial

the

considered

schematic

cross-sectional

the

drillstring

of

of

used

the weight

collars

against

determine

be

by

application

Fig 4.lOa

bottom of

drill

hydrostatic

stress

of

composed Fb on the bit of

the

axial

of

force

compute the The axial

divided

be

composed

is

is

portion

ported area

well

in

suspended

to

string

must

pressure

schematic

drilistririg

hydrostatic

However

required

points

relation

in

drillpipe

pipe string

When

cffcctive

of

effect

necessary

the pipe

in

for

Stress

was

in the

point

forces

axial

diagram

net

string

be

may

it

Axial the

only

on

pressure

body

free

of

the pipe

given

sectional

of

hydrostatic

and

collars

in

equilibrium

Example 4.9 for

FT_W2F2Fb_WdCXdCP2A2_Fb

the

develop

4.24a

expressions

Xdc

distance to

the

per unit length

of

from the bottom point

of

interest

drill

of

collars the

drill

in

air

for

The hydrostatic

Solution weight

of

described

in

axial

tension

Example axial

determining

vs 4.8

stress

depth Also in

the

drilistring

where Wdc

graph

Prepare

drillstring

collars

is

given

pressure

at the

by

collars

P1

O.05215lO0007800

psig

top of the

drill

APPLIED

124

--

TENSION

COMPRESSION

lOOK

3OOK

HOOK LOAD 2I830O Ibf

300K

lOOK

ENGINEERING

DRILLING

2000 4000 PIPE

DRILL

I95O00

6000 O4325.73

Fj 780

800O

Ibf

29213001bf

10000

III

88200Ibf

12000

F2 826843.2 357200 Ibf Fig

the

Similarly the

hydrostatic

collars

drill

is

given

4.11Axial

pressure

P2

tensions

bottom

the

at

as

function

of

by

of

depth

and

an

this

is

At

P2

0052 5l0600 8268

same

depths

218300

of

intercept the

4.9

Example

for

below

ft

10000

Note

at surface

lbf

obtained

result

Example

in

Eq

4.24a

that

4.8 used

be

can

psig

FT 147l0600D826843.20 The

area of

cross-sectional

approximately

19.5-ibm/ft

is

given After simplifying

by

19.5

FT

Ibm/ft 144

A1 490

driflpipe

Ibm/cu

sq

in./sq

ft5.73

collars

is

the

ft

for

cross-sectional

given

of

area

147-ibm/ft

drill

490

10000

the

144

Ibm/cu

sq

in./sq

ft43.2

sq

in

10600

was

graph

equa shown in

obtained in

the

tension

axial

the

depth

the

Using

range

ft

of

function

as

stress

axial

Thus

Ibm/ft

FT

for

Axial the

147

obtain

1201000 lbf147D

Fig 4.11

by

A2--

we

equation

sq in

tions

Similarly

this

pipe

by

stress

at

az

is

string

the

obtained

any

point

by area

cross-sectional in the

drillpipe

dividing of is

steel

given

by

ft

21830019.5D The

tension

given

by

Eq

in

the

function

as

drillpipe

of

depth

5.73

is

4.24b

38098 FT19.5lo000.D

147600

foi

simplifying

this

equation

we

at

stress

780043.2 5.73826843.2 0.0 After

the

psi3.403

0D any

10000-ft

point

in

the

range drill

Similarly

collars

1201000147

obtain

43.2

FT218300_

19.5D

27800 for

the

equation

10000 of

straight

line

ft

range

with

Note

that

slope of

this 19.5

is

psi3.403

the

lbf/ft

for

the

10000D

10600-ft

range

is

given

the

by

axial

HYDRAULICS

DRILLING

125

Thus

ble

shown

if

to

will

may

of

drilipipe

the

the

the

drill

as

drillpipe

bit

The

At

point

equal

to

Fig

4.14

the

of

average Current

the

the

point and

radial

design

below

point

referred

the

axial

no

is

the is

stress stresses

maintain

to

is

during

drillpipe

the

as

to

tangential

practice

be

for

there

which

sometimes

sec

may

weight

tendency

above

neutral

practice

lower

in the

creating

tool

the

common

desired

the

point

is

the

condition is

collars

drill

without

buckle

to

tendency

neutral

in

It

fail

that

so

buckle

to

and

walled

heavy

drillstring

to

neutral

above

exists

occur

buckled

in

quickly

fatigue

the

applied

rotated

is

use enough

tion

tendency

buckling

Fig 4.13

in

If drillpipe joints

buckling

helical

collars

the

drilling

operations Neutral

Point

If

the

rotate

bit

The the

the

be

of

the

be applied

to

the

collars

bit

Ldc

collars

given

is

be

chosen

axial

stress

such

that

desired weight

minimum

the

case

this

in the

condi

simplified

zero

the

to

to

required stress

of

can

equal

is

In

point

then

collars

torque

tangential

For these

the

is

the

and

radial

point

drill

of

weight

and

air

is

the

negligible

neutral

length

drill

low

is

may

drillpipe

tions

fluid

drilling

the

to

of

length

by

Fb

Ld0-.-in

4.25a

air

dc

Neutral

where

Fb

during

drilling

of

the

under

result

in the

tween

the

slender

The of

buckling

slender

and

suspended

in

pipe

nored well

slender

buckled

partially

slender

has

these neutral

of

if

proper

as

of

graph

axial

vs

stress

depth

is

student exercise

added

to

puting

the

Effect slender

resistance fail

by

to

load

of

moment

the

of

pipe

as

helical

by

is

IrI64d4

given

pipe

The

that

slender

the

resisted

are

of

sub

is

less

is

in

moment

to

compres

or casing

occur

forces

tend

long

if

bottom can

buckling

the

4.12

low

and

vertical

welibore

load on

pipe Buckling of

moments to

Fig

have

drilipipe

bending

in

confined

inertia

Buckling

subjected

compressional

hook

circular

applied

shown

is

on

such

when

As

that

to

Portion

any

load

dnllpipe

the

Buoyancy

columns

buckling

sional

jected

of

than

lower by

inertia

For

example

Fb

inside is

large

prevent dnlpipe

d0

is

diameter and

buckling is

For

small

net

the

vertical

should

by

Eq

of

hydrostatic

stresses

4.25a

at

present

conservative

overly

need

the

predict for

even

be

com

when

bit

for

loading

of zero

One of

the

the

cluding

of

Goins

pipe The

most general approaches

the

pipe

force

stability

is

pressure

defined

due

force

stability

and

to

in

was proposed

buoyancy on buckling

introduces

inside

pressure p1

and

easiest

effect

by Goins.4

of

to

fluid

outside

p0

the

by

F41pA0p0 where inside

or outside diameter

drill

is

collars

assumed

However and

collars

into

effect

be

drill

the

Fh

about

past

simply

tangential

may would approach

length of

the

ig

there

by

nominal

generally

and

not be

collars

the

the

the

d4

the

drill

thus

and

this

of

of

However

that

loading

ignores

radial

point

considerable

should

buoyancy

length

approach

be

junction

buoyancy

reasoned

to

drill

would

portion

in

including

have

the

used

is

of

compression

buckling

compressional

the

neutral

area

where

bit foot

per

length

No

axial

to

fluid

due

minimum

the

this

at

collars

on

for

people

this

pressure on

Long

the

to

weight

conditions

amount of confusion

force

the

However

4.5.2

applied the

well

occurring

subjected

procedure

Many

is

use of

the

drill

drilling

great

compressional of

point

buoyancy

liquid

been

that

and

is

drillpipe

effect

analysis

left

be

to

Wdc

simplified

drillpipe

pipe

pipe

the

The preparation

force and

operations

collars Note

drill

collars

Fig 412Helical

maximum

the

is

Point

generally

the is

the to

and

moment be

great

moment assumed

of to

of

is

the

inertia

enough inertia

pipe

the

cross-sectional

pression

The

of

tersection

force

of

point the

the

such

diagram

neutral

then

axial

area

and

diameter

computed using The stability force

to

be negligi

is

A0

outside

can

be

as

the

can

be

computed

is

shown

force

the

of

the

pipe

tension/com

on

in

determined

compression

using

cross-sectional

diameter

plotted

one

the

and

Fig

from the

4.11 the

in-

stability

./

APPLIED

126

Fh

Fb

to

the

hydrostatic

uniform

density

applied

Recall

was

it

surface of

an

the

if

of the

fluid to

also

is

fluid the

by be

be

to

Pipe

the

the

Ldc Collar

fluid

the

Large

by the

to

drillpipe

fluid of

The weight the

of

rod

the

weight

the

to

buckle

given

should

fluid

in

when

air

of

length

proper

be used

computing

desired

buckling

of

condition

and

drillpipe

above

undesired

drill

buckled

by

Wdcl

condition

shown

be

can

axial

and

Note

the

circulation

tial

are

it

is

advisable

depth state

in

steel

of

determine

10600

in

the

and

wall

4.25b of

at

of

cause

friction

is

from

used

have

lbf

is

at

starts

an

diameter

1.3

least

68000

hole which

external

tangen

Fb

loading

collars

drill

an

thus can

Eq

two

These

and

bit

fluid

effects

radial

weight

of

to

the

the

factor

bit

section

The

ft

of 3.0

point the

safety

maximum next

in the

diameter

the

to

are

Also

load Thus when

Example 4.10 anticipated

neutral

include

to

the

hydrostatic

rotation

on

effect

the pipe wall

in

only

neglected

drillpipe

in

hook

observed

the

for

stresses

used

the pressures due

Also

significant

difficult

it

will

and

between

junction

is

and

neglected

shift

significant

makes

at

line

collars

needed

axial

and

the

length

conditions force

stability

Eq.4.25b

have

can

collar

drill

hydrostatic

the

considered

torque

factors

of

drill

when

that

pressures were

the

for

line

compression

of

use

the

intersection

an

drillpipe

of

that

4.25b

Eq

by

in

result

Fig 4.14Stress

4.25b

in liquid

predicted

neutral

the

for

collars

It

at

col

drill

tendency

Fb 4.13Helical

have

loads and

eliminate

required is

the

in

rod

the

of

Ldc Fig

the

weight

This arm with respect to given point column immersed in fluid long slender

moments Thus

Ldc

the

to

contained

the

distributed

are

must

direction

surface and

the imaginary

weight the

of

instead

bending

FbToo

However

fluid element in

sutface

the

of

body both

for

that

effective

lars

magnitude

contained

the

of

weight

shape in

foreign

means -Drill

in

force

element

but opposite

the

by

the

of

same moment

the

was reasoned

It

must be equal

acting on

forces

magnitude

caused

contained of

was merely

surface

the buoyant

fluid

the

if

the

at

in

equal

regardless

Point

the

for

hydrostatic

moment

Neutral

that

the

on

unchanged

on acting sum of the moments rest element must be zero Thus the moment caused

surface Drill

true

relation

surface is at by must be zero and the

forces

contained

be

the

contained

vertical

Neutral

be

the liquid

in

of

can

law

acting

pressure

this

that

in direction

the

but opposite it

and

fluid

Archimedes

body would

element

fluid

of

weight

the

drawn

surface

sum

the

rest

that

fluid

not present

imaginary

that

developing

are

pressures

drilling

Archimedes

of

in

foreign

any

were

body

out

pointed

fluid

of

pressure

corollary that

the

when

For simplified conditions due

Fb

ENGINEERING

DRILLING

internal

of

in

8.0

point

and

mud

the

minimum

density

length

buckling

tendency

drilipipe

The

external

intersection

of

of

collars

the

of

drill

15

has an

internal

diameter of 5.0 plot

stability

of

required

occurring

axial

force

in

to

the

prevent 19.5-lbf/ft

diameter of 4.206

in Also show

compressive

occurs

at

the

Compute

ibm/gal

collars

from

drilipipe

in and an

plot

is

that

stress

the top of

the

the

and drill

HYDRAULICS

DRILLING

127

COMPRESSION -400

300K

-200K

.-

TENSION

-lOOK

200K

lOOK

and

300K

the

have

50300 STABILITYJ

AXIAL LOADING

STA8ILITY

to

surface

at the

Note

the

that

and

stability

force

between

the

drillpipe

and

tion

The

actual

should

be

of

factor

safety

of

length

increased

the

of

at

axial

junc

the

collars

drill

in

used

collars

drill

of

occur

lines

points

function

as

intersection

by applying

1.3

zero These

is

force

stability

plot

compression

FORCE

4000

used

Fig 4.15

in

2000-

force

stability

been

practice

factor

safety

Using

gives

I-

F2I83O0-6 8000

Ui

Ld6OOl.378O

F19.5D

ft

8000 000

201

FTr

68

000L

00CC 200

4252OOL3D INSTGBILITY

Fig 4.15Stability

Nonstatic

The

determination

well

can

analysis

for

plot

or

4.10

Example

the

be

per

of

foot

the

drill collars

given

is

by

the

in

of

effect

The weight

of

32490 lbflfl

timum

4144

pump

during

The

effective

per foot

weight

density

circulating

147

mud

in

is

given

of

by

control

15

147

Wdce

113

lbf/ft

The

65.5

Thus bit

minimum

the

of

weight

68000

68000

given

is

required

tum

by

600

the well conditions

that

ample 4.9 except The stability force

that

the

are

load on

bottom

at the

identical

of

the the

to

bit

is

collars

those

of Ex-

68000 is

given

lbf by

F2Ap1A0p0

rate

8268

Mass

into

crease

the

lbf

the

stability

force

at

the top of

the

collars

is

given

by

ideal

gas

at

_____827

is

within

mass

of

remains

the

drilling

in

points

all

the

the

stability

force

at the

bottom

is

of

the

_420627 800____527800

mean per

geometry

points

the

area

unit

may

the

net

gas

at

in

which

any point

in the

of

can

be

considered

is

must be

ac

the surface equip-

the flow

same

the

or

same

of any

absence

in

fluid

air

incom the

essentially

the

in-

engineer

exception

In

mass of

rate

conditions

formations

be

well

at

given the

that

mean

the

is

rate at

all

of an

in

points

in

in

at

though

velocity

various the

often

the

points

flow

frequently in

as

the

of nonuniform

knowledge

the well

engineer

defined

is

point Because

velocity

same

point

flow

point

even

the

drilling

mean upward

given

at

at

different

in the

example lbf

real

the

of well

velocity

flow

drillpipe

velocity

44700

the

drilling

density

system

fluid

that

The

density

fluid

the well

well

flow

well F5

the

are

well

The Similarly

state

compressible

with

fluid

drilling the

fluid

Also

or leakage

compressible

337000

of

the time

to

steady-state

or

constant

ment or underground

lbf

and

model

and

states

equal

volume

the

considers only

cumulation

800

are

engineers

slightly

mass

of

volume

any

7r

.._....327800

Ex

Balance

pressiblei.e

F2

the

an

using

of state

plastic

equation

gas

mass concentration

well and

laws

drilling

Bingham

model

of conservation

normally

357200

by

momen ob are

of

equation

The law ____82

the

the

mass

flow

fluid

Example equations

fluid the

of

physical

models used

to

applied

model and an equation

model

model

rates

conservation

these

well

during

conservation

of

application

flow

describing

downhole

and

commonly

energy and

incompressible

4.6.1

328268

laws

sizes

cuttings-carrying

drilistring

mud

various

power-law model

fluid

the

are

rheological

Newtonian

the

in

occur for

ample rheological

ft

the

Note

of

by

lbf

lbf/ft

the

op

the

nozzle

bit

surface

the

All of the equations

tained

and

rate

and

fluids

for

assumed

Ld 113.3

lbf

collars

drill

tripping

flow

physical of

conservation of

length

operations

will

basic

movement

cement

or

drilling

during

operations

operations

for

pressure or

pressure or equivalent

mud

the

that

pressures

during

the

system

determined

the bottomhole

pressure

drilling

capacity

the

be

bottomhole

flowing

density

circulating

must

well

in the

mathematically

of

complexity

mud

drilling

forces

the

in

points

the

describe

forces

the

of

ing operations

Wdc

the

various either

Frictional to

frictional

calculation

when

difficult

spite

at

pressure

moving

is

these

equivalent

7r82

Conditions

complex

be

can

However

of

quite

drillstring

system

Solution

Well

4.6 REGION

12000

is

in the

rate

of

at

desired will

annulus

all

mean

the

For

compute to

ensure

APPLIED

128

TABLE

4.1

The energy

system

p2

E2 17.16

bbl/min

V2

enthalpy

bbl/min

d-d

d2

gD2

energy

fl/mm

3.056

cu

dd d2

kinetic

internal

diameter

of

pipe

in

internal

diameter

of

outer

pipe

inner

pipe

ly

for

adequate

4.1

used

diamter

of

fluid

given

equal

to

minus

the

Thus

the

forms

E2

in

per

mass

unit

leaving

the

per

unit

Point

at

of q/A

law

fluid

is

work

to

equal

the

by

fluid

done

by

of conservation

the

to

energy fluid

on

pump

of energy

or

engine

fluid

the

yields

for units

E1p2

Pt V1gD2

V2

D1

P2 vWQ

Shown

in

frequent

field

the

system

the

Point

at

borehole

or

removal

rock-cutting

convenient

are

in

of

by the

mass

and

in

Table

ft/s

velocity

external

is

of

mass

2.448

average

it

energy

system

The work done

that

leav

and

where

d2

fluid

It/mm

in

gal/rn

2.448

unit

per the

leaving

the

Point

at

system

potential fluid

Cu

mass of

unit

per

the

ing

3.056

sum of

the

is

Annulus

Pipe

17.16

the

leaving

ENGINEERING

DRILLING

this

Simplifying

expression

differential

using

notations

yields

Example 4.11 400 gal/mm diameter

of 4.33

diameter

of 2.5

Calculate

the

5.0-in

in

and

and

is

drill

bit

has

diameter in

velocity

annulus

an

have

collars

has

circulated

being

drillpipe

the

in The

average

collars

drill

mud

12-Ibm/gal

The

an

of

the

internal

9.875

in

Eq

4.26

processes Solution of

units

the expression

Using gallons

given

minute inches

per

1ab1e

in

and

feet

for

per second

gives

400 ft/s

ing

2.4484.332

the

26.143

This drilling

of

the

fluid

considered

be defined

in

and

the

heat

the

friction

Eq

us

4.26

expression

pdVQ

ft/s

of

engineers

using

terms of

prop

form

by

is

adiabatic

or

transfer

flow

for

thermodynamic

applied

energy

to

applied suited

best

previously

usually

can

following

400 Vdº

internal

fluid

term which

loss

8.715

Vdp

the

by

whose

has been

in

change

gained

is

heat

either fluids

tabulated

seldom

equation

The

involve

been

of thermodynamics

This equation

involving

have

erties

law

first

process

that

systems

drilipipe

the

is

flow

steady

drillpipe the

opposite

4.26

at

internal

4.27

2.4482.52 The

400

Vp

2.253

ft/s

52

2.4489.8752

for

forces

within

into

4.6.2

The

law

rate

energy

work flow

done

conservation out

is

p1

of

within

system

system

F1

of

the

shown

of

in

equal

is

states

that

to

time

the

system Consider 16

Fig

the

The energy

the

per

potential

entering

the

4.26

Eq

4.28

the

energy

per

system

mass

system per

of

the

fluid

flowing

of

of

mass of at

mass of at

fluid

the

Point

Joule

Point entering

fluid

and the

and

used

by

viscous

the

of

Substitution

ac

to

conveniently

wasted

Eq

4.27

428

no

included

in

first

the

term

of

The

and effect

friction in

Eq

use even

energy

transfer

general

magnetic of

loss

4.28

heat

term

flow

balance

energy

before heat flow by

Carnot

expression

other than

assumptions

boundaries effects

in

completely

limiting

phase

mechanical

the

was

form

as is

chemical

The the

called

is

This equation

fluid

Point

system

unit

system

mass

at

unit

the

per

the

unit

be

or energy

yields

often

equation

taining

entering

entering heat

unit

energy

fluid

work

of

rate

generalized

and

kinetic

the

was recognized

enthalpy

term can

loss lost

net

of

sum

entering

gD1

energy

system the

Eq

the

VdpgDWF

Balance

Energy

frictional

count

the

electrical in the

con

exclusion and

system

is

DRILLING

HYDRAULICS

be

may

unless

difficult

known with

evaluate

to

exact

the

129

of

path

Fortunately

the

if

is

compressible

or expansion deal

engineers

drilling

fluids

incompressible

essentially

fluid

compression

is

primarily

having

constant

volume

specific

Since

for

DO

incompressible

fluids

term

the

Vdp AL

FL is

given

r2

Eq

ERGY

by

Vdp

4.28

also

be

expressed

4.7

by

Flow

Through

schematic

ADppWpF

p-pg

of

practice

as

pressure due the this

Expressing pounds

ond

feet

feet

per gallons

of

units

sec

per

tional

D1--8.074

v0

the

pressure

loss

4.29

reduces

1400

is

flow

internal

the

drillstring

diameter of

the

2.5

in is

at

pressure

loss

the

the

pump

is

by

pressure

rate

and

Ibm/gal

The

developed

frictional

the

psi

12

is

density

the

if

drilistring

string

the

is

depth

collars

drill

and

the

3000

bottom

the in

the

400 gals/mm

well

The

average

velocity

at

is

the

ft

bottom

of

the

collars

given

is

I226

10

142

of for

equation

celeration fluid

term the

of

can

through

Eq

be the

4.29

the

ignored bit

minor

in this

in kinetic

change

effect

drilling

energy

except

nozzles

the

Eq

4.30

than

not

difference

correction is

the

To

true

strictly

is

the

primarily because is

Cd usually

4.30

never

smaller

always

flow

Eq

by

bit

or

factor

introduced

so

that

the

4.31

30001400 result

for

of

kinetic

application

caused the

the

flow

by of

fluid

In

ac

drilling

the observed

in

discharge

coefficient

ly for bit

nozzles by

Eckel

and

0.98

recommended

experimental

Bielstein

These

value

has

bit

nozzle

one of

the

to

Eq

zle

may be

of 0.95

as

authors high

as

more prac

as

limit

more than

one

same number of nozzles and

the

The

nozzle velocity

determined

coefficient

discharge

indicated

but

the

for

value

has been

that

ruck

general

is

velocity

this

modified

predicted

across

frictionless

coefficient

tical

energy

velocity

vnCdJb4

psi

illustrates

actual

discharge

will

Example 4.12

drop

nozzle veloci

zero

essentially

062406.630001400 7833

exit

computed using

compensate

pits

pressure

4.30

pressure drop

The

realized

is

00.05212l00008.074

P2

the

Unfortunately

ft/s

mud

the for the

104p

8.074x

2.4482.52

in

for

equation

Pb

assumption

velocity

this

increase

pressure

drill

Pa

symbol

solving

mud

10000

400

The average

and

yields

velocity

26.14

Thus

drill-

the

psi

in the

fric

the

negligible

is

of

for

Solution

nozzle

the

negligible

is

and

to

the

P2

ty

the

across

nozzle

the

velocity

in

change

negligible

is

4.29 P1

Determine

nozzle

In

P2

Substituting

Example 4.12

of

upstream

with

the

elevation

in

Fig 4.17

in

that

con

short

through

shown

is

assumed

change

system

flow

nozzle is

DONE

Bits

Jet

Pt

zip PfP2

l04pf

to

velocity

compared

Eq

gives

0.052pD2

Pi

field

practical

inch pounds

per square and

in

equation

bit

generally

it

flow

incompressible

such

stnction

WQD

OUT

4.16Generalized

Fig

can

rNrMG

is

present

the

must be

4.31

the pressure drop

if

velocities

usually

the

same Fig

through

is

all

the

18 same

nozzles

having

more than

pressure drop applied

nozzles

the

nozzle

cones When

across

all

According

for

each

are

noz

equal

APPLIED

130

ENGINEERING

DRILLING

Doll

StrIng

Nozzle

____/

.---

_7_ 4.17Flow

Fig

Therefore rate

q/A

each

same

the

is

of

are

nozzle each

for

bit

through

nozzles

the

if

through

--

nozzle

different

must

areas so

adjust

nozzle

If

that

the

flow

the

ratio

nozzles

three

413

Example

v_---_ q3

A1

A2

A3

containing

400

gal/mm

Calculate

The

Solution Note

also

that

the

total

flow

of

rate

the

pump

is

A1 q2q3i5A1 this

Simplifying

area of

total

Thus equal

the to

of

velocity the

flow

flow

total

given

is

of

bit

by

132132

132

0.3889

each

through divided

rate

rate the

across

nozzles

three

flowing

at

767 11r4169169169

yields

A2A3vA

qDA1

pressure drop

the

is

nozzles

4322

-l-tA2i5A3

expression

the

fluid

drilling

%2-in

three

given

by

qqt

nozzles

parallel

12.0-ibm/gal

abit

through q2

through

are

present

qi

4.18Flow

Fig

nozzle the

by

also

is

nozzle

total

Eq

Using

in

sq

4.34

the

the

across

pressure drop

bit

given

is

by

area

XI05124002

8.311

4.32

In

A1

A1

A2

field

units

the

Pb

0.9520.38892

A1

nozzle

1169 given

is

velocity

psi

by

4.33 3.117

where

A1

has

gallons

per

Combining

Since

Bit

inch

A1

has

units

the

across

has

of

and

4.33

and

bit

zpb

yields

of

units

square solving

both

no7zle For

flow

by

frictional

32

if

the

denotes

jfl

of

effects

short

are bit

are

the

mass

rate

to

flow

of doing

rate

work

pump

power PH

hydraulic

energy

by multiplying

pq Thus

pWqpq

the

flow

pump

rate

is

pressure

in

expressed

Ip

is

gallons

expressed

in

per minute

pounds

and

per square

essentially

Eq

nozzles

non-Newtonian

and

diameters often

diameter

converted

PH If the

through

example

diameter of

be

Power

the

inch

Newtonian

this

power

can

is

the

X105pq2

viscous for

Hydraulic

Since

inches for

CA12

12-13-13 having

second

4.34

the

for

per

4.31

Eqs

8.311

negligible valid

feet

minute and

pressure drop

Ph

of

units

4.7.1

expressed nozzles

that

the

in

and

bit

are

in

32nds

4.35

is

1714

of an

described

contains one

two

4.34

liquids

as

nozzle

nozzles having

where Likewise equation

is

can

multiplying

be

the

in

expressed

other terms

in

Eq

expressed

as

pressure term

hydraulic

4.29

the

hydraulic by

horsepower

pressure balance

q/l714

horsepower

by

DRILLING

HYDRAULICS

Example

414

Determine

developed

ing

How

much

forces

in

131

of

this

the

pump

the

by

power

hydraulic

discussed

be

Example

12

due

lost

being

is

horsepower

in

to

4.8 The

frictional

equation

the

drillstring

evaluate since

The

Solution

pump power

used

bcing

is

given

Eq

by

4.35

However

extremely

move

to

used

the

Lpq

3000400

1714

1714

700

for

quired

hp

The

due

friction

to

in the

drilistring

the

4.8.1

1400400

1714

327

hp

The

model

To

Hydraulic

The purpose of

action

Before

the

thc

of

the

assumed hole

in

that

the

is

fluid

the

traveling

at

hole bottom

and

after

hole

the

striking

momentum in

field

chips

the

bit

the

Fig 4.17

in

bottom is

time

the

given

action

If

bottom of

vertical rate

stant

required

4.31

and

the

4.36

mass

rate

of

the

to

motion

in

sufficient

con

of

moving

plate

upper

magnitude be

19

Fig set

is

be achieved

to the

keep

fluid area

the

was

force

by

given

the

is

fluid

The term F/A

the

striking

fluid

is

shear

Thus

called

shear

the

exerted on

stress

defined

is

stress

by

of change

of

by

4.38

4.36

fluid

the

velocity

Note

that

the

of the shear is

to

of

After

velocity

motion

The

velocity

eperimentally

area

with the fluid

pq

constant

gravity

plates

rest

at

of

oils

consider

distance

initially

steady

high

parallel

fluid

Examples

the

32.1760

where

and

viscosity

small is

at

constant

of

by

which

Newtonian

simple

large

for

found

the

and

model

plastic

is

it

of

pq

in

F1

two

direction

is

drilling

are

viscosity

water gases

time has passed force

by

is

impact

bottom

before

zero

at

traveling

in

several

all

velocity

con

in the

in

fluid

nature

separated plate

cleaning

bottom Since

the hole

to

units

the

not

are

the

are

the

between

The upper

at

the

hydraulic

hole

hole

were

cleaning

total the

cleaning the

was

life

While

impacts

vertical is

of

rock

of

the

against

transferred

is

bottom

the

that

stream

jet

the

well-understood

manner shown

the

momentum fluid

not

maximizing

jetted

improve

fragments

concluded

maximized by force

at

much

rock

is

jet

which to

is

introduced and

the

have

vestigators

fluid

were

efficiently

of

nozzles

jet

drilling

sumed regrinding action

Force

Impact

the

bits

jet

removed

of

used

Bingham

present by

fluids

contained

equations

behavior

fluid

re

fluid

loss

Model

forces

understand

friction

generally

the

Newtonian

Newtonian

mathematical in

present

of

overcome

be

long slender conduits

model

characterized

are

must

to

important

quite

process

forces

approximate

viscous

1714

through

the

models

power-law

is

Lpfq _____

to

Newtonian

forces

development

rheological

be

can

difficult

most

the

viscous

drilling

pressure balance

the

in

is

term

viscous

the

the

engineers

The power consumed

fluid

rotary

of

4.29

this

large

drilling

in

description

4.7.2

Eq

as

given

term

loss

pressure

viscous

the

Models

Rheological

The

of

the

the

is

plate

in

area

v/L

gradient

velocity

is

contact

an expression

rate

Eqs

Combining

yields

dv

4.39

F/0.01823CqJ where

F1

is

given

in

dL

4.37

pounds

Thus is

Example the

bit

Solution

F1

15

discussed

Using

Compute in

Eq

the

impact

force

model to

proportional

states

that

shear

the

the

shear

stress

rate

by

Example 4.13

4.40

4.37

0.01823O954OO5lJ69 820

developed

Newtonian

the

directly

where

the

viscosity

of

plate

this

fluid

means

lbf velocity

Viscosity dyne-s/cm2

constant the

also is

or

that

will

of proportionality

Fig 4.20 if

the

force

is

known

terms of

In

is

the

doubled

as

the

moving the

plate

double

expressed

g/cms

in In

poises the

poise drilling

is

industry

APPLIED

132

dinitially

Upper

rest

at

ENGINEERING

DRILLING

set

plate

motion

in

\\//7\\7/\\77\\///\\///\\7

//7\\.///

to

tO buildup flow

Velocity

Final

unsteady

in

velocity in

distribution flow

steady

Small

Large Fig 4.l9Larninar

flow

Newtonian

of

The

shear

fluids

rate

given

is

by

rn

10

cm/s

10

tx

seconds

cm

p.

tx

Eq

Using

4.40

Ct

dyne/cm2

0.5 10

SHEAR

s/cm2

dyne

seconds

RATE or

50

Fig 4.20.Shear

vs

stress

shear

rate

Newtonian

for

fluid

The viscosity

generally

0.01

cp units

of

poise

at sea level

Occasionally

The

ft

lbf-s/sq

in

expressed

is

is

viscosity

of

units

where

centipoises

expressed

can

viscosity

be

in

related

moves

is

30.48

cm/s2

fonned

479

or

laminae

be

in

would

cross

section

poise

has

47900

cp

bulent

Example 4.16 above

dyne

is

of

fluid

required 10

to

of

plate

upper

stationary

of

velocity

An

move

the the

plates

upper

if

plate

cm/s

area the

Compute

plate

between

20-cm2

is

spaced

viscosity force at

of

in

4.8.2

drilling

by

single

100

constant

measured

measurement the

Solution

The shear

T5 100 20

stress

is

given

by

fluid

is

for

tionality

between

classified

as

dyne/cm2

are

shear-rate

the

apparent

entire

of

fluids

Thus when

the

do

nut

shear

tur

must

be

characterized

rate

at

shear

shear

are

with

the

of

history

direct

and

Fig 4.21

which

rate

Non-Newtonian

decreases

viscosity

apparent

exhibit

stress

non-Newtonian dependent

prior

be

to

The

shear

the

and

that

viscosity

flow

are

stream

the

throughout

pressure drops

viscosity

dyne

cm2

in

eddies

flow

the

turbulent

complex

too

on

made

Fluids

turbulent

and

into

at the

Models

are

depends

shear

correlations

empirical

value

The

frictional

fluids

to

this

only

downstream

mathematically

Non-Newtonian

Most

flow

rate fluid

in

true

of

vortices

quickly

fluid

the

that

is

rates

move

the

flows

that

laminar

shear

as

long

This

high

injected

dispersed

occurs by

so

Dye

described

flow

fluid

particles

motion

of

been

not

fluid

fluid

be

determined

centipoise

the

in the

thus

from

changes

as

flow

At

and

stress

only

laminar

of shear

rates

dyne-s/cm2

479

cm

to

chaotic

tumbling

shear

valid

is

said

which

in

4.40

layers

pattern

flow

cm/ft2

Eq

low

relatively

between

relation

by

in

manner

flow

ft2

linear

described

by

454 g/lbf980

lbf-s

ep

propor rate

fluids

are that

pseudoplastic increasing

if

shear

DRILLING

HYDRAULICS

133

Cl C/ Lu

Lu Cr

Cr

Cl 21

Cr

Cr

Lii

Lu

V1

SHEAR

4.21Shear

Fin

vs

stress

dilaiant

shear

behavior

rate

P2

for

pseudoplastic

and

fluids

dilatant

pseudoplastic

ai

RATE

behavior

and

/a2

Lu Cr

cr

Cr Lu

Ui

TIMET

4.22Shear

Fig

rate

and

with

are

dilatant

are

generally

Non-Newtonian

Fig

4.22

decreases

new

creased ment

behavior ent

the

ment

increases

with

are

used drilling

shear

and

so

accounting but

number of present

that

cement

for

direction

in the

flow

shear

rate

errors

changes

system

is

and

model

defined

is

by

YTy

4.4la

rrr

4.4th

to

is

and

in

and

ce

pseudoplastic

At pres

slurries

drilling

fluids

are at

are

4.41c

various

obtained

when

diameter

changes

graphical

Bingham the

behavior

this

in

changes

most

plastic

only

rate

After

shear

and

viscosity

parent

the

yield are

of

/1 Eqs flow

laminar are

the

stress

same

viscosity

as

until

minimum

constant

the

viscosity for

not flow

will

certain

point

yield

shear

plastic

exceeds

stress

large are

of

representation

shown

is

in

Fig 4.23

ce

stirred

for

satisfactory result

and

However

generally

conditions

can

plastic

Model

r/i

viscosities

apparent

Plastic

behavior

rheopectic

rheological

mathematically

slurries

thixotropy

Bingham

apparent

fluids

the

cement of

steady-state

significant

the

if

the

approximate

behavior

the

measuring

increased

is

power-law

and

The

and

behavior

Bingham

viscosity

thixotropic

modeled

not

rate

Drilling

and

fluids

thixotropic

rates

cases

to

after

value

plastic

of

is

time

generally

are

fluids

before

Not

rheopectic

constant

4.8.3

ILp

apparent

shear

new

thixotropic

shear-time-dependent the

the

to

cement

fluids

nature

are

slurries

drilling

are if

and

fluids

and

Bingham

models

that

rheopectic

increases

viscosity

in

pseudoplastic

and

thixotropic

after

slurries

The

Drilling

thixotropic

time

for

value

constant

viscosity

time

rate

fluids

are

with

vs

the apparent

if

shear

increasing

slurries

stress

TIMET

point

applied shear

known

has been

exceeded

proportional

to

4.41a

through that

units

To be consistent

the

of

changes is

proportionality

Note the

the

value

called

4.4lc units

are

of

Newtonian

the

units

of

as

in the valid

plastic

or the

yield

APPLIED

134

ENGINEERING

DRILLING

or

lOOcp

Power-Law

4.8.4

The

SHEAR

power-law

Like

model

requires

or

vs

shear

rate

Bingham

for

fluid

plastic

must be the same

point

Thus

the

in

pressed can

units

field

be

of

units

for

of

point

per

454 g/lbf980

shear

units

yield

pounds

at sea level

related

lbf

units

consistent

However

centimeter

square

has

point

yield

the

as

stress

dynes

sq

The

ft

ex

is

usually

100

per

two

by

index

10030.48

ft

sq

cm/ft2

index

cm force the

move

the

dynes and

upper

plate

The

Solution

is

plate

upper

plate

yield

between

to

required of

cause

400

constant

at

is

point

area the

Compute

fluid

force

20-cm2

of

plate

of

viscosity

200

of

upper

stationary

plastic

in

the

any

dynes

index

field

eq cp

of

can

be

related

The

at

of

by

Eq

479

cp

eq

to

cm/s

10

4.41a

with

Example 4.18

to

10

cm/s2

dyne-sYcm2

47900

of

required

dyne/cm2

An

stationary

flow-behavior

move

and

the

upper of

force at

100

constant

of 20

upper

plate

plate

Compute

index

force

if

dyne velocity

of 50

required

is

of

10

dyne

is

velocity to

cm

spaced

is

index

consistency

constant

at

plate

cm2

the

move

required

of

cm/s

the

upper

cm/s

units

shear

10

lbf/l00

sq

Application

observed

of

Eq 442

at

the

two

yields

ft

4.79

50

plastic

is

viscosity

given

by

by

10

Eq

4.41a

with

/4\fl

20

and

10 cm/s

seconds

cm

Thus

of

by

if

plates

cm2

T2.O9 given

units

cm/ft2

30.48

ft

Solution

The

index

two

level

sea

called

represent

consistency

ft

of

units

unit to

con

the

Khas

be used

the

lbf-s1/sq

of

text

the

which

to

units

of

this will

in

flow-behavior

degree

value

called

flow-behavior

The

In

454 g/lbf980

point

yield

plate In

the

is

spaced

movement is

velocity

given

is

and

dyne

20

for

in

consLctency usually

the

or

Occasionally

units

the

the

g/cms2

ccntipoisc

expressed

called

dimensionless

on

depend

dyne-s7cm2

above

200

only

dyne/cm2

An

above

fluid

valid

is

parameter

the

the

sq

and

of

or

equivalent

is

exponent

dyne-s/cm2

is

4.42

non-Newtonian

is

lbf-s

Example 4.17

the

characterizes

unity

consistency

4.79

usually

deviation

from

sistency

cm/s2

Eq

and

fluid

behavior

fluid

Fig

in

power-law

Newtonian

fluid fluid

power-law

The

0.01 100

the the

dex

the

flow

of

either

shown

is

model

power-law

The parameter dex

model

the

plastic

for fluid characterization two parameters model can be used to represent

the

dilatant

laminar

of

Bingham

the

pseudoplastic stress

by

4.42

representation

4.24

However

4.23Shear

defined

is

rKj

STRESS

graphical

Fi

Model

model

is

100 20

given

by Dividing

400/20

10

100 1.0

10

/10\

dyne-s/cm2 50

the

second

equation

by

the

first

gives

rates

of

DRILUNG

HYDRAULICS

135

Lii

Lii

1-

SHEAR

4.24Shear

Fig

log of both

the

Taking

vs

stress

shear

rate

and

sides

RATE

for

fluel

power-law

for

solving

pseudoplastic

4.16

yields

power-law

100/50

fluid

0.756

velocity

is

radius

given

shear

fluid

of

the

related

The

the

to

angular

vrw value

this

Substituting

of

in

the

first

4.43

above

equation

Thus

yields

50

the

0.8765

with

Rotational 4.16 the

law

fluid

movement in

of

Fig 4.25

centric

the

API is

has been turbulent

flow

the

to to

In

available

on

the

4.2

The

dard

combination

The parallel

plates

for

shear

shear be

be

given

was

no

another

one

past the

in

change

but

velocity

by

slip

Thus is

con

shear

the

given

due

rate

to

slippage between

fluid

layers

by

relative

dc

4.44

described dr

fluids

drilling

rates

the

torque

rotor

viscometer

for

field

assumed

to

must

in

fluid

torsion

When

and

torque

applied

the

rotor

the

moving

of

constant

is

the

drilling

and in

stan fluid

moving

Examples

fluid

lower layer

and

layers

layer

an

between velocities

of

tionless

torsion

in

constant

angular veloci

motionless to

spring

direction

to

the

bob

the

the

torque

must

be

applied

to

motor The torque is transmitted between bob by the viscous drag between the suc of fluid

fluid

of at

held

is

the

by

at

rotating

the

by

rotor

cessive

shown

Table

is

bob

the

but opposite

equal

the

in

rotor

the

ty

bob dimensions

stationary

be

the

by

are

testing

all

made

be

exerted by

and

to the

only

analytically

combination

between

laminar

Since

measured

is

bob

inner

the

from

described

rotor/bob

rate

the

of

instead

bob The

used

shown

about

to

transition

usually

rotational

r11/r22

fluid

tests

relative as

The viscometer

the

can

practice

to the

dr

plug

viscometer

higher

bob

dv

power-

slipping

solid

extremely

However

measurements

stationary

attached

spring

as

would

radius

physical

the

on

similar

sleeve

extend

be

outer sleeve

diagnostic

outer

regime

flow

of an

plates

characterization

laminar on

found

based

plates

rotational

the

flow

laminar fluid

of

the

would

it

somewhat

parallel

see Chap Rotation

parallel

rotation is

standard

the

illustrate

Bingham plastic and

viscometer

two Oat

of

4.18

Unfortunately

cylinder

movement in

through

Newtonian

build

to

were not

layers

together

Viscometer

parameters

difficult

by

dr

moving

meaning of

given

is

cp

eq

Examples

radius

dw

If the

4.9

with

velocity

rw

dv

cm2 dr

87.65

in

change

dyne-s756

2040756

in

rate

radius

by

10/4

log

at

the

function

is

fluid

power-law

dilatant

However

viscometer

vclpcity

and

fluid

4.18

through

rotational

log

RATE

SHEAR

If there

immediately

angular r2

is

no

and

is

fluid

immediately

If the

small

end

are

r1

no

moving slip

at

adjacent

effect

to

the

the

rotor rotor

Successive

velocity

If there

slip at

adjacent

at

the

at the

to

wall also

layers

is

of

successively

bob

the

bottom

wall

bob of

is

the

the

mo bob

4.2ROTOR

TABLE

Sleeve

Rotor

FOR

BOB DIMENSIONS

AND

ROTATIONAL

VISCOMETERS

Dimensions

Bob

Radius

Dimensions

Rotor

Radius

Length

cm

Type

ENGINEERING

DRILLING

APPLiED

136

cm

r11 r12

1.7245

3.80

1.2276

3.80

T3 r1

0.86225

3.30

0.86225

1.89

Type

ciii

r21 r22 r33

1.8415 1.7539 2.5867

Bob

Assuming

the

viscometer

fluid

no

that

r2 Thus

occurs

slip

velocity

angular

variables

separating

at

in

the

zero

is

Eq

of

walls at

4.46

r1

and

the at

032

gives

dr

360.50

4.47

dw r3

27rh r1

4.25Bottom

Fig

view

viscometer

rotational

of

and

Integrating is

then

ignored

stress

in the

and

r1

the

TT

torque Tcan

the

fluid

at

rotor

r2

related

between

radius

any

radius

be

using

the

to

4.48a 4irhw2

testing

of

the

fluids

drilling

is

torsion

spring

chosen

such

used

generally

shown

and

r2 units

value

the

Substituting

in

yields

1\

360.5071

radius

equation

27rrh

The spring constant

viscosity

shear

the

bob

the

following

for

solving

to

N/60

2ir

Table

in

centipoise

w2

for

and

4.2

this

simplifies

the values

changing

of

r1

viscosity to

equation

the

that

following

T360.5 300 where

the

is

dial

of angular

degrees

for

pressions

of

reading

displacement and

torque

Fann

the

measured

two ex

the

Equating shear

for

solving

4.48b

in

stress

yields

where fluid

cp

viscosity

360.5 dial

4.45

2rhr2

Eq

4.45

fluid

relation

fluid the

is

shear

the

with

the

defining or

does

not

stress

of

square of

consequence and

The shear

plastic

that

inversely

viscometer

the

depend

in

present radius

the

of

geometry

on

the

the

Note

that

rpm

the

This the

of

can

be

related

for

equation

fluid

power-law

the

to

shear

stress

Newtonian

models

using

Bingham

discussed

in

in

the

However will

the is

the

given

will

some

to

300

either

multispeed

200 300

100

desirable

often

operate

at

know

the

is

and

viscometer

Newtonian fluid

Model be

can

then

the

4.48a

described

shear

stress

by at

any

the

Newtonian

point

in

the

fluid

fluid

be

can

for

rearranged

given to

numerically viscometers or 600

600 rpm

shear

rates

speed

of

give

dw

Ly

Combining

this

equation

with

Eq

4.45

expression

with

Eq

4.46

yields

47rN/60

dw dr

4.46 27rhr3p

r30.l37

dr

360.50

2r r1

r2

that

used

present

by

this

is

rotation

360.50

Substituting

rpm

viscometer

is

dr

300

at

operated

Most

centipoise

cases

at

operate

It

model

field in

rotational

If

is

rpm

cylinder

viscometer

the

used rate

in

viscosity

the

and

viscometer

outer

the

viscometer

of

reading

rotational

of

rotation

rotational

the

the

to

equal

nature

if

dial

the

sections

previous

4.9.1

of

speed

indicates

varies

of

reading

yields

in

Eq

DRILLING

HYDRAULICS

Thus

shear

the

137

rate

dw

given

is

or

by

dr

4.49

at

300

Fann

600

and

Compute

rate

cm

1.7245

viscometer

viscometer

normally

API

standard

in the

rpm shear

the

of

radius

r2

19

Example

would

that

these

for

is

operated test

diagnostic

occur

two

Newtonian

contained

rotor

at

bob

the

speeds

the

if

fluid

Eq

Using

4.49

we

Laminar Flow

4.10 The

and

drilistring

obtain

enough

Bingham to

1.703N

frictional

placd

given

300

of

speed

rpm

shear

the

rate

bob

the

at

is

by

are

in

fluid

ing

shape

is

pump

is

Newtonian

development the

or

casing

is

hole

open

the

hole

of open

diameter

drill

the

flow

the

and

incompressible

these

drillstring

sections

known

of

the rate

be employed between flow rate

this

In

rotated

and

the

between

the

made

in the

of

of

model can

are

not being

is

bore

If the

laminar

relation

drop

pressure

concentrically

circular

be

to

mathematical

the

hole

or power-law

plastic

dnllstring rotor

flow

the flow

circular

annular space

or open

casing

the

the

Annuli

with

primarily

circular

simplifying assumptions

1.72452

At

for

develop

and

5.ObbN

the

and

drillstririg

the

up

and

Pipes

down

cements

and

fluids

in

deals

engineer

drilling

drilling

low Solution

dynes0737/Cm2

0.618

5.066N ____________

is

isothermal

seconds

1.703300511

In

at

Similarly bob

the

is

rotor

given

600 rpm

of

speed

shear

the

rate

at

seconds

1022

perfectly

the

In

laminar

actual

has been 4.9.2

The

Non-Newtonian

flow

the

law

of

models

same

the

ing for

summarized be

models

two

flow

must

readings

shear

rates

computational

are

have

flow

the

computed using readings taken

made

and

with

the

fluid

and

distant

from

the

imum

Typical

pattern

arc

the

can

parameters

he

sidered ner

as

of

speed of

of 300

600

rpm

behavior

viscometer

rotational

fluid

dial

gives

rpm and Compute

index of

the

dial the

containing

reading

reading

of 20

consistency

model

power-law

of

12

at

at

rotor

index and for

this

non-

of

diagram

The

the

direction

rotor

Using

consistency

Table

index

are

4.3

flow-behavior

the

by

given

flowfluid

Thus

of

51012

5ll

61.8

eq

cp

flow

index and

the

is

shell is

interest

of

in

from

left

of

interest is

of

given

force

by

p2rrLSr

fluid

moving

interest

The

F1

can

in

which

of

motion

to

next

moving applied

than shell

and

the

of

thickness

such

is

and

that

increasing by

fric

shell

of

right

of

in

free-body

4.27

the

con

the

from

for

the

fluid

fluid

that the

radius

fluid

ele

element

fluid

slower than by

down

and

is

z.L

Fig

flow

zero

obtained

4.27

the

figure

be

stress

enclosed

faster

the is

flow

be

with

decreasing

in this

telescoping

Pipe

the

max

be

laminar

for

are

Fig

used

is

Furthermore

element

F1

flow

next

the

interest

Point

log20/120.737

of

will

of length

fluid

convention

sign

velocity

of 3.32

of

in

speed

ment of Solution

law

Shown shell

L\r

in

walls

can

dpf/dL

Newtons

of

radius

at

adjacent

shear

radius

between

pressure gradient

is

velocity

value

speeds

fluid

420

has

pipe r1

the

does

pattern

fluid

of annular flow

case

annulus

As shown

velocities

the

practice

to

profiles

laminae

fluid

limiting

consideration

Newtonian

of

in

flow

the

pipe

additional

remove

justified

the

Fig 4.26

different

at

radius

tional

Example

velocity

in

rings

conduit

relation rotor

flow

shown

the

to

immediately

velocity

variations78

pressure

If

research

eccentricity6

concentric

velocity

zero

most

Some

required

the

approximate

only

However is

power-law account

into

of pipe

and

be

region

and

in

mind

in

keep

behavior

seldom

computa

characterize

and

pipe or

in

will

Normally

in the

lower

at

above

uniform

walls

pipe

mud

temperature

listed

Fluid flowing

laminar

take

effect

complexity

assumptions

the

it

lower

are

parameters

speeds

and

at

and

the

should

not

will fluids

drilling

plastic

fluid

on

of

not

pressure gradients

concentric rotor

flow

equations

plastic

be

flowing

follow

equations

Bingham

on

not

the

derivations

final

two

the

different

at

of

600 rpm readings are used However when is desirable to

300

fluid

Since

both

for

viscometer

rotational

tion

43

the

powercalcula

for the

These

and

and

derived by

derivation

model

Table

in

be

determine

to

plastic

needed

can

in the

Appendix

calculated

power-law

the

used

steps

in

Bingham

parameters

Newtonian

the

presented

must

the

used

do

drilling

conducted

pipe rotation be

also

The equations

flow

these

can

of

parameters

fluid

tions

Models

viscometer

rotational

Bingham

completely

equations

flow

student

models

nature of

thixotropic

of

system

the

Newtonian

are

assumptions

laminar

addition

rheological

the

these

resulting

the

fluid

of

the

well

that

1.703600

and

describe the

by

none

reality

valid

of

enclosing

the element pressure

at

133

APPLIED

43SUMMARY

TABLE

OF EQUATIONS

FOR ROTATIONAL

300 Newtonian

Bingham

Model

Plastic

DRILLING

ENGINEERING

VISCOMETER

vN 5.066

7ON Model

3U0

or

300

3.174

479r

5.066

0JN

___N___L__

0N2

_i

oo

Ty

or

N1

_tp

TYON

rpm

OmaxCt

PowerLaw

Model

n3.322

log 0300

or

log..i

510

7O.2094N

Shy or

5100

1703

Likewise

the force

Point

given

is

F2

applied

the

by

fluid

pressure

at

If the

fluid

sum of

by

the

element forces

on

acting

we

forces

Summing

moving

is

constant

at

the

elements

the

velocity

must

equal

zero

obtain

dpf

dL

27rthrp_27rrLrp____LL The

negative

because

The fluid

frictional

P2

p1

represent

for

sign

the

frictional

enclosed

rather

the

is

change

by

element

required

is

used

to

shell

of

Pi

P2

than

exerted

fluid

tenri

dpf/dL

pressure

force

by

the

the

of

dT

dr

adjacent interest

2rrLr2Lrrrr0

is

given

by

Expanding

Similarly

given

F4

and

taking

the

dividing limit

as

through

r0

by

yields

r2irthL

F3

shell

equation

this

2irrL1rzL

of

the

fluid

fnctional that

encloses

force the

exerted fluid

Trr

by

element

the

of

dpf

drr

dL

dr

4.50

adjacent interest

is

by

dT

Since

dp/dL

tegmted

is

with

not

respect

drr dL dpcr

\rdr

dr

function to

of

Separating

Eq

4.50

variables

can

be

yields

in-

DRILUNG

HYDRAULICS

139

--

Fig

4.26Velocity

4.27Free

Fig

Upon

we

integration

laminar

for

profiles

body

flow

diagram

for

If

4.51 dL where

C1

the

which

radius

and

shear

derivation

Newtonian

the

model

can shear

the

flow

element

fluid

fluid

constant infinite

and

Mocld

be

described

stress

at

with

any

point

with

Eq

the

Newtonian

in the

fluid

is

fluid

given

of

the

require

be

zero

Eq

if

geometry of

assumption

dr

4.51

pressure gradient

the

dv

for the

that

must

at

frictional

consequence

not

Note C1

of

is

rate

given

this

Combining

the

convention

sign

used

4.51

gives

fluid

dv for

equation

the

model

rheological

The

the

be

to

stress

is

does

of integration

flow

not

is

shear

relates

system

constant

of pipe

stress

given

at

the

is

shear

annular

by

case

special

and

flow

annular

4.10.1

obtain

C1

dpy

pipe

in

the

C1

dpf

dr

dL

by After

-_ dv

variables

separating

and

integrating

we

obtain

4.52

dr r2

The

shear

defining

rate

can

equation

or power..law

fluid

be for

related the

model

to

shear

Newtonian

stress

using

Bingham

C1

dpf

......-.-1nrC2

the

4i

4.53a

11

plastic

where C2 drilling

is

fluid

the

second

wets

the

constant

of integration

pipe walls

the

fluid

Since layers

the

im

APPLIED

ENGINEERING

DRILLING

140

mediately

rr2

to

adjacent

have

4.53a

zero

rr1

these

Using

and

at

was developed

relation

For annular

flow

rate

the

is

mean

velocity

area

cross-sectional

qirr

C2

lnr

Lamb.9

by

first

flow

the

annular

the

multiplied by

dL

4p

This

boundary

yields

C1

dpf

at

walls

pipe

of

velocity

Eq

in

conditions

the

this

Substituting for

ing

the

for

expression

frictional

Eq

in

gradient

pressure

4.54a

and

solv

gives

dpf/dL

and

dpf

Ci

dp

lnr2C2

rr

dL

dL

4/L

4.54h

________ lnr2/r1

two equations

these

Solving

for

simultaneously

and

C1

C2 gives

from

Converting field

1dpfrr dL

consistent

Lambs

units

units

more

to

convenient

becomes

equation

lnr/r1

4.54c dL

and

lnd2/d1

rlnr1rlnr2

dpf

l500d

where

C2

flow

mean

dL

4/L

______

cp

viscosity these

Substituting

4.53a

fts

velocity

lnr2/r1

for

expressions

and

C1

C2

frictional

dpj/dL

Eq

in

outside

d1

yields

gradient

pressure diameter

psi/fl

inner

pipe

in

the

outer

pipe

in

Eq

4.54c

becomes

of

the

and

dpf

diameter

inside

d2

lnr2/r

1nr/r11 Note

4.53h

that

in the

dp

limit

as

of

p0

d1

fLu

4.54d Note

that

brackets pipe

in of

the

limit

Eq

4.53b

as

second

the

r1

also

zero

approaches

dL

in the

term

Thus

l500d2

for

flow

This

is

equation

circular

in

pipe

the

familiar

law

Hagen-Poiseuille

for

units

field

dpf

v----rr2 4i dL If the

4.53b

pressure gradient and

4.53c

can

be

4.53c

and

are

viscosity

used

to

dctcrmine

known the

Eqs

velocity

distribution

within

an

However

relation

between pressure gradient and total for most engineering applications

flow

The

rate total

contained

needed

is

flow in

rate

each

can

annulus

or

be obtained

concentric

shell

pipe

by

respectively

summing

of fluid

the

flow

Example

4.21

viscosity

of

containing rate

of

2ir

80

bottomhole

Newtonian

9-Ibm/gal cp

is

circulated

being

7-in.-ID

casing

and

gal/mm

Compute

pressure

by

fluid

in

5-in.-OD the

static

well at

drillstring

and

circulating

laminar

that

assuming

having

10000-ft

flow

exists

pattern

Thus The

Solution

qv2r

15

4.2b

Since

static

bottomhole

annulus

the

is

dr

open

pressure to

the

is

given

by

atmosphere

Eq

at

the

surface

pO.O529lO000O468O

dPfr2

psi

dL

r1

If fluid

dr

_rr_r12r

pressure

lnr2/r1

Upon

integration

dpj

q------

acceleration

bottomhole

lnr2/r

this

As

equation

4r

shown

given

becomes

effects is

pressure plus in

the

frictional

Table

4.1

are the

neglected

sum

pressure the

mean

of loss

4.54a

circulating hydrostatic

in the

annular

annulus

velocity

by

r_r2 lnr2/r1

the the

2.448dd

l.362ft/s

2.44872_52

is

HYDRAULICS

DRILLING

141

Fig

The

frictional

the

4.28Representing

pressure gradient

determined

is

annulus

using

as

Eq

4.54c

slot

annular

force

F1

applied

151 362

the

by

fluid

Point

at

pressure

is

given

F1

7252

dL

15007252_ 7/5

In

0.0051

Since

the

total

pressure

loss

ft51

10000

psi/ft

the

Point

given

is

bottomhole

The

frictional

given

the

flow

flow

accurate

minimum

ratio

can

and

be

As

using equations slots

The

to

use

and

ratio

d1/d2

rectangular simpler

long

as

the

almost always

As shown

in

is

slot

given

slot

F4

are

in

rotary

an

annular

having

an area

Arr

force

fluid

exerted by

element

of

the

adjacent

interest

is

4.55a

hr2r1

4.55b

relation

pressure gradient

element

of

element

of

the

fluid fluid

between

of

the fluid

frictional the

above

force

exerted

element

fluid

rWL

for

slot

in the

having

slot

of

fluid

by

of

shear can

stress

be

Fig 4.29

width

and

obtained

viscous

and

forces If

we

the

by

interest

adjacent is

given

dr

_yWL dy

flow

If the fluid

is

element

steady

the

sum of

be equal

must

to

the

zero

forces

F1F2F3F4

dpf

frictional

from acting

con on

an

consider an

thickness

the

r1tsy WtL0

acting

Summing

obtain

pwzy__jL

pressure and

layer

given

and

of

at

by

by

and

sideration

pressure

0.3

exceeded

Fig 4.28

narrow

as

represented

height

The

fluid

by

Slot

approximated

much as

applications

drilling

be

through

are

equations

reasonably

space

can

also

for

Annulus

the

Representing flow

the

F3rWL

psig

layer

developed

by

by

Similarly

Annular

applied

is

psi

is

pressure

p46SOSI473l

4.10.2

F2

F2p2 WzXyp_-f--L Way

annulus

in the

below circulating

force

Likewise

psi/ft

frictional

pjO.OOSl

This

slot

equivalent

by

dpf

the

and

WiyrWL

on

forces

the

we

APPLIED

142

ENGINEERING

DRILLING

FL F3

4.29Free body

Fig

this

Expanding

WLy

and

equation

dividing

diagram

through

by

for

fluid

element

and

yields

h2

4.56 dL

r0h

dpf

2dL

dpf

vo

jz

dy

Thus Since

slot

narrow

in

with

tegrating

function

not

is

dpf/dL

tegrated

to

respect

Eq

of

4.56

can

variables

Separating

be and

constants

the

of

and

integration

v0

are

given

by

in dp1

in

dL

gives

dp 4.57

and

v0 where to

the

shear

constant

stress

at

of

yO

that

integration

For

the

sign

corresponds

convention

used these

Substituting

shear

the

the

is

rate

given

is

values

for

r0

by

and

v0

in

Eq

4.59a

yields

dv

4.58 4.59b

dy

dl

2/L

Thus

for

Newtonian

the

dv

ft

TLy

variables

we

obtain

The flow

and

gives

integrating

this

4.59a

v0

\vets for

the

yh

4.59a

equation

yields

dpf

4.60a dL

12/1 the to

corresponds

hyy2dy

0y

dp

is

by

qvdAvWdy___f

2dL wheie

given

dp

T0 dL

Integrating

y2

is

rate

dpf

dy

Separating

model

second

the

pipe walls Applying

constant

fluid

velocity

the

velocity

these

of

v0

boundary

which

integration

aty0 is

Since

zero

for

conditions

the

fluid

y0 and to

Eq

Substituting

Eqs

4.55a

the

and

expressions

4.55b

in

Eq

for

Wh

4.60a

and

given

by

gives

yields

OO0v0

q.._L.r22_rj2r2_ri2

4.60b

DRILLING

HYDRAULICS

the

Expressing

and

velocity

143

flow

rate

terms

in

for the

solving

of

frictional

mean

the

flow

gradient

pressure

shear of

stress

pipe wall

the

at

Newtonian

the

the

using

defining

equation

model

gives

dpf/dL

4i

4.62a

dpf

______

4.60c

r2r12

dL

from

Changing from

Converting field

of pounds

units

and

second

consistent

units

inch centipoise

per square

we

inches

feet

per

________

dL

l000d2d12

circular

4.60d

where

the

mean

the

internal

the

shear

annulus

the

Compute

discussed of

representation tern

the

in

frictional

Assume

annulus

the

loss

pressure

4.21

Example

using that

this

the

for

lot

flow

flow

pat

stress

given

is

by

where

wall

for

Eq

is

ratio

has

d1/d2 than

greater

value

Eq

0.3

0.714

of

4.60d

can

be

100022

dL

that

Thus

given

shear

the

approxima at

stress

the

by

r2r1

dpf

4.63

dL

the

for

expression

Eq

given by

r2r1

Tw

4.60c

the

in

frictional

Eq

4.63

pressure

yields

this

value

same

the

is

for

Eq

using

frictional

pressure

4.54e

12j2i

Lr2_ri

psi

was obtained

that

and

.3621510000

dp

loss

second

per

of inches

Since

gradient

Note

obtain

applied Substituting

51

feet

units

slot flow

annulus

an

4.57

is

dpf

The

ratio

we

units

seconds1

of

units

of

units

pipe has

the

dL Solution

field

4.62b

has

velocity

has

rate

laminar

is

to

pipe

diameter of

The shear tion

Example 4.22

units

96

obtain

dpf

consistent

convenient

more

to

Thus

for

laminar

rate

the

pipe wall

at

flow

of

Newtonian

given

is

fluids

shear

the

by

6i Determination

4.10.3

of

knowledge sometimes

can

fluid

parent

in

present

sometimes

Newtonian the

closely

rates

Care

well

can

be

If

achieved even

Newtonian

4.51

For with

circular

is

Tw

given

taken

if

well

the

the

good

flow

shear shear

the

field

becomes

equation

d2d1

4Mb

annulus

not follow

range

of shear

occur

stress stress

is

at

at

the

given the

by wall

by

Example 4.23 Compute annulus flow

discussed

pipe

4.61

is

pattern

dpf circular

this

units

144

for

equations

will

In

ap

accuracy

does

wide rate

the

near those

rates

4.64a

r1

well

pressure

measure

fluid

of shear

pipe

to

done

model over

the

in the

of shear is

in

present

using

Thus

C1

where

be

this

r2

accuracy

values

at

viscosity the

fluids

can

Rate

rate

improved

The maximum value

pipe walls

Eq

to

determination

loss

shear

the

lead

Shear

of

The

Solution

Mb

the

shear

rate

4.21

Example

in

at the

wall

Assume

for the that

the

laminar

shear

rate

98

at

the

wall

is

given

by

Eq

1441.362

the

Substituting

gradient

expression for

dpj/dL

/8/n

for

circular

the

pipe

frictional

into

Eq

4.61

pressure yields

Thus

ji

the

rate

at

the

pipe wall

can

be obtained

from

the

for

well

seconds

rb

The shear

seconds

improved

fluid

should

accuracy be

measured

the

apparent at

shear

viscosity rate

of

near 98

44SUMMARY

TABLE

Pressure

Frictional

Newtonian

OF LAMINAR

FOR

FLOW EQUATIONS

Shear

Loss

Pipe

Wall

Pipe

1500d2

ulus

Ann

dp

IWd

d2-d12

1000

ulus

144v

_________

dL

Plastic

At

96v

dL

Bingham

Rate

Pipe

dp

Ann

ANNULI

AND

PIPES

ENGINEERING

DRILLING

APPLIED

144

Pipe

Pipe

96v

Upv

dL

1500d2

225d

Lp

Annulus

Ann

dp

ulus

144v

__________

dL

d2d12

1000

239.5f--

d2d1

200d2

Power-Law

Pipe

Pipe

KV dL

31n 24v

131ln d14 0.0416

144000

Annulus

Annulus

Kv

dpf

dL

Non-Newtonian

4.10.4

Analytical of

The

reader

is

and

ment of

annular

nular

the

However flow

interest

the less-complex of

derivations

Bingham

slot

to

flow

and

The

summarized

of

the

for

use of

The

for

the

are

given

is

loss

pressure

predicted

by

given

94001.8O3

dp1

_21/0.3

14400O8.O974.5

dL

0.0779 Also

or 77.9

psi/ft

using Table

pipe wall

is

derived

4.4

0.0208

ft

psi/l000

the

approximate

shear

rate

and

Annuli

at

the

by

given

481 803

in

21/0.3

narrow

as

equations

frictional

usual

the

slot

model

the

model

develop

through

represented

The flow

power-law

and

narrow

fluid

was

Table

the

fluids

equations

for

flow

0.0208

4.4

Using by

for Bingham plastic Newtonian fluids an

engineers

power-law

annulus

of

accurately

equations

4.5

8.097 are

4.4

Table

in

case

drilling

these derivations

in

equations

laminar

the

plastic

Appendix

flow in the

flow

Laird0

of

discussion

for

12lIn

d2d1

following

Newtonian

for

work

the

to

modeled

be

can of

geometry

as

laminar by

derived

used

steps

Bird11

isothermal be

the

can

referred

Fredrickson

fluids

for

fluids

same

the

essentially

0.0208

Models

expressions

non-Newtonian

d2d11

144000

48v

21fflfl

128 seconds

Example 4.24

cement

index of 0.3 and ing

pumped

gal/mm the

in

8.097

an

frictional

pressure

estimate the shear

rate

loss at

1000

is

flow-behavior

9400

annulus

pattern

per the

has

index of

4.5 in

the flow

Assuming

that

slurry

consistency

at

eq cp

laminar

ft

is

be

4.11

200

In

compute

at

rate

of annulus

of

Also

pipe wall

many

by Solution annulus

Table

Using is

given

the

average

by

velocity

in

the

803

2.4488.0972

...452

ft/

chaotic

distribution

thin

become

to

of

the

boundary

remains

in

laminar

and

fluid

become conduit layer

laminar turbulent

of

Pipes

the

laminar

for

flow pattern

this

portion

200

rate

laminae

diffused

in

operations

drilling

too high

fluid

Flow

Turbulent

drilling

flow

unstable and

The

be

to

movement

fluid

flow

for

laminar

near

the

pipe flow

is

chaotic

the

across

flow

pipe

schematic

pumped The

momentum

causes

more uniform than

is

into

break of

transfer

fluid

maintained

caused

velocity the

walls

generally

representation

shown

in

center

However of

Fig 4.30

DRILLING

HYDRAULICS

145

4r

DYE

TRACERS

4.30Laminar and

Fig

and

mathematical flow

turbulent

the

encing

to

been

4.11.1

The

Newtonian

shown

that

tonian

fluids

flow

mass

of

through of

density

that

for

equations

has

flow

the

been

done

fluid in

pressure

identified

of

these

analysis

fluid

data could

For

ex

be

in

Osborne

Reynolds12

terms of

In

time

has

New

in the

flow

on

pipe diameter of

viscosity the

these

of

of

units

primary

have

the

dimensions

m/L3

Buckingham that

that

groups

can

of

theorem

ir

number

the

m/Lt

of

be obtained

from

analysis

dimensionless is

parameters

given

by

number

Reynolds

number

Reynolds

numbers of about in

actually fully

has

the

ting

be

using

by

three

all

one

of

number of primary

tlie

units

primary four

the

units

and

parameters

shown

are

9.0-lbm/gal

1.0

circulated

being

is

cp

gal/mm

involved used

Since

one

ble The dimensionless pressed

in

consistent

grouping

units

in at

equation

Reynolds

commonly

is

drilling

if

well

viscosity

at

the

fluid

the

internal

of

rate

in the

drilipipe

diameter of

of 600 is

the

The average

in

velocity

the

is

drillpipe

given

Eq

used

ft/s

2.44842762

d2

4.65b

number

the Reynolds

is

given

by

possi is

ex

928

p5d

9289.013.44.276

NR

by

number

situations

478556

In

field

units

this

fluid

the

number

Reynolds

in the

drilipipe

is

in

is

well

turbulent

above

2100

the

flow

becomes

928

NRe

the

as

that

conditions

these

13.4

Since is

high

pipes

least

4.65a

NRe

as

straight

600

group

NR

where

hit

in

previously

dimensionless

to

ar

by

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the

brine having in

flow

turbulent

4.276

is

2.448

independent

rotary

is

and

by

Using only

1200

as

However

whether

Determine

laminar or

N43 and

smooth

in

Example 4.25

Solution is

realized

flow

may be made

numbers

Reynolds

vibrations

not

are

to

extremely

for

flow

system--e.g

the

the

experimen

careful

low

as

the

if

the

laminar

region

into

energy

extended

from

insulated

drillpipe

rn

number

fluid if

However

4000

to

hammer Likewise

pipe with

region can

turbulent

flow Also

Reynolds

40000

and

between

laminar

the

introducing

laminar

100

2000

region

that

be

than

greater

turbulent

shown at

tificially

is

Newtonian

of to

2100

than

less

is

transition

developed

tation

in

where

flow

considered

L/t

dimensional

independent

and

cp

Reynolds

generally

Units

in

purposes is

usually

terminate

fluid

variables

ft/s

velocity

viscosity

engineering

pipes

are

states

flow

factors

numbers

turbulence

velocity

fluid

By ap

Parameter

The

turbulent

Ibm/gal

density

mean

influ

factors

frictional

been

pipes depends

and

and

laminar

between

transition

where

However

the

empirical

fluid

length

following

laminar

pipe diameter

and

have

the

work

onset

the

pipe

Fluids

experimental

average

flow

of dimensionless

terms

circular

date

pipe and

circular

so

flow to

work

of turbulence

grouped

in

pressed

of

possible

experimental

turbulent

in

patterns

method of dimensional

the

plying

been

not

of

unset

due

losses

have

of

sections

straight

flow

flow

development

has

amount

large

turbulent

turbulent

pd

Once

4.65b

it

turbulent loss

must

has

been

the

determination

be

based

established

on

of

empirical

that the

the

flow

frictional

correlations

pattern

is

pressure

The most

APPLiED

ENGINEERING

DRILLING

146

1.0

0.5

0.2

0.05 Ls

0.02 E/d

Turbulent

0.01

0.004

000

0005 Li.

0.0004

0.000 0.002 0.001 i02

i06

REYNOLDS Fig 4.31Stanton

used

widely

is

correlations

known

quantity

defined

the

as

chart

on

based

are

The

factor

friction

showing

NUMBER factors

friction

fanning

turbulent

for

dimensionless

Substituting

friction

4.66a

factor

NRe

these

flow

circular

in

expressions

pipe

for

and

Fk

Eq

into

Ek

yields

by

dpf

.1 Fk

dL

4.66a

AEk

4.66b

2pv2A

where force

Fk

on

exerted

characteristic

Ek

conduit

the

walls

due

to

If

kinetic

area of

energy

per

the

the

unit

conduit

volume

reduces

given

pipe

flow

Eq

by

shear

the

stress

fluid

dL

4.66c dL

on

conduit

the

walls

is

4.66c

friction

dp

ning

4dL

the

is

factor

force

Fk

exerted

at

the

pipe wall

due

to

fluid

motion

by

where depth tion

ird2

Fk

rid

27rrziLr

presented given

Ek

kinetic

pv2

energy

per

unit

volume

for

of

fluid

is

given

The

absolute

the

of

pipe-wall

the

NRe relative

turbulent by

term

roughness to

roughness roughness

Colebrook

13

is

the

An

the

of

relative

defined

as

the

pipe diameter the

empirical

of

friction

factors

in

circular

pipe

The

the

Fan

the

function

is

called

represents

irregularities

flow

called

is

factorf

and

and

equation

equation

friction

determination

the

Fanning

this

by

The

absolute

the

developed

dpc

dL

The

of

as

defined

Number

Reynolds

ratio

known

factor

friction

roughness

given

2irrAL Eq

4.61

dpf

is

be

to

dp

Eq

The

chosen

is

to

and of

2pv2 For

area

characteristic

4.67b

movement

fluid

Colebrook

average correla for

has

fully

been

function

is

by

by

l.255\ log

\O.269

eid

4.67a

HYDRAULICS

DRILLING

147

TABLE 4.5ABSOLUTE PIPE ROUGHNESS FOR SEVERAL TYPES OF CIRCULAR PIPES Streeter14

after

70 II

Absolute

Type

in

Pipe

of

0.00025

steel

Concrete Cast

of

plot

factor

log

paper

the

Colebrook

the

solution

of

not

difficult

and

ble

using

The for

the

4.5

average

for

an

in

pipes

average

pipe

most

of

tions

in

the

fluids Also

is

values

is

less

conditions

zero

roughness

calculations

the

can

be

to

in

Eq

to

extended for

factor

the

laminar

the

4.67d

to

The proof

of

this

relation

turbulent

simplified

smooth

and

pipe

is

100000

Eq

substituting

equation

moderate

4.67c

be

can

developed

numbers by

Reynolds

Eq

into

student exercise

as

left

flow

drilling

4.66d

relative

For

smooth

4.67a

friction

by

0.0791

pipe

25.8d

most engineering

for

applied

defined

be

can

equation the

if

found

sections

all

for

is

Fanning

region

in

for

the

factors

flow

16

applica

exceeds

0.0004

the

addition

em

apply

viscous

geometries

friction

In

Cullender

drilling

rotaly

pressureloss

4.26

Example

Table

obtained

in

relatively

than

in

service

pipeline

in

smooth pipe

For

data

turbulent

and

laminar

of of

equations

region

roughness

Also

0.00065

number seldom

usually

these

of

use

welibore

most

roughness

and of

4.32Comparison

is

possi

determined

published

gas well

the

is

Shown

difficult

VELOCITY

FLUID

5.0

ft/c

However

than

absolute

conduits

of

Fig

for

laminar

types of

Reynolds

for

often

Fortunately

involving

log-

calculator

results

appropriate

roughness

data

the

on chart

solution

study

steel

Fig 4.31

precise

AVERAGE

by

4.0

3.0

2.0

.0

function

electronic

roughness

several

Smith

clean

an

application

are

pirically

more

avoided

Stanton

in

using an

graphical of

shown

is

4.67a

yields

selection

given

and

Eq

chart

the

iterative

number

Reynolds

Stanton

function

be

can

Colebrook

the

against

called

is

outside

requiring an

difficulty

of

and

inside

equation

This

representation

friction

lfl

-J

13

both

appears

Colebrooks

technique

graphical

0.0000

0.0000004

factor

of

solution

steel

tubing

friction

term

0.000033

iron

cast

Commercial

log

0.000042

iron

Asphalted

The

2100

0.00083

to

0.000071

iron

Galvanized

Drawn

0.0025

to

0.000033

flc

1.314

-J

Riveted

41

trli

Roughness

reduces

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to

0.25

928PPd\

\tL 4logNRe_0.395

4.67b this

Simplifying In

addition

smooth

for

2100

range

of

on

log-log

This

approximation

given

pipe

100000

to

of

plot

the

and

Colebrook presented

first

approximation

function

is

p0.75q1.75th0.25

dpf

is

8624d75

l800d25

dL

16

______

_____

possible

Blasius

by

yields

number

Reynolds

straight-line

expression

by

4.66e 0.0791

4.67c

0.25 hiRe

for circular

and

the

2lOOsNRelOOOOO

where formula

allows

and

nomographs used

in

the

and

construction

the

hydraulic

special

by

past

of

field

e/d0

The

slide

personnel

in

Blasius

hydraulic

simplified

rules the

widely

relative

ample 5-in

it

would

drillpipc

drilling

by

drillpipe

about

NRe form

of

that

changing

reduce of

factor

the

is

2100

between

that

readily

various

the

from

pressure

iden

hydraulic

pressure loss

frictional

shown

be

can

and

in

is

importance

turbulent

on

parameters

/d0

4.66e

Eq

100000

tifies

where

pipe

For

4.5-in loss

in

ex to the

two

industry

The

Fanning of

calculation

flow verting

in circular to

field

can

equation frictional

pipe units

be

rearranged

pressure drop Rearranging

due

to

Eq 466c

for

the

turbulent

and

con

Example 4.26 Determine 10000

gives

of 3.826

4.66d dL

25.8d

ft

of 4.5-in in

of

lbmgal

400

gal/mm

if

is

the

drillpipe

20-cp

pumped

frictional

an

having

Newtonian through

fluid the

in

pressure drop

diameter

internal

having

drillpipe

density at

rate

of

APPLIED

ENGINEERING

DRILLING

148

The mean

Solution

fluid

is

velocity

400

l1.l6

ferent

equation

when

the

equation

ft/s

2.4483.8262

2.448d2

Newtonian

of

by

given

flow

may

transition

number

Reynolds

is

given

criteria

by

the

9289l

928pfd

NR 20

flow

turbulent

is

pattern

solute

is

roughness

Thus

number

Reynolds

the

relative

is

than

greater

For commercial Table

in

given

100

the

the

ab

steel

4.5

0.000013

as

is

roughness

flow

Consider

Fig

on

Eq is

this

4.67b

corresponds at

by

0.00666

and

Thus

the

frictional

dp1

fpD2

dL

25.8d

to

smooth

the

number of

error

the

17831

Solving

friction

Fanning

loss

pressure

This

pipeline

factor

given

is

by

illustrated

be

to

and

loss

ex

not observed

is

the

using

in

given

properties

of

range

shown

Table

in

20tl0000

l500d2

15003.8262

has

mean

been

Example

is

the

4.4

gives

fluid

frictional

approximated

fluid

velocities

the

and

wide

for

Fig 4.32

At higher

turbulent

fully

be

can

At low

and

9.llv

in

plotted

velocities

fluid

pattern loss

pressure

laminar

is

p.iAL

flow

the

Example 4.26

in

pattern

equation

equation

frictional

Eq

4.66c

Fig

4.32

using

V175/L25AL

p075

AL

0.0066691

flow

______

closely

Reynolds

trial

fluid

data given

the

loss

pressure

3.826

4.31

can

the

artificial

an

pressure

generally

problem

and

the

velocities

0.0000034

that

This

geometry

between

relation

which

velocity

as

equation

causes

often

the

flow

100

flow

laminar

the

in

turbulent

number

Reynolds

equation

the

pressure and

neither

loss

4.26

0.000013

Note

in

dif than

However

the

laminar

from

flow

perimentally pipe

the

use of

the

changing

turbulent

mean

831

between

is

laminar

is

using turbulent

determined pattern

accurately

predict

discontinuity

163.826 17

Since

for

be

flow

the

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Furthermore The

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l800d25

1.16210000

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1.75

90.75 psi

25.83.826

It

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the

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this

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As discussed loss

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4.32

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ft/s

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4.11.2

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2.100

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2100

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ning

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928pi7d

_____

90.7511161.75200.2510000

The

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DRILLING

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To avoid tional

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Fig 4.32

the

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identical

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the

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compute laminar

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relation

mean

and

assumed

is

the

in

discontinuity

pressure

sumetimes

149

circular

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to

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All

above

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de

Note

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diameter

for

4.68a no

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inner

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the

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the

diameter

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for

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4.68a

is

petroleum

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the

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tions

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4.54d

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laminar

Newtonian

Comparing

the

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for

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pipe

fluids

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in

the

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Example 4.27

9.0

of

circulated

the

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as

Eqs

4.54c

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tern

10.0

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d22

d22

de

by

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Eqs

for

4.68a to

drillpipe

5.0 in

and

viscosity

having

well

in

at

4.68d

The

the

to

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pat

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200

equiva

computing

determine

of

rate

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pressure gradient

diameter of

diameter

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is

The

Solution through

tamed using

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brine

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d22 d1

Thus

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Apply

diameter

lent

of

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cp

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1.0

pressure-loss

Consider

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cir

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4.68d

d2

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as

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4.68a

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10.05.05.0

4.68a

in

by d2

d1

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4.68b

ln

d2/d

lnd2/d1

third

annulus

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be

for

obtained

the

by

equivalent comparing

diameter

Eqs

4.54c

of

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_.f2l05_4o99 ln

in

4.68b

APPLIED

ENGINEERING

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four

all

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fluid

the

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is

4.68c

d2 d1 in

d12

22

Note the

d2/d1

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should

54

411.4

l0 52

102_5

be

The

In

frictional

flow

of

Bingham and

density fluid

7.309

4.68d

iii

flow

and

both

fluid

higher shear

The

true

given

is

velocity

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by

the

pattern parameter

200

d1

2.448d2

tional

1.089

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fictitious

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criterion

is

needed

velocity

to

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more

200 2.4487.3092

2.448de2

1.529

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model

When

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number

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and

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928p9d

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9289.0

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4.66e

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frictional

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in

Table

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slurry

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4.4

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1800

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91.75

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9O.751O.25

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125

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O.75 p1.75o.25

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the

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highly

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empirically

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2.448102

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fluid

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_______

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4.68c

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4.27

Example

in

agreement

close

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gl.75

0.002887 125

The

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summarized

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for

each

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the

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methods

Pa9

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l500d2

l500d2

are

follows Solving

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4.68a

3.000

4.68b

4.099

4.68c

4.080

4.68d

Ty

7.309

the

apparent

Newtonian

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gives

dL

45476

4.48x

10

1.089

37282

5.75x

10

1089

37.109

578x

10

93337

497x10

1.529

for

6.66rd fL0

4.69a

HYDRAULICS

DRILLING

151

lO

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34567B9

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HEDSTROM Fig 433Critical

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of

comparison Table

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4.4

laminar

the

Newtonian

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NUMBER

numbers

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flow

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for

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4.70

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Fig

above

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simultaneous

Parameter

4.33

It

L/t

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of

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4.71 16800

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Ty

Ty

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the

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number

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number could

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the

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as

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2100

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In

apparent

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4.69b

ip

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Newtonian

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As shown number

NRCC ___________

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pid

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p.p

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4.72

APPLIED

152

flow

If the

be

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Reynolds

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Colebrook

in the

to

deterniine

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fric-

flow

__________________________

428

Example

of4O

viscosity

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if

of

length bulence

rate

pressure

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the

collars

drill

1000

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the

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in

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Check

viscosity

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represent

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velocity

number of 4218 is

pressure drop

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25.8db

have for

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0.0098l0l1.l42l000

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25.81.632

equivalent the

289

and

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note

to

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the

fric

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Reynolds

______

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drill

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smooth

for

for

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geometry

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function

0.0098

the

concept

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approach

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ft

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Estimate

6.5-in

apparent

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the

of

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turbulent

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tion

NRC33OO

than

greater

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plastic

lbf/100

15

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number

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of

point

600

of

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the

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4218

Since

ENGINEERING

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4.66e

the

that

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simplified

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by

25L

O.75 1.7S 600

800d125 2.448/22

2.4486.52 ...452

d1

10

l1.14ft/s

40

11.14

1000

1800l.632E25 The apparent

Eq

mean

at this

viscosity

velocity

is

given

by

289

4.69b

5rd2

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It

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flow

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40 5152

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to

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the

of

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use

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200d2d1

11.14

an

Computing

diameter

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using

4011.141000

4.68c

151000

yields

2006.54.5

l0006.54.52 de

Thus 53.5

d1 0.8162

0.816d2

number

the Reynolds cp

is

given

1.632

149

an

for

in

apparent

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by

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928

NRe

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928lO11.14l.632

than

less

value

the

Thus

relations

frictional

pJd

psi

of

loss

pressure

predicted

flow

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the

by

turbulent

the

giving

pattern

greatest

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turbulent

3154

53.5

Since

NR 2100

turbulent

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pattern

is

indicated

4.11.5

Power-Law

Dodge

and

Metznert9

correlation

Their

37100 PTp1e2 NHe

37100lO151.6322

9263

40 Using

Fig 4.33

indicated

40 cp

is

the

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the

laminar For

power-law

Reynolds

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for

number of 3300 plastic

viscosity

928

gained

An

industry

number flow

equations

for

Newtonian the

for

laminar

in

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by comparing and

power-law

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144000dn

by

928

10

11.1

1.632

Solving

for

the

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4218

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model

power-law

widespread apparent

criterion

equations

example

the

flow

turbulent

published

follow

in

and

Table

4.4

1/n

of

1500d given

that

has

correlation

petroleum

have

fluids

yields

critical

The Reynolds

for

the

fluids

Model

Kdt

a961

31/fl\n 0.0416

0.0416

Newtonian

viscosity

yields

153

HYDRAULICS

DRILLING

0.l

0.0

zt

U-

0.001

0.0001

REYNOLDS 4.34Friction

Fig

the

Substituting

apparent

number equation

the

in

viscosity

factors

NUMBER for

value

For

and

89l00pt2

As

4.73

31/n of

case

in the

the

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0.0416d

apparent

with

used

factor

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given

by

given

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not

new the

friction

Newtonian

000d7

number

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is

is

shown and

for

flow equations in

Table

4.4

d12 21/n

000d2d08

4.74

n/2

developed

not

severe

in is

for

only

for

limitation

graphical

applications

4.74 is

was

correlation

fluid

given

to

viscosity

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correlation

for

Fa

the

Newtonian

apparent

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gives

representation

Fig 4.34 The upper identical

to

smooth most

line

smooth

the

on

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pipe

drilling

Eq

of

this

pipeline

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nt

this

applied

0.395

4.0

However

be

apparent

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fluids

power-law

by

7J

of an

laminar

Kv

Solving

The

the

can

correlation

development of

and

for

of factors

friction

empirical

factor

by

comparison

However

function

with

The

friction

Metzner

the

number

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4200

use of

the

calculation

accurate

yield

use

for

the

in

developed

4.73

model

plastic

Colebrook

the

Metzner

and

Dodge

for

concept

viscosity

number does

Reynolds

when

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the

from

is

critical

the

example

The Dodge

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model

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value

an

gives

NR fluid

power-law

Reynolds

p00000

100000

Ic00

1000

tOO

Substituting

number

graph

on

Fig

diameter

this

equation

apparent and

viscosity

using

Eq

in

4.68c

the

Reynolds

for

equivalent

gives

4.31 The pattern

dex

is

for

starting

is

number

Reynolds

turbulent

It

number the

critical

recommended given

point

of

value the

that

be

turbulent

above of

function

is

the the

taken flow

which

critical

from line

in

NRe

21/n

Reynolds

Fig 4.34 for

109000p2 10.0208d2di1

flow

the

flow-behavior

the

as

given

4.75

APPLIED

ENGINEERING

DRILLING

154

429

Example

index

consistency 0.67

index of

mine

Eq

335

of

the

frictional

4.68c

hole

the

sluny

and

cp at

of 672

7.0-in

of

ft

be

gal/mm

Deter

casing

per 100

loss

The

having

flow-behavior

rate

and

pressure

obtain

to

eq

pumped

being

is

9.625-in

between

cement

15.6-Ibm/gal

sluny Use

computed

known

Since

this

where

is

given

is

velocity

V22

672

given

is

the

at

the

gel

can is

fluid

drilling

pipe wall

occur

will

yields

strength

4.75

Eq

by

4.76a

and

24489.6252_72

number

circulation

pipe

r2r1 dp -.-----

from

Changing for

4.76b

annulus

dL

ft/s

The Reynolds

of

the

movement to

stress

start

greatest

fluid

shear

wall

Tg

by

Tg

629

stress

initial

the

is

to

diameter

equivalent

fluid

strength

gel

shear

the

the

Equating

the

if

dpf

The mean

Solution

required

pressure gradient

the

to

units

consistent

pressure gradient

field

and

units

solving

gives

dp1/dL

1090001 5.66.292067

NR

dpf 335

0.67

10.02089.6257

477

pipe dL

300d

and

3612

2110.67 Tg

From

4.34

Fig

0.67

flow

the

Thus

the

frictional

number

Reynolds

Fig 4.34 the friction is 0.00815 This can

NRe36l2 4.74

critical

2100 Thus

is

from

Also

the

turbulent

is

pattern

factor

n0.67

for

verified

be

pressure drop

and

using 100

per

Eq ft

is

where Tg has units of pounds low annular At extremely and

stress

and given

because point

8de

be

9.1

25.8 71 Summary

of

it

It

unfortunate

is

rather

be

had

the

have

the

frictional

summarized

been

somewhat

feels

who To

same feeling

various

have

facilitate

Table

before

the

muds usually

will

circulation

is

time

pressure-loss

equations

4.11

neglect

the

they

should

be

sheared

sonic

for

displaced

observed circulation

the

in

In

at

application

in

10.0

rate

only

time The

before

to

the

after

entire

the

10

of

mud

annulus

may be

good

circulation

the

frictional

yield

point

mud of 50

has an

not

external

occurs pressure

substituted

below

density

having lbf/

internal

has an

casing

drillpipe

quired

to

Eq

Using the

break

gel

4.78 at

the

the

density

100

sq

ft

just

diameter

of

diameter of 5.0

pressure

pipe

50

_________

wall

is

gradient given

re

by

0.0333

psi/ft

300105

300d2d1

may

pressure

deal at

to

and

been

have loss

pressure

break

is

given

at

the

is

casing

seat

when

by

dpf

p0.052pD

dI

to

0.05293

.000

initiate

higher than the

The

mud

the

has

pressure required

sustain

the

condition

this

equivalent

strength

the

will

in

dL

frictional

Sections

frictional

steady

annulus

in

characteristics

gel

The

fluids

yield

of

behavior

the

Since

and

the

occurs

the

derivation

plastic

when

ft

This

twice

least

field

Well

the

and

flow

to

3000

at

the

with

Compute

seat

casing

Solution

they

practical

thixotropic

started

thixotropic

some cases

in the

of

exhibit

presented

applied

pressure required

flow

strength

the

equal

you

equations

4.6

Circulation

Initiating

Drilling

the

4.78

gel

dpf

4.12

be

Eq

of

begins

not

units

at

using

place

shear

Bingham

for the

in the

approximate

in

of 9.0 Ibm/gal

is

bewildered

gone

pressure-loss in

frictional

annuli

student reader should

The

those

the

pipes and

circular

he

if

of

Many

point

have of

concerned

of

development

for

endeavor

lengthy

overly

this

the

that

equations

to

at

When

gradient

the

pressure-loss

better

is

wall

the

value

not

Bingham

see Appendix

valid usually

ft

approximately

high

made

for

sq

equation

is

stress

equation

Example 4.30

Equations

too

give

shear

assumption

psi

Pressure-Loss

Frictional

will

the

pressure-loss

0.008151566.292l00

4.11.6

the

and

be

pressure-loss

wall

100

per

velocities

may

point

yield

model

plastic

zL

the

frictional

the

by

25

4.78

annulus

300d2d1

dL

for

1404100

desired

1504

psi

0.03333000

the

gel

begins

to

DRILLING

HYDRAULICS

55

TABLE 4.6SUMMARY Newtonian

Mean

Velocity

OF FRCUONAL

Model

Btnghani

PRESSURE

LOSS

EQUATiONS

Model

Plastic

Power-Law

Model

Pipe

2.448d2

2.448d2 2.448d2

Ann

ulus

Flow

v_-.-

dr

2.448d27

2.448d2

d2

2.448d22

Behavior

Parameters

0300

log 0600

n3.32

0300

300

510

P0

Ty033Q

O35

511 Turbulence Criteria

Pipe

37100

N0 2100

NH

Nn0

from

434

Fig

0u2

928p

vd

Npe

Nnec

from

Np

4.33

Fig

89100pV2

0.0416d

31/n

vd

928p Nne_ Pp

Anriulus

24700

2100

Npec

d2

d1

N6

Npe

from

Fig

4.34

Pp

pvd2d

757

109000

Laminar

pv2t1

Re

Nne ha

21/ri

Flow

Frictional

Pressure

Loss

Pipe

731/n

dL

Ann

Ky

L_

dp3

1500d2

dL

huV

0.0416

dp1 d2

1500

225

dL

144000

dtue

ulus

72lfn

1000d2d2 Turbulent

Ky

dp

dp1

P0

10OQd2d2

dL

0.0208

dp1

200d2d

dL

144O0Od2dt

Flow

Frictional

Pressure

Loss

Pipe

v2

dp

fp

dL

25.8

or

dp

fp

dp

fpv2

dL

25.8

dL

258d

or

dp

p075v

dL

dp

1800

d125

p0

dL

7S

75

1800

dt2s

025

Annulus

dp3 dL

21.1

fpv2

dp1

d2

dL

or

dL

turbulence

criteria

are

fpv2

d2d1

dL

or

L_ AIlernte

fpv2 21.1

075t 7SO2O

O75l

1396d2-d1t25 to

a550me

the

low

pattern

dL

which

gives

1396

the

geatest

75/a25

d2d125 lrLtional

pressure

loss

21.1d2d

APPLIED

ENGINEERING

DRILLING

156

The

given

is

density

equivalent

is

velocity

by

across

pressure drop

1504 Pc

nozzle

the

pressure drop

pump loss drilling

of small

clearance

break

to

quired

at

ceed

fracture

To

depth

can

string

is

drilistring

direct

be

drive

flow

into

the

with

pump the

closing

well

the

be

to

line

drill-

In

the

while

Maximum

4.13.2

1958

In the

soned

by

then

starting

gradually

Bit Nozzle

The determination of

more

the

of

the

increases

in

of

bit

by

can

nozzles

In

improved

to

Wasteful

as

of

regrinding

circulated

the

through

made

are

they

rate

In

be

increase

cuttings

the

they were

was

due

and

annulus

Before

yet

mathematical of

effect

the

the

if

as

due

rapidly also

as

to

the

hydraulic of

level

the

monly used zle

bit

velocity force

pact of

hydraulic

the

Current nozzle

bit

Before

at

flow

the

annular

To some extent nozzles rate

pressure the

is

velocity

cause

This

the

to fluid

that

can

equation

so

be

can

that

the

concluded

bit

impor that

bit

derived by

were

horsepower

is

in

the

pressure

fluid

losses

in

the

drilipipe

nozzle

Stated

annulus

Pdp

caused

by

and

drill

accelerating frictional

and

Pdca

annulus

collar

drill

fric

equipment

losses the

through

frictional

by

expended

and

mathematically

JL jca Pdpa

Ps I.Pdp

4.79

total

the

called

the

frictional

pressure

parasitic pressure

loss loss

to

and

from

the

bit

is

then

PdPs

Pdp

Pdc Pdca Pdpa

selection

one

of

4.80a

these

PpPbPd pumps to

the

the

in

achieved using

shown

in

the

estimated

the the

even

cuttings

today

pressure allowable bit

and

nozzles

still

lift

Eq

4.31

this

equation

the

4.80b

were

usually

lift

surface

maximum

velocity

be

would

continues

that

proved

As

rig

corresponding

practice

sized

equal

then

rate

velocity

this

are

maximum

tings

that the

noz

3jet im

Velocity

Nozzle

were introduced

bits

minimum

flow

was

power

and

jet

operated

com

bit

and

involves

will

it

bot

the

at

hydraulic

maximum

Maximum

4.13.1

that

losses

indicate

The most

horsepower

practice

sizes

be

to

parameters

jet

field

the

drilistring

hole

If to

are

parameters

hydraulic

bit

surface

in the

the

Pp

from

out

pointed

the

developed

power

in after

necessarily

pressure

Pdc

drilling

driuipipe

authors in

as

level

increase

concluded They pump pump horsepower was

maximum

losses

pressure

fast

Goins.2

pressure

collars

as

Shortly

power

disagreement

still

be used

action

cleaning

design

tional

with hydraulic

further

loss

in rea

drilling-fluid

is

should

that

by

maximized by operating maximum possible horsepower The

the

for

no

pressure

Furthermore

at

pump

than

was not

pump

pressure

rate

potential

there

parameter

hydraulic

penetration

and

washout

At present

capacity

what

hole

as

on

wear

bit

define

that

out

Speer

removed

several

different

the

rather

and

The

the

be

was

parameter

pump

be

hydraulic

hydraulic

the

by

Kendall

accurate

done

developed

rate

perfect cleaning

this

paper

his

hole

the

conditions

fluid

fluid

jetted

be

can be

hydraulics

costs

such

carrying

of

level

operational problems

this

must

relations

The

flow

improved

increase

were

should

frictional

the

to

horsepower

the

After

with

published

for

may aid in the destruction of the hole bottom The true optimization of jet bit cannot hydraulics achieved

the

pointed

be the

power would

cuttings

there rate

that

tant

the

that

could

rate

generated

achieved

Specr

bottom

hole

cuttings the

formations

soft

be

to

felt

the

prevented

removes

bit

is

at

when

Horsepower

of

hydraulic

until

horsepower

the

through

competent

relatively

is

one

is

frictional Significant

achieved

action

cleaning

sizes

the

personnel

drilling

rate

mations the penetration mainly

of

the

pressure

minimum

is

paper

bits

jet

penetration

developed

nozzle

bit

applications

penetration

proper choice

Selection

properjet

frequent equations

pressure-loss

Size

of

the

that

the

bypass

Jet

frictional

the

minimum

published

effectiveness

tom of

4.13

maximum when

is

and

Hydraulic

Bit

Speer2

penetration

and

open

be

allows

gradually

bit

annulus

is

loss

pressure

horsepower

installed

This

and

drillstring

with cannot

speed

be

can pit

the

maximum

is

bit

minimum

is

adcli

equipped

pump

line

increased

the bypass

is

rig

the

and

that

at

very slowly

the

bypass

discharge

in

frictional

creasing

If the

and

re

the

started

puITnl

increased

system

gradually

pump

the

be

rotated

being

power

increased

tween

can

speed

be

may ex

formation

is

the

an

at

available

pressure

the

at

pressure

requirements

pressure

before

rotated

pump

the

tion the

be

the

the

circulation

pressure of an exposed

reduce

may

pressures

initiate

in

gclled

some cases

In

to

depth

given

severely

excessive

circulation

required the

becomes

fluid

the

maximum when the is maximum The

is

velocity

available

pressure drop

nuli

the

Ibm/gal

the

of

root

square

nocvlThus

When

the

bit

00523000

0.052D

9.64

to

proportional

directly

If

at

the

Since

each

computed

term for the

of

the

usual

parasitic

case

pressure

of turbulent

loss

flow

can

using

be

Eq

66e

this

surface will the

be

cut

nozzle nozzle

and

we

can

represent

the

total

parasitic

pressure

loss

using

4.81

HYDRAULICS

DRILLING

where and

and

tics sion

constant

is

175

that

wellbore into

has

theoretically

that

constant

is

for

depends

geometry

Substitution

Eq

and

4.80b

value

mud

the

on

of

proper-

this

expres

Pa

for

solving

near

yields

bottom

the

bit

of

horsepower

given

is

Eq

by

found bit

to

with

working

that

the

small

bits

could

rate

penetration

number group

Reynolds

maximum im

the

the

in

be

cor

that

so

1pd\aq

dD

hydraulic

Eckel23

laboratory related

maximum for

was

hole

the

force

pact

Pp cq

Pt Since

157

cit

Pa

4.35 where

pq

pq--cq

1714

dD

714

penetration

rate

dt

calculus

Using

determine

to

flow

the

rate

which

at

the

bit fluid

horsepower

maximum

is

density

gives nozzle velocity

dP

L\p1nlcqm

dq

1714

nozzle diameter

Pa

apparent

a8 for

Solving

the

of

root

this

equation

pmlcqmm1p

4.82a

can

that

shown

be

of

the

this

m1

The

4.82b

F1

root

loss

11/m

is

From

maintain

10

the

convenient suitable

for the

entire

the

the

theoretical

liner

well

size

rate

liner

For

rate

that

rate

given

is

the

held

is

with

derivation

was

impact

jet

Goins.2

and given

Eq

by

loss

pressure

parasitic

4.37

is

by

given

Eq

4.81

_ocqm2o5

Ij0.0l823Cdppq2

be

achieve

to

the

is

focc

maximum

reduc calculus

of

part

constant

horsepower

impact

Kendall

The

exercise

usually will

Using

achieved

pump

is

that

shallow

the

by

for

so

Reynolds

maximum The

also

is

selected

the

0.0l823CdqxIK_pJ Since

increases

student

conditions

are

desirable

periodically

in

by Eckel

as

sizes

maximum

pressure

It

size

first

left

nozzle

is

0.01823Cq

hydraulic

always

ratio

depth

usually

can

given

not

than

Thus

he

bit

parasitic

liner

rather

the well

as

flow

the

maximum

well

maximum

maximum size

pump

shear

at

and

the

root

pressure

is

it

PdPp

optimum select

the

pump

the

standpoint

to

ing

the

times

practical

this

Thus

maximum when

is

for

zero

maximum

to

corresponds

horsepower

than

less

jet

force

defined is

proper

published

when

that

impact

Jet

proof of

is

fluid

the

seconds

constant

number group

or

d2Pflh/dq2

10000

yields It

Since

of

viscosity

of

rate

at

to

force

impact

determine

the

maximum

is

flow

rate at

which

the

bit

gives

the

convenient

Hp

rating

this

by

dq

_pcq205

1714 PHpE

qmax

4.83 max Solving

where

the

is

maximum This flow

allowable rate is

decreased

the

at

the

reduced

is

pump

used

is

with

PdPp never

at

pump

overall

optimum

below

is

depth

value

the

in

flow

rate to

depth

flow

at

the rate

then

flow lift

the

root

of

this

equation

yields

2pppqm2pCqmfl

which

pq n2pdlO

is

maintain

to

for

the

is

contractor

by

However

minimum

Pmax

reached

The

value increases

optimum

set

pressure

until

subsequent

and

efficiency

rate

or

the

cuttings

Maximum

4J3.3 Some the

4.84

rig

jet

Impact Force

Jet

operators prefer impact

hydraulic perimental

force

is

that

select

the

hit

nozzle

maximum

McLean22

horsepower work

to

velocity

sizes

rather

concluded of

the

flow

so

that

than

bit

from

ex

across

the

Since

d2F1/dq2

coriesponds

maximum

is

less

than

zero

maximum Thus

to

when

times

the

the

pump

for the

parasitic

pressure

this jet

root

impact

pressure

the

root

force loss

is

is

APPLIED

ENGINEERING

DRILLING

158

Shown the JMP

AVAILABLE

HORSEPOWER

AS

FUHCTIOH FOR

at

SIVEN

DEPTH

of

parameters

operation

and

tion

of

and

the

the

line

where

and

pump

Interval

defined

reduced

01

Optimom

maximum

deep

of

Hydrouliao

qQ

m00

LOG 4.35Use

Rg

of

plot

log-log

and

operation

selection

for

nozzle

bit

reduced

to the

cuttings

to

the

of

pump

proper

sizes

at

intermediate

loss

increases

at

tersect tained

Known

When

high-pressure

large

and

drillstring

possible

clean

to

needs

cleaning data taken bit

of

bit

the

in

flow

can

be

rate

to

needed

Under those

input

should

if

desired

the

pump

hydraulic

or

in

bit

If

in

hydraulic

force

will

neither

hydraulics

the

force

as

force

us

The

90%

within

pro

somewhat

through the

involving case

of turbulent

proximated tion

of

paper

Since

can

hydraulic of

using

parasitic

logp also

use

10

vs be

bit

nozzle

use

of

of

flow

Eq

the

A.1

of

most accurate

method

for

loss

depth

so

the

that

total

the

parasitic

at

given

pressure

during

section

well

during

the

As

pump

operations

flow

two

in

to

rates

dis

be

will

are

pressures

the

event

the

nozzle area of

total

by

customary

is

least

these

control

Since

at

operations

drilling

next

the

in

for

It

is

the

bit

cur

the

in

bit

use

can

computed

jet

and

Eq

ing

generally

is

be

4.34 The

these

flow

as

the

at

flow

given

can

the

across

us

rates

be obtained

between

difference

the

pressure drop

across

pressure drop

the

pressure then

parasitic

rates the

known easily

pump

the

bit

shown

is

graph

plot

Eq

to

has 4.35

as

logp

that

the loss

lines line

logq

usual is

ap

representa on

q-75 slope

straight

vs

line

possible

proportional

from

of

is

Example

technique

for

pressure

straight

theoretically

simplified

solution

Since

paper

loss

be

can

parasitic

4.66e

pressure

Pd log

sizes

graphical

log-log

horsepower on

the

graph

Analysis

of

selection

total

kicks

rently the

at

Graphical

the

on

A101 perhaps

pump

the

pressure and

The

the

across

great

versa

4.13.5

ob

is

from

area

selected

measurement of pump pressure

cussed

well

maximum

the

the

periodically

proved

two

the

and

easiest

useful

maximum

of

best

is

not

is

of

is

Pd

Prnax

to

in

to

point read

The proper nozzle area by rearranging Eq 4.34

are

near

is

determining

the

about

has been

there

horsepower

be

concerned

application

would tend

4.85

just

maximum

be applied

impact

criteria

run

Pbopt

nozzles then

nozzles

the

impact

because

is

of difference

cedures

or

would tend

bit

be

bit

decreasing

at the

overly

power

cases

all

be

not

to

pressure

IThlXl05pq2 Cd

Three

could

logic

A10t

measure

main reason

the

superior

impact

same

to

of

optimum

run

pressure drop

proper

the

lift

conditions

by

hit

operated

horsepower

should

parameter

amount

of

level

is

of

intersection

qopt

the

been

level

higher

reduced

computed

vary

parameter

student

Perhaps

be

the

This

provide

of

point

will

parasitic

can

is

is

rate

penetration

conditions

be

bit

the

rate

the

intersection

can

shallow

corresponds

hole

the

If

then

direct

hydraulic

which

from

under

than

hydraulics

Pbopt

hit

at the

be

may

it

adequately

wasteful

is

it

pressure

either

The

bit

the

large-diameter fluid

than

until

obtained

of

established

similar lithology

energy

allowable

vice

be

hydraulics

the

ing

can

of

drilling

level

higher

and

available

because

hole bottom

the

hydraulics

pump

low

is

proper

to

intersection

path

Since

deep

Once

addition

the

the

proper

This corresponds

depth

flow

In

to

rate

has

rate

efficiently

and

line

depth

Interval

flow

4.35

Fig

and

the

graph are

pumps

low-viscosity

achieve

to

needed

ing

loss

pressure

parasitic

Needs

Cleaning

that

value In

in Interval

occurs

run

with

rating

corresponds

the

the

or impact

horsepower

qqmin

pressure-loss

Interval

for

the

at

well

allowable

rate

horsepower

1PdPmax

where

well

hydraulics

at

pump

hydraulic

surface

parasitic

intersect

4.13.4

bit

the

flow

by

the

of

portion

LtPd corresponds well where the flow

the

minimum

the

an

and

defined by

portion

la

defined

possible

maintain

to

Interval

op

segments

constant

of

portion

of

path

maximum

the

at

size

by

gradually

for

force

liner

The

shallow

the

loss

pressure

parasitic

Interval

maximum

convenient

value

to

intersec

the

straight-line

operated

is

the

intermediate

the

hydraulics

pump

proper

at

for

various

the

for

occur

and

pump

the

pressure

conditions

three

corresponds

-J

Roth

has

conditions

the

using

selection

optimum

Intervals

qqmax

Impoct

The

sizes

representing

of

hydraulics

beled

nozzle

nozzle

bit

path

summary of

is

bit

hydraulic

timum

INTERVAL

Fig 4.35

in

selection

in

log-log plot

of

1.75

of It

of constant with

slope

conditions

431 the

force

for

three

12/32-in

when

the

gal/mm when

pump rated

the

bit

next

minimum

nozzle bit

pump pump

1250 flow

sizes

The

run

The

nozzles

mud

9.6-lbm/gal

pressure at

the

Determine

and

slowed

is

of

900

psig

hp

and

has

rate

to

lift

bit

to is

the

has

of

is

rate

247

and

gal/mm

observed

The of is

has that

of 485

observed

efficiency cuttings

impact use

recorded

at

psig

rate

an

in

currently

pumped

2800

operating

pump

maximum jet

driller

is

pressure of

proper for

pump

0.91

225

is

The

gal/miri

DRILLING

HYDRAULICS

159

The maximum allowable The mud density

surface

remain

will

is

pressure

unchanged

in

3000 the

psig

next

bit

run 5000 Solution bit

Eq

Using

flow

at

4.34 485

of

rates

the

and

pressure drop

247

through

are

gal/mm

as

the

follows

000

cc

500

cc

Pbt

i2

0.952

io

8.311

1894

psig Optimum

Hdrulic

200

uJ

lO

9.62472 491

0.952

m2

pq2

___________ 2A

Pb2

PUMP PRESSURE

OTUUM

8.31lxlO5 Liph

XltU

3000

50

psig

4\32i

Fig

4.36Application

of

selection

Thus 247

the

parasitic

gal/mm

are

pressure

loss

flow

at

485

rates

parasitic

well is

points

are

pressure

determined

mud

could

Fig 4.36

rate

to

be

4.36 and

line

Interval

650

qopt

for

techniques

the

the

of

intersection

of

path

optimum

the

parasitic

oc

hydraulics

at

have

establish

for

the

The slope of value

determined

Pd

gal/mm

1300

psi

Thus to

relation

properties

graphically

natively

analysis

sizes

psig

in

plotted

in

curs

psig

loss/flow

and

geometry

Fig

in

pressure-loss

28001894906

two

graphical nozzle

bit

and

As shown

Pd29OO491409 These

of

gpm

follows

as

PdPpLPb Pdl

RATE

FLOW

1000

500

tOO

given

the

of 1.2

using

the

Lph3OOOlSOOl700

psig

line

Alter

Thus

the

nozzle

total

proper

area

given

is

by

two-point

method

8.311x105 log906/409

pq2

4zopt C0

1.18

LJhopt

log485/247

path

of

59.66502

Ix 10

8.31

The

0.47 optimum

hydraulics

is

determined

in

sq

0.9521700

as

follows

Interval In

l714PHPE

qmax-

1714l250O.9l ___________________

3000

Prnax

determined

of

Interval

PdPmax rn2

1.22

1875

psig

rates

Also

portions

flow

current It

3.000

flow

conditions

flow qmin

225

the

it

rates field

not

will

personnel is

often

and

bit

gal/ruin pressure

loss

at

Reported

values

are

frequently

much

be

done

nozzle

sizes

The

various

to

change

with

sizes

at

when

the

well

calculation

depths

rig

the

during

of the

for

at

of dif at

dif

from

far

slope

proper

during

the

attach to

too

constant the

1.2

assume

data

pattern

primarily

to

than

extrapolate

of

generally

flow

calculate

available

is

pressure

subject

nozzle

it

rather

the

to

to

and is

Thus

data

are not

desirable

personnel

1.75

since

desirable

phase This

of

conditions

operating

operating

case

best

is

pressure

value

pump

well

the it

sometimes

is

planning

Interval

of

rates

parasitic

have

data

field

from

requires

ferent

the

to

value

This

ferent the

field

1.75

two

least

value

theoretical

determine

to

value

found

from

the

of

slope

was

theoretical

of

best

gal/mm

the

than

than

the

line

rate

rather

lower

650

4.31

Example

loss/flow

pump

the

well

engineering site

In

this

recommended plan furnished the

parasitic

well

planning

APPLIED

ENGINEERING

DRILLING

160

OF SURFACE

FLOW RESISTANCE TABLE 4.7TURBULENT CONNECTIONS

Combinations

Typical

No.1 ID

ID

in

Components

40

hose

Drilling

Swivel

ID

in

It

Standpipe

No

No

No.2

in

ft

31/2

45

ID

in

ft

It

40

45

45

55

55

55

40

40

washpipe

and

2/

gooseneck 40

21/4

Kelly

40

31/4

31/4

Drillpipe

OD in

Weight

Equivalent

Ibm/It

Connections

31/2

13.3

41/2

16.6

437

can

loss

be

accomplished

equations

mud

and

properties

function

of depth

made The

be

nections

761

equipment Table

standpipes Since well

quite

not available

an

by

an

assuming

method

loss to

they

However

best

to

then

other flow

the

an

ff1

Ibm/gal

opt

5000

9.5

15

6000

9.5

15

7000

9.5

15

8000

12.0

25

9000

13.0

30

Point lbf/I00

sq

ft

12

The

Solution

of

path

is

hydraulics

optimum

as

entire

using

be

to

Interval

is

program

can

rate

Viscosity

follows for

solution

and

calculations

in

kelly

computer

flow

arbitrary

Yield

Plastic

Density

lengths

accomplished

suitable

if

in

com

losses

calculations

are

approximate

extrapolate

and

swivel

con

Shown

typical

the

Mud

surface

The equivalent

considering

hydraulics

lengthy

computer

pressure

by

hose

drilling

optimum

are

for several

lengths

579

Depth

can

surface the

340

816

Program

as

computation

in the

479

The

planned

length of drilipipe

equivalent

obtained

be

Mud

pressure-

sections

representing

surface connections

were

size

loss

pressure

equivalent

are

of

must

nozzle

the

estimated by

is

an

as

4.7

bination

shown

before

frictional

preceding

hole geonletry

frictional

usually

the

using in the

developed

Drillpipe

161

19.5

phase

of

Feet

in

Surface

of

Length

achieved

perform

17 I4PHPE

the

17141

3.423

Prnsx

using

6000 85

max

graphical

rates

681

gal/mm

Interval

Example 4.32

well

casing

surface at

to

bit

000ft

between

termediate

and

at

horsepower

the

desired

is

conditions

operating bit

It

9000

estimate nozzle

sizes

increments

ft

proper for

for

an

The well plan

pump

maximum interval

4000

at

casing

the

ft

and

calls

of

in

Since

of

pump

solution

simplified

value

is

.75

data

pressure

is

technique

used

For

maximum

3423

psi

maximum

1600

hp

maximum

0.85

pump

bit

Pd Prnax l.7l in

Pump

not

are

desired

surface

and

available theoretical

horsepower

for the

conditions

following

measured

3423

pressure

-1245

input

psia

efficiency Interval

Drilistring

16.6-Ibm/ft

4.5-in

drillpipe

3.826-in

ID 600

ft

For the

of 7.5-in.-O.D

minimum

annular

velocity

of

120

ft/mm

opposite

drillpipe

x2.75-in.-I.D 120

drill

collars

qmin2.448l0.0524.52 Surface_Equipment

Equivalent

340

to

ft

of

drillpipe

395 Hole

Size

9.857

in

washed

10.05-in-ID

out

to

10.05

Parasitic

Annular

velocity

Pressure

Losses

casing

The

Minimum

gal/mm

in

120

ft/mm

parasitic

pressure

convenient

flow

used

example

in this

rate

losses

flow

The

can rate

frictional

be of

computed 500 gal/mm

pressure

loss

at

any

will in

be

each

DRIWNG

of

section the

HYDRAULICS

Table

and

drilipipe for

equations

161

the

annulus

wid be calculated using

Bingham

model

plastic

outlined

5000

in

4000

4.6

The mean

velocity

in the

given

is

drillpipe

by

3000

500

13.95 2.448d2

The

Hedstrorn

2000

ft/s

2.4483.8262

number

is

given

by 1000 900

37 l00prd2

800 700

/.Lp

600 500

l0095538262

37

114650

152

400

300

From The

Fig 4.33

the

928p0d

NRe

critical

number

Reynolds

is

number

Reynolds

given

7200

is

200

by

9289.513.953.826 _________________ 15

00 100

000

1370 Fig 4.37Hydraulics

Thus

flow

the loss

pressure

in

given

is

drillpipe

The

turbulent

is

pattern the

frictional

The

of 1.75

0.75

0.75

are

Pdp

AL

slope of

rates 1.75

1800d125

ample frem

5000600

.25

18003.826

and

lines

1.75150.25

loss

loss

the

in

340

equipment

of drillpipe

ft

38

Ap5490

is

to

equal

thus

psi

The frictional

pressure

of to

determine

the

8000

computations

in

The

drillpipc

6000 7000

these

loss

other

similar

procedure

section

repeated of

path

are

to

entire

sections

that

is

outlined

procedure

total

parasitic

and

9000

summarized

The

in

the

above

Col

then

losses

ft

4.37

38

490

320

/4m._ 20

at

caH

for

be

results

of

following

25

1004

38

601

320

38

713

320

20

29

51

1116

433

28

75

57

1407

482

27

pattern

urdiutted

by

Iledsirom

20

number

111 criteria

/.L 888

7000

flow

the

optimum

in the

parasitic

The preper

Note

D9000

for

The

psi

nozzle

that

all

in

occur

ft

pump

proper

are

areas

ex

pressure-loss

hydraulics

that

at

with

previous

follows

as

5000

600

1245

2178

0.380

6000

570

1245

2178

0.361

7000

533

1245

2178

0.338

8000

420

1245

2178

0.299

9000

395

1370

2053

0.302

columns

the

by

the

there

are

that

will

rock

in

rock

sizes

are

1703

from

one

tom and zle

This

nozzle exit

on

flow

was

the

hits

the

used

is

For

found

to

move

side

created

of

larger

size

bit

forces

com total

using

that

the

force

when flow

example across

three

correct

increased

the

only

have

work

fragment found

opposite

pattern

indicate

jet

closely

bit

3.423

4.85

Since

1.120

2084

of

pressure

Eq

experimental

beneath

Fig shown in

Ap

number of nozzle

large

fragment

nozzle

bit

approximate

of

model

physical

the

from

directly

calculations

hydraulics

Sutko24

area

pump

using

in

sq

subtracting

maximum

nozzle area of

nozzles

equal

of

results

read

were

was obtained

was obtained

total

on

iSp5

psi

from

The the

Rate

psi

Col

psi

depths

20

6000

tLaminar

of

zpI24S

Flow

three

binations

L/AL..

9000

line

computed points as

rate

expected

by drawing

obtained

and

losses

gal/mis

Col

nozzle

8000

of

conditions

first

computed

table

5000

the

are

other than

the

4400

following

estimated

intersection

where

Interval

surface

in

340

The

be

pressure

depth

flow

psi

pressure

pressure

the

the

Depth

The

can

through

intersections

operating

490

parasitic

assumed

the

at

each

at

expected

Fig 4.37

The

conditions

hydraulic

9.5l3.95

in

plotted

500 gal/mm

other flow

losses

pressure

parasitic

assumed

by

4.33

Example

for

plot

un only

the

hole

bot

froni

the

noz

the

rock

on

APPLIED

ENGINEERING

DRILLING

162

in

Fdc

bh

bh

4.38Relation

Fig

than

nozzle

the

in

the

However many as

as

evenly

ed

in

possible

one

using only this

of

case

pressure

drillpipe

no7zles

resolve

to

divide

to

sizes

well

during

control

cone

bit

work

of

is

need

of

the

bottoinhole

drillpipe

controversy

Pressure Schedules

The

Control Operations

must

well

be

tion

control

maintained

from

the

well

the

This

is

and

to

for

the

through

the

while relation

surface

was

the

annular

developed

possible

ingful

distnbution generally

not

pressure

control

the

However frictional

at

cannot

of constant

possible

control

tion

of

the

the

of

circulation

pressure drops

must

well

the

is

considered

be

be

In

and

zp

052pD

This

use of

losses

of

the

rela

4.86a

It

is

pressure

are

mean

fluids

information

kick

the

for

and

bottomhole surface

Pdp

pressure

pump

as

the

circulating static

measured

routinely

measured

APp

pressure

of

sum

the

and

choose

to

convenient

usually

is

accurate

at

the

drillpipe circulating

selected

pump

speed

their is

4.86b

Pd2fPdp1Pp

annular accurate

pressure during

more accurate

the

dc

dp

Sec

this

used

the

initiated

to

changed

dpf

kick

time of

by

pressure

operations

an

requires

bottomhole

through

after

necessary

pressure

Since

sur

given

is

pressure and

calculation

profile

annulus

available

operations is

is

it

considerations

frictional

composition

the

profiles

maintenance control

the

in

well

hydrostatic

However

and

pressure

bottomhole

surface

bottomhole

of

Fig 4.38A

Pb/

between

pressure

in

conditions

shut-in

be

O.O52PDPhh

on

choke

circulated

being

is

of

pressure

shown

well

can

pressure balance

bottomhole

for

are

pressure

operation

flowing

the

Unfor

drillstring

drillpipe

proper control

shut-in

between

the

the

maintain

to

annulus

in the

the

fluids

value

proper in

drillstring

involve

designed

losses

well

the

procedures

the

at

considering

drillpipe

drillpipe

small

knowledge

well

the

well

the

adjustable

Thus

present

annular

annular of

into

pressure from

pressure during from

because

generally

at

bottonthole

4.4

tion

an

of

the

in

formation

circulated

backpressure

measurement

direct

measurements

of

use

by

relation

forma

the

are

circulated

is

are

given

fluid

schedules

pressure they

determination

Pdp fluids

maintaining

by

not possible

is

infer

mud

kill

Unfortunately pressure

cir

pressure

above

slightly

formation

the

accomplished

annulus

value

at

pressure while

bottomhole

the

operations

as

negligible

face

Dunng

and

conditions

with

control

pressure

well Consider

the

drilling

pressure

frictional

tunately not

the

modern well

use

achieved

Pump

shut-in

contaminated

not

is

most

The

for Well

dc

LSP5

operations

since

drillpipe

Thus

when

cleaning

the

schedule

4.14

0.052PD

dpf

generally

flow

the

nozzles because

Additional

this

near

exit

nozzle

equal

three

and

and

turn

prefer

the

among

to

three

still

cooling

bit

or two

area

surface

had

path

engineers

of uneven

reports

flow

the

if

as

BHP and

between

bh

conditions

culating

fragment

PD

0.052

dp

well

pressure pressure

in

While the

this

drillstring friction

measured

routinely

annular

friction

and loss

is

loss

as

pump

well

through

the

usually

only

as

bit

the

Eq

small

pressure includes pressure

loss

4.79

the

fraction

of

in

the

annular the

total

DRIWNO

HYDRAULICS

the

Thus

change

pressure

selection

slightly

of

4.86b

the

shut-in

bottomhole

by

Eq

ficult the

bottonthole maintain

to

drillpipe

large

below

It

is

will

the

Pp

be

least

if

tour the

dimensions

drillstring

measure

pump

the

An

shut

in

with the kick

bottomhole

of

tion

until

brought

at

the

up

to

kick

the

the

if

value

increase

while

by

annulus

pressure

will

stabilize

pressure then

itiated

when

and

the

pump

culating the

is

kick

have

rigs that

such

lines

blowout

the

included excess

in the

losses

pressure

be

the

as

proper value

and

the

losses

frictional

in

for

the

average

Significantly tional

the

pressure

lines

fracture

the

mud

maintaining drillpipe

the

are

both

density the

losses

to

the

change

in the

in

in

density

the

loss

pressure can

he

pressure

re

drillstring

circulating

drillpipe

surface and

the

pressure and

in hydrostatic

increase

the

bit

given

is

by

at

in

the

in

cir time

lie

in the

to

choke

pro

choke

line

losses

used

are

the

hydrostatic

be

pressure

determined

are

density

only

the

to

the

corresponding

bit

the

reaching

calculate

to

Intermediate

by

means

of

taken

at

drilipipe or

graphical

above

4.33

Example 10000 an

initial

drillpipe

pressure of

ing

capacity the

of

bbl/ft

is

stant

as

from

an

the

After

capacity

required the

of

to

of

rate

bbl/stroke

0.2

the

value

and

800

stabilized

an

initial

The

0.01422

psig

the

of 9.6 lbm/gal

recorded

pressure

pressure

the

con

increases

drillstring to

and

0.0073

The pump

drillpipe

bottomhole in the

is

was

20 strokes/mm

cas

internal

bbl/ft

collars

drill

Compute

keep

mean mud density

initial

is

900-ft

pressure

reduced

at

drillpipe the

psig

of

depth

pressures

recorded

were

psig

of

is

the

of 520

pressure 720

pump

schedule

kick

4.6

9100-ft

the

internal

factor

20-bbl

Example

ft

final

kill

mud

density

unprotected

the

drillstring

be

held

initial

is

speed

drillpipe

stabilized

PdfPdpPp

varied

Thus to

pressure required 20

strokes/mm

psig

of

The

kill

mud

density

Pdp

fric

the

at

520-1-8001320

changes

altered

and

pump

The

at

constant value

drillstring

are

drillpipe

mud

to

respect

convenient

interpolations

as

frictional

However when

must

with

linear

usually

density

previously

underwater

pressure and

drillstring

pressure

is

the is

well-suited

at

pressure

is

pump

observed

speed

pump

relation it

Pp

Pdp

pressure can the

PfP2 P1 o.o52D_

pressures then tabular

method of

an

this

mud

the

in

density

hydrostatic

drilipipe

in

the

between

final

applied of

pump speed

given

mud

pressure

circulating

offset

by

loss

bottornhole

alternative

However

cause

increase

circulating

with

this

using

Since

between

losses

vessel

hottomhole

the

in frictional

4.87

por

accurate

not

is

it

pressure

drilling

average

circulating

Pd

the

the

constant

offset

4dpfPh

Solution

As long

decrease

to

pressure

is

formation

remains

net

circulating

pressure

not

choke

may

The

final

alternative

available

pressure

in the

pressure

PfP P2PD

held

is

circulation

are

pressure

annular

and

seat

kick

when

When

bottomhole

casing

data

floating

frictional

without

annular

using

first

of

useful

frictional

preventers

cedure

the

relation

assumed

for

is

equal

difference

Unfortunately

high

as

the

This

quite

pressure

was taken

mud

in

change

approximated

increase

the

small

Since

error

large

power linear

be

can

pro Thus

is

portion

circulating

drillpipe

was shut in

determining

are

to

Pf

and

flow

0.75

the

to

in

loss

pressure

turbulent

increase

density

linear

varies

constait

upper

the

value

after

stabilized

well

the

due

raised

density

density

introducing

initial

even

the

and

normal

as

observed

pressure

an

at

The

be taken

can

or

can

speed

amount

only

used

for

pump

value

in the

drillpipe

lower

the

rapidly

the

loss

rate

mud

of

usual case

mud

reasonable

between

the

bit

frictional

re

well

the

casing

pressure

flow

for

the

through the

several

proper if

the

will

the

the

surface

frictional

for

at rate

reaches

desired constant

the

density

mud

to

Also

desirable

flow

to

pressure

drillpipe

often

available

is

confined

Thus

shut-in

portional

at

be

may

pressure

not change

top of

the

annulus

the

constant

fluids

pressure does

kick

gas

value

operations

The annular pressure required

well

the

by

1D

pressure drop

drillstring

quired

suitable

to

taken

is

pressure

drillpipe

the

in

mud

with

ly

circulating

is

method of determining

alternative

circulating

It

pump most

pump

nozzle sizes

bit

changed

the

kick

of

control

pressure due

Most well

taken

is

well

The change

for

oc ex

the

an accurate

that

measurements

circulating

when

selected

so

properties

are

that

so

speeds

for

fluid

of

circulating

kick

Additional

drilling

keep

since

losses

effect

given

is

re

to

is

pressure

in hydrostatic

density

O.052p2

losses

the

measurement

suitable

dif

minimal

is

event

the

rate

once

quired

in the

Also

pressure

adverse

the

enough

frequently

at

frictional

to

required

intended

Ph

the

is

it

change

The change

mud

in

bottomhole

the

if

seen

Eq 4.86b and then Eq 4.86a This small

setting

measure

to

be

since

terms

main constant

the to

equal

This can

desirable

value

seat

pressure

require

pressure

is

choke

the

at

casing

available

operators

exact

amount

loss

pressure

Eq

using

in in

annular

important

pressure

of

the

bouontholc

cess

to

of

for

pressure

the

in

pressure exceeds an

for

pressure

portion

curs

4.79

When

annulus

in the

results

pressure only

value

bottomhole

4.86h

4.86b

bottomhole

pressure by

Eq

Eq

use of

shut-in

loss

pressure

substituting

excess

the

circulating

substituting

the

circulating

than

higher

frictional

163

P2

0.052D

just

frictional

10.6

Ibm/gal

is

given

96

by

520

0.05210000

is

after

given

the

by

APPLIED

164

ENGINEERING

DRILLING

400

300

O0

--

200

O.

300

Nt

-iN

OLj 1100

1100

000

______

______

______

______

900

______

C-

o0-

800 98

9.6

0.0

102

MUD

Fig

439A-.--DriIIppe

total

the

drillstring

by

Eq

for

pressure constant increases from

the

circulate-and-

mud

the

10.6

to

maintain

to

required as

9.6

300

500

400

STROKES

Fig 4.39BDriflpipe

in

density is

Ibm/gal

given

4.87

mud

for the the

proper

he

obtained

that

700

800

900

wait-and-

the

for

this

Thus

point

time can

point

in

the

mud

for

density minutes

17

suction

pump

the

at

to

given

at

Fig 4.39A

by entering

measured

surface

the

pressure

drilipipe

was

schedule

pressure

move from

to

600

PUMPED

method

weight

pressure change

drillpipe

200

100

Ib/gI

schedule

pressure

bottomhole

the

DEiSITY

lOG

method

weight

The

104

earlier If

to.o52D

PdpfP2

mud

the

10.6

before

10.69.6 the

press

of

tion

psig

final

circulating

given

is

pressure

drillpipe

by

Because

the

termediate obtained

while

record

of

be

some

error

mon

drillstrings

The

of

is

circulating If

mud

this

in the

and

given

density

at

that

in the

method

Half

obtained

by

drillstring

the

has an total

the

mud

is

drillstring

lhe number of pump

strokes

that

mud

volume

equal

volume of

the

of

68

required

to

Thus

at

mud

bhl

pump

68

bbl

relation

intermediate

obtained

graphically

4J5

Vertical

In

Sections

bbl

is

4.10 of

However

is

when

different

duit

moved

is

it

will

20 strokes/mm

17

minutes

strokes

the

increases

drilistring

Assuming

linear

be

pressure can

drillpipe

Fig 4.39B

in

take

Due

conduit

into

the

well

increases

pipe

movement

If

well

casing

string

pressure pressure

fluid

is

or

at

by

decrease

upward

new

due

point to

swab in

downward

to

is

an

is

in the

point

surge

drillstring

con fluid

drillstring

given

called

commonly is called downward pipe is moved

the

at

the

than or

string

given

trip the

in that

rather

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developed

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increase due

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must

or

pressure

commonly

were

encountered

casing

the

pressure

the

well

conduits

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described

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equations

the

through

the

if

4.11 through

running

lowered

strokes

strokes/mm

of

shown

as

situation

through

Similarly

20

680

680 strokes

values

and

fluids

slightly

As strokes

to

Pipe Movement

movement

the

rate

in

density

Surge Pressures

to

fluid

340

com

all

required

by

given

9000.00731

pumping

after

decreases

pump

mud

mean

the

lbm/gal

drillstring

0.2 bbl/strokes

the

is

for

the

density

by

340

Since

small strokes

error

internal

assumption

simplifica

by

68

is

number of

the

bit

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the

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in the

density

assuming the

be

increased

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frequent

lOO0.0l4229000.00731

given

to

uniform

0.2

in

pressure can

into

mean

the

that

drillstring

below

mud

kill

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simplicity

Since

the

linear

is

density

pumped

times

all

is

technique

density

pressure

drillpipe

mud

the

in

density

circulate-and-weight

so

known

is

mud

point above

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the

l000.01422

mud

mean

drillpipe

circulating

maintained

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mean

of

graphically

slowly

tion

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circulating

values

clrillstring

give

not

is

func

psig

relation

and

drillstring

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883

the

For

pumped

ex

to

as

drillstring

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initiated

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convenient

usually

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value

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in the

strokes

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pump

1320437

number of

relation

diameter of

is

it

mean

the

linear

437 Thus

the

the

to

of

circulation

method mud density

wait-and-weight

800

increased

is

density

Ibm/gal

pressure from

pulled in

the

upward

well pipe

pressure

well

the

drilling

upward to exit the region being entered volume of the extending Likewise an pipe

move

pipe

movement

requires

downward

fluid

DRILLING

HYDRAULICS

movement either

The

laminar

which

the

for

must

pipe

The

conditions

velocity

Note

that

by

the

profile

inner

pipe

the

derived circular

.vp

on

correlations

Section

in

and

pipes the

conduit

fluid

Only

as

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the

4.10 anriulj

well

as

boundary

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pumping

fluid

10

in

4.54d

in

inner

identical

the

applied

Eq

the

to

down

the

ex

is

pipe

pipe flow

the

be

can

for

in

velocity

wall

by

shown

inside

profile

movement

fluid

Section

in

caused is

by

pipe

term

flow

velocity

pipe

caused

to

laminar

for at

velocity

mean

If the

developed the

hole

vertical

relative

pressed

at

derive

turbulent

is

through

profile the

pipe caused velocity

be

different

pipe out of

Fig 4.40

in

the

through

are

typical pulling

flow

movement

movement

fluid

to

swab pressures

Empirical

pattern

can

velocity

possible

and

surge

fluid

the

on

is

equations

laminar

conduit

to

apply

moving

Flow

differential

describe

to

It

pattern

flow

the

if

Laminar

basic

for

flow

the

depending

moved

is

laminar

used

4.15.1

of

pattern

equations

the

be

flow

or turbulent

mathematical ly

165

equation

Substituting yields

dpf

dL The

velocity

pipe

movement

by

pumping the

at

4.88

500d2

wall

4.53a

fluid

of

inner

the

for

slot

The

integration

Eq

simplicity

the

pipe

is

annular

flow

are

are

is

still

used

flow

to

for

not

in that

slot

applicable

if

the

because is

caused velocity

dHI

and

evaluate

flow

the

vertical

However Eq Eq 459a

zero

flow

by

profile

representation

preferred

4.59a

caused

velocity

annulus

for

slot

usually

geometry

annulus

the

through

conditions

boundary

the

from

differs

developed

developed

in

profile

the

proper

constants

of

d2

of the annular of

given

its

relative

by

Fig

440Velocity pulled

y2dpf

of

laminar

for

profiles

out

flow

pattern

when

pipe

is

hole

T0 10

2dL

and

The

constants

evaluated

using

vv

of

integrations

the

boundary

r0

and

vo

can

be

conditions these

Substituting

aty0

values

for

and

in

Eq

4.59a

yields

and

v0

yh

at

v_Lyhy2_vp1

4.89

2dL

these

Applying

boundary

conditions

yields

0010

vP

The

flow

is

rate

given

by

and

vdA

h2

dpf

2i

dL

Wdpf

T0

Solving V0

these

hYY2dYVW

fA

two equations

simultaneously

for

r

dpf

v/1

ldy

and Integrating

gives

2dL

vWdy

this

Wh3

equation

dpf

yields

VJWh 4.90a

APPLIED

ENGINEERING

DRILLING

166

will

open

vertical

fluid

flow

both

in the

pipe and

since

the

pipe

and

bottom

If the

geometry

of annular

terms

In

cause

However

r1

AW7i71r22

tional

4.90d

of

Substitution

Eq 490a

these

relations

equivalent

for

and

W7z

For

be

annular

the

annulus

common

have the

inside

fric

total

pipe and

the

geometry

frictional

in

as

the is

pressure gmdient of

combination

direct

such

same

movement

in the

bottom

the

the

uniform

casing

possible

is

top

pipe

annulus

and

must

and

uniform

also

hr2 r1

the

of running

case

is

pipe

loss

pressure annulus

the

and

both

at

pressure

the

of

4.88

Eqs

and

that

in

gives

qr22 dpf

71

d12

combined

flow

4.92

2r2r12

r1

dL

l2

1000d2

500d2

Also

since

the

must be equal moved

_r22_r12

in

magnitude

or out of

into

in

the

the

to

and

pipe

rate

annulus

which

at

steel

is

well

the

4.90b

qj flow

the

Expressing

rate

in

pressure gradient

dp1/dL

of

terms

annulus 0a and

in the

velocity

mean

the

for the

solving

flow

or

frictional

gives

d2

virdi

following

dpf

4.90c

dL

from

Converting field

r12

r2

units

more

to

VaVp

When dpf

4.90d

d12

ment

The

but

upward flow

total

in

opposite

from

displaced

pipe section

in

equal

volume torn

of

rate

is

rate the

direction

to

bottom

the

caused

by

the

is

be

hole by

closed

is

the

at

the

downward

pipe out of in

magnitude

flow the

of

the

rate

the

to

the

If the

bot

total

flow

the

the

the

pipe

magnitude

is

closed of

the

all

the

flow

mean annular

is

in

the

velocity

Td22_d12

Since

pipe

annulus is

and given

ID

10.0-in

that

annular

if

12-in

in

will

pipe

to

Similarly

cause

the

the

cause

When

of pipe

move

pipe

pressure change

the

at

this

movement

is

pressure

pipe

pressure change

at

the

this

pressure

of

direction

direction

frictional

when

Calculate of

the casing

of 2.0

is

open

that

4000

the

at

equivalent

ft

of

10.75-in

is

being

hole containing

the

If the velocity

bottom

the

to

point

cp

pattern

bottom

of

is

given

is

the

by

closed

4.91 0.489

ft/s

1.0

having

for

bottom

is

open

4.94

31044l0.75212_l0.752

610

of

rate brine

cas end

laminar

casing

Eq

having

at

calculation

with

casing

flow

lowered

9.0-Ibm/gal the

Perform

and

below

density casing

the

by

d12v

d22d12

4.94

derivations

computed

the

will

joint

1.0 4q

opposite

frictional

4.34

bottom

Solution inner

of

pipe

Example

Assume

the

cross-

of

ing

of

the

decrease

downward

ft/s

outer diameter

uniform

hole must

71d1

the

vertical

is

by

is

of

that

recall

equation

the equation

bottom

viscosity

where d1

fluid

the

increase

fluid

direction

of

pipe

Newtonian

the

yields

to

elongating

withdrawn

being

by

magnitude

which

rate

the

total

caused

in

equal

the

pulling

which pipe

pipe

given

of

fluid

drilling

but opposite

magnitude at

of

rate

hole must

the

Likewise

fluid

drilling

be

into

pipe

in

to

point

lowering

open-ended

was assumed

upward

is

the

at

this

using

movement

l000d2

due

flow

6d44d2d12d22d1

flow

fluid

dL

an in

area

simultaneously

laminar

for

3d44d12d2d12

convenient

obtain

we

units

of

movement

493

and

expression

sectional

consistent

4.92

Eqs

Solving

l20a

493

v7rd2dI

v1ird2

412--- 10.752122_10.75

the

mean

DRILLINS

HYDRAULICS

167

0.6

Turbulent

Q5L

27

a2 Ia

ci

0.4

a2

I-

C-

ri2..2a2

0.3

na

a2

na

02

-J

01

0.2

0.1

0.3

0.4

OF

cud1/d2-RATI0 Fig

The viscous

41 Mud

pressure gradient

is

given

cIingng

by

constant

Eq

4.90d

0.5

PIPE

for

0.6

0.7

0.8

computing

Thus

the

casing

is

total

pressure

4000

pressure below

surge

given

DIAMETER

swab

surge-and-

1.0

0.9

DIAMETERTOHOLE

of closed

ft

by

1-

Va

/L

dpf

.pfLLY.OO58400023 dL

psi

1000d2d12 The

equivalent

at

density

210.489

surge

--0.0O1O1

pressure

psi/ft

100012_l0.752

given

is

Pf

PeP

the

surge

pressure

diameter casing If the velocity

bottom

is

of

given

is

is

negligible

when

the

large-

9.11

open the

by

casing

Eq

is

closed

the

d22

406

23

9.0

0.0524000

Ibm/gal

mean annular

2v

10.7521.0

d1

12.02_ 10.752

and

flow

turbulent is

solved

best

assumed well pressure giadient

is

given

by

Eq

to

flow

between

split

also

such

cannot

be

of the

drillpipe

when

applied

complex

problem

The

technique

bottom

the

containing

possible

iterative

using an

annulus

It

is

to

applicable

directly

dnllstring

ajet bit

start at

not

is

as

pattern

ft/s is

4.94

pipe such

collars

drill

Eq

of

use

nonuniform

proach

The viscous

this

4.91 The

d1

for

ft

by

0.052D Thus

4000

of

depth

1.0

the

drillstring

pipe

interior

ap

usual

with an and

that

4.90

q1qaqp For

simplicity

dL

4.42 1000d2--d12

and total

The

has an flow

drillstring

exit

restricted area rate is

collar

drill

by

represented

bottom

the

equal

to

displaced

given

of

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with

the

represents

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by

total the

can

drillstring restricted

area

bottom

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exit

nozzles the

of

in

the

nozzles the

be

Fig bit

The

simplified

by

4.06 0.00584

100012.0

10.752

psi/ft

tl

4.95

APPLIED

168

d12

value

If

forfa

such

assumed

is

ENGINEERING

DRILLING

that

Ia

then the

annular flow

the

rate

drillstring

bottom

the

opposite

can

of

portion

computed using

be

q1 fq1l 4.96a

fa

At

any

in the

point

such

changes and

the

at

outer diameter

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between

juncture

annular

the

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drill

where

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flow

the

drilipipe

accord

changes

rate

to

ing

qiqa-i 1v

be

flow

interior

the

Similarly can

_d13 rate

in

4.96b

q1

pipe exit

the

computed using

q1fqi lfavp

4.96c

_A1

qp Likewise

at

any

diameter

ii

and

the

at

lars

The

d1

flow

total

rate

annular

the

the

rate

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above

at

flow

inner

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driuipipe

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drill

to

changes

__v

qq1 sum of

as

between

flow

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drillstring

such

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in the

point

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any

elevation

rate

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the

4.96d

in the

flow

rate

well

is

the

in

the

pipe

interior

d21 -l-q

It

Fig

4.42.Simplified of

hydraulic

representation

of

the

lower

part

can

shown

be

4.96d

that

the

from

total

combination

flow

rate

at

drillstring

pressed

of

Eqs

elevation

any

4.96b

However may be

flow

it

in

annulus the

If

is

tional

nulus

4.96e

possible

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is

that

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true

than

must well

as

flow

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direction

sign

direction

rate the

take

as

inside

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to

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pipe in the track

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magnitude

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rates

To determine value

ex

by

qvd21 d2

of

and

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can

Offa

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must

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correct

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pressure changes is

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the

surge so

through

sum of

swab

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all

frictional

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sum

sections

of of

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the

fric

an

pressure changes

DRILLING

HYDRAULICS

through rate

all

in the

rate

in

than

nal

pipe

one

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area

Values

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in

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than

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very small which

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are

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flow flow

the

are

greater

Values

when

occur

comparison

in

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Offa

to

If the

than

possible

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small

very

interior

direction

values

root

than

less

drillstring

different

interior

greater

is

annular

of

sections

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the

169

the

to

the

commonly

inter

annular

to

area

when

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the

internal

area

flow

tunately of

no

In

the

of

case

interior

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For

is

not

is

outer diameter

Eq

4.91 or

present

an

Total

pipe and

Examples of the

in

known

is

situation

the

drillpipe

in the

ft

required

of

flow

pipe no

and

this simplified

procedure

casing

closed-end possible

this

with

and

on is

It

possible

is

tions

using

Bingham

and

plastic

complished

by

wall

pipe

derive

to

included check

v0

for

the

model given

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pressure

flow

running

valve

float

4.35

Example calculate

boundary

vv

to

Bingham

are

equations

through

This can

be

ac

viscosity

conditions

at

the

annular

model

However

Appendix

in

the

such

the

in

plastic

too

far

was

technique

presented

by

method in the

based

is

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annular

on flow

equations

gested

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for

Eq

by

4.90d

for

field

ae is

0.5

used

in

Burkhardt

of 60

is

and

sug

surge

model

sections

bit

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the

given

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annulus flow

Eq

near

Burkhardt

flow

equation an

using

given

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annular

Eq

flow

slot

small

annular

proaches

slot

of

Schuh26

used

tween

Burkhardts

the

clinging

Bingham of

values for

the

of

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complex

model using

plastic

Note and

surge the

that

bottom

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of

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addition fluid

the

is

it

level

approximately of

assumed

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joints

of

the

outer shape to

assumed

The

equal is

that

pipe and

in the

drillstring

of be

given

total

by

17r

q1v

_d12_A1

also

can

value

be obtained fluid

power-law

of for

flow

and

pattern

laminar

and

in

sq

ft/s

cu

The

flow

the

bit

fa1

calculations

been

not

of

surge

given

drill

pipe

rates

in

interior

be flow

qp2O.844SI

and

Sections are

given

fa

of

Eq

by

the

swab

drill

collar

4.96d

ft/s

lw

sqft sq

in 144

developed or

by

ft/s

_0.2784j have

is

jets

pl 1fq1

and

resulting

turbulent

the

through

ap

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falls

rate

swab

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model The

geometry

in

Ii6.252_0.2784sq L4

for

Flow

the

at

effect

the

bottom

has been

constant

using

annulus

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annular

curves

correlations for

Fig 4.42

sqft

Fig 4.41

using

for

significant

irrespective

Turbulent

that

in

4.95

The flow

is

specifically

mud

correlation

most

constant

at

annular

0.5

curve

Empirical

for

the

clearances

approximation

4.15.3

the

be

will

Clinging

work

called

representation

pressures

ft

sq

4.60d

mean

effective

annular geometry

given

derived

equations

In

and

the

144

obtained

the

ignored

maintained

are

rate

by

for

plastic

10 lbf/lOO

l_

where the constant obtained

moving

is

problem Pipe and annular

starting

tool

full

kept

0.8445

is

collars

having

of

4.5-in

11/32-in

drillstring

shown this

of

effect

ae

and

negligible

hole

of

solution

For simplicity

ft/s

slot

drill

three

fluid

point

of

ft

ft/s

numbered

are

Vp

the

of 4.0

14300

For given

mean

effective

an

the

pressure

fluid

yield

The nomenclature

velocity

of

flow

The

model

hole below

of 6.25-in

drilling

and

cp

ft

containing

in

sq

rate

in the

adopted

the

fluid

pressure equation

an

if

larger

by

suggested

velocity

surge

Newtonian

surge

simplified

suitability

annular

the

the

for

defined

ac

velocity

of

obtained

is

The

bit

10-lbm/gal

pressures

The

effective

predicting

similarity

Newtonian

the

of an

equations

pressure equations

example

usc

the

to

flow

resulting

surge

and

0.2784

maximum

the

1961

in

ID

power-

complex

computing

Burkhardt25

nular flow by

ID

drillstring for

the

plastic

7.875-in of

composed 700

drillstring

Solution

and

application simplified

use

to

Bingham in

pressure

3.826-in

nozzles

as

models

models

the

equa

pressure

the

Using

swab

the

2.75-in

surge

fluid

then

is

laminar

the

the

Models

power-law

changing

from

derivations

law

laminar

non-Newtonian

and

onset

procedure

both

for

pressures

patterns

the

establishing

em

Unfor

pipes

usual

these

an

value

15000-ft

Fluid

flow

turbulent

for

that

on

given

pipe string

Non-Newtonian

swab

or

Recall

circular

The

available

are

surge

drillpipe

4.15.2

criteria

published

turbulence

for

developed

equations

based

are

con

clinging

flow

geometry turn

in

equations

have

calculation

velocity

situation

to

equal

based

is

annular

well

be

iterative

flow

the

through

to

apply

Schuh2t

for the

turbulent

the

annular

for

correlation

calculate

pipe

by

pirical

used

and

correlation

to

required

of ft

annular

occur

comparison

Fig 4.41

presented stant

Burkhardt25

However

pressures

fa0.15731cu

ft/s

sq

in

and

APPLIED

DRILLING

ENGINEERING

through

their

jets

170

OF SWAB PRESSURE TABLE 4.8SUMMARY CALCULATION FOR EXAMPLE 4.35

The

use

Variable

fq/q1

q1 q2 q3 AP5 ApdG

0.5

0.692

ft/s

0.422

0.211

0.251

0.260

cu

ftfs

0.265

0.054

0.093

0.103

Cu

ft/s

0.111

0101

0.061

0.052

115

160

171

442 104

psig psig

Ap

Total

0.70

cu

psig

Ap

0.75

psig

44

33

through

vie

of

through

the

the

flow

ing

laminar

46

449

273

293

297

results

995

421

497

514

loss

selected

is

the

total

CU

ft/s

0.422

0.633

0.594

0.585

q82

CU

ftls

0.012

0.223

0.183

0.174

APdca

psig

104

139

128

126

APdp

psig

335

405

392

389

velocities

439

544

520

515

losses

psig

The

in

similar

the

and

of

qai

fluid

surface

Table

flow

frictional

using

4.8

rates

pressure procedure

The flow

and

to

rates

in

pipe annulus

drill

4.96b

and

ir

the

bit

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an

to

respect

jets

given

observer

d12

2j

_452

ft/s

fa

at

by sq

ft

in

0.84451 fa _________

qt/A1

ft/s

ft/s

sq

v11

drill

pressure

interior

in

The

collar

-v

qa2qai

with

velocity

through

given

interior

0.8445f

faqtt

0.8445

mean

the pipe

the

are

and

two

the

summed

drillstring

determined

are

for

used

the

the

of

velocities

annulus

the

15730.1544

108445faY0.31171 The

values

of

ir

fa0

0.84451

calculations

these

to that

in

computed using Eqs 4.96a

are

9P39P2_4

losses

both

for

are

they

us

frictional

larger

Once

value

determined

losses

replaced

The

the

is

the

calculated

are

calculated

are

correct

is

effective

Sections Fir

as

assumed

various

for

the

pressure

of

results

section

and

4.6 with

flow and then

section

each

Table

in

Pb

4.31

pressure

pipe

respectively

each

for

Eq

frictional drill

given

v3

turbulent

and

foi-

give

Total

equations and

losses

pressure

The and

collars

bit

of

rearrangement

for drill

vj2

by

loss

pressure

calculated

144

in

sq

0.2784/144

08445fa0.4104

cu

ft/s

ft/5

The

mean

observer Similarly pipe

the

interior

fluid is

velocity

given

in

the

drill

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collar

annular the

at

fluid

with

velocity is

surface

given

to

respect

an

by

drill

8445fa

by

Va1

q0t/I

ai ir

v2 q2/A2

_7.8752 _6.52__

fa0.1573

0.84451

_______________

144

ir

_2.752

7.34fa

ft/s

144

ft/s

0.4104

0.8445fa

qa2/A

a2 ir

Vl3

_7.8752_4.52__

fa03h17

0.84451

144

q/31A/3 ir

_3.8262_

3.707fa1.802

ft/5

144

The

10.58l

faY39041

defined the

The

effective

wall through

fluid

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velocity bit jets

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with given

to

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nozzle

Vietvitvp

are

pipe

wall

the

effective

in the

drill

fluid collar

velocity

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drill

with pipe

respect is

Vie2Vi2Vp

v3v3v4

given

to

0.410

and

0.465

Thus

drillpipe

Similarly

and

0.794

constants

the

fluid

mud

the

Fig 4.41

drillpipe

flow flow

ft/s

where

by

clinging 4.41

by

annular

effective

aKip

ft/s

The

opposite

obtained and

0.460

and

0.486

effective

1Id2 the

for

drill

these

0.571

is

is

The mud from

for

respectively

turbulent

opposite

velocity

is

7.834

vaet

Vat

0.410

Kvp7834fo46s

ft/s

ft/s

Vaet

7.834

fa1.64

7.834

fa

1.86

for

laminar

for

turbulent

Fig

laminar

for

the

by

by

opposite

collar values

respectively

annular

given

constant

clinging

ratio

is

velocity

flow

flow

the

DRILLING

HYDRAULICS

the

Similarly collars

drill

171

annular

effective

velocity

opposite

the

is

3.707

Vae2va2KVp

13.707

ae2

1.802046

fa

3707fal.802O.486

Ia

3.707

0.038

for

laminar

0.142

for

turbulent

losses

in the

flow

flow PIPE

OUTSIDE

The

frictional

pressure

annulus

pipe

Table

in

given

then

the

Once

section

losses

the

frictional

total the

Phe

of

4.8

The

movement 69.2% from

was

of

annulus

the

terior

515

of

the

losses

to

The

at

the

of

final

the

due

to

results

lb/tOO

14

/Lp

and

I0.9

in

loss

upward

the

flow

28

solution

total

also

of

the

total

summarized

that

3mm

ft

Ib/I00

InitialID

until

interior

pipe

are

bottom

the

30.8%

and

the

tried

ft

GEL

annular

give are

Offa

in the

drillstring

psig

flow

the

Values

indicate

the

as

each

lb/ft

l8I2-I8S

flow

selected

for

summed

are

calculations

results

beneath

pressure

loss

equal thus yielding

these

sec

turbulent

is

23

a-

pressure

are

results

and

results

pressure

annulus

in the

annulus

Table

two

the

the

determined they

is

pressure

in

laminar

each

for

PIPE

INSIDE

vae2

b/ft

ft

equations and

losses

pressure

both

of

larger

value

correct

for

Vae

by

40

drill-

2100

flow

the

using

replaced

frictional

calculated

are

and

4.6 with

The

respectively tion

calculated

are

and

collar

drill

in

pipe

indicate

the

drillstring

was

was from

-300 TIME

in

the

Fig 4.43Typical

drillstring

pressure

was

of7casing

surge

pattern

lowered

the

into

measured

as

wellbore

after

joint

Ref

25

In

Example

and

the

to

respect

flow of

based

is

case

the

value

over

inside

the

the

interior

pipe

ror

to this

the

interior

approach

the

pipe

The

computed

the

constant velocity

divided

this

It

not

flow

traveling

by

Clark

bottomhole

and

Clark

also

the

the

inertial

were

movement

er

alter 27

compared computed values

well

computer

surges

were

achieved

downhole

downhole

broken

and

fluid

fluid

4.12 the

gel

pressure surges than

those

values

for

power-law

10

to

be

pressure

and

sections

easily

This

the

allow

varied

with

required

the

the to

when the

the

inertial

viscous

effects

The fluid

4.15.4

to

effects also

occur

the

of

pressure

vertical

in the

pipe

weilbore

surges

caused

in

The pressure change

on

an

the

due

accelerating

the

sum

of

of

the

in in

the fluid

fluid

Sec

4.1

element

the

at

due

to

by

of

by

Section

of breaking the

general tend

to

be

effects

vertical

forces

less

for

example

direction

forces

times

not

must its

pressure

be

this

equal

acceleration

FMa pA P_DAFwvAADPAD

ac

the

be

to

In

can

hole of

in

depth

the

pressure the

pipe

gel

inertial

Fig

downward

downward

to

of

Consider

area

but

mass

of

element

discussed

element

fluid

from consideration

estimated

dp

movements

the

Effects

Inertial

program

addition

by

drag

downhole use

brakes

the

in

effect In

drag

and

gel

developed

movement

when

gel

of breaking

effect

and

viscous

deceleration

calculate

by

the

maximum velocity breaking

single

bottomhole

the

slips

equations

pipe

by

Fig 4.43

in

as

string

of the

to

caused

caused

in

properties

pressure

to

rapid

used

vertical

by

at

casing

breaking

the

effect

Thus

be

can

also

of

measured

rheological

temperature

into

properties

temperature

viscous

results

with

for

was

rheological

In

Best

model

corrected

experimentally

The identical

is

pumping

of

effects

applied

that

of changes

well

in

the

by

from

was lowered

pipe

cross-sectional

two wells fluid

to

pressures

the

to

and

acceleration

record

is

occurred

that

added

caused

lifted

fluid

Fig 4.43

well Note are

was

casing

when

was

the

pressure peaks

ting

surge

into

and

gel in

pressure

casing

lowered

be

Fontenot

of

the

Shown

deceleration

up

and

trial

equivalent and

by

is

average

flow

In

pipe

is

the

is

annular

interest

the

by Fontenot

Eq

the

value

to

of

flux

effective

of

velocity

fluid

using

interior

is

on flux

constant point

or

from pipe

some

by

pipe

must be determined

given

is

joint

done

the

fluid

or

description

in

area

the

on

used

along

amount of

the

still

excellent

at

total

rate

be

the

riding

pipe length

area

add

flow

subtracts

rate

The

surface

break

to

required

with

approach

inside

flow

equal

However

An

native

is

that

observer

entire

pipe to

velocity the

the

the

annulus

computed

was based

total

velocity

interior

pipe

necessary

an

were

pipe This can zero Flow up

leak

fluid

to

respect

this

be

to

The

at

4.96e

compute

to

equal

rate

with

to

in the

velocity

equivalent

closed-end

considered flow

observer

alternate

with

fluid

the pipe

Eq

flux

always

on

4.96e

fluid

An

authors

the in

velocity stationary

or

rate

steel

both

4.35

fluid

fluid at

rest

case to

the

ft2

APPLIED

ENGINEERING

DRILLING

172

TABLE 4.9-FOR SPHERICflES VARIOUS PARflCLE SHAPES Shape

Sphericity

Sphere

1.0

Octahedron

0.85

Cube

081

Prism

Ct2f

077

2f2t

0.76

2t3

0.73

Cylinders

hr/15 hr/10

0.25 0.32

h.r/3

0.59

hr

0.83

h2r h3r

TFbO

0.87 0.96

hlOr h20r

0.69 0.58

Fig

444Streamlines

of

movement

fluid

about

settling

particle

of

Expansion

second

the

A.D

ment volume

term

and

division

ele

the

by

gives

When the

realistic

dp

expression in

depth

the

of

the

in

change

with

pressure

fluid

accelerating

the

fluid is

acceleration

magnitude

the

is

to

equal

the

hydrostatic

hammer

However

equal

to

we

are

If

the

fluid

due

pressure gradient

times

density

interested

in

to

wall

can

elastic

the pressure surge

1POOOI2

accelera

the

elastic the

of

inertial

of

that

predicts

zIv

the

is

velocity

the

pressure

and

theory

scope

velocity

given

is

pipe

water

this

hook

an

instan

for

of

magnitude

by

LXV

PVwave

then

where

pa with

pipe the

relation

celeration

is

closed

between

given

end

fluid

an

in

given

effective

and

pipe

ac

Vwave

completely

effective

velocity

Eq

4.98

units

the

following

4.97

into

and

to

converting

expression

for

field

closed-end

pipe

Ce

psi

dPa

O.00162pad21

dL

dd21

99

the

is

and

is

effects ft

effective the

fluid

inside

situation solution

is

to

and too

be

open

outside

complex

easily

pressure surge small and of no

pressure

pipe

wave

end the

the

pipe

for

practical

by

at

acceleration

different

convenient

developed

caused

fluid

However

inertial

interest

effects

rates

can

of

compressibility density

the

fluid

ibm/gal

the surge pressure due to iner Compute 0.5-ft/s2 acceleration of by downward

caused of

1075-in

12.25-in

borehole

Solution

The

casing

with

pressure surge

Pa2

closed

10-Ibm/gal

containing

0.00162pa

occur

the

wave

by

Example 4.36 tial

10000

an

rigid

of

pressure inelastic

CeP

Substituting

pipe with

the

ij

by

4.98

For

of

velocity

For

incompressible

acceleration

where

yields

the

or borehole is

the

fluid

the

ft/see

For fluid

is

wave

through

4.97

dL

the

of

beyond

fluid

in

not be

rilay

characteristics

dampen

also

theory in

change

elastic

that

recognize

fluid

the change the

discussion is

should

one

the

only

fluid

4.99

incompressible

when

effects

less the

gradient

an

addition

seen

taneous

which

effect

fluid

tion

says

of

weight

inertial

that

downwardly

specific

In

hole or casing surge

This

of

especially

very rapid

pa

dD

Eq

applying

assumption

is

given

by

end

through

mud Eq

4.99

d21

This

approximate 0.00 for

this

are

generally

case

162100.510.752 12.252

_10.752

l0000271

psi

DRILLING

4.16 The

HYDRAULICS

Particle

fluids

often

is

discussed the

in

well

solid

of

and

of

the

describing for

only

forced

particle

observations

direct

of

of rock

cuttings

the

conditions

most

of

the

Again

by

4.103

drilling

law

found

is

expres

to

be

used

is

acceptable

give

For

below

The

friction

in

factor

numbers

friction

case

this

for

accuracy

Reynolds

empirically determined

than

greater

must

engineer

number

Reynolds

obtained

factors

defined

is

by

and

correlations

empirical

units

As

Stokes

been

field

in

well

geometiy

analytical

have

number given

Reynolds

from

the

complex

slip velocity

for

the

engineer

involved

primarily on

depend

out of

settle

drilling

functions

primary because

idealized

very

to

the

removal

conditions

boundary

sions

to

the

fluids Unfortunately

dc

will

particles

concern

Chap

one

is

Velocity

Slip

which

rate at

173

applications

4.104a 4.16.1

Newtonian

For at

terminal

its

on

ing

the

force

the

the

to

be

Wof

can

viscous

expressed

by

terms of

in

the

The buoyant

viscous

to

kinetic

of

area

energy

the

per

and

particle

volume

unit

force

defined

is

Eq

by

volume

unit

per

the

and

4.100

given

is

EKpfv5j

force

If the

Eq

characteristic

4.104a

area

reduces

chosen

is

24

rd5

be

to

the

vertical

v1

FWFb0 p5p1gV

The

spherical

given

by

ird53/6

and

terms

in

pressed

of

viscous

the

the

volume

the

particle

of

the

force

can

Fp pfg7d5 I6 Stokes28

streamlines spherical the

shown

has of

and

velocity

v5

of

there

viscous

the

particle

the

for

creeping

movement

fluid

particle

pass no

is

smoothly

is

the

through

related

i.e

the

about

the

fluid

to

the

cle

slip

factorf case

function

is

spheri city sphere

Sphericity

by

shapes

and

the

their

facilitate

lines

slanted

noniterative

term

are

solution

graphical

some

4.9

Table

The

shown

is

Fig 4.45

the

particle

of

list

relation in

the

as

in

called

surface area of

the

particle

shown

are

sphericity

as

number

Reynolds

volume

the

friction-factor/Reynolds-number

in to

provided

technique

Ex

ample 4.37

of slip

same

surface area of

the

shapes

defined

is

the

containing

divided

of

of nonspherical

Fig 4.45 The

downstream

eddying

drag

sphere

flow

The

factor

friction

of

calculation

by

from

104b

F37rd5/2v51

can

equation

consistent

be

units

to

for

rearranged

velocity

slip

particle

Converting

field

units

the

Eq

gives

4.101

Eqs

Equating

ex

be

4.100

that

in the

is

particle

diameter

particle

Pf

friction

and

For

4.104b

obtain

we

forces

then

to

Pf

Summing

kinetic

by

of displaced

weight

pf5g

Fb0

EK The

of gravity

acceleration

expressed

due

particle

and

density

by

liquid

characteristic

energy

the

is

be

can

the

on

drag

the

caused

drag

of

particle

by

exerted

force

downward

the

counterbalanced

and

where

act

forces

V5g

where Fb0

force Fb0

The weight

vertical

zeroi.e

be

exactly

is

gravity

the

fluid

through

falling

sum of

must

buoyant

fluid

Wp5

material

the

velocity

volume

the

Fluids foreign

particle

due

sum of by

of

particle

AEK

4.100

velocity

and

4.101

and

fr3.57- Ps solving

for the

si

parti

lO4c

Pf Pf

yields

Solving

this

for

equation

the

particle

slip

velocity

yields

d2

p1g

p5

sl

102a

18 which tent

is

4.ld

known

units

as

convenient

to

law

Stokes

field

from

Converting

units

consis

gives

This

l38p

pfd

is

can

equation

below

if

defined

the

be

extended

friction

factor

to at

Reynolds

low Reynolds

numbers number

by

4.lO2b 24 Stokes

law

4.105 can

be

of

spherical

particles

as

turbulent

eddies

ticle

used

to

through are

not

determine

Newtonian

present

The onset of turbulence can

in the

the

slip

as

liquids

wake

be corrected

NR

velocity

of to

the

long

par parti

The

proof

of

this

relation

is

left

as

an

exercise

APPLIED

174

ENGINEERING

DRILLING

10000

fCrushed

Silica

Pt

LL

--

LL

Crushed

Spheres

200 60 40 20

Galena

11

i_l LL

0.6 0.4 0.2

01

-i

ii

I-

0.001

-001

RARTICLE

24

01

00

10

000

106

0000

SIZE

REYNOLDS NUMBER BASED ON AVERAGE SCREEN

10000.

LL

000 600 400 200 100

60 40 20

4-44

if

10 if

--

t4

p0600 I\HII

0.4 0.2

01 0.001

0.01

10

0.1

PARTICLE REYNOLDS

BASED

Fig 445Friction

factors

sphericities

for

computing

ON DIAMETER

particle-slip

velocitV

1000

100

10000

106

NUMBER

OF EQUIVALENT

crushed

l0

solids

and

spheres

and

SPHERE

particles

of

different

DRILLiNG

HYDRAULICS

175

Example 4.37 How of 0.025 of

and

hole

the

and

cp

if

specific

circulation is

4.45

of

gravity

Solution

is

slip

must

first

law

by

the

of

porosity

bottom

on

fill

is

approximately

minutes The

volume

0.01

of

viscosity

303

ft

10.4

The

factor is

assumed

be

plot

shown

in

to

Fig

4.16.2

Fluids

Non-Newtonian

applicable Particles fluid

l38 pfd

the

the

fluid

force

net

sufficient

to

For

sphere

the

required this

Equating

the

on

force

break

to

force

to

the

non-Newtonian

static

through

settle

is

buoyancy

the

__8.3300252

not

will

unless

and of

13812.68.33

the

0.40

bottom

2.6

is

friction

Stokes

Assuming

30

to

having

sand

sand

the

settle

for

water

velocity

point on

will

about

the

mean diameter

having

stopped

8.33-Ibm/gal

containing

establish

sand

of 0.81

sphericity

fluid

drilling

much

overcome surface

the

force

the

to

to

by

given

strength

and

xd5

is

area

gravity

gel

equal

is

gel

net

due

particle

2T8 4100

ird

Eq

gives

1.15

This

slip

ft/s

velocity

to

corresponds

number given

Reynolds

p

ds2Tg

friction

factor

and

by

Thus

the

Pfg

gel

needed

strength

diameter

is

given

to

suspend

of

particle

by

pjd

3.57p

TgPspf

PfVI

3.57

this

Converting units

8.331.152

4.106a

from

equation

consistent

units

field

4.lO6b

rgIO.4dspspj

0.108

to

gives

or conversely

the

diameter

particle

must

exceed

and

928pfvjd

NR

9288.33l

Tg

.150.025

4.106c

_____________________

lO.4p

222

to

settle

Fig 4.45a

Entering and

moving

I0.81 Thus

an

yields

the

slip

the

to

is

f0.108 NRe222

point

the

slant

intersection

velocity

.89

VsI

at

parallel

lines point

given

to

curve

the

f5

NRe4O

An

having

Eq

by

106c the

around

pattern for

fluid

through

Particles

given

Pf

for

gel

will

slowly

settle

greater

such to

corresponds

sphere

for

than

that

has

that

flow

the

flow

creeping

flow

creeping

non-Newtonian

rg

strength

slightly

solution

analytical

developed

having

diameter

been

not

fluids

by

Ps-Pf

4.38

Example

suspended gel

mud

has

that

lbm/l00

of

maximum-diameter

gravity

specific

by

strength

the

Compute

having

particle

sq

of

2.6

density of

that

sand can

lbm/gal

be

and

ft

l.89.J 8.33

Solution grain

0.17 If circulation tle

from

ft/s

is

the

stopped

bottom

for

30

minutes

the

sand

will

given

by

Eq

l0.4ppf 0.038

of

maximum

set

ft

portion

The

diameter

of

spherical

106c

ft/mm

10.1

approximately

30l0.1303 of

or

is

the

hole

If the

sand

packs

with

in

l0.4

sand

176

APPLIED

DRILLING

ENGINEERING

IL

ov

4.16.3 In

Carrying Capacity of

rotary

fragments ther the

wall

the

rotation

in the

the

behavior

rate

or

lems

the

related

countered

muds

thick

flow

in

beneath rate

the

Thus

have

been

Bruce2

the

lift

nular

ft/mm ft/mm

drilling-fluid several

the

among In

1951

Before

gradually

of

was

to

tions

for

of

pump

have

achieved

Moore31

flow

the

most

these

correla

extremely

accurate

32

they do

behavior of

selection

widespread

correla

lhe

Walker

and

pro fluid

drilling

conditions

operating

Chien

the

Moore

Moore3

and

Mayes33

acceptance

Correlation

has proposed

velocity

equation

average

flowing

an

for

condition

Newtonian

apparent

for

procedure static

The method

operations

based

on

during

the

11

pressure-loss

Newtonian-fluid

Newtonian

parent

obtained

viscosity

manner

in this

the

then

The

viscosity

of

computation

annular

the

for

expressions and

the

drilling

method pro using and in Sec presented

viscosity

models

slip

to

the

by

tional

lO4d

experienced

is

the

applying

Eq

fluids

and Metzner19 Dodge This method involves equating

posed

for

solving

given

ap

the

Newtonian

apparent is

fric and

power-law

by

work

their in

work

et

al.30

cutting

estimating

for

transport

investigators the

have

cutting

slip

of about

100

\0.020

4.107

experimen

fluid

while is

provide

drilling

empirical

100

water

should

velocity

\fl

an 200

that

typical

proposed

/2

mud

on

recent

indicates

to

ex

was about

value

More

accepted

of

results

minimum

the

practice

for

required

measurements

used

their

Sifferman

the

and

need

the

d2di\i--n

capaci

Williams

velocity

may be required when the drilling minimum annular velocity of 50 ft/mm Several

mud

or

rate

recognize

ft/mm

satisfactory

penetration

carrying

authors

annular

field

generally result

by

the

flow

they reported

capacity

As

first

minimum and

work

tal

of by

laboratory

velocity

action

economic penal

higher

studies

the

carrying

of

use

conducted

cuttings

tensive

the

considerable

en

toward

cleaning

in

tions

in

give

necessary

were

establishing

reduction

may be

with

the

the

prob

However as mud viscosity

velocities

to

flow

are

tendency

complex insight

and

properties

4.16.4

if

such

for

valuable

to

expected

this

lifting

the

not be

While

operations

drilling

rotary

results

vide

Moore

of

should

tions

primarily

removal

increasing

cause

of

the

either

natural

on

location

increased

is

at

addition

relied

cuttings

4.13

zero

force

determining

fluid

annular

fur

complexity

practice

in

in

relative

have

detrimental

and

Experimental ty

be

there

than

viscosity

the

resulted

Section

bit

associated

ty

of

high

can

rate

In

inefficient

and

pointed out or

to

This has

their

for

fluid

viscosity

pipe

centrifugal

extreme

experience

drilling

effective

the

personnel

drilling

and

affects

of

rock

the

from

varies

imparts

during

and

complicated

center of

the

which

Because

is

correlation

velocity

Fluid

fluid

velocity

drillpipe

fragments

of

at

the

situation

fluid

maximum of

observation

ability

the

that

annulus

flow on

fact

to

rock

the

The

moving

are

the

by

4.46Particle-slip

Drilling

both

operations

drilling

102

REYNOLDS NUMBER

PARTICLE Fig

I0

mud

correla

experienced

This

apparent in

viscosity

defined in

this

by

Eq

103

manner then

correlation

4.46

viscosity

was

given obtained

in

used

is

the

computing

The

can

be

Fig using

in

place

particle

used

limestone

Newtonian number

number computed

with

The

the

Reynolds

Reynolds

4.46

of

the

data and

friction

shown shale

factor in

Fig

cuttings

DRILLING

HYDRAULICS

EQUIVALENT

177

ANNULAR

50.0

V0

VELOCITY

25.0

ftl

6.7

mm

Transport

Ratio For

Error

100

12.5

Prediction

70%

Pprcept

Confidence

LU

LU

LX

LL

LX LU

.04

.02

INVERSE

Fig

ANNULAR

4.47Comparison

of

field

bulent stant

300

and

the

friction

value

at

methods

1.5

-250

predicting

For Reynolds the

this

numbers is

particle

becomes For

reduces

104d

of

-200

the

plots

considered

is

as

staight

be

to line

4.16.5

108a

or less

laminar

such

error

of

by

in

250

200

CUTTING

ratio

cuttings-transport

methods

various

slip

Chien

The Chien in

and

the

the

flow

friction

pat

factor

that

Correlation

conelatihn32

that

it

Newtonian tern

iso

to

numbers of

Reynolds

too

con

essentially

condition

so

-50

ERROR IN PREDICTED RATIO TRANSPORT

predictions

tion

particle

-100

Fig 4.48Histograms

tur

fully

154 For

-150

PERCENT

around

factor

of about

Eq

velocity

flow

the

10

ratio

operations

drilling

than

greater

.06

I/V0 mis /ft

VELOCITY

various

cuttings-transport

from

.06

is

involves

for

viscosity

number determination recommends

Chien

similar

the

to the

use

in

the

the

correla

an

apparent Reynolds

particle

For polymer-type computing

Moore of

computation

drilling

apparent

fluids

viscosity

using

40

4.109

NRe

For

this

condition

the

slip

velocity

reduces

equation

to

However

d2

si8287PP

4.108b

Pa

apparent

100 factor

For intermediate proximation

for

recommended

numbers

Reynolds

shown

in

Fig

4.46

is

the

dashed

given

line

ap

by

the

plastic

viscosity

For

particle

recommends

Chien This

recommended numbers

of

suspensions that

the

is

only by

the

slightly

Moore

following

bentonite

Reynolds use of

higher

1.72 than

For lower

correlation

in

be

viscosity

water used

for

is

it

the

numbers above for the

the

value

particle

friction

of

1.5

Reynolds

was presented

22

Pi 0.0075

._ pfd

For

this

relation

the

2.90dp

slip

velocity

equation

reduces

Pf0667 108c

VSI

0.333

Pa

Pf

This

corresponds

laminar

flow

and

to

0.333

to fully

transitional

developed

flow

pattern

turbulent

between

flow

4.110

APPLIED

178

II

Slip Error

For

Difference

Velocity

70%

for

Confidence

the

Walker shear

the tion

200

calculation

of

Mayes

developed

and

is

due

stress in

given

units

field

numbers

Reynolds

particle

an

to particle

ENGINEERING

DRILLING

relation

empirical

The shear

slip

for

rela

stress

by

4.113 CHIEN

150

CORRELATION Fluid

All All

The

Types Typas

Cutting

shear

then

obtained parent

using

then

is

rate

stress

stress

particle

using

T

dial

1.703

speed

The ap number

viscometer

the

in

shear

rotor

rotational

obtained

use

for

viscosity

determination

50

shear

vs

standard

shear

the

of

plot

using

1.066

reading

100

to

corresponding

rate

determined

is

Reynolds

Pa479

4.114

Ys

If

the

200

computed

is

correlation

Li

number

Reynolds

velocity

is

numbers

100

than

greater

4.112

Eq held

in

provided

the

The

units

slip

following

for

Reynolds

100

than

less

is

using

MOORE CORRELATION

50

All

Ftuid

All

Types

sl0.02O3TA/

Types

Cutting

4.115

100

where d5 out

that

shear

account

to

nulus -50

the

to

particle

the

Mayes

of

the

disk

slip

the

liquid

on

by

relative

not take

in

the

an

in

velocity

independent

is

be pointed the

does

predicted

velocity

correlation

and

fluid

the

to

should

It

based

is

viscosity

shear due

fluid

Thus

and

lO0

apparent

of

rate

diameter

the

is

this

the

Walker

of

annular

50 velocity

DIFFERENCE BETWEEN OBSERVED AND PREDICTED PARTICLE SLIP VELOCITY FPM

For

field

sent of

in

error

Chien

slip

velocity

predicted

by

correlation

an

chosen

shapes

projected

The

friction face

Walker

and

correlation

by Walker

proposed defined

factor

rather

horizontal

Correlation

Mayes

for

circular

than

for

and

Mayes33

disk

sphere

in

flat

For

uses fall

ing

the

ing

Eq

diameter

divided

settling

of

velocity

as

by

The thickness can

area

the

chosen

is

be obtained

is

For odd

four times

the

pro

around

the

by

water

in

repre

thickness

the

perimeter

cuttings

from

to

disk thickness

be chosen

can

particle

estimated

and

diameter

equivalent

area

be

measur

and

solv

rate

equal

the

parti

forh

4.112

flat

4.16.7

this particle

configuration

4.111

Cutting

Rock

cuttings

to

difference

the

cle

f2hPsPf

disk

represent an

the

must

The diameter

cuttings

sectional

representative

thickness

equivalent to

jected

4.16.6

and

of rock

sample

Fig 4.49Histograms Moore and

applications

diameter

slip

face

is

toward

between

The

velocity called

Ratio

Transport advance

the

the

particle

transport

the fluid

surface

at

and

velocity

relative

velocity

to

the

sur

velocity

Pf

VT where

is

number

Reynolds considered of

1.12

field

andf this

units

of

the

100

than

greater

turbulent

Substituting to

veiling

thickness

the

is

assumed

value

off in

disk the

For flow

constant

Eq

4.111

particle is

pattern at

value

and

The transport dividcd

by

the

ratio

defined

is

annular

mean

as

the

transport

velocity

velocity

con-

gives

FT.l--

4.116

Va

4.112 For

positive

transported This tion

equation first

is

also

presented

by

equivalent

to

Williams

and

slip

velocity

Bruce.29

equa

cutting to

zero the mean nular

velocity

the

transport

surface

cutting

and

the

For

velocity cutting

ratios

the

particle is

equal

transport

cuttings slip to

be of

mean

an

unity

As

the

ratio

will

velocity

is

HYDRAULICS

DRILLiNG

179

Io

65

DEPTH MUD

8000

DENSITY

PLASTIC

60

FT 6.2

POINT

YIELD

PPG

VISCOSITY

55CP

I5LBS/IOQFT2

VELOCITY

SLIP

16.7

Li

FPM

55

JET

FORCE

IMPACT

16.6

LI cr 50

16.5

OQ

Li -J

\\ 45

BOTTOMHOLE

16.4

EQUIVALENT DENSITY

CIRCULATING Li

-J

40

MIN

16.3

COST-PER-FOOT

35

16.2

25

50

75

ANNULAR Fig

the

slip

velocity

and

the

concentration

to

the

ticular In

to

be

nique As can

should

be

The slip

which

ft/mm

drawing of

11v5

slope of

the

the

an

Eq

is thus par-

line

thex slip

transport for

Thus

slip velocity

was by

is

of

cuttings-transport

plied

Sifferman

of

intercept

to

in

annular veloci

one

velocities essentially

an

Sample and below

Fig 4.47 and

Note

about

independent experimental

Sample and

types

prisms and

static

column and then

predicting

of 10

to the

are

representation

intercept

of

cutting

actual

evaluate

shown

found

to

the cuttings in

be

rock

published in

the

and

example the

com gave

flowing

fluids for

of

muds

the ratio

The

an

file

data

variety

file

of

was used

methods

error

experimental

file

fluid

rectangular

various

The

data

different

using

The most accurate of

data

expenmental

obtained clay

transport

use

as

correlations

spheres disks The data cuttings

accuracy

Fig 4.48

in

Sam

well

sizes

and

and

plotted

for this

computer

compiled

measurements

water polymer

as

various

the

available

velocity

slip

of

results

data

Walker are

method of

the

by

Fig 4.47

plot

Bourgoyne the

all

cuttings

particle

to

with

results

that

best

experimental

straight-line

containing

types

the

obtained

results

consists

Note

in

and

Chien the

was ap

experiments

shown

are

and

the

Bourgoyne gave

essentially

ott

Moore

applied

comparison

that

This procedure full-scale

results

the

of

were

for

also

puted

equal

equal

The

velocity

making

in

plot

numerically is

is

and

correlations also

in

obtained

al

et

be obtained

could

data

using

The

optimization

ratio

transport

ple

tech

slip velocity

intercept

infinite

ratio

annular

velocity

approximate

an

to

velocity

straight-line

the

particle

from they

if

of

plot

graphical

4.116

and

that

slip

of

convenient

to

velocity

line

route

of

capacity

velocity

corresponds

found

determination

from

velocity

of

reciprocal

annular

ratio

of the annular

reciprocal

annular

ty must be equal

120

seen

particle

Bourgoyne

carrying

en

150

125

VELOCITY FT/MIN

Mayes

the

result

tercept

of

transport

an extremely

of

independent

the

Cutting

annulus

Sample and Bourgoyne34

by

vs

ratio

was found

the

in the

the

decreases

ratio

transport

of results

fluid

work

recent

the

4.50Example

cuttings

of

measure

drilling

transport

to

of

surface increases

excellent

an

increases

FLUID

100

for

histograms

approach slip

was

velocity

180

APPLIED

MUD 60

FT

25000

DEPTH

ENGINEERING

DRILLING

I8PPG

DENSITY

PLSTIC

YIELD

SLIP

VISCOSITY

POINT

VELOCITY

CURVE

CP

FPM

LBS/2 100 FT

________

_______ 30

35

55

40

20

Ii

55

IS

50CROSS-OVER POINTS 45

40-

35

INNULR

VELOCITY CORRESPONDING TO MINIMUM COST-PER-FOOT

30 50

25

75

ANNULAR 4.51Example

Fig

measurement made the

was found

tion ror

fluid

drilling

to

in

for the

histogram

most of

that

accurate

static

viscosity

on

sample

of

correla

empirical

er

slip velocity

correlation

shown

is

Fig

in

4.49

given

predicts

Sec

1.10 the

Sec

5.7

assumes

of

set

the

using

cost

of

per

developed cuttings

foot

using

Eq

The penetration

Chap

computer ratio

transport

The computer

conditions

field

1.16 rate

model

presented

in

was predicted

model defined by Eq 5.28 presented in The penetration rate equation Chap

drilling

of an

exponential

increasing

bottomhole

penetration

rate

force

cuttings-transport

and

For low

of

raised

to

increases the

0.3

decline pressure

mud volume

determined at

the

tings

bit

the

in

turn

the

rate

concen

causing

causes

high

high cir

low penetration rate in

cuttings

cuttings

penetration

ratio the

high

is

pressure and of

foot

per

transport

This

fraction

and

cost

annulus

by considering

bit

given

cuttings

density

bottomhole

culating

minimum

in the

cuttings

effective

FT/MIN

feed

of

the

feed

can

be

cuttings

FT

ratio

transport

dD/dt

mud

the

rate

rate

For of

cut

is

qA dD

4.117

dr

in

penetration It

also

proportionally

power

values

of

tration

The

Sample and Bourgoyne34 also model for estimating the optimal for

optimal

50

125

FLUID VELOCITY

31

Moore

Moore

mud

of

stirred

recently

The be

effect

100

to

rate

assumes the

jet

with that

impact

where assumes individual

is

that

the the

grains

area

cuttings

cut

by

do

not

Otherwise

the

bit

disintegrate factor

of

This

equation

to the

size

must

of be

DRILLING

HYDRAULICS

where

applied velocity

of

the

annulus

of

area

181

Au

rock

the

is

given

is

The

porosity

and

VT

Cuttings

fluid

transport

in

borehole

by

must

serve

cost

used

ple

Since

flow

the

is

volume

the

is

f5

and

the

in

cuttings

FT

defined

is

Example 4.39 Compute

as

having

cutting

q5

nular nulus

lf

for

volume

the

fraction

of

and

the

120

the

Apply

Walker

for

fluid

drill

densi

blowout

fluid

drilling

uf2.6

ft/s

data

following

were

and

obtained

viscometer

rotational

using

Chien

Moore

of

in

21.6 Ibm/gal

at an an pumped in l0x5 in an

being

2.0

ft/mm

025-in

of

ratio

transport

Dial

Speed

rpm

volume

the

exam

gives

qFq

Reading

degree

4.118

2.0 3.3

of

fraction

mud

annular

the

viscosity

For

high

prevent

correlations

Rotor

Once

to

fluid in

low-viscosity

maintain

mud

Mayes The

q5

tive

fluid

drilling

gravity

clay/water

velocity

afs

expression

considered

not

achieve

the

specific

9.O-lbm/gal

FT

this

required

crossover

drilling

considerations

many to

the

the

mud

the

then

Solving

the

simultaneously

may be

of

left

the

shallow

theoretical

mud

the

ratio

transport

of

fraction

of

rate

and

which

ty

of

may be impossible

it

fluid

ing

and

formula result

to

the

Of course

functions

other

for

primarily

where

451

Fig

many

often

is

seen

occurs

foot

per in

foot

per

als

where

cost

shown

region

re

rule

boreholes

large-diameter

minimum

VT

this

to

Exceptions

known

is

cuttings

can

density

be

effec

the

computed using

100

13

200

22

300

30

600

50

4.119 where

is

The

by the

creasing

density

is

increased

excessive

to

Also

the

decrease

with

frictional exists

frictional

optimal

flow

cost

per foot

theoretical

Typical

mud

while

drilling

minimum

curred

an

8.5-in

an

equivalent of

velocity

studied only

yield

to

excessive

the

Thus

ft

used

of

of 30

at

the

ft/mm

120

maximum

slightly

higher

For impact costs

with

the

300-

the

Moore

such

theoretical

use for

transport

annular

of

fluid as

viscosity

cost

per

low-viscosity

muds

of

ratio

velocity

valying

be

can

log 30

5ll

the

oc the

occurred

force

criteria

increased

than

or density foot

could

fluids viscosity

be

In

by the

most

achieved

index

normally

are

0.74

30

510

and

drilling

or by adjusting

behavior

reading

l52eqep

at

Newtonian

The apparent 120

ft/mm

ft/s

is

at

viscosity

given

by

an

condi tended the

7d2d 1n2__1/n\

true

increasing fluid

cases

prop

152

lower

l442

through

the

Example results computed shown in Fig 4.51 are

58

l0_5\0262l/0.74\\074

cp

an

Eq

0.0208

Cuttings

erties

flow

correlation

optimum

the

and

600-rpm

i50

ft/mm

force

ft/mm

foot

and

for

that

most

per

cuttings

an annular

impact

density

circulating

50

on

40 ep

Note

occurred

index

consistency

based

model of

of

velocity

maximum

velocity

the

there

4.50

viscosity

foot

per

The

of

Correlation

minimum

in

Fig

18000

at

thickness

Solution

The

annulus begins

computer

slip

hole

cost

annular

to

in

plastic

cuttings

ft/mm

the

and

in

due

rate

the bit

results

shown

0.25

in flow

of

minimum

tions

and

100

at

annular

15

in

drilistring

using are

having

theoretical

of

velocity

to

of

the

diameter

the

approximately

Moore

flow

the

due

which

both

n3.32

Borrgoyne

16.2-lbm/gal point

in

rate

obtained

results

Sample and

yield

losses

pressure

an

are

which bottomhole

at

rate

be

thus

mud

the

as

can

and

rate

losses

available

flow

increasing

at

annulus

increasing

pressure

force

impact

jet

with

increasing

flow

reached

is

Assume

cuttings

in the

However

ratio

point

pressure begins

mud

the

increasing

the

mud

of the

transport

of

density

average

average

decreased

rate

the

0.0208

annular

4.107

velocity

APPLIED

182

ENGINEERING

DRILLING

then

0.00758.89

Grovel

Sp.Gr.261 Porovity

al

Fig

0.79

ci

IbI

4.52ExampIe

0.3

columns

fluid

for

The

Exercise

given

number

Reynolds

particle

4.1

ft/s

for

this

slip

is

velocity

by

82.5

8270.790.25 an

Assuming

flow

transitional

Eq

intermediate

pattern

the

slip

is

velocity

NRe

number

Reynolds

particle

given

20

by

4.108c

Since

2.90dp

Eq

Pf0667

0.333

1a

Pj

this

0.333

number

Reynolds

4.110

is

The

justified

than

less

is

the

use of

given

by

100

ratio

transport

is

200.79 0605or60.5%

Fr 2.0

2.90.2521 .6_9.00667 0.49

ft/s

Walker

and

The shear The

particle

number

Reynolds

928pf1d

is

this

annular 0.49

108e

given

is

is

is

and

ft/s

2.0

cutting

300

ratio

transport

the

for

140 shear

muds

viscosity

600-rpm

static

liquid

is

sq

ft

stress

lbm/lOO sq

of 14

given

ft

to

corresponds

Fann

by

14

75.5%

13.1 1.065

For clay/water

and

lbm/lOO

reading

0.49 or

in

of

slip velocity

Correlation

plastic

Eq

by

0.755

falling

particle

4.113

an

2.0

Chien

the

7.9JO5T0 and

dial

FT

using

of

7.9\pf

Ts

18

between

The

justified

20

of

velocity

ft/s

number

stress

estimated

58

Reynolds

Eq

use of

by

92890.490.25

Pa Since

given

Correlation

Mayes

as

Chien

recommends

the apparent

readings

503020

on

the

viscosity

Fann

use of

the

Using

the

the

300-

This

in

rpm Fann

for

we

gives

turn the

corresponds data

viseometer

given

1.703

is

to

roughly

The

shear

times

rotor

rate

the

at

rotor

speed

bob

the

speed

of

100

in the

Thus

have

14

ep

39ep

i.ta479

.703lOO Assuming given

by

transitional

Eq

flow

pattern

the

slip

velocity

is

4.110 Assuming

0.0075

si

given

t_

by

Eq

vOO2O3

/La

___pfd5

particle

given 20

--8.89 90.25

velocity

is

/dy

.703100

0.0203l4 The

slip

r-s.J

/0.251

_l

the

pattern

4.115

Pfdc

Since

flow

transitional

Reynolds

number

for

by

92891 .070.25 57

NRe 39

this

1.07 slip

ft/s

velocity

is

DRILLING

HYDRAULICS

Since

Reynolds

Eq

this

4.115

is

183

number The

justified

than

less

is

100

ratio

transport

the

is

use of

given

0465

46.5%

or

surface

2.0

Answer

4.8

The can

4.1

Calculate the

the

hydrostatic

column

fluid

Answer

5200

for

each for

psig

at

pressure

shown

case

bottom

the in

of

231

be

tom

Fig 4.32

4.2

mud

Calculate

the

stratum

5000

at

Answer

psig

density

ft

the

if

14.6

to

required

fracture

that

ibm/gal

An

ideal

20 What

600R

has

gas

the

is

an

of

density

Answer

molecular

average

0.8

the

2000

at

gas

of

weight

of

mud

The 10

between

in the

well

the

stop

is

at

the

blowout

after

832

preventers

is

blowout

the

psig

14

4.9

8000

of

depth

well

massive of

0.30

at

drilled

to

The

of

ft

at

mud

drilling

are

nular

capacity

preventers

of

Estimate

below

the

5500

ft

4378

the

exerted

pressure

bottom

of

the

Assume

4000

is

the

well

at

that

sand

is

the

nulus

5500

the

equivalent

Answer

ft

15.3

density

at

casing

of

depth

of

10000

when

casing

cementing

of

500

16.7-lbm/gal

by

mud

be

will

brine

9-ibm/gal

pressure required

the

5.8

no

shoe

the

completely

ft

of

ft

The

high-

the

easing

minimum pump

displace

used

are

joints

2000 1500

from

the

casing

Answer

1284

psig

4.10

well ft

is

1-ibm/gal fluid

ing

If

against

mud when

7000

psig

circulation

pressure the

12000

at

permeable

using

is

cut

by

exerted

by

an

hav bit

the

what

stopped

is

be

will

ft

formation

permeable

pressure of

fluid

hydrostatic

drilled

being

mud

the

formation Answer

6864

psig Will are

left

the

flow

open Answer

Calculate blowout

well

the

preventers

blowout

preventers

yes

surface are

the

if

closed

pressure

Answer

an

ideal

psia

mud

in

weight

an

the

ibm/gal

mud

of

vs

of

density at

mud

the

atmospheric

leaving

pressure

density of

the

the

fluid

drilling

depth

mud

gas-cut

completely

by

at

the

be

surface

the

mud

depth

of

increasing

densi

no

rels

mud

of

are

ized

an

initial

easing

136

if

the

psig

is

driilpipe the

posite

the

in

pump

closed

mud

pressure

ft

the

is

and

stopped the

550

opposite

of

Fifteen

bar

5-minute the

blowout

pressures

400

psia

stabil

and

were

recorded

5-in

19.5-lbf/ft

psia the

12200

rate

over

pit

pressure of of

at

flow

to

After

driilpipe

0.0775

600

vertical

begins

gained

are

before

preventers

at

12-ibm/gal

the well

when

period

drilled

circulating

bbi/min

an

The annular capacity op of 3-in ID drill collars is 0.035 bbi/ft

bbl/ft

Compute

the

the

kick

assuming

of

density entered

as

the

slug

kick

material

Answer

5.28

Ibm/gal

Compute

the

the

kick

assuming during

drilipipe

Assume

as

Ibm/gal

being

is

while

initial

well

the

reached

are

pressure

methane and behaves

The annular capacity 4.7

of

annulus

flush

displaced

is

temperature

velocity

conditions

the surface

the

ty Answer

the

bit and

ibm/gal

slip

bottomhole

equivalent

plot

eliminated

being

gal/mm The an

400

of

porosity is

cuttings

11.9

the

at

12

the

6205

is

of

The mean

pure

is

Can

The

that

the

cement

Calculate

to

so

from

and

high-strength

mud

bottom

designed

Assume

9.875-in

Ignore

is

annulus

in the

depth

l0lbm/gal

displaced

cement

at

place

on

placed

is

be

will

filler

cement

Assume

contains is

of 8.5-ibm/gal

ft

12.7-ibm/gal

strength

well

string

operation

mud

10-ibm/gal by

The

ft

the

in

velocity

slip

0.35

using

density

rock

Answer

of

gal/ft

gas

Answer

ft/hr

steady-state

annulus

the

Ibm/gal

be cemented

to

is

string

an average

having

ft

2.8

and

Make 4.6

6.5

to

scf/gal

rate

effective

What

psia Calculate

0.764

at

the

What

of

depth

80

has

is

Answer

gas

Answer

behavior

gas

effec

the

velocity

saturation

600R

is

After

what

psia

against

surface casing

ideal

the

Neglect

per

gallon

per

and

well

the

water

fresh

10000

at

of

rate

circulated

lbm/gal

surface pressure

the

con

gas

lower

to

ft

of

Answer

water

being

annulus

and

are

pressure

feet

the water

to

gas sand

and

the equivalent

methane gas occupying the upper The mean gas temperature is

contains

6000 170F

cubic

174F

bot

methane

of

5000

the

hole

with

gas

gas behavior

ideal

of

the

hydrostatic

volume

at

process

pressures

injecting

by

gradient

gas behavior

gas bubbles 4.5

in

lowering

against

formation

injected

relative

gas

the

from

when

stopped

flowing What

ft

closed Ansier

is

muds

annular

from

4000

at

density

increased

being

what pressure must be held

the

by

is

pump

two

the

drillstring

surface

the

well

if the

lbm/gal

interface ft

of

density

12

to

be

by

standard

Assume

the

ideal

4.4

water

gas temperature

Ibm/gal

be

shut

is

drilling

rotary

effective

the

hydrostatic

lbm/gal

and

psia

of

must

tive

4.3

Calculate

volume

3800

is

pressure

the

reduced

is

the

exerted

where

areas

easily

fluids

fracture

before

ft

will

well

the

greatly

pressure

sometimes

after

of

rate

increased

In

trolled

what

closed

arc

000

11

psig

hydrostatic

Case

of

1.1

gravity

specific

depth

pressure

penetration

Exercises

to

up

preveriters

annular

of

brine

annulus

the

blowout

the

2.01.07

FT-

formation

if enters

by

Do

the

density

mixed

detection

you think

Compute

the

of

the

with

the

time Answer

that

the

pressure

kick that

is

will

kick

material

mud pumped 1.54 liquid

be

ibm/gal or

gas

observed

at

184

APPLIED

the

casing

kick from

reaches well

the

Answer

the

the

reaches

the

annular

Answer

kick

zone

increased

is

tion

of

5-in

the

circulated

lars

the

at

the

be kick

also

surface

mud

kill

the

Answer

927

the

Using

that

gain the

data will

be

if

the

surface

before kick

from

kick

top of

3.0-in

circula

remains

behaves

as

an

as

mud

the

increasing

drill

vs

and

slug

ideal

that

Answer

gas

applied

to

ment

the

in

surface

the

Assume

that

any

present

density

20-bbl

influx

10000-ft nular

well

and

drill

gas

the

load

so

bit

to

would

the

the

observed

the

when

is

in

4.17

the

kick

reaches

be

in The

sur

the

surface

annular

the

kick

1040

surface if

Assume

the

gas

that

pressure

was methane

was 0.1667

capacity

derrick

he

supported

open-ended floated

4.14

capable

The

lost

hook

in

bbl/ft

level

mud

load

4.18

8500 is

the

and

the

drillstring

to

the

yes

dur

bit

19.5-ibm/ft and

collars 13

is

of

the

lbm/gal

re

collars

drill

tendency

at

flowing

in

pressure

5-in

drill

length

buck

of

compressive

in

the

of

160

ft

an

rate

steady

an

having

10

is

internal

diameter

external

of

in

flow

average 3.49

in

the

the

an

velocity

ft/s

the average the

Determine

pressure

the the

if

flow

the

psi

negligible

easing

easing

flow

in

velocity

Answer

0.871

the bottom

of

drillpipe

frictional rate

and

10-Ibm/gal

ft/s

at

loss

350 gal/mm

is

well

the

mud

lbf

diameter

sounded

by

driller

was

run

and

not

the

the

depth

contained

consisted

of

of

hook the

5860

9400

8000

collars

drill

is

pump

the

by

mud

the is

depth

the

drill

is

density

The in

ft

in

2.75

2600

is

900

is

drilistring

and

psig

psig

4.19

mud

10-Ibm/gal

600 gal/mm

2-in

one

3000

psi

in

well

the

is

If the

contains

nozzle

what

is

circulated

being

bit

the

and

total

the

at

pump

frictional

system Answer

1969

rate

2-in

two

of

nozzles is

pressure

pressure

loss

psig

that

4000 load fluid

14.5-Ibm/gal of

the

pressure developed

Answer

well

notices

total

before

the

of

in the

could

and

increases

Calculate

the

60000 ibm The

is

of

of the hole

Answer

ft

the

was gained

well The well the

if

and

to

Answer

buckling

is

point

anticipated

nulus opposite

collars

of

500000

72-Ibm/ft

l2-lbmtgal

alarm

slowly

load

stabilized

and

the

equipment

in the

of 4.33 diameter

Compute

gas and instead

is

density

supporting

derrick

Answer

circulation

Ibm of hook again

the

through

monitoring the

by

of

13i-in

of

feet

hook

the

or compres

axial

applied

hole

psig

is

many

be

mo

applied

hydrostatic

drillpipe

Compute

in

can

psig

annular

kick

the

gas

off is

the

be

of

density

mud

that

pressure

was methane

or com

K-ibf

example

to

weight

down

drillpipe

if

external

this

Answer 496

lO-lbm/gal

bbl

64

neutral

the

prevent

diameter

would

that

gain

pit

the

which

minimum

the to

of

circulation

psig

Answer

bbl/ft

density

ibm/gal

bottom

bending

tension

be composed 2.75x8.0 in

will

driilpipe

saltwater

of

ft

8.0-

that

weight

weight

at

interval

and

that

the

How

next

the

ternal

413

psi

gal/mm

top of

the

Compute the would be observed

684

18150

Compute

the

before

density

total

Compute would be observed

annular

for

maximum mud

kick

18

off

slacks

axial

psig

pressure

mud

the

to

true

quired

top of

the

easing

of

defines

maximum

The

driller

computed

point

equal

drillpipe

the

806

psig

annular

if

208

20

of brine

785

when

the

Answer

4.16

of

is

causing

Answer

the

graph

pressure

after

ft

19400

tension

axial

without

that

the

ing

and

drillpipe

observed

surface

the

Answer

0.0775

be

mud

kill

Compute

the

drillpipe

is

pa

of

ft

inside

The formation

surface

Answer

well

stead

the

of

Ibm/cu

ft

suspended

of

drillstring

the

this

Is

the

600

factor

extends

depth

drilistring

reaches

face

the

inside

capacity

shut-in

Compute the would be observed

the

factor

the

well Answer

the

creased

opposite

bbl/ft

the

that

pressure

kick

hhl/ft

stress

The an

opposite

as

of

600

maximum

the bit

Construct

ling

enters

mud

ID-Ibm/gal

The

ft

depth

490

of

and

is

graph

the

that

sion vs

psia

Compute

entered

water

bbl/ft

and

0.008

is

salt

well

total

in

an

depth

Assume

998 bbl

0.0775

0.0500

bbl/ft

collars

6000

is

is

The capacity

collars

0.0 1776

is

containing

capacity

drillpipe drill

of 9.0-Ibm/gal

9875 in

of

composed

is

string

Lubinski4 4.12

having

4000

at

The mud density

collars

the

pression

to

col

drill

set

is

the

drillpipe

Construct

psia

circulated

The

the

Casing

density

drillstring

drill

Assume

4.10 compute the pit when the kick reaches

is

collars

ft

19.5-ibm/ft

Exercise

observed

to

has

Determine 4.11

in

diameter seat

Steel

20000-ft

5-in

that

density

before

density

1029

the

mud

the

if

12.347

easing ft

air

in

drill

air and

in

0.0775

pressure

when

surface

the

hole having

from

4.15 annular

of

of 7-in

ft

ibm/ft

Ibm/ft

diameter

10000

The

density

is

100

open

to

psia

surface

reaches to

easing

the

circulated

mud

the

the

is

will

of

top

kick

the

increasing

1204

the

19.5

weighs

weigh

600

and

drillpipe

drilipipe

density

that

pressure

if

well Answer

the

top of is

mud

the

when

inside

Compute the would be observed the

the

kick

the

increasing

surface

capacity

bbl/ft

casing

surface

before

surface

annular

if

ternal

the

at

when

ft

psia

Compute

zone

the

before

3198

observed

4000

of

depth

zone

ENGINEERING

DRILLING

ft

of

4.20

the

Compute

pump from

9-lbmgal

fluid

1000

Assume

tional

468

ft

pressure

psig

pressure sea

that

changes

level

inertial are

required to

and

an

to

pump

elevation

viscous

negligible

of

fric

Answer

HYDRAULICS

DRILLING

421

pump

185

being

is

operated

fluid

drilling

area of

the

bit

the

to

Compute the

gal/mm of

the

total

developed

loss

pump

energy Answer

this

the

of

of

force

impact

bottom

viscous

to

the

of

jets

Answer

hole

the

hp

Define

Newtonian

shear

fluid

2709

dilatant

4.23

4.24

of

stress

shear

for

Newtonian

or

Answer

cp

The

rate

25

apparent

in

plot

between

the

Shear

600

was

11.0 15.2

40

19.1

22.9 26.5

250

rotational that

of shear

4.30

shear

behavior

Newtonian

Derive

the

Compute data

using

be

Bingham

apparent

the

20

at

cp

yield

taken

seconds

432

or power-law

each

for

viscosity

shear

plastic

of

rates

and

60

4.33

viscometer

dial

reading Is the

of

index shear

at

What

contains rotor

at

40

fluid

nian fluid

and

flow-

the

poise

centipoise

4.17

10

rates

of 20

cp

eq

in

speed

Fann

the

fluid

that

is

rpm 600 rpm

of

radii

r2

Is

between the

the

velocity

fluid

for

obtaining

ob rpm fluid

power-law rotor

at

rotor

speed

of

speed

of

flow

index and

Answer

the

apparent

Newto

viscometer

and

at

viscosity

lbf-s/sq

4.35

300

ft Answer

rpm 20

in

65

eq

cp

contains

of

fluid

cp

at

fluid rotor

that

speed

bob

radius

profile

velocity

and

vs the

approximately

is

consistency rotational

cp

in dial

100

in

and

the

vertical

well

tubing

that

the

the

is

viscosity

of

annulus

pattern

flow

the

having rate

6-in.-

the

flow

7694

psig

that

tub

frictional

psig

Compute

in

pressure

Assume

at

containing

cp

of 3-in

ft

the

fluid

circulated

index.for eq

Compute

88

Answer

drillstring

Compute

ft

94

9000

through

of

viscosity

sq

flow-behavior

Newtonian

being

7176

and

plastic

lbf/100

0.888

laminar

4.5-in.-OD

has an

having

2500 B/D

is

cp

as

point of

flowing of

loss

is

culating

10

the

from

rpm and

to

index

9.2-ibm/gal

in

ft

of

index

Answer

rate

at

pattern

100

gal/mm

casing static

of

15000

laminar

and

and

cir ft

Answer

psig

of 600

436 plot

200

and

at

consistency

at

yield

oil

40-cp

pressure

and

rpm Make

of 22

reading of 39

reported

fluid

of 30

viscometer

viscosity

sq

viscosity

readings

100

contains

the

plastic

dial

and

reading

of

the

rotational

flow-behavior

fluid

4.34

gives

of 300

speed

rotor

at

lbf-s/sq

rotational

apparent

yield

lbf/100

and

cp

rpm

Assume 4.26

17

obtaining

rpm

equations

and

this

Why is

and

viscosity

plastic

Answer

dial

40 cp and

p.139

n0.8

Answer

reading of 20

speed

the

viscosity

20

dynes/crn2

consistency

seconds

rotational

speed

for

dial

and

200

and

point

s3.3

the

dial

plastic

rotor

viscometer

gives

Derive

ing

4.25

Bingham

at

readings obtained

seconds

index using data taken

60

contains

reading of 39

and

at

consistency

and

cp

from

point

rotational

cp behavior

cen

in

modeled

accurately

plastic

shear

at

Answer

Compute

viscosity

of

speed

fluid

the

dial

equations

yield

dex

55

of

rotor

rotor

fluid

behaviorindex

model Answer

the

Newtonian

at

at

rpm Compute of

five

0825

paper Can the fluid

Compute

11

of 22

of 600

log-log

rate

Answer

fluids

reading

rpm 600 rpm Compute

abscissa on Cartesian paper Make of plot shear stress ordinate vs shear rate abscissa on

the

200 300

dial

rpm and

300

rate

by

rotational

of

100

ft

ordinate vs

stress

for

radius

rotor

containing

viscometer

gives

of 300

that plot

bob

the

reading of

Answer

4.31

Make

be

radius

the

of

speeds

rpm Compute

tained

60

and

at

viscometer dial

gives

and

50

rate

the

429

dynes/cm2

30

vs

stress

Newtonian

for

rpm

rotational

Stress

20

radius

rotor

point

seconds

shear

shear

centipoise

observed

Rate

of

for

fluid

Shear

rotor

constant

approximately

bob

th

fluid

the

behavior

shear/stress-rate

vs

the

r2

and

Make

tipoise

following

and

radius

bob

the

rate

Viscometer

4.28

in

Compute

viscosity

rdw/dr

rate

shear

seconds

measured

is

seconds

shear

Is

Determine

and

rheopectic

dynes/cm2 of 20

rate

of

plates

r2

pseudoplastic

and

thixotropic

shear fluid

r2 r1

previous

between

moving

section

lhf

non-Newtonian

shear

stress

radius

radii

4.27 4.22

for radii

and

stationary

plot

radius

effects

210

the the

in

Make

tween

power

of

discussed

nozzle

the

by

case

the

the

in

sq

power

the

happens

against

and

800

density

hp

1400

Compute What

The

psig

ibm/gal

0.589

is

Compute Answer

15

is

of

rate

at

3000

pressure of

and

radius rotor linear

for

radius as

in

Bingham cp

and

that tional

plastic

yield

the

flow

fluid

point pattern

of is

pressure gradient

has 12

plastic

lbf/100

laminar resulting

viscosity sq

ft

compute from

of5O

Assuming the

fric

flow

APPLIED

186

of

rate

4.37

50

through

gal/ruin

3.826-in

ID

through

10-

psi/ft

0.0240

and 7-in

The following

having

drillstring

flow

of

rate

annulus

90

4.42

gal/mm

Answer

Work

Exercise 4.40 of

density

0.0171

taken

with

psi/l000

ft

Show

Eq

fluid

power-law flow

144

having

behavior

index

consistency

turbulent

Answer

readings were

for

ibm/gal

and

0.75

psi/ft

12

ENGINEERING

DRILLING

200

of

psi/l000

index

205

turbulent

ft

of

cp

eq

rotational

viscometer 4.43

that

0N

flow

45

friction

4.66d the

region by

can

be extended

laminar

to the

Eq

of

substitution

4.67d

for the

factorf

5.5 100

4.44

9.0 14.5

300

19.0

Compute

32.5

in

600 the

Using

model

power-law

pressure gradient

flow

Compute

to

expect

give

pressure

shear

the

What

drillpipe

0.00586 rate

two

rotational

an

the

best

the

wall

annulus

1.5

cp

eq

flow

turbulent

shear

estimate

rate

ql294

the

wall

the

at

Rec 3200

For

and

ft/s

9000

Also

the

Answer

rate

from 130

gal/nun

y8I7

ft

psi/l000

and

loss

pressure flow

this

Fig 4.34

flow

and

of

the

would

readings

factors

computation

gradient

for

for

required

rate

in

flow-behavior

index of

psi/ft

the

at

fric

SO-gal/mm

Assume

drilipipe

Answer

laminar

is

pattern

from

resulting

2.9-in-ID

rate in

the

compute

flow

the

has

slurry

consistency

8.097-x4.5-in

frictional

tional

cement

15-ibm/gal dex of 0.3 and

200

445 Show

you

for

bit

the

Answer

that

number

Reynolds

identical

86

conditions

the

to

hydraulic

given

conditions

the

maximize

to

required

pid1

by

are

/p.a

maximize

to

required

the

the

force

impact

seconds

plot

Make

plot

of shear

stress

of

flow

vs

vs

velocity

and

radius

4.46

pipe radius

The

bit

The

driller

mud 4.38

fluid

power-law and

cp

flow

frictional

Assume

4.39

flow

the

index

rate

in

0.9

of

gradient

flow

index of 90

consistency

behavior

pressure

l2O-gal/min

0.0182

has

11-in laminar

is

pattern

pump

from

resulting

9-

the

at

Answer

The

psi/ft

seat

the

flow

to

begins

gel

diameter of to

start

and

in

the

circulation

ibm/lOU

has an

has

how

can

be

the

ft

hp and has an minimum flow rate

an

Answer

reduced

conditions

11.6

What

4.40

well

is

water

being

drilled

having of

viscosity

has an

6.5

in

of

500

of

The

the

as

cp

external

diameter

of

3.826

fluid

drilling

is

The

fluid

conditions

internal

diameter of

the

hole

circulated

relative

240

surface pressure

condi

operating

maximum

for

bit

q514

run Answer

bit

will

horsepower

Answer

force

will

Answer

nozzle

obtained

will

Answer

at

the

hp

be obtained

con

at the

lbf

1270

velocity

selected

be

611

be

477

obtained

at

the

ft/s

drillpipe

an

being

bit

selected

selected

What

using and

and

Assume

gal/mm

ft

ibm/gal

of 4.5 in

The

in

8.33

drilling

diameter

5000

of

depth

at

density

sizes

next

the

impact

lbm/gal ditions

0.9

is

cuttings

0.345

A1

What

required

pump

proper

nozzle

for

horsepower

gal/mm

the

bit

just

external

rated

of

psi

and

tions

the

the

pump is

efficiency

The maximum allowable

3000

10

lift

pump when

and

The pump

overall to

10-ibm/gal

gal/mm

observed

is

the

gal/mm

of 250

rate

psi

Determine

diameter

pressure

800

500

observed

is

psig

to

when

of

rate

t2-in nozzles

three

that

1000

casing

sq

internal

drilipipe

Discuss

the

density of

having

of 70

strength

The casing

in

7.825

below

density

mud

when

ft

and

lbm/gal

of

equivalent

4000

at

of

gal/mm is

Compute

slowed

is

pressure

annulus

at

3000

pressure of

eq

Compute

has recorded

pumped

is

use has

in

currently

at

4.47

rate

of

roughness

Work

Exercise

4.46

for

maximum

than

rather

is

Answers

are

the

qqx

for

both

same

maximum

bit

for

impact

horsepower

conditions

given

force

Answer because

cases

zero Determine

Answer

flow

the

the

in

pattern

drillpipe

4.48

turbulent

Work

Exercise

Determine

1000

ft

the

ft

of

51.3

the

loss

per

q24O

ft

psi/1000

in the

pattem

Answer

drillpipe

pressure

Answer

flow

the

Determine

1000

frictional

of drillpipe

Determine posite

the

annular

op

4.49

frictional

annulus Answer

pressure 72.9

psi/i

loss

000

following

Work

Exercise

having of

25

Answer ft

4.40

density

cp

and

turbulent

of

for 10

yield

132

Bingham

Ibm/gal point psi/l000

plastic

plastic

of

Well

depth

ft

185

well

nozzle

horsepower

v553

conditions

are

velocity

Answer

ft/s

given

sq

psi/l000

ft

15000

ft

OD

in

ibm/ft

fluid

in

viscosity

lbf/lOO

bit

per ft

Drillpipe

4.41

maximum

for

gal/mm A10.l36

The

turbulent

4.46

maximum

than

rather

Drill

collars

Casing

19.5

ID

effective

8-in -OD

J-55

set

at

4.33

3-in-ID

4500

ft

in Ibm/ft

ft

600 10.75 40.5

DRILLING

HYDRAULICS

87 Bit

diameter

assume

in

Compute

9.875 hole

average

Nozzles

three

Surface

equipment

of

size

in

10

in

Compute

/32

Double-acting

duplex

pump

hp

1500

in

Overall

Maximum 200

piping of

ft

85

surface pressure equivalent

4.52

3500

psi

drillpipe

12

100

speed 1.8

Reading annular

Compute

the

300

15

20

4000 14000

to

an

annular

4.53

circulating

15000

of

the

12.10

Bingham

2A2-in

model

desired

is

conditions

the

the

well

total bit

nozzle

area of

the

the

nozzle

000-ft

between

0.324

sq

4.54

for

increments

10000

at

following

if

sizes

for at

an

interval

of

and

in

4.000

ft

The well plan

ft

4.55

Density

Viscosity

Point

in

lbf/100

sq

6000

10.0

25

5.0

7000

10.0

25

5.0

8000 9000

11.0

30

6.0

12.0

35

8.0

Pump efficiency Maximum pump Drilipipe Drill

OD

in

3200

psig ft/mm

ID

in

and

4.5

4.57

ID

Casing Surface

of

and

plastic

of

bottom

the

lowered

Assume

ibm/gal

ibf/lOO

of

8.33

0.126

at

that

the

that

the

viscosity ft

sq

gravity

100

an

826

annulus

of 0.81

of

in

lbf/lOO

the

and

in

having of

viscosity

diameter

ep

of

ratio

following

fluid

using

Rotor

Speed

that

having

gel

in

cutting

having

mud

ft/mm

data

0.070

O.375-in

thickness

of 90

particle

fluid

being

in

were

specific

pumped

6.5-

at

x3.5-in

obtained

for

the

viscometer

rotational

600

out

in

10.05

in

10.05

equipment

to

equivalent

140

Dial

rpm

Reading

degrees

ft

4.0

of

drillpipe

6.6 4.51

50-bbl

kick

with

drilling

an

of

and

1100 rate

1000

psig

of

25

bbl/stroke

ft

mud

is

0.0087

After

bbift

previously

strokes/mm

was The

pump pump

psig

of

13000

an

factor

200

44.0

300

60.0

600

100.0

the

Compute

transport

ratio

the

using

Moore

correlation

of

reduced is

26.0

ft

internal

pressure at

100

psig

were

of 0.0 1422

having

recorded

while

pressures

1200

2600

capacity

collars

ft

the

composed

internal drill

14000

pressure of

pressure of

an of

of

depth

drilipipe

drilistring

having

of

capacity

at

casing

The

drilipipe

bbl/ft

initial

initial

recorded

taken

15-ibm/gal

stabilized an and

is

Compute

the

transport

ratio

using

the

Chien

correlation

0.24

Compute and

Mayes

18

sand

Answer

ft

sq

14-Ibm/gal

velocity

The

of 0.0

12-ibm/gal

transport

of 2.5

annular

having

water

through

and

ibm/gal

sand

diameter

ft/s

diameter

both

mean

maximum

the

of

velocity

2.6

sphericity

Compute

drilling

2.75-in.-ID ft Hole size washed

flowindex of

ft/s

closed

is

three

lowered

having

being

hole

ft

6.25-in

being

below

casing

point

settling

be suspended

7.5-in-OD

collars

the

strength

0.85 pressure

13

of

containing

3.5

density

string

yield

gravity

Compute can

1250

annular velocity

and

cp

density

if

4.56

hp

of

density

Answer 5.0

Pump horsepower

of the casing

of

rate

hole

11400

consistency

8.5-in

an

of ft

is

fluid

and

of 7-in

in

bit

driiistring

of 0.8

ft

7.875-in

600

and

drilling

equivalent

ft/s

Compute specific

25

Minimum

28

Yield

cp

the

10000

has

Plastic

10.0

the

calls

conditions

ibm/gal

and

Ibm/gal

composed

ID

maximum

at

ep

bottom

of

The

index

of

mud

ID

2.75in

14-ibm/gal

of

Mud

5000

12.8

in

pressure

4.3-in

Calculate

rate

pump operating maximum jet im

proper

surface casing

casing

Depth

the

calcula

the

laminar

Answer

of

10-ibm/gal

Perform is

an

rate

at

containing

pattern

end

surge

nozzles

250 eq

need

bit

Answer

horsepower

estimate bit

at

termediate for

to

and

force

pact

in

bottom

the

lowered

cp

drillpipe

through

12.13

Ibm/gal

the

behavior

maximum

of

closed

collars

of

drilipipe

plastic

12.10

ibm/gal

hole

driiistring

5-in

Joint It

casing shut

having

casing

being

is

12000-if

correspond

the

opposite

in 4.50

was

below

density

flow

the

has

at

density

ft

casing

viscosity

Calculate

drill

velocity

using

Compute for

the

at

well

36 120

ibm/gal

ed

density the

11.75-in

12.25-in

assuming

casing

of

ft

the

in

below

and

equivalent

if

with

tion

600

ft/mm

equivalent

of

ft/mm

200

10

velocity

depths

Answer

for the

ibm/gal

the

ID

ft/s

fluid

Rotational

120

after

just

the

control

well

equivalent

ft

6000

of

li-in

properties

Minimum

the

18.9

Calculate joint

to

Density Ibm/gal

ing

Answer

pressure schedule

method of

13000

for

control

2.5

efficiency

Surface

of

seat

18

Rods

Mud

Compute

6.5

in

Stroke

method of well

drillpipe

wait-and-weight

Liner in

pressure schedule

drillpipe

circulate-and-weight

the

transport

correlation

ratio

using

the

Walker

APPLIED

188

4.58

ting

mud

the

Compute

density

gal/mm

bit

of

density

of

size

in

9.875

9.11

the

drill

600

of

rock

bulk

920

10.7

28 29 30

Stokes

Ibm/gal

CE

Muds

Trans

References

32

E.J and

Wiley

Standing

Principles Inc

MB

and

N.L

Carr

DL

Katz

Gases

John

Fluids

of

Density

Gases

Natural

and

under

Better

Viscosity

World

Problems

Oil

Jan

Part

Prevents

1980

201

101

Tubing

Buckling

Feb

Part

1980

35

JR

and

Rate

Drilling

WJ

Bielstein

and

Pump

Nozzle

and

Design

Drill

Operations

No

NA

and Prod Prw

API

AIME

Flow ASME

Paper

thesis

Slurry

AG

Frednckson

and

Which

cumstances

Rough

16

City

Trans

Blasius

Das

19

Dec

1967

21

Drill and

Crossflow

Under

Useful

on

AIME

Oil

for

Carrying

AIME

Trans

AT

Bourgoyne Fluids

Drilling

SPE

paper

the

Determining

Conference

Technical

of Improved

Development

for

Procedures

Field

7497

and

Carrying

presented

Exhibition

at

of

coefficients

gas-cut

mud

equation

area

capacity

and

Co

base

of

of

Rate

Bit

Tech

the

Pet

Pressure

Computer Makes and Gas Aug

1961

Eng Non-

of

and

Tech

AIME

Bit or

Shear

in

Dec

Surge

of

clinging

constant

1965

240

Trans

Pressure

weight

or

ponents

NHe

Hcdstrom

also

consistency

also

moment

NRe

Reynolds

NRec

WV

critical

moles

of

also

segments

1973

of

number

gas dispersed

gal

of

in

liquid

by

Pipe

AIME

Calculations

heat

power

rate

energy

per

unit

radius

hydraulic

radius

universal

gas constant

mass

com

flow

number Reynolds

hydraulic flow

of

index

pressure Force

or

gas

number

Properties

Produced

inertia

mass

volume

Aug

595605

force

gravity

usoment

behavior

Jet

Force

Removal

Trig

of

number of moles

Drilling

Impact

tension

also

ratio weight

length

of

Operation

of Chip

l964 96

q/q

index

130-147

of Fluid

Surges

annulus

force

acceleration

in

255

June

transport

of

Plastic

Pet

Flow

Pet

in

in

238-247

Trans

Soc

flow

volume

gain

2129

Optimum

Effect

Study

fractional

stability

Gas

1959

1958

and

unit

per

volume

specific

Bingham

Soc

Energy

Bits

energy

molecular

API

logarithm

fractional

F5

Temperature

Oct

1-lorsepower

of

natural

energy

FT

189

Kinetic

Studies

of

internal

New

Interpretation

Turbulent

219

coefficient

discharge

unit

the

Houston

Shall

234

Wetlbore Pet

and

Flow

Design

Hydraulics_A

Trans

F.J

Muds

Particular

Solution

Determining

Jet

Drilling

Jet

222 Schuh

AIME

J.A

of

893900

diameter

l938..39

Large

Plates

Prac

Hydraulic

Full-Size

Movement

Mechanics

acceleration

240

AIME 1960

Three-Cone

Dnlling

Burkhardt

Rock

Nomenclature

Chan

Reibungsvorgiingen

1959 for

W.C

Goins

Microhit

Hydraulics

Sutko

Design 1975

July

Cir

the

Smooth

Book

Tech

the

AB

Velocities

Trans

JR

233-235

26

Pet

AIME

and Prod

Trans

RH

Under

25

1-4

28187

of Design

Parallel

Trans

Maximum

for

McLean

Eckel

Between

Method

Kendal

and

24

Oct

and

Annual

131

On

Metzner

Techniques

1443-48 23

SPE

An

in

Parallel

the

with

bei

1913

DR

Flow

with

Pipes

Practical

207

Mechanics

Pratt

and

Velocity

Terh

Operations

Drilling

and

516

TM

Mayes

Rotary

Drilling

force

London

Pipelines

Forseh

342-46

WA

in

R.V

and

Systems AIChE

Programs

22

1978

174

McGraw-Hill

AIME 1956

JW

Speer

Jet

of

Capacity

Eng

of Water in

Between

Engs.

Civil

Smith

Wells

Pipes and

Newtonian

20

Flow Region

Treatment

and

D.G

Dodge

on

1971

kinetic

l883

Aehnlichkeitsgesetz

Fracture

in

Publishing

May

and

of

Motion

the

of Resistance

London

Mechanics

B.C The

Slumes

Pet

depth

md

Investigation

Laws

Inst

VDL

R.W

Hanks

and

and

347

Whether

Turbulent

Gradients

Hydraulic

18

K.J

Sample

Publications

Non-Newtonian

the

Soc

for

Equations

Crittendon

Dover

RB

Transition

the

Flssigkeiten 17

and

Laws V.L Fluid 1962 M.H and

Collender Flow

34

Dur

Rouge

Transport

Bird

Pipe

Streeter

York 15

Baton

Suspension

Experimental

Royal

to

56

Pet

Trans

Pressure Losses

on

edition

sixth

Determine

CF

Colebrook Reference

14

1074-SO

State

Chem 1958

or Sinuous

Direct

nels Trans 13

1967

Temperature

Louisiana

and

An

Reynolds

Be

RE

for

Velocity

Conference

Fifth

TX Jan

138

1957

nuli md andEng 12

SPE

1945

City

W.M

HA

WahI

Annul

Petroleum

Manual

Practice.s

Drilling

S.F Annular

Cd

York

and

Vertical

compressibility 01

Hydrodynamics

Laird

EL

Haderi

of Water-Base

Properties

Aug

Dnlling

12951302

Proc

ab

Flow

Tech

Eftect

MS

Dnlling

hem II

Pet

H.B The

1972 Lamb New

Annular

ot

1974

240

Butts ing

in

High-Temperature

Fluids

Drilling

Losses

1963

MR

Annis

10

Pnetion

63-sVA-lt

1851

1845 Capacity

111120

Full-Scale

in

on

Efidet

Its

t951 28-46 Dodge

G.M

for

45162

1974

Carrying

192

of

AIME 1954

Trans

Understanding

Pressures

259

Burrows

Pressure

Method

Soc

Phil

GH

in

Improved Circulaling

Oct

Eng

Cambridge

Myers

Chien

Walker

Pet

Bruce

1974

P.L

Tulsa

Laboratory

W.C

Eckel

33

Pressures and

Transport

Capacity

264-272

Gons

Nov

Moore

RE An

Surge

AIME 1951

Cutting

Austin

140149

146

Kobayashi

Hydrocarbon

Resersoir

1957

London

Sons

AIME 1942

Trans

Petroleum

of

and

T.R

Siffcrman

Co

Clark

and

Well Soc G.G Trans

Williams

Tech 31

and

Swab

Calculating

Drill

Burcik

J.E

Fontenot

Drilling

rate

and

Answers

g/cm3

2.2

flow

27

mud

the

if

and

Ibm/gal

is

cut

for the

5%

and

Assume

ft/hr

100

is

well

the

entering

rate

ing

90 50

of

ratios

transport

annulus

in the

density

ENGINEERING

DRILLING

HYDRAULICS

DRILLING

189

time dpf time of

kick

or

flowing

circulating

drillpipe

detection also

effective also

temperature

torque

fluid

equivalent

also

fraction

also

hydrostatic

velocity

gas

volume

hook

volume

specific

jet

weight total

xy

per

foot

kick also

weight

work

mud

coordinates

spatial

nozzle gas deviation

also

nominal

factor

pump

d1/d2

steel

also

solid

also

surface

of shear

rate dial

reading

equipment

of

rotational

viscometer si

slip

viscosity transport

apparent plastic

viscosity

wave

pressure

wave

viscosity

average density radial

stress

axial

yield

Metric

Conversion Factors

stress

shear gel

SI

stress

tangential

bbl

stress

bbl/ft

strength

angular

ft/bbl

1.9

velocity

annular

also

3.785412

in

2.54

ft

4.788

026

Ibm

4.535

924

ibm/cu

acceleration

bo

ft

Ibm/ft

bit

Ibm/gal

bouyancy

lbm/sq

casing

134

gal

lbf/sq locations

17

ft

psi

1.601

846

1.488

164

1.198

264

4.882

428

6.894

757

2.262

059

9.290

304

parasitic

dc dca dp

dpa

psi/ft drill

collars

sq drill

collar

annulus

ft

sq in

6.451

drillpipe

annulus

opposite

drilipipe

Conversior

factor

is

exact

E0l EOl

m3 m3/m

E03 E02

Pas mN/cm

E0l

3M48

Subscripts

3.

119

1.0 ft

porosity

873

1.0

cp

dyne/cm2

point

1.589 5.216

E00 E03 E00 E02 E0l 01

E00 E02 E00 E00 E0l E02 E00

rn/rn3

m3 cm kPa kg

kg/m3 kg/rn kg/rn3

kg/m2 kPa

kPa/m

m2 cm2

Chapter

Rotary

The the

purpose

ojthis chapter

selection

and

operation

are

discussions

the

chapter

available

criteria

situation

given bits

of

process

use of used

the

by

best

bits

tant

the

he

so

the

for

can

various

different

learn

to

basic

tool

It

the

elements

and

junk

en of

differences

Bit Types

Rotary

Available

drilling

bits

as

either

their

design

drag

bits

consist

with

the

body

usually

drag

of of

fixed

the

hit

drillstring

The use of

this

troduction

of

tury

the

Rolling

ing

the

the

cone

two-cone

the

hit

rolling

is

and

rotate

type of

drilling

bit

cutter

rotate the

was

hits

are

with

unit

back in

to

the

of

introduced

the

of

5.1.1

and

Drag design

shape

location

tersects that

the

tend

blades

of

hit

and

plowing like

drag be

can

the

of

Diamond

rapid

bits

all

angle

have

formations stick

so

jet

that

blade

the

to

bits

with

displaced

the

This

drilling

Because

harder rocks

drag

been

soft

of

in

it

effectiveness

placing

in

rapidly shape

which

may

surface of

dulling

wear in

bit

the at

in

their

formations

largely

almost

in

types

by

upper

uniformly formations

of

rate

cuttings

reduce

reduced the

the

bot

fishtail

decreases

hole Also

the

and

bit

the

the

junk the

as in

the

by changing

reducing

of

gummy

elements

ting

and

on

problems in

reduced

types

rate

drilling

gummy

be

impinges

cleaning

he

hottoin

to

of

the

Removing

As

more abrasive

would

which

such

bit

of

piece

time

elements other

to

cutter

cutter

solid

trips to

rig

formations

and

element

cutter

hole

the

to additional

cutter

relative

can

problem

of

not

is

bit

rolling

breakage

bit

considerable

steel

best

the

for

re

especially

and

bit

steel

cut

other

bit

by

areas best

perform

formations

that

relative

have

to

plastic

other

hit

mode

types

of

in

failure

Bits for features

of of

with

hits

nonbrittle

The

of

of

is

space

both

into

bits

cutting

which

parts

This

made from one

lead

can

loss

rapidly

1909

in

bottom

bit

harder and

fluid

hole

the

creases

problem

axis

the

chance

rolling

where

sizes

needed

be

less

in

rolling

strength

can

over

hits

any

hole

PCD

diamond

surfaces

bearings bits

become

in

contain

small

unconsolidated

soft

the

cen

19th

the

about

bottom

All

integral

more cones

or

which at

as

process

two

rotated

that

dates

bit

to

according cutter

rolling

blades

cutter

have

bits

elements

cutting as

rotary

cutter

classified

are

bearing

is

perform

the

hits or

not have

designing

thus

Drag bit

This

5.1

do

the

Fig 5.1 diamond

cutters

of drag

clean

previous

tom and

steel

polyciystalline

advantage

Also since drag

from

fundamentals

fully

for

leave

impor

and

the

in

available

the

available

bits

important

with

bits

they

strong

most

variety

is

that

is

quire

there

of the

includes

Fig 5.2 Fig 5.3 An

steel

situations

the

understand

the

large

operations

drilling

requires

of

bit

bits

dull

speed

selection

extremely

bits

speed

most

one

is

of

in

for

drilling

the

to

types

bit

rotary

the

is

and

An

engineer

best

ground

conditions

faces

rotary

drilling

design

among

he

that

during

bit

engineer

manufactured

are

for

the

operating

problems

countered

bit

hit

and

the

in

hit

for evaluating

wear and

weight

Indeed

drilling

and

bit

basic

bits

drilling

the

methods

hole

drilling

Included

various

of

selecting

hit

of

student

the

bits

drilling

bit

affecting

optimization

The

of

for

introduce

to

is

standard

factors

and

of

Drilling Bits

the

the

cutting cuttings

farmers

of

the

cutting

water

bit

blades

or

courses

elements from

plow

drag

the

cuts

and

Drag

include stones the

bits

bottom furrow

of in

number

the the

size

metallurgy drill

the the

by

and the

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ROTARY

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Two-blade

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ROTARY

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COLLECTOR Secondary FEEDER

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5.48Diamond

BREAKER

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APPLIED

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NEARLY

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The common bearing assemblies used for rolling cutter are shown in Fig 5.10 The standard or most inex pensive shown in Fig bearing assembly l0a consists termediate

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classification

system

several

Contractors system

from

for

various

adopted

is

the

code

three-digit

bit

bit

of

are

designs

Intl

standard

approved

manufacturers.3

The

bit

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identifying

the

during

variety

IADC

Classification of

manufacturers

Journal special

Standard

5.1.4

the

by eliminating one of the com becomes available space

extremely

Silver

bits

are

additional

require

and

metallurgy

CENE

bearing

lOd

Fig

bits

the journal bearing

advantage

Also

advanced

most

bearings with

the rollers

ponents

the

bearing

which

area through

contact

with

bits

are

type bearing

for

cutter

rolling

tripping

Rolling

this

of

drilling

wear

assembly

NO

STEEL TOOTH

5.6Parts

Fig

fluid

CONE

Co

Tool

Hughes

NO

the

D5 soft

in

the

number

bit are

is

bit

or

for

medium-soft

fonnation

letter

diamond

reserved

scheme

classification

The

categories

PCD

drag

diamond

medium

is

precedes

bits

bit

called

the

Series

and

PCD

first

Dl bits

medium-hard

and

Series

D7

respectively

ROTARY

DRILLING

BITS

197

DIRECTION

OF

ROTATION

OFFSET DISTANCE

Fig

5.7Cone

promotes cone

offset

slippage

during

rotation

Hard

FcIng

Chipping

Wear New Toot

Case

SELF SHARPENING

WEAR

DUE

TO

Fig

Gage Compact

HARD

characteristics

Ovoid

Wedge

Crested

SELF SHARPENING

FACING

5.5Wear

of

milled-tooth

5.9Example

tungsten

insert

cutters

used

Sharp Chisel

in

HARDENING

9O

itluit

carbide

CASE

bits

hul

Chisel

Fig

DUE TO

Conical

Ogive

Scoop

Chisel

Hardened

rolling

cutter

bits

Chisel

APPLIED

198

DRILLING

NGlNEERING

PRESSURE AREAS E-

COMPENSATOR PLUG

COMPENSATOR GREASE RESERVOIR CONNECTING HOLE

SEAL

KD Roller

Sealed

design

bearing

roller

EARfNG

design

bearing

AREA

PRESSURE

JOURNiL

er inA

AR

Cone iioroi Ra

ER

55L

RACE

Journ

NTERGA

BALLS CONE RHEP BAL RACE ANGEl

Bearirci

Pr

HARD FACNG BUSHiNG

Gas-cooled natural

bearing

design

for

D9

bits

core

are in

bits

in

categories sert

bits

reserved

the

the

and

and

reserved

arc

or

Journal

categories

for

use with

categories

milled

formation for

are

extremely

Series

respectively

special

hard and

and

PCD

formation for

such

is

The

for

formation the

is

digit

PCD

hardness

feature

called

the

drag bits

hardest formation

The

design

bearing

type

Types

subclassification

within

numbers

each

are

number

Type

through from

is

the

softest

to

differently

profile

type The

and

are

PCD

two

recover

central

portion

length

of

PCD

oil-base

selected

standard

feature

by feature

core-cutting of formation

the

drag

and

PCD

core-cutting

borehole

the

bit

features

downhole-

motor

type and

No bit

are short-

profile

profile

remaining

drag-type

drag-type

long-taper

type

features

special

diamond

bits and

nontaper

sidetrack

There

to

category

interpreted

for

dcsigriate

cutter

described

being

bit

for

PCD

and

diamond

of

type

defined

rolling

profile

taper

bits

general are

diamond

step-type

ejector

second

the

standard

type

sal bit

reserved

on

numbers

bits and Eight

cutter

rolling

bits

drag

hard

reserved

for

depending Feature

in

univer

as

used

assemblies

bearing

and

hard

and

Series

medium hard

soft

formation future

air

bits

mediummedium

soft

respectively

in

diamond corc

for

soft-

the

Series

categories tooth

with

ling

5.10Common

Fig

through

dri

gas

is

core-

reserved

manufacturer

numbers bits These sample

The two

for

diamond

bits are

cored features

used

from arc

the

ROTARY

DRILLING

BITS

199

TABLE 5.1IADC

DIAMOND CHART FOR

CLASSIFICATION

AND FOUR

DRILL

PCD

BIT

MANUFACTURERS

MANUFACTURER AMERICAN

COLDSET

STEP

1.4

DAM

ESUrI305IGN_FEATURES

lUNG NON

Wl1OL.E

CORE

SIDE

Dli

011.440

BASE

TAPER

ryri

SERIES

TAPER

OTOR

REACTOR

NUMBER

IC

__._

STRJTACUT

sTR.ATACuT

SHARKTOCTI-1

Dl

SOFT

AU

ifTE

A4ADLO

ici iiIiEE

STRATA

UT

SIRATACUT EPUADI

TRIGG._.____

---

D2

MEDIUM

AGE

SRARKTOOTR

RUILR

US

CRUSIB

EINAP.XTOCRH

50 FT STRATU.CUI

TOnGS

STRATACUT

RMADILLO

TBYY

US

D3

MEDIUM

SERCU

TRIGG

04

MEDIUM

FRE

TOrY

MOLE

--

liAr-iD

IF

D5

HARD

t-o--

C0BE-

---11UILDR

CORE

CRUS

ER

--

.-

CRU

L1

I8SET

DRILL

MANUFACTURER CHRISTENSEN BIT IA SERIES

FORMATION

STEP

LONG

SNORT

TYPE

TAPER

TAPER

DESIGN

FEA

URES

DDWNROLI

PEON

TAPER

SIDE

MOTDR

CORE

OIL

TRACK

BASE

EJECTOR

DIRER

NUMB

o-ko

YUCHsT

160-38

1417-34

16034

110115

Rocku

Roskut26

10-26

MD-262

140-SIP

017-31

MD-34

140-262

Rsckxt

77

RkUt

TI

27

.s1DiR__

Dl

SOFT

140-503

MTI8P

MD-43cr

10-38

LiLL_ 02

MEDIUM SOFT

ROCUUt

B5Th

00-26

26

ROLkUt

26

MD-43ST

Rcckt

MEDIUM

ROCKUT

TT

26

T1TY

MD-SI 116262

--_.iii

04

MEDIUM HARD

rr-54P.

RIU3171L___

140-262

.t1t2thL_

MD-

05

HARD

M1DhJJ10I-..

41

TTTF

1rr54P

160-23

160-24 163-210

conventional

As

type for

rolling teeth

are

bits

cutter

for

previous

eight

gauge

and

bit

hit

bit

or

No

numbers

regular extra

insert

bearings

friction

reserved

is

manufacturer

numbers

feature

roller

sealed

the

feature

protection sealed

face-discharge

feature

by

standard

jet

and

type

case

selected

The standard

cutter

protection

Nos

the

features

special

There

core-barrel

in

160-240

bearing

for

are

rolling-

standard heel

for

gauge

combination and

of corn-

ol

Nos

designate Tables rently

bits 5.1

available

for

designed

No

bits

Contractors

diamond

bits

for 5.3

through by

surrimariZe

IADC bits

bits and

by

the to

drilling

many and

classification

from

Nos used

often

is

manufacturer

feature selected

directional

diamond core While

features

special

Feature

Drilling

respectively

The remaining

and

reserved

were

manufacturer

hit

T-shaped teeth

hination and

of

Intl

number

rolling-cuttci-

different

cur

the

Assn

of for

bits

manuthcturers

APPLIED

200

DOWDCO

MANUFACTURER

.TYPE

SERIES SUIIDIR

RFV-21

TAPER

RFv30

RFT-20

RF-21

ROT-fl

CH2O

CIW20

01125

RFV

RFV-21

0121

ITT3D RFT21

ROT-3D

D3

MEDIUM HARD

04

HARD

D5

ctr

ovoo

RFT-

ClIRE

oIl

SF0120 SF0121

30

501-3

RF-31

SIFT-fl

010-30

0113D

RFT-30

010-30

010-40

Rrv-31

010-31

IF-fl

SF1-li

01031

013f

TFV-41

501-40

.Q_

Sri-IC

CHIT-3D

511.1

RFvfl

RFv-SC

01-40

SIFTIl

RFV-50

0J3i

5U55 0151

SF0Si

00515

EJECTOR

RFV-20

01-20

TlVV21

21

SIDE

lIlACS

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CflR-20

SOFT

MEDIUM

15500

501-21

cssc

MEDIUM

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55051

ECArURES

DSSIGN

SIT 0515

ALEc

FUEMATIOS

ENGINEERING

DRILLING

RFV4.L....

SIFTSO

RST50

RFT51

.__

4D

SF0

._______

SF0150

0100

SF1Si

P.RSO

CF-SO

MANUFACTURER

K1

HYCALOG

NL

IT STEP

AD

TYPE

SERIES

FORMATION

10516

TAPIR

TAPER

Dl

TAPER

go

D2

SOFT

HARD

D5

MIIT

Some

of

in

Table

features

that

the

as

height the

and

class

5.4 and of

Fig

and

increases

Shown

capacities

for different

in

tooth

bit

204

9015

901CC

2O

ST

9015

9O1CE

730CC

ST

9015

971CC

73CC

204

ST

901S

971CE

7300

204

9015

901CC

73CC

204

iTyci

ST

73t

M1T

901

901

901T730

Mj.L903j30

1Ij_JjP

73

9017730

MiT

WM

WM

ST

.i__._

52

73CC

204

901

525

501

MIT

t1T

730

ST

9015

7300

204

525

501

MiT

9OtT

730

ST

901S

73CC

204

s25

501

9015

730T

731

525

not

are often

the

some

are

types and

are

classes

tooth the

Note

CNTR

the

offset

decreases case

tilT

971T73C

525

MIT

for

that

tooth

an

501

in

ST

9015

730CC

ST

901S

730CC

WEt

bearing

capacity

number

class

of

730

bit

teeth

This

at

is

is

higher

Rock

5.2

possible

for

possible

due

bit

the

with

bits

to

higher

shorter

the

length

numbers

class

To

operate

given

needs

tooth

mechanisms of rock

while

bearing increase

to

understand

wedging fluid

jet

sion

or

bit

as

twisting

removal

as

and

To some one

are

at

be

work

these

the

basic

including erosion

grinding

dominant

engineer

about

or crushing

extent

may

drilling

possible

that

percussion

While

the

properly

much

scraping

action

interrelated

Mechanisms

Failure

Note

hardening

relative

UiL_21.L730

501

204

various

classes

cone

ffTttYIT7t37j

525501

summarized by Estes.4 of

ST

97iT

studies

of

L1L.20.llJ00

MIT

exactly

useful

performance

the

...0aL

5.22_._.Qi 731

is

01

204

9.UJ.............L3I

hardfucing

12

9OlCt

ST

amount of

Fig

204

901S

130

number increases

teeth

204

901CC

01T

II

bit

901CC

9015

73

been

various

the

9015

ST

1151

features

design

amount of

number of

drilling

ST

QOl

scheme

types have

hit

design

in

main

the

rolling-cutter

Shown

hits

730 730

number

classification classification

204

S1T9C1

90173

the

204

901CC

73

901

same

901CC

901S

1151

.Q1.J.1 .U1_J3l

similar

grouping

OTHER

OIIECX._

9o17a

the

EJECTOR

901S

ST

901

901

equivalent

901T

73t

qQL...........Z.3i

given

901T

11517

1151

901

D4

MS1T

901

901

D3

MEDIUM HARD

SAM

MS1T -__________

IJJIL3ALIC

MEDIUM

CORE

OIL

SIDE

TRACE

5901051

TU000PAX

9Q........._

MEDIUM

0050515011

JtTP4x

SAJ3jS4T1T

SOFT

FEATURES

DESIGN

55051-

51

5513MB

Cl-SORT

and

mechanisms for

by tor

given

are bit

ROTARY

DRILUNG

BITS 201

TABLES 2_IADC D1AMOND CLASSIFICATION CHART FOR

MANUFACTURER

AMERICAN_COLDSET IA

OESIG

FEATUHES

05 COVEITIODS1

SERIES

SRMATI0N

AND PCD CORE BIT MANUFACTURERS

FOUR

RUMBIR

RELARSjn SIRATACORE

HEA

SO FT

ER

STAR

AEFO

MEDIUM LA

STAR

MANUFACTURER

EACFE_

STAR

FR

HARD

FE

D9

DOWDCO

DESIGN

FEATUREs

CcVENTJOlML SERIES FONUBTIOR

RAR5t

D40C1UJE

WDOIAX7F

OErrS000AX_7C

T02rI ID-3U

MS

SOFT

D7

IUWDCOPAX-c

RF

OliICIIIAX8l FD-30

MEDIUM

SIFtER

NUMBER

AIJR

D8

$OP

DowDcoPAx9r FIJ511

HARD

lAS

D9 ---v

MANUFACTURER

NL

HYCALOG

DE

IA

CORE

SERIES

FORMATION

FEATURE

GtE

CONVENTIONAL BARREL

101 DESCEIA13E

NUMBER

GecPax

GeoPax CSFD

SOFT

07 CSFD

---t MEDIUM

D8 CMH

_______

HARD

CH

D9

----CUH

CUHR

CUH

CUHT

DTEIER

APPLIED

202

TABLE 5.3IADC CHART

HUGHES

ENGINEERING

ROLLING-CUTTER BIT FOR FOUR MANUFACTURERS

CLASSIFICATION

MANUFACTUVEEPE

DAILLNG

CO

TOOL

FORMATIONS

FEATURES

CO

CO

SEAlED

SANDAHD

LU

POlISH

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HELTER

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101

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fORMATIONS HIGH

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sioJ

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WITH

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---------------_ HH55

STRENGTH

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MANUFACTURER

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FORMATIONS

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ROlLER ERG

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101

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FORMATIONS

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151

SEMI

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ABRASIVE

ABRASIVE

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FPAEG

Y3EFoA

-__________

FORMATIOPRA

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FORMATIONS

WITH

LOW

COMPRFESEVE

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AND ITS

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TO

MHDIUM

FORMATIONS LOW

__

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._

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WITH

552

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2$L___

FHPSMP62 $62

_____

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_______

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564 HARD END

SEMI-AORHSITAE

72

ABRASIVE

FORMATIONS

________

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273

Y73

_______

HPH HPFH

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63 FPW4

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ROTARY

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BITS

MANUFACTURER

203

SECURITY

Dlv

FORMATIONS

FEATURES

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EM

LU

SERIES

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HIS

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411

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MEDIUM

TO

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M44L

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ANDSURSSIVE EDITMATIDNS --

EUTRIMEIHHARG ABRASIVE

RUAMASIOGS

9JA

F9

At

204

APPLIED

ENGINEERING

DRILLING

ID

5.11Tooth

Fig

variations

design

between

types

bit

Fig 5.12Relative ferent

more than

design this

discussion be

will

types cutter

mechanism

one

the

only

two

is

usually

present

rotary

drilling

basic

discussedi.e

the

drag

and

hit

the

The depth of

In

and

bit

is

radius

rolling

bits

to

the

terms of

in

function 5.2.1

Failure

Mechanisms

of

and

Drag

bits

arc

mechanism ing

and

dragging slowly

and

tribute

to

hole drag

torque

erties

applied

cuttings to

of

the

to

the

turn

sheared of

the

of

action center

bit

they

also

may con

is

the

tooth

as

bit and

The of

of

tooth

dependent

causing

Fig

bottom

too

two

these

or

wedge

at

an

on

the

the

rake

slight

wedging may

not

the

angle

mechanism be

hole

bit

from the

necessary

bottom

tooth

loses

when

Class

1i 12 13 14 21 22 23

Formation

can

very

soft

digging

hard-faced

Description

the

bit

of is

as

degrees

tip

to

side

to

medium

hard-faced

side

to

medium-hard

case

hardened

hard

case

hardened

case

hardened

hard

5.2

soft

64

53

medium-soft

65

to

61 62

medium

shales

65

to

medium

limes

60

to

71 72

medium-hard

80

to

medium

60

to

hard

chert

90conical

very

hard

120

long

80 80 70 90 70

blunt

to

circumferential

chisel

long

sharp

to

chisel

to

medium

chisel

to

medium

projectile

to

short short

conical

chisel projectile

or hemispherical or hemispherical

too

the

rake

and

ratio

an

is

effi rake

downward

operated

the

great

too deep

positive

because

The

fast

help promote

hard-faced

soft

very

insert

Tooth

thus

wear be

although

strength

from

and

weight-to-torque

Estes4

Type

to

not

Offset

Tungsten-carbide

relation

wedge

chip

and

chatter

bit

whenever

rotary

angle

The

the

taking

should

angle

the

prevents

while

jump and

to

prevent

cient

ly

prop

to

great

slope of

initial

bit

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angle

hole bottom

clearance

stalling

the

clearance

the

however

result

of applying

bottom

of

after

milled-tooth

This

5.1

TABLE 5.4TOOTH DESIGN CHARACTERSTtCS FOR ROLLING.CUTTER BITS

Steal-cutter

is

revolution

per

hole

the

increased

Type

the

expressed

cv

dragging

horizontal

result the

in

The

the

rock

Bit

thrust

and

The angle

angle penetration

center of

rock

often

is

cut

of

plane

the

drill

of

portion

shear plane

in

that

to

the

result

thrust

off

thrust

as

by

cutter

the

of

L1 tan

are

that

wedging action failure is shown

to

defined

the

cutting

desired from

of

the

by

strength

The depth

radius

wedg

they

the

applied

tooth

plane

plane

grinding

cutting

is

the

wedging by

when

is

dif

rr

the

weight

the

to

the are

to

force

necessary defines

from

by

drilling

It

twisting

prior

collar

kept

and

illustrating

just

drill

primarily be

quickly

scraping

removal

vertical

is

so

quickly

rock

tooth

bit

force

angle

dull

dull

of applying

The

not

schematic

5.13

forces

bits

thus

drill

could

drag

would

they

to

designed If

he

between

capacity

controlled

on

bottom

the

Bits

can

Drag

the

is

cut

based cut

of

bearing

types.4

the

selected

and

offset bit

proper angle

is

ROTARY

DRILLING

BITS

205

Ui

\TURNING

RAKE

BACK

FORCE

CUTTING

F\PSV

OR0E-

BOTTOM CUTTING

Fig

Diamond

individual

may the this

not

rock he

situation

eementaceous by

into

grains

much

diamonds

broken

bits

drag

smal penetration

in

smaller

The is

are the

drilling

primarily material

the

to

designed

formation the

action

grinding

holding

such

depth of

the

with

drill

as

the

sandstone

of penetration

diamond drag action

in

individual

of

bits

\vhich

in

the

grains

diamonds

action

is

of

drag

Reck

very

The diameter on

formation

than

5.13Wedging

bit

cutter

mechanics in

simple

compression

an

attempt

One such

failure

The Mohr

sum

should of

the

frictional

occur

to

the

when

states the

resistance

of

the

rotary

slip

drilling is

the

that

yielding

stress

of

material

planes

or

5.14Mohs

circle

representation

ot

Mohr

failure

criterion

in

process theory

or frac

exceeds

fracture

COMPRESSION

Fig

Mohr

shear the

failure

measured

strength

used

often

criterion

several

applied

rock

relate

criterion

cohesive resistance

to

tests

of

turing

have

experts

criteria

failure

ANGLE

and

the the

plane

206

APPLIED

-NORMAL FAILURE

DRILLING

ENGINEERING

TO

PLANE

REFERENCE

ANGLE FA

LURE

PLANE

A3

a3

A3

Sin dA1

Cos

-r

tan

-r

COMPRESSION or

ton

Fig

515Mohrs normal

circle

and

graphical parallel

to

analysis failure

plane

reference

and

rock

specimen

construction

reference of

Mohrs

circle

free-body

stress

element

force

balance

ROTARY

DRILLING

The Mohr

BITS

criterion

TCa

207

stated

is

mathematically

by

tan

BOREHOLE

5.2

FLUID PRESSURE

where

WINDOW shear

stress

cohesive normal

stress

of

angle

As shown is

pression

internal

Mohrs

the

material

failure

and

plane

FORMATION

this

is

at

the

of

equation

drawn

for

different

line

least

at

of

levels

PRESSURE

that

confining Fig 5.lGApparatus

To understand rock

OVERBURDEN

com

two

pressure

when

confining

use of

the to

sample

5.15

FLUID

PRESSURE

friction

circles

made

tests

of the

at

Fig 5.14

in

to

tangent

failure

at

resistance

along

fail

loaded

Mohr

the

criterion

in

force

compressive

The compressive

pressure

shown

as

plane

under

under

consider

used sinlulated

tor

of

study

borehole

tooth

bit

penetration

conditions

Fig

and

stress

is

given

by

Expressing

all

unit

terms of

in

areas

dA0 and simplifying

yields

The

stress

confining

is

given

Note

examine

small

the

bisecting

sample

in

forces

present along

free-body of

the

elements

failure

plane

noimal-to

the-failure

also

to

equal

of

direction

and

the the

normal

the

on

element

the

Fig 5.15b

given

element

any in

is

Furthermore we the

failure

shown is

in

angle

stress

must

stress

the

the It

plane

and

Both

shear

stress

to

the

balance

of

plane

the

and

Summing

forces

normal

fracture

varies

between

fra

can

used

30

approximately

to

shear

predict

the

and

the

plane

an angle

Assuming

bit

drag

be

the

of inter

implies

unit unit

area

along

dA

areas

the

and

fracture

dA

al

plane

dA

is

related

of

cost

and

the

of

in the

force

balance

Suirming

forces

7-dA-a1dA1

parallel

by

Gray

pressure

psi

along

plane

direction

the

of

the

criterion shear

undera to

2000-psi

which

makes

determine and

the the

an

loading of

angle

load

compressional

strength

confining

compressional

angle

Using of

cohesive

27 the

internal

resistance

Solution

The angles

the

of

angle

internal

and friction

2c/ is

must

sum

given

by

to

90

Thus

9022736 03

to

experimentally

material

the

01 sin2a3 cos2

03 aI

subjected

equation

gives

sample

when

failure

friction

dAdA0 sin substitutions

verified

atmospheric

fails

10000

Mohr

these

at

rock

Exanple5.I

with

Making

made

to

by

pressure

cL43dA0

has been

of

in tests

sin

andAna3dA3cosa1dA1

an

rocks

most

30

et

the

the

that

90

to

gives

This value

The

for

also

sum

must

or

Fig

plane

and

friction

graphically

l5d Note

9030

03 5.15c

represented

Fig

40 criterion

of

are in

friction

angle

thrust

friction

5.3b

failure

is

failure

to

Mohr

orientation

plane

to

5.3b

shown

internal

30

the

The

between

present

of

about

the

and

internal

characteristic

angle

be

of

angle

from

using

horizontal

the

The

state

examine

failure

Eqs 53a Mohrs circle

angle

nal

between

principal

plane

stress

lsb The

Fig

and

plane

the

can

at

plane

defined by

vertical

cos4

sin2q

that

the

by

we

sin

a3

by

03

If

03

01

irr2

the

eos2 fracture

cosa3dA3sinf

5.3a

plane

gives

The

shear

strength

is

computed

using

follows

03

sin2

l00002000 sin543236

Eq

5.3b

as

APPLIED

208

BIT

TOOTH PRESS

The

stress

Eq

5.3a

normal

the

to

fracture

3a1 a7 cos2 l00002000

IMPACT

Eq

5.2

resistance

can

tan

cutter

for

angle

of

or crushing

bit

tions

POST-FRACTURE

BRITTLE

considerable

1PSEUDOPLASTIC

PRESSURE

\HIGH

PRESSURE

conducted on the

mode with

working bit

economic

tooth

tions

This

pressure

and

x-y

some

The

crater ferential

mechanism

beneath

bit

tooth

from

of

Maurer

as

As

is

rock

the

on

solid

rock

the

...

linear

pro

poten curves

rock while

crater

ejected for

in

this

low

at

in

Fig

bit

high values

and

of

in

from

completely low

of

the

deformed

both

figure

to the

values

beneath

rock

described

is

depended between

At

pressure

not

to

then

the

high dif

17

The se

described

is

is

shear

shear

tooth

rock

the

formed

tooth

These surface

of

by

the

the

solid

of

the

the finely

As

tooth

forces

shear rock

propagate

intersect

constant

exceeds

material

lateral

until

fractures

which

the

the

high

wedge

it

wedge

beneath

exerts the

strength

the until

and

increases

and

surrounding

the

bit

increases

tooth

of

the

fractures

maximum

and

differential

crushed

shown

applied

compresses rock

exceeds

was

strength

powdered

wedge

to

piston

those

to

follows

load

force

the the

pressure

events

pressure beneath crushing

static

displacement

crushed

mechanism

crater

fluid

quence

pore the

pressure

manner and

plastic

in

varied

with

mechanism

crater

pressure

rock

the

ejected

differential

EJECTION

the

the

pressure

was

tooth

that

on

and

pore

oscilloscope

found

differential

rock

be

similar

gauges

to

prior

pressure

force

studied

condi

used

air-actuated

an

impacts Strain

16

to

into

Maurer

borehole

equipped

of

is

tests

impacting

Fig

pressure

obtain

to

plotting

extent

borehole

used

in

those

was

used

force

drilling

were

Maurer

WEDGE

which

in rotary

an

confining apparatus

constant

tiometer on

rock

The

drill

insight

tooth

bit

borehole

the

and

tooth

simulated

unlike

allowed

device

simulate duced

under

apparatus

work

loading

shown

apparatus

low

experimental

single

the

Since

forma

mechanism

considerable

beneath

basic

present

bits

brittle

be

to

Basic

provided

offset

the

percussion

cutter

percussion

instrumented

the

hard

in

tend

rates the

failure

the

Maurers

EJECTION

I-

of

use

interest

have

penetration

dependently

Ui

an

sample

basic

high

of

all

mechanism

rolling

for

designed

be

to

with

rock

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cone

large

predominant

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Cutter

Rolling with

employ removal However the

is

psi

formations

rock

are

which

in

costs

ing

of

Series

types

585

designed

soft

action

IADC

for the these

bits

drilling

mechanisms

tan36

Mechanism

Failure

Rolling

FRACTURE

Fig 5.17Crater

computed by rearranging

FORMATION

5.2.2

SECOND

be

psi

WEDGE

32363.649

LOW

3649

follows

as

Ta WEDGE

/710000

2000 cos54 The cohesive

CRUSHED

computed using

is

plane

follows

as

D..b ROCK

TOOTH

ENGINEERING

DRILLING

in

on

the the

stress

and

the

along

direction

of

ROTARY

DRILLING

BITS

209

0000

8000

In -J

Ui

6000

4000

F-

2000

.04

.08

TOOTH force

Fig 5.18Typical

threshold

value

region

above

broken

rock

tings

formed

from

the

until

be

repeated

rock

As

the

FG

This

and

tion

in

craters

of

in

mudcake

with

pressure

differential

pore

with bit

formed

made

were

although

bits

with

observed is

shown

at

and

large

offset

parison

of

shown

with

craters

19

no

4000 is

was

air

as

in

single

in

the

is

offset bit-tooth

sequence

lbf

of

were

left

The

and

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craters

lbf

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bottomhole

the

and

offset

and

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evident

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action

dragging

from

bottomhole

the

con

action

alter

cone

and

com

is

generated

patterns

with

bit

with

is

wedging

Fig 5.21

in

and

designed

formations

simple crushing

Shown

present

Final

rock

the

considerable

drags

rock

used Since each

is

offset

the

the

diminishes

bits

plastic

than

of

explosive

Photographs

the

to

cutter

an

bit

by

The

offset

the

offset

high of

pattern

the

bit

for

teeth

5000

The

the

failure too

impact

at

fluid

for

rolling

different

from

experiments

photographs

in

the

Figs

The

performance

of

interval

Eq

Chap amount

no tion

used

the

drill

to

formations be

logs

and

mud

initial

made on

the

characteristics

with

correlated

can

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by

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for

formula

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on in

per

Since

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the

must

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comparisons

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given to

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same formations

drilled

well

The

bits

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bits

more than once

of hole

between

available drilling

cost-per-foot

1.16 can

of arithmetic

best best

be determined

valid

most

various

The

drilled

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can

composition

error

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the

cement

of

selection

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like

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in

of

at

the

psi

formation

circulating

and Evaluation

Bit Selection

Unfortunately

unit

material

drilling

5.3

the

removed easily

bits

of

the

characteristic

not

not

from

fluid

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mechanisms

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force

soft

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buildup

pressure

two

full-scale

with

on

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that

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low

rolling

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curves

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of

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into

discharge

particle

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in in

ejected

further

to

In

transmitted

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proceeds

be

starts

Photograph

5.20b

Fig

sinks

10

has been In

crater to

tooth

forward

rolls

cone

the

force

in

the

tooth

for

action

equalizing

2200

The

and

weaker than

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craters

easily

of

the

atmospheric

1600

movies8

verified

two

3500

the

conditions

mospheric

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twisting

in

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the

rock

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High-speed

This

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The

the

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Photograph tooth

as

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the

as

through

is

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Chips

pressures

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manner

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made

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ly

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pressure

shown

is

process

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single-tooth

in

Photograph

the rock

threshold

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and

in

Starting to

apply pressure

in

Fig was loaded to pro of Rush Springs sandstone The

sample

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entering

have

force

pressure2

carbide

tungsten

failure

sample

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forward

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manner

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formed

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5-mm

right

the

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of

5.20b

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Examples values

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of

of

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to

the rock

5.18

Fig

duce

to

5.20a

the

easily

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parallel

Typical

values

increasing

the

5.19Example

Photograph

cut

the

the

forces

of

in

in

ejected

and

Fig

the

zone

differential

appearance

formed

craters

pseudoplastic for

the

above

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crater

increased

is

are

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at

threshold

pressure

frictional

planes

gives

the

of

Co

Tool

Hughes

of

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occurs

then

At high

tooth

the

rock

ejection

prevent

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FG

fracture

along

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The

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Courtesy

Pf

called

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The the

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the

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downward

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on

At low in the

IN

zXppbh

criteria

the

subsequent

the

reaches

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force

the

failure

beneath

begins

As

force

Mohr

the

by

fracturing

displacement

.20

.16

PENETRATION

mud pressure7

differential

predicted

.12

bits

wells

previous

The

nearby

progress using well

records of

bit

of what drilling

type is

in

known cost

in

wildcat about an

area can

be

the formation

area

The

terms

210

APPLIED

used

usually tion

by

of

drillability

formation pressive

to

important

with

depth

bit

there

are

crease

It

of

is

the

rock

wear when

will

the

of

listing

types

The

order

of

bit

formation the

used

to

for

the

milled

Although tends

to

Table

5.5

various

drill

listed

are

types

decreasing

of

in

are

decrease

of

teeth

Shown

decreases

often

types

factors to

abrasiveness

the

the

com

the

formation

the

drilling

drillability

other tends

the

rapidly

some exceptions

as

to

The abrasiveness

how

of

related

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The

how easy

of

generally

area

given

measure

forma

the

abrasiveness

measure

inversely

Drillability

in

is

tooth

drill

is

describe

to

and

drillability

formation

strength

also

mation

are

the

is

engineers

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characteristics

ENGINEERING

DRILLING

inis

formation in

approximately and

drillability

increasing

abrasiveness In

rules for

absence

the

thumb

often

for

the

foot

bit

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of

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of

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the

of

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However the be common on

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Some of

the

are

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engineers

follows

5.3

The IADC

classification

charts

Tables

provide

approximate

listing

of

in

plicable

The

of

the

tend

type

shallow

exceed

not

of

the

should

be

Premium diamond

cost

rolling-

PCD

and

most

the

versatile

choice

initial

for

the

bit

size

of

possible

tooth

wear

tooth

cannot

weight milled

should

breakage

shorter

selecting

enough

tooth

are

good

tooth

amount

to

day

per

bits

rolling-cutter

than

When

sharpening

ap

well

longest

rather

economically

rig

are

the

using

small tolerated

selected

high-cost

the

and

portion

Use

features

rolling-cutter

available

When

through types

more applicable when the daily cost operation is high The cost of the bit prob

Three-cone bit

5.1

bit

hardness

considerations and

the

be

to

drilling

should

cost

features

design

ably

type and

bit

bit

by

bits

drag

formation

given

initial

governed cutter

an

tooth

bit

longer

tooth

be to

he

size applied

cause

size

self-

should

be

used

When

the

of bearing

rate

bearing

the

rate

of

the

tooth

economical

Fig

5.20Elastic

rock

failure

beneath

high-speed

photographic

enlargement

of

crushed

from

rock

Sequence

rolling

cutter

sequences showing

bit.8

and ejection

wear

more

bit

mode

of

portion

of

deep

well

tripping

operations

favors

long

size

favors

PCD

of

crater

the

carbonates shale

tions

bits

or other

drag

which

bits

brittle

should

have

are

forma

and

bit

of

small hole

design

broken

not

cost

high

uniform

in

in the

especially

bit life

rock

more

weight

bit

the

than

less

in nonbrittle

of

sections

up

with hard

types

not be used

strong

the

better

size

where

drag

that

less

best

best

perform

or evaporites

stringers

PCD

of

simplicity

drag

tooth

failure

bottom

much

is

shorter

perform

than

less

size

weight

wear

design or apply

plastic

much

is

longer tooth

select

hits

drag

having

wear

of bearing

rate

bearing

Diamond tions

tooth

select

or apply

design

When

of

rate

wear

tendency

in to

gummy forma stick

to

the

bit

cutters Since the is

bit

selection

importance

removed

of

from

is

done

carefully the

well

largely

evaluating cannot

be

by

trial

dull

and bit

error

when

overstressed

It

it

is

ROTARY

DRILLING

211

BITS

TABLE 5.5BIT IN VARIOUS IADC

TYPES OFTEN USED FORMATION TYPES

Bit

Classification

Formation

11

Soft

12 51

formations

shates

soft

drillability

low

having

unconsolidated

compressive red

clays

and

strength

beds

soft

salt

high

limestone

etc

formations

62 13 61

Soft

medium

to

streaks

firm

formations

21

Medium

to

62

shales

shales

medium

limestone

23 62

Medium

interspersed

sandy shales

with red

harder

beds

salt

hard

harder shales sandy of sand and

formations

streaks

with

alternating

etc

hard

abrasive

rock

strength

or

limestonesetc

soft

anhydrite

sott

or

unconsolidated

to

dolomite

hard

formations

hard

high compressive hard

limestone

shale

slaty

etc

31

Hard

72

limestone dolomite

32 34

formations

semiabrasive

Hard

abrasive

sand

hard

formations

hard

chert

or chert

sandy

bearing

etc

chert

granite

quartzite

pyrite

granite

etc

rock

8i

also

to

important

has adopted

wear

diameter

gauge

of

logged

careful

for

code

for

teeth

wear

structure

to

in

quickly

the

bit

bit

wear

of

degree and

bearings code

the

The IADC

the

reporting

This

of

aspects

records of

written

references

future

the

more important

the

and

bit

numerical

relative

bit

maintain

of each

performance

bit

allows

some

be quantified

to

reports

worn

BT The

The the is

tooth

fractional

reported

it

of an

Fig

the

tooth

is

nearest

sometimes

entire

bit

with

5.21Comparison and

the

soft

single

of

to

number

bit

the

worn

are

bottomhole

formation

worn away

For example

characterize

if

bit

half

the

be

will

tooth wear

teeth

of

hard

patterns

and

cone

may be

and offset

soft

be in

satisfactory

Changes types

tooth

the

more

visual

made Fig when

rapid

piofile

5.22

Visual bit

single tooth

recording

is

to

is

of

wear

average

wear

wear

reported

measure

the

bit

chart

guide

estimates used

is

type

heights

inaccurate

cause

by

run However with estimates of tooth condi

the

using

original

the

most severe

after

in the

can

obtain

to

and

column

the

broken

be

may

indicated

are

due

to

like

the

are

usually

in

well

the

changing

estimates

visual

one

bit

of

tooth

rates

may worn

wear

Unfortunate the

Some

maximum

terms of

in

graded

worn away

teeth

difficult

is

has been

eighth

has been

height

T-4i.e

as

graded

ly

to

bits

that

height

can

teeth

before and

height

shown

wear of milled tooth

tooth

original

Wear

Tooth

Grading

teeth

way

experience

with

some

and

others

broken

remarks

in

best

tooth

than the

row of

the

tion

5.3.1

more

Generally

in

occur

some areas before

However

formation

rolflng

the

tooth

structure

penetration

cutter

low penetration

unacceptably

the

bits

rate

hard

of

is

the

formation

completely bit just

bit

before

zero cone

pull-

offset

APPLIED

212

5.22Tooth

Fig

the

ing

There

does

not

The

mean

to

The

tooth

worn

Thus

broken

or

The

field

The

the

tooth

to

the

nearest

bit

the

evaluation

would of

dull

or

failed

the

or

too

5.3.3

Grading

When

the

tooth than the

as

have

been

Thus

an

insert

would

be

graded

bit

bearings as

detected

it

is

reported

life

is

the

that

in

estimate

results

they

in

10

the

an

hours

bearings

grading

wear

of of

wear such

and

as

the

lasted

be the

the

be

necessary

should

to

Listed

that

the

cutter

bit

the

if

of

severe

bearing

in

5.6

the

and

gauge

of

condition

the

use

condition

to

describe various

in

Fig 5.6

the

bit

of

the

some common

are

bit

may

condition

bit

will

actual

Table

describe

to

bit

Recall

condition of

parts

rolling

one

is

bit

drilling

an

reported

Co

5.23Example

in to

used

the

time

Example 5.2 The use of

addi

has

as

have

shown

in

worn fallen

Describe ring

in out

of

the

its

dull

wear

shown

bit

indicated

gauge

from

and

the

all

in

the

value The

initial

the bit

that

Fig

hit

roller

cones

5.26

diameter bearings are

very

loose

Fig 5.24Bearing

Tool

in

loss

the is

teeth

the

about

the

in

alphabetically

HRS

Fig

The

bit Thus G-O-4 The

and

subsequently

ID

of Smith

graded

about

remarks

ACTUAL

Courtesy

eighth

bearings

readily

given

shown

as

wear

gauge in An

of

worn

who

visualize

are

is

the

undersized

the

used

of

hole This

bit

those

used

in

be

nearest

comments

names used

bit

the

out

is

These

enable to

to

grading

additional

run

of diameter

in-gauge

bit

bit

amount of gauge

the

0.5 in

the

undersized

be

thought

Thus

have will

area

proper

number of

wear with

operation

is

usually cannot

the

life

bearing

should

chart

on

engineer

bearing

base

in

must

ruler

diameter has

the

next

the

and

reported

is

lost

abbreviations

B-8i.e

code

the

loose cone

drilling

Linear

hours the bearing

bearing

bearings have

that

based

the

an

drill

will

of

gauge

In addition

the

examination

usually

bearing

estimated

assumed

after

using

slightly

When

B.-7

felt

the

dicate

bit

last

10

examine

to

An

failure

difficult

very

so

would

engineer

is

one or more extremely loose cones become exposed Fig 5.23

bearings

was pulled

wear

so

determining

excessively

bit

measure

to

the

records

usually

this

Fig 5.25

has

the

damage

ring

no

worn

of bearing

cause

hole

that

have

are

can

dicates

cones

in

Wear

Gauge

wears

bit

of diameter

or lost

whether

only

wear

cones

will

failure

bearing

B-4

are

rather

that

journals

Bearing

used

is

code

bearing

reported

disassembled and

locked

bearings

reported

reveal

intact

more

rotate

longer

be

to

bits

frequently

this

indicates

bearing

bearings

still

or

of

have

the

bit will

are

one

tional

is

broken

are

5.24

Fig

but

steel

lost

inserts

lost

.or

inserts

milled-tooth

for

rolling

eighth

broken

the

or

wear usually of

generally

milled

broken

chart

T-8

as

bits

as

number

inserts

of

condition

hours

insert

drill

Grading Bearing Wear

5.3.2

the

reported

of

guide

wear evalua

not

will

be

significantly

total

tooth

the

T-3

become

the

lost

half

that

as

the

T-4i.e

of

should

it

inserts

of

influence

when

structures

abrade

fraction

not

times

are

cutting

hard

with

should

bit

tion

wear

ENGINEERING

DRILLING

grading

ROTATING OR

12

HOURS

HRS

guide

tO

for

rolling

cutter

bits

DRILLING

ROTARY

Solution

This

B-8 G-O-8 worn

the

bit

cones

remarks

column

for this

the

reduce on

life

to

ability

tions

To

wear

factors

that

the

at

causing

discussion

not

are

and

in

of

failure

in

condition

good

ing

Bit

balling

will bit

gauge

interval

of

this

of

Figs 5.27 to

of

the

bit

experience abnormal

the

identify

bit

5.30

through

possible

before

wear shown

is

condi

reading

follows

to

rotate

However

bearing

bit

wasting

various

types

attempt

type

that

free

this

experience

run under

several

The type of wear shown cones

run

this

as

little

least

shown

the

bit

cause

probable

bits

illustrate

picture

to

the

additional

increases

dull

are

by

for

choice

per

high due

run by

with

bit

generally

provide

each

Study

bit

cost

Wear

Bit

recognize

failure

or

drilled

next

better

evaluating

bits

several

the

be

observed in

hole

the

operations

would

gained

of

bit

this

The

of

end

the

the

damaged

is

wear on

practices

of

out of in

placed

shirttail

unnecessarily

rates

undergauge

Abnormal

wear

probably

is

in

is

be

gauge

drilling

penetration

reaming

5.3.4

wear and

completely

is

bit

the

the

that

of

efficiency

protection

The

run

the

addition

In

indicate

tooth

bit

low

and should

T-8

code

the

using

structure

SD

choice

poor

graded

very loose

to

excessive

extremely

cutting

addition

indicates foot

be

the

are

gauge The

should

since

In

213

BITS

and

usually

tions

when

sufficient

teeth

in the

formation

cone

in

in this

case

in

is

is

by

forma-

sticky to

of

Security

Rock

Bus

and

for

Courtesy

Hard

Conditions

of

Spearpoint

shale

sandy shale

Sticky Chert

Nose

Chat row

Middle

Drill

Granite

of

Hughes

Tool

HSSH STSH CHE CHA GRA

gauge

of

Fig 5.25_Determination

bit

ABBREVIATIONS TABLE 5.6COMMON IN DULL BIT DESCRIBING BIT CONDITION

Location

Tools

the

bury

tendency

Coartesy

OUTOF GAUGE

%BIT

CONDITION

ball

bit

by

applied

The

completely

the

bearings were

the

very soft

weight

when caused

occum

was caused

drag

occurs bit

Fig 5.27

This frequently

wear

USED IN EVALUATION

Co Broken

circumferentially

Broken

spearpoint

BC BS CC EC

Cracked Eroded cone

shell

Heel Quartzite

Gauge

Bearing_Conditions

Cone

or

head

Classification

number

of

123

Pyrite

Run Bit

Good

Very good Good Above

average run

Average Below Poor

Good

run

average

Body

Bent

Conditions

legs

Damaged

Avg

Eroded Lost

nozzle

Avg Plugged

nozzle

Shirttail

Very

poor

run

bit

nozzle

Avg Poor

run

CK

Chalk

damaged

Poor

Cone

Teeth

Bearing

failure

Broken

bearing

Broken

rollers

BL

Compensator

DB EN

Cone

LN

Lost

rollers

PN SD

Seal

failure

Lost

BF pin

plug

damaged

locked

BP BR CPD CL LC

cone

LR

Seals

questionable

Seals

effective

SF SQ SE

Conditions

Formations

Broken Sand

Balled

Lime lime

Sandy

SL

dolomite

SD

Arihydrite

Red

beds

Shale

Hard Sandy

shale shale

dragged

Lost/loose

compacts

Off-center

wear

Rounded

Gypsum Salt

Cone Cored

Dolomite

Sandy

BT

teeth

up

SA RB SH HSH SSH

Uniform

Worn

Cone

gauge wear

out

of

Shell

Broken

BU CD CR LT

OC RG

gauge

Conditions

axially

Journal

Bearing

Seals

effective

Seals

questionable

Seal Bit

Bits

SE SQ SF

failure

FiR

rerunable

Bit

not

Bit

was

NR GR

rerunable regreased

Pulled

for

Pulled

on judgment

torque

precaution

BA

Pulled

for

penetration

rate

APPLIED

214

Courtesy

Hughes

of

Co

Tool

can

balling

be

the

creasing

reduced

jet

nozzle

central

5.26Example

nose

to

of

areas

the

the

occurs

quently

cone

of rock

reduces

the

When

taken on

bottom

bit

without be

low

next

subsequent

condition

this

the

on

This can ing

causes

run

and

weights

high

the

solids

or

the

high This problem bits

since

the

bit

regular

the

through

not

causes

of rock well

on

Also that

the

the

front

and

cones

of

shell

back

for jet

tooth

indicates

or

of

need

for

the

bit

is

be

achieved by

bit

circular

assembly

properly

be

provide

time

siderable

that bit

Tooth

Affecting for

insight

interval

dicates

Thus

of the life

the

evaluating

bit

about bit

use

bit

was

the

selection

If

the

pulled

remaining

dull

bit

to

greee expensive

in bit

tooth

wheel contact teeth

viewed

almost

is

rig

in the

how

of

of

tooth

wear

abrasiveness and

speed

fluid

drilling

is

the

initially

bits

grinding

be

have

or

teeth in

area given

Fig

to

in

the

The cross

view

side that

the

abraded

wheel

triangular front

shown

contact

can

proportional

the

either

geometry

has

tooth

generally

from

that

experimentally

directly

with

milled tooth

all

using

can

5.31

be

The

by

w1

w1

ensure in

dull

After removal

of tooth

Lr

height

of

the

original

tooth

the

bit

L1

the

bit

tooth

has

contact

is

Aww w2wXI

suitable

evaluation

i.e

not always

rate

the

steel

Lr

the

more

bit

steel

when

weight

Wear of

of

showed of

height

This

with

centered

of

are

penetra

altered

condition

be

use can

Height

Mitchell9 the

tooth

described

height

Factors

deter

to

bit

rotary

action of

at

Wear

grinding

the

section

teeth

teeth

bit

the

and

stabilized

Tooth

of

Tooth

and

by

area of

to

rings

the

by using

could

of

which

at

This

ridges

higher

increasing

Effect

Rate

away the

hole

the

between

area

faces

the

perhaps

bottomhole

One purpose to

on

desanders

circular

The

weight

cooling

an

if

the instantaneous

formation

bit

and

re

hole or

knowledge

affect

needed

is

on

will

knowledge

needed

is

of

runs

bit

bit

bit

of

borehole

5.4

5.4.1

eliminated

when

old

next

Thus

practices

parameters

also

geometry

cleaning

shape

and

wear

primarily

Campbell

be

hole These

the

cone

the

5.30

center cut

than

and

drilling

bit

depends

new

the

drilling

the

the

wear

bit

interval

This

from

if

the

of

extremely

is

bits

fluid

Fig

be

of

rate

rate

drilling

true to

of

the

which could

the the

the

hole

bottom

usually

rate

longer

the

on can

for

of

junk

the

of

rate

hole

the junk

efficiency past

much

too

the

wear

bit

time However

trip

in

junk

the time

Since

safely

various

the

bit

problem tion

about

wear away as

of

directly

same

the

concentration rate

regular

creased

much

dragged

increased

is

to fish

trip

instantaneous

the

tooth

when

occurs

usually

wear occurs

bit

rotate

an oversized

develop

as

strikes

problem

operation

Off-center does

fluid

This

us

bit

speeds

high

for

core

new bit

new

in the

circulation

worse

is

of the

tips

be

must

care

formation

the

Fig 5.29

contains

fluid

drilling

abrasive

cone

use

leaving

apart

cone

of

unnecessary

bit

may reduce greatly the tempt is made to drill of

of inner

on of

additional

mine how

cone

rotary

in

an

quire

core

by breaking

The type of wear shown

break

may

pattern

detected

the

breaking

fre

applied

wasted

interval

allowing

abrading

is

been time

bottomhole

eliminate

to

accomplished

bit

the

the

or lost This

have the

balling

when

loads being

break

tips

center of

in the

for bit

occurs

worn away

are

of excessive

with

bit

tendency

in

or by

weight

Co

Tool

5.27Example

Fig

action

Fig 5.28

in

The cone

cut

The rock core metal

cones

because

tips be

to

less

cleaning

The type of wear shown

bit

dull

by applying

hydraulic

often

of

Smith

ot

Courtesy

Fig

ENGINEERING

DRILLING

in

with

con

time

may

wy2_wyi

area given

by

ROTARY

of

Courtesy

DRILLING

Bit

Security

ratio

and

Drill

215

Tools

Courtesy

5.28Example

Fig

The

BITS

Lr/Lj

is

defined

cored

of

as

the

bit

fractional

wear

tooth

Expressing

wear

wear

If

the

contact

area

in

terms of

fractional

tooth

wj wi

wXl hw2 wi 1i

wX2

we

define

the contact

wxi

Tool

Co

5.29Example

the

eroded

of

geometry

teeth

constants

bit

and

G1

wear

G2

by

and

yields

hw2

Hughes

G2

54

hLr/Lj

of

Fig

can

area

be

expressed

by

AAl G1 hG2h2 Since

h2

the

the

inverse

instantaneous of

the

wear

contact

rate

dh/dt

is

proportional

to

area

dh

A1G1hG2h2

Courtesy

of

Hughes

Fig

Tool

Co

5.30Example

off-center

bit

wear

Fig

5.31Typical tional

shape tooth

of

wear

milled-tooth

as

function

of

frac

216

APPLIED

The

wear rate

initial

Thus

dh/dt

rate

dt

For

be

to

The

di the

hard

abrasive

tooth wear

constant

H2

taneous Insert

10

the

rate

of

the

that

been

Eq

in

studied

thus not of

rate

the

face

PCD tion

________________ Fig

5.33PCD ter

to

of

blank

wear

geometry for

as

function

zero-back-rake

of

fractional

angle

CUt

different

and

ing since

tend

to

the

far

more

the

flow

removal fractional

wear

the

the

as

value

This value

has not of

zero

is

bits

insert

cutter

wear to

of

drilling

to

the

The wear amount

the fluid

of

between

is

the

of

manner

in

acmss

Fig 5.32

ciystals

the

PCD

blank

fractional

For

to

the

lower surface of

the

the

tooth

cutter

height

wear

dimension

\COS_

shown

in

given

Fig

provides

tooth

zcro back-rake

proportional

somewhat

random orienta

5.33

wear angle

length

of

the the

cutter

remain

Lr Fig

5.33

by

Lr

and

frac

some

is

negative

sensitive

due

diamond shape

area

area

defined by

after

The

increases

practice

using

cutter

circular

contact

contact

chord

by

individual the

there

phenomenon

this

of

fraction

increasing

bit

by

tooth

broken

accelerates

the

fractional

is

relationship

cutter

cutter

the

steel-tooth

the

However

in

fail

this

bit

the

blanks

similar

Lr

to

with

instan

wear by breakage or loss of the dia The wear rate of diamond bits is

bits

provided

of

and

also

sensitive

the

modeled with

when

H2

elements

diamond

of cooling

be

For

been

breakage beneath

the

usually

contrary

However

detail

bits

cutter

the

tooth teeth

for

Diamond

hE

not decrease

could

in

bits

have

the

Eq i5b

carbide

that

self-

in

Mitchell

that

using

represents

teeth

than

and

such

selected

To

5.5b

recommended

mond

bit

the

different

predicted

with

self-sharpening

Campbell

tungsten

does

type of behavior

be

of

tooth

mechanism of

the

rolling-cutter

wear

number of broken

H2

of

greatly

function

or

have

will

wear

tooth

dh/dt

tooth

evidence

for

approx

5.5a

as

tooth

somewhat

be

brittle

number of

rate

tional

can

in

bit

though

is

can

used

teeth

total

wear

wear

wear

tooth

often

Even

usually

fractional

type bit

be

can

Eq

of

place

of

experiments

wear

fracturing

drag

rate

5.5b

in

side

one

wear

tooth

sharpening

PCD

wear

the

case-hardened

on

facing

type of

5.5b

calculation

time

rotating

on

that

be

will

constant

1H2h

Eq

of

use

simplifies

wear

such

wi

This allows

/dh\ oc

cutter

5.5a

w2

w1

w2

with

chosen

dt

5.32Example

wear

initial

using

dh

Fig

to

proportional

standard

dimension

the

types

compared

imated

is

terms of

1G1hG2h2

bit

most

in

gives

dt

small

H2

when

expressing dh/dt

ENGINEERING

DRILLING

is

ROTARY

DRILLING

BITS

217

Then Note

I\

equation

COS

COS

rr

2r

and

tooth

relation this

Solving

for

expression

subtended

the

angle

used

wear

is

diameter

bit

given

instantaneous

most

Later

applied the

between

the

Perhaps

Thus

weight used

commonly

by

COS

2h

dbm

5.5c where

Since

the

chord

contact

area

is

subtended

length

the

by

to

proportional

directly

then

/3

angle

the

bit

W/dbm

diameter

diameter

bit

/3

contact

dh/dt

rate

standard

is

to

proportional

inversely

wear

dt

dr

5.Sd

The

wear tooth

tiorial

dh/dt

wear

For nonzero

PCD

the

becomes

to

the

angles

and

the

believed

is

wear

the

total

contact

to

resistance

this

area of both substrate

above

the

of

geometry

5.7b

the

predominant

of

the

PCD

imum

bit

similar

results

Effect

Galle

and

of

Galle

rate

and

published

the of

tooth

Woods

of

effect

one bit

PCD

thin

contribu

of

the

first

on

Wear

equations the

10000

in

and

5.7b

the

field

the

max

somewhat

Since

lbf/in

over

wear

relative

the

assuming

of

range the

conditions relation

simpler

more widely Eq 5.7b Eq 5.6b nor Eq 5.7b has

5.4.3

used

is

However

been

verified

by

data

experimental

Effect

Rate

on

of Rotary Speed Tooth Wear

of

first

wear

tooth

Galle

by

dh

the

and

relation

for is

instantaneous

the

was

also

speed

rotary

Woods

and

Woods

The Galle and

between

relation

published

of

presented

instan

assumed

relation

of

by

neither

The

Tooth

of

5.6b

obtained

are

of

comparison

is

Eqs

weight

published

blank

weight

The

wear

given

is

Rate

on

Weight

Woods

predicting

taneous

Bit

5.7 by

encountered

usually

rate

5.4.2

Table

db

analysis

the

be

in

predicted

given

carbide

tungsten

the

Above

increasing

However

of

representative

which

layer

rake

layer

frac

increasing

0.5

and

increases with

more complex

remains

with

between

rate

Shown rates

decreases

wear

the

range

sin1312

rate

of

lbf/in

Ii

Ldm dh

rela

this

4000

at

instan

fail

Expressing rate

of

inch

per

would

--4

dh

this

area

dh

weight

bit

teeth

W/dhm

W/db of

bit

rfw\ dh

wear

the

yields

2sin the

maximum

the

is

terms

in

db

which

at

and

taneously tion

fd\

57

W\

dt

for

10

fail

dh

/3

tiori

W/dh

were

relation

simpler

rate

for

would

teeth

/3

yields

and

of

lbf/in

authors

infinite

the

predicts

10000 H15

if

ly

becomes

dh/dt

that

this

milled-tooth

bits

by

given

N4.34X105N3

by

5.8

dt

by

However that

dh

5.6a

several

more

recent

authors

same

results

can

the

essentially

be

shown

have obtained

using

the

relation

simpler

dt

log

dh

5.9a dt

where bit

l000-lbm

in

weight

where H1

units

the bit

dh

diameter

in

inches

bit

and only

W/d

10.0

to

terms weight this

of of

rate

at

various

standard

4000

standard

wear

lbf/in

wear

bit

rate

weights

rate

Thus is

given

can

that

would

the

wear

be

expressed

occur rate

for

relative

dh bit

0.3979

The

5.6b

ing

Effect effect

fluid

of

of on

important

log__

rate

for

wear

rate

tooth

would

that

occur

use

60

at

for

in soft

terms

in

rpm

of

yields

5.9b

dt60

dt

5.4.4

dt

dt

Expressing

wear

types designed

the

by

dh dh

bit

ll

in

to

used

milled-tooth

mations standard

The wear

Also H3 was found to vary with The Galle and Woods relation applied

constant

is

type

rolling-tutter

the

cooling cutter

the

for

Hydraulics

diamond bits

Each

and

wear and

on

Rate

cleaning rate

diamond

drag

cutter

of

action

dh/dt

PCD

Tooth

of

is

bits

must

the

much

Wear drill

more

thaii

receive

for

suf

218

APPLIED

TABLE 5.7COMPARISON THE EFFECT OF TOOTH

OF EQUATIONS FOR MODELING HEIGHT ON TOOTH WEAR RATE Wear

Relative

Bit

Weight

L1//db

The flow

temperatures ed

high

with

enough

rock

varies

specify

the

each

for

system

bit

across

Mathematical hydraulics

The

employed

designs flow

present

of hydraulics

fect

5.4.5

32

1.65

10.0

0.9

3_3

1.60

10.0

1.0

1.0

41

1.50

10.0

1.3

1.2

1.8

1.5

must

It

is

to

the

generally

distribution

manufacturer flow

for

of

such

will

or

models

to

that

cool

the

rate

can

wear

be

of

bit

as

be

bit

Eq

after

and bit

the

bit

given

4000

of

bit

If

final

we

can

approximating

geometry tooth wear

bit

weight

and

the

long the

formation be

can

wear

tooth

wear

tooth

using

as

ef

ignored

be the

speed

rotary

instantaneous

obtained of

effect the

on

rate

of

by tooth

Eq

can

be

expressed

by

of

rate

ii

wear

tooth

5.10

hf

lH2hdh

dt_Jr4

by

N\1

when and

5.11

wear equation

Thus

is

com

to

type

run

define

has

T11

lbf/in

The average

the

5.10

constant required

during

5.10

pulling

the

weight

60 rpm

of

speed

hours

in

of

teeth

encountered using

observed

time

Eq

by

of

would

cutters

bit

given

abrasiveness

the

the

constant

rotary

evaluated

to

the

at

constant

that

been

yet

variety

assumed

generally

effect

not

wide

the

relations

db

of

Integration

TH60

dt

dull

operated

abrasiveness

rate

the

wear have

and

pletely

formula

rate

so

equal

parameterf2

estimating

of

wear

tooth

normalized

Equation

tooth

15

fluid

bits

face

cutter

cutter

various

The been

numerically

im

extremely

will

bit

the

given

is

passages

distribution

the

the

combining

is

fluid

bit

maintain

fluid

drilling-fluid bit

clean

on

the

of

be

also

of

among

TFA

because

Wear

Tooth

composite

0.8

0.8

development

available is

0.6

manufacturer

of

rate

difficult

extremely

10.0

drag

models the

on

9.0

1.70

addition

the

8.5

1.76

PCD

recommended

specify

pressure drop

the

In

8.0

1.80

31

of

area

22

23

clogging

the

flow

total

to

7.0

1.84

0.7

design

or

to

WIdax

H2

1.90

0.4

considerably

However

available

13 21

H1

12 14

to

Eq.57b

velocities

The

Class

Bit

11

Eq.5.6b

prevent

diamond

in

and

portant

to

cuttings

passages

Rate

Inch

per

ENGINEERING

TABLE 5.8RECOMMENDED TOOTH-WEAR PARAMETERS FOR ROLLING-CUTTER BITS

/dh LJ/

lbf

DRILLING

this

equation

5.12a

yields

15J27HhfH2h12/2 for

Solving

5.12b

abrasiveness

the

constant

TH

gives

/lH2/2\ 5.10

lH2h

tb

TH

tooth

fractional

that

height

has been

use

constants

cess

to

sert

bits

weight

rotary

speed

formation

TH

000-lbf

rpm

units

than

and

be

from

bit

abrasiveness

hours

constant

used the

scheme

classification to

four

Recommended shown in Table

characterize major

bit

the

shown

many

types

of

H1 H2

5.8

the

various

and

5.3

the

speeds

of

bits

to

above

with

insert

inserts

50

milled

some degree by

In

rotary

loading

hard

rpm may

tooth

of

suc In

breakage

lower

impact

for

developed

of

teeth at

reduce

about

were

height

operated

carbide

tungsten

tooth

applied

loss

generally

milled-tooth

insert

of

speeds on

the

formations

quickly

shatter

16

available

companies

manufacturing

values for

bit

Table

in

are

the

5.15

through

loss

been

also

describe

brittle rotary

rock

the

modeling

bit they have

bit

can

in

5.10

Eqs

Although

time hours

H1H2

W/dh

hf212

worn

away

The

5.13

J2h1H

where

W/d

rolling-cutter

are

rock

bit

Example

classes depth

of

5.3

An

8179

to

8.5-in

8404

ft

Class in

10.5

1-3-1

bit

drilled

from

hours The average

bit

ROTARY

DRILLING

weight

and

lbf

90

and

was

rpm

same

for

the

When

bit tha

T-5 B-4 0-I Compute for to

required

bit

used

respectively

abrasiveness time

the

219

speed

rotary

graded

tion

BITS

this

and

weight

the

was pulled

the

average

interval

depth

dull

teeth

was 45000

run bit

Also

TABLE 5.9RECOMMENDED EXPONENT

it

Bearing

the

Using

B2

Type

mud mud

barite sulfide

water

Solution

Table

Using

andW/dh

5.8

8.0

we obtain H1

Eq

Using

1.84

5.11

we

H2

mud

clay/water

obtain

oil-base

1.84

8.045/8.5

BITS

Fluid

Drilling

Type ________________ Nonsealed

speed

rotary

WEAR

BEARING

ROLLING-CUTTER

forma. estimate

completely

FOR

roller

1.0

1.0

10

1.0

1.2 1.5

1.0

mud

2.0

1.0

Sealed

-l

10

0.70

0.85

1.6

1.00

bearings

\9Q

8.04.0

Sealed Journal

bearings

_._z008 16/2 Lummus be

Eq

Solving final

5.13

fractional

for

the

abrasiveness

dullness

tooth

of

constant

or

using

T5

0.625

gives

has indicated

detrimental

occur In

which

the

to leads

was important 10.5

4.5

hours

for

0.080

625

60.6252/21

the

can

be

obtained

bearing

to

dull

the

teeth

hf

completely

life

hours

lb0.0873.oIl-l-6l2/2234

is

given

metal can seals

phenomenon values

horsepower

above

general model on

hydraulics

wear

bearing

IS

used

frequently

to

estimate

by

w\B2 5.14

4dh

where fractional

life

bearing

has

that

been

consumed

5.5

Factors

The

prediction

than

the

of

rent

of

of

manufacturers bearing as

as

long

excessive

The

the

dull

speed

to

vary

cutter

roller

and

lowest

for

bits

sealed the

nonsealed

and

roller

revolu

to

highest

bearing

wear exponents

TB

bearing

constant

Recommended

values

in

Table

given

by

Eq

stant

TB

ing

used

and

hours

59

of

the

Note

bearing

that

the

wear exponent

bit

5.14

constant

equal

4000

at

operated

is

normalized

is

numerically

is

in

dull

be

evaluated evaluation

wear parameter

J3

that the

and

Ibf/in

bit

can

of

results

so to

using If

we

the

life

60

Eq

are

wear formula

bearing

bearing

con

of bearings

5.14

define

and

the

bearing

using

the

for

the

bit

60

i3_

is

sealed

B1

B2

4db

5.15

___.-

journal

The

bearings bearing fluid

of

effect

number and

bit

sealed

are

lubrication

and

the

also

thought

rate

increases

flow to

to

increases rates

prevent

When is

mud

The hydraulic

also

on

weight

bearing

type of bearings used

have

of

some

also the

However

the it

is

sufficient

to

excessive

temperature

lift

are

with affect

drilling

effect

of

ability

depends

whether

bearings

accomplished

properties

action

the

the

life

and

cuttings

on

to

at

cool

generally will

buildup

also

the

Eq

5.14

can

be

expressed

by

not sealed the

bearing

fluid

the

on

or not

drilling

bearing

fluid

if

rpm The bear

sealed of

price

lbf

inches

life

speed

rotary

diameter

B2

prevent

roller

The

journal

force

bearing

assemblies

nonsealed

are

bit

bit

bearing

total

enough

weight

given

the

with

main types of bearing

three

rolling

B1

rpm 000

bit

be

linear

applied

Thus

linearly

dh

increases

Also

terms of

increase

cur

surfaces

speed

rotary

the

the

evaluation

low

is

on

wear

given

in

expressed

rotary

wear

surfaces cannot

bit

for

difficult

bearing

assumed

is

that

temperature

assumed

is

usually

be

tooth

bearing

bearing

the

wear usually

can

the

time hours

more

wear depends of

the

found

Like

After

rate

during

have life

bit

since

much

is

wear

bearing

the

readily

bearing

tooth

the

However

examined

tions

of

damaged

greatly

rate

of

rate

condition

become

wear

bearing

prediction

Wear

Bearing

Affecting

instantaneous

an

of

effect

/N\Bi/

dt

the

by

this

can

velocity bit

bearing grease

bottom However

-1 60

db

.0

5.12

Eq

from

the

Lummus

hydraulic

wear formula

bearing

The time required

bit

of hole

predicting

of

failure

of

was not presented

hours

73.0

for

in

hp/s9

to

jet

Erosion

life

discussed

example

too high

that

bearing

dtJ3T

life

the

bit

life

As flow

the

bearings

believed be

in the

db

is

that

where the

is

bit

the

final

Integration

bearing of

this

wear observed

equation

after

pulling

yields

sufficient

bearings

tb

J3

TBbf

5.16

220

APPLIED

for

Solving

bearing constant

the

gives

can

life

the

in

ple TB

5.17

with

the

shale

constant

bearing

sealed

intermediate-size

ing

constant

formance

of about

to

the

hole

new bit

of

the

the

when

not

is

probably

the

hil

stabilized

bearing wear

on

Also

Example 5.5 in

and

the

to

the

parameter

value

value

of

B2

be

J2

has and

value

of

6.0

value

of

0.55

has

was

T-5

graded

30000 Solution

B-6

70

5.15

we

value

after

Eq

5.9 B1

for

the

and

1.6

hours

the

B2

Us

1.0

constant

using

hours

almost

The

use of

will

provide be

will

the

become

the

in

the

the

total

the

cost

rent that

bit

if

computed the

life

cost

lithology

always case

the

would bit

result

an

the

is

in

effective

more of

the

rotate

he

cost

be

not the

is

foot

case

foot at

the

uniform minimum

criterion

for

this total

helpful

to

bearings frequently

fluctuation

wear parameter

J3

has

constant

bearing

cost

$800

is

10

constant

the

7H

TB

has

cost

rig

is

hours

Time

Drilling

hours

30

2.0 4.0

65

6.0

77

8.0

87

10.0

96

12.0

104

14.0

Ill

16.0

Remarks

increased

Torque

The time required

Eq

using

as

the

before

the

t1

bit

wear out

to

the

teeth

can

be

5.12

by

165

The

cost

the

it

of the

the

bit

to

well

be

com

ter

when

cost

will In

optimum

bit

16

would shown

run

at

Thus result are

if

as

Time

Drilling

LD

tht

ft

hours

various

the

depths

overall

the

cost

were

bit

can

be

per

foot

pulled

at

follows

Drilling

Cost

Ci Sift 0.0

However

procedure

determining

can

bearings

is

cur

pulled

increase

of

Eq

that

Footage

run assuming depth Even if be

the

hours

depths

run

various

minimizing time

foot

per

computed using

wear

bit

keeping

bit

wear out

to

hours

5.16

0.5530l

uniform

best

by

Eq

using

bit

should to

bit

large

current

bit

begins

the

rapidly

for the

the

is

somewhat

determined

per

remains

pull

equations

the

minimized

this

pulled

per

to

best

cones

the

decreases

be

In

or

the

when

it

When

lithology

can

run

bit

estimate of the

If

run can

bit

addition

to

rate

wear of

torque

increase

needed

cost

of each

significant the

worn

drilling

the

or

bearing

be advisable

may

wear

operations

tripping

estimate

In

sudden

penetration it

completely

one

torque

progresses

and

table

cause

rotary

When

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rough

worn

worn

badly

minate

wear

about

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run and

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tooth

at

completely

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the

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0.4501 612/2 80

puted

Run

Bit

bit

The

bit

known

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H1

the

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life

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terminate

bit

lithology

constant

the

bit

time

trip

50

computed

Terminating is

0.4

bearing

hours and

The time required

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bit

severe

b1

0.8200.75

time

formation where

area

this

of

formation

ft

at

0.820

bearing

TB______.__l04

There

in

to

ti

Solution

5.6

bit

best

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in

value

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64

hard

section

optimum below The

hours The the

Footage

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47.875

5.17

be

Newbit

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64

drilling

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sharp

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it

the

table

The

of 50

of 30

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1.6

60

G-l

constant bearings

drilled

abrasive

place

place

rpm

From Table

Eq

ing

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lbf

bearing journal

to

to

uniform

essentially

value

5.4 the Compute 7.875-in Class 6-1-6 sealed

then

abrasive

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in

S600ihr and Example

and

order

Determine

described

run

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drill

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per

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hard

problems

variations

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run

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section

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lithologic

desirable

ENGINEERING

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numerical

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on

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hours

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established

properly

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45

variation

function

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bit

in

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large is

intermediate-size

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100

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tal

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define

to

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it

tion

1i1

be established area

DRILLING

30

2.0

266.66

50

4.0

184.00

65

6.0

160.00

77

8.0

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87

10.0

14712

96

12.0

145.83

104

14.0

146.15

111

16.0

147.75

not this bit

Note the

that bit

the

was

lowest

pulled

drilling

after

12

cost

hours

would

have

resulted

if

ROTARY

DRILLING

Alternate

Solution

determine

to

BITS

graphical

the

221

usually

It

Eq

procedure

Ch

easier

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for

minimum

of

point

field

16 can

be

personnel

cost

drilling

using to

rearranged

th

11

00

give

cs Ui

75

-J

LD

Cr

Thus per

Iy

Ct/Cr

if

foot

is

te

tf

D/Ch/Cr

is

in

11.33

hours

of

rate cost

noted

foot

rate

studied

include

bit

tics

drilling

bit

fluid

to

most

variables

have

the

bit

direct

been

bit

as

af

variables

identified

and

characteris

condi

operating

speed

rotary

well

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fomiation

type

the

of

bit

tooth

failure

the

strength

the

crater

found in

of

effect

these

variables

work

experimental studied

was

work has been

while

on the

drilling

of

effect the

holding

optimal

bit

rock

to

uniform

in

life

shear

an average

The angle of most

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internal

rocks test

pression

from

90G

be

cor in

deter

compression

test

was assumed

about

40 com

30

to

standard

for

a3

pressure

18

drilling

To

from

5.3b

of

determined

as

35

of

varies

Eq

atmospheric

at

constant

initiate

pressure

single

friction

Applying

to

rock

friction

in

strength

pressure could the

that

is

rock Bingham

the

required

of

internal

tooth

single

atmospheric

at

strength

angle

of

force

characterize

compressive

strength

strength

test

compression

the

to

has reported

beneath

atmospheric

at

shear

the

the

shear

used

is

Maurcr7

both

to

threshold

the

given

for

other

the

and

that

related

wear

formation

the

volume produced

rock

the

sometimes

criteria

of

proportional

versely

mine

this

of

ft

Rate

amount of experimental

variable

single

that

HOURS

determination

Fig 5.34Graphical

indicates

hydraulics

study

In

or 96

and

properties

and

considerable

rate

TIME

is

starting

lithology

The most important

drilled

weight

with

has an obvious

wear

penetration

and

line

Penetration

achieved

fecting

bit

of

hours

12

drilled

Fig 5.34

in

plot

con

graphical

footage

Mohr Affecting

bit

per

The

about

after

of penetration

rate

in the

Next

maximum slope

the

is

slope

Factors

done

hours

offset

5.34

Fig

vs time and

maximum

tions

11.33

negative

shown

plotted

the

slope

25

as

plotted

struction

the

the

600

Cr This

The

when

50

cost

maximum

is

10

5.7

the

800

C1

at

vs

plotted

minimum

be

will

gives

a1

TQ1/2a1 5.7.1

Type

Bit

The

bit

rate

For

often

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are

hard

formations

tooth

bits

type rock

are

depends

ting

angle

cost

in

tooth

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bearing

drilled

bit life

that

at

on

obtain

in the

which

the

bit

PCD

per revolution

and

number of

tive

number of blades face

the

the

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depth

of

of

be

can

The the

bit

bits

used

length

less

the

are

the

by

orPCD

number of diamonds

and

from

penetration

give bit

wedgingper revolu

compute

of

the

the

for

of

the

The width the

cutters

bottom

cut

bottom

to

effec

project

clearance

cut

the

Formation

The

elastic

are

the

limit

most

penetration

weight

by

zero in

plotting

manner

this

and

The

rate

drilling

rate

drilling

as

ex

then laboratory

shown

is

in

to

required

diameter

bit

per

to

W/d1

weight

in

Fig

The cant the

drilling

the

bit

on

and

rock

pressure

each

affects

would

be

containing

required

gas than

to

can

containing and

cause

gummy

drill

in

rapid

very

of

dulling

minerals

clay

the

can

inefficient

more

has

also

the

of

the

filtrate

pressure

containing

pro

that

spaces

the

containing

to

the

formation

argued

pore

rock

the

crater

of

on

acting

since

rock

of The mineral composition fect on penetration rate Rocks minerals

the

equalize

in

rocks ahead

would tend

be

can in

mechanism

this

rock

the

into

This

also

It

signifi

permeable

mode of

contained

fluids

has

also In

differential

tooth

elastic

5.17

Fig

the

also

volume

the

beneath

in

nature of

rate

move

can

filtrate

more explosive

the

formation

the

penetration

equalize

described

rock

the

fluid

chips formed

mote

of

permeability

effect

in

liquid

some ef

hard abrasive

bit

cause

teeth the

bit

Rocks to ball

manner

Characteristics and

ultimate

important

rate

bit

cos

5.35

up 5.7.2

bit

obtained

penetration

blanks

of

correlation in

usually

selection

drilling

function

or

obtained

of rate

designed

force

was

back

will

give

number of blades and

The diamond and

penetration

bits

drag

threshold

itiate

trapolating

optimum

given

The

these

because

penetration foot

per

longest

previously

size

ing

formations

decline

to

designed

failure

tion

limits

with

However

angle

with

bits

using

is

rate

conditions

As discussed

given

the

using

consistent

operating

rate

soft

and

penetration

penetration

when

offset

The lowest

when

life

Drag

in

only

destruction

initial

formation

cone

large

on

effect

large the

bits

given

practical

obtained

is

in

and

tooth

rapid

cutter

rolling

teeth

has

selected

type

highest

long

sin

The

strength

formation shear

strength

of

the

formation

properties

predicted

affecting

by

the

5.7.3

The

Drilling properties

penetration

Fluid of

rate

the

Properties drilling

include

fluid

density

reported

to

affect

rheological

the

flow

222

APPLIED

filtration

properties and

tent

size

crease

pressure

beneath

the

frictional

losses

in

reduces

l8

fect

ci

balling

on

Pink

Knippa

I4

evidence rate

rate

in

that

some

of

of

composition

the

the

the

is

perfectly

rate

affected

are

also

ef

has an

fluid

hydration

clays

is

viscosity

bit

the

rock

hydraulic

There

increasing

of

control

parasitic

the

thus

when

even

solids

of crushed

cleaning

that

composition

penetralion tendency

and

for

jets

mud

the

in

to

and

bit

the

by

fluid

the

Quartzite It

Basalt

has been

order of

Springs

than

are

Ihat

the

colloidal

Sandstone

An hydrite

more detrimental

the

ment of

the

Sections

2.3.9

reducing

the

about

beneath

filtration

nondispersed

concentration

It

muds

of

at

develop

discussed

Chap

of

efficient

The

bit

the

rate

believed

is

more

an

are

penetration

30

polymer

2.3.11

through

colloid-size

gm

to

much

are

particles

of

presence micron

coarser than

particles

off

the

than

less

are

magnitude

plugging

that

reported

which

particles

Rush

bit

tends

controls

viscosity

drillstring

the

penetration

chemical

16

fluid

The chemical

clean

of zone

the

fluid

increasing

The density

rate

across

composition

and

characteristics

the

at

with

content

filtration

The

bit

decrease

con

solids

chemical

solids

filtration

experimental

Pressure

and to

and

differential

available

energy

20

tends

increasing

and

content the

rate

viscosity with

characteristics

distribution

Penetration density

ENGINEERING

DRILLING

in

was aimed

colloidal-size

at

particles

present

The cZ

by

12

several

40

80

120

200 240

160

280 320

an

decrease crease in

crease 5.35Relation bit

weight

I-

between at

rock

shear

atmospheric

and

strength

pressure

and

density

in

in

differential

rate

penetration fluid

the

pressure the

the

cutter

an

fluid

borehole

mechanism

density

rolling

the

bit

and

between pressure

-J -J

4000

5000

PRESSURE

6000

7000

PSI

DIFFERENTIAL

PRESSURE

PSI Fig 5.36Effect ing

of

cutter

overbalance bit

on

drilling

rate

in

Berea sandstone

for

clay/water

mud and

.25-in

roll

An in in the

thus

an

in

borehole

This pressure

pressure and

.9

3000

bits

the

by

causes

increase

tjJ

COLUMN

using

conditions

causes

differential

formation

between

for

densily beneath

the

fluid

drilling

10

2000

resulting

conducted

LI

MUD

the

borehole

into

insight

in

pressure

were

simulated

some

in drilling

pressure and

threshold

18

fluid

which

under

increase

bottomhole

db

Maurer7

tooth

provided

which

1/

Fig

of

bit

single

drilling

studied pressure on penetration rate has been 7.I94 authors The previously discussed ex

periments

have

of

effect

bottomhole

foniation

ROTARY

DRILLINJG

pressure often

fluid

in the

change

criteria

given

balance

on

the

in.-diameter

obtained of

range

150

of

range that

pt

Data of

similar

of

the

of

on

values

fora

Note

data

the

12

wide

pressures

when

Indiana

Data in the

are

to

of overbalance

limestone

having S..

shown in

in

formation of

the

bit

Note rate

is

and Li

sandstone

Apparently for the

by

solids

the

INDIANA

LIMESTONE 1000

IJi

50

deposition

lbf

RPM

prevented

sufficient

that

5.37

Fig

Berea

the

caused

bit

and

ahead

to

equalize of

effect

more pronounced

over at

low

-J -J

of overbalance

than

is

have

fluid

permeability

differential

overbalance

the

Fig 5.36

in

function

are

the

penetration

overbalance

permeability

obtained

mud

of

filtrate

pressure

balance

If

cake

mud

on penetra

having

in

higher

beneath

damage

filter

flow

much

1.25drilling

permeabilities

as

md

10

to

those

to

had

mation

obtained

with

overbalance

obtained

rate

at

failure

rock

shown

is

over

stress

laboratory

formation

drilling

permeability

which

and

correlation

with

replotted

are

sandstone

borehole

in

of of

are

normal

working

effect

range

450 md

to

good

Pbh

the

failure

of

effect

overbalance

to

bit

the

increas

wedging-type

related

cutter

wide

Berea

in

The

Eenink

rolling

studied

similar

for

and

Recall with

Fig 5.17 The Mohr

performance

directly

for

overbalance

mechanism

predicts

plane is

the

in

5.3

bit

Cunningham

rate

called

formation

Eq

drag

mechanism

tion

223

described by

failure

machine

is

crater

overbalance

ing

BITS

at

high values

additional

large

quite

of overbalance

essentially

no

Lingen2

have

increases

on

effect

in

penetration

rate

Gamier data

and

obtained

van

using both

ter bits

in

ed

the

effective

bit

often

that

drag tween

the

chip chip

is

laboratory

static

being

unless

small

drilling

be

borehole

greater

and

sufficient

liquid

can

laboratory rolling

They

during than

rock

vacuum

lifted

and

bits

apparatus

overbalance

can

published

drag

chip

the

removal

difference

pore pressures

can be

be created supplied

cut

to

fill

DIFFERENTIAL

by

Fig 5.37Effect

of

the

limestone

the

ter

bit

S.

uJ

-J -J

25

Pbh

3000

4000

5000

PRESSURE-PSI

be

When

under

2000

1000

conclud

Pf PRESSURE

kg/cm2

overbalance for

clay/water

on

drilling

mud and

rate .25-in

in

Indiana

rolling

cut

224

APPLIED

100

void

opening

fluid

80

filtrate

the

was

reduction

40 32

static

rpm

Atmospheric

Pore

Dbernkirchener

Sandstone

Bit

Load

Vaurion

Limestone

Bit

Load

Belgian

Limestone

Bit

Load

20

the

same value

ing

fluid penetration

Pressure

300kg 500kg 700kg

pressure

even

constant

This

balance

50

75

00

25

for

the

rate

rocks

remained

for

drag

while

tained

using

shown

for

diamond

comparison

core

Pore

Pressure

Diamond

Core

data

Load

Bit

Vaurion a-

LimestoneO LA

00

Load

Bit

10

1200

20

15

DIAMOND

rate

scale

in

bits

stone

800kg 1000 kg

Load

Bit

penetration

Typical

Bit

kg

and

psi

5.40

Note

observed

25

CORE BIT

that

data

rate

balance

on

drilled

are

also

in

was

liN

Data

12000

with

ft

shown

in

similar

quite

20

Belgian

Limestone

Bit

shale

due

rate

to

for

ci

OVERBALANCE ROL

If VG

20 kg/cm2

CUT TER

BIT

in

5.39Comparjson rate

of

effect

of

overbalance

on

penetralion

to

formation

Figs

5.37

through

reasonably is

accurate

possible for the

for

that

of

and about

bit

are

curve

the

widely in

is

and field

by

penetration

the

relation

be

could

be

rate line

on

5.41

by

straight-line

values

shown

used

the

penetration

borehole

The

sug

Note

that

of

representation

of overbalance

Fig 5.35

data

as

presented

Fig 5.42

in

in

normalizing

pressure are

in

semilog

commonly

overbalance

fluid

Young

line

wells

cutter

suggested

dividing

moderate

straight

seven Vidrine

of

changes

straight

zero

and

over

Cunningham

accepted

they

equal

Bourgoyne

by

by

by

to

on

of

rolling

overbalance

data

rate

tests

effect

depth

penetration

addition

corresponding

equation Fig

In

penetration

gested

data

of

range

practice

pressure

25

the

behavior

density

and

approximately

of

Fig

in

overbalance

shape

observed

Young

overpressure

given 10

and

is

with

mud

in

changes

Bourgoyne tween

familiar

sand

strength

by

of

on full-

simulator.2

the

at

data

bit

using

Colton

on

studied

the

laboratory

This type of behavior

rate

1500kg

that

personnel

the

Load

the

Note

using

shown

The

8.5-in-diameter

ob Also

cutter

by

are

of

Well

Eenink

field

Bit

to

on

drilling

paper

rpm Atmospheric Pore Pressure 7/8 Conventional Roller

an

Fig 5.41

represented

32

obtained

bit

overbalance

.2

Benit.-

were

results

laboratory

effect

at

at

obtained

confirmed

rate

Louisiana

pressure

was already

the

in

40 Ld

rate their

constant

compressive

available

penetration

south

in

the

pressure

operated

weilbore

of

rapid

penetration

rolling

of

small-scale

on

penetration

drag

obtained

tests

previous

field

penetration

these

more

obtained

unconfined

static

fluid

and

are

data

effect

permeability

in the

Some

an

over

overbalance

tricone

results

mud

drilling

pressure

similar

at

drill

the

borehole

static

high-pressure

had

of

pore

recently

the

remained

mud

Fig 5.39

the

the

was

on

double-blade

on

were

the

pressure

37/8-in

experimental which

7.600

in

are

and

bit

as

Lingen

levels

and

Shown 1.25-in

Laboratory

96x63mm

dynamic

the

equal

essentially

as

than

chip

van

the

the

dynamic

greater

increasing

pore

Since

pressure

low

quite

Atmospheric

the

by with

increasing

effective

was

of overbalance

various

at

maintaining

used

is

with

the

and

the

pressure

indicated

permeability

Gamier

low forms

beneath

overbalance

was used

with

effect

of

obtained

mud

the

beneath

constant the

bit

mospheric

L1

water

moderate

machine

drilling

32rpm

that

rock

the

readily

void

and

chip

pressure maintained

static

formation

chip

the

prevent

was

by

drilling

rock

the

decreased

the

indicates

of

To obtain

Li.I

rate

only

from

which

were

weilbore

though

pressure equalization

DRAG BIT

This

when

of

void

to

which

that

When

overbalance

25

Note

during

slow

chip

5.38

pressure and

pore

the

into

liquid

too

the

Fig

in

of

supplied

pores

into

mud

be

ENGINEERING

fracture

drilling

to

beneath

shown

data

the

be

When

flow

the

the

clay/water

chip

found

call

flowing

with

cake

filter

chip

liquid

through

through

fluid

permeability

60

flowing

flowing

formation beneath

The

space

fluid

drilling

DRILLING

is

the

The given

by

20

logR/R0

mp Pr

l8

ROTARY

DRILLING

BITS

225

200 WELL 8.5in

db

160

45k-Ibf La

140rpm 4.89hp/in2

120 COLION

SSNDSTONE

60RPM

80

-J

40

-J

W4C0OQ _OW20000_o

W3O

-4

000

____________

LU

2000

1000

4000

Fig 5.40Penetration balance

for

rate

as

Colton

function

of

PSI over

pressure

Fig 5.41Field

sandstone.21

Phh

rate

bottomhole

pressure

formation

Pj

the

in

fluid

slope of

zero

at

in

pressure

the

we

express

mud

culating

we

in

and

chose

Young

O.052in

and

Substituting

this

terms

pore

of

for

or pore

5.18b

value

overbalance

in

Eq

changes

relating to

pressure gradient

0.000666

of

this

value

rate

in

of

this

and

shale

at

the

shale

Evaluate

estimate

12000

the to

ft

line

the

density

increased

is

rate

in

from shale

12 is

to

20

moe

The

coefficient

be 13

Ibm/gal

BitFig

Diamond

Da

given

5.39a

BitFig

5.3gb

Rolling

Cutter

BitFig

5.39c

Roltng

Cutter

BitFig

5.36

Rolling

Cutter

BitFig

5.37

Rolling

Cutter

BitFig

5.41

Rolling

Cutter

BitFig

5.40

shale

-I

-2

000

500

OVERB4LNCErttlrttinn

hptwppn

rRnptrRtInn

rRtP

2000

2500

PSI lInt1

nvprhsllInci

fnr

by

106

a40.0520.00066635X

Drag

Fiq 5.42ExonenriaI

in

mud

penetra

rnIline

ri1tr

Fig 5.42 has

in

expected

ft/hr

is

a4

in

coefficient

change

5.18a

Soluiton

500

in

changes

0.052mD

-J

a4

rate

penetration

0.052mDg1

combination

the

coefficient

g/

gives

logR/R0

on

cir

equivalent

pressure gradient

Dp ge

expression

overbalance

of

replace

single

for

Example 5.6 The slope of

p1O.052

to

by

useful

is

expression

density

obtain

phh

effect

the

of

shale.22

in

logR/R0a4Dg This

line

overbalance density

rate

overbalance the borehole

tion If

and

of constants

rate

penetration

measurement

penetration

Bourgoyne

R0

100 PSI

PRESSURE

where penetrate

l6

bh-f- DIFFERENTIAL

5000

PRESSURE

DIFFERENTLAL

12

hit.

a4

for

penetration if

The

the

mud

current

226

APPLIED

Fig

5.43Typical

response

of

rate

penetration

to

bit

increasing

Fig

5.44Typical

weight

mud

and

R1

in

to

the

using

terms of

density

the

definition

initial

of rate

penetration

give

of

bit

tion

R0e2303a4DPp

weight

called

is

to

10a4g1p

R0

R1

rearranged

rate less

P2

sity

final

penetration

mud den

and

R2

rate

obtain

we

R0

R2

the

element

10

typical

tained

shown

a4Dgp2

02.3O34Dg

P2

with

linearly

the

for

equation

R2

the

by

R1

for

equation

tion

rate

to

gives

speed

R2

tomhole

p2

.3O3a4Dp1

Maurer25

for

the

final

penetration

R2

rate

tooth

R1

R2

Xe23O3a4P

r20

tO

t2OOOl2

7.60

13

ft/hr

to

effect

rate

has been

of

rate

other

vs

rate

is

Point

with

rapidly

values

of

bit at

However

at

in

weight

in hit

penetration

values

the

bit

values

weight

causes

Segment is

of

bit

ab

Segment

higher

rate

Fig

until

of

bit

observed

linear

curve

In at

slight

improvements

some cases extremely

wO

of

rock

bot

for

rolling

weight

rotary

equation

rate

to

bit

The

observation

was

equation

made

in single-

proportional

is

to

square

the

of

cutter

penetration

is

inversely

propor

strength

of

the

penetration

rate

is

given

by

5.19

proportionality

bit

often

be in in

decrease high values

The ing

and

theoretical

and

rock

weight and

relation

incomplete

experimental

weight

the

speed

theoretical

cleaning

bit

diameter

rotary

This

of

strength

weight

threshold

db

moderate

subsequent

rotary

efficient

penetration

the

Segment

less

of

where

weight

is

The poor

values

all

increases

for

weight

volume

cutter

conditions

bit

weight

of penetra

experiments

constant

bit

to

is

speed

rotary

diminishes

strength

following

significant

then

rate

the

rock

compressive

threshold

weights

only

cd

with has

No

5.43

the

of penetra

plot

constant

Penetration

moderate

rate

penetration

in

obtained

increasing

observed

crease

is

in

attributed

of

ob

increases

usually

high

--

penetration

experimentally

held

shown

shape

penetration applied

Typically

obtained

variables

drilling

characteristic

field

weight

on

speed

rotaty

numerous authors both

by

in the

bit

and

weight

studied

and

laboratory tion

bit

of

these

Conditions

Operating

The

the

The depth

For

the

constant

response

theoretical

and

crater

depth

tional

5.7.4

from

The the

size

impact

P2

at

penetration

relating

bit

derived

yields

held

values the

speed

rate

developed

bits

speed Solving

of

cleaning

R1 cutter

also

of

rates

speed

rotary

rate

low

rotary

vs

rate

speed

rotary

attributed

is

higher

penetration

variables

at

penetration is

at

often

penetra

bottom

hole

speed

of

usually

complete

Penetration

increasing

usually

increasing

of

response

weight

drilling

5.44

rotary

of

response

to

type of behavior

cleaning

penetration

other

all

Fig

in

bit

to

the

of

At higher values Dividing

or

into

plot

with

of

bottomhole

generation

cutting for

Similarly

high values

at

This

The poor

floundering

efficient

cuttings

de

Segment

bit

rate

penetration

speed

rotary

Eq 5.18b can be common logarithm

of

response

ENGINEERING

DRILLING

rotary

equation data speeds

assumes bit

of

tooth

Maurer can

obtained

bottomhole

perfect

penetration

at

corresponding

be

relatively to

us

verified

low

Segment

bit

ab

in

ROTARY

5.43

Figs the

DRILLING

value

5.44

and

weight

BITS

of one

than

At

exponent than

one

of

following

and

values

observed

is

of two

weight

indicated

of

the

closer

to

Eq

5.19

by

of

exponent

Bingham

on

weight

bit

be

to

predicted

weight

equation

drilling

laboratory

value

bit

is

usually

moderate

usually

the

At higher values

227

EA

the

The

K_ 4/

the

constant

of

rock

of

and

the

is

a5

includes

that

proportionality

strength

bit

be

to

and

negligible

constant

used

in

data

showed

the

hc

equation similar

of both

bit

and

the

values

of

data

field

the

bit

which

changes

in

evaluate

the

to

ponents

from

made

various

at

speed

observed

the

be

as

in

to

the

increased rate to short

very

bit

rate

penetration and

0.4

make

the

speeds

rotary

many

weight In

manner

bit

law

brake

the

bit

of the

the

maintain

from

has

drillstring

and

response

the

in

hook

penetra

be determined

the

lock

that

the

in

change

over

stress

is

test

change

case

of

equal

divided

by

change

in strain

per

unit

the

length

axial to

the

tension change

in

in

cross-sectional is

equal

to

drillstring bit

area the

Thus Hooks

weight of

change law

the in

the

axial

becomes

The length

of

bottomhole the

following 26

U.S.A

pattern

before

test

per was

procedure

recommended

prac

run

increase

in

the

bit

the

drilloff

usually with

the

bit

time required the

to

to

initial

be

time

bit

value

of

weight

the

20%

least

at

off

drill

characteristic

the

use

in

currently

should

the

over

section

expected

the

value

weight

where

weight

weight

initial

is

bit

called

is

test

shale

in

currently

use Drill

new

one

usually

time

lbf

the

If

the

of

midpoint

until

test

rotary

curred second

The

of

of Ar

weight

bit

rotary

weight

off

falls

the

use

fluctuating

weight Continue

bit

the

to

the

initial

bit

or

occurs

is

has

weight

observed

was

the

in

in the

initial

using

should

the

test

log-log

having

Deviation bit

from if

weights

in

the test

use

initial

If

at

different

behavior

nonlinear

second test

result

hit

impending

repeat

floundering

bit

vs

or plot

weight exponent may occur at high

bit

behavior

speed

vs

straight-line

time permits

weights

is

the

as

50%

least

plot

straight-line

no

higher

test bit

at

use

rotary

high

floundering

rotary

speed

bit

lower

in

oc the

test rotary

penetration at

fluctuations

paper

If

indicator

bit

characteristic

in

bit

is

in

constant

the

the

off

Make

speed

weight

at

drilled

If

time

increase

the

increase

maintain

time each

the

establish

time allowed

10%

per

20%

to

The

of twice

interval

and

enough

bit

the

time

for

brake

the

Record

4000

but

used

be

Lock speed

of

characteristic

would

time

long

weight

pattern

weighte.g

the

bit

this

at

bottomhole

stress

tension

drilipipe drillpipe

The

determine

This

floundering

is

and

Increase

graph

5.21 the

and

small

also

is

the

weight

test

weight This

this

slope equal

For

establish

bit

to

drilling

drilloff

directly

strain

in

to

lithology

brake

the

been

change

collars

drill

Chevron

depth

While

then

elasticity

decreased

can

weight

monitor

and

time while law

large

interval

states

to

proportional

applying

amount

the

compute

this

the

with

Hooks

speed

changing

of

locking

weight

on

depth

Hooks

then

consists

the

initial

drilloff

uniform

it

ex

measurements In

5.22

of

be taken the

at

Select

of

while

speed

rotary

gives

tice

ob

from

can

depth

and

to

0.95L

by

At

change

must

the

adapted

2.0

contribute

not

Replacing

ignored

en

exponent

range

with

weight

test

bit

rotary

applied

stretched

tion

bit

weights

and

bit

decrease

constant

load

bit

drilloff

to the

weight

can

of

penetration

to

do

essentially

of

area

......._

length be

forming

lithology before the tests are com may change To overcome this problem be drilloff rest can

performed

ing

The can

the

pleted

change

cross-sectional

AW

varied

exponent

0.6

exponent

lithology

of

series

and

5%

about

over

upsets

greater

observed

0.95

Care

both

was

type

weight

from

range

prevail

be

joint

much

pipe body

length

10% of

Frequent

ing

the

the

development

could

rotary

the

the

speed

rotary

difficult

cases

than

tool

have

the

0.9

to

that

his

rotary

the

in

formation

from of

the

system

and

weight

and of

speed

new

Values

from

equation

LW

off

drill

to

in

change

this

Ar

has

drillpipe

length

Seg

by

proposed

representative

rotary

bit

have

exponent

control

computed

response

tained

some of

described

has pioneered

when

and

automatically rate

weight

drilling

weight

countered

13

Young

systematically

the

was

of one

though

that

authors

bit

using data

computerized

the

even

be

conditions

exponent

to

must

exponent

prevailing

its

EA

several

recently

exponent

of

the

speed

rotary

behavior

conditions

ing

weight

for

was assumed

weight

bit

Fig 5.44

in

More

bit

Bingham

determination speed

the

experimentally

However

ment

threshold

the

equation

determined

for

dividing

by

required

EA

At

Range

this

.it

interval

observed

obtained

weight

exponent In

time

the

by

be

5.20

the

is

effect

Wcan

weight

rate

penetration

average

bit

where

gives

of considerable

data

field

AL

for

expression

less

suggested

basis

this

Solving

the

speed

rates

same

bit

can

exponent

obtained

weight

at

two

be

different

obtained rotary

using speeds

228

APPLIED

TABLE 5.10EXAMPLE

DRILLOFF

TEST

ANALYSIS

N100

______N150 Average Weight

Bit

1000

Bit

1000

Ibf

Elapsed

Elapsed

Time

Weight

Time

seconds

lbf

ENGINEERING

DRILLING

seconds

seconds

ft/hr

seconds

ftlhr

54

16.6

60

14.4

76

74

52

72

16.6

52

54

70

53

68

16.6

105

114

66

55

64

66

15.7

160

62

58

60

14.9

218 63

71

80

90

104

8.3

626

nent

the

bit

10000 5.275

Assume

ft

sq

and

the

in

that

120

at

has

bit

the

rotary

time of

for

steel

weight

is

rotary speed

test

speed the

cross-sectional

modulus

threshold

No

Test

and

exponent

drillpipc

drilloff

following

drilipipe

Youngs the

132

6.5

7.2

746

the

weight

The length of

7.4

773

The

Solution

evaluate

116 641

38

Using

8.6

9.6

522 42

5.7

101

525

46

Example

9.6

10.8

432

36

90 424

50

40

10.7

12.2

352

44

81

334

54

48

11.8

13.7

281

52

73

253

58 56

13.1

180

is

data

Eq

rate

penetration

be

can

evaluated

using

5.21

expo

test

LW

was

area of

0.95

EA.

30x 106

zero

10000

rpm

150

4000

0.95

0.24

301065.275 Bit

Weight

l000 ibm

Time

Elapsed

seconds

we

If

76 72

52

68

105

64

160

60

218

56

281

52 48

44

36

this

No

rotary

352

The

432

pression

drilloff

Weight

000 ibm

746

drilloff

100

Elapsed

rpm

Time

seconds

76

tion

1.6

The

54

For

114

served

60

180

of

150

between

for

48

525

44

641

40

773

bit

rpm in

bit

vs

from

in

this cx-

using

5.45

weight

lines

can

of

Reducing

the rate

rate

Kl50ah

of

10.7

be the

5.45

Fig

por

of

1.6

approximately

flounder

evaluated

lbf

rotary

of

in

value

parallel

58000

penetration

of

straight-line

is

the

be

the

penetration

can

done the

exponent

in

weighl results

yields

below

weight

bit

the

been

slope of

exponent

have

average

has

the

Fig

bit

RKN 13.7

This of

weight

we

evaluated

paper

on

the

example

weight Thus

334

424

of

speed

resulted

56

line

observed

253

52

and

864

been

rate

log-log

analysis

values

rotary

68

have

evaluation

either

the

for

spacing

on

test

of

72

64

hour

per

10

Table

of penetration

plot

constructed

Thus Bit

seconds\

data

test

in

626

speed

feet

becomes

hour

Graphical Test

of

units

expression

/3600

0.24

522

40

in

express

seconds

region

from

the

region 13.7

and speed ft/hr

ft/hr rotary to

at

the

100

is

ob

speed

rpm same bit

ROTARY

DRILLING

BITS

229

20

30

40

50

60

70

80

00

lbf

5.45Example

Fig

drilloff

test

analysis

and

a6

K100

10.7

where

constant

the

is

speed

rotary

the

Dividing

of proportionality

and

the

is

a6

exponent

13.7

top equation

the

by

bottom

equation

gives

Fig

150\

view

5.46Cutaway

of

extended-nozzle

bit

27

l00

10.7

the

Taking

of

logarithm

both

and

sides

for

solving

a6

HYDRAULIC

PARAMETER

yields

log13.7/10.7

a6

LEVEL

0.6

log 150/100

In

this

example

below

zero

may

be

from

the

it

weight data

If

best

by

Bit

Most

tend

to

of tooth cutter

rolling

As

teeth

altered

to

process

However does teeth fail

tooth

fimr

slower

is

invert

The

is

by

as

the

bit

can

be the

gives

in

or

self-sharpening

while

tends

tungsten

lost rate

for

carbide rather

when due

than

to

the

keep

Section

by

reduced

by abrasion occurs

tooth

bit

and the

tooth

wear

pointed

rolling

bits

cutter

Often

the

entire

Reductions as

it

The

length

5.47Expected penetration

case-hardening

wear usually are not fr nid1d I-r-.th ht .rt to

Fig

tooth

5.3

type of tooth the

insert-type

breakage

run progresses of milled

by abrasion

continually

discussed

hardfacing

this

bit

length

promote

hit

it

that

It

the

plotting

known

value

the

tooth

reduced

previously

by breaking

penetration

as

threshold

before not

is

weight

bit not

is

db

drill

not compensate of

the

error

wear

bits

chipping are

subtract

column

weight

Wear

Tooth

bits

because

bit

fit

straight-line

5.7.5

bit

and

trial

threshold

threshold to

bit-weight

obtained

was

the

assuming

the

necessary

threshold

the

determined

fit

straight-line

region

zero When

was

weight

good

flounder

the

in

severe

relationship rate

between

bit

hydraulics

and

APPLIED

230

ENGINEERING

DRILLING

100

80

GL./MIN

DIAMETER1in

60

/8

/4

3-1/2

40

10-1/2

20 Iii

co

10

0E3

0000 -J -J

WI000LB

NZ75RPM 500PSI

Pf

ii 0.06

ii 0.2

0.1

0.4

0.6

Fig

number of bits

also

from

teeth

the

broken

are

from

fail

5.48Penetration

tooth

the

during

as

of

loss

diamonds

authors

for

computing

for

rolling-cutter

the

have

mathematical

published of

effect

tooth

bits Galle

model

following

wear

on

Woods

and

is

and

value

less

the

the

fractional

a7

is

an

of 0.5

tooth

complex

the

for

exponent

hits

tooth

the

Rourgoyne and Young based on

0.75a7

recent

similar

but

the

Taking for

a7

with

tooth

wear

for

_______

that

the

decline

previous

bits

of penetration

run under

similar

5.7.6

The

in bit

was

under

Solution

the

The

to

the

of

bit

in

However same

the

If the

approximate

of

of

bit

bit

and

was The was

rotary

of

rate

formation

shale bit

run

weight

drilling

previous

value

ft/hr

bit

current

same conditions etc

of 20

rate

beginning

identical

the

the

penetration the

at

speed mud density tt/hr was Observed pulling

that

be

was graded

12

just

most the

of

for

the

previous

of

used

with

ilist

before

jet-type

bit

the

an

cutter

bits

in

as

well

as

the

the

are

jets

Fig 5.46

extended-nozzle

bits

to

action

bits

brought center

jet

prevent

at

better

bottom Some

jetting

using extended-nozzle of

rate

action

promoted hole

the

that

1953

penetration jetting

action

presented28

ends

in

improved

jetting

teeth

when

hole

rolling

improvements

through

been

discharge

closer

to

must

also

bit

is

which

in

the

be in

balling

formations

soft

As

discussed

siderable

hit

the

has

of

the

improved

effective

bottom

T-6

a7

of

The

evidence

to

value

solving

0.68

significant

achieved

bit

cleaning

shale

and

Bit Hydraulics introduction

the

initial

sides

a7be

exponent

observed

could

An

both

0.75

showed

Example 5.8

of

logarithm

ln20/12

conditions

compute

natural

gives

by

suggested the

yields

07

5.24

determined

second

the

by

primary

more

In

suggested

given

relationship

the

equation

first

12

publication

Young5

and

the

Dividing

17/i

xe

before

5.24

75

a7

Ke

20

was recommended

Bourgoyne

worn

has been

that

height

exponent

in

operated

Eq

as

given

a70

Ke

20

12

wear of milled

previous

relation

and

type discussed

observcd

for the

Ke

a7

rate

Thus

zero

is

5.23

self-sharpening

work

number.25

have

rate

published

6h

0.928l25h2

for

bit

we

models

penetration

a7

bit

new

150

K---

Reynolds

bit

100

1963

in

Rc

away

of

40

matrix

Several

where

FUNCTION

function

run Diamond

bit

or

breakage

NUMBER

rates

20

10

1.0

REYNOLDS

Ii

II

use

previously

uncertainty in

as

characzing

to

in the the

Chap best

there

hydraulics

effect

of

is

con

parameter

hydraulics

on

ROTARY

DRILLING

BITS

231

100 INDIANA

P-

LIME

500

Pf

ps

00

75

00

rpm

Lii

20

1.25

or

SHALE

MANCOS 7.875IN

F-3

SMITH

30

BIT

K-LBF

N60RPM

Lii

10

2000

.5

PSI

Lii

.5 Lii

a-I

lii

II

liii

II..j_.j_J Lii

100

10

NUMBER

REYNOLDS

LU

FUNCTION

pvd

8910

1976

observed

Fig 5.49Experimentally

Reynolds number

The by

to

behavior tion

often

and be

the

at

of

and

weight

bit

JETS

IN

JETS

THREE THREE

10/32

IN

JETS

11/32

IN

40

30

80

5060

NUMBER

JETS

100

FUNCTION

bit

thought

is

bit

the

to

date

level

of

of

Shown

made

the

in

2o

MANCOS

SHALE

.87INSMTH

..-

F-3

HIT

to

the

bit is

and

as

most

rate

in

is

be

will

found

that

a8 Z7

THREE

7/32-IN

JETS

THREE

9/32

JETS

-IN

0/32-IN

THREE THREE

JETS JETS

11/32-IN

I4 LU

15

30

25

40

50

60

HYDRAULIC

JET

80

00

300

200

ISO

HORSEPOWER

400

tHP

laboratory

penetration

rate

bit

constant

penetration

number group

20

drill

laboratory

extensive

at

10

Lii

in

between

LU

quickly

hydraulics

penetration

cut

reached

occurs

the

Reynolds

penetra

hole clean

point

of

level

Working

Eckel

speed

to

of

type

and for

removed

not

microbits

relation

the

weights

required

applied

and

weight

hydraulics

correlated

the

with

has

bit

are

floundering

working

rotary

If

of

flounder

cuttings

bit

bit

is

faster

the

higher before

machine

the

At low

generated

Eckel28

study

bit

IN

9/32

rate.28

example

As more weight

are

creased

ing

of

point

of hydraulics

level

generated

reached

achieved

flounder

reported

the

are

they

effect

penetration

hypothetical

eventually where as

25

7/32

THREE

IS

small

is

the

is

rates

tings

on

hydraulics

affect

5.47

Fig

ing

of

level

many

20

REYNOLDS

THREE

and

weight could

rate

given

by

2O

vd

NRC

5.25

MANCOS 7.875

SHALE -3

SMITH

IN

81T

W30 KLBF 60

Li

bhf

RPM

2000PSI

where

flow

ID

constant

scaling

zB 27

density

drilling

rate

nozzle

diameter

apparent

and of

viscosity

fluid

drilling

10000

at

II

seconds Lii

shear

of

value

convenient

The

creased the

of

full

of

is

was

present

the

in

somewhat

was

used

chosen bit

and

to

by

increasing

shifted

upward

flounder

the

of Reynolds

as

shown

that

function

the

shown

correlation in

was not

point

number

numbers studied

for

given is

Fig

5.49

studied drilling

maximum when

maximum spp Char

When

curve

by

The

fluid the

the jet

the

Fig

5.50Effect

bit

behavior

at

can

be

It

Reynolds

impact

of

hydraulics

force

tions

using

eter

and

force

as

bit

penetration

LBF

using

hydraulic

hydraulics

power

number

observed as

correlation

parameter

Mancos

in

conditions

Reynolds

parameter

observed

rate

borehole

simulated

correlation

observed as

on

hydraulics

under

shale

for

was

simply

Eckel

FORCE

8001000

but

number function

Reynolds

600

yield

tion

range

IMPACT

II

1_Il

400

nozzle

arbitrary

by Eckel

300

200

150

as

of the Reynolds number group Eckels experiments are summarized in 5.49 Note that penetration rate was in

was increased

is

rates

1/1.976

weight

the

seconds

range

results

5.48

shear

constant

scaling

constant

10000

of

rate

representative

Figs

100

JET

The

The

80

hydraulico using

jt

func

correla

param impact

232

APPLIED

5.7.7

Penetration

The manner have

been

only

ment of

an

drilling

models have

possible

of

achieve

POINT$

ON

BIT

FACE

the

best

bit

cost

Diamond designed

bits

such

is

the

at

bit

drag the

as

well

ideal

that

the

design

for

bit

is

given

formation

kept

rate

cutting

is

given

to

in

authors

bit

models bits

rate

of

element

cutting

in

by

heN

LPefl

per

forma

the

penetration

the

are

and

weight

into

feeding

of

cost

drilling

penetration

the

5.26

where effective

penetration

effective

number

Peterson30 effective

ii

Lp

for

diamond

The of

MATRIX

as

which

has

bit

area

removed

DIAMOND PENETRATION tLpe

The

tL

PENETRATION

The bit

Stone

layout

after

tRef

equation

assumed

in

is

spite

of

5.48

and

Figs

applied force

in

the

5.49

practice

more

are

Hydraulic

the

between

Recent

obtained

periments tions29

similar

bit

29

under that

the

and horsepower when used to on

obtained

obtained

full-scale

results

hydraulics tions

shown

in

penetration for

each

Mancos

in

shale

not

Reynolds

jet

impact

correlate

the

Fig 5.50

these

with

been

are

by

diamonds

laid

and

jet

drilling

borehole

spherical

in

shape

so

that

shown

as

are

spaced

stone

the

maximum

is

7.875-in

Fig

cross-sectional for

is

at

operated

the

design

bit

hydraulics

are

sufficient

for

conditions

the

effective

number of blades

effective

0h

the

design

depth

perfect

penetration are

given

of

bot

Lfl

and

by

S.27a

and

5.27b

of rate

where

ex

condi

all

of

shows

parameters

in

cleaning

concentration

number group force

as

impact

penetration

effect

out

widely

development

laboratory

simulated jet

rate of

the

and

hydraulics

in

conducted

has

hydraulic

bit

has

in

presented

horsepower

used

frequently

correlations

data

Eckels work

the

S.Sla

Fig

per

bit

For these

penetration

30

correlation

convincing

to

perpendicular

0.67 In

for

penetration

tomhole

rate

that

the

of penetration

depth

EFFECTIVE

S.51Diamond

for

equations

number of blades

5.51

AREA

FORMATION

Fig

effective

face

formed

is

in

The diamonds

DIAMOND

theoretical

and

The equations were derived assumed the following

flat

blade

shown

The stones FLOW

element

cutting

and

hole

the

Each helix

L1

bits

model

simplified

axis

has developed

penetration

FORMATION

each

blades

speed

rotary

DIAMOND PENETRATION

of

of

jet

give

Smith

data

F3

diamond

cutters

depth

of

penetration

of each

stone

in

bit

correla

using

actual

of

in

carats/sq

bit

diameter

in

in

diameter

average

of

the

face

and

diamond

size

carats/stone

stone

it

the

speed

rotary

types of drag

The

penetration

make

Many

maximum

conditions

known

the

mathematical

other

as

given

Under

revolution

tion

approximate

achieve

to

torque

these

and

foot

reductions

significant

use of

rotary several

methods

weight per

develop the

models

optimization

minimum

the

reported

through

to

selecting

the

combine

These

that

com

quite

However

to

attempt

proposed

formal

is

of

riiodel

possible

15

have PLOTTING

that

been

apply

to

problem

yet

rate

Thus

understood

not

variables

drilling

penetration

mathematical

is

process

mathematical

important

affect

partially

ENGINEERING

Equation

the

accurate

relationships

to

which

in

discussed

and

plex

Rate

DRILLING

cutters

ROTARY

DRILLING

formation used

is

design

called

property

the

compute

to

233

BITS

needed

allowing

the

to

stone

formation

weight

The

penetration

pressure

the

bit

formation the

penetrate

the

to

obtain

to

required

overcome

taken

resistance

resistance

the

is

formation

the

strength

of

dependent can

on

the

that

rate

rotary

in

all

are

effect

composite

of

computed using an equation

be

weight

bit

penetration

and

another

one

of

effects

the

etc

wear

tooth

speed

that

assume

to

is

form

the

rock

R1f2f1J..

5.28a

We

5.27c

r1

where the

Ad

and

from

For

of

given

is

area

rate

the

after

with

contact be

can

bit

ac

into

taken in

after

bit

computed is

operated

interest

stone

spherical

been area

resistance

penetration

formation

in the

tact

observed

an

have

diamond

total

The formation

formation

the

the

is

to

applied

weight forces

pumpoff

hydraulic

count

effective

the

is

shown

as

Fig 5.51b

in

con

the

by

f1

tions

between

f2

variables based

on

__ deLp Lx

5.27d

fitting

Some

tions

been

drilling

variables

defined

by

model

that

posed of

An

rate

penetration formation

tained

of

could

that

at

be

most

has

been

270

containing

bit

to

carats

is

designed

of 0.01

in

Estimate

the

this bit

the

obtained

with

if

tion

The

fined

are this

for

torque rotary

speed

Ignoring

the

such

bit

acceptable

could

penetration

200

of

an

that

hydraulic have

to

and

action

face

flat

bit

contouring protection

gauge

that

is

for

required the

bit

to

the

perpendicular

is

proper

functions

Eq

5.28a

model

the

15

pro

of

most

previous

model

of

sec

de

be

can

functional

following

the

the

is

They

effect

the

in

drilling

with

bits

cutter

Young

and

to

drilling

mathematical rolling

discussed

variables

5.28b

f3e

9.0

5.28d

Pc

2.303a4Dg

f4e

the

5.28c

D69g

assumed

axis

the

model

Bingham

2.303a1O000D

f2e

rpm

of

three

or

fie

main

be

ex equa

relations

2.303a

Solution

for

Bourgoyne-Young

by

two

the

is

complete used

Bourgoyne

by

eight

drilling

curve

mathematical

only

example

func

the

used

5.20

the

using

the

An

have

2.303u

characteristics

and

weight

stones

1.75

of penetration

depth

at

diamond

8.625-in

0.23-in-diameter operate

Eq

model

field

mathematical

simple

that

are

or

define

to

others

empirical

relatively

used

drilling

usually

laboratory

chosen while

obtain

to

techniques

pressions have

have

graphically

model proposed

s1

Example 5.9

authors

relation

chosen

either

in

vanous

and

rate relations

observed

trends

Some

studies tional

functional

rela

Ilinctional

the

represent

penetration

The

Perhaps

ir2dj

etc

where

dt

5.28c

Thus

hole

270

4.621

in

stones/sq

The

dh1t

_I

Sd

5.2Sf

J51 number of blades

effective

0be

1.92

is

given

by

4I dht

5.27b

Eq

db_L

5.28g 60

Sd

5.28h

f7ea7

1.924.6218.625X.J3O.Ol_O.OI2 3.59

5.28i The

effective

is

penetration

0.670.0l0.0067 The penetration

rate

at

given

Eq

by

000

5.27a

in

rotary

In

speed

of

200

mm

these

tmc is

0.0067

pore

Pe

equivalent

W/d/

3.5960X200

threshold

weight

at

per

which

1000

drill

ft

ibm/gal density

circulating bit

diameter

the

inch bit

of

bit

begins

to

lbf/in

ft/hr

_________________________-

Penetration proposed

rate

by

equations various

for

authors

rolling

cutter

bits

The approach

have

usually

to

a8

dullness

fractional

tooth

hydraulic

impact

lbf

been

depth

pressure gradient

g1

12

24

well

veffical

given

by

RLpeflb.N

equations

constants local

force

beneath

the

bit

and that drilling

must

be

chosen

conditions

based

on

234

APPLIED

The

constants

prior

data

drilling

used the

both

obtained

prior

of

changes

used the

data

both

for

primarily

ft

and

strength

pore the

on

type

it

in the is

forfj

nique

when

useful

presented

obtained

data

allows

the

common cludes

of an observed

discussion

pressure from

pore

The

rock

and

depth

the

function

compaction

experienced

tions

that

Note

pore

of

The

10000

to

value

of

diameter

andJ

rpm

This

would

have

The

tions can

be

where tent

has

has

value

bit

in

formations

are

the drilloff

weights

The

function

5.7

The

values

of a6

penetration

rate

and

at

end

of

run

bit

tungsten moderate often

Typical to

1.5

has

carbide hit

as

values

the

weights

of a7

and

The

tion

of

under

normal

new

bit

zero

and

for

at

lhf/in

the

the

observed

of

drilling

the

in

the

various

data

obtained

the

of

ft

drilled

penetration

of to

the

the

frma

penetra

formation

given

with

operating

of

depth

formations from

4000

of

weight

and

rpm

in

value

as

equal

when

average

types

being

units

bit

of 60

best

drillability

numerically

be

the

the

same

the

in

as

rate

0.6

to

formation

the

with

number

formation

the

overbalance

drillability

using

0.3

select

compaction

speed

rotary

The

ft

puted

10000

com

be

can

previous wells

in

area

Example 5.10

40000

ff

are

small

rotary

which

low

0.5

using

be

be

and

a6

Solution

The

functional

by

Eqs

5.28a

through

for

the

from

the

in

speed can bits

When

operated

tooth

be range

mud

to

jet

on

density

impact

force

computed

fractional

apparent

formation

of zero and

weight

the

a8 a5

a6

a7

a8

0.00003

1.0

0.5

0.5

0.5

normal

throughf8

relationsf2

decrease

in

of

are

The multiplierf2 penetration

10000

with

rate

given

accounts depth

ft

2.303atO000D f2 0.000

t2.000

0.724

The multiplierf3 rate

due

to

accounts

for the

increase

in

penetration

undercompaction

D9g

_9

2.3030.000005

1200069t2 1.023

beginning

wear

and

ft/hr

from

Example 5.8

tooth

15

a4

5.28h

reference depth

trma

similar

at

bit

through

a1

wear on

estimated

in

the

threshold

0.000005

2.303 tooth

the

Compute

of

equivalent

bit

Example 2.0 and

to

rate

is

at

formation

shale

computed and

lbf

operated

bit

in

equivalent

The

of a2

a2

.0

of

used

in

the

limit

must

as

as

to

zero

tooth

0.3

values

0.00007

be

upper

tests

can

milled

drillabi1ityf

and

1200

is

is

tooth

drilling

penetration

at

Ibm/gal

bit

milled is

pressure gradient

2.3030.00007

from

term

and

coast

can

very

at

12.5

the

more compe

an

0.4

this

condi

weight

mud

wear

tooth

ft

pore

Ibm/gal is

rpm

12000

formation

beneath

of

product

gulf

In

of

80

speed

rotary

quite

previously for

is

9.875-in and

lbf/in

depth

at

has

U.S

taken

.0

zero

Ibtiin

the

conditions

bits

and

that

of

is

would

rate

type

of impact

penetration

However

called

is

drillability

tion

to

for

expressed

is

from

interest

commonly

choice

weight

often

effect

of a5

bit

thatf5

The constants

from

shown

insert

insignificant

strength

12.0

on

for

drilling

point

range

operating

value

the

has

measurements bit

The termf7

a5

value

that

drilloff

range

The

similar

with

following

4000

of

bit

f5

tests

models

rate

and

pressure

of

Note

terminated

from of

effect

soft

flounder

drilloff

function

varies

rate

the

value

be obtained

affecting

a8

of

the

or nozzle Reynolds

range

interval

The termf1

normali7ed

could

results

prudent

depth

The

for

well

for

as

relatively

bit

values

penetration

tions

the

from

Reported

reported

1.0

.0

pore

1.0

is

such

of

of

common

for

tests

be determined

can

of

threshold

from

to

the

weight

estimated

also

forma

to

overbalance

the

rate

so

1.0

areas

of value

value

chosen

formations

established

with

9.0 lbm/gal

to

in

model

near

a8

is

through

the

as

for the

of under-

effect

equal

effect

pressure

was

a2

with

on

hydraulics chosen

compac

compaction

formation

W/d1

threshold

corresponding

of

pressured

is

has

penetration

value

neglected the

the

andf6 on

60

bit

of

product

the

when

when

1.0

in

formation

accounts

the

equivalent

bottomhole

speed

rotaly

of

effect

abnormally

This function

The functionsf5 and

models

models

rate

the

which

of

bottom

overbalance__i.e equal

The

rate

ft

function

penetration

the

normal

the

J3 in

pressure gradient

depth

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f7J

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mation

this

t64l5.7O.2S2_

1.16

foot

cases where

with

can

can

using

drilling

few

rapidly

This

cost

For

Eq

using

the

give

wear

bit

wear

timum

into

J2

com

computed times drilled

foot

per

will

decreases

lower

and

TH

15.72---

the Compute The procedure

life

of

gives

4d6

the

would

that

values

the

Us

0.250

of

12b

/60\1.84

the

5.31

and

value

Eq

1.0

teeth

5.16

and

has

J2

of

J27H

Substituting the

out

dullness

tooth

yields

time required

footage

speed

rotary

60

and

final

ing

5.12

and

smaller

the

and

.84

4d11N

the

used This

Bourgoyne-Young penetration rate are used the following procedure

weight

the

5.15

Using

ly

forms be

can

calculation

time required

the

Compute

pute

average

integrated

/60\

for

used

be

using

the

wear models

Assume

using

the

the

during

single

wear models

tooth

number of

the if

use of

the

possible

is

drillability

penetration

may be encountered

that

when

run However

bit

ENGINEERING

DRILLING

gives

com is

22

yields

ROTARY

DRILLING

BITS

W/db

For

and has

the

both

have

functionf6

the

weight

value

of

failure

at

function

0.90.974e 1.0

drilled

before

tooth

15.7 hours

is

The

cost

/DJiJ2rH

a7h1

bit

Eq

will

Note

be

tail

5.32 Solving

first

When

1.0

above

the

the

the

final

tooth

value for

equation

dullness

fail

bearings

known

for the

compute h1

given

first

of

zD

that foot

per

09

0.9e

than

greater

maximum

the

possible

bit

____________________________

wear

____________

0.9

slightly

the

we obtain Relatively

09

is

to

is

it

constant

61

foot

per

corresponding

using

tb

simple bit

Bourgoyne

le

this cost

life

D26.70.250l5.7

246

is

547.69/ft

a7h1

a7hfe

to

to

time

238

a7h1

teeth

known

is

drilling

400500150.46.5

cost

necessamy

of

hours

15

Cf _________________

a7

hf

after

a7

H2

the

ft

by

le

Since

foot

per

5.31

Eq

238

-o.9o.974/092

thus

26.7

of

value

by

60

and

rotary

The footage given

239

can

limits

be

0.92

and

weight and bit

speed

for

the case

life

Eq to

rearranged

1.16

the

in

best

the

derived

were

rotamy

Young15

for

expressions

analytical

by

tooth

which

equation

cost-per-foot

give

CfCbtftCtb Cr

ft

iD

This

footage

at3 minutes

drilipipe tion

time

to

corresponds

approximately

The

per connection

of

joints total

connec-

is

this

i8O.4

Eq

Substituting

5.12a

for

formula

cost-per-foot

tb

Eq

and

5.31a

LD

for

in

yields

hours

60

The

cost

foot

per

for

the

bit

run

given

is

by

Eq

1.16

Cr

Cf

h1

Cf

Crtb

Cb

40050015.70.46.5

Cr _______

______________

7hh

J1J2TH

lH2hdh

547.56/ft 246 This

the

is

ending

the

minimum

cost

run

cost

assumed

speed

per

should

foot

be

cost

predicted bit

just

per

per

before

foot

for

However

to

after

15

hours

from

Eq

5.32

For

the is

the

final

bit

ensure

example

given

that

failure

to

corresponding

checked

foot

bit

tooth

corresponds

and

slightly the

dullness

usually

and

weight that

if

is

this

is

bit

bit

the life

Taking

3C/

and

solving

yields

was pulled

as

computed

rr

by

________________

Cb

__ H2J2T 2tb

H2

rotamy

true

shorter

to the

___________ _____________

maxII

__________ 215

0.974

asJ2rH1H2hdh

5.33a

60.25l5.7 The

footage

drilled

for

this

value

of

h1

would

D26.70.25l5.7

be

Taking

and

dCf/dN H1

Cb l

Cr

0.90.974

0.9o 974

a6

solving

JT

yields

H2 hdh

240

the

gives

two equations

these

Solving

following

optimum

for

W/d6

for

simultaneously

expression

than

weight

must

flounder

be

obtained

is

weight

bit

the

greater

used by

the

Eq

equation

the

flounder

5.33a

or

Eq

time of about

-1

is

16.1

0.6

optimum

can

speed

rotary

hours

be

calculated

Eq

using

5.36

bit

bit

71/H

maxopt

5.33b

_____________

N0160

_l H1

Cr

d/

5.35

a6

The

optimum rotary known value of t1 in

Eq

then

from

be

can

this

The optimum

optimum

either

solving

by

weight then

bit

for

C5

the

predicted

lH2hdh

foriTH

to

connection

/1.84

500

5.34

time and

trip

i400

The optimum

the

life

ENGINEERING

obtain

06

aH1

opt

total

hours we

a6_ max

d5

Assuming

weight

bit

If

a6Hi If

DRILLING

APPLIED

speed

obtained

following

obtained

is

5.12b

and

for

expression

Il This

Eq

using

using

601

the

for N1

solving

36

rpm

NON Since

1W

the

computed

used

for

optimum

use of

optimum

the

point

d5t01

the

point

computed

d6max

/1.84

8_6.4

leads

flounder

N0160I

max

the If

justified

above

is

below

is

is

05

the

flounder

the

occurs

should

reported

from

floundering

bit

optimum

weight for

weight

which

at

weight the

hit

1.2

be

weight

max cost

Significant

have

savings

held use of mathematical

5.36 for

Unfortunately

sions

and

the

where

case

wear or penetration

bearing

for the

the

optimum

construction This

approach complished

life

such

calculation

is

limited

simple

have

not table

cost-per-foot

of

type

using

conditions

of

bit

rate

is

expres

been is

most

by

found

the

best

easily

ac

computer

digital

timum

bit

niques

should on

vision

made rate

the

equations

optimums

to

of

rotary Bit

/3

speed

for

floundering

above

6700

Compute the

was

lbf/in

bit

the

optimum

run described

observed at

60

to

in

occur

bit

weight

5.12

Example for

bit

and

weights

rpm

can

their

supervision of

range one

bit

The optimum

bit

is

weight

computed using

Eq

5.34

manufacturer

bit

bits the

guidelines

and

judgment

asHi___

max

a6_

5.1

List

the

two

list

discuss

dull

5.2

the

diameter

bit optimum The optimum

35

weight

is

bit

is

life

6400

lbf/in

computed

of

using

bit

Eq

List

i4 5.5

The

bit

performance and

activity

engineering normal

the

recommended

12

experiment

by

insert-tooth these

Using his

using

own

evaluation

of each

how

cutter basic

in

Discuss

bits

the

the

in the

in

use

offset

today Also

basic

considered

between

bit

ideal

type and

for

the

ap

given

tooth

height

soft-

and

number

and

hard-formation

bits

mechanisms of rock removal

in the

the

bits

of each

subclassification

cone

differ

five

Discuss

used a6

example

Table

in

can

conditions

the

employed

used

Cr

when

speeds

two main types of

teeth

rolling

5.3

Thus

Discuss of

6.4

.840.6

1.21

shown

bit

drilling

journal-bearing

subclassifications

plication

1.21 848.0 0.60.5

is

For

rotary

for

driller

of

driller

be

com

the

acceptable the

is

run can

bit

Exercises

a5H1a6

opt

and

weights

rolling-cutter

Solution

available

not

is

the

computed

supervision

between

evaluating

areas

for

guidelines

is

are

various

the

in

deviation

the

penetration

the

engineering

results

constantly

bits

furnish

that

ensure

and

results

super

assumptions

and

progress of each

observed

manufacturers

Example

the

field

the

wear

tech

these

engineering

instances tooth

When

not valid

in the

and

puted

many

wear

inaccurate

yield

are

monitored

In

the

op

the

obtaining

However

without

applied

bearing

for

speed

rotary

be

not

location

in

present

and

weight

been

methods

design

primary design

mechanism

of drag

primary design

that

are

of bits of

rock

removal

of

rock

removal

bits

mechanism

of hard-formation

rolling

cutter

ROTARY

DRILLING

BITS

241

TABLE 5.12.RANGE OF BIT WEIGHTS BY ONE MANUFACTURER

RECOMMENDED

lNSERTTOOTH Bit

Size

in

Weight

Bit

8/4

to

97/s

12

_j__

Shales

517

7/a

Speed

lbflin Soft

81/2

ROLLING

and

Clays

Salt

6/4

BITS

Speed

rpm

lbf/in Unconsolidated With

Soft

Sand

55/90

2500/4700

40/60

55/90

2500/4800

40/60

1500/3700

55/90

2500/4800

40/60

1500/3600

55/85

2500/4500

40/60

and Medium-Soft

Limestone

Weight

Speed

_iE

Ibf/in

Shale

1500/3600

Shale

Bit

Streaks

1500/3500

Medium-Soft

Rotary

Rotary

Weight

Bit

Soft

537

Class

SPEEDS

JOURNAL-BEARING

FOR CUTTER

Rotary

Range

Class

AND ROTARY

and

Dolomite

Unconsolidated Soft

Lime

Shale

and Sand

2400/3200

55/70

3200/4300

45/65

3200/4000

40/55

7/8

to

7/8

2900/4000

55/70

3900/5000

45/65

3900/4500

40/55

8/e

to

8/4

3200/4100

55/70

4000/5000

45/65

4000/4600

40/55

91/2

to

3200/4100

55/70

4000/5000

45/65

4000/4600

40/55

3000/4000

55/70

3900/4500

45/65

3900/4500

40/55

2800/3800

55/70

3800/4300

45/65

3800/4400

40/55

2700/3700

55/65

3700/4300

45/60

3700/4300

40/55

2600/3100

50/65

3200/4000

45/60

3200/3700

40/55

to

10%

to

11

12

14 171/2

Medium-Hard

617

Class

6/4

to

7/8

to

8/e

to

7/8

91/2to9/

10%

to

11

12

14 171/2

627

Class to

7%

to

8/e

to

91/2

to

10/8

7/8

9/8

to

11

121/4

Medium-Hard

Shale

and

Shale

Lime Mixtures

to

7/8 81/2

to

91/2

12 727

Class to

7/8

to

8/e

to

77/s

50/65

3200/4800

40/60

3200/4300

35/55

50/65

4200/5500

40/60

4200/5300

35/55

3600/5100

50/65

4400/5600

40/60

4400/5400

35/55

3600/5100

50/65

4400/5500

40/60

4400/5400

35/55

3500/5000

50/65

4300/5400

40/60

4300/5300

35/55

3400/5000

50/65

4200/5300

40/60

4200/5200

35/55

3300/4700

45/60

4000/5000

40/55

4000/5000

35/55

3100/4100

45/60

3500/4700

40/55

3500/4700

35/50

Hard

Shale

Lime

With

Hard

Sandy

Shale

3300/4500

40/60

3300/4400

35/50

4300/6000

40/60

4300/5500

35/50

4300/6000

40/60

4300/5600

35/50

4300/6000

40/60

4300/5600

35/50

4200/5800

40/60

4200/5500

35/50

4200/5600

40/60

4200/5400

35/50

and

Dolomite

Brittle

Shale

Lime and

Sandy Dolomite

35/60

3000/4300

35/50

4500/6300

35/60

4500/6000

35/50

4500/6300

35/60

4500/6000

35/50

4400/6300

35/60

4300/6000

35/50

4000/6200

35/60

4000/5700

35/50

Hard

Lime and

Hard

Dolomite

Sandy

Lime

2800/4600

35/55

2700/4300

4500/6500

35/55

4300/6000

35/45

4500/6500

35/55

4300/6000

35/45

Sandy

Lime

Chert Basalt

837

Medium-Hard

3200/4500

Hardest

Class

Bromide

etc

Hardest

35/45

Unconsolidated

Abrasive With

Pyrite

Formations

Chert etc

61/2

3500/5500

35/50

2700/4300

7/8

4000/7000

35/50

3500/5000

30/45

4000/7000

35/50

3500/5000

30/45

81/2

to

8/4

Sandy Shale

3500/5000

Medium-Hard

637

Lime and

2600/3900

Limestone Class

Medium-Hard

30/45

APPLIED

242

5.6

rock

at

axially

to

quired

for

of

the

the

stresses

of

area

with

angle

direc

the

loading circle

the

two

the

using

prin

Answer

failure

Answer

1973

Compute Answer

stress

present

2819

psig

normal

the

the

stress

of

the

of

plane

interval

steps

Mohr

force

parameters

5.14

friction

resistance

of

of

rock

how

the

previous Using

mode

of

the

sample

confining

List

is

the

tooth

best

The

bit

tion

two

different

bit

type

currently

used

to

type

150

hours

bit

of

life

bit

is

Label

the

binations not

5.10

the

of

region

If the

the

bit

12000

to

weight

and

40000

lbf

was tluid

12200

was

12

Compute constant

lbf/in

and

of

rate

hours

bearing

TB

observed

weight

for

bit

this

exponent

Answer

to

100

at

hours

bearing

for this

TB

at

weight bit

of 67

life

bearing

promote

of

observed

1-1-1

hours

bit

lbf life

these

rotary

in

12

hours

used

speed

The

the

hours

for

the

clay/water

7.875-in

at

bits

this

average depth

formation interval

of

ft

Estimate bit

teeth

the

using

time bit

required weight

to

of

nonsealed

bits

roller-bearing

weighted

clay-water

mud

recommendation

muds

containing should

be

completely lbf

H2S based

sulfide

on

of

was bit

43.7

dull

Courtesy

Fig

of

Hughes

5.53Dull

Tool

bit

Co for

Exercise

oil

muds

bit

and

in

operated barite

abrasiveness

45000

bit

40 rpm Compute the values of apparent TB Answer 0.67 and 42 hours Recommend values of B2 and TB for 7.875-in

hours

the

4000

60 rpm and 55

having

Answer

at

an average

indicated

speed

rotary

Series

operated

drilling

mud

Answer

at

the

the

values

apparent

by

run

bit

assumed

and

clay-water

depth

of 60

speed

observations

using insert

diameter

bit

are

average

showed

an

Using

5000

to

hours

roller-bearing

of 42

at

compute

from

4000

diameter

bit

40 rpm

obtained

per inch of

hours

5.18

107

hours

at

B2

for

TB

data

95

hours

1.0 and

and

of

life

185

of

B1

per inch of

sealed

Series

with

operated

bits

from

drilled

rpm

5700

at

lbf/in Compute the exponent B2 and bearing type Answer 0.99 and 95

self-sharpening

rolling-cutter bit

60

of

3800

on 7.875-in

bits

weight

bit

Field

B1

and

done

sealed

Series

speed

rotary

below

is

lbf/in

type

self-sharpening

what

of

bit

what would

photograph

an

weight

Com B2 and

3800

for

roller-

show

rpm

for

on 7.875-in

bits

average

Field data

sealed

of

com

which

life

hours

60

Ibm/gal the

for

15

new

shows

ft/hr

Discuss

barite-weighted of

rate

90 rpm respectively When was graded T-6 B-6 The

it

an

1.64 5.17

the

the

45

32

Series

of

speed

bit

between

wear

ft

rotary

and

pulled

density

the

of

depth

of

penetration

in

milled-tooth Class

bit

is

about

the bretk-even

that

and

ofB1 and Answer 41.7

5.9

hours

43.1

shows

for

$750/hr

penetration

Pull

difference tooth

9.875-jn

is

evaluation graph

of

bit

weighted

Use values

GO

manufacturers

wear on

bit

and

value

bit

and

for the

shows

hour

shown

bit

operation

of

initial

first

T-8 B-8

the

t2

the

during

$10000

rate

bit

abrasive

life

the

recommend Answer

and

bit

field

you

Describe

usual

10 hours

of penetration

the

the

that

new

Answer 5.11

in

acceptable

Grade

of

and

constant

rpm and

formation

this

life

function

as

assist

experimental in

the

were

7.875-in

of

life

apparent

Field data

lbf

about

bit

drilling

graph

of

cost

have

costs

approximately

$50/ft to

to

bit

Prepare

the

medium

evaluation

of the

cost

time

for

new

lbf/in

on rotary

journal-bearing

forma

given

drill

new

expected

is

choose

to

trying

drilling

compared with

The

interest costs

is

as

operating

to

Table

for

hours

types

sending

field

bit

hours

Trip

are

the

The new

when

yields

You

What

selection

bit

of comparison

consistently

$50/ft

thumb of

of

rules

basis

between 5.9

bearing

constant

overbalance

as

changes

5.16

seven

the

5.15

pressure

beneath

failure

bit

mud

in

dull

and

lbf

hours

12.8

fluid

barite

at

journal-bearing

increases 5.8

average

apparent

cutter

depth

completely

45000

TB

constant

drilling

obtained

bits

0.84

compressional

if

the

if

bearing

pute

psig

the

rolling

the

failure

5000-psi

16200

in the

construction

compute

for

under

Discuss

circle

bearing

mud

Field data

bearing

computed

Mohrs

the

criterion

required

placed

5.7

the

on

Answer

5.3

5700

the cohesive Compute Answer 2100 psig

the

Example

to

of

weight

rpm Answer

100

this

hours

to

psig angle

bit

recommended

material

four

the

the

along

20

Label

Compute

clay-water

shear

the

of

speed

rotary

5.13

time required

the

for

hours

24.3

bearings using

hours

13.5

constant

bearing

Answer

Estimate

failed

sample

present

Compute failure

The

interval

rpm Answer

100 the

Compute

re

cross-sectional

in

350

Mohrs

Compute plane

makes

that

the

sq

compressional

Construct cipal

2.0

was

was

lbf

of

speed

rotary

compressed

12000

of

failure and

rock

strength-testing

and

pressure

force

failure

plane of

in

placed

atmospheric

sample

along tion

is

sample

machine

ENGINEERING

DRILLING

5.10

the

muds and

mud

The

laboratory

ROTARY

DRILLING

BITS

243

TABLE 5.13LABORATORY DATA OBTAINED AT Bit

BEARINGLIFE 60

Mud

Sulfide

K-Ibf/in

hours

Life

Bearing

Weight/in

The penetration

5.23

rpm

Mud

Barite

Mud

Oil

48.0

7.5

17.5

12

from

30000

bit

25.0

a6

wear

bearing

Table

in

The

ft

Test

No

5.19

Answer

races

31.5

hours and

Field

data

insert tain

2.87

0.9 and

obtained

bits

on

shown

are

this

10.8

below

hours

1.46

sealed Use

data

82

and

to

ob for

Bit

Weight

Rotary

Speed

Life

Bearing

1000 60

41 30

5.20

1.68 0.77

Determine

the

described

known The the

to

be

Bit

parameter

hours and

the

hours is

for

life

the

table

The

depth

range

hit

run is

lithology

of

interest

has

value

constant

The

cost

bit

and

Drilling

Total

Time

Footage

TB

$600

is

the

trip

0.56 The forma

has

constant

bearing

$l000/hr

of

TH

value has

40

value

Answer 5.25

hours

of

rig

operating

end

hours

is

ft

from of

18

the

which

Remarks

rpm

80

speed

Time

Elapsed

seconds

lbf

76

108

72

228

68

360

64

506

60

668

56

848

52

1050 and

06

a6

in

rate

new

for

shale bit

104

to the

at

T-6 B-7

graded tooth

re

wear

wear exponent

to

decrease

being

15

stopped

to

Il

to

ft/hr

temporarily

from

fall

apparent

cir

penetration

600

400

to

expo

hydraulics

0.4

Answer

with

bit

from is

rate the

the

is

The

gal/mm

mud

and

Ibm/gal

600

Compute

diamond

nozzles

10

of

circulation

the

a8

of

two pumps

the

of

gal/mm

observed

is

lift/hr

to

was

bit

%2-in

three

rate

one

causing

nent

blade

total

of 5.585

length

in

117

12

200

contains 14

127

16

135 the

18

142

20

fora

.0

0.01-in

carats

rate

depth

of

have

that

of 0.01

penetration

penetration

expected

for

of

stones

in

of 0.0848

if

in

sufficient

diamond

22

151

Answer

12

penetration

increase

so penetration

affecting

rate

in shale

of 20

ft/hr

rate

was obtained

mud density of 12 Ibm/gal at depth ft When the mud density was increased the

Ibm/gal ft/hr

for

apparent

Assume

hours

factors

eight

Torque

penetration

similar

value

106

of

drilling the

rate

was decreased

conditions

overbalance

penetration

depth

Answer

An

Class

I-I-I

8.5-in

and

to

depth

to

The

a4

90 of

9000

I.

drilling ft

formation

9.0-Ibm/gal on

is

rpm

bottom ......

mud is

at

9.7 tk.

10.2

and

operated

in

shale

the

i.

is

at

The fl1

Ikc

35000

formation rate

of

30

equivalent

equivalent

Ibm/gal

rpm

arrayed

maximum

the

bit

pressure

could

ft/hr

penetration

pore

weight

iOO and

shaped

two-thirds

is

penetration

are

Compute bit

of

speed

rotary

diamonds

the

that the

that

of

Compute

exponent

5.28

at

maintained

width

penetration

147 be

Answer

1045

observed

is

when

5.27

the

48

density

at

bit

88 10

9.5

864

0.7

has

culated

73

13

704

52

run The

bit

54

10000

562

56

ft/hr

contains

bit

rate

using

60

penetration

Answer

a7

New

5.22

436

other than Assuming all variables mained constant evaluate the tooth

30

List

320

64

1.6

a5

The average drop

the

time

of

5.26

5.21

68

1000

hours

bit

for the

J3

abrasiveness

cost

210

Weight

wear parameter J2 has value of 0.15 constant H7 has value of 7.0 and the bearing

tion

104

72

rotary

tooth

wear

40

41

following

uniforni

seconds

81

optimum

the

in

and

rpm

80

40 Answer

120

drilipipe

Time

76

hours

_________

60

exponent

16.6-Ibm/ft

Elapsed

lbf

No

Test

rpm

lbf/in

the

evaluate

80

and

r8

ex

weight

speed

rotary

speed

Weight

1000

type

bit

and

roller-bearing

these

of

bit

data

test

4.5-in.

the

rotary

hours respectively

8.5-in

values

representative

256

and

increased

is

0.8

a5

12.000

increase

to

weight

bit

Compute

exponent

rotary speed rpm The bearing life was determined based on 0.1-in wear in the bear ing

lbf

drilloff

length of

observed

is

the

following

con

and

13

when

50000

to

of 60

at

in shale

rate

ft/hr

Bit

shown

data

18

weight

was

ducted

the

Using

80.0

to

as Answer

ponent 5.24

14.0

from

mud

computed .1

lbf at

ft/hr to

density

impact

APPLIED

244

wear

fractional

tooth

formation

drillabilityj1

threshold

using

values

ing

of a-

02

The

ft/hr

of 38

hours and hours The

22

is

the

weighted

has

formation 9.0

minutes

nection

30-ft

bit

the

pute

cost

W/dh of

4.5

1100

Ibf

Write

table

has

value

Compute for the life

the

bit

and

be

to

the

new

bit

make

is

18

and

be

con

J.H

Engineering

Drill

Prod

Prac

con

the

5.28

for

ajet impact

Pm

cost-

weight

lbf/jn

Soc

Eng

Pet

Eng

the

constant

determine

to

speed

and

weight

Exercise

wear

5.29 assuming the

Ignore

flounder

bit

Answer

speed

rotary

of

5650

of

known

is

and

lbf/in

24

26

28

60

the

program

determine

the

for

Exercise

22

hours

developed

optimum 5.29

if

bit

has

Tfi

Exercise

in

value

5.30

to

speed

rotary

of 95

29 30

Design Diamond SPE

Regional

Handbook

Tcch

Hughes

Tool

Hughes

J.C

Bit

the

Selecting

World

Gray

K.E.

Study

of

and

WC

Tech

Jan

Bit-Tooth

Conditions

Pet

Tech

lem

in

AS

on

Tooth

and

Drilling

Campbell

Bits

and

Interactions

to

Approach Oil

Pet

Rock

lntcrpreiing

Go.s

series

Petroleum

by

J.G Laboratory

Eenink

Mud

and

El

of

Study

Column

Formations

on

Pressures

AIME 1959

li-tins

and

AS

and

Effect

Maurer

WC

ing

Pet

213

of

Deep

on

Effect

Rock

the

of

Effect

Ti of

Mud

Column

204

196-204 Trans

Drillability

1-6

The

Perfect-Cleaning

Nov

Tech Chevron

Vidder

Pm

AIME 1955

Trans

Pressure

of

Verification

R.A

Cunningham

Rates

of

1978 Rate

Drilling

Affecting

232239

216

Simulation

Laboratory

March

E.J Field

Benit

Drilling

JR

Si

Eng

Phenomena

AIME 1959

Trans

Green Pet

N.H

Lingen

Pressure on

Murray Eckel

van

Depth

and

Di

Vidrtne

Theory

127074

1962

DOT

Test

Drill-Off

of

Drill

Rotary

A1ME

Traiv

Chevron

225 Co.

Oil

Orleans

Pratt

CA

Increased

tended

Nozzle

Eckel

JR

Penetration

Pc

Bit Microbit

Hydraulics

on

Tech

Studies

of

Achieved

1978

the

With

Fluid

Properties

SPE

paper

GA

Peterson

al

Effects

Shale Diamond

of

Drilled

JL

Tech

Hydraulics

Tech

2244

Feb

on

SPE

Full

1981

July

Model

Drilling

Pc

Tests

Bit

Pet

Ex

New

119298

of

Effect

11

Rate

Drilling

Rate

Aug

1968

Tibbilts

Verified

Field

in

15222

1976

Scale

118088 and

Traits

Moun Moun

Rocky Rocky

19-21

Bit

final

B1

B2

of

Light

at

Trans

Under

J.M Wear

Mtd-Continent

Mackay

with and Rate

Dat

Air

Mitchell of Rotary Spring

and

Still

Gas

AIME

B.J Rock

Meeting

Effect

Bits March

of

paper

bearing

bearing

area

in

wear

at

contact

with

the

10 Tooth

cost

of

resistance

per

interval

of

bit

run

material

225

Cr

Prob

diamond

cutters

operating

cost

of

rig

per

unit

diameter d6

diameter

of

bit

dr

diameter

of

cutter

105

1957

fixed

of

drilled

in

carats/sq

AIME

Tough

Geometry

presented

1959

end

wear exponents

concentration

Borehole

Trans

Poses

June

bit

Atmospheric

Simulated

1433-42

S.P Water Oil

equation

Speed

Two-Dirnei1nal

9398

1965

A51

diamond

cohesive

in

Drilling

Penetration

of

total

Cj

Gatlin

1962

area

Ac

IADC

by

94

Drag-Bit

rate

penetration

formation

Rock

Look

the

in

Ab

1976

Rotary

exponents area

of

234 Murray

257

Rock

Insert

Rotary

Hydraulics

Formation

and at

AD

76

New

Dec

the

Future

SPE

Simplified

1965

in

Breakage Pet

May

1972

Rate

March

Armstrong

Rock

Pressure Maurer

Oil

in

1982

Houston

Proper

Nov 1971 135967 R.V Drag BiN

Drilling

MT

Identification

May 22

Gas

the

at

Co.

and

Cutters

presented Billings

Rock mid

Appltcation

Compact

10893

Meeting

Durrett

Estes

Detection

Pressure

Tans AIME

1-384

Nomenclature

paper

Oil

Drilling

Optimal

AIME 26

Polyciystalline

tion

and

Permeable

Drilling

a8

Bit

of

A.J

Laboratory

Cerkovnik

tain

Teilr

1965

April

R.A

Rates

of

instead

References

tains

Co

Laboratory

and

weight

Pit

9-17

Black

and

to

Abnomral

37

Mud

of

New

Overburden

Gamier

New 27

Control 246

Selecting

froni

reprinted

AIME 1957 25

and

for

MG

Rate

API

Operations

Drilling

Approach

1974

Lummus J.I Analysis Feb 1974

Bingham

Pam

1974

Sept

Pressure on

bit

effect

weight

23

Young

Aug

of

and

Weight

mid Prod

423438 Trans AIME 253 F.S Jr Multiple Regression

Drilling

Guidelines

Differential

is

op

the

for

22

Carlo

972

and

Constant

Drilling

Oct

Technical

3855

AIME

Monte

Optimal

J.C

Estes

Dallas

Use

AT

to

Drilling

and

throughout

dnulability

Exercise

tooth

by

Eng

Approach

216 20

force

determining

rotary

bit

RL

Reed

ConlputeriLzd

Trans

47

Drill

Design

1964

API

483-496

19691

Drilling

con-i

observed

bit

Jr

F.S

Young

Publishing

21

program

in

and

Annual

Oct

Best

Bits

of

Condttions

SEE

Antonio

AR

Rock

Rotary

Wear

High

1981

the

al

San

Woods

and

19 Cunningham

s/ft for

presented

Esaluation

Laboratory

and

Speed

Exhibition

for

Drillability

rpm 5.32

48-73

Pet

is

Using

Exercise

maintained

and

time The

60000

16

$600

is

High

Edwards

Soc

mud

operation

0.5

constant

optimum

limited

is

1963

fect

of

and

formation

described

connection

EM Speed

15 Bourgoyne

5.29 5.31

14

gradient

cost

to

would

rpm

be

10326

Rotary

J.N

Middleton

Under

and

Galle

April

17 bit

drilipipe

29.73

will the

weight

bit

value

barite

trip for

in

program

Use

constant

timum

has

gradient

drilling

of

Assume

that

SPE

Well

speed

rotary

run and

bit

Answer

FORTRAN

per-foot that

90

of

fluid

required

that

paper

and

Bits

Etg

to

given

drillability

7h

fluid

per inch

foot

to

11

The

the

are

08

per

12

0.4

be used

pressure

drilling

joint

weight

thmugh

a2

pore

Ibm/gal

of

hours and

stants

constant

hearing constant

cost

per

0.4

will

bit

has

that

ft

time required

the

threshold

5.30

the

I-i-i

of 9.7 lbm/gal

operating

$800/hr

9000

clay/water

density

the

U5

0.6

13

Class

to

equivalent

12

ft/hr

at

Drill

follow

06

abrasiveness

of

the

PCD ft

II

0.00002

26.1

9000

ER

Hoover

apparent

at

Conference

a4

formation

drill

type

a8

through

9.875-in-diameter

40

bit

of zero and

weight

0.000004

Answer

this

10

the

Compute

for

a3

0.00009

529

bit

0.4

is

ENGINEERING

DRILLING

at

depth

API

LID

depth

interval

drilled

during

bit

run

time

ROTARY

DRILLING

f8

fi

BITS

245

Youngs

modulus

functions

defining

of

elasticity

of

effect

subtended

angle

variables

drilling

PCD

wear surface on

by

blank

various

axial

or elongation

strain

per

unit

length

force

of

angle formation

pore

an

as

viscosity

fluid

equivalent

Pa

density for

design

H1-H3

wear

used

speed

wear

equations

formation

used

to

and

of

bit

in

penetration

weight

bearing

of

and log

rate

wear

in

penetration

of

bit

drag

cut

by

an

diamond

individual

dp

drillpipe

for

blades

of

drag

bit

max

rate

maximum

or

normal

plane

to

resistance rate

penetration

rate

aiso

overbalance

of

during

bit

run

such

as

operations

required

to

on

bit

sq spatial

bottom

2.54

lbf

4.448222 4.535

psi

6.894

in

6.451

coordinates cutting

angle

Conversion

factor

924

1.198264

lbm/gal

width

412

in

ibm

bit

3.048 3.785

gal/mm

time

tripping

directions

Conversion Factors

Metric

ftx

connection

or

rock SI

nonrotating

or reference

average

life

weight

slope

carats/stone

strength

time

standard

coordinates

spatial

zero

at

diamond

change

also

threshold

time

of

destructive

removed steel

of

circulating

optimum

opt

compressive

xy

also

jet

number

penetration

time

base

initial

cutters

formation

bit

10

formation of

radius

th

base

direction

and

effective

speed

Reynolds

size

natural

cutter

pressure

R0

logarithm

bottomhole

L1

number

number of rotary

rj

common

bh cutter

removed

height

flow

logarithm

plane

apparent

height of

effective

NR

principal

stress

Subscripts

penetration

fl

failure

bit

initial

width

between

respectively

length

Lr

constant

abrasiveness

predict

length

depth

constant

life

bearing

run

constant tooth

stress

angle

functions

composite

tooth

bit

wear

tooth

rotary

of

constants

geometry

bit

end

at

stress

shear

wear

tooth

tooth

tooth

density

tooth

given

normal

fractional final

viscosity

apparent

mud

constant

geometry

internal

pressure gradient /1

expressed

friction

is

exact

757

E01 E03

m3/min

E00

em

EQ0 E01 E02 E00 E00

kg kg/rn3

kPa em2

Chapter

Formation Pore Pressure and Fracture Resistance

The

objective

occurring

can

the

that

of

at

naturally

occurring

any

maximum

withstand

of

of is

be

mon

forces

given

that

depositional detritus

were

suspension

are

initially

remains

fluid

Once particles

these

two in

important

is

the

4.2b

pore

for

subsurface

is

be be

is

be

as

long

the

surface to

required

and

negligible

maintained

Thus

computed by

the

Eq

of

use

formation pressure the

pore

pressure

hydrostatic

pressure

for

said

is

given

hydrostatic

area

for

approximately for

the

is

Normal

expressed

Table

several

lists

areas

equal vertical

given

normal

be

to

usually

gradient

pressure gradient drilling

is

pressure

con

have

that

in

nor

the

activity

fluid

com

most

in

the

Eainple expected

Compute depth

at

normal

the

6000

of

ft

the

in

formation Louisiana

pressure gulf

coast

area

in

slowly

carried

by

and

river

relatively

to the

deposited

unconsolidated

mixed

communication

that

will

as

to

path

gradient

will

continually

processes

occurs

down

expelled

However

flow

water

pressure can

formation

theoretical

depth

of

com

more

Chap

in

When to

pore

is

space

potential

equilibrium

formation

water

pore

compaction

hydrostatic

the

realignment in

resulting

permeable

flow

upward

release

load through

This causes

sediment

occurs

relatively

deposited

Fig

from

and thus have The seawater

in

the

mal

laid

which

permeability

hydrostatic

there

burial

greater

previously

increased

points

decreasing

terms of

distributions

environment

formed

compacted

fracture

well

material

released

sediments

how

of

extremely

responsible

pressure

sediments

is

is

and

the

the

to

subjected

lower-porosity

from

With

density

closer spacing

to

grains

fluid

continues

contact

As compaction

deter

the

chapter

on

various

pressures during

pressure

can

focused

area previous geologic One of the simplest and

considered

While

formation

we

this

and

are

grains

siderable

subsurface

deltaic

the

the

fluids

Pore Pressure

the

in

shallow

that

wellbore

between

Chap

fluid

deep

the

formation

the

In

depth

drilling

To understand

must

that

In

deposition

grain-to-grain

are

rate

significant

Knowledge

with

vary

Formation

pressure

welibore

formation

and

planning

In

operations

formations

maintained

pressure

discussed

parameters

be

fracture of

at

dictates

safety

welibore

drilling

pressure

fluid

rock

formation

the

on

only as

depth

and

fluids

given

wells

naturally

pressure of

without

mination

fluid

depends

the

deep

depth

determination

types

most

wells

pressure

the

formation that

pressure

flow

will

these

drilling

sea

subsurface

student

naturally

without fracture

drilling

penetrated

6.1

of

wellbore

the

the

pacted

With

the

tofwniliarize

is

methods of estinating

pressure

withstand

the

chapter

used

maiimum

the

this

of

conmonlv

with

and

high porosity

with with

these

the

Solution

the

coast

Un-

normal

and

is

listed

formation

pressure gradient

in

Table

as

for the

0.465

pore pressure expected

at

U.S

gulf

Thus

psi/ft

6000

ft

the

is

and

sediments

sea

The normal

area

is

PfO.463

6000 ft2790

psi/ft

psi

at

pressure has occurred

deposition is

settled

supported solids

pressure contained

have

below within

the

weight

at grain-to-grain

no

influence

Thus the

contact

hydrostatic

pore

the

on

spaces

of

the

solid

points

and

pressure of of

the

6.1.1 In

hydrostatic the

sediments

that

The

Abnormal

many is

instances

greater

term

Formation

than

Pressure

formation the

abnormal

normal formation

pressure pressure

is

for

pressure

encountered that is

depth

used

to

FORMATION

PORE

PRESSURE

AND

FRACTURE

FLUID

RIVER

PRESSURE

DELTA

247

RESISTANCE

0.052

LEVEL

SEA

Pf10

PORE FLUID

WEIGHT

DETRITUS

OF

AT

TRANSMTTED

GRAINTOGRAIN CONTACT

6.1Normal

Fig

describe

mal

formation

and

countered used

Abnormal

While

of

understood

of

also

nor

en

are

is

pressure

arc

formation

basins

in at

pressure

the

have

generally

as

diagenetic

effects

differential

the the

pore

burial

creasing the pore

space

of

path

To

formation

to

mechanics

the

rock

this

another

are

natural

flow

and

by

compressional

the

space

between

surface

psi/ft

Texas Mexico

of

coastline

Sea

Malaysia

Mackenzie West

Africa

Anadarko Rocky

Delta

Basin

Mountains

California

allow

In

given

springs the

have

by

as

pore

the

will

remain

will

continue

natural at

until

water

hydrostatic to

increase the

can

rate

pressure as

as

escape

compaction

the

overburden

the

The

pistons stress

as

quickly pore

matrix

move is

this

stress closer

balanced

in

only

may

Equivalent Density

kg/rn 1.000

0.465

1.074

0.452

1.044

0.442

1.021

0.442

1.021

0.442

1.021

0.433

1.000

0.439

has

PRESSURE AREAS

0.433

0.436

contact Connate

path

SPR

PIG

ob WATER

.007 1.014

Fig

6.2One-dimensional

sediment

compaction

re

pressure

forma

pistons

Water

of by

and

a-

stress

in the

depth

model

the

that

pistons

However

Gradient

North

be maintained

Fig 6.2

in

Pressure

Gulf

or matrix

Thus we

pressure

the

support provided

simple one-dimensional

shown

TABLE 6.1NORMAL FORMATION GRADIENTS FOR SEVERAL OF ACTIVE DRILLING

West

the

are

load

geostatic

to

by at

while

temperature

exists

represented

to

with

expands

increasing

pressure can

is

the

fills

path

by

ub

readily

through

water which

water

increased

principle

model

grains

Pore

permeability

escape

illustrate

soil

one

reduced

sufficient

water

tion

and

depth is

Thus normal if

Effects

Compaction

load

grain-to-grain

fluid

As long quired

together 6.1.2

this

Resisting

vertical

load

of

weight

6.1

be

effects

migration

pistons geostatic

the

valve

the

closing

loaded

are

to

can

effects

density

or

by

represented

not

is

effects

compaction

restricted

overburden

sediments

deltaic

identified

mechanisms

These

shallow

model The

the

least

tend

that

been

in

become

world

pressure

mechanisms

several

formation

found

basins of

sedimentary

abnormal

distribution

burial

classified

fluid

pressure

than

greater

pressures

pressures

the

completely

sedimentary

fluid

pressures

of

abnormal

are

term subnorinalformation

formation

origin

that

formation

these

most

the

cause

the

describe

to

portion

in

pressures low

Abnormally

subsurface

model

248

APPLIED

0l

DRILLING

0.05

ENGINEERING

02

01

O.3Q405

2.000

iiiiiiiiii 8000

Ui

--3 --

0000

Iii

O.4le0000 Ui

2000

Ui Ui

4000 Ui Cl

.-

6000

Ii

9000

1.9

2.0

2.1

2.2

2.3

BULK DENSITY1 Fig

6.3Composite for the U.S

bulk

density

curve

Pb

2.4

2.5

20000

2.6

.Ol

g/cm3

from

density

log

0.05

data

6.4Computed

Fig

gulf coast.1

However

the

if

the

restricted

Sediment

Bulk Density

Average

pressure

Porosity

normal

Pb ft

g/cm3 1.95

1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 16000 17000 18000 19000 20000

frac

2.02

0.38

2.06

0.35

2.11

0.32

the

2.16

0.29

2.19

0.27

2.24

0.24

2.27

0.22

2.29

0.20

2.33

0.18

2.35

0.16

2.37

0.15

2.38

0.14

2.40

0.13

2.41

0.12

2.43

0.11

2.44

0.10

2.45

0.098

2.46

0.092

2.47

0.085

2.48

0.079

0.5

vertical

average

U.S

for

blocked

is

gulf

also

The

compaction

pressures

overburden

stress

Pb

bulk density

is

given

than

greater

natural

of

loss

of

fine-grained

may

create

seal

develop

to

from

resulting for

depth

cause

hydrostatic

remain

will

shale or evaporites

sediment

will

above

depth

burial

or severely

stress

water

pore

through as

path

volume

given

such

at

trend

overburden

would permit abnormal

The load

porosity

flow

the

The pore for

sediments that

water

of

permeability

0.43

average

increasing

pressurization

Thickness

0.3

area

coast

TABLE 6.2AVERAGE SEDIMENT POROSITY COMPUTATION FOR U.S GULF COAST AREA

0.2

0.1

POROSITY

sediments

geostatic

having

an

by

6.2

where

is

the

density as

at

given

the pore

Pg

constant

gravitational

The bulk density

fluid

depth

is

density

related

Pfl

and

to the the

follows

PbPglIPfl1I In

an

bulk

grain

porosity

area of

6.3a

significant

density with depth

tional

well

average Louisiana

gulf coast

paction

to

in the

Grain

areas

bulk

is

densities

determined

The

shown

density

change

is

in

of

with

sediment the

in in

the

in

change by

of

effect

sediments

for

density

The change primarily

methods

logging

bulk

the

activity

drilling

usually

conven

depth Texas

on and

Fig 6.3

burial

depth

porosity

common

is

related

with

minerals

com found

FORMATION

in

PORE

sedimentary

can

be

value

is

To

depth

are

when

this

Eq

6.3a

usually

to

use

the

the

for porosity

yields

at

bulk

average

In

from

well

these

any

grain

porosity

values

semilog tained

paper good The equation of

this line

trend

is

fluid

read

6.5

density

be

the

8.5

to

the to

equal

two

bottom

of

depth

the

porosity

6.4 Thus

Eq

6.5

becomes

the

interest

forma

normal

the

and

the

and

Ibm/gal

area

the

in

integrated

ocean

to

equal

assumed for

Eq

must

to

mudline

the

is

density

fluid

computed using

be

can

given

rDw

density

vs

plotted

straight-line

Eq

of

terms of average

density and are

data

density in

easily

assumed

average

bulk

average

be expressed

to

logs

for

porosity If

allows

is

From

is

6.5

surface

the

density

fluid

tion

Eq

areas

From

porosity the

Pfl

equation

sedi

average

Substitution

6.2 gives

offshore

parts

6.3b

This

in

change

obtained

density

porosity

Pb

Pg

the

is

gD pfldD

ob

given

seawater Pg

Eq

into

porosity

overburden

load

of

for

expression

ment porosity with depth

exponential

the

average

terms

convenient

6.3a

sediment

geostatic

in

average

density

average

approach first

and

greatly

calculating

from

resulting

expressed

Solving

in

burial

use

fluid

pore

249

RESISTANCE

representative

convenient

is

it

change

uh

data

for

true

FRACTURE

not vary at

relating

of

depth

stress

also

AND

do

constant

areas

many

relationship to

deposits

assumed This

In

PRESSURE

depth

Ohg

on

pdD

ob

is

usually

by

PfledD

Pg 6.4 where

of

the

is

decline the

surface and

constant

porosity the

is

depth

The constants

sediments

mined graphically

or by

the

and

porosity

the

surface

be

can

deter

DD1

Example 6.2 Determine

Use

area

6.3

an

pore

Solution Table

the

The

6.2

from

The

values grain

given density

Eq

bulk the

at

density depth

of 2.60

were

in

g/cm3

2.60

6.6

and

an

summarized

are

in

in

Cot

Cot

was

Example

6.3

Compute

resulting

from

geostatic

in coastline

computed using an average density of 1.074 g/cm3

fluid

Solution

The

geostatic

load can

and

1.526

porosity

zero

depth

line

at

of 0.41 porosity

depth

constant

are

of

is

ft

Fig 6.4

on

indicated

of 0.075

20000

in

plotted

the

read

is

Thus

the

sur

trend

from

line at

the

porosity

trend

the

0.052

to

Eq

in

units

the

overburden

be

stress

calculated

in

to

rela

is

in

psi/ft

pore

g/cm3

and

with

Example 6.2 respective

fluid

density the

Converting

using the conversion

lbmlgal to

1.074

6.6

ft

0.000085

the normal

area

from

resulting

surface porosity

determined

and

Table

pg

stress

Mexico

of

porosity

Eq

using

zero The grain density

convert

6.6

the Gulf

Use

ft

decline constant

gulf coast

density

near

10000

g/cm3 0.41

ly As shown

overburden

vertical

Example 6.2

in

vertical

of

depth

porosity

the

load

of

depth

determined

tionship

for

face

at

read

The porosity

were 2.60

porosities

le KD

pgpflgcb0

pggD

p.%.gD4

water

The computed

D5

sediments

Fig

260Ph

2.601.074

the

gulf coast

shown

6.3b

2.60

of

substitution

surface of

the

g/cm3

given

given

and

U.S

data

calculations

Cot

in

of

of 1.074

and

equation

below

surface porosity

density

density

density

porosity

Fig 6.3

for

for the

bulk

grain

fluid

values

this

depth

method

least-square

constant

average

average

average

in

decline

porosity

the

yields

0/

and

of

Integration

the

is

below

inserting

constant

these

values

yields

decline

is

ob

In

0.41

0.0522.608.3310000 .0748.330.41

0.0522.601

ln

50000085ft

0.0000 85

20000 .-_O.000085iO000

and

the

average

O.4le

porosity can

be

computed using

1126218269436

-085D The

The geostatic

overburden

vertical

load

is

computed

stress easily

resulting at

any

from

depth

the

nnr

Thic

overburden

vertical

load often

is

assumed

iorrsnnnds

to

stress

equal

th

to

iis of

psi

resulting

1.0

psi

per

onstqnt

from foot

wq1w

geostatic

of

depth of

huh

APPLIED

250

Fig

for the

density

assumption of

tion

not

total

cause

stresses

coast

of in

American lateral

large

rocks

with

state

at

the

6.1.3

shear

6.5

tends

geologic

resistance the

to

to

the

shear

rocks

stress

relieve

the

pressured

domes

is

west of

the in

overlying stress

This

il

is

faulting

will

of

stresses

Diagenetic

Effects

osmotic

of rock

are

An

pressure of

kaolinite

to

is

contributes

within Pore

rnorillonite terlayer

water

water clays

burial is

the is

to

clays

in

changes

to

in

car

crystalline

abnormal

conver

possible

illites

compaction

of

cause the

alteration

Shales and

processes

example

present

in

clay

of

is

lost

chlorites

the

tends

to at

during

bonded be

which

dehydrated

both

which

outerlayer

first

water

depth

deposits

hydration

shale

the

structure

reaching

chemical

and of

presence

if

only

as is

structure

compaction within

retained

the

free

held

see

or that

than

of

montmonllonjte

pore

However

if

shale can

be

mont in

shale

After

longer

temperature

of

to

more Fig

200

to

releases

lower

normal to as

of

ratio

reverse

centrated

As

sieve

ion

between

the

mem

by

or

clay

controlled

from

resulting

difference

to

exist

an

in

flow

darcy

pressure

relatively

thin

which

by

form

to

overlying

form

to

appears

such

sec

seal

shale formation

such

caprock

is

water

water

to

The

higher be

can of

are

left

eventually

less

is

the

il

water

that

This

and

forming

the

water

has

water

for

shale

the

greater

reversal

enter

become

is

the

is

lower

solution the

is

will

pressured

sometimes

cannot

shales

enter

from

pressure

water

water

the

tendency

abnormally

transfer

behind

water

and

overcome

water

osmosis Ions

readily

is

accept

of

activity saline

solution

water

saline

of

However

the

there

saline

forced

that

if

Since

absorb

will

activity

shale

the

shale

the

leave the

shales

or

potential

of

fresh

direction

terlayers

to

analogous

may be

potential

pressure

release

activity

activity

of

that

than

activity

shale

by shale

semipermeable

some cases

sieve

chemical

dehydrate less

ion

cause

Fig 6.7

than

greater

In

caprock

absence

the

to

similarities

by

mechanism45

in

the

In

abnor

in

pressure gradient

pressures

partial

lustrated

as

from

be present

molecules

present as

the

undergo

during 23

ions

and

tightly

to

often-cited

clays

Water

30tJF

refers

montmonllonjte

potassium

6.6

thought

which

structure

water

that

minerals by geological

bonates

sion

term

is

as

the

explain

demonstrated

partial

through

well

as

For abnormal

hypothesized

pressure

to

pressure developed

chemical

in

dense

in

water

last

depth

thought

or

by

adsorptive

resulting

of

at

water is

pressure developed

gradient

tion

fresh

are

difference

must

overlying

would be relative

thought

found

there

Water movement

seal

for

Chap

shale

potential

is

is

the

thus

becomes

the

of abnormal

released

This

membrane

and

salinity

of

con

and

and

of

manner somewhat

in

act

the

desorbs

it

release

be

to

salts

brane

by

low

affinity

to

in

as

montmonllonite

semipermeable discussed

water

has

formations

as

formations

free

sometimes

that

such

than

development

water

of dissolved

clay

acts

Diagenesis

in

last interlayer

free

interlayers

permeability

sufficiently

The chemical

upward

the

result

mally

tend

generally

buildup

is

can

water

load

geostatic

sediments

last

increase

When

water

free

fresh

fail

and

volume

undergoes

illite

in the

density

greater

becomes

and

interlayers

interest

vertical

load

geostatic

siderably

load

geostatic

of hydration

ly

results

are

water

water

The

U.S

which

If there

of

describe

the

the

last

The

terlayer

collision

plates

However

over

also

shale

In

causing

is

is

processes

these

plastic

area

the

excess

in

resulting

of

depth

example

stresses

subjected

which

above

or

Pacific

exceed

may Fig

when

occur

and

significant

in

readily

drift

compressive

depth

lustrated

For

coast

gulf

continental

area

North

U.S

the

from

salt

low-density

the

stress

may be present

compaction

only

depth

average

adequately

at

resulting

sedimentation

movement

always

rock

the

to

was indicated

psi/ft

overburden

not

of

state

sediment

common

vertical

an

shallow

made

respect

Example 6.3

load does

stress

other than

in

be

stress

computa

for

should with

density

compressive

simplifying

in the

especially

of 0.944

of

calculation

Compressive

to

that

of

This

errors

assumption bulk

gradient

geostatic

section

significant stress

an

Note

stress

The

to

in

change

known

from the

Such

the

burden

lead

overburden

sediments

when

sediment

entire

can

6.5Example

ENGINEERING

DRILLING

of

the

of the the

referred shale

in

more con

precipitates

The

FORMATION

PORE

PRESSURE

AND

FRACTURE

RESISTANCE

251

W1ATER

__--LLt\ST

-__p

WATER

WAT

RE

R---iii---_

MONTMORILLOFJITE BEFORE

LOSS

OF

TO

DIAGENESI5

LAST

CONVERTS

INTERLAYER

per

of

of

part

dense

and

mation shale will

of

give

Evaporites

are

in

the

carbonate

the

rate

to

become

of

often

up

the

relatively

these

the

the

become

to

rate

of

to

STAGE

WATER WATER

PORE

OF

COMPACTION

be

contacts

localized

areas

anhydrite

below saturated

solution

the

is

to

lute.3

at

recrystallization

rock

exist

not

abnormal

to

in

by

pore pressures

the

case

the

permit

demanded

as

quickly

As

can

sites

adjacent

matrix

the

pore natural

lead

of

more

to

shales

water rate

to

of

com path

if

as

escape

compaction

result

2H2O

them with

equal

pressure solubility

Subsequent

6.1.4

When

evaporite

However when grain

for

impermeable

sediments

tends

causes

CaSO4

totally

pressured

carbonates

at

montmorillonite

pacted

types other than

impermeable

nearly

ioni.e

selectively

also

rock

in

hydration

extremely

in

solution

water gypsum

recrystallization

in

from

barriers

free

abnormally

The pore water of

of

water

up an

increased

zone

of

does

permeability

CaSO4

applied

diagenesis

woald cause

carbonates

of minerals

loss

INTERLAYER

FINAL

impermeable

After

resulting

and

high-pressure

Precipitation

OF SOME

AND

ILLITE

silica

the

LOSS

MONTMORILLONITE

Fig 6.6_Clay

precipitation

lNTERLYEft._--

to is is

ture fluid

Differential the

density

density

countered situation

with

the

is

this

updip

dip

potential

gas

Effects in

any less

area abnormal

encountered

significant

familiar

present

significantly

for the

in

recognize in

fluid

pore

has

Density

sands

of

portion

frequently is

drilled

nonhorizontal than

pressures can the

when

Because

hazard blowouts previously

struc

normal

the

structure gas

pore

en

be

This

reservoir

of

failure

have

occurred

penetrated

by

to

other

APPLIED

252

ENGINEERING

DRILLING

PREFERENTIAL ABSORPTION FRESH

CLAY

OF

FORMATION

WATER

WATER

LEFT

MORE

ECIPITAT1ON

BEHIND

SALINE

OF

CARBONATES OF

ZONE

Fig 6.7Possible

OF

mechanism

HIGH

for

of

FORMATION

CAPROCK

PERMEABILITY

formation

AND

SILICA

CAUSED

seal

pressure

AND

HIGH

above

abnormal

This corresponds

PRESSURE

to

zone

pressure

of

gradient

2283 0.571

psi/ft

000

mud

The

needed

density

balance

to

this

pressure while

would be

drilling

0.571

11

lbm/gal

0.052 Fig

6.8Example

illustrating

caused

by

origin

low-density

abnormal

of

fluid

pore

pressure

in

dipping

formation

In

addition

during

However

wells can

be

the magnitude

calculated

pressure concepts density top of the

is

the

presented to

required

gas/water

the

is

the

abnormal

use

of

the

to

required

near

safely the

drill

6.1.5

zone

the

near

The

water-filled the

portion

gas/water

what

mud

top of

the

Solution

be

is

Thus

the

pore

at

normal

pore pressure

and ft the

through of

depth

4000

ft

of 0.8 lbm/gal

density

Table

If the

5000

of

drill

pressure gradient in

to

to

area

normally

depth

at

safely

given

pressured

Fig 6.8

in

gulf coast

required

gas has an average

area

is

occurred

structure

corresponds

lbm/ gal

U.S

sand

the

shown

gas sand

the

in the

would

The normal

Mexico

which

of

contact

weight

the sand

Assume

of

Consider

6.1

water at the

for

the

0.465

as

becoming

density gas/water

of

6.9 be

can

quired and

Gulf

8.94

contact

fluid

return

psi

The

fluid

static

gas zone

at

4000

p2325 0.0520.85000-_4000

ft

ing

2.283

osi

This

the

literature

the

Many

over

rf

in

migration

upward move re

bleed

off

blowouts

have

oc

formation

was

en

time zone

situation

to

is

in

the

formations

the

most

critical

planning

particularly

at

magnitude articles past

.hnrrm..J

and

25

nr

the

of have

the

must

first

be present

will

If

pressures depart

pressures must

appeared

years on

by

modern

drilling

fluid

drilled

needed

engineer

pressures

which

be

to

parameters

the

planning

abnormal

depth

and

also

occurs

may be

severe

charged

fluid

the

if

charged

Many

within

the

well

In

normal

etimqtinn

of

whether

be

type of

considerable in the

this

As shown

fields

engineer

well

estimated

is

this

to

forma

for Estimating Pore Pressure

one

drilling

will

old

When

charged

man-made Even

pressure

establishes

they

for

unexpectedly above

be

to

shallow

Methods

from in the

0.3

reservoir

shallow

in the

pressured

said

path

normal

6.2

determine

is

pressures

to

countered

deep

The pressure

about

pressure surges

deep

result

can

stopped

when

curred

the

or is

for the

is

pO.46550002325

flow

the

from

fluids

abnormally

natural

ment of

common

psi/ft

of

formation

shallow formation

Fig was encountered

flow

upward

the

which

of

density

overcome

to

Migration Effects

more shallow tion

contact

Example 6.4

needed

operations

tripping

Fluid

mud

higher

gas zone

mud

incremental be

pressure

hydrostatic

Chap

in

drill

than

structure

of

by

easily

an

would

ibm/gal

the

in the detection

The

be

drill

and

FORMATION

PORE

PRESSURE

AND FRACTURE

RESISTANCE

253

BANDONEO

IMPROPERLY

BLOWOUT

UNOERGROUNO Fig 6.9Situations

given

to

this

tance

of

the

been

and

of

the

fluid

both

migration

the

difficulties

impor have

that

method of accurately

in establishing

information

this

upward

reflection

information

experienced

providing

is

problem

where

when

needed

is

it

most

urgently For formation

must

they

utility

However has been

and

drilled

evaluate

be

Such

mation

tests

been

would

pressures

be

forced

indirect

on

an

pressure

formation

made

to

only

abnormally

is the of same as the matrix stress state more shallow normally pressured formation at depth which gives the same measured value of the porosity-

parameter

graphically

Fig 6.lOb moving

interest

line

Point

at

the

reading matrix

with

abnormal

and

have

area for

that

be used

generally of

function

as

a0

where

trend

because of

depth normal

pressure

abnormal

Detection

zone curs

before

plot

Two

basic

dependent the

approaches

increased from

the

this

be

assumption

same

of

the

effective

state

used

to

that

depth

One

similar

relation

of

in

the

matrix

of an

stress

abnormally

and

Then

depth

make

well

can

be

normal

the

use

by

plots

the

variable

Thus pressured

based

is

the

having are the

at

depth

under matrix

formation

at

is

estimated the

stress

must

be

cor

using an empirical

cor

from

trend

also

are

parameter

the

extrapolated In

plot

Points

difference

as

matrix

data

Fig

and

empirically

correlations

The more

empirical

actual

at

normal

expressed

trend

the

read

be

to

pomsity-dependent

before an

both

related

the

Empirical

normal

the

When

from

are is

correlations

porosity-dependent

interest

and

line

from

Graphical

of

of

depth

gradient

pressure

the

for

parameter

thought

of equivalent

interest

developed of

formation

calculating

considerable

area of

and

pressure

for

be

of

XIX

porosity-

approach

previously

Eq

generally

values

equal

values

trend

values

are

However

sometimes

quantitative

of

as

depth

porosity-dependent

assumption

for the

can

at

the

having

relation read

oc

than

parameter

into

transition

zones

formations

porosity-dependent

this

use of empirical

the

correlations

depths

available

departure

set

at

use of

of

plots

involves

depth

the

region

the

vs

at

recognized

transition

of

permeable

pressure from

vs

parameter

same value

are

at

Point

The pore pressure

where Uob is evaluated at depth The second for approach

departure

formation

point

Pcrob

accurate

porosity-

with

called

must

casing

pressured

the

first

Example 6.3

computed again through

empirical

departure

which

at

this

computed

is

evaluated

is

in

pressure from

Generally

easily

portion

at

depth

any

porosity

safely

estimate of

stress

the

excessively

drilled

the

of

an

commonly

because

critical

is

Thus

Fig 6.10

probable

upper

line

to

depth

pressure

with

measured and

porosity

signals

is

pressure

compacted

normal

compaction The

less

formations

pressure

in

have

decreased

the

and

pressure trend

abnormal

on

of

burial

formations

depth

is

are

should

abnormal

that

formation

in

shown

pressures

parameter

burial

parameter as

be

to

abnormal

of depth

formation

If

dependent

fact

similar

changes

detect

the porosity-dependent ted

tend

trend

corresponding

state

plot

abnormal

the

is

formation

estimating

the

than

same

the

reflects to

and on

also

porosity at

pressure

measurement can

based

the normal

to

at the

limited

only

estimates

detecting

are

pressure

higher

normal

also

for

from

obtained

is

the

by entering

vertically

depth

stress

depth

ofEq 6.1

is

pressure

The

dependent

pressure

Most methods

formations

depth

described

formation

shallow

pressured

if many measured for

engineer

drilling

is

to

Even

available

the

depend

in

possible

the

are

zones

number of them Thus to

after

lead

of

greatest

as

early

generally

drilled

the

formation

only

producing

had

have

to

as

of

possible

is

potential

wells

previous

available

measurement

direct

expensive

very

pressure data

pore

can

to

the

line

observed

XX

have

lOb

The pore

been

Departure or

ratio

developed

lines

overlays

gradients

quickly

have

based and

been

on

constructed

empirical

conveniently

porosity-dependent

parameter

that

permit

correlations

from

the

vs depth

basic

to

be

plot

254

APPLIED

POROSITY

DEPENDENT

Normally

Pressured

Fig 6.1OGeneralized

POROSITY DEPENDENT

PARAMETERX

Formations

example

showing

effect

Abnormally

of

abnormal

TABLE 6.3REPRESENTATIVE INTERVAL TRANSIT TIMES FOR COMMON MATRIX MATERIALS AND PORE FLUIDS

Transit

methods

10

formation

pressure information

val

the

during

46

Limestone

48

before casing

Anhydrite

50

methods

Granite

50

Gypsum

53

Quartz

56 62to

Pore

to

59

Fluid

Water

distilled

100000

200000

218

ppm NaCI ppm NaCI

208

Oil

Methane

6.2.1

set

is

ing

Prediction

are

data

based

from

of

Formation pore

near

14.7

psia

and

6OF

obtained are

wells

and

previous

experiences

wells

drilling

seismic data

only

189

To data

the

must

be

estimate

emphasis

acoustic

determined

computer-assisted forms

this

reciprocal is

for

of

displayed

the

in

is

placed

the

pore velocity

area

again

evaluation

before of

drill

available

When plan on

data from

For

wildcat

drilling

or

of

as

interval

seismic of depth

who

seismic

engineer

from

function

pressure

geophysicist analysis

velocity

inter

may he available

formation

average

made

seismic data

wells

by

Pressure

correlation

ning development

target

formation

must

updated

checked

are

pressures

on

910 only

planning

the

drilling

using various

primarily

nearby

After

pressure estimates

Estimates of formation

240 626

Air

VaIjd

167 67

53

well

estimates

initial

dnlling

formation

Calcite

Sandstone

Those

wildcat

and

drilling

incorporate

constantly 44

Salt

while

applicable

for

predictive

sift

Dolomite

Shale

as

Initial

method

abnormal

estimating

classified

are

methods

predictive

Material

parameter

verification

Time Matrix

and

detecting often

pressure

methods Matrix

Formations

porosity-dependent

for

Techniques mation

ENGINEERING

PARAMETER

Pressured

on

pressure

DRILLING

For

specializes

data

usually

convenience

transit

in

per the

time generally

FORMATION

PORE

PRESSURE

TABLE 6.4AVERAGE

AND

FRACTURE

INTERVAL

TRANSIT

TIME

DATA

COMPUTED FROM SEISMIC RECORDS OBTAINED NORMALLY PRESSURED IN SEDIMENTS TREND

OF GULF

UPPER AREA6

COAST

255

RESISTANCE

TABLE 6.5EXAMPLE MATRIX TRANSIT

IN

OF APPARENT DATA

CALCULATION

FROM

TIME

SEISMIC

MIOCENE Average

Apparent Matrix

Interval

Average Depth

Interval

106

1500to2500 2500 to 3500 3500to4500 4500 tO 5500 5500to6500 6500to7500 7500to8500 8500to9500 9500to 10500 10500t011500 11500to12500 12500to 13500

The

observed

cording

interval

to

the

153

132 126 118

120 112 106

and

is

val

the

transit

fluids

in

than

for

plotting

use

depths

where

Often

linear exponential

assumed

the

so line

straight

paper will

the

normal

on

83

93

73

96

13000

0.136

96

78

is

porosity-

ac

porosity

some

In

not be

more complex

for

observed

is

are

known

puted

each

transit

the

exponential

for

porosity

model of

the

time can

be

porosity

Eq

in

this substitution

vs

to

sediments

abnormally

the

normal

Solution

deeper

U.S

is

as

plotted

log-log

on

shale

for

209

shales

tion

to

matrix

vaty

time

by

trend

of

ap

pressure

psi/ft

values

coast

ft_I

of

determined

for

Example 6.2 were From Table 6.3 respectively

indicated

for

interval

these

Inserting

and

in

area

time

transit

constants

in

Eqs

in

the

0.41

and

value

of

9O000-ppm

6.4 and

6.7 gives

0.4le

-O.000085D

trend

Eq

by

of

t209t

6.4

terms

paction

constants

both

matrix

if

_KD

167

highly

is

and sufficient

in

s/ft

normal

the

with

in

entry and

ft

the

values

these

-0.0000852000

c0.41e

Table

6.4

observed

forD and

the travel

mean time

interval is

153

yields

0.346

and

153

can

2090.346

tma

122

ps/ft

10.346

addi

In

normal

pressure

Using

6.3

uncompacted

problems

data

2000

effects

shales also

depth

first

is

by

varies

Table

for

time and These

observed

complicated

also

the

depth us/ft

compaction

compacted

with travel

6.8

average

time As shown

changes

in

only

salinity

give

substituting

defined

from

results

from

for

ps/ft

formation

available

transit

travel

changes

resolved

to

for

resulting

and

of

depth

matrix can

ma

and

variance

62

is

brine

and

compaction

rearrangement

relationship

time

This

shales

water

required

Example times

graph

straight-line

developed

After

/oOfl

pressure

that

porosity

The

gulf

0.000085

pressured

relationship

approaches

normal

expression

6.7

Ima

travel

fact

of 0.465

is

in

the

fit

and

com

travel

curve

porosity

These

sands

yields

otfl normal

of

90000 ppm

area

matrix

and

Upper

ofKand

gulf coast

average

given

function

as

gradient

For

sediment

interval

depth

U.S

apparent

of

mainly values

the

the

coast

gulf

model must be used

mathematical

This

compute

consist

and

for the

previously

values

to

in

occurring

Louisiana

the

these data

Using

data

desirable

extrapolate

these

sediments

time

transit

computed from seismic records

sediments

pressured of

shales

interval

average

6.4 were

trend

proximately

it

be

normally

are

parameter

or

Table

in

Miocene

pore

transit

The

6.5

Example

6.2

porosity

acceptable of

Inter

and times

transit

semilog

any

matrix

fluid

pore

or power-law

an

cases

rock

materials

pressure trend can

observed

for interval

in the

the

shallow

cartesian

87

0.148

Since

are

112

12000

pore pressure

formations

94

0.208 0.191

93

in the

to

120

79

solids

in

88

0.226

103

matrix

model

observed

96

118

0.161

porosity-dependent

mathematical trend

pressure

126

0.246

11000

increases with increasing

estimate formation

to

100

82

time

6.3

Table

108

132

102

shown

time

140

0292 0268

106

with

transit

0.318

122

0.175

time

transit

153

10000

varies

common

for

fluids

rock

When depth

interval

given

for

in

interval

times

are

greater

time

to

the

sift

0.346

102

of

is

Time

106

sIft

103

6.7 where

Transit

Time

106

/o

2000 3000 4000 5000 6000 7000 8000 9000

140

Transit

Porosity

ft

relation

following

Average

Depth

s/ft

transit

that

parameter

Average

Time

Transit

ft

dependent

Interval

cause

com can

data

be are

Similar

shown

calculations

in

plot

Fig 6.11

Table of

for

other depth

intervals

yield

results

6.5

matrix

From

transit

this

plot

time

vs

note

that

porosity for

the

is

shown

predominant

in

256

APPLIED

DRILLING

ENGINEERING

Ui

1/

ILii

11

03

0.2

0.1

0.4

05

POROSITY Fig 6.11Relationship porosity

Miocene

between

computed trend

of

matrix

for

U.S

the

time

transit

sediments

in

coast

gulf

the

and 1.0

upper

.0

area

.2

1.1

INTERVAL Fig 6.13Pennebaker

INTERVAL

TRANSIT

TIME

1.4

1.5

TIME

1.6

t/t

RATIO

between

relationship

and

pressure

1.3

TRANSIT

seismic-derived

formation

interval

pore

time

transit

106S/ft 00

200 shale

of

lithology

matrix

U.S

the

time can

transit

be

gulf coast

the

area

average

estimated by

50 Use of

this

for

expression

209

and

1ma

for

Eq

in t17

6.7

gives

l02

S0339 the

Substituting the

yields

Louisiana

pressured

This

time

sit

Other

Table

authors

have

power-law

mally

mathematical yield

fit

computed trend

of

from the

U.S

trend

line

seismic gulf

coast

for

data

inlerval in

area

transit

upper

time

Miocene

could

made

be

approach curs below

time

transit

can

It

for

limited

ft

at

normal

time

and

depth

lithology time the

for

younger

within

to

interval

at

occur

either

for

nor

that

the

not

logarithmic

good

straight-line

range

using

either

line

straight

has been between

the

in

time

downward annears

an

which

at

to

general

that

produces

found interval

same

more shallow

produce

transit

relation

depth

shown

from

sediments

pressure trend line

sediments

and

oc

low porosity values

older

time appears

transit

on

relationship

even

Drilling

compaction

normal

given

pressure

tran

Example 6.5 does

depth

The geologic age of sediments the

surface

interval

logarithmic

be

although

departure

Significant

15000

in

extrapolation plots

for

normally

with

an exponential

model developed

straight-line

6.12

both

and

sediments

or semilogarithmic FIg 6.l2Normal-pressure

assumed

interval

pressured

Fig

the comparison 6.4 are shown also

relationship610

between

ship

in

For

from

data

6.4

for

O.000l7D

l00

plotted

0.41

to

equal

Eq

by

model

sediments

gulf coast

is

relationship

porosity

mathematical

OOOoo8sD

SO339i0e

Lu

defined

expression

following

have

affect travel

type

had

of

more

upward

shift

given

interval

depth shift

reter

in

Similarly in

which

drith

Ii

FORMATION

PORE

PRESSURE

TABLE 6.6AVERAGE

INTERVAL

COMPUTED FROM LOCATION

FRACTURE

TRANSIT

RESISTANCE

SOUTH

TEXAS

FRIO

257

AVERAGE

DATA

TIME

RECORDS AT

SEISMIC

THE

IN

AND

INTERVAL

TRANSIT

WELL

40

106S/ft

TIME

50

100

200

TREND6

Average Interval

Depth

Transit

Time

Interval

106

ft 1500

to

2500 3500 4500 5500 6500 7500 8500 9500

to to to to to to to

10500 11500

TABLE

2500 3500 4500 5500 6500 7500 8500 9500

s/tI

137 122 107

104 98 95 93 125

to

10500

132

to

11500

130

12500

126

to

6.7EXAMPLE

uJ

CALCULATION

POROSITY

OF SURFACE

CONSTANT

Depth Interval

ft

practice

geologic to

6.5

down

the

0.269

98

0.257

7000 8000

95

0.261

93

0.270

trend

pressure similar

nonnal

the

trend

in

often

or increasing

line

is

ap

down

or

up

pressure

of

the

the

by

6.10

such

as

the

normal

either

the

shown

method

from

in

interval

Verification

is

basic

up

First

vs

Fig 6.14

depth

line

for

mined

is

curves

used

time data

described

illustrated

needed

to

in

for

detail

apply

data

to

the

be

much

in

the

in

transit

time data

0.000085D

l80 2e

formations

older

Miocene

than

trend

pressure trend adjusting Solving

for0

it

line

value

the

the

the

equal

in the

0.41

to

south

formations

was

This

of

the

Texas

of

This

surface

the to

necessary

upward

mathematical

forma

Section

6.2.3

proposed

Fno

basic

well

approaches

developed

pressure discussed

model

mathematical in

in the

location

Example

-.....

for

6.5

at in the to

south Texas

9000

ft

shift

porosity

model of

the

Section

using both

6.2

normal this

trend

339

of

Extend

pressure select .4

trend

an

ap

720 50 e0t7D

the the

360 0607/

the

are

Upper normal

constant

normal

339

Frio trend

trend

was accomplished

Methods

formation

relationship

Louisiana

yields

interval transit time Example 6.6 The average data shown in Table 6.6 were computed from seismic records

Estimate

plotted

0.00017D

e00008

at

are

be

use of

estimating in

south

tor

plot

line compares these Fig 6.14 The dashed south Texas Frio trend data Since the

in

plotted

penetrated

em

made The

to

surface porosity

the

in

curve

developed

also

is

the

is

departure

measurements

be

for

pressure can

approaches

interval

Example 6.5

50339qe

or

greater

line

time

The average normal pressure trend Louisiana Upper Miocene trend was deter

the

in

transit

surface

pressure

developed

Fig 6.13

may

transit

trend

abnormal

transit

sonic log

pressure

the

Departure

interval

significantly

formation

empirically

one

using

sonic-log

of

of

is

pressure

abnormal

An

basic

pirically

time

transit

The magnitude

Fig

Solution

the

interval

trend

Frio

Exam

in

shifted

value

the

is

varying

normal

developed

trend

Texas

but line

the

model

pressure

line

lithology

6.14Seismic-derived

Fig

with

formation

computed by

tion

0.262

104

behavior

interval

predicted

dicated

shale

0.315

107

constant

When

second

122

4000 5000 6000

mathematical

by decreasing

given

0.364

shifting

normal

the

porosity

than

the

137

of

observed

In

region ple

age by

the

fit

lj

slIt

2000 3000

normal

single

sediments

to

plied

106

It

1500to2500 2500to3500 3500to4500 4500to5500 5500to6500 6500107500 7500 to 8500

trend

by

q7 line

258

APPLIED

AVERAGE

TRANSIT

INTERVAL

of

depth

I06S/ft

TIME

the

normally

same value of 00

o0

200

in

interval

6.14

Fig

from

resulting

Eq

defined by

The

formation

pressured time

transit

shown

is

load

of

ft

a0h

1300

ft

is

6.6

O-O52Pg

aob

300

be

stress

depth

at

this

having to

overburden

vertical

geostatic

ENGINEERING

DRILLING

Pfl00

O.OS2pgDs

KDc

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259

RESISTANCE

formations

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--

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FORMATION

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PORE

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261

run When

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RESISTANCE

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ticipated

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FRACTURE

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6.16

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1971

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d-UNITS

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APPLIED

262

TABLE 6.8EXAMPLE TAKEN IN U.S

MODIFIED d-EXPONENT GULF COAST SHALES15

DATA

well

as

tion

been ft

the

1.55

transparent

1.57

the

10100

1.49

10400

1.58

10700

1.60

10900

1.61

11100

1.57

11300

1.64

11500

and

ly

dOd

1.61

11800

1.54

12100

1.58

12200

1.67

12300

1.41

12700

1.27

12900

1.18

were

13000

1.13

following

13200

1.22 1.12

13500

1.12

13600 13700

1.07

13800

0.98

13900 14000 14200 14400 14600

tion

0.80

lbm/gal

15200

0.82

15300

0.87

15400

0.92

15500

0.87

15700

0.80

16200

0.80

16800

0.65

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Often

of

Rehm

11600

13400

in

plastic

dmod

scales

1.48

Numerous

concept form

152

detection

qualitative

developed

stress

d-Exponent

8100 9000 9600

the

pressure

Modified

Depth

for

DRILLING

for

the

formation

the

pressure gradient

defined

pressure gradient

by

in the

Eq

gg dmod

6.10 Recall

U.S

gulf

coast

6.14

dmod

psi/ft

where

0.465

8.94

is

the

normal

pressure gradient

for

the

area

Ibm/gal

0.052

Example and

6.8 were

tained

in shale

the

/8.94\ dmod

1.64

formation

pirical

1.54

The

6.8

Table

pressure of

correlation

empirical

correlation

in the

at

Rehm of

data

d-exponent

from

formations

d-units

\9.50

modified

computed

shown

penetration-rate

gulf coast

13000 and

ft

data

area

Estimate the

using

McClendon

in

ob

and

em the

Zamora

Solution

The The titative

modified estimate

d-exponent of

formation

often

pore

is

used

for

quan

pressure gradient

as

are

plotted

dinates

as

modified first

as

d-exponent in

recommended

Fig by

data 6.19

Rehm

given

using and

in

Table

cartesian

McClendon

6.8

coor

PORE

FORMATION

PRESSURE

AND

FRACTURE

263

RESISTANCE

EXPONENT

MODIFIED

d-EXPONENT

MODIFIED

.0

0.4

0.2

0.6

Cd-UNITS 0.8

.0

.4-

.4-

LiJ

Lii

6.20Example

Fig

IB000

modified

Fig

6.19Example

modified

d-exponent

plot

with

d-exponent

with

plot

semi

coordinates

logarithmic Cartesian

coordinates

normal

trend the

through region

line

At

dmod

available

respectively

Using

7.65

in

of

13000

from

Fig

depth read

are

slope of 0.00003

having

data

the

values

ft

6.19

these values

in

as

of

12

6.19

Figs

and

Eq

6.20

6.14

gives

pressured and

dmod

1.17

Eq

l7 16.514

logl.64

was drawn

normally

and

dmodn 6.14

gpgn

1.64

dmod

yields

l.64\

0.652

0.465

Ibm/gal

psi/ft

1.17 and

and

P0.052l4l30009464 The Plotting

use of the

Zamoras

semilogarithmic normal data depth from that

line

available

in

of

13000

Fig 6.20 at

resulting

this

ft as

depth

from

the

as

shown

in

n0.000039

was drawn

the

pressured

normally

values 1.17

of dmod

and

there different

1.64 is

no

plotting

and ft

fig

using

6.20 the

through region

dmodfl

are

respectively

significant

psig

requires

data

dexponent

coordinates

trend

correlation

empirical

modified

p0.65213OOO8476

psig

At read Note

used

the

weight

bit

changes

in

wear

difference

procedures

Since

preting in the

mud the

other type

obtained

variables

the

changed

still

plots

included

may In

create

addition

in the

new

conditions

such

variables

drilling

trend

The

the

as

utility

of

bit

problems extreme

calculation

must

effects

mud

and

speed

rotary

etc

problems Usually in

considers only

parameter diameter

be the

of

bit

density

type in

bit

inter

changes can

create

established

d-exDonent

for i.s

APPLIED

264

diminished pounds

gallon

penetration

in

increases in

shift

higher

of

fluid

density

responds

pore

overbalance

expa7h

a8

to

significantly

Under these conditions

density

cause

d-exponent This

pressure readings

the

erroneously

an

erroneous

which

plot

yields

unfortunate

is

need

for

the

6.17

since

increase

This in drilling

fluid

1974

In

to

The

parameters and

5.28a

5.28d

is

bit

in

of

by

Chapter

by

zero

69

observed

while

\a

.ea7h

6.15

\l000/

where

expx for

puted as

and

be

each

rate

model

used

and

the

quired

the

model

is

The penetration bit

weight

second

and

bracketed

be

impact

term

in

of

for

of

db

Eq

for

a7

0.41

0.30

Solution

Eq

The

theoretical

new

bit

zero

diameter

rpm It

and

WIdb

the

and

ajet

was

that

penetration

by

straight

reasonable

Chap

line

speed

would bit

F1

be

be

The

of

6.18

with

the

the

U.S

of

of overbalance

the

defined

is

by

0.4

0.3

60

1000

drillability

normal

parameter

is

defined

pressure gradient

gulf coast

equal

by to

Eq 8.94

area

lO_61290016.7_8.94 units

This

5.35 of

penetration

rate

defined drillability

parameter

per

pressure

for the

parameter

drillability

formation

the

of

definition

in

bit

unit

for

the formation

pressure gradient

of 60

be

can

gradient

Eq gp

6.15

related

Eq

using

and

6.15 solving

yields

lbf

1000

Kai a210000D

overpressure

represented

Figure

the to

speed

between

related

Young

modified

the

to

observed

weight

rotary

overbalance the accuracy diminishes Since overbalance is logarithm

a60.40

tooth

by

Substituting

with

cessive

the

a50.80

0.8

1.703.505.2

approximately

semilogarithmic

in

the

units

1.70Kg

of

effect

corresponds

relation

on

illustrated

and

following

a274x106

a8

49.875

re

.7035

that

force

could

rate

range

and

rate

the

Compute

the

using

parameter

28

6.16

k-lbf/in

impact

found

Ibm/gal

drilling

by dividing

rate

dullness of

the

31.4e041042

The modified

tooth

16.7

and

The equivalent

ioooJ

penetration

penetration

lbf

log

a8

normalized

was 51 rpm

was 0.42

6.17

F1

15

\60

\4db

drillability

bit

equation

Rexpa7h

w\

The

ft

The

parameter

35x106

a4

a8

was

bit

through

a2

and

1150

was

12900

area

speed

rotary dullness

was

ft/hr

of

gulf coast

parameter

100xl06

for

R__

the

tooth

a3

com

force

for the

rotary

values

is

computer

normalized

force

and

drillability

drillability

also

31.4

depth

at

U.S

the

at

the

of

rate

shale

force

modified

func

computations

use on

of

Kr

parameter

the

fractional

density

values

nozzle sizes

density

number

can

impact

jet

complexity

suited

diameter

jet

the

mud

the

large

best

rate

bit

dullness

of

must be

tooth-wear

using

current

Because

exponential

dullness

Also

Chap for

the

represent

tooth

interval

depth in

computed

pump

to

fractional

presented

must

used

is

The

tion

in

impact

jet

circulating the

bit

and

was introduced

d-exponent

in

drilling

was 28 k-lbf/in

computed

60

modified

9.875-in

weight

\4db

the

density

6.18

penetration

The computed

1_a5

mud

in

parameter

drillability

the

to

Example

using

mI

a3D069g

to

analogous

changes

drillability

modified

analogous

a2l0000D

Rexp2.303

The

more

in

for

a4Dpp

various

adopted

here

repeated

modified

depth

somewhat

is

account

model

in the

model

weight

using

Bingham

changes

presented

and

threshold

for

proposed the

drilling

was

Young

through

form

concise

for

mathematically

Bourgoyne

Eqs

Young model than

drilling

To

exponent

16

and

Bourgoyne

compensate

drilling

parameter

density

more complex

ENGINEERING

logR

several

is

formation

the

excessive

the

longer

modified

confirm

to

than

pressure

drilling

the

pore

tends

it

formation

in

changes

no

rate

mud

the

greater

Because

pressure gradient the

when

especially

per

DRILLING

was

plot

discussed

However the

for

straight

more

directly

Bourgoyne given

6.19

a4D

a3D069

over

by

in

ex line to

and

The

coefficients to

cording

Young6 computing drilling cients

a1

local

presented the

value

data obtained a3

through

through

a8

chosen

ac

Bourgoyne

and

must be

a8

conditions

drilling

multiple regression of in

these the

constants

area

often can

be

In

technique from

addition

for

previous the

computed on

coeffi

the

basis

265

PRESSUPE

PORE

FORMATION

FRACTURE

AND

RESISTANCE

a5

54

1O

90x

cluen

Values

are

1O

35x

bds

loath

milled

for

10

IN

0.5

0.9

Use

or-dy

TABLE 6.10EXAMPLE PARAMETER OBTAINED

l0

Coeffictents

Regression

lOOx

PARAMETER

DRILLABILITY

MODIFIED

OF REGRESSION VALUES TABLE 6.9AVERAGE DRILLING MODEL OF BOURGOYNE-YOUNG COEFFICIENTS U.S GULF COAST AREA FORMATIONS IN FOR SHALE

0.4

brls

nsert

for

0.3

MODIFIED DRILLABILITY SHALES U.S GULF COAST Modified

Depth

Drillability

Parameter 1.76

9515 9830

observed

of

in

change

10250

1.58

10390

1.80

10500

1.85

10575

1.72

10840

1.82

10960

1.83

11060

1.83

11475

1.92

11775

2.49

11940

3.95

12070

3.99

12315

4.50

12900

5.15

12975

5.22

13055

5.28

13250

5.43

13795

5.27

14010

5.65

14455

5.55

14695

5.69

14905

5.86

in

of

one

the

and

from

mined graphically mally available

to

average

in

given

basic

a2

usually data

If

no

that

technique

he deter

can

in

nor

data

are

obtained

a8

through

a2

6.9 can

Table

by

Examples

previous

coefficients

determine

values

the

drillability

formations

pressured

variables

drilling

illustrate

Chap

caused

rate

the

modified

6.21Example

Fig

penetration

used Coefficients

be

can

IL

1.80

changes only

5.8

5.7 and

1.82

10130

90X

10

from

the

read from

depth

the

of 8.94

dient

line

trend

normal

ft At

10000

Coefficient

units/ft

Eq

plot Ibm/gal

for

to

reference

ft

U.S

the

read

normal gulf

be

of

depth

pressure

coast

1.94

of 5.15

value

with

6.19

is

a1 the

at

13000

of

plot

driIlability-Parametel

area

is

gra

yields

8.94

gp

used

be

94_90X106l000Ol3 35X 10 613 000 106X13000O69

15I

shown rate

in

obtained

The

area

intervals

depth

6.10

Table

in

data

coast

modified

6.10 The

Example

were

computed

shale

formations

values to

of

from in

in

fluctuations

dampen

penetration

U.S

the

for

computed

were

bOX

data

parameter

drillability

computed

the

15.6

gulf

Ibm/gal

50-ft-

where

results

Estimate

the

formation

trend line

10

35 lected

by on

The

plotted

diniteu

was determined exponent

regression

previous

Solution are

a2

overbalance

average

as

model

drilling

Bourgoyne-Young mal

pressure

wells

modified

shown

The nnrmal

in trend

a4

analysis

in the

line

be

90x

the

drilling

data

to

be

6.21

using

data

cartesian

was drawn with

psig

col

that

sometimes

first

coor slope of

increase

ing movements fragments both

give

in the

and

lower drag

part

tend

of to

or accumulations the

borehole

increase

slowly

rate

pore-

during

vertical

during fill

penetration formation

torque

rotary

drag hole

and

of

indication

an

include

frictional

torque

other than

data

performance

Drilling

pressure

parameter

10546

0.052U5613OO

nor The

10

was determined of

the

using

slope of

The to

ft

area

drillability

Fig

13000

at

drill

drillstring

of

rock

Normally with

well

00

cp

11

nl

In

nl

r\

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I-

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SABINENSIS PSEUDOMENAPDII

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CI

60

59

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57

56

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52

SI

48 49 SO

47

45

44

43

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59

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55

49

50

6768694

65

62

53

56

47 51

52

ni

-1

JJ

ij

C/

ij

ii

268

APPLiED

However

depth an

of

interval

torque and tion

or

differential

pressure

overload

fluid

from

After

can

the

cause of

sides

the

in

problems

other

can

increased

these

than

However

symptoms

abnormal

torque

formation

drag

hole

or

with

drilling

become

drilling

numerous

also

pressure

the

shale

is

the

of

valuable

formance

data

may be required from

to

travel

The

approximate

from

careful

pump

the

quired

increase

of

the in

the

at

normal

Graphical

mud

the

Usually

in correlating

formations which

formation

in

about

the

fluids

in the

and

and

of

the

to

ab

well

in

wells

the

in

formation

the

area

for

Information of

formation

com

of

detection

well

as

fluids

lithology

in

as

the

Analysis The

lecting

fresh

rock

regular

depth

intervals

and

studied

minerals soaked

in

under

be

to

the

from

formation certain

presence lithology

key

solutions

by

being

drilled

other wells

marker

drilled

formation

of of

microfossils

Variations

Louisiana present

in

size

is

type of

fragments that

in the

can

cases area

be

gulf coast

shown

in

and

are

further

present of

that

may

it

area

along

screens

and

or

diesel

of

include

properties

content

Shale

received

cutting

on

ap

measurement

determination

which

of

is

or kaolinite

the

the

cation-

when

greater

As

clays

discussed to

of abnormal

origin

ex

an

widespread

chemical

shale

indicate

Commonly

gradient

sample one

oil

in

illite

is

formation

screen

are

may of

the

are

larger

brought

on

the

the

surface

Care

from

the

liquid

must

and

reduces

exercised

bulk

the

screen

not

from

the

den

affected

as

blotted

warm

dark to

to

cuttings

are

with

to

cut

larger

the

be

blown

then

sheen be

The

pressure

20-mesh

on

towels

paper

of

pass

20-mesh

shale

to

thought

release

caught

surface

pearance water

the

oil-base that

on

Also

depth

of

water

either

cuttings

held

are

the

series

water- or

shale

sloughing

is

cuttings

from

on

with

processing

or

by

cuttings

quickly until

to

further

unknown

an

at

extent

The

for

spalling

screens

whether

and

taken

placed

used

methods

these

all

is

are

Only

screen

retained

walls

greater

on

used

being

be

the

is

or

The procedure

for

cuttings

then

through

4-mesh

tings

of

quart

commonly

mud balance

cuttings

similar

is

depending is

shale

cuttings

washed

through

of

mercury pump column liquid

The

fluid

drilling

of

Mercury imately

the

the

Fig 6.22 volume

the

fluid

be

general with

to

density

Approximately

the

by

chemical

can

diagenesis of montmorillonite

by

drilling

The

The

pattern

primarily of montmorillonite

related

hulk

prepare

below

identified

drilling

and

successfully

not

the

the

chlorite

variable-density to

abnormal

just

the

remove

air

ap

dull

pore

shale fragments

the

identification

microfossil

shape

the

so

encountered

which

particular the

some

at

is

of

composed

the

used

common

most cuttings

be

measured

washed

Identification

allows

In

is

shaker are

microfossils

any

often

pressure generally

rock

the

or kerosene

screening

mierofossils

formation

known

of

by col

shale

then

determine

to

occurs allowing

and

the

fragments

portion

detergent

separated

minerals

The

microscope

present

fragmentation

from

fragments

determined

is

lithology

than

incom

pressure

borehole

pressure

Spalling

fracture

which

physical

has

but

illite

to

thought

been

18

capacity

6.1.3

sity

Cuttings

shale

is

and

off

inch

splintery

physical

moisture

has

The

than

are

progress with

known

in

well

informa

of

concentration

helps

by

formation

the

are

the

displays

knowledge

accumulations

of abnormal

plication

is

many

and

by

shale

an

chemical

wall

pressure

porosity-dependent

made on

more

cuttings

formation

basis

Sec

shale

on

density

exchange

spall

surface

the

concoidal

makes

also

logger

in

rather

has

also

to

than

under

perimental

ap

collected

from

log

previous

fluid

drilling

hydrocarbon

detection

mud

and

bulk

the

borehole

the

permeability

begin

from

results

greater

microscope Examples of spall sloughing shale are shown in Fig 6.23

mud

The

circulated

pressures

composition

as

shale

at

and

more

and

greater

thinner

At

sometimes

low

fragments

over

continually

becomes

pressure

observed

which

apparent

The

be

shale

in

gra

be

tendency

information

the

bottom

penetrated

the

mercial

the

of

fluid

drilling

the

can

using

is

ing

possible

drilled

lithology

in the

present

obtained

between

fluid Spalling

also

of ascertain

the

patibility

resistivity

performance

methods

Thus

as

fluid

drilling

logs

about

tion

results

is

provide

pressure gradient

presentations the

monitoring

indirect

indicators

obtained

pressure

drilling

shale

measured

re

can

drilling

pressure

angular

Fragments

longer

sloughing

changes

time

can

it

often

computed cumulative

borehole

while

the

pressure while shale

large

the

measurements

reinforce

formation

of

length

that

cut

fluid

drilling

formation

lag

be

in

formation

the

shale appears

surface

pressure gradient

the

confidence

collective

can

and in

from

formation

pressure

called

formation data

and

can

it

available

with complete

look

in

be

delay or that

because

was not evident

changes

aids

information

rock

the

the

depth

per

several

and to

must

The

drilling

fluid

which

time

the

provide

because

well

the

drilled

possible increase

None

plied

of

drilled

of

performance

of

that

ing

of

spite

valuable

drilling

warning

data

In

of an

dication

dient

records

the

as

drilling

from

were

additional

extremely

the

can

fluids

formations

timely

bottom

fluids

strokes

as

depth

and

fragments

well

previously

for

the

the

evalua

formation

subsurface

not

discussed

tings

the

is

and

from

about

provided

continuous

fragments

pumped

information

information

hours

rock

fluid

drilling

Data

Logging

formation

the

the

in

Mud

of

Analysis tion

If

formation

cuttings

more

thinner

As

decreases shale

indica

provide

increases

density

the

overbalance

drilled

sides

zone

hole bottom

the

can

also

pressures

fluid

drilling

longer

than

fluid

formation

transition

across

reduced

fill

drilling

the

in

constant

balance

shale

the

abnormal

pressure

borehole

the

of

tions

connec

large

in

fragments

in

be observed

may

well

over

increase

upward carrying capacity of

the

resulting

cause

also

fill

the

away

sudden

observed

is

hole

into

break

to

fragments and

made

is

underbalanced

shale

sometimes

drag

trip

becomes

well

the

if

impermeable

ENGINEERING

DRILLING

shale

upper

first

piston

position

is

used

chamber of

air

level

is

of

sample

usually

mercury

pump the

Purap 25

in the

lowered

to

to

marked

indicator in

crements

An empty

weighing

determine

mercury lower

bulk

starting

level

point

sample

cup

on

mercury is

the

6.24 mercury

by withdrawing

piston-position

displaced

approx volume in

pump Fig

chamber of

reference

The

0.01-cm3

calibrated

cuttings

to

placed

the

piston-

indicator

volume in

the

is

in

lmnner

FORMATION

PORE

PRESSURE

AND

FRACTURE

shale

Spalling

variced

The

with

the the

between tings

chamber chamber

the

piston

6.23Examples

and

denoted

25-g

sample

second

Thus

read

is

readings

is

to

given

V2

24

the

to

is

in the

as the

gives

is

piston

sequence

cuttings

denoted

is

The

pressurized

This

as

bulk density

the

is

of shale

reading

two

the

closed

is

air

indicator

position

0.01-cm3

and

the

until

shale

Sloughing

Fig

chamber and

269

RESISTANCE

of

ad

psig

nearest

and

shale

sloughing

in the

was placed

cuttings

cm3

34.24

density of

the

cup

sample

obtained

was

scale

the

Compute

reading of bulk

average

sample

repeated

sample

cup

The difference

volume

spalling

12

of

Solution cuttings

The average bulk density of the sample 6.20 can be computed with Eq

of

shale

cut

the

by

2__2.27gIcm3

Pch

45.334.24

msh Psh

V1

where

mSh

6.20

V2 the

is

of

mass

shale

used

cuttings

in

the

Mud

Balance

Sec

sample

ty

of

Chap shale

similar

Example 6.11 reading cup

of 45.30

in the

air

mercury

cm3

chamber

at

injection

24

When

psig

pump

with

25

an

scale

gave

empty

l3-g sample

sample of

shale

to

balance of

the

is

shale

equal

standard

sometimes

cuttings that

dry mud

clean

The

for

Shale the

balance to

cuttings

the

is

mud

balance

used

to

cuttings

until

the

density

in the

prepared

pump

mercury

of

balance

described

measure

density

are

in

is

manner

placed

indicated

water Thus equal

to the

in

densi

the

in

by the

the

mass

mass

of

APPLIED

270

AND

-VENT

FULL

CHAMBER

ENGINEERING

DRILLING

INDICATOR

CHAMBER

It

PISTON AD VAN CE

Fig

volume of water

6.24Mercury

to

equal

the

total

cup

pump used

volume

in

volume

bulk

determining

of

Vi

Psh Vh

mSh

__________________

PwVt

where

is

the density

this

Solving

of

water

for shale

equation

volume

and

6.21

dicates the

with

the

then

cap

pressed

of

is

on

cap

water

mixture

and

mixture

to

added

when

water

fresh

the

is

been

and

stirred

is

replaced

cuttings/water

have

cuttings

mud

the

density

The

cup

mud

shale

enough

balance

to

the

is

added

remove any

average

in

to

fill

The

air

/m

density

determined

obtain

rider

can

be

umn

liquid

five

shale

PmPshpw Substitution into

of

Psh

density

shale

above

the

volume

equation

VSh

and

defined for

solving

by the

Eq shale

yields

Bromoform

the

graduated

at the

as

place

water air

all

is

is

and

Shale

the

density

added

bubbles

determined

density of

the

have be

to

is

achieved

indicator

the cup

to

are added

cuttings

balance

until

been 1.55

and

the

reads

gfcm3

shale cuttings

1.0

mixture

removed

clean

is

stirred

until

The mixture density the Compute average

is

pipette

to

the

over

above

just

beads the

Use of

Eq

6.22

gives

to

fill

are

is

the

quence

is

1.02

Psh

2.22g/cm 2.0 1.55

6.25 rod

uniform

allowed mixing

the

until

the

then to

across

is

stand the

the

to

stirred

cross

section

After

calibration

As

depth

with

as

this

This

indicate

hour rf

lifted

density

separate

with

is

released

liquid

beads

the the

thumb

the

pipette

is

in

cylinder

with

the

are

is

allowing

slightly

about

spread

28

pipette

Brornoform

variation

for

are to

pipette

Again

calibration

density

that

2.0

lifted

top of

begin

leaving

graduated

solvent-rich

beads

linear

The column

and

into

calibration

repeated

the

of

the is

where

Slowly

lifted

proximately

the

pipette

grouped

pipette

of

mixing

stopper

10-mL

the

thumb

elevation

the

of

is

keeping

capacity of

the

solvent

range

Bromoform

the

while

densities

the

end

the

tilted solvent

percent

clean

the

into

The

excessive

with

as

graduated

of

known

over

in

filled

air-tight

bottom

the

with

of

an

column

the

specific

such

prevent

filled

for

with

inserted

end

to

by careful

solvent

Bromoform

the

is

top

thumb over

the

pipette

done Solution

disre

having

poured

is

60%

is

tilted

possible

into

thy

the mud cap g/cm3 Fresh

the

beads

as

slowly

with

to

with

to

are

be obtained liquid

Twenty

cylinder at

space

evenly

it

top of

cylinder

graduated air

first

interface

liquid

serted

balance

is

fragments

results

low-density

until

on

slowly

dropped

mud

Usually prepared

clinging

or trichloro-ethane

cylinder

Calibration

Example 6.12

cut col

the

each

five

the

dense

with

2.S5

graduated

20% 6.22

the

shale

some

with

observed

column can

cylinder

the

Psh

from

of

are

the

recorded

is

column

the

carbon-tetrachloride

poured

6.21

in

Bromoform

of

gravity

VlVh

point

density

Since

contact

selected

bubbles

variable-density

mixing

ly

by

Vh

rest

average

fragment

same

until

fall

of

density

prolonged

are

air

the

column

the

with

density

garded

of

ex

the

into

the

are

by

initial

When

reported shale

the

increasing

which

liquid

altered

fragments

and

sample

the

be

may

column

variable-density

an

dropped

at

depth

fragments tings

sh

fragments

reach

they

Vch gives

has

that

liquid

Shale

depth

Vsh-V When

Column The

Variable-Density contains

in

cuttings

balance

the

the

shale

of

is

se

ap Fig

stirring for

more

th column

FORMATION

PRESSURE AND

PORE

FRACTURE

RESISTANCE

271

250

SHALE CUTTING

CALIBRATION DENSITY

.--

BEAD

2.90

2.70

2.30

2.50

2.10

DENSITY Fig

The

column

variable-density

used

in

used

in

hood The

fume

column

the

be

should

be

and

sealed

in

bulk

determining

of

density

shale

cuttings

hydrocarbons

should

be

not

when

tightly

used

g/cm

and

prepared

halogenated

toxic

are

The column should

column

6.25Variable-density

I.70

1.90

not

inhaled

in

use Ui

6.13

Example

Five

column

variable-density at

stopped graduated

mine

the

the

shale

150

cylinder

bulk

in

reference

following

average

fragments

shown

155

6.25

marks

on

145

and

160 of

density

the

into

dropped

Fig

the

initially

250-mL

the

155

Ui

Deter Ui

cuttings

3-

Solution

ing

use of

By

Fig 6.25

and

shale

the

the

calibration

calibration

densities

are

constructed

curve

beads

density

the

in

follow 0.3

indicated

SHALE

U-

Bulk

Reading

Fig 6.26Boatnian

g/cm3

150

2.32

155

2.30

160

2.28

145

2.34

shown

155

2.30

approach

in

for the

five

bulk

density values

for

the

Fig 6.26

by

Eq

terms Shale

density

is

When

the

shale

falls

line

for

bulk

of

magnitude either for

the

of

density

significantly

shale

the

the

estimate formation

of

abnormal

the

example

developed

normal

pressure

is

pressure can

two basic approaches

curve

of

pressure

be

in

The

estimated by previously-

10

Fig

such

as

the

needed

model of

6.4

the

exponential

for

porosity

this substitution

to

the

normal

Eq

second

basic

trend

compaction

can

cuttings

pore 17

cuttings

the

apply

be developed

expression

porosity

in

formation

shale

of

6.3a

by

defined

After rearranging

yields

PshnPgPgPflo

-KD

pure trend

indicated

discussed

illustrated

departure

pressure

composed

cutting

below

abnormal

generalized

empirically

to

depth

is

density

that

parameter

porosity-dependent

is

vs

plotted

bulk

bulk density of shale

substituting

between

relationship

and

pressure

mathematical

often

0.6

PShfl-p5hg/cm3

Density

mL

The average shale density shown is 2.31 g/cm3

05

0.4

DIFFERENCE

DENSITY

An one

where shales pore

Pshn

The

fluid

Constants density

is

the

shale

grain

density

Pfl

and measurements

formations

for

density

density

of pure can

can

be

made

be

found

based in

normally

shale

the

on

is

pressured

2.65

from

Average

Table

shale-cutting

normally

6.1 bulk

pressured

272

APPLIED

TABLE 6.11BULK DENSITY DATA FOR SHALE OBTAINED ON SOUTH LOUISIANA WELL VARIABLE DENSITY LIQUID COLUMN19

SHALE

CUTTINGS USING

Psh g/cm3

DENSITY

20

ENGINEERING

DRILLING

2.2

2.4

Bulk

Depth

Density

fi

glcrn

2000

6500 6600 6700 6800 6900 7000 7100 7500 7700 8000 8200

2.38 2.37 2.33 2.34

4000

2.39 2.39

.35 2.41

237

6000

2.39 2.38

8300 8500 8900 9400 9500 9700 10000

2.34 2.34

8000

2.41 2.41

Ui

2.41 2.44

I0L00

2.44

10500 10600 10800 11100 11200 11400 11600 11900 11950

2.45

12100

2.44

12300

2.30

12400

2.21

12500

2.23

12600

2.22

13000

2.29

13100

2.26

2.42 2.46 2.44 2.44

iajoo 2.45 2.44 2.46

4000

2.42

13200 13400

2.42

13600

2.40

13800

2.28

6000

Fig

14300

2.38

15000

2.38

15700

2.39

16100

2.42

Application the

normally

the

6.11

6.14

were

south

in

umn

bulk

determined

for

Louisiana

Determine line

trend

The

determined

Solution

shown which

in

of normal of

the

shale density

Fig

6.27

to

formations formation

be expressed density

grain density tion

of

of

1.074

for shale

in

the

establish

are

terms

pore

plotted

the

normally

in

the

pressure

relationship

This

and

depth

vs

interval

to

normal

an

gives

by

6.3b pore

following

sh

P3h

1.576

and

the

in

the

An ac was

trend

of

ob line

Example

use

in

gives

6.2

surface

0.33

of

c130

data

the

porosity

obtained

ft

6.28

Fig of

average

to

11000

values

following

for

and

Pfl

nor

for the

expression

2.651 .O74O 33e

-0.0OO085D

for

2.65 O.52e

depth

The

At

with fluid

Psh

trend

depth

and

Boatman equa

defined

line

pressure

is

in

psi/ft to

of

13000 obtained

ft

given

the

values from

gives

Thus

in

plotted

of

Fig

as

2.28

6.27

Fig 6.26

formation formation

be

p0X6ROflfflrii

is

equation

the

normal

Fig 6.27

are

correlation

estimated

0.tXiO085D

this

by

line

2.482.280.2 of 0.86

2.65

the

corresponds

yields

as

pressure region

average the

to

6.23

above

mal pressure trend line

The zone

extend

Eq

Eq

12

plot

shale density data

the

representation

of appropriate

2.65

depth

Table

gulf coast

shift

porosity constant

at

pressure

pressured

of porosity

g/cm3

g/cm3

porosity

col

Substitution

empirical

is

Louisiana

upward

in

the

first

the

The

to

fonnations

upward

shifting

shale-density

equation

in

drilled

liquid

normal

formation

pressure appears

2.65

well

this

straight-line

by

Table

Fig 6.26

ft 12000 The shale density data

can

for

equation

Boatman

by

The

the

an

in

for

on

cuttings

tained

shown

variable-density

compute 13000 ft using

of

depth

shale

using

Also

data

density

of

pressured

shown

results

ceptable

Example

6.27-_Example

2.25

1Rflnir

for

and

Ph

pressure

pressure

2.48

for the

Entering

at

Psh

gradient

13000

ft

FORMATION

PORE

PRESSURE

SHALE 0.05

AND

FRACTURE

273

RESISTANCE

POROSITY 0.2

0.1

0.3

0.4

LAMP SSEM6Lt

HEAT 0.5

TEMPER4TURE ond CONTROLS TIME

2000

4000

6.29Ohaus

Fig

balance

moisture-determination

6000 Moisture

Content

lhe

moisture

Ui

can

tings

be

balance

8000

tings

with

the

shown

such

are

as

is

size

1000

as

for

placed

on

show

to

loss

weight

stabilizes

dicating

that

the

the

12000

to

6.28Example

shale-porosity

pressured

line

in

normally

of water

in

loss

as

density

and

of

TABLE 6.12EXAMPLE COMPUTATION OF AVERAGE SHALE POROSITY IN NORMALLY PRESSURED FORMATIONS

Thickness

ft

Bulk Density

Average Porosity

mixed

assumption

8200 8300 8500 8900 9400 9500 9700

the

be

content

and

minerals shale

without have

shales

such

as

g/cm3

pyrite

and

structure

2.65

be the

This allows

older

the

the salts

can

porosity

determined

of

of

to

equal

centimeter

Some

density

shale

moisture

to

within

grain

is

the

cannot

be

made

in

be

Exactly

10

of

and

the

bulk

pump

mercury

4.20cm3

0.178

sample

2.33

0.203

content

2.34

0.197

sample

2.39

0.165

2.39

0.165

2.35

0.190

weight

stabilizes

reading

The

Solution

2.41

0.152

proximately

2.37

0.178

Thus

2.39

0.165

2.38

0.171

2.34

0.197

2.34

0.197

2.41

0.152

2.43

0.140

2.41

0.152

2.44

0.133

10000

2.44

0.133

10500

2.42

0.146

10600

2.46

0.121

the

to

water

volume was

4.2

the

cubic

weight

volume

cm3

in

the

is

the

of

is

ft72

17.1%

100%

Alternatively

since

the

bulk density

10

Psh7238

g/cm3

of

is

to

moisture-

in

the

drying

moisture-

porosity

centimeters

water

cm3

0.72

porosity

placed

determined

rendering

Compute

volume

water

equal

is

placed

minutes

9.28

at

7.2%

of

is

are

cuttings

volume

After

balance

0.171

2.37

shale

then

l0-g sample

determination 2.38

is

to

directly

of the dissolved

the

of heavier

g/cm3

6500 6600 6700 6800 6900 7000 7100 7500 7700 8000

weight

milliters

the

cutting

density

of

Example 6.15 Sediment

the

grain

calcite

of

product

high concentration

formation

in

effect

grams per cubic

in

porosity

assuming

the

neglected

is

the

loss

If

grams

sample

determined

the

by

in

minutes The balance

lost

content

the

The

noted

0.1

in the

bulk

water

is

about

after

has been

and

sample

loss

pore-water

moisture

the

volume

weight left

all

read

nearest

The

trend

from

resulting

sample

0-g

the

above

tile

lO-g designed

is

for

zero

placed

is

in

measurement

The balance

of

cut

Shale dried

and

screened density

content

cut

shale

Fig 6.29

in

balance

the

moisture

sample

scaled

Fig

bulk

The drying lamp

weight

4000

washed

collected

same manner sample

one

of

content

moisture-determination

determined

loss

Since

in

of

the

is

ap

grams

the

bulk

TRAP

GAS

SHALE

FLOW

AT

SHAKER

MOTOR

AGITATOR

Fig

the

is

porosity

given

REGULATOR

6.30Mud-gas

by

detection

system

bitrary

7.2%2.381

17.1%

placed

is

significance

capacity of titration

are

discussed fluids

API

in

Fluids capacity

milliliters

of

of

In

shale

normally

the

pressured

montmorillonite

to

content

zone

the

that to

of

water

is

in the

of

concentration

the

by

water

interlayer

abnormally

is

to

high

il

pore

pressure

Mud well

as

in the

hose

drilling

the

draws

Increase

defined

removed gas-trap

fluid

fluid

An

and

usually

of

air

agitator

is

of

transmitted values

to

cataytic

hydrogen tor

filament

present

The

flame gas

that

Some

the

detector

recorder

in

on

the

borehole

to

all

newer

place Ic

of

to

the

ci-qled

the

is

enter

fluid

the

the

exceeds

it

at

during

This can

be

least

The

gas

trap

minimal

is

allows

is

small

Typical

combustible

employ

hot wire

detec

time

make

which required

of are

occur to

making

term

used

to

be

to

the at

time

trip

denote

fluid

the

for the

of

intervals

one trip

new

base-line

of

peaks

is

fluid

drilling

relatively

of

examples

drill

pipe and

which

Background gas detector

gas to the

corresponding

gas

oc

fluid

connection

joint

bit

surface

circulation

in

Common

to the

zones

the

drilling static

an

drilling

movements

pipe

and

by

the

drilling

the

the is

increased

of

concentrated

down

and

has

to

detection

drill

the

into

borehole

circulated

by

fluid

drilling

connection

after

periods

seepage

behavior

peaks employs

any

volume

such

such

during

the

and

characteristic

by

vertical

caused

pressure

the

portion

detected

upward

from

bit

pressure caused

the

periods

and

stopped

into

pressure

where

to

correspond

the

formation

formations

fluids

formation

the

by

was

curred

The

million

per

parts

fluid

drilling

that

to

to

C5

computed

exposed

of

seepage

where

operations

the

chromatograph

in

the

destroyed

from

fluids

that

point

at

water-base

as

through

component plotted

placed

85%

units

each

The

indication

trap

Fig 6.30

of then

well

of

vacuum

that

removed

gases

chromatograph

withdrawn from

is

gas

concentrations

gases

of

seepage

into

injected

of the rock

fluids

gas

detector

in

the

efficiency

gas

mud log

Formation pore

vapor

being

mud

the

from 50

the

usually

in

gas

responds of

into

Gas-trap

gas

range

the

the

gas

as

then

of high gas concentration

is

well

built

efficiency

The hot wire gas detector shown gases

depth

muds

oil

the

system

by

gas trap the

gas from

usually

from

detected

are

from

and

percentage

efficiency

circulated

Fig 6.30

in

gas-trap

the

gases

returning

mixture

the

as

Formation

shown

one

drilling

gas detector to

mud

drilling

Gas Analysis

such

of

the

in the

the

parts

much

of montmorillonite the

and

still

in

transition

at

of

composition

for

of

sample

decline

the

the

made by means of

is

successfully

muds determine

this relationship

held

tightly

mud

of

decrease

explain

used

steam

measured

as

to

conversion cause

primary

to

In

of

analysis the

diagenesis

gradual

content

more

the

the

depth

observed

is

One hypothesis

release

pore

lite

usually

rate

the

with

in

titrate

shale factor

the

in the

changes

detected

The technique used is by one company illustrated in Fig 6.31 mud sample is placed in steam-still reflux where most of the chamber are lighter hydrocarbons from the mud as vapor This method can be separated

in the

to

practice

for

cation

required

relative

In

from

reported

cuttings

blue

causes

illite

The

on

only

the

by

differently

the

instruc

included

is

sediments

montmorillonite

factor

faster

shale

with

detailed

Manual

called

is

montmorjllonite

shale

which

An

exchange

Chap

more

methylene

sample

Sect

in

Also

RP13B

of

0.01

cation

be determined

Laboratory

exchange

100

can

cuttings

drilling

given

Drilling

The

Capacity

shale

procedure

clay/water tions

the

defined

are

manufacturers

gas-detector

concentrations

Cation-Exchange

which

units

gas

various

sh

ENGINEERING

DRILLING

APPLIED

274

occur

gas

is

readings

PORE PRESSURE

FORMATION

AND

FRACTURE

275

RESISTANCE

Ref lux

Condensing Unit

PLOtS_

Mud

MudT

c23cC

c1 .J1

ft

it1 ppm

6.31Flow

Fig

Connection

mud from is

the pore

Methane

well

as

the

C2

The gases

can

also

Cuttings of

traces

be

fluorescence use of

Both

leaching

certain

the

com

test

for

crude

for

light oils

exhibit

The

wavelengths to

necessary

bring

be

can

it

the

deposit

ultraviolet

where

oil

detected

to

by

fluorescence

and

make

reach

of

results

vs

for the

of the

the surface originated

most

accomplished cumulative

pump

of

the

strokes

of

the

hole

nection Note

gas

also

drilled

at

CG the

6300

Drilling Fluid cedures

ft

the

well

rock

to

The

also

causes are

Note

and

occur peak

the

on

the

of

the

record

approximately

TG

formation

peak

to

the

ft

the

Fig 6.32

in

at

This

of

from

sample

deter

hole

increments

In addition

sample

observed

keeping

that

gas

the

30 to at

of and

bottom

con

the ft

apart

the

6500

analysis

fragments

is

and

sand ft

pro gas

have

Sec

the

into

from

returning

in

the

more gradual

mud

Periodic

decrease

in salinity

most accurately an

AgNO3

Since

stream

in

as

salinity

probes

resistivity

to

by

solution

change

resistivity

mud

the

in

much

with

from

fluid

drilling

determined

change

monitor

continually

of

abnormally

changes water

high

tends low

to

increase

returning

in the

with

from

time

the

higher geothermal tunately

of

the

bit

also

data

temperature

the

affect

fre

well

the

be

to

the

Unfor

zone

from

returning

mud

the

reflects

run

transition

variables

mud

geothermal

of

temperature

the

of

the

to

ab

an

zone In some cases

during

other the

causing

the

and

conductivity

This causes

in

well

formations

these

transition

gradient

many

temperature

content cause

thermal

high heat capacity to

increase

quently

forma

of

formations

mud

than

greater

influx

salinity

Chap

abnormally

gradient the

the

cause

sample

formations

normally

the

causes

fluid

is

abnormally

an

enters bit

dilution

mud

placed

pressured

must

logger

for

sample

corresponding

trip

analysis

the

increase

in

often

that

as

of

resistivity

significantly

drilling

salinity

discussed

salinity

much

slow

of

such

titration

is

salinity

fluid

pressured

by

in

water

the

water

treatments

or

salinity

abnormally

increase

abnormally

density

drilling

cause

destroyed

change

the

the

from

water

The

Fig 6.32 To

mud

of

detect

to

mud

other

fluid

drilling

include

formation

the

salinity

wellboi can

combustible

calculation

the

depth

pump

Analysis

performed

by

at

to

peaks

in

the

bottom

surface

larger

shown

depth-lag

easily

required

to the

is

time required

the

strokes

total

chromatographic

when

bit at

both

depth

lag

The

surface

the

the depth

the

of depth

parameters

allowances

mines

showing

log

function

these

plot

to

the

as

plotted

When

the

measured

and

temperature

tion

from

are

formations

pressured

for salinity

mud

sample gases

that

Formation and

liquids

further

and

often

is

agents

and

ultraviolet

of the cuttings

in

that

hydrocarbon

under

separated

the

water

hydrocarbons

analysis

properties

as

gas because

and

separation

samples

penetrated

as

refined

bit

mud-gas

den

aquifers

and

indicative

commercial

the

by

formation

crushed

examined

are

under

the surface

be

analyzed

of

oil

more

are

can

cuttings

present

the

the

fluid

drilling oil

deposit has been

hydrocarbon

possible presence

when

in

by

enters

drilling

the heavier

in

that

destroyed in

mostly

in

gas

range

drilled

rock

the

suppressed

Gas

increases

occur

increases

through

mercial

of

containing

dissolved

be

density

by can

peaks

formations

Simultaneous the

fluid

unaffected

sity

gas can

trip fluid

drilling

relatively

of

and

gas

the

creasing

of

diagram

09

difficult

to

in

terpret fluid

Drilling significantly ing

fluid

In

fluid

density

used

as

course

density

when

reduced

rough the

at

indicator

use of

gas

is

gas

entrained

extent by

the

some cases is

from the well

returning

formation

the

of

which

surface by the

detector

mud

decreases

in the the

drill

drilling

entrained gas gas

generally

content

gives

is

Of more

APPLIED

276

ENGINEERING

DRILLING

SAND FRACTION

METHANE ETHANE PROPANE BUTANE

PENTANE HEXANE

LIME STONE FRACTION

Fig

6.32Example Courtesy

satisfactory

discussed on

of

presentation

hydrostatic

pressure

the

in the

well

Verification

of gas-cut

mud

small

quite

log

Laboratories

Formation

of

Pressure

The decision of when to stop ment casing in the well

most

formation

drilling

drilling

operations

economic

set

too

be

required

high

much

higher

size

If

to

an to

key

decision

of

drilling

unplanned reach

well

casing

underground

is

success

costs is

blowout

stop and

could

depth

and

not

both

in

additional

the

set

may

with

casing

when occur

it

casing

final

needed

is

can

plugging

be and

Ifl

well an

ver aban

is

formations

generally

have

pressure

select

of

the

extremely

by

made

knowledge the

best

to

running for

developed of

the in

These

drilling

valuable

in

from

pressure

well

of

casing-

the

are

either

formation the

sonde

made

wells

transit

The

verifica

during

in the

parameters

estimation

interval

for

estimating

pressure estimates

for

of

Em

porosity-dependent

manner allow

future

conven

records casing

well-logging

this

planning

logs

with

logged

permanent

previous pressure estimates and

The porosity-dependent obtained

prior

some

measured

is

provide

been

from

pressure estimates

planning

to

penetrated

methods

mation

pore

accurate

to

necessary

borehole

open

pirical

tion

An

borehole

the

depth

parameters is

will

string resulting

reduced

which

deeper

technical

If

objective

greatly

necessitate

the

venture

ce

and

temporarily

proceeding

of

pressure

wireline devices

tional the

before

Inc

doning

setting

Well Logs

Using

costly

is

As

content

gas

effect

Core

The

6.2.3

and

mud

the

Sec

Chap

in

mud-gas of

are

well also

area usually

of formation

time

or

FORMATION

PORE

PRESSURE

At1D

FRACTURE

277

RESISTANCE

INTERVAL

RAY

TRANSIT

TIMEt

IO6sec/ff

150

50

5200

Ui

5300

00

SHALE

200

INTERVAL

Fig 6.33Interval and

used

but

C0

time

is

give

the

Pore

pressure

Criteria

can

from

shales

with

It

is

deep

establish

areas

the

of

wells

Sec

ray counts

of

interval

between

The for

enough

transit

thickness

number of

sufficient

trend

obtained guide

line

normal from in

pressure data

shale

formations

pressured

average

Time

the

The

with

data

trend

to

from

lines

interpreting

effect

of

shale

21

the

small

pure

shale

procedure

as

seismic-derived

the

for

procedure

interval

transit

of

area

obtained

the

accurately

for

all

data

formations

shown

time the

Fig

Example 6.5 the

in

in

Texas

shale for the

and

6.33

Loui the

Using fit

relation

be

nor

the

shale

good

following

pure shale

may

time

transit

of in

data

log

model of

transit

shales

is

in

in

well

interval

for

using

time

of

interval

Oligocene

procedure

of

these

for

the

ma

622024

of

log

in

6.24

time

discussed

transit

trend

plot

described

travel

well

seismic

only

times

mathematical

establish

coast

is

uses

included

determined

with

travel

amount

siana gulf

matrix

estimation

interval

and

one

are

used

be

mal compaction

data in

to

An example Miocene

for

number of

large

available

log-derived

same

time

when

be

done

interval

considerable necessary

cannot be

to

average

time

having

this

that

is

lithology

the

present must

pressure

useful

showing

transit

formations

shale

the

only

analysis

devices

in shales

normally

pressure from

for

on

difference

primary

resistivity

separation

interval

find

to

drilling

essentially

composite

log

hydration

data

minimum

constant

Published

Transit

6.2.1

6.34Acoustic

potentials

well

formation is

of spontaneous

gamma

obtained

normal

provide

Interval

data

and

values

active

given

Fig

therefore

amount of normal on

shales

more pure

the

radius-of-investigation

difficult

well

single

of

the shallow

in

logging

pure

more

or often

points

in

5500

porosity-

from

selecting

conductivity

Use of values ft

using

include the following

values

values

Maximum of 20

to

thought

fluctuations

small

and

in

data

line

Maximum shallow

is

The

Maximum values

been travel

obtained

obtained

applied

the logging

no

have

acoustic

and

variables

parameters

he

essentially

The

constructed

points

Minimal base with

Louisiana

results

plots

only

that

and

also

logs

extent

other

by

formation

include

Miocene

pressured

Texas

the

of

density

lesser

most accurate

dependent data

affected

less

normally

shales

Nuclear

much

to

in

5400

area.2

gulf coast

conductivity

time

transit

Oligocene

TIME

TRANSIT

IOs/ft

t$h

in

time data

Substituting

6.7

using

this

equation of

tfl

207

for

matrix

105000

travel

ppm

time

into

NaC1

Eq and

APPLIED

278

ENGIJEERING

DRILLING

TABLE 6.13ABNORMAL PRESSURE AND INTERVAL TRANSIT TIME DEPARTURE IN THE MIOCENE AND OLIGOCENE FORMATIONS OF THE TEXAS Parish

or

and

LA

Offshore

Terrebonne

St

LA LA

St

Mary LA

Calcasieu

0.87

22

0.62

10820

0.82

21

11900

9996

0.84

27

0.86

27

0.73

13

11281

8015 6210

11500 LA

.sslft

6820 8872

10980

LA

Martin

Offshore

psi/It

11647

13118

LA

Rouge

S0

FPG

psi

11000

LA

Vermilion

COAST2

Pressure

ft 13387

LA

Offshore

Baton

GULF

Depth Well

Lafourche

Assumption

East

LOUISIANA

County

State

Terrebonne Offshore

AND

13350

0.54 0.86

11481

6608

11800

30

0.56

Offshore

St

Mary

LA

10

13010

10928

0.84

23

Offshore

St

Mary

LA

11

13825

12719

0.92

33

Offshore

Cameron Cameron

Plaquemines LA

12

LA TX

Jefferson

Terrebonne Offshore

LA

LA

TX

Galveston

Chambers TX Formation

fluid

8874

0.60

13

11115

9781

0.88

14

11435

11292

0.90

38

15

10890

9910

0.91

39

16

11050

8951

0.81

21

17

1750

1398

0.97

56

9422

0.78

18

18

pressure

5324

12080

32

gradient

Eq

substituting for

the

normal

6.4

for

the

yields

following

equation

pressure trend line

6.25

1shn

An

excellent

tained

good simple

and

of

fit

of

results

would

tion the

transit

6.25

yield

values

time of

solid

for

yields

matrix

obtained

the

with

interval

depth

more accurate

iriuch

line

straight

interval

ob

is

surface

respectively be

over

while of

6.33

Fig

0.0001

could

also

relationship

depth

greater

in

and

constant

shown

data

straight-line

at

0.33

compaction

the

shown However Eq

Lu

shown

data

the

values

c/

porosity

of

fit

using

transit

extrapola

time

less

than

has

been

material

Lu

The

geologic

found

Ct

to

interval

the

had

longer time

ward

shift

in

for

the

mal

sediments

by

the

changing

20

SHALE

40

INTERVAL

DIFFERENTIAL

with the available in

The shape also

sensitive

FT

6.35Hottman tion

pore

and Johnson pressure

and

relationship shale

interval

between transit

forma time

20

of

times

problem

data

from

puted

the

drilling

handled in

normally

the into

brought

observed

the

alteration

fluid

pressured

the

the

given

of

water

com

is

same well

differences

transition

line

There

deeper

at

depths

less

just

of the

on

when

zone is

dif

Because

more emphasis

place

trend

on

Fig 6.34

in the

significant

at

in

nor

in the

be cti

is

line

made

people

mud

shale

interval

normal

the

either

transit

pressure trend

abnormal

magnitude by

by

above

to

data

trend

runs

the

constant

model

the

up

Similarly

time of

above

the

zone

interest

The

the

normal

transition

of

by

Just

shale exposure

When

affected

many

establishing

above

normal

logging

can

in

interest

be

Note

this

of

the

shales

parison of two ferent

Fig

the well

may

TIME S/

porosity that

formations

well

10-6

tsh

so

shift

this

have

that

result

line

trend

practice

agreement

60

TRANSIT

surface

occur

downward

in In

between

relationship

to

pressure

line

model

mathematical

sediments

Older sediments

depth

compaction

result

pressure trend

shale

pressure

normal

Li

younger

the

normal

time and

travel

Li

C-

of

age

affect

of of

the

the

formation abnormal

two

basic

time line

falls

near

pressure

significantly the is

pressure can approaches

formation indicated be

com

discussed

for

FORMATION

PORE

PRESSURE

AND

FRACTURE

279

RESISTANCE

0.4

0.5

0.6

0.7

II

0.8

0.9

a-

1.0

678910

.5

SHALE

INTERVAL

th Fig

the

6.36Matthews

generalized

ed

an

of

Hottman pirical

the

and

between

shales

adjacent and

Mathews

for the

the

gulf

similar

developed South

China

Sea

and

6.35

interval

This

the

More

area

correlations

the

for

These

is

coast

time

transit

for

Texas

south

23

coast

gulf

in

.60

still

.70

area

correlations

of

trends

authors

North

correlations

interval

Table

in

Vicksburg recent

shale

pres time

correlation

similar

and

80901X

60

.50

em

first

given

gulf

50

.40

Lii

published

areas

and

pressure

provid

transit

are

Louisiana

Frio Wilcox

coast

of

40

DIFFERENTIAL

available

is

measured formation

the

Kelly23

Fig 6.36

Fig 6.10

one

basic data

Fig in

today

and

Texas

Their

in

plotted

used

widely

formation

technique

presented

sandstones

permeable

in

departure curve

second

the

Johnson

relationships in

6.13

illustrated

example

TIME

1d6s/ft

tsh1

between

Kelly relationship

empirically developed

for application

sures

and

30

20

TRANSIT

.80

have

Sea

and .90

are

presented

Fig 6.37

in

Example 6.16 The Table

in

6.14

in Jefferston

depth

of

interval

TX

County 12000

ft

sonic log

made

Estimate formation

Hottman

the

using

and

pressure

Johnson

6.37Comparison

Fig

vs

depth

pressure and

interval

shown

as trend

line

K0.0001

dashed

line

pressure

above

0.0001

it

trend

Solving

Fig

is

Eq

Since

data

the

in to

downward

6.25

for

shift

by

basins

normally

by falls

pressured

the average the

normal

The 160

values

value

of

value

of

terval are

404

eO2D

8O8t2hn

62

into

of

of

shn

transit

time

pore several

in

21

above

the

0.367

trend

62

line

152.6e

relationship

O.000ID

plotted

6.15

Table

surface at

region Note

each

Thus

for

is

these

porosity

depth

9000

above that

6.14 of

Substitution

gives

pressured

equation

in

given

calculations

indicated

was

ft

equation

Table

in is

2775

Similar

the normally

0.373

time value

of

depth

summarized

pressure

This

at

of

value

409

shale

first

us/ft

value

yields

409 _______

formation

transit

normal

line

using an average

interval

plotted

plotted

dashed

adjusting

between

relationship shale

0.33

with

was

the the

are

average

6.25

relationship

6.37

first

The

Eq

by

necessary

line

6.38

Fig

given This

ft

in

significantly

formations

in is

time data

transit

of

and

pressure territory

The

Solution

I06s/ft

at

cor

Fig 6.34

in

TIME

t-

DIFFERENTIAL

well

in

INTERVAL TRANSIT

SHALE

shown

time data

transit

were read from

shown

relation

shale

in ft

an

average

the

normal

becomes

28 by

le

O.0002D

solid

line

in

Fig 6.38

APPLIED

280

TABLE 6.14SHALE INTERVAL TRANSIT TIME DATA FROM SONIC LOG OF WELL IN JEFFERSON COUNTY TX2 Shale

106

ft

INTERNAL

70

80

2775 3175 3850 4075 4450 5150 5950 6175 6875 7400 7725 7975

60

200

180

Time s/ft

153 147 143 139 137 137 131 125 120 124 121 121 118 118 119 122 125 125

127 131 131 140 142 146

10150

149

10325

147

10475

147

11140

148

11325

143

11725

148

12300

142

13000

138

6.38Example

Fig

shale

TABLE 6.15EXAMPLE SURFACE POROSITY JEFFERSON

CALCULATION CONSTANT

COUNTY

At

TX

Depth

106

0.367

156

0.363

sonic-log in

interval

transit

Jefferson

0.364

153

0.382

147

0.367

143

0.372

139

0.381

6175 6875

137

0.378

137

0.405

tion

7400 7725

131

0.390

tivity

125

0.367

Johnson

time

for

plot

TX

County

Well

data

used

are

on

the

almost

every

0.379

121

0362

the

121

0.383

The term formati on factor

FR

118

0362

to

of

0.373

tion

most common

tion

ratio

R0

to

factor

tivity

of

the

resistivity

the

also

that

well

porosity-dependent

of formation

resistivity

can

be

of

the

expressed

plot

39 in

in in

/2S/ft

Thus

psi/ft

11160

psig

forma

measure of

conduc

Since

the

conductivity used

is

in

from well logs is

used

water-saturated

water in

1shn

Fig 6.35

parameter

generally

for

shown

drilled

pore pressure

the

144

reciprocal

available

readily

0.341

the

of 0.93

devices

120

estimation

given

isp0.9312000

124

the

and

105

correlation

resistivity

almost always

are

105

from the

144

logging

or

conductivity

of

read

pressure gradient

pressure

Conductivity

be

1shn

and

formation

151

ft values can

Using

formation

gives the

12000

respectively

Hottman

the

160

of

depth

tsh

Fig 6.38 sift

of

formations

OF

and

Average

40

120

151

10050

7975 8300 8400 8950 8975

00

lOi/ft

TIME

156

9775 9850 9975

2775 3175 3850 4075 4450 5150 5950

TRANSIT

160

8300 8400 8950 8975 9175 9250 9325 9350 9400 9575 9650

It

90

Interval

Transt

Depth

SNALE

ENGINEERING

DRILLING

terms

to

refer

forma

The forma of

conduc

ratio

R0

FR

6.26 C0

FORMATION

The

PORE

relation

has been

PRESSURE

between

defined

AND

formation

empirically

FRACTURE

factor

RESISTANCE

and

Shale

6.27

the

of

data

laboratory Formation

water

Shales

value

can

of

the

the given

water

the

be

standard

account

conductivity

or

and

SP

fluid

Even to

properties

made

the

at

times

different

by

log

well

using

be

drilling

im

relatively

the

in

changes

model of

mathematical shale

formation

the exponential in

porosity

factor

and

the

borehole

6.27

constants

in the

054

6.17 Table

in

must be chosen in

by

Eq

6.4

terms

normally

log

were

on

the

basis

of

forma

pressured

and

terest

Table

the

shale

0.85

10485

0.92

10659

0.91

0989

0.90

11162

0.91

11478

0.90

11588

1.20

11776

1.16

11966

1.10 1.11

14188

0.96

14487

0.71

14566

0.80

14833

0.80

14960

0.90

15275

1.06

by

example

water the

at

water

ft

from

an

in

matrix

equivalent

bulk

depth

as

The shown

computed the

water

water

stress

density

con

least

at

in

each

Fig 6.39 depth

resistivity

first

are

The formation

listed

from

data

Fig

in

Table

6.39

at

the

plotted

factor

6.16

resistivity

depth

first

formation

0.91

in

from the graph Table

in

entry

of

resistivity

listed

resistivity

read

is

read

6.16

from

of

Fig

of

factor

0.91

in

The

varies

Fig 6.3

resistivity

shale

0.55

R0

offshore

vs

then

is

and 6.28

obtained

factors

Table

6.16

depth

of

pressure

40.0

at

have

in

line ft

region

are

Use

yields

by reading depth

of

in-

In

6.0mK3000m

manner

plotted

in

in

selected

of

these

as

two

at

all

to

depths

6.40

Fig

appears

ft Representative

10000

trend

10000

this

been

pressured

normally

to

normal Solution

the

dividing the

values

resistivity

obtained

sediment

mean

that

0.80

1.06

then

16

Formation

using

shown

0.86

0.96

this

listed

as

0.91

13983

for

14000-ft

Assume

0.85

13778 trend

at

depth

0.80

1.05

values resistivity computed from SP log at all available water sands are given in Table 17 Using these data estimate the formation pressure

with

0.85

1.10

the

cept

0.76

13573

For

well

6.16

depth

0.71

13385 deep

well Water

Louisiana

0.70 0.70

1.06

interest

The

0.70

10217

6.39 This gives

shown

0.55

0.91

be

3110 Example

0.55

6.28

obtained of

area

0.50

6167 6482 6577 6955 7113 7255 7696 8200 8342 8767 9113 9492 9665 9996

13069

can

ln

and data

conductivity

0.50

6041

0.90

yields

FRmKDm

0.50

12785

with

of

0.50 0.55

on logging

substituting

After rearrangement

0.50

0.96

by

defined

equation

0.55

12550

compaction

be obtained

0.55

12470

problem

device

0.55

water-

of highly

normal

the

can

porosity

Eq

substitution

tions

Om 21m

12265

of chemical

readings

logging

clean

sand

the

result

This

for

borehole

the

to

filtrate

composed

different

give

in

nearby

near

fluid

drilling

of the borehole

same time

shales must

are

as

spon

of investigation

radius

The

occur

the

the

made

exposure

mud

of

in

of

available

is

in

formations

gradually

shales

minimized

ln

shale

between

sensitive

by

for

measured

is

in

resistivity

in-situ

depth

the

at

of

obtained

or

invasion

the

wall Sections

for

value

calculation

of

technique

significantly

though

interaction

runs

made

The value

and

calculating

resistivity

interpretation

conductivity

affected

permeable shale

the

measurements

or

observed

correct

proposed

generally

of

resistivity

at

salinity

Whalen22

only

used

salinity

the

the

from SP measurements

Fonnation is

in

as

because on

in

use of

nonshaly sandstone assumed equal to the

also

fraction

into

well

R0

Resistivity

3110 3538 4135 4544 4890 5175 5363 5867

varies

are

avoided

taken

conductivity

computing

An

when

lithology

shales

are

changes

from

well log

by

pure

through

and

formation

as

of

temperature

potential

temperature

effect

resistivity

taneous

R0

limestone

factor

water

Foster

terest

that

of

formation

the

essentially

The

temperature

in practice

resistivity

caused

some limestone

effect

conductivity

or and

changes

in

containing

large

C0

salinity

avoid

obtained

and 3.0

1.4

used

is

not available

conductivity

To

porosity

between

2.0 generally

are

with lithology

values

varies

exponent

value

average

of

Depth ft

where

DATA

TABLE 6.16SHALE RESISTIVITY LOUISIANA22 FROM OFFSHORE

porosity

by

cbFRm

the

281

extend

values 6.0

at

points

of

at the

3000 in

ft

Eq

APPLIED

282

WATER

Rw2m2/m

RESISTIVITY 0.2

0.1

0.3

0.5

SHALE

0.7

ENGINEERING

DRILLING

FORMATION

FACTORFR 100

ID

1.0

flflI JLl -s

-c-

400C

600C .4-

.4-

8000 I-

u-I

0000

--

20 4000

J_

1600C

Fig

6.39Example

formation

water

Fig

profile

resistivity

6.40Example

Louisiana

and this

having mal

40.0niK10000m

in

value

two

equations

simultaneously

gives

in

0.000271

40

nKin

0.977

of

average

An

pressure

trend

iine

is

given

equivalent

determined

from

the

expression

in

stress

9297 values

ft

a0b

was

of

and

determined

due

to

obtained for

the

using

Eq

6.6

sediments

all

in

Example

O.O52Pg

Pfl0

previously

load

geostatic

aub9 more convenient

form

is

297

O.OS2pgDn

_e_Kn 0.0522.68.339297

The 6.40 mally

To 14000 shale

line

and

defined

was found

pressured

compute ft

Using

formation

Fig 6.40 The depth

by

at

fit

was

equation the

data

plotted

accurately

in

on

Fig

the

nor

0.0522.61

region the the

equivalent

the

ft

.0748.330.4l

0.000085

formation

factor

14000 of

to

this

first

is

An FR

normally

at

pressure matrix

stress

read from value

the

of 33

pressured

of

depth

concept plot

the

given

in

e000859297

was obtained

shale

formation

X.7N

nci

and

6.2

2.656eOMOO271D

FRfl

nor

at the

including

by

0.000271D0.977

in FRfl

is

330.977

nonshales normal

then

line

9297ft

depth

the

in

depth

0.977

The overburden

Thus

vs

0.000271

and

10000

factor

0.000271

100003000

In

formation

well

in

ln40/6

mK

FR

of

pressure trend

In

these

Soiving

shale

of

plot

offshore

104701741

FORMATION

PORE

PRESSURE

6.17WATER FROM SPONTANEOUS

TABLE

AND FRACTURE

RESISTANCE

RESISTIVITY

VALUES COMPUTED POTENTIAL LOG ON OFFSHORE LOUISIANA WELL22

283

Louisiana

Water

South Depth

Resistivity

3611

0.72

3830 4310 4625 4950 5475 5630

0.68

6100 6540 6910 7280 7460 7900 8400

0.41

coast

gulf

Texas

Fro

0m2/m

ft

OF SLOPE CONSTANT VALUES OF togC0 VS DEPTH

TABLE 6.18AVERAGE K2 FOR PLOT

trend

Wilcox

trend

TABLE 6.19PRESSURE AND SHALE RESISTIVITY RATIOS WELLS OVERPRESSURED MIOCENE-OLIGOCENE

0.45 0.38

0.45

Shale

0.39 Resistivity

0.38

Parish

0.36 0.30

St

0.28

8600 9460 10700 11400

0.16

11800 12020

0.18

or

and

Cameron Cameron

Depth

psi

12400

10240

Well

LA

Martin

LA

10070

LA

10150 13100

0.24

St

LA

Mary

5000 6350 6440

12300 12500

0.19

14000

12350

0.19

12880

0.19

13290

0.19

Jefferson

LA

Davis

11500

7970 7600 7600

10948 10800

0.24

14300

0.34

14500

0.30

14680

0.37

15090

0.65

Cameron

LA

12900

LA

Iberia

11000

7200

13844 15353 LA

Lafayette

12100

9000 9000 8700

12600 12900

14550 LA

Cameron pressure

at

ft

is

given

13600

323

TX

the

14000

ft

effective

matrix

stress

at

both

9297

872943234406

09297

overburden

stress

0ob

ft

fluid

pressure

0.0522.6

l.0748.330.41

in

depth

used

as

the

of

shale

1.30

0.82

2.40

0.73

1.78

0.70

1.92

0.71

1.77

0.85

3.30

0.52

1.10

0.79

2.30

0.71

1.60

0.70

1.70

0.74

1.60

0.74

1.85

0.85

3.90

0.68

1.70

080

2.35

0.88

3.20 1.60

13500

11600

0.86

2.50

13950

12500

0.90

2.75

shale

pressured

pore

psig

is

equal

to ln

P14oool354944069143

practice

it

is

often

range

of

interest

estimated sandstone

difficult

water

obtain

to

conductivity

Formation

in are

reasonable

over

water

SP logs only which formations

from

of

resistivity

overpressured

C0

is

When

resistivity

this

can

R0

is

be

calcula

in the

parameter

it

changes

salinity

water

pore

C0 or

Thus

regions of

effect

be

the

value

normal

obtained for

of

done Eq

FR

compaction by in

formation 6.28

trend

substituting

Eq water

6.28

the

and

conduc

becomes

K1 K2D

6.29a

psig where

estimates of formation

observed

pressured the

C/Co

ratio

If this

tivity

pressure

can

constant

assuming

15767221813549

to

pressure

model of

conductivity

conductivity

thick

0.52

2.80

porosity-dependent

formation

of

tion

_0.0000851400O

and

1.15

0.88

conductivity

mathematical

be

115

0.52

11150

formation

the

fonnation

done

0.000085

can

4.20

0.53

gradient

of normally

resistivity

in many abnormally may be necessary to ignore

with

depth

0.89

is

0.0522.68.3314000

14000

In

1.95

psig

14000

at

of

istent

pore

1.70

0.79

is

014000

the

2.60

0.74

0.71

12700

and

Ratio

the

8750 7680

10800

LA

Formation

Since

10900

10000

St Martin LA

Cameron

Thus

9400 8100

11900

by Jefferson

2974

.465

LA

Terrebonne

9297

10800

11070

1tm

0.83

11600

9370

Ratio

psi/ft

7500 8000

0.25

Offshore

FPG

Pressure

County

State

11750

P9297

20

0.49

0.29

pore

39

0.51

13.700

formation

0.0001 0.0001

0.66

10750

The

35

0.000132

trend

Vicksburg

0.0001

coast

gulf

the

rare

Hn

K1

ln

and

c1

K2

are

defined

by

6.29b

cntire

conductivity

relatively

K1

constants

and

clean

or nonex-

K2

mK

6.29c

shale

APPLIED

284

ENGINEERING

DRILLING

Ui

Ui

C/ Ui

Ui

.25

1.0

3.0

SHALE

Fig

RESISTIVITY

6.41Hottman tion

and siana

and

pore

Johnson

gulf

shale

formations

coasts

of

the

Texas

for

forma

and

Shale

ft

2665 3062 3767 4273 4493 4747 5100 5143 5.319

pore

Loui

ROih

and

Conductivity

10-3 m/ttm2 998

1020 1197 1144 1225

1262 1005 1206 1170

The constants

mations

data

in the

published

between

resistivity

formation the

for

south

When shale

shale

pressure mal the

falls

trend

line

formation abnormal

two

basic

of

interest

Hottman pirical

the

and

pressure

in

904

resistivity

in

714

listed

10500

1252

10860

1480

in

be

second

Johnson

Table

6.19

curve

is

sandstones

Example

1252

Table

11475

1831

drilled

11750

1723

mation

1845

12860

1404 1436

em

first

formation formation

basic

data

Fig

6.41

Another

in

are

published

by

gulf coast

area

correlations

for

of

major

values

shown

literature

private

of

oil

companies

10990

12235

area

the

and

other

the

an for

Their

595

in

the

the the

available

of

one

shales plotted

of

of

for

measured

693

exist

either

in

used commonly empirical relationship Mathews and Kelly23 for the south Texas is shown in Fig 6.42 Many similar areas

abnor

magnitude

Fig 6.10 provided

presented

and

interest

previously

in

between

adjacent

normal

The

technique

permeable the

of

or

above

computed with

departure

794

703

lines

Table

in

the

below

discussed

relationships

877

560

for

trend

given

significantly

formation

illustrated

983

1076

are

indicated

is

approaches

application

698

basis

which were

pressure

falls

the

pressure can

1179

812

the

on

pressured

K2

of

significantly

near

1013

1321

Values

normal

pressure

6498 6840 6938 7060 7224 7400 7480

10320

be chosen

normally

and Kelly23

conductivity

resistivity

6421

7575 7960 8390 8910 9185 9504 9900 10030

in

6.18

developed

1005

must

interest

average

empirically

904

K2

Matthews

by

1311

1803

15000

C01

shale

obtained

area of

from

computed

and

K1

of conductivity

example

14086

SO

RATIO

coast.23

gulf

generalized

5639 5826

13140 13460 13890

or

and

50

4.0

Kelly relationship

pressure

Texas

3.0

CONDUCTIVITY

or

20

TABLE 6.20SHALE RESISTIVITy DATA FROM WELL DRILLED IN FRIO TREND OF SOUTH TEXAS23

Depth

6.42Matthews

Fig

Miocene

25

2.0

RESISTIVITY

R/

between

resistivity

175

.5

SHALE

5.0

ROfl/ROh

relationship

and

pressure

Oligocene

RATIO

4.0

6.18

6.20

The

were

in the

mation

from

well

Frio trend of south

pressure

Mathews

shale conductivity

read

and

at

Kelly

pressure and

Texas of

depth empirical

recorded

log

Estimate

13000

ft

the

using

between

relationship

shale conductivity

in

for

this

in

well for the

for

area

1187 1351

1060 918

Solution depth mation

as

The

shale

shown

in

conductivity

Fig 6.43

pressure appeared

to

data

first

are

plotted

The region of normal extend

to

deoth

vs for

of Q.SO0

FORMATION

In

ft

is

above

the

those

to

value

600

of

the

of

values

Table

and

6.18

an

interest

value

6.29a

200

ln

400

1000

2000

3000

ft

representative

of

these

of 0.000

K2

139

yields

C0K1D

K1ln

Co

the

9500

Use

for

CONDUCTIVITY

103m/flm2

salinities

At

appeared

SHALE

just

altered

have

formations

average

Eq

in

been

285

em

line

formations

have

of

RESISTANCE

trend

the

probably

m2

m/2

pressured

with

along

in

formations

10

normally

pressure

which

fluid

the

FRACTURE

obtained

zone

drilling

AND

normal

data

transition the

by

closest

on

placed

the

least

See

PRESSURE

determining

phasis

of

PORE

2000

6000.0001399500

6.401.327.72 Thus

the

normal

trend

pressure

line

defined

is

4000

by

C0 7.720.000139D

ln

After

into

rearrangement

more convenient

form

this

becomes

equation

6000 0.000139D

C0 2250e The normal

pressure trend represented

was drawn on fit

to

data

the

At

the

accurately of

depth

indicated

shown

plot

in the

shown

Thus

respectively

values

ft

the

in

and

the

of

equation

Fig 6.43

and

ratio

zone

1700

C0

for

.4-

was found

transition

369

conductivity

this

by

Fig 6.43

above

just

13000 plot

in

8000

are

C0

and

is

4.6 C0

1700

C0

369

Use

of

this

correlation

6.42

Fig psi/ft

value

for

for

the

ratio

conductivity

in the

empirical

Frio trend

of

formation

pressure gradient

yields

the

Therefore

10000

south

formation

Texas

pressure

shown of

in

0.82

is

12000

pO.82l3000

6.3

Formation

When

abnormal

density of the to

the

wellbore

into

maintained

in

the

fluid

there

without

to

control

to

in

the

can

another

Fig

Thus

pressure must

that

cause

the

into

can

pressure

that

Pj mud

and

pressure

casing

knowledge

seat

of

just the

This

the

means

abnormally drilled

in the for

safely

well the

P2

This

typical

formation

density

6000

forma

maximum

is

be

string

Note

fracture

exposed

tolerated

well

casing

the

will

there

depth

6.44

formation existing

be

pressure

formations

welibore

weak

seat

casing

the

maintain

to

pore

permeable

the

relatively

which

encountered

formation

from

since

Pff shown

the

at

the

fluids

that

is

must be increased

maximum

of formation

pressure

pressure

density

cementing

illustrated

pressure

the

is

zone

behavior ture

14000

below the pressure

below

just

pressured

is

of

more shallow

drilling that

flow

Resistance

pressure

fluid

However

be

tions

Fracture formation

drilling

well

the

psig

pressure above

the

prevent

10660

frac

needed

at

Dmax causes below the fracture

pressure

at

which

Fig

6.43Example Texas

shale

conductivity

plot

for

Frio trend

south

APPLIED

286

-p

DRILLING

ENGINEERING

O.O52pD Note

Mud

pressure

approaching

Just

after

Fig 6.44Typical

formation essential

fracture

stress

down

6.45 the

states in

but

can

stresses

into

the

pressure and

well

is

abnormally

the are

essentially

rock

the

defined

in

much

increased

sediments

general

If

we

that

matrix

to

at

expand

doing

the

strain

horizontal

well

pressured

is

essentially

and

stresses

ap

are

so by

ax

and

ay than

are

tend the

to

can

law

be

stress

relative

magnitude

stresses

can

such

as

matrix and

equal If

the

such

faulting

occurs

between

On

other

either

using

Hookes

horizontal

the

vertical

coast

For

compressed

elasticity

rock

and j.t

caused

is

by

that sent

25

horizontal

the

of

vertical

rock

elastic

matrix

stress

may

very

the

is

the

of

stress from near be

tends

such salt

principles

200

larger

trends the

For

than of

structures

regional in

California

300%

and

local

stress

shortened

much

dome

the

can

exam

Louisiana

gulf

considerably

of rock to

as

be

to

stress

matrix

being

such be

to

Of course

altered

fracturing

are

faulting

stress

tends

matrix

vertical

that

geologic

where normal

stress

vertical

vertical

occurring In

regions

matrix

stressbetween

difficult

basic

50%

regions

and

naturally

gulf coast

the

thrust

matrix

stresses

area

is

and

horizontal

from

geologic

than

in

matrix

Hydraulic of

the

horizontal

departures the

the

the

hand

matrix

of

Louisiana

folding or

by

the

ple

modulus

of

assumption

inferred

the

smaller

usually

the

elastically

as

considerably

the

be

in

patterns

regions

cause

Youngs

the

37%

For

sedimentary

0.27

to to

horizontal

the

The

in

fL

ratio

valid

matrix

vertical

is

not

is

0.18

the

if

stress

consolidated

22%

from

However

stress

fracture

shown

stress

expressed

from

range

planes

condition

horizontal

behave

for

varies

horizontal

average

of

principal to

as

region

the

matrix

to

be

which

rocks25 matrix

the

values

higher

approximately

vertical

assumed

strain

basin

denotes

measured

through

as

stress

and

geologic

where

matrix

normal

subsurface

6.30

1ti

horizontal

laterally

are

equal

axaY-aH-aZ

behavior

designate

of

sedimentary

smaller

sediments

Poisson

abnormally

have

loading

tend

causes

transmitted

relaxed

relatively deltaic

horizontal

where

since

in

horizontal

the

sedimentation

zero and

resistance

Fig

vertical

tendency

stresses

terms

the

the

from

points

those

shear

stresses

fracture

sediments

young

prevented

This are

contact

stresses

In

formation

subsur

Fig 6.45

young

next casing

forma

that

environment

and

of

resist

common

most

depositional

because

that

that

processes

relatively

continues

contacts

stresses

no he

well

geologic

in

deltaic

grain-to-grain

with

the

occurs

surrounding

matrix

in

depths

drilling

underground

consider

grain-to-grain

matrix

all

at

well

pressure

before

proximately

increases

az

laterally the

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formation

occur

and

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stress

of

casing

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occurred

laid

will

planning

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face

running

formations

pressured

tion

Pressure

behavior

fracture for

open

Abnormal

to

Formation

of

top

section

hole

iI---Ii---Transjtjon

fracture

at

pressure

is

complex

phenomenon

describe mathematically involved

wp

rein cider

To pre firif

FORMATION

PORE

PRESSURE

AND

FRACTURE

287

RESISTANCE

River Del to

Rock

Element

Normal

0b

Faulting 6.45Example

Fig

very

assumed fluid

rock

the

have

to

one

is

For

pressure of the formation

the

fluid

pore

When

the

matrix

rock

the

matrix fracture

principal

stress

by

the

and

the

orientation

is

borehole

The

stresses

and

ay

dicular

circular

at

all

and

the

stress

few

hole small

minimum

regional

matrix

cumferential rpcinql

stresses stress

hriintq1

that

stress

For

the

the

tr

borehole

in

were wall

and

formation

and

lengthy

for

not

to

of

any

not available

wells

extremely

are

without

used

widely stresses

principal

generally

is

the

these

used

been

the

directional

not conveniently

wells

for directional

about

characteristics

the equations

Also

and

addi

Unfortunately

have

information

hydraulic

In

parallel

stresses.26

solutions

required

not

is

of

penetrating

developed.2627

developed

axis

principal

complex

because

been

been

both

computer

Methods

6.4

for Estimating

Fracture Pressure Prior

with

how

of

with

when

depth

will

determining

by

based

method

predictive

place tions

anticipated

below

just

the

before

pressure

test

planned

casing

After

fracture

drilling

well

data

plan

obtained in

cemented

is

casing

that

those

like

Initial

fracture

of

must be

forma

the

verified

be continued

can

well

predictive

resistance seat

casing

prior varies

Techniques

pressure

methods

formation

as

deep

pressures

include

pressure

on

pressure

pressure

drilling

fracture

verification

be

fracture

important pore

formation

pore

and

the

and

planning

formation

determining

as

just

formation

the

penetrate abnormal

methods

formation

be

can

depth

knowledge

how

of

knowledge

varies

to

by

the

next

depth

but

local

fracture

the

of

treatments by

6.4.1

Prediction

Pressure

Fracture

of

stresses

wellbore

case

and

cr

quite

once

by

than

stresses

regional

controlled

an

matrix

higher

were

is

in

perpen

concentrations

have

welibore

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ning must

principal

axis

much

Thus

the

and

matrix

the

with

stresses its

more

have

fluids

equations

directions

for

stresses

weilbore

which

in

for

the undisturbed

from

the

borehole

horizontal

be

horizontal

distance

at

with

could

wall

for

mathematical

within

nonpenetrating

approximate

three

regional

hole

diameters

extension pressure

the

rigorous

fracturing

the

borehole

of

was found

regional

approached

propagated ture

It

borehole

the

cases

rapidly

within

tal

plate

undisturbed

the

with

containing the

an

least

near

stress

near

was applied

theory plate

to

one

to

impermeable

stresses

in

elastic

made

the

formation

the

of

state

of

The

propagates

through

the

parting

to

More

sediments

deltaic

young

relatively

is

stress

sum of

the

perpendicular

cylindrical

the

for

com

be

matrix

pressure

concentration

parallel

the

compression

fracture

Willis24

and stress

and

the

pore

spaces

the

to

begins

minimum

horizontal

smooth and

vertical

infinite

the

the

assuming

axis

6.46

and

Hubbert of

matrix

above

in

tion

but

rock As

the

increased

the

is

pressure of

the

pressure exceeds

stress

alters

borehole

of

fluid

cylindrical

calculation

Fig

in

fracture

the cavity

of

spaces is

the rock

occurs

preferred

significantly

pore

that

the pore

into

enter

to

6.46

the

nonpenetrating

must exceed

fluid

direction

fracture

minimum

the

shown

in the

greatest

in

fracture

pressure

As

pressed

fluid

in

created

the

distance

fluid

frac

located

and

strength into

fracture

fracture

pressure of the mation

flow

significant

rock

the

tensile

will

cavity

6.45

Figs

zero

distribution

nonpenetrating

small

into

element

that

not flow

will

which

in

introduced

is

center of

of

situation

simplified fluid

ture

underground-stress

the

is

frac

undisturbed

which

horizon

equal

the

cir

was

twice

the

of

Estimates setting

ly

by

the

described plied

in

casing

tions Since

the well

formation

formation pore

before

fracture

formation

pressure

based

fracture

pore

iistI

fracture fraiiuiv

on

one

made

empirical

pressure

pressure

pressure prediction

use of

crnimnnlv

are

is

of

before correla

affected the

methods must

pressure correlation

nrsiir

great

previously

iiiiafjnns

be

ap The and

288

APPLIED

correlations

Pf

tion nebaker

Fluid

Hubbert

the

and

Eaton

the

equation

ENGINEERING

and

Willis

Kelly correlation

correlation

Christman

Cavity at

include

Mathews

the

DRILLING

and

Pen the

correlation

MacPherson

the

equa

the

and

Berry

correlation

Pf

Hubbert

and

introduced used

to

extend needed

pressure

Equation

Hubbert

fundamental

and

an

existing

to

overcome

wellbore

fracture the

Willis24

that

principals

today The minimum

widely

quired

Willis

many

are

still

re

pressure

was given the as minimum principal

stress

pffaminpf Since

Pressure

Pore

with

Pressure

the

earth

many

fracture

6.31a

existing

planning

and

principal

stress

concentration

and

at

to

formation

are

if

1Hw

fracture

in

and

local

On

the

is

basis

Mohr

and

Willis

such

as

stress

is

concluded

the

minimum

in

coast

gulf

matrix

stress

of

weight

extension pressure

in

the

was

It

in

the

the the

analyzed

Chap

also

shallow

vertical

matrix

Thus

situation

is

.o-x

matrix

aob the

Pf

Fracture

Stress

fracture

which

3000

is

extension

given

pressure

by

is

expressed

by

bert

Fig 6.46Fracture

an initiation

opposes

least principle

and

6.32

Compute

normally ft

Willis

maximum mud density U.S gulf coast formation

the

pressured

be exposed

can

without for

equation

surface

average

fracture

fracture

porosity

Use

extension

constant

of

stress

porosity grain

decline constant

density

Solution faults

Pg

of

Willis

2.60

indicates

presented

shallow

of as

0.000085

computed

The U.S gulf coast area has

which

much smaller than

for

frac

the

approximately

Pj

Example 6.19

Pressure

is

stress

Pff4ob 2pj/3

Pressure

that

sediments

pf

Pffrnjn

the

matrix

concluded

Pf

Since

faulting

horizontal

overburden

for this

using

Hubbert

regions of normal area

stress

one-third

from

experiments

presented

that

U.S

resulting

Pff

criteria

the

approximately

ture

6.3lb

of laboratory

failure

minimum

the

re

isotropic

PffaHWPf2crHpf

the

the

pressure

homogeneous

if

stress

twice

is

the

well

minimum

the

the

Thus

for

plane

equal

wall

stress

initiate

used

horizontal

borehole

the

horizontal

quired

the

this

planes

is

However

in

anisotropic

bedding

generally

design

occurs

stresses

regional

and

pressure

casing

and

inhomogeneous

joints

extension

horizontal

so

is

that

the

Eq

vertical

6.32

formations

the

in

as

and in

matrix

stress

an approximate

this

type of

at

Hub-

Assume 0.41 average

Example 6.2

regional

horizontal

matrix

an

the

to

normal stress

Hubbert

relationship

geologic

is

and

recion

FORMATION

PORE

PRESSURE

AND FRACTURE

RESISTANCE

289

2000

-4 \4

4000

6000 .4-

2w

8000 fl

10000

OC 12000 fl

4000

0.7

MATRIX 6.47Mathews

Fig

mally

fmm

Also

gradient

and

Table

6.2

overburden

the

a0b

1.0

normal

or

coefficient

is

formation

g/cm3

1.074

computed

by

Eq

.2

F0 for

nor

formations.23

psi/ft

stress

16000

0.9

RATIO

Kelly matrix-stress

pressured

0.465

is

STRESS

0.8

pressure

The

vertical

6.6

2.6 8.33

.6

MATRIX

6.48Pennebaker

Fig

Eq

6.32

that

was

and

minimum

the

stress

.8

STRESS

correlation

not

generally

Matthews

tions

burden

ob52

.4

valid

Kelly23

matrix

for

the

replaced

stress

8.33

where

3000

33787182660 pore

pressure

is

formations

6.47

shows

1395

were

curves

abnormally

for

which

same

of

stead

Thus

fracture

actual

pressure given

Eq

by

6.32

is

of 0.465

gradient

Pff

This

pressure fluid

drilling

1395/3

1817

would

exist

3000

at

density

ft

psig

in

static

well

for

The Ibm/gal has

3000

showed denth

that

evpn

Kelly

Correlation

formation in

ncirm-1l

as

the

used

in

determining

the

is

and are

an

an

the

assumed

depth

abnormally

Fig 6.47 matrix

average

average

and

coast

correlation

would have

formation

stress

interest

psi/ft

gulf these

formations

pressured

simplicity

overburden

normal

Thus

in

stress

pressure

the

normal

becomes

stress

fracture

Drilling

gradients

frn

experience

increased

trn

with

at

depth the

vertical

pressured

and

pressured

psi/ft

Texas use

pressured

correlations

0.535

11.6

Matthews

To

determined

aflbPflDIO.4S

of

817

0.052

matrix

vertical

For

.0

was

normally

empirical

south

the

when

F0 in

the

areas

of

depth

F0 of

taken

matrix

vertical

formation

0b

stress

coast

normally

coefficient the

for

presented gulf

by

psig

Fig

Louisiana

pressured

Pj465 3000

coefficient

data

the

given

stress field

that

psig

matrix

the

empirically from

at

formation

6.33

0.41

0.000085

The

over

the

by

3000

2.61.074

0000085

forma

assumption

amjnFaaz 0.052

ratio.6

deeper the

was one-third

stress

F0

RATIO

effective

for

1.0

which

matrix

formation

____ 0.535

of

aOb 0.535

normally

interest

Pf

pressured

present

stiength

in the

formation abnormally

is

Dpf 6.34 0.535

OVERBURDEN

AVERAGE 0.5

GRADIENTpsi/ft

0.8

0.7

0.6

ENGINEERING

DRILLING

APPLIED

290

0.9

1.0

cr

4-

Ui

Ui

Ui

Fig

6.49Pennebaker

correlation

for

overburden

vertical

stress.6

POISSONS Example 6.20 10000

was

ft

found

Compute

psig

Matthews

the

and

Solution

south

have

to

pore

formation

equivalent

formation of

pressure gradient

8000

using

6.50Eaton

depth

of

Eq

6.34

normal

pressure

pore

always

3738

area

atadepthof3738

coefficient

ftyields

0.59

of

Fa

6.33 the minimum matrix

min FjUz 0.59

1180 fracture

pressure

stress

Thus

shown

avalueof

relation

from

parameter

Eq

stress

is

10000 8000

is

given

Eq

by

6.31

18080009

180

psig

is

gradient

0.918

was found

depth

gradient

Solution

ing

psi/ft

Pennebaker ratio

and

Correlation the

Matthews

used called

correlated

to

compute the

The Pennebaker and

Kelly

the

coefficient

this

to

coast

gulf

for

constant

value

developed

the

for

cor this

determining

overburden

on

geologic

age

by

family

of

for

curves

interval

Texas gulf coast

have

indicate

of

tran

ft

interval

transit

Compute

Pennebaker

the

formation

psi

time of

100

formation

the

at

8000

pore pressure of

an

6000

using

ratio

minimum Fa

with

correlation6

correlation

the

depth

in

that

matrix

stress

effective

stress

regardless

of

Fig

Entering value 6.49

Fig

6000-ft

is

and

6.49

of

south

records

at

values

6.33

correla

this

ps/ft

6.21

ft

depth

overburden

Eq

for

Texas

which the seismic-derived

10000

yields

to

correlation

frac

correlation

is

10000

similar

100

a0

account

into at

Example

1zs/ft

9180

is

of the for

depth

Field data

assume

Fig

effect

taken

depths

not

stress in

The

is

time

sit

ture fracture

Pennebaker

actual

Pennebaker

from the south

did

overburden

Seismic

the

the

the

psig

Pffmjn pfl Thus

in

Fig 6.48

in

primarily

Pennebaker

various

The

ratio.1

ft

vertical

Fig 6.47

used

is

shown

is

come

tion

0.535

stress

Poissons

for

Thus

pressure gradient

mation

which

matrix

correlation

the

100008000

Entering

RATIO

at

Fig

fracture

with

computed

is

gulf coast

Kelly correlation

The

formation

Texas

in

of

effective

at line

depth for

gradient

Eq

a1 F0r

6.33

100

1ob

6.48

at

stress

of ps/ft

of

10000

1.02

Pf

0.82 .02lO0008000 11A

..

of

10000

Fa of 0.82 and

ft

yields

gives

Fab

depth

ratio

value

psi/ft

using of

Use

ft

Enter the

vertical

of

these

FORMA11ON

PORE

PRESSURE

50

AND

FRACTURE

RESISTANCE

291

EDL0RLIMI

.75

500

___

2.00

400

________

tJ

2.2

___________

300

--

---

_____________ 0.2

0.4

0.6

MATRIX

0.8

STRESS

_.-1-

200

1.0

2000

RATIO F0

FRACTURE

Christman

6.51

Fig

correlation

for

effective

stress

28

ratio

6.52MacPherson

Fig

________ _______ 6000 8000 10000

__.L.......

4000

PRESSURE

and

Berry

psig

Pff

correlation

for

fracture

pressure

The

fracture

pressure

given

is

by

Eq

6.31

0.44

The

vertical

overburden

gradient

is

given

by

Eq

6.6

riipt 180480009804 Thus

the

fracture

gradient

psig

Ob 0.052 8.5 2000

is

0.052

9804 0.98

8000

2.6 8.33

p.siift

10000

2.61.074 8.33

0.052

0.45

0.000085

Eaton the

Correlation

between

relationship

stress

described

is

Poissons dients

were

Texas

the

the

and

constant

Values

fracture

variable

overburden

tegration

of bulk in

overburden density

analyzed

stress

stress

The

logs

a0

grain

stress

Texas in

psi/ft

in ft

2000

ft

subsea the

pute

of

An water

air

surface

the

Compute

to

the

fluid

the

seawater

sediment

grain density

porosity

At

of

will

flow

of 8.5

of 2.6

0.45 and

well

be

drilled

at

10000

have and

line

lbm/gal

g/cm3

The

is

the

minimum

6.30

an

80-ft

the

given

is

by

Eq

psig

6.31

psig

Thus

the

fracture

gradient

is

sea

gradient

an

pressure

1310

the

7810 0.775

average

psi/ft

1000080

surface porosity

decline constant

fracture

8l676500

pffl3lO6SOO78lO

Corn-

psig

assuming

overburden

vertical

density

to

6500

formation

the

drill

well

formation

pressure of of

drilling

assuming

of

Louisiana

penetrate

pore

used

between

gap

will

gradient

semisubmersjble

which

Eq

0.44

offshore

having

fracture

by

in

by

10.44

Example 6.22

stress

computed

correlations

6.50

Fig

is

0z

Umin 1.0

matrix

horizontal

matrix

obtained

cr0b

The

psig

the

assuming

of

resulting

884901017278167

of

were included

coast

gulf

8.000

that

matrix

vertical

6.30

observed

predict

Louisiana

vertical

and

shown

to

Eq

The gulf coast data were

analysis

are

and

horizontal

by

assumes

computed from field data resulting shown in Fig 6.50 Data from west

correlation

and

correlation

accurately

needed

ratio

e085

The Eaton

of 0.000085

ftl Christman Solution the

sediments

rInth

nf

01111

depth

8000

is ft

10000 ft

ft

subsea

Entering ...i.

Fig

the

depth

6.50

.. ..

into

with

Santa that .c

Correlation

Barbara

stress

ratio

channel could

Christman28 working off the California coast be correlated

lh. Cl...

to

the

bulk

in the

found density

ENGINEERINIG

APPLIED DRILLING 292

and

pffl3346SOO7834 Thus

the

fracture

psig

is

gradient

3000 7834 0.777

psi/ft

1000080 IiJ

MacPherson

2000

approach

LU

With and Berry Correlation MacPherson and Berry29 developed

and

wave

formation of

measurements sonic

and

log

bulk

time

Using

density the

using

of

means

by

means of

computed

is

compressional

pressure

transit

density by

K1

for

K1

fracture

interval

modulus

elastic

modulus

elastic

between

tion

novel correla

log

the

following

equation

1000

Kil.345Xl0I0._

An shown

between

correlation

empirical

pressure

6.35

for

developed

the

and

K//a/

offshore

fracture

Louisiana

is

area

Fig 6.52

in

246810 VOLUME PUMPED

min

TIME

Bbl

6.53Example

Fig

sand

first

leakoff

test

below

the

results

taken

seat

casing

after

6.24

Example

The

pressured

sand

us/ft

The

density

bulk

tmnsit

interval

mally

formation log

g/cm3

overburden

Vertical

Compute

the

fracture

was

ft

the

pressure using

105

of

2.23

7400

psig

MacPherson

and

0b

stress

abnor

an

in

reading

gave

the

drilling

30

time

8000

at

is

Berry correlation

Fig 6.51 The bulk density of with

crease

geologic

All

age

formation

of these

fracture

the

sediments

tends

overburden

depth

increasing

variables

to

to

appear

in and

stress affect

The

Solution

elastic

modulus can

the

Eq

computed by

2.23

2720000

Kbl.345X101

gradient

be

6.35

psi

1052 The Kb/a0b Example

6.23

tained

the

in

Louisiana

Apply

offshore

well

Christman

the

California

described

in

area

the

to

ratio

is

ob

correlation

offshore

2720000

368

Example 6.22 7400

Solution depth

of

The 10000

average ft

of

porosity

the

sediments

at

is

Use

0eO.45 e000085

of

this

Kb/fOb ratio shown in Fig

correlation

10000

4500

of about

in

and

MacPherson

the

6.52

fracture

gives

Berry

pressure

psig

0.192 This

corresponds

bulk

to

6.4.2

of

density

Verification

After each Pb

PflPgl _4

test

0.1922.6

1922.31

stand

g/crn3

next Entering with ratio

8167

the

bulk

F0 psig

Chrjstman

density of2.3l Since and

Example 6.22

min0.8

the the

shown

correlation

gives

vertical

pore

value

overburden

pressure Pj

816765001

is

in

of 0.8

Fig

for stress

stress

6500

6.51

0ob

psig

see

face

closed

psig

or

until

departure

pump

then

least

10

is

casing

to

in

place

verify

that

the

by

the

will

well

be

rate

to

minutes

to

and

the

take

In

test

whole

the

is

the

the

sur

into

the

at

pressure

mud

observed

rate

with to

general

pressure trend

pressure

determine

safely

pumping the

casing

can

the well

until

begins

drill

set

and

from the increasing

stopped

to

pressure thc

seat

casing

closing

preventer

constant

at

uscd

below

conducted

is

blowout

well

reached ing

334

test

with

cemented

pressure required

which

at

depth

leakoff

is

test

formations

wellbore

the

is

string

leakoff and

cement

1.074

casing

called

Pressure

of Fracture

of

is

caus The for

at

pressure

PORE PRESSURE

FORMATION

The

decline

and

cement tested

of

ducted

the

after

periodically

may have

lower

U.S

in the

gulf coast

the

casing

lower

for

sandstone

The 6.53

well

for

has

short

posed for

each

that

the

incremental

The

straight

start

grains

mud

whole

take

to the

leakoff

pressure

formation

fracture

gradient

called

leakoff

the

ing

test

stopped

and

pressure

decline of

dicative

the

the

The

that

the

the

the

the

to

helpful test

The

in

is

the

filtrate

is

rate

of

is

in

decline is

being

lines

are

yields

rg

the line

The

anticipated

results

line

slope

determined

is

the

and

casing

borehole

of

pressibility

the

effective

caused

of

posed

c5 Ce

and

water oil and

by

and

solids

be

the

of

com

the

neglected

com

fluid

drilling

compressibilities

having is

test

of

expansion

can

of

Ce

respectively

the

compared with

fluid

drilling

compressibility

leakoff

early

compressibility

the

small

is

the

for

from

system The compressibility

given

by

c0f Cf0 CJ

while

test

dd2d1

Ddd2d1

extremely

leakoff

the

to

slope

anticipated

These

strength

300p

frac

pump

corresponding

the

conducting

person

6.38

progress

the formation

The

are

results

surface

anticipated

fracture

leakoff

the previous

in

presented

surface leakoff

anticipated

Plo

pressure

of the

one

by

on

based

is

pressure

pressure predicted

correlations

empirical

lines

pressure and

test

early

6.53

Fig

leakoff

anticipated for

in

for gel

Solving

The shown

300d2d1

dur

lost Also

300d

is

the

the

mud

or

rgD

the

continued

is

pressure

mud

so

compute

observe

in to

of

rate

rD

line

Point

at

to

ensure

to

ex

where

At Point

shut

which

at

used

is

by

4.78

and

the formation

pressure

and

reached

well

rate

apart

The

Eqs

obtained

is

circulation

initiate

4.77

Fig

pumped straight

and

Pumping

left

hole

Point

O.2x 10-6

to

required

pressure

pressure increase

until

enough

long

pressure has been

ture

often

is

open

of

_1

sand

first

in

relatively

move

to

oil

solids

that

shown

volume

fluid

on

fall

water

combining

section

drilling

results

test the

are

psi

3.0x106 5.OxlO6

practice

gradient

test

trend continues

line

formation begins

test

early

common

constant

is

Compressibility

Component

con

be

formations

fracture

leakoff

As shown there

can

shale

for

typical

are the

forma

the

tests

pressure

since the than

that

to

is

into

ft

gradient

area

seat

of

results

10

through

drilling

fracture

below

about

seat

from

COMPONENTS

FLUID

FOR DRILLING

VALUES

joints The

drilled

COMPRESSIBILITY

TABLE 6.21AVERAGE

manner

this

casing

is

seat Subsequent

casing

in

the

cement

the

and

casing

leaks

293

RESISTANCE

the bottom

below

just

after

FRACTURE

for

from

drilled

manner

joints

below

tions

is

formations

in this

bottom

tested

is

casing

cement

the

before

AND

section

is

given

f1

where

and

denote

solids

Since

and

water oil

volume

the

of

fractions

defined

is

compressibility

by

JV

by

clp

6.36

PffO.OS2PDlPf

Pb

since

and

where

leakoff

served

leakoff

term

loss

initiate

and

When

4.78

has been

been

criticized

and

this

of in

Fig

pump is

run

pump

well

the

just

used

10

is

gel

after

that

not

the

the

leakoff leakoff

is

obtain

to

this

after

the

to

and is

the

be

proper annulus

computed

initiate

circula

period using

the

downhole

in the

may

initiated

test

at

reflect

quiescent

test

given

is

plot

the

well

volume

slope of

the

in

equal in

change

the

by

CeV

where

Point

the

additional

performed

same test

The

the

is

solids

are

be

leakoff that

rate

the

than

used

is

other 1.50

bbl/min

small

pump

flow-rate

control

properly

the

are

casing

tinuing

to

shoe

with

the

in

this

obtain

drilling

and

intervals

be

that

6.54

the

rates

results

results

operations

of and

applicable

hole

provides

range

squeeze-cemented

pump effect

open

indicated

Such

slightly

bbl/min

of

pump

flow-rate

should

rate

too slow

0.25

meaningful

test

Fig

should

If

with the higher

cementing

run leakoff

shown

well

the

only

mask

losses

large

as

over

results

between

rates

typical

such

may be required bond

fluid

with

in

water oil

pump

test

slope line

anticipated

conducted

tests

conducted early

filtration

are

for

values

6.21

is

Pumping

leaks

to

test yields

volume

fluid

drilling

Table

in

given

selected

lower

initial

compressibility

Approximate

When

difficult

may be

strength

10-minute

Circulation in

Eqs

of

minutes This method has

does

in

already

the

6.39

dV

12

not performed

mud the

use

gel

fric

rg Normally

pressure required

after

6.53

rate

it

the the

viscometer

rotational for

is

leakoff

to

/dp\

pressure-

for

by

Sec it

fluid

drilling

pressure

usually

break

to

done

strength

pressure and

problem

be

the

approximately

is

in sign

Chenevert30

of the well

and 4.78

in

because

from observed tion

frictional

Chap

for gel

of any contaminated avoid

the

of

pumped

opposite

to

tests

neglected

can

in

4.77

quiescent

and

temperature

To

Eqs values

obtained

is

mud

This

presented

using

representative parameter

often

is

circulation

pressure loss

tional

4.77

ties

and

leakoff

using the pressure required

and

strength

Since

dur

com the ob

used

is

Pff from

pressure

Pbo

be

formation

the

also

low pump rate

at

recommends

gauge equation

fracture

small

is

and

the well

in

loss

pressure

This

pressure

conducted

are

test

observed

the

pute

frictional

surface pressure

the

the

ing

the

is

tween

volume

the

magnitude

Several

good tests

Results of poor

cement

indicate

before

that

con

APPLIED

294

10000

for the

ft

fluid

ing

of

fraction

shown

line tare

of

solids

mud was

the

13.0

test no

containing

0.20

10 lbmJ 100

ft

and

Verify

compute

The the

gel

drill

volume

total

having

was used sq

Fig 6.53

in

water-based

lbm/gal and

oil

ENGINEERING

DRILLING

anticipated

slope

formation

the

of

strength

frac

pressure

The

Solution

computed

is

compressibility

CJ0 cf

Cwfw

Ce

effective

6.38

Eq

with

3.Ox 106 0.800.2

10

_6 0.2

2.44x 106 psi The

of

capacity

annulus

the

and

driflstring

hole

open

are

0.0464

bbl/ft

0.97135x

i03 4.6720.0212

0.97

l0

Ad

TIME

i03 8.8352_5.52

0.97135x

Aa

bbl/ft

and 6.54Leakoff

Fig

test

results

indicative

of

cement

poor

bond

Before

leakoff

culated

until

the

throughout the

kelly

the

drillstring

or

and

slug

is

The

the

Many

resistance

so small ring the

that

such

it

be

the

anticipated

slope

the

will

The

to

the

lower

the

fracture

The

was

test

depth having

of

the

an

diameter

in

conducted

of

external

of 4.67

test

which after

frictional to

flow

the

pressure needed

the

diameter

in

loss

pressure

down

was

drillpipe

pressure drop

assumed

is

break

to

4.67-in

predicted

Eq

by

Since

internal

4.77

is

300

71

The

Once

present

psi

4.67

300

is

occur

will

approximately

circulation

having

1010000

the

most rocks

naturally

be

will

stress

ing

fracture the

pressure

leakoff

is

obtained

psig

6.36

Eq

by use of

2540

pressure of

shown

in

close

Us

Fig 6.53

required

PffPI 0.052

the

holding

diameter

in

Fig 6.53 an

having

was cemented to

drilling

an of

was placed

is

psi/bbl

from

entirely

fracture

shown

casing

sandwith

first

6.39

psL

LXfif

pressure

the compressional

9.625-in

diameter of 8.835

Eq

by

frac

the

pressure of

are

the

604

total

additional

However

generally

The leakoff

in

predicted

2.44x 10_6

bbl

pDpf 13 l001571 9239

25400.052 conducted

line

occurred

an

almost

678

closed

Example 6.25

30

l00000.0702

bbl

dV

the

equal

Also

released

is

yields

same

overcome

to

fracture

is

1000000212

well

volume

to

losses

test

results

neglected

fractures

pressure the

Essentially

from

formation

test

by the compressive The tensile strength

can

the

practice

The

equal

the formation

formation

and

fissures

wellbore

again

that

in

in

pressure behavior

of

Thus

fluid

drilling

bbl/ft

test

bled

thus provides

fearing

rock

surrounding

density errors

good

fluid

fluid

to

678

8.52 0.0702

dp

filtration

not

of

cause

released

prefer

created

in

the annulus

in

test

drilling is

recovered

observed

resistance

stresses

of

both

fluid

leakoff

by

leakoff

approximately

only

operators

fracture

the

the

of fracture

point

ture

be if

volume

on

of

pressure

should

of

introduce

will

V0.0464

by removing

can

drilipipe

which

well

volume

the

injected

fluid

check

in the

conclusion

recovered

volume

column

pressure determined

the

when

well

mud

verified

of

be cir uniform

is

density

be

The volume

should

annulus Cuttings

in the

the

in

monitor

to

fluid

static

observing

well

the

initiated

drilling

and

fracture

After

is

well This should

of heavy

differentials the

test

the

135

at

8.5-in

5.5

in

in the

10000

bit and

well

to

was

internal

10030

an

psig

ftthe

6.1 at

Compute

depth

gulf coast

Drillpipe internal

depth

Exercises

ft

of

of

normal ft

California

Basin Answer psig

the

8000

for

formation

these

Rocky

areas

pressure expected west

Mountains

Texas

and

3464 3720 3512 3488

U.S

Anadarko and

3464

FORMATION

6.2

PORE

Determine

Use

6.55

the

an

normal

defined

normally

Assume

depths

tilted

be

drilled

to

penetrate

have

6.6

of

1.0

mud

with

of

that

The

at

gas

is

to

Lu to

expected to

6.7

second

the

p2l4.S 10000

situations

shallow

Graph

mally

that

formations

interval

U.S

pressured of

lead

can

upward

gulf coast

on

linear

for

6.8

Develop line

for

assuming

the

an

Fig

Use

depth graph

logarithmic

graph

Compare

normal

the

time

transit

data

Answer

in

6.4

the

ft

6.9

the

line

for

assuming graph

the

an

Exercise

interval

Answer

paper

pressured

interval

negative

is

for

equation

the

correlation

formation

transit

shale time

data

pressure

of

on

representation

Table

6.4

logarithmic

tll00D257 with

results

in

the

Compute

28000

Answer

ft

in

pore

shale

extrapolation

Exercise

pressure from

derive interval

stress

of

stress

pressure

straight-line

6.9

equivalent matrix

pore

6.7a Use

the

interval

and

the

12000

for

reading

transit

time

vs

trend

line

as

the

transit

and

compute ft

psig

overlay

interval

pore

depth plotted

Pennebaker

correla

time departure

pore pressure

and

the

to

13000

at

equivalent

stress

of

gradient

pressure

pore

of

1.0

using stress

and

nor

psi/ft

0.456

ft

matrix

Answer

psi/ft

psig

Rehm

and

McClendon

equivalent

matrix

resulted

an

in

data

the

the

6.19

Fig

Use an overburden

stress

indicated

in

high pore

Part

that

with

concept

inaccurately

answers

equation

transit

concept

1.0

gradient

an

psi/ft

of

0.465

time

com

Table

ratio

t/i

posed

and assume

ver

shore

and

for

the

normal

The average

6.14

for

6.22 well

normal

estimate

psi/ft

the

use of an

the

data

d-exponent

Do

value

pressure

statement

this

support

10.535

\t

plot

obtained

using

Using pore

in Part

with

Fig 6.13

Rehm

Repeat and

the

the

the

pressure the

vs

method

Exercise

McClendon

in

at

matrix

of

in

off

the

for

in

depth

and

concept

6.13

Fig

Example 6.8

depth

in

pro

Example 6.5

stress in

at

model

1000-ft

presented

given

of

trend

mathematical

pressure

shown

records

trend developed

equivalent

data

time data

Pleistocene

correlation the

transit

from seismic

Using

formation

pressure using 6.16

results

in

area

compaction the

of

interval

computed

location

Pennebaker

6.15

\3.89

were

Louisiana

crements

Compare

11000

11600

compaction

Compute of

concept mal pore

relationship

Answer

pDI

and

Fig 6.13

Answer Yes

overburden

mation

pressured

straight-line

the

Using

developed

the

the

using

normally

0.09

6.10

puting

of

porosity

Barbara

6.6

Example in

10000

at

of

Exercise

relating

data

the

Exercise

6.7

Santa

logs

pressure

12570

obtained

plots

for

in

given

graphical plot

normal in

13

normal

pressure

Develop

Assume

density

presented

9600 10600

6.12

tion

from

curve

data

the

Using

Answers

predicted

the

time

transit

straight-line

Compare

normally

straight-line

Answer

Develop

trend

of

porosity

using

extrapolation

tical

6.11

previously

Compute

g/cm3

channel

pressures from

6.7

28000

2.6

DENSITY

6.55Bulk-density

CA

semilogarith

obtained

plots

Table

0.000043D

l6le

with

results

pressure

of

on

representation

straight-line

paper

graph

for

equation

interval

2.4

6.5

Pennebaker

trend

Use

2.2

BULK

nor

semilogarithmic and

scale

Example depth

sediments

and

ft

in

time and

paper

at

20

abnor

to

of

result

as

developed

transit

30000

to

depth

paper

function

the

average

interval

at

8000 LU

conditions

drill

Answer

first

is

is

known

is

reservoir

required

ft

well

migration

between

mic

6000

1obgooo

which

structure

the

8000 Answer

Ibm/gal

three

mally pressured

gulf coast

4500

at

ibm/gal

density

4000

and

psig

psig

ft

and load

psig

2700

3500

a0

zero

encountered

the

at

the

geostatic

U.S

the

of

depth

sand

sand

Discuss

fluid

of

porosi

yields

stress

from

000 2000 4000

pressure of

p1ll.5

Ibm/gal

by

formation

top of

the

the

the

safely

Eq 6.7 Eq 6.8

198

gas

density

well

into

cr3716

pore

near

Compare

exponential

psig

have

to

Fig

average

40.34

the

resulting

500

and

psig

6.5

known

in

an

Answer

overburden

vertical

water

430

500

7439

6.4

given

stress

of

ft

aob

the

pressured

at

Eq

by

model

matrix

area

of

substitution

Compute

vertical

in

and

2000

that

compaction

6.4 the

shown

2.60

g/cm3

1.014

chan

ft_i

expression

ty

of

of

and

Barbara

data

density

density

porosity

Santa

the

295

RESISTANCE

FRACTURE

surface

for

grain

density

Show

6.3

for

bulk

average

K0.00019

AND

constant

average

fluid

pore

values

decline

porosity

nel

PRESSURE

Compute

construct the

pore

Zamora 15

using

the

method

of

296

APPLIED

TABLE 6.22AVERAGE

INTERVAL

TRANSIT

TIME

DATA

Make

COMPUTED FROM SEISMIC RECORDS OBTAINED AT PROPOSED WELL LOCATION IN THE PLEISTOCENE TREND OFFSHORE LOUISIANAI2

Make vs

Average Depth

2500 3000 3750 4250 5500 6500 7500 8500 9500

to

3.000

to

3750 4250

to to

5500 6500

to to

7500 8500 9500

to to to

10500

to

11500

to

exponent

137

It

121

11.5

pressures

118

Do

ft

decreased

increased

from

20

1.0

by

to

obtained

ft/hr

Ibm/gal

when

Estimate

in

shale

mud

the the

At

area

value

drillability tion

The

was 2.0

If

is

plot

the

6.20

value

next

between

Make Cartesian

Make

be

to

Answer 87x 106 in

given

vs

Example

depth

in

in

south

6.23

ft

of

data

estimate

penetration

1.2 rate

removed

and

method

of

d-exponent

vs

of

modified

6.23

for

using

Cartesian coordinates

using

Carte

It

5003 6000 7000 8000 9000 10000

Rate tt/hr

each

sample

cup

scale

the

are

Ibm

shale

porosities the

grain

the

in

the

added

to

DATA

FOR

the

Table

in

density the

using

vs

Bit

Rotary

Tooth

Speed

Wear

rpm

the

shale

in

in

trend

zone

Assume pore

pore

60

11.6

30

9.875

42

28.0

0.5

55

9.875

84

0.3 0.0

24.8

60

9.875

90

6.4

50

9.875

60

Ratio

ECD Ibm/gal 9.5 9.5 9.5

0.950

900

9.5 10

2.9

09

20

0.850

9.875

60

0.9

8.2

20

0.850

9.875

60

0.0

0.850

9.875

90

11.0

0.0

0.850

11.0

11.0 11

10040

8.0

20

9.875

10050

90

12.1

0.0

50

0.400

9.875

60

11.0

9.3

0.0

50

0.850

9.875

12000

60

0.8

19.0

30

0.800

13000

6.5

120 120

60

0.0

13.1

0.750

14.0

6.5

42

0.5

0.700

14.2

cen in

of

using

obtained an

fluid

pressure

050

south

given

line

average

density

of

gradient

at

of equivalent

Parameter

1.150

66

9.875

cut

example

densities

6.20

06 02

9.875

13.3

shale

curve

shown

as

and

concept

fraction

40

20

the

are

be

to

grams per cubic

pressure

from

g/cm3

fraction

40

the

column

calibration

depth

normal

EXERCISE

Size

in

to

bubbles

were obtained

density

10020

11000

of

mud

thy

added

is

air

all

density

6.24

shale

formation

using

the

density

determined

g/cm depths

of

density

the

water

until is

average

transition

of 2.65

was cm3

31.4

clean

with

Fresh

stirred

shale

depth

the

in the

cuttings

g/cm3

using

apparent

densiti

32.5

20

bulk

reading

cup

of

reading

average

density

computed

Estimate

RATE

in

scale

sample

of shale

achieved

is

is

2.48

increased

g/cm3

shale density

26.6

10.0

is

using pore

be

gave

empty

10010 10030

ft

known

this

parameter

should

Hydraulic

Bit

Weight

1000

depth

Fig 6.27

us

depth

6.23PENETRATION

Penetration

Depth

well

at

Plot

a5

various

TABLE

the

Answer Yes

23.4-g

1.98

mixture

Determine

depth

vs

d-exponent

vs

6.25

1.074 plot

using

11000

at

using

modified

an

8.3 Ibm/gal

The data

timeter

0.3

and

depth

in

weight

modified

a3

pump

injection

Compute

Louisiana

above of

for

density

psig with

The mixture

Answer

6.23

on

of Table values

coordinates plot

the

pressure

drilled

balance

the

Ibm/gal

construct

in shale

vs

the

mud

is

cuttings

reading

cup

Fig

a8 Answer 0.9 0.5 plot

taken

drilling

10050

depth

and

pressure

from

Compute

Shale

dicator

Louisiana

Short-interval

and

were

pore

sample

until

Kp

of

the

Determine

Table

pore value

the

24

Answer

11.5

tings

the

in

6.22

35xl06

6.9

using

of

When

chamber

balance

forma of

value

coordinates

Make ing

known

the

sand

at

was obtained

modified

shale

line

of

Young

10000 and

data

is

that

mercury

cm3

placed

gulf coast

the

pressure gradient

of a4

a3

for

trend

decrease

mud

to

vs

pressure

MeClendon

think

you

sample

U.S

the

drilling

pressure

pressure

and

the

Using

sian

the

The data

drilled

a6 a7

of

in

air

was

density

effective

obtained

pore

value

value

pore

Bourgoyne

well

was

ft

when

normal

the

Using of

3.0

have

to

Ibm/gal

6.19

of

10000

parameter

thought

what

of

depth

12000

at

a4.Answer 33x10-6 6.18

pore

and

computed

6.21

rate

due

ft

Answer l2Ox 106

plot

the

of 43.2

The penetration

parameter

Note

plot

before

6.17

drillability

10050

Compute

Make

115

of

known

pressure point

112

depth

plot is

Ibm/gal

113

12500

and

plot

Rehm

117

118

modified

10040

Make

140

11500

of

plot

method of

147

115

vs

parameter

increase

160

10500

drillability

ENGINEERING

coordinates

using Cartesian coordinates

between

Time

6s/ft

to

2500

Interval

Transit

ft

1500

depth

of

plot

using Cartesian

DRILLING

effective

FORMATION

PORE

PRESSURE

AND

FRACTURE

TABLE 6.24SHALE DENSITY COLUMN EXERCISE 6.23 Density

Density

ft

163

164

158

154

155

150

145

147

148

140

144

143

142

138

140

137

135

11000

133 130

139 137

133

129

132

12000

130

132

134

128

13000

165

166

163

167

14000

166

167

165

164

normal

Answer

psi/ft

Fig 6.26 Answer 6.24

and

rump

4.09cm

The

10-g

stabilizes

cuttings

then

at

is

ft.

placed

are

is

in

given

determined

of

be

to

moisture

in

placed

minutes

in

the

drying

9.15g Compute the porosity sample Answer 0.208 2.44

at

of

density

ft

14000

at

After

0.465

is

relationship

volume

sample

sample

weight

shale

1.0

pressure gradient

Boatman psig

is

stress

gradient

14000 pore

the bulk

balance

the bulk

at

of

determination

and

psig

12300

10

Exactly

mercury

pressure

the

using

overburden

the

the formation

depths

134

pore

11400

Estimate various

ft

178174

168

Assume

the

gcm3 6.25 pore

Using

pore

bulk

density

dient

The 11000

have

formation

gulf coast

pressure of

and

Eaton

700

11

The 6.29

the

assume

correlation

ft

and

psi

fracture

gra-

90

SHALE

0m2/m

RESISTIVITY

6.30

Shale

Depth

JL 8600 8800 8900 9000 9200 9400

1.0 1.0 1.2 1.2 1.3 1.2 1.1 1.1

1.3 1.3

Resistivity

Dm2Im 1.6 1.6 2.1

2.0 2.5 2.2

9450 9600

3.1

9800 9900

2.6

2.5

2.6

1.2

10000

3.2

1.3

10200

2.7

1.4

10400

1.8

1.1

10450

1.5

1.0

10500

2.8

1.4

10600

1.1

1.2

10700

1.3

14

10800

1.4

1.5

11000

1.9

1.3

11100

1.2

1.3

11200

1.2

1.5

11300

1.4

1.2

1.5

1.6

11400 11700

1.3

11900

0.8

1.6

12100

0.8

1.5

12300

1.0

7100 7200 7300 7400 7450 7600 7650 7800 7850 7900

1.4

12500

1.0

1.5

12900

1.0

1.2

13200

1.0

1.4

13300

1.2

1.3

13500

1.1

1.4

13600

0.8

1.2

0.7

1.6

13700 14000 14100

1.3

14300

0.7

8000 8050 8200 8250 8400 8450

1.4

1.0

1.3

14400 14700 14900

1.5

15100

1.3

1.7

15400

1.5

1.8

15600

1.6

1.4

1.5

1.2

0.8 0.9

1.4 1.4

Answer

interval

js/ft

The

Answer

from

were

TX

Using

6000 ft

at

for

sand

log

fracture

using

The

to

logs

be

Depth ft

reading

gave the

psig

14000

at

stress

13500

was psig

shale

data

these

well and

of pore

plot

data

resistivity

on

drilled

shown

in

Table

Kenedy County method of Matthews and

the

pressure

in

and

fracture

gradient

depth Plot the

mud

the

well

on

drillstem

pore

pressure of

pare

to

Part

the

pore

the

density graph

test

12775

at

Table

6.26

constructed

14350 psig

ft

How

actually in

indicated

does

pressure computed from

used

to

Part

this shale

formation value

com

resistivity

Density

Ibm/gal

of

MacPherson

overburden

density

Mud

Answer 10700

psig

obtained

make

Kelly

the

bulk

The

6.30 6.25

is/ft

density

correlation

8.000

COUNTY TX MUD DENSITY DATA FOR EXERCISE 6.30

TABLE 6.26KENEDY

time

transit

bulk

Compute

Berry

over

variable

100

correlation

The

calculated

drill

2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 5900 6000 6200 6400 6600 6800 6900 7000

Resistivity

psig

Christman

2.45/cm3

in

of

12000

at

correlation

Kelly

TX

EXERCISE

psig

Answer

vs

of

following

Answer 10700 burden psig The Pennebaker correlation

arid

plot

17500

g/em3 Compute

Matthews

The

was

plot

make

Example 6.18

pore

2.35

the

using

make

Example 6.17

data of

Texas

of

plot

depth

south to

make

depth

vs

pressure

found

data of

the

Using

6.28

was

vs

pressure

Example 6.16

of

depth

the

Using

6.27 pore

vs

pressure

6.26

data of

the

COUNTY FOR

Shale

176

the

TABLE 6.25KENEDY DATA

Depth

165 156

stress

and

psi/ft

FOR

Colunin

172

10000

overburden

DATA

Readings

4000 5000 6000 7000 8000 9000

297

RESISTANCE

8.7

10000 11000 14600 16000

9.0 12.6 18.5 18.4

298

APPLIED

6.31

leakoff

ing

having

ft

The

test

ftthe

000

ft

the

of 0.09

and

area

is

line

test

Use

see Point 6.33

the

Compute

data

the

Example 6.25 Exercise 6.31

in

of

in

vs

data given

fracture gel

Fig 6.53

Example 6.25

in

27

20

28

computed

J.F

April

W.B

30

Log

Oil

Formation Pet

Study

of

1973

6168

Analyst

H.C

America

Formation

Predict

and

Logs

Sonic

How

of Physical

No

Paper

Feb

Prediction

Can

Cloud

19

Gradients

L.N

36

Fractures Soc

ConceptStress and Gas

92

1979 Pet

of Fracture

Tech

Gra

12

1972 Run

to

Handbook

Hydraulic

Fracture

Berry

Frac

of Hydraulic

Special

Inclined

Oil

Oct

and Gas

to

Electric

153-160

Spicer

of

Failure

ME

Chenevert

Tests

and

910914 L.A and

1973

MacPherson

of

Louisiana

Mechanics

210

Soc

Offshore

Christman

dients

D.G

Mathematical

Borehole

Aug 29

Tech

1967

Willis

Geologic

Eng

from

AIME 1957

A.A

Bradley Predict

pressure using

strength

and

Shairer

Daneshy Pet

the

by

in

M.K Trans

Estimation

How

Kelly Gradient

Feb

turing

Constants

Potential Pet

Plots

SurveysOffshore

and

Fracture

Hubbert

Birch

Tech

165171

W.R Gas

HE

Whalen

Electrical

1966

and

and

Pressure

Log-Shale

the

26

indicated

circulation

24 25

Use

depth

Oil

line

correlation

strength

the

south leakoff

Feb

Matthews

Formation

Pet

AIME 1965 234254 D.J and Zanier A.M

Timko

and

From

Pressure

of

Properties

10391048

J.B

Foster

Estimation

Shale

Trans

Acoustic

1973

Tech

mud

pressure

of

Pressures

frac

the

E.B

Reynolds

R.K

Johnson

Log-Derived

17727

1965

Sept 22

and

From

Hazards

in

an

the

Prepare

gradient

and

21

bit

depth

of

leakoff

formation

of

June

volume

located

pressure

well

the

3030

water-base

strength

CE

Hottnian Pressure

23 gel is

break

to

and

to

total

pressured

gel

conducted

in

20

3000

l2.25-in

and

well

fracture

at to

IO-lbm/gal

oil

of

set

drilling

inserted

anticipated

plot

Kelly

Compute

pressure

the

the

on

Matthews and 6.32

no

normally

by placing

slope

test

The

ft

sq

be

will

used The

is

in

diameter of

in

the

after

13%-in cas

in

of 12.515

sandwith

first

external

an

lbm/100

chart

and

of

containing

solids

Texas test

conducted

conduct

to fluid

of

14

is

be

having

drilling tion

will

diameter of 4.276

ternal

be conducted

diameter

depth

Drillpipe

will

test

internal

an

ENGINEERING

DRILLING

and

Casing

March

Open-Hole

Pressure

1978

References

B.A

Eaton Oilfield

Fracture

Gradient

Operations

M.C

Powers Marine

Fluid

Mudrocks

AAPG

Pet

and

their

Possible

Relation

in

of Gulf

in

Coast

Migration

Houston

Subsurface

PH

Gulf

Soc

Geological

Jones

on

of

in

Deposits

Louisiana

the

Subsurface

Data

SPE

paper

Meeting

Time

Geologic

10

S.S

Sariento

11

13

mance 1966 14

16

SPE

proach

Soc

Pet

Optimal

Dnlling duction

18

Boret tion

Shale

19

and

Pressures Resistivity

Rogers L. and

of

Gas

oil

compressibility

of

solids

compressibility

of

water

conductivity

of

formation

conductivity

of

water

diameter

Fall

and

Depth

Upon

and

Seismic

bit

d1

inner

diameter

of

annulus

d2

outer diameter

of

annulus

D5

depth

of

depth

into

sediment

depth

into

water

SPE

the

48th

1973 L.J McClure

Safely of

Application

New

Perfor

Drilling

Pet

volume

fraction

of

volume

fraction

of

solids

volume

fraction

of

water

formation

Nov

Tech

Measurement SPE

paper

Aids

1972 F.S Young

Forma

of

3601

Oct

Orleans

Correlation

and

Drilling

presented

36

FR

at

F0

1971

Use

Exponent

Multiple

Regression

Pressure

371-384

Trans

force

impact

matrix

resistivity

stress

gravitational

Ap

and

High-Pressure lIlanual

Dallas

Using

Areas 1967

R.L Ways

Lewis Pet

Eng July-Nov Oct 1969 82

12

1966

Log

Helps

to

Shale

Density

API

Drilling

pressure

expressed

to

Aid

in

porosity

Kb

121 Detect

Abnormal

1969

Part

Detect

constant

formation

and Pro

Forma

Oil

decline

K2

density

dullness constant

parameter drillability

constants saturation

gradient

equivalent

modulus

modified

K1

as

tooth

drillability

3Surface

Overpressuie

elastic

factor

coefficient

pressure gradient

Defection

AIME 1974

oil

factor

formation

normal

Abnormal

1974

interest

Youngs modulus

to

Techniques at

30Oct

Sept

Data

Shale-Density

Sept

diameter

db

Depth

Estimates

Porosity

presented

M.T

Measuring

in

Practices

W.J

of

hole

compressibility

fractional

WA Wells

compressibility

18

Aug

Eng

Boatman

Ce

c0

45 633

Detection

Meeting

Dcc

257 17

1960

Pressure

O.J

Drilling

Fall

A.T

to

open

effective

jet

Slide-rule

Bourgoyne

of

Prospecting

Velocity

Influencing

Vegas

Abnormal

McClendon

From

and Gas

area

653

15

SPE 4643

Overpressum

Annual

Zamora Oil

of

Seismic

Wave

1950 Factors

Shirley

and

Pressure

tion

15

W.A

dnllstnng

capacity

Seismic

13871399

Rehm the

to

of

192 in

of Seismic

Las

Drill

and

Data

area

equation

depth

paper

Meeting

JR

Jordan

Annual

43rd

Function

1977

Houston

SPE

the

Functions

Geophysics

Li

McClure

capacity

Ah

18 289

Techniques Fall

of

16

Logs Bull AAPG E.B The Application

Annual

Ad

C0

1967

Rouge

Interpretation

as

1950

Geological

Reynolds

capacity

Sym

First

Baton

rate

penetration of annulus

1969

1968

Velocity

Drilling

12

at

Velocity

Dependence

Lithology

from

29Oct

Velocity

1953

Geophysics

and

presented

Geophysics

Kaufman

West

Engineering

Sept

Seismic

in

exponents

area

Aa

Northem

the

State

Pressure

2165

Houston

L.Y

Faust

An

E.S

its

Report

Study

132 Penriebaker

and

AAPG

Bull

Group

Neogene

Basin Proc

Abnormal

Sediments

Bull

a8

16

1971

Hydrology

of Mexico

posium

PressureA

a1

Compacting

Exploration

Clayey

in

Application

13531360 in

Oil

53 80 Abnormal

its

1969

Mechanisms

Importance

Petroleum

Nomenclature

and

Oct

Release

1967 51 1245 J.F Diagenesjs

Burst

Prediction

Tech

exponent

parameter

FORMATION

PORE

mSh

PRESSURE

of

mass

AND

299

RESISTANCE

FRACTURE

shale

rotary

Pif Pfn

p0

Pf Pr

seawater

formation

pore

formation

fracture

pressure

leakoff

pore

hydraulic

power

pressure

matrix

rate

gel

Tg

rate

normalized

penetration

stress

stress

strength

porosity

of

water

resistivity

of

water-saturated

effective exp fi

transit

time

interval

transit

time

of

interval

transit

time

of matrix

fluid

pore

ma matrix

fluid

mod modified observed

interval

transit

oil

sh

shale

volume SI

on

weight

Metric

Conversion Factors

bit

general porosity-dependent

in

2.54

ibf

4.448

222

ibm

4.535

924

parameter

ratio

1.198

ibm/gal density

grain Pfl

pore

density fluid

density

Conversion

264

6.894

757

psV

1.450

377

psi/ft

2.262

059

psi

density

119

3.048

ft

strain

Poissons

5.216

bbl/ft

coordinates

spatial

bulk

value

water

volume

weight

Pb

intercept

solid

time

volume shale

equivalent

exponent

normal

interval

normal

constant

Subscripts

material

Wb

vertical

rate

resistivity

total

stress

overburden

porosity c/

penetration

time

Vt

matrix

of

burden

formation

Vsh

density

horizontal

a11

radius

R0

grains

density

weight

pressure drop

density matrix

solid

stress

pressure

frictional

flow

water

pressure

formation

normal

of

density

pressure

Pf

mixture

average speed

factor

is

exact

E01 E01 E00 E00 E0l E02 E00 E04 E01

m3/m cm

kg

kg/m3 kPa

Pa1 kPa/m

over

Chapter

Casing Design

The

purpose

functions

of casing

chapter

to

is

the

the primary

present

the

casing

and

used

strings

this

of

oilwell

of

ed

various types of casing

procedures

used

in the

design

strings

to

circulate the

dations

when

also

Casing

serves

several

well

completing during

from

fluids

It

the

subsurface

subsurface

the

of

the

reaches

search

and

safe

with

control

of properly

the

age

cost

of

of

generally

of for

the

BOPs

with

ings

that

well

as

the

be

risk

Fig

the

casing

7.1

shows

lost

drilling

is

the

objective

earth

to

surface

Subsequent

engineer that

to

is

will

an

the

can

through

an

its

on

the

re

to

5000

any

event

be

as

justi of

phase

casing

programs

for

basins sedimentary abnormal formation pore

the

wells

deep

casing for the

zones and well

or

well

casing

The conductor

that

pressure

salt sections

suiface

may to

casing

will

gra

require

drill is

into

ft

the

closed

placed

crater could

to

the

need-

to

up

several

sediments

are

Because

of

or

lost

salt sections

final

mation

pore

of

cementing

penetrate

the

below

will

generally casing

well

depth

pressures

the

abnormal

pore

hundred

feet

the

rig

300

to

of

possibility surface-

are

practices

subject

the

are

in the

present is

needed

from

drilling-fluid

an

or

more

strings

to

the

density below

additional

depth

abnormal

deeper

for

portions

forma

protect

pressures

created

Similarly sections

br

sections

surface-casing

lb When

pressures are found

pore pressure

shale

one

require

Fig

pressured

unstable

between

surface casing

required high

normal

the

eventu

aquifers

abnormally

zones

well intermediate casing

tions

by

that

circulation

of intermediate the

formation

regulations

Deeper wells mations

and

enough

from

the

to

casing

deep

engulf

usually

depths

government

the

fractures

completely

depths

cas

by closing

from reaching

such

through

sup

casing

surface

kick

seat

casing

fresh

also

casing

unless

has been

casing-setting to

weaker

shallow

contained

of shallow-water-supply

and typical

large

which

The sur

subsequent

of

be

to

and

of formation

depth

the

contamination

The sav design

design

this

flow

least

well

life

optimal

from an improper effort

aver

important

the

erode

diameter

the

pressure-induced

the

shown

the

design

allow

throughout

safely

failure

Thus

in

the

on

personnel

rig

Surface

flow

prevent

below

initiated

Surface-casing-setting

18% of

about

most

the

have

studies

program

engineering

circulation

Conductor

In the

some of

installed

influx

protects

the

different

encounter

and

well

allows

casing

of unconsolidated

from corrosion

fracture

success

of

one

program

in several

dients

become

well

achieved of

deposits

well

complete

has

tubulars

program

considerable drilling

of

operated

can

to

drilling

the

casing

and

the

be

surface casing

BOPs should not be BOPs are attached

The which

ally

completed of

expensive

and

Casing

cost

average

sponsibility

drilled

drill

to

parts

in

ing

from

interest

increases

eXpensive that

run

strings

flow

contamination

protects

the

cement

communication

isolated

ports and

for

required

also

fully

depth

the

permits

flow

high-strength surface

commercial hydrocarbon depths the number and sizes of

greater

strings

only

the

hostile

by

sediments

sands from

can

foun

rig

from corro

strings

system

cave-in

and

rig

structurally

unexpected

to

drilling

the

casing

divert

shaker without

shale

The conductor

support

of an

prevents

near-surface water

to

case

during

casing

into

As

not

to

face

to

diverter

in

fluids

well

load casing

wellbore

envi

subsequent

equipment

borehole

formation

the

conductor

the

subsurface

the

perforation

permits

formation

given

BOP

Selective

also

casing

and

and

the

and

the

provides

It

fluid

drilling

pressure

isolates

of both

process

in drilling

of

collapse

formations

damage

drilling

preventers

mation

prevents

environment

for

blowout

ed

the

functions

hydraulically

minimizes

ronment by

conduit

It

and

drilling

fluids

important

to the

below

initiated

is

may be used

wellhead

fluid

drilling

drilling

protects

sion and Introduction

the

surface sediments

eroding

when having

intermediate casing

CASING

DESIGN

IBm

301

LI

Soft

Couductor

5/8

9-

in

Surface

3000

30

In

20

in

ft

nduCorJJ

200

2Dm

ft

Conductor

Conductor

600

ft

ft

Casing

3/8 Surloce

13-3/8

4000

in Casing

13-

ft

5p00

in

Surfocn

ft

Casing

7-in to

Tapered

5-in

Liner

Tieback

9-5/8

in

m-

Intermediate Casing

9-5/8

in

Intermediate

Ii Ii

ii

Ii

ii II ii II II

7-5/Bin

6000

in

in

Production

7000ff

Liner

Drilling

51/2

Sin 15000

Casing

MISSISSI

ft

Production

OFFSHORE MIOCENE

PPI

Fig

permits tions

shale

Liners

are

casing

to

provided

from

the

sometimes

re

or

liner

using wear

similar

is

LOUISIANA

casing

programs

7.1

Manufacture

The

three

tend

problems

above

string

the mill rolls

plug

plug mills

iso

are then

final

vironment during

in

the

liner

of

interval

nected

to

nected

connector

well

the

liner

Production

from of

drilling

the

also

of

design

by

well

similar

uniform

advance

in

the

wall

the

similar

in

into

billet

to

pipe dimensions

processed of

thickness

design

the

to

the pipe surfaces

Fig 7.2c

thickness

is

in

lower

the plug and

mills

roundness

and

produce

Fig

and

exploratory Casing to

interval

the

fluid

liners

thus often

with

the

for

is

an

tie-back

weights permits

in

en

well

are

casing

is

con

lot

ROTARY

PIERCING

REELERS

MILLS

designed

casing

strings

below

drilling

wear

con

casing

resulting

deeper

portion

not exposed extended casing

to

peri

strings

the upper

part

more economical

Ib

PLUG

IdI

MILLS

Fia

7.2Manufacture

of

SIZING

seamless

MILLS

casino

tube rolls mills

to

Finally

productive

specially

limited

hanging

of

the

piercing

production

life

central

two single-groove

plugs with

design

billet

The pierced

where

burnish wall

orient

gripped by two obliquely

string

tie-back

with tie-back

drilling

for the

generally

Tie-back

planned is

the

the

using

productive

of production

results the

the

damage

od Use

is

operations

well and

potential

to

introduced

is

billet

the

mandrel

by

productive

tubing

the

through

with

when

interval

productive

in

liners

liner

liners

are most advantageous the

set

completed

the

the

permits later

wellhead

is

top of

the

to

and

or repaired

surface

of

failure

well Production

the the

when

string

of

is

the

through

provides protection

operations

be replaced

production

set

casing

string

event

production to

tubing

is

casing

This casing

interval

Reelers

The heated

In

welding

pierced

operations

drilling

Production

by

more uniform

problems

is

and

central

used

mills

it

Fig 7.2a

piercing

ing

well

rotate

through

reduced

mill

where

that

Fig 7.2b to

it

to

serves

it

into

is

drilling-liner

that

process

electric-

process

first

is

of

manufacture

the

electric-flash

and billet

rotary piercing

in

used

seamless

the

in

ed

Casing

processes

welding

are

seat

principal

cement leakage

cause

to

of

feet

The

drilling in

sur

the

basic

of

include

resistance

next larg

the

However

casing

casing

to

21000ff

Liner

DELAWARE BASIN TEXAS ELLEN BURGER TREND

Cc

TREND

seamless

casing

and

seal

Production

well

prevent

hundred

the

cost

the

that

zones

of

cement seal

exposes

intermediate

to

and

top

lower

its

bottom

during subsequent

troublesome

during

in ft

an

zones

Several

from hanger

arise

additional

liner

to

do not extend

the

good

liner

these

ic

promote

of

advantage

late

be

also

zone

penetrated

that

strings

Fig

string

between

overlap

is

casing

is

below

drilling

but are suspended

Also

forma

deeper

may

casing

lost-circulation

salt section

or

while

problems

er

drill

7.1Example

20 000

casing

unstable

face

to

density

Intermediate

troublesome

after

quired

mud

the

lowering

economically

__

Casing

TREND

SMACKOVER

ft

Liner

Drilling

75/8

ft

11000

ii

3000

Casing

Surfo

to

form siz the

.2d

APPLIED

302

In

the

and

electric

The

desired tube

makes

ly

ing

the

the

two edges

pipe

entire

elastic

limit

pendicular

wall

be

also

7.2

of

for

accepted dustry

ODs

of

the steel

lower

its

properties3

the

properties to

nation

in the

API

by

the

in

per

C-90 C-95

P-hO

110000

Minimum

Ultimate Tensile

Strength

Maximum

psi

80000 80000 80000 90000 95000

60000 75000 95000 95000 95000

Elongation

29.5 24.0 19.5 19.5 19.5

110000

100000

18.5

105000

100000

18.5

110000

105000

18.0

140000

125000

15.0

Test

is

with

strength and

small

vide in

Strength

tempering

to

used

was

grade

minimum

range

yield

of

the

in

of

in

the

design

of

pipe The

selected

teller

stipulates

not exceed

steel

grades

USED

that

to

grades

0.04% and

given

GRADES

Manufacturer

S-80

Mod

Strength

psi

Grade

Lone

Star

Minimum

the

Mannesmann Mannesmann

Tube

SS-95

Lone

Steel

S00-95

Mannesmann

Tube

S-95

Lone

Steel

Star

Star

Tube

Co Co

80000 90000

Maximum

95000 105000

95000 75OOO Co

95000

110000

yield

Mannesmann Tube Mannesmann Tube U.S Steel Mannesmann Tube

S00-140 V-150 S00-1

55

iest specimen Circumfe ti

with

area

greater

than

0.75

Co Co Co sq

in

Longitudinal

Maximum

ultimate

tensile

strength

of

120000

psi

strength

tensile

strength

at failure

length

that

the

of each

maximum

the

amount of

used

in

Table

in

the

of

commonly

yield

and

Table in the sulfur

the

7.1 steel

must

petroleum-producing

7.2 These

steel

OF CASING

Ultimate Strength

Minimum Elongation

psi

Sb

75000

20.0

100000

24.0

120000

26.0 18.0

110000

20.0

110000

16.0

92OOO S00-125

data

be

grades there are many propri do not conform to all API specifi

95000

95000

average test

computed as 80% observed In addition to

should

55000t N-80

C-9o

an

API

that

Tensile

75000

Steel

in

pipe

considerable

Minimum Yield

Non-API

on

beyond

variations

rather than

on

acceptable

Strength properties

are

NON-API

slightly

amount of phosphorus

the

but are widely

industry

Based

unit

of 0.005

length is

yield

required

0.06%

addition

cations

criterion

ultimate

per

The

stress

significant

specifies

minimum

of psi

on manufactured

strength

API

elongation

etary

pro-

yield

minimum

strain

adopted

minimum

the

tensile unit

per

are

yield strength

casing

the

This

there

strength

minimum

In

as

measured

was adopted

the

not exceed

code

TABLE 7.2COMMONLY

yield

of casing

grade

thousands

in

API

elongation

the

also

steel

limit Since

of

must

desig

to

arbitrarily

in

sq

each

for

specimen

strength

It

define

grade

The

0.75

number designates

by

strengths

average

grade

of casing

to

the

test

failure

casing

designation

the

total

minimum

specifying

of

of the

test

stress

are

API provides

computation

number

by

been

The minimum-perfor

grade of

followed

yield

quality-control

the

possibility

casing

elastic

in

The

defined

produce

the

minimum-performance for

is

the

couplings

standards

properties

the

and

than

designation

strength

strength

stan

included

properties

and

recommended

must be

have

pipe with

pipe

these

formulas4

that

greater

standards

standard

goods

the

both

unique

the

yield

manufacturers

has developed

area

rela

Petroleum-producing

tubular

as

with

specimen

and

strength

casing

most

API

the

by

characteristics letter

its

other tubular

has adopted

of

suffi

raises it

N-80

of Casing

for

minimize

strength

L-80

steel

be normalized

dimensions

and

strings

the

C-75

to

Inst

addition

mance

consists

K-55

cost

minimum-performance

API

can

20 in Among

to

In

on

40000 55000 55000 75000 80000 80000 90000 95000

J-55

The strength of

in

quenching

defined

is

physical

bulletins

welded

yield

used

favored

is

Petroleum and

by the

increase

by

which

standards2

procedures

Some

Minimum

H-40

form

pressing

reduces

OD

its

Steel

and to

increased

Casing

strength

weld

and

Grade

by

and

deform the

is

controlled

is

internationally

API

sheet

Strength

psi

API

desired lengths

flashing

the

Minimum

into

arc The

limit This process

of casing

size

casing

of 4.5

fed

electric

RECOGNIZED

the

Yield is

processes

stressed

Standardization

dards

form

simultaneously

that

elastic

manganese

The American

the

dies

direction

casing

process because

make

TABLE 7.1GRADES OF CASING BY THE API

continuous

that

to the

technique

to

mud 0.3 carbon of

cut

cut

ENGINEERING

directions

size

amounts can

its

in the

thickness

tively

by an

tube and

through

The nominal given

then

is

to

together

exceed

to

ciently

stock

sheet

is

together

to

process

welded

welding

length

passed

is

metal

desired dimensions

the

to

it

coiled

machine

the

electric-flash

cutting

extraneous

formed and

pipe leaving

The

from

welded

are

edges

electric-resistance

casing

machine

the

of

sheet stock

flat

processes

two

the

addition

the

without

welding

and

formed

DRILLING

125000

150000

135000

18.0

140000

165000

150000

17.0

150000

180000

160000

14.0

155000

180000

165000

20.0

used grades

non-API are used

303

CASING DESIGN

for

special

steels

that

The

of

more

are

API

16

25

to

R-3

Range

that

when casing

than

one than

R-3

addition

mum

Since be

and

casing

handled

To meet held

of

generally

will

mandrel

in For

ensure

to

diameter

for

that

passed

dered

requirements the

before

the

wall

specify casing

discussing casing nominal for

foot

is

cation

weight

threads and

not

true

the

weight

pipe

body

of an

length

weight

possible

per

the

average

design

weight

calculations

per are

weight The nominal

but

useful

is

the

for

is

cut

and

at

ist

with

the

weight

This connection seal

pressure If

the

separate

the

Because

is

leak

of

yielding

used

to

In

and

cou

foot

the

total

practice to

of

weight

nominal

is

generally

performed

with

the

for the

also

the

to

Size

in

drift

pressure

the

obtain casing weight

8%

9%

the

to

average the

best

9/

10

string per

foot

nominal

weight

four

types

loose connection

have

7.3SPECIAL of

forces

result

of

Weight

Wall

TC

Thickness

Star

for

connection assisting

Steel Drift

Diameter

in

API

23.00

0.317

6.241

6.250

32.00

0.453

5.969

6.000

46.10

0.595

32.00

0.352

7.796

7.875

40.00

0.450

7.600

7.625

49.70

0.557

40.00

0.395

8.679

8.750

43.50

0.435

8.599

8.625

47.00

0.472

8.525

8.625

58.40

0.595

8.279

8.375

59.20

0.595

62.80

0.625

45.50

0.400

9.794

9.875

55.50

0.495

9.604

9.625

Special

6.500

7.500

8.500 8.500

0.595

9.404

9.504

60.00

0.489

10.616

10.625

65.00

0.534

10.526

10.625

11/

71.80

0.582

l3/e

72.00

0.514

12.191

12.250

86.00

0.625

11.969

12.000

81.40

0.580

12.250

88.20

0.625

12.250

13%

exces

powdered metals

DIAMETERS

DRIFT

or and

strength

during

material

Lone

con

threads

end

casing

filler

can

over-tight the

reduced

containing

frictional

provide

An of

galling

65.70

131/2

to

the

both

monitoring

by

11

small and most

liq

acts

further

diameter as

compounds

Ibfflt

seal high-

low-viscosity

internal

threaded

Courtesy

cow

with

following

can

reduce

make-up and

per

portion

pipe

of

reduced

produce

com

Thread

dependable

strength

because It

peaks

stress rapidly on taper made up The proper amount

reduced

have

Special thread are

be

number of turns

the

will

to

determined

best

Thread

are cut

threads are

the

cost

obtain

to

solid-free

surfaces

threads

the as

and

Round

thread voids

these

ineffective

threaded

make-up torque and and

gases is

seal

fill

of

low

formed small voids ex

is

not designed

is

for

needed

because

has rounded

and

of each

crests to

coupling

and

API

the

angle

coupling

and

roots

foot

per

is

included the

and

when

connectors

7.3a

threads diameter

of manufacture

Fig

must be used

pound

uids

in

600

When

roots

used

ease

of this

on

thread run-out strength

and

shape

Because

in./ft

3%

same

the

API 8-Round

as

greater

commonly

seen

rounded

taper of

longer

reliability

be

per

identifi

weight

per

calculated

total

specifications

connectors

proven

As can

to

shown

are

have

connectors

have

referred

provide

very

average

foot

casing

are

their

OD

be

weight

one end divided by

is

foot

These

OD

per foot

and

average is

weight

between

variation

API provides of

the

estimate of

However

LCSG

connectors

API

the

threads per inch

eight

pipe sizes

all

unsatisfactory

known

differentiate

threaded

the

at

sometimes

foot

per

should

foot

joint

average

give

most manufacturers

proved

drift

conventional

is

weight

of

Threads

sometimes

are

the

has

by casing

of threaded

power-tight the

foot

average joint

for

of

sive

size

it

that

depth

The threads are cut with

can

company

and

size

one

per

excluding

average

of

by

approximate

weight

The

weight

pling attached

and

an

as

they

with

made

thread

well

design

to

coupling

non-API

plain-end

per

spaced

cracked

threading

However

couplings

weight

purposes

pling

specified

weights

The plain-end

foot

tal

can

are

passage

oversized

be

basic thread

can

or

XCSG

CSG

LCSG BCSG

API threads

of

of each

nection

that

threads

Fig 7.3 The CSG and LCSG

TABLE

thickness

In

weight

be

dimensions

to

tween

the

in

leak

manufacture

pipe

nominal

and

Schematics in

of

specially

available

they should

distributor

dimensions

Casing and

the

be

increases

diameter

casing

can

7.3 When

Table

in

given

drift

couplings

V-shaped

enough

casing

API

instances

mandrel

drift

specified

are

mill

these

In

run

to

with

of 4.5

man

and

threads

development

casing

diameter

the

couplings

increases

drift

the

couplings

and

sharp

must

that

not long

ensure

more commonly

the

are

drift

greater than

oversized

diameters

drift

will

it

wall

range

12-in is

desirable

is

it

size

Some of

but the

length

sizes

the

specified

of

in the

mandrel

drift

pipe

slightly

casing an

sizes

casing

by

diameter

pipe The

casing

than

less

size

some instances

In drift

of

for

larger

straight

bit

of

to

in

mandrel

of

controlled

is

minimum

and

controlled

is

the

through

OD

for

minimum

is

87.5%

is

be

to

The mini

oversized

and

threads

used

casing

found

is

maximum ID

tolerances

must be used The

drel

string

However

thickness

The

The minimjm ID

8.625

to

R-3

in

in the

usually

slightly

pipe-wall

pass unobstructed drift

ft

often

the

Casing

thickness

diameterthe

drift

ensure

to

combined

thickness

maxi

try to prevent pipe from thread when mn-out adequate

API tolerance but

wall

the

by

0.75%

tolerance

permissible

nominal

for

ft

R-

for

ft

number of connections

connection

machining the

36

have

threads

round

Extremeline

great lengths

and

run most

is

Casing

specified

have

must

shipment

range

amounts

R-2

for

ft

no greater than

the

undersized

mum

the

in

pipe must

the

28

also

is

mill

34-ft

round

Long

Before

range

made up in single joints R-3 lengths can easily by most rigs API specifications the OD of casing must be

manufacturers

within

the

It

for

ranges in the

to

Short

Buttress

is

within

being

of

R-3

for

ft

of

R-1

for

95%

reduce

to

lengths

ft

variation

length

R-2

for

18

25-

the

is

from

95%

sulfide

length

and longer

ft

ordered

carload

greater In

is

34

is

high-strength

lengths

joint

R-2

Range

or

three

includes

tensile

high

very

hydrogen

to

recognize

R-1

ft

require

resistance

resistant

Standards

Range

and

er

collapse

special

casing

that

applications

strength

10.625

in

304

APPLIED

CASUG

ENGINEERING

TPCR

Silt

IS 1.112

DRILLING

IS PER

53-3/I

FOOT

OS

CIA

3/4

141.20

Round

API

Thread

Connector

API

Buttress

plugging

any

remaining

crests

the

threads

in

prevent

and

galling

connection

up

joint

the er

of

included casing

tensile

the

This can the

addition

of

it

run-out

up

ings

The

tegral

On

to

an

is

at

the

It

the

Fig

and upon In

or coupling

the

near

the

to

of

the

for

basic

Thread

and

thread so

the

Five threads

are

squarer

34-in./ft

16-in

the

for

or

casing

cas

larger

of

placement

provides

the

choice

when

good

thread

sealing leak-

Fig

API

other

box

the

is

is

of

machine is

the

stronger

an in

therefore

are

is

half

as

run

many

fewer

minimum

the

casing

ID

to

it

the

provide

connector

the

when

potential will

be

sites

be

OD

of

API

largest

situa

restricted-clearance

threaded

in

neces

other the

It

wall

must

the

The

than

an

is

pipe

pipe wall

alternative

7.3c

Fig

in that

less

significantly

providing

in

machined on

connection

ends

shown

connectors

size

there

The

Round

is

is

teeth

connector

comlector thus

API

effi

joint

most cases

needed

is

integral-joint

the

of

coupling

pin

reduced

in./ft

roots

i.e

joint

connector

the

the

Threads

possible casing tion Also only

ever

the

600

the

collapse

longer coupling

not however

is

in

thread taper

the

XCSG

from

couplings

of

of

that

greatly

in and

API

XCSG

as

effect

out of

thread shape

the

tendency

to

sary metal an

and

connection

thicker

to

great

end

Fig 7.3b The

in

100%

is

However

inch and

compound mechanism

differs

and

fracture

is

well

as

joint

efficient

threaded

yield

shown

is

As with API Round

proof

the

their

the

Although

100%

are

threads

jump

body

to

used

to

connector

unzippering

to

similar

is

are used

the

sizes

an

connector

tapered

is

unzippering to

to

jump-out

BCSG

this

thread design in that

pipe

connectors

occur

API

ciency

the

begins

appears

the

Connector

that is

of

strength

neither

on

ensure

to

API Extreme-Line

made-

according

LCSG

the threads

produce

pin

to this

can

The

cut

of

sometimes

failure

of

API

critical

connector

rated

tensile

connector

tapering

angle

often

strength the

given

Connector

and

roots

is

properly

exercised

the

the

is

of

CSG

the

Because

7.4

the

be

are

which

efficiency

than

leak-proof

for

connections

by

joint

also

compound

efficiency

divided

to obtain

the

used

compound

Care must

proper thread Threaded

small voids around

The

Thread

7.3Api

Fig

connections

exist

for

How

less

leakage

for

the

XCSG

7.4Jo

nt

pull-out

failure

mode

for

API round

thread

CASING DESIGN

305

available

API connections

on

offered

the

are

Flush

following

Smooth

maximum

for

joints

bores

the

Among

features

special

items clearance

tur

reduced

for

connectors

through

bulence Threads to

for

designed

with low

make-up

fast

tendency

cross-thread Multiple

metal-to-metal

seals

shoulders

improved

for

pressure

improved

integrity Multiple

High

for

compressive

strengths

strength

torque

for

sit

loading

special

uations Resilient

Several

shown cial

for

rings

nector corrosion

its

and

seal-lock

connector

collapse

from

the

below the

joint

of

elastic

limit Similarly

sional

force

required

7.3c

This

for

does

sealing

the

and

ends

for the

In

of

addition

connections

to

are

IJ-4S

INTEGRAL

than the

the

seal

pin and

depend

API

XCSG

offer

CONNECTOR CONNECTOR

JOINT

Fig

7.6Sample

box Fig

on

is

needed

pipe walls

tolerances are

premium

joint to is

rating

cause

sure

that

sence

of

Bradford

API these

pressure will

rating

cause

the

axial

recommended

performance

walls axial

external

for

ab

Fig 7.8b

collapse

formulas4

internal

in the

rupture

loading

its

ten

Fig 7.8a

minimum

loading

to

ten

the

body the minimum

minimum

the

pressure and

internal

provides

is

to

is

exceed

to

failure

joint

casing

the casing

cause

is

the calculated

pressure and

external

pipe

strength

suspended

strength

yield

the

results

loading string

pres

ab

in the

Fig

8c

computing

properties

much 7.3.1

proprietary features

THREADED

Atas

Body

in

burst pressure

need

connectors

many

Collapse

thread

still

thicker

connectors

API

connections that

only

tension

of the casing

connector

the

compound required

the other

available

XCSG

the

the

closer machining

the

metal-to-metal

more expensive

not

although

lubrication Because

near

in

used

between

seal

connector for

compound

ed

mechanism

sealing

metal-to-metal

of

sence

Axial

cause

to

required

will

spe

of casing

properties

tension

interest

force

that

the

Properties

wcial

weight

sional

pressure

The

for

pressure

primarily

Burst pressure

is

performance

values

rated

are

connectors

illustrate

which

API Casing Performance

clude

con

and

seals

above

listed

The most important

7.5Armco

non-API

of premium Figs 7.5 through 7.7

in

pressure

protection

examples

features

7.3

Fig

secondary

not

Tension

Pipe-body

in

strength

tension can

the simplified free-body

diagram

TC-4S CONNECTOR AND COUPLED CONNECTOR

connectors

with

resilient

seals

and

be

computed by use of in Fig 7.9 The

shown

FL-4S

FLUSH

smooth

bores

CONNECTOR

INTEGRAL

JOINT

APPLIED

306

Nd

CONNECTOR

CONDUCTOR

FOR

EXTERNAL

CASING

NON-CROSS

UPSET

GEOTHERMAL

THREAD

HIGH

DESIGN

CTS

STRENGTH

CONNECTOR

COUPLED

SERVICE

COMPRESSIVE

WITH

TRIPLE

TRIPLE

SMOOTH

SEAL

SEAL

INTEGRAL

BORE

FOR

NON

CONNECTOR

FJIFJ-P CONNECTOR FLUSH INTEGRAL JOINT

CONNECTOR UPSET

ENGINEERING

DRILLING

PIPE

INTEGRAL

JOINT

7.7Sample

Fig

force

F2

of

F2

the

pull

the

apart

pipe

is

which exert

walls

pipe

given

is

F2

to

tending

Ften

strength

Hydril

connectors

two-step

resisted

with

three

metal-

to-metal

seals

the

by

counterforce

by

JOINT

aICIdAS

FAILURE

where

yieId

cross-sectional is

given

Ften

The pipe-body

of

the

in

of

and

Eq

Because

87.5%

is

formulas

by

API

for

computing

minimum

for

design are

formulas pending

joint

lower

are

minimum

nominal

based

wall

cannot

theoretical

values

for

minimum

the

presented

on whether

force

are for

JOINT

the

is

wall

INTERNAL PRESSURE

thick

acceptable

BURST

FAILURE

FROM

INTERNAL

PRESSURE

thickness be assured consider

for

the

joint

Buttress

area

is

for

connections

pipe-thread

strength

Fig

Extreme-line

steel

fracture

are presented

recommended

minimum

coupling-thread

pin or pipe body

on

pull-out

Similarly

presented

minimum

the

the

OR

on empirical observations have been For API Round Thread connections

partially

The

of

BODY

signifi

wall

acceptable

permanent deformation

formulas

lOa

minimum

the

accepted

mulas

be

value However the nominal

absence

casing

expected

this

pipe

PIPE

IN

perma minimum

two would

in

7.1

FAILURE

cause

higher than

used

the

The

pipe

the

to

expected

the

Joint-strength

and

be

pull

thickness

ations

Eq

computed with

to

required

is

wall

strength

7.1

would

that

thickness rather than ness

the

is

pipe-body

TENSION

strength

force

deformation

cantly

the

d2

FyieIddn2

force

strength and

yield

Thus

area of steel

by

minimum nent

minimum

the

is

strength

lOb

connections

minimal

in the

force

Fig use

in

EXTERNAL PRESSURE

for and Three

de box

COLLAPSE

FAILURE

FROM

EXTERNAL

PRESSURE

Fig 7.lOc in

Tn.nn

....1

..

...i

DESIGN

CASING

307

Ft en Area

under

last

thread

perfect

d2

_0.14252 Tensional

force

Fte

Tensional

F0

for

fracture

O.95A1pai1

force

for

puH-out

joint

95A

14d

\0.5Let0

Thread

Round

Area

of

Steel

L0.14ci

Connector

Body

Pipe

in

Ad2d2 Area

of

Steel

Coupling

in

d2 d1 Tensional

yied

Force

for

Pipe Thread

Failure

aeId1

O.95Apoit

it

Fig

7.9Tensional

balance

force

on

body

pipe

Tensional

Force

K-55

with

casing

and

the body-yield

Compute

7.1

nominal

nominal

weight

per

wall

thickness

of

foot

133

20-in

for

strength

Buttress

in

of 0.635

This

minimum

has

pipe

Thread

Connector

lbflft Tensiona

Solution

yield

Force

for

and

psi

ID

an

Fie

of

Force

Tensional

d20.002O.63518.730

Pipe

-d

of

strength

ii

55000

for

cross-sectional

the

Box

in

area

of

steel

minimum

and an

pipe-body

load

axial

db

F10

predicted

Eq

by

7.1

at

2125000

7.10API

Fig

lbf

7.11

the is

string exert

F1

for

the

internal

LdS

is

free-body

The

burst

to

Pin

Failure

UItd2

Connector

force

F1

which the

joint-strength

conditions

static

formula.34

gives

Fig

casing

of the pipe walls

br acting on

pressure

given

of

diagram

F1

force

by the strength

counterforce

2F2

F1

which results

projected

the

Substituting

and

solving

for

burst

for

expressions

appropriate

the

pressure

rating

and

F1

Pbr

F2

yields

by

br

PbrL1O

The strength

resisting

force

acting

tL dO

F2

simplified

tendency resisted

from the area

the

for

forces

Totaling in

br

Extreme-Line

7.3.2 Burst Pressure As shown

Force

of

5500038.63

Ften

is

yield

in

sq

Failure

is

Tensional

A520218.73238.63

Failure

_d2

Fte

Thus

Failure

O.95Asco

Ften

Example

Thread

Coupling

for

over

F2 the

resulting steel

area

from

the

tL

given

is

steel

by

This

greater

Barlows5 the used

is

equation

values

above in

valid

than

equation equation

place

of the

only

those

for

ID

for

for

of

thin-wall

pipes with

most casing

strings

thick-wall

thin-wall

pipe

pipe

if

is

the

Barlows equation

It

identical

OD results

to is

from

APPLIED

308

F1

ENGINEERING

DRILLING

PbrLdS

PbrLd0 dS

dO

F20tL

sin

dO

o5tL Fig

7.11Free-body

solution

nonrigorous conservative

minimum

the

count

is

burst

casing

accurate

fairly

Fig 7.12Two-dimensional

slightly

formula The API burst-pressure on Barlows equation Use of 87.5% of

yield

21

for

strength

minimum

the

but

for

thick-wall

based

is

rating

diagram

allowable

o1

steel wall

takes

thickness

ac

into

and

gives

the

ample any

dimensional radius

and

classical

problem and

API recommends

ed

the

to

to the

nearest

use of nearest

10

this

equation

0.001

in and

with the

wall

thick-

in and

nominal

weight

wall

of

foot

per

133

of 0.635

lbf/ft

where

and

radius

For

will

Solution

Eq

of

The

burst-pressure

rating

by use

0O00.635/20.00

3056

psi

are both

that

Pe

the

then

the

pipe

10 psi

nearest

This burst-pressure

psi

mum

expected

deformation no

the

to

internal

could

external

pressure

place

or

axial

at

if

which

the

is

pipe

the

conditions

to

only

an

If

external

reduces

at

stress

direction

tangential

7.3b

stresses

tangential

burst

subjected

rr1 Eq

for

and

and

it

is

pres

to

2PeTo ____________________

at

mini

permanent is

r2

r1

2t2t

3060

the

to

corresponds

rating

pressure

take

becomes

value

this

7.3a

7.3b

radial

in

tr0

Rounded

r2

r2

collapse

maximum

be

assumed sure

7.2

0.875255

Pbr

computed

is

inner

the

for

rating

thickness

between gives6

r2_pero2ri2 r2r02

burst-pressure

Ap two-

this

and

pr12r02

nominal

for

r2

Ut

the

with

round

results

psi

7.2 Compute Example 20-in K-55 casing with

To

r2pero

7.2

r2r02

ness rounded

radius

any

radius

Fig 7.12

pressure

theory

elasticity

at

outer

in

internal

p1r2r02 2r2 ___________________________

ieldt

Pbr.875

the

shown

section

pressure

of

plication

cross

casing

external

wall stress

pipe to

subjected

Use of

the

effective

and rearranged following

compressive

terms

formulas

reduces

for

yield

the

collapse

loads

to

equation

pressure

as

for

strength

above

the

rating

1d/t11 7.3.3

The

of

collapse

more complex nal

ful ty

steel

as

the

one

results theory

tangentiaj

pipe from

simplified

shown

However

can

hoop

be

used

stress

in

external

than

phenomenon

pressure

such

Pcr2Uyjelde

Pressure

Collapse

free-body

establish

in the

the

pipe wall

analysis

not lead classical radial

much

is

from inter

diagram

Fig 7.11 does

more complex to

pressure

pipe burst

to

use

elastici stress

Consider

7.4a

for

It

can

also

be

when

the

pipe

proof

of

this

The

and

Eq

ex

shown

collapse

7.4a

is

is

is

shown

left

that

called

Eq

that

subjected

only

7.3b to

student

as

occurs

in

reduces

internal

that

Eq

7.2

The

exercise

approximate

agreement

yield-strength collapse

experimentally

to

pressure

yield-strength

It

has

cnlkinse

with been

nmirc

CASING

309

DESIGN

TABLE 7.4EMPIRICAL FOR COLLAPSE-PRESSURE

COEFFICIENTS

USED DETERMINATION4

F4F

F2

to

2950 2976

0.0465

754

2.063

0.0325

0.0515

2.003

0.0347

2.991

0.0541

60

3.005

0.0566

-70

3.037

0.0617

3054

0.0642

1056 1206 1356 1656 1806

3.071

0.0667

C-90

3.106

0.0718

1955 2254

C-95

3.124

0.0743

H-40 -50 J-K

55

C-75 N-80

L-80

0.0360

pressures

0.0373

metric

1.984

0.0403

1.990

0.0418

1.998

0.0434

leads

0.0466

2.029

0.0482

2.040

0.0499

2.053

0.0515

3.143

0.0768

3.162

0.0794

P-hO

3.181

0.0819

2.066

0.0532

-120

3.219

0.0870

3151

2.092

0.0565

-125

3.239

0.0895

3301

2.106

0.0582

than

the

2.119

0.0599

-135

3.278

0.0946

3601

2.133

0.0615

-140

3.297

0.0971

3751

2.146

0.0632

-150

3.336

0.1021

0.0666

3.356

0.1047

2.188

0.0683

-160

3.375

0.1072

2.202

0.0700

-170

3.412

0.1123

2.231

0.0734

-180

3.449

0.1173

4053 4204 4356 4660 4966

2.174

-155

2.261

0.0769

isformation

letter

designation

are

not

API

being

considered

for

use

and

but

grades

for

casing

range

is

the

7.5a

for

is

It

calculated

of

range

The upper

limit

values

It

of

the

for

applicable

yield-strength

values

where

7.4b

OF d/t

AXIAL

occurs

in

and

are given

F2

from

but covers

not sharp

is

Based

on

the

results

16.40

27.01

42.64

37.21 35.73

-70

13.85

23.38

33.17

C-75

13.60

22.91

32.05

13.38

22.47

31.02

C-90

13.01

21.69

29.18

C-95

12.85

21.33

28.36

12.70

21.00

P-105

12.57

20.70

26.89

P-h 10

12.44

20.41

26.22

-120

12.21

19.88

25.01

-125

12.11

19.63

24.46

-130

12.02

19.40

-135

11.92

19.18

23.44

-140

11.84

18.97

22.98

-150

11.67

18.57

22.11

-155

11.59

18.37

21.70

-160

11.52

18.19

21.32

-170

11.37

17.82

-180

11.23

17.47

without

showr

letter for

designation

information

the

with

Eq

collapse

elastic

of

range

are

collapse

are

not

purposes

API

grades

but

are

27.60

23.94

20.60 19.93

grades

in

use

or grades

being

7.4

collapse

many

Collapse

Collapse

24.42

are

of

elastic

significant

of

Elastic-I

TraflsitiOfl

Collapse

14.44

indicated

for

Table

VARIOUS COLLAPSE-PRESSURE STRESS IS ZERO4

-60

and

in

yield-strength

38.83

use

limit

applicable

7.5b

25.01

for

proper-

equation

by

25.63

Grades

The

by API

The lower

7.5

14.81

-100

agreement

approximate

collapse

15.24

N-80

applied

7.5a

J-K-55

L-80

this

-FF2 IF1

F1

PIastic-

Strength-

Collapse

-50

in the

variations

is

pipe

recommended

transition

values

FOR

WHEN

H-40

12

106

calculated

is

lapse

-Yield

geo

theory7

stability

formula

collapse

elastic

Table

in

The

Grade

of

3F2 IF1

F31Jyjelde

REGIONS

that

called

d/t

JFl228 F12 7.5RANGE

elastic

lower

at

occur

because

oil-

collapse

with

TABLE

of

for statistical

46.95

purposes

lower

can

Pcr dItd/t12

range

well

is

stress

becomes4

given

only

in

equal

are

shown

are

axial

the

7.4a

Eq

by

Application

following

manufactured

Collapse without

or grades

is

ayjelde

when

collapse

p2d/td5/t

of

ties

3451

use

predicted

After an adjustment

0.0920

indicated

Values

shown

2E

3.258

in

d/t

of

instability to

pcr

-130

grades

yield

are

zero

1.983

2.017

stress

strength

strength

yield

At high values

P-105

Grades

effective

minimum

the

1.989

2404 2553 2702 2852

-100

7.5

Table

Coefficients

Empirical

Grade

F1 F2 and F3 are given axial computed by Eq 7.4b for zero The

7.4

Table

in

where

considered

to elastic

range

experimental

col

of d5

It

tests

APPLIED

310

API has adopted tions

cover

to

for

ing

collapse-pressure

region

above

just

the

plastic

equa rat

collapse

yield-strength

collapse

significantly

axial

by

casing

the

design

f_F2

Pcryieide

F3

7.6a

on

stress

and

quist

and

the

bend

by

performance

before

was

1939

in

energy

for

relationship

or burst

collapse Nadia8

distortion

for

they are used

application

The generally accepted ial

values

table

must be corrected

often

properties

tension or compression

Thus

stresses

ing

in

with

predicted

is

additional

transition

values

It

region

two

the

ENGINEERING

DRILLING

casing

HoIm

by

classical

the

gives

ax

of

effect

of

Application

to

theory

the

presented

following

equation

The upper lated

of

limit

the

collapse

plastic

calcu

is

range

by

7.8

F4

Jyielde1i

7.6b

F3UyjeIdeF2_FS

where and

and

vertical

distortional

where F1

and

elastic

collapse

stress

the

defined

is

value and

plastic

collapse

use

by

of

of

or

dIt computed

7.3

20-in K-55

Solution

This

7.6b

for

zero

_..2

7.8 takes

the

of

the

form of

of

the

onset After

casing an

either

the

stress

yield

ellipse

Jz

7r7t

7r

7r2

Jz

Jyield

or

3Jt7r2

nominal

weight

wall of

foot

per

thickness

133

pipe has

ratio

It

of 0.635

lbf/ft

given

by

indicates

it is

that

can

rating

be

value

this

Thus

in the

falls

the

Eq

with

computed

d/t

for

collapse

collapse-

used

that

the

and

radial

were defined previously

by

imum

at

stress

of

tion

7.7

was chosen

plasticity

more commonly

radial

and

in

for

be

book

this

current

engi

drilling

practice

Recall

for transition

of

ellipse

cause

neering

7.5

7.9b

Jyield2

I\

dIt20/0.6353l.496

specified

JtJr\2

for

rating

The

pressure

failure

the

denotes

developed

is

physical

Eq

on

axial

7.5

with

casing

Eq

the collapse-pressure

Compute

nominal

Table

that

based

is

tangential

The application

circle

7.7

with

Table

in

in and

range

surface

the

not

yield

regrouping

_5

shown

Example

regions

7.4

Table

theorem

energy

radial

principal

respectively

7.9a

of

are

in

region between

collapse

PcrJyieide

Values

are given

F5

through

transition

the

are

stresses

will in

rr1 stress

at

occur

Eq this

7.3a

stresses

Eqs

and

7.3a

inner

the

gives

point

terms

rearranged

tangential

7.9a

max

wall Substitu

pipe

value

of

this

value

Use of

Eq

of

7.3b The

for

Eq

in

the

7.9a

yields

1.989

PcrSS000

0.036

l493

psi

JrPi2JzPi

\31.496

Jyield

Rounded This

psi

mum

to the

collapse-pressure external

expected

collapse sure or

10 psi

nearest

if the

rating

pressure

which

at

the

no

to

mini

internal

7.10

pres

Jyield

loads

axial

Casing Performance

The values collapse

for

with

ed by

API The

casing

properties

Such and

this

tables

Effect

zero

for

of

axial

ly many of

last

and

7.6

in

be

to

design

Combined

formulas

7.1

to

through

extremely

atPi

in

no

pipe

7.11

useful

This in

performance

is

Table

properties

7.6 apply only Unfortunate are

altered

in

the

7.11

external

nrnnf

nf

and this

the

pressure

mode

a0 Eq

is

left

the

is

of

ellipse

plasticity

Eq

7.3b

combinations

of

of

substitution

defines

yield strength

forp10

for

equation

Fig 7.13 With

Eq

bending

yield

the

applications

in

yield

7.3

Stress given

properties

casing

gives

Jl_JzPi2IJzm

Jyieid

sure and

equation

adopt

corresponds

Examples

are found

casing

and

resistance

were computed

empirical

in this table

entry

tension

the

burst

Table

in

theoretical

generally

The performance for

given

quadratic

Summary

strength

determined

convenient

7.3.5

tensional

resistance

accordance

Jyield

would

pipe

Solving 7.3.4

Jyieid

1490

to the

corresponds

were subjected

pipe

becomes

value

this

and

axial

stress

of failure 7.11 ctndent

It

reduces

can to

eYerie

with

shown

rr

internal that

will

be

shown

Eq

for

pres result that

7.4a The

CASING

311

DESIGN

--

The ID of

fOP\100%

FII

in

present

0yleId C0MPRESSi0F

casing

Eq

and

stress

the

7.11

for

internal

4.548

is

Evaluation of

in

nominal

terms

the

of zero

conditions

axial

gives

pressure

I0

_HH

-0-

fh flhi

_____1

atPi

2r0

/Ct yiei

yieId

mii

25.52 _1 L5.52_4.5482

20

LU

Pi_Pe

r0r1

40

.80000

-40

-GO

II flL

PrPe

80

12649

-I

Pe

12649 20

10

30

40

60

50

70

80

90

00

ayield

Use of

Ix

tt

0yieId

in

Eq

7.11

or

7.13

Fig

yields

Pe

111

100.-5c

P1

O_t

terms

these

12649

6C

12649

Pe

-IC

-80

Note value

90

TNSI0N

-lO

ble

Ioo%

7.13Ellipse

Fig

it

with

is

that

shows

that

rating

detrimental cial

has

axial

contrast

practice

is

it

to

customary detrimental

when

effect

in

Ta

40000

of

and

psi

lOOOO_Pe 12649

the

apply

and

rating In

be

zPi

4000010000

____________

has

0.625

80000

benefi

casing-design of

ellipse

would

on

burst-

on

compression

rating

effect

this

10 psi

shown

7.13

effect

detrimental

on burst-pressure

effect

Fig

plasticity

beneficial

on collapse-pressure

effect

only

In

rating

of

and

nearest

7.4 and

plasticity

of

ellipse

tension

axial

collapse-pressure pressure

the

Eq

psi

yieId of

the

to

by

given

conditions

in-service

OtPi Examination

rounded

7.6

pi10000

yietd

after

agrees

For

fOz4Pfl

that

Use of

terms

these

in

Eq

7.11

or

Fig

7.13

yields

plasticity

observed 10

000pr

0.5284

_________ 12649 Compute the nominal 5.5-in N-80 casing with

Example 7.4 for

ing

ness lbf/ft

In

service

pressure

in

which

tension

axial

the

determine

addition conditions

40000-psi

nominal

in and

of 0.476

Assume

nominal weight

wall foot

per

collapse pressure

the pipe and

stress

yield

collapse-pressure

strength

is

of

of

100000.528412649

Pe

to

internal

failure

This

and

7.11

For can

yield

be

strength

applied

mode

Use of

Eq

of failure 7.3b

with

Eqs

rr

pjr02

rj2_2pero2 r02

r2

the

present

sure minus

internal

was reduced

psi

given

pressure

pressure

of

because

that

difference

required

to

52.84% of the nominal

in

Table

the

combined pres

external

for

collapse

failure

collapse pressure

7.5

7.3b gives In

a1

indicates

analysis

stresses

rating

Solution

16684

26

for in-

subjected

10000-psi

mode

rat

thick

casing

not be

mode state

design

applied of

in

failure

which

is

the

the

practice

unless

the

known internal

to

of

ellipse

assumption be valid

of

can

yield-strength

For

pressure and

plasticity

simple

axial

stress

tension are

APPLIED DRILLING

312

TABLE 7.6MINIMUM

PERFORMANCE

PROPERTIES

OF CASING 10

Threaded

and

Nominal

Outside

Diameter

in

Outside

41/2

Threads

Diameter

and coupling

Ibmlft

Grade

Wall

Inside

Drift

Thickness

Diameter

Diameter

in

in

in

of Coupling

in

9.50

H-40

0.205

4.090

3.965

5.000

9.50

Diameter Special

Olearance Coupling

in

J-55

0.205

4.090

3.965

5.000

10.50

J-55

0.224

4.052

3.927

5.000

4.875

11.60

J-55

0.250

4.000

3.875

5.000

4.875

K-55

0.205

4.090

3.965

5.000

10.50

K-55

0.224

4.052

3.927

5.000

4.875

11.60

K-55

0.250

4.000

3.875

5.000

4.875

11.60

C-75

0.250

4.000

3.875

5.000

4.875

13.50

C-75

0.290

3.920

3.795

5.000

4.875

11.60

L-80

0.250

4.000

3.875

5.000

4.875

13.50

L-80

0.290

3.920

3.795

5.000

4.875

9.50

11.60

N-80

0.250

4.000

3.875

5.000

4.875

13.50

N-80

0.290

3.920

3.795

5.000

4.875

11.60

C-90

0.250

4.000

3.875

5.000

4.875

13.50

0-90

0.290

3.920

3.795

5.000

4.875

11.60

0-95

0.250

4.000

3.875

5.000

4.875

13.50

C-95

0.290

3.920

3.795

5.000

11.60

0.250

4.000

3.875

0.290

3.920

15.10

P-hO P-hO P-hO

0.337

11.50

J-55

13.00

J-55

15.00

13.50

Extreme

11

12

Line

Outside

Weight Size

coupled

ENGINEERING

Drift

Diameter

in

Outside

Pipe

Diameter

Body

of

Box

Powertight

in

Collapse Resistance

psi

Yield Strength

1000

2760

111

3310 4010 4960

152

3310 4010 4960 6100 8140 6350 8540

165 184 152 165 184 250 288 267 307

6350 8540

267

6820 9300

300

317

4.875

7030 9660

5.000

4.875

7580

367

3.795

5.000

4.875

10680

422

3.826

3.701

5.000

4875

14350

485

0.220

4.560

4.435

5.563

0.253

4.494

4.369

5.563

5.375

J-55

0.296

4.408

4.283

5.563

5.375

4.151

5.360

3060 4140 5560 3060 4140 5560

307

345

364

182 208 241

11.50

K-55

0.220

4.560

4.435

5.563

13.00

K-55

0.253

4.494

4.369

5.563

5.375

15.00

K-55

0.296

4.408

4.283

5.563

5.375

4.151

5.360

15.00

0-75

0.296

4.408

4.283

5.563

5.375

4.151

5.360

18.00

0-75

0.362

4.276

4.151

5.563

5.375

4.151

5.360

21.40

C-75

0.437

4.126

4.001

5.563

5.375

11970

470

23.20

0-75

0.478

4.044

3.919

5.563

5.375

12970

509

24.10

0-75

0.500

4.000

3.875

5.563

5.375

13500

530

15.00

L-80

0.296

4.408

4.283

5.563

5.375

4.151

5.360

18.00

L-80

0.362

4.276

4.151

5.563

5.375

4.151

5.360

21.40

L-80

0.437

4.126

4.001

5.563

5.375

12760

501

23.20

L-80

0.478

4.044

3.919

5.563

5.375

13830

543

24.10

L-80

0.500

4.000

3.875

5.563

5.375

14400

566

15.00

N-80

0.296

4.408

4.283

5.563

5.375

4.151

5.360

18.00

N-8O

0.362

4.276

4.151

5.563

5.375

4.151

5.360

6940 9960

7250 10500

7250

182 208 241

328 396

350 422

350

10500

422 501

21.40

N-80

0.437

4.126

4.001

5.563

5.375

12760

23.20

N-80

0.478

4.044

3.919

5.563

5.375

13830

543

24.10

N-80

0.500

4.000

3.875

5.563

5.375

14400

566

15.00

C-90

0.296

4.408

4.283

5.563

5.375

4.151

5.366

18.00

0-90

0.362

4.276

4.151

5.563

5.375

4.151

5.366

21.40

0-90

0.437

4.126

4.001

5.563

5.375

14360

564

23.20

c-go

0.478

4.044

3.919

5.563

5.375

15560

611

24.10

0-90

0.500

4.000

3.875

5.563

5.375

15.00

C-95

0.296

4.408

4.283

5.563

5.375

4.151

5.360

4.151

5.360

7840 11530

16200

8110

394 475

636 416

18.00

0-95

0.362

4.276

4.151

5.563

5.375

12030

501

21.40

0-95

0.437

4.126

4.001

5.563

5.375

15160

595

23.20

0-95

0.478

4.044

3.919

5.563

5.375

16430

645

24.10

0-95

0.500

4.000

3.875

5.563

5.375

17100

672

15.00

P-ho

0.296

4.408

4.283

5.563

5.375

4.151

5.360

18.00

P-itO

0.362

4.276

4.151

5.563

5.375

4.151

5.360

21.40

P-hO P-hO P-lW

0.437

4.126

4.001

5.563

0.478

4.044

3.919

5.563

0.500

4.000

3.875

5.563

23.20 24.10

8850

481

13470

580

5.375

17550

689

5.375

19020

747

5.375

19800

778

Ibf

CASING

13

DESIGN

14

313

15

16

17

18

19

20

21

22

23

Internal

Pressure

Resistance Buttress

End

Extreme Line

Round Thread Short

3190

3190

4380 4790 5350

4380 4790 5350

4380 4790 5350

4380 4790 5350

Long

Regular

Clearance Coupling

Higher

Same

Higher

Grade

Grade

Grade

Grade

5350

4790 5350

4790 5350

7780 9020

7780

7780

7780

9020

9020

7780 9020

7780 9020

7780 9020

7780 9020

8750

8750

8750 10150 9240 10710

10150

9240 10710

9240 10710

10690

10690

12410

12410

14420

14420

4240 4870 5700

4240 4870 5700

4240 4870 5700

4240 4870 5700

Line

Round

Short

Long

Special

Coupling

Regular

Higher

Clearance

Higher

Coupling

Gradet

Coupling

Gradet

Standard

Jnt

4790 5350

132

154

203

203

203

203

162

225

225

225

225

249

249

249

249

180

277

277

277

277

212

288

288

112

7780 9020

10150

Extreme

Clearance

ular

101

4790 5350

7290 8460

10690 12410 13460

4790 5350

4790 5350

4790 5350

146 170

7290 7490

257

331

320

212

291

291

7990

7780 9020

257

334

7780 7990

7780 9020

223

304

304

304

304

270

349

349

337

349

8750 9000

223

309

270

355

9240 9490

234

325

325

325

284

374

374

353

320

309 337

10690

10690

10690

279

385

385

385

385

12410

10990

12410

338

443

443

421

443

14.420

10.990

13910

406

509

509

421

509

133

4870 5700

4870 5700

4870 5700

4870 5130

4870 5700

169

182

252

252

252

252

207

223

293

293

287

293

186

201

309

309

309

309

228

246

359

359

359

359

328

147

4870 5700

4870 5700

7770 9500

12550

10140

13130

10140

7770 9290 9290 9290 9290

10140

8290 10140

8290 9910

12240

10810

13380

10820

14000

10810

9910 9910 9910

10140

8290

10140

10140

12240

10810

13380

10820

14000

10810

9320 11400 13770

11400

15060

12170

15750

12170

9840

Thread

77

7290 8460

8290

27

____________________

Special

Re

Coupling

Same

7290 8460

8290

Buttress

Coupling

4790 5350

11470

26

lbf

and Coupled

Thread

5350

7770 9500

Threaded

000

Special

Plain

or

PSI

25

24

Joint Strengthi

9320 12170

8290 9910 9910 9910 9910

4870 5700

4870 5130

4870 5700

295

375

376

452

364

466

510

364

513

510

364

538

510

364

295

379

364

416

376

457

364

446

466

510

364

513

510

364

538

510

311

396

396

383

396

437

10140

396

477

477

383

477

469

10250

490

537

566

383

479

10260

540

537

614

383

479

10250

567

537

639

383

479

311

404

383

430

396

487

383

469

490

537

383

540

537

383

567

537

383

326

424

402

459

416

512

402

493

515

563

402

567

563

402

595

563

6990 6990 6990 7000 6990 8290 10140

7460 7460

8290 10140

7460 7460 7460 8290 10140 12240 13380 13620

7460 7460 7460 7460 7460

9320 11150 11150 11150 11150

8400 8400 8400 8400 8400 8850 8850 8850 8850 8850

416

364

8290

416 446

364

15890

12850

9840 11770 11770 11770

16630

12850

11770

11400

11400

11400

11400

10250

11400

388

503

503

479

503

547

13940

13940

13620

13940

10250

13940

495

606

606

479

606

587

16820

14870

13620

16820

10250

13980

613

671

720

479

613

18400

14880

13630

18400

10260

13990

675

671

780

479

613

19250

14870

13620

18580

10250

13980

708

671

812

479

613

9.840

12040

12040

14530

12840

402

Optional Joint

314

APPLIED

TABLE

7.6MINIMUM

PERFORMANCE

PROPERTIES

OF CASING

DRILLING

cont 10

Threaded

and

Coupled

ENGINEERING

Extreme

ii

12

Line

Nominal Outside

Weight Threads

Size

Outside

Diameter

and

Outside

Wall

Diameter

Coupling

in

Ibm/fl

Grade

14.00

H-40

51/2

Thickness

Inside

Diameter

in 0.244

Drift

Diameter

in 5.012

of

Coupling

in 4.867

Diameter

Outside

Special

Clearance Coupling

in

Drift

Diameter

in

of

Box

Powertight

in

in

6.050

14.00

J-55

0.244

5.012

4.887

6.050

15.50

J-55

0.275

4.950

4.825

6.050

5.875

17.00

J-55

4.82

4.653

0.304

5.860

4.767

6.050

5.875

4.653

5.860

4.687

6050

14.00

K-55

0.244

5.012

15.50

K-55

0.275

4.950

4.825

17.00

6.050

5.875

K-55

4.653

5.860

0.304

4.892

4.767

6.050

5.875

4.653

5.860

4.892

4.767

6.050

5.875

4.653

5.860

17.00

C-75

0.304

20.00

C-75

0.361

4.778

4.653

23.00

C-75

6.050

5.875

4.653

5.860

0.415

4.670

4.5ts

6.050

5.875

4.545

5.860

4.767

6.050

5.875

4.653

5.860

17.00

L-80

0.304

4.892

Pipe

Diameter

20.00

L-80

0.361

4.778

4.653

23.00

6.050

5.875

L-80

4.653

5.860

0.415

4.670

4.545

6.050

5.875

4.545

5.860

Body Collapse Resistance

psi

Yield Strength

1000

2620

161

3120 4040 4910

222

3120

222

4040 4910

248

6040 8410

372

10470

6280 8830 11160

248 273

273

437 497 397 466 530

17.00

N-80

0.304

4.892

4.767

6.050

20.00

N-80

5.875

4.653

5.860

0.361

4.778

4.653

N-80

6.050

23.00

5.875

4.653

0.415

5.860

4.670

4.545

6.050

5.875

4545

5.860

11160

530

6280 8830

397 466

17.00

C-90

0.304

4.892

4.767

C-90

6.050

20.00

5.875

4.653

5.860

6.740

0.361

447

4.778

4.653

6.050

5.875

4.653

4.670

5.860

9630

525

4.545

6.050

5.875

4.545

5.860

23.00

C-gO

0.415

26.00

C-go

0.476

4.548

4.423

c-go

6.050

5.875

35.00

0.650

4.200

4.075

6.050

5.875

12380

676

18760

891

17.00

C-95

0.304

4.892

4.767

20.00

C-95

6.050

5.875

4.653

0.361

5.860

4.778

4.653

6.050

5.875

4.653

0.415

5.860

4.670

10010

4.545

6.050

5.875

4.545

5.860

12940

4.767

6.050

5.875

4.653

5.860

23.00 17.00 20.00 23.00

C-95

P-hO P-hO P-hO

630

4.778

4.653

6.050

5.875

4.653

5.860

0.415

4.670

11100

641

4.545

6.050

5.875

4.545

5.660

14540

729

5.730

7.000

J-55

0.288

6.049

5.924

7.390

7.000

0.352

5.921

5.796

7.390

7.000

6.049

5.924

7.390

7.000

5.921

5.796

7.390

7.000

20.00

K-55

0.288

24.00

K-55

0.352

24.00

C-75

0.352

5.921

5.796

7.390

7.000

28.00

C-75

5.730

0.417

7.000

5.791

5.666

7.390

7.000

5.666

7.000

5.675

5.550

7.390

7.000

5.550

7.000

7.390

7.000

5.730

7.000

7.390

7.000

5.666

7.000

7.390

7.000

5.550

7.000

L-80

554

4.892

J-55

24.00

471

0.361

24.00

C-75

6940

0.304

20.00

32.00

597

14240

0.475 0.352

5.921

5.796

5.730

7.000

28.00

L-80

0.417

5.791

32.00

L-80

0.475

5.675

24.00

N-80

0.352

5.921

5.796

7.390

28.00

N-80

7.000

5.730

0.417

7.000

5.791

5.666

7.390

N-80

7.000

32.00

5.666

7.000

5.675

5.550

7.390

7.000

5.550

7.000

24.00

C-gO

7.000

5.730

7.000

0.475 0.352

5.921

5.666 5.550

5.796

7.390

28.00

C-gO

0.417

5.791

5.666

7.390

32.00

C-gO

7.000

5.666

7.000

0.475

5.675

5.550

7.390

7.000

5.550

7.000

7.000

5.730

7.000

24.00

C-95

0.352

5.921

28.00

C-95

0.417

5.791

5.666

7.390

7.000

32.00

C-95

5.666

7.000

0.475

5.675

5.550

7.390

7.000

5.550

7.000

5.796

7.390

7480

2970 4560 2970 4560

546

315 382 315 382

5550 7790 9800

520

5760 8170

555

10320

5760 8170 10320

6140 8880 11.330

6310 9220 11610

610 688

651

734 555 651

734 624 732 826 659 773 872

24.00

P-lb

0.352

5.921

5.796

7.390

28.00

P-hO

7.000

5.730

0.417

7.000

5.791

5.666

7.390

P-itO

7.000

5.666

7.000

0.475

5.675

5.550

10160

895

7.390

7.000

5.550

7.000

13220

1009

32.00

6730

763

Ibf

CASING DESIGN

13

14

315

15

16

17

18

Resistance

psi

19

20

21

22

23

Joint Strengthi Internal

Pressure

Buttress

Regular

End

Extreme Line

Thread

and

000

Round Thread Short

3110

3110

4270 4810 5320

4270

lbf

Coupled

Buttress

4270 4810 5320

4270 4810

4810 5320

Long

Coupling

Thread

Coupling

Higher

Same

Higher

_Ii_

Grade

Grade

Grade

Grade

Short

4810 5320

4810 5320

4810 5320

4810 5320

4730 4730

4810 5320

7250 8610 9900

7250 8610 9260

7250 8430 8430

7740 9190

7740

7740

7740

6880

7740

9190 9880

8990 8990

9190

6880 6880

7740 9190 9880

7740 8990 8990

6880 6880 6880

10560

8710

Clearance Coupling

Higher

Standard

Gradet

Joint

8710

10120

11880

11110

10120

13630

11110

10120

18610

11110

10120

9910

10560

7740 9190 10560

9190

10910

10910

10680

12540

11730

10680

10640

10640

10640

10640

12640

12640

12360

12640

14520

13160

12360

14520

217

300

300

300

300

339

339

229

247

329

329

318

329

372

372

222

239

366

366

366

366

429

429

252

272

402

402

402

402

471

471

327

423

403

497

473 338

9190 9460 7740 9190 9460

403

471

471

403

497

479

550

403

549

479

428

403

471

471

416

503

403

497

479

489

550

549

479

348

446

446

424

446

496

496

428

524

524

424

524

523

504

502

579

596

424

530

577

504

7740 7740 7740 7740 7740

356

456

424

496

496

438

536

424

523

504

514

580

424

577

504

598

580

424

614

580

424

8170 8170 8170

374

480

445

521

521

460

563

445

549

530

606

530

403

540

608

9460 9460 9460

10640

445

568

568

445 530

568

620

620

11880

548

667

667

530

667

654

630

11880

643

724

759

530

668

772

630

477

477

605

605

3040

3040

4180 5110

4180 5110

4180 5110

4180 5110

4180 5110

4060 4060

4180 5110

245

266

374

374

374

374

314

340

453

453

390

453

4180

4180 5110

4180 5110

4180 5110

4180

4060 4060

4180 5110

267

290

453

453

453

453

342

372

548

548

494

520

6970 8260 9410

6970 8260 9410

6970 8260 9200

5540 5540

453 552

5540

7440 8810

7440 8810

7440 8810 9820

5910 5910 5910

7440 8810 10040 8370

9910 11290

8830

Joint

202

6450 6450 6450

8710

10340

10040

Optional

189

10340

9190

Higher

Gradet

Coupling

172

4730 4730

7740 9190

Regular

Couphng

Line Special

130

4810 5320

10560

Long

Coupling

Extreme

Clearance

Regular

Round

Same

4810 5320

5320

Special

Clearance

4810 5320

5110

27

26

Special

Plain

or

Threaded

25

24

184

10040

7440 8810 10040

8370 9910 11290

8830

7440 8810 9820

5110

7440 8810 10040

8370 9910 11050

8830

10460

10460

10460

11920

11830

11660

10230

10230

10230

10230

12120

11830

12120

12120

13800

11830

13500

13800

583

494

605

605

683

494

648

644

638

771

494

717

644

473

592

494

605

605

576

693

494

648

644

666

783

494

717

644

520

615

637

637

481

615

615

586

721

721

520

650

682

678

677

814

814

520

650

755

678

6550 6650 6650

520

633

520

637

637

633

742

520

682

678

732

837

520

755

678

7020 7020 7020

546

665

546

668

668

665

780

546

716

712

769

880

546

793

712

641

786

786

65

786

796

796

781

922

922

650

832

852

848

650

832

944

848

5910 5910 5910

8120 8120 8120

7440 8120 8120

8310 8310 8310

904

1040

1040

APPLIED

316

TABLE

7.6MINIMUM

PERFORMANCE PROPERTIES

Threaded

and

Outside

Diameter

in

Outside

Threads

Diameter

and Coupling

Line

Wall

Inside

Drift

Thickness

Diameter

Diameter

in

in

in

of

Coupling

Diameter Special

Clearance Coupling

Drift

Diameter

Outside

Pipe

Diameter

Body

of

Box

Powertight

lbm/ft

Grade

17.00

H-40

0.231

6.538

6.413

7.656

20.00

H-40

0.272

6.456

6.331

20.00

J-55

0.272

6.456

6.331

23.00

J-55

0.317

6.366

6.241

7.656

7.375

6.151

7.390

J-55

0.362

6.276

6.151

7.656

7.375

6.151

7.390

26.00

in

in

in

in

1970

230

7656

2270 3270 4320

316

2270 3270 4320

316

3750 5220 6730 8200 9670

499

6.456

6.331

7.656

23.00

K-55

0.317

6.366

6.241

7.656

7.375

6.151

7.390

26.00

K-55

0.362

6.276

6.151

7.656

7.375

6.151

7.390

23.00

C-75

0.317

6.366

6.241

7.656

7.375

6.151

7.390

C-75

0.362

6.276

6.151

7.656

7.375

6.151

7.390

C-75

0.408

6.184

6.059

7.656

7.375

6.059

7.390

32.00

C-75

0.453

6.094

5.969

7.656

7.375

5.969

7.390

35.00

C-75

0.498

6.004

5.879

7.656

7.375

5.879

7.530

38.00

C-75

0.540

5.920

5.795

7.656

7.375

5.795

7.530

L-80

0.317

6.366

6.241

7.656

7.375

6.151

7.390

L-80

0.362

6.276

6.151

7.656

7.375

6.151

7.390

0.408

6.184

6.059

7.656

7.375

6.059

7.390

26.00 29.00

L-80

1000

7.656

0.272

23.00

psi

Yield Strength

196

K-55

29.00

Collapse Resistance

1420

20.00

26.00

10680

3830 5410 7020 8610

366 415

366 415

566 634 699 763 822 532 604 676

32.00

L-80

0.453

6.094

5.969

7.656

7.375

5.969

7.390

35.00

L-80

0.498

6.004

5.879

7.656

7.375

5.879

7.530

10180

814

38.00

L-80

0.540

5.920

5.795

7.656

7.375

5.795

7.530

11390

877

N-80

0.317

6.366

6.241

7.656

7.375

6.151

7.390

N-80

0.362

6.276

6.151

7.656

7.375

6.151

7.390

29.00

N-80

0.408

6.184

6.059

7.656

7.375

6.059

7.390

32.00

N-SO

0.453

6.094

5.969

7.656

7.375

5.969

7.390

N-SO

0.498

6.004

5.879

7.656

7.375

5.879

7.530

10180

814

38.00

N-SO

0.540

5.920

5.795

7.656

7.375

5.795

7.530

11390

877

23.00

C-90

0.317

6.366

6.241

7.656

7.375

6.151

7.390

C-90

0.362

6.276

6.151

7.656

7.375

6.151

C-gO

0.408

6.184

6.059

7.656

7.375

0.453

6.094

5.969

7.656

0.498

6.004

5.879

7.656

23.00 26.00

35.00

26.00 29.00 32.00 35.00

C-go C-gO

3830 5410 7020 8610

745

532 604 676 745

599

7.390

4030 5740

6.059

7.390

7.580

760

7.375

5.969

7.390

9380

7.375

5.879

7.530

11170

915

12820

986

679

839

38.00

C-gO

0.540

5.920

5.795

7.656

7.375

5.795

7.530

23.00

C-95

0.317

6.366

6.241

7.656

7.375

6.151

7.390

C-95

0.362

6.276

6.151

7.656

7.375

6.151

7.390

C-95

0.408

6.184

6.059

7.656

7.375

6.059

7.390

C-95

0.453

6.094

5.969

7.656

7.375

5.969

7.390

C-95

0.498

6.004

5.879

7.656

7.375

5.879

7.530

C-95

11650

0.540

5.920

5.795

7.656

7.375

5.795

7.530

13440

0.362

6.276

6.151

7.656

7.375

6.151

7.390

6230

0.408

6.184

6.059

7.656

7.375

6.059

7.390

8530

0.453

6.094

5.969

7.656

7.375

5.969

7.390

10780

1025

26.00 29.00 32.00 35.00 38.00 26.00 29.00 32.00 35.00 38.00

7%

Extreme

Coupled

12

11

Outside

Weight Size

ENGINEERING

OF CASING cont 10

Nominal

DRILLING

P-hO P-hO P-hO P-hO P-hO

4140 5880 7830 9750

632 717 803 885 966 1041 830 929

0.498

6.004

5.879

7.656

7.375

5.879

7.530

13020

1119

0.540

5.920

5.795

7.656

7.375

5.795

7.530

15140

1205

2030

276

6.750

8.010

2890

414

24.00

H-40

0.300

7.025

6.900

8.500

26.40

J-55

0.328

6.969

6.844

8.500

8.125

26.40

K-55

0.328

6.969

6.844

8.500

8.125

6.750

8.010

2890

414

26.40

C-75

0.328

6.969

6.844

8.500

8.125

6.750

8.010

564

29.70

C-75

0.375

6.875

6.750

8.500

8.125

6.750

8.010

33.70

C-75

0.430

6.765

6.640

8.500

8.125

6.640

8.010

39.00

C-75

0500

6.625

6.500

8.500

8.125

6.500

8.010

3280 4650 6300 8400

C-75

0.562

6.501

6.376

8.500

8.125

10240

45.30

C-75

0.595

6.435

6.310

8.500

8.125

10790

47.10

C-75

0.625

6.375

6.250

8.500

8.125

11290

42.80

641

729 839 935 986 1031

Ibf

CASING

13

DESIGN

14

317

15

16

17

18

19

20

21

22

Joint Internal

Pressure

Resistance Buttress

Regular

End

Extreme

Round Thread

Line

Short

2310 2720

2310 2720

3740 4360 4980

3740 4360 4980

3740 4360

Thread

and

Strength1000

Buttress

Long

Same

Higher

Same

Higher

Grade

Grade

Grade

Grade

Round

Coupling

Special

Regular

Higher

Clearance

Coupling

Gradet

Coupling

Thread Short

Long

Extreme

Clearance Coupling Higher

Gradet

Standard Joint

Optional Joint

122 176 234

4360 4980

4360 4980

4360 4980

284

313

432

432

421

432

499

334

367

490

490

421

490

506

309

341

522

522

522

522

632

632

364

401

592

592

533

561

641

641

5380 5380 5380 5380 5380

416

557

533

632

632

489

631

533

641

641

562

707

533

685

674

633

779

533

761

674

703

833

533

850

761

5380

767

833

533

917

761

3950 3950

4360 4980

506

254

3740 4360 4980

4360 4980

5940 6790 7650 8490 8660 8660

5940 6790 7650 7930 7930 7930

6340

6340

6340

6340

5740

6340

435

565

533

632

632

7240 8160 9060 9960

7240 8160 9060 9240 9240

7240 8160 8460 8460 8460

7240 8160 9060 9960

5740 5740 5740 5740 5740

7240 7890

511

641

533

641

641

587

718

533

685

674

7890 7890 7890

661

791

533

761

674

734

833

533

850

761

801

833

533

917

761

6340 7240 8160 9060 9240 9240

6340 7240 8160 8460 8460 8460

5740 5740 5740 5740 5740 5740

6340 7240 7890 7890 7890 7890

442

588

588

561

588

666

666

519

667

667

561

667

675

675

597

746

746

561

702

721

709

672

823

823

561

702

801

709

746

876

898

561

702

895

801

814

876

968

561

702

965

801

447

605

561

666

666

563

687

561

675

675

648

768

561

721

709

729

847

561

801

709

809

876

561

895

801

883

876

561

965

801

699

699 709

4980

4360 4980

Special

Clearance Coupling

__________

Thread

Regular Coupling

lbf

Coupled

Special

Plain

or

Threaded

psi

27

24

23

5940 6790 7650 8490 9340 10120

10800

6340 7240 8160 9060 9960 10800

7130 8150 9180

7130 8150 9180 9520 9520 9520

10190 11210 12150

7530 8600 9690 10760 11830 12820

9960 12460 13700 14850

2750 4140 4140 5650 6450 7400 8610 9670 10240 10760

10800

6340 7240 8160 9060 9960 10800

7130 8150 9180 9520 9520 9520

3950 3950

4360 4980

6450 6450 6450 6450 6450 6450

7530 8600

7530 8600

6810 6810

505

636

589

593

722

589

709

9520 9520 9520 9520

9690

6810 6810 6810 6810

683

808

589

757

744

768

891

589

841

744

853

920

589

940

841

931

920

589

9520 9520 9520 9520 9520

11220

4360 4980

10050 10050 10050

9960

9960

11220

11220

11640

11790

11640

11790

11640

11790

4140

841

844

7480

7480

693

853

853

702

853

844

7480 7480 7480 7480

7480 7480 7480 7480

797

955

955

702

898

902

886

897

1053

702

898

886 1002 1002

996 1087

1096

1150

702

898

1002 1118

1096

1239

702

898

1207

1053

212

2750 4140

1013

4140

4140

4140

4140

315

346

483

483

483

483

553

553

4140

4140

4140

4140

4140

342

377

581

581

581

581

700

700

5650 6450 7400 8610 9670 9840 9840

5650 6450 7400 8610 9190 9180 9190

461

624

624

700

700

542

709

709

700

700

635

806

735

766

744

751

929

735

851

744

1035 1090 1140

735

4140

5650 6140 6140 6140 6140 6140 6140

852 905 953

764 735

316

APPLIED

TABLE 7.6MINIMUM

PERFORMANCE

PROPERTIES

OF CASING

DRILLING

cont 10

Threaded

and

Nominal

Size

Coupling

in

lbmlft

7/

26.40

12

Line

Wall

Thickness Grade

L80

in 0.328

Inside

Drift

Diameter

Diameter

in

in

of

Coupling

Diameter

Outside

Pipe

Special

Diameter

8ody

Clearance Coupling

in

in

Drift

Diameter

in

6.969

6.844

8.500

8.125

6.750

of

Rox

Powertight

in 8.010

Collapse Resistance

psi

Yield Strength

1000

3400 4790

602

6560 8820

778

29.70

L-80

0.375

6.875

6.750

8.500

8.125

6.750

8.010

33.70

L-80

0.430

6.765

6.640

8.500

8.125

6.640

8010

6.625

6.500

8.500

8.125

6.500

8.010

8.500

8.125

10810

683

39.00

L-80

0.500

42.80

L-80

0.562

6.501

6.376

45.30

L-80

0.595

6.435

6.310

8.500

8.125

47.10

11510

L-80

1051

0.625

6.375

6.250

8.500

8.125

12040

1100

0.328

6.969

6.844

8.500

8.125

6.750

8.010

26.40

8%

Outside

Diameter

and

Diameter

Extreme

11

Outside

Weight Threads

Outside

Coupled

ENGINEERING

N-80

29.70

N-80

0.375

6.875

6.750

8.500

8.125

6.750

8.010

33.70

N-80

0.430

6.765

6.640

8.500

8.125

6.640

8.010

39.00

N-80

0.500

6.625

6.500

8.500

8.125

6.500

8.010

895 998

3400 4790 6560 8820

602 683 778 895

42.80

N-8O

0.562

6.501

6.376

8.500

8.125

45.30

N-80

10810

0.595

6.435

6.310

8.500

8.125

47.10

N-80

11510

1051

0.625

6.375

6.250

8.500

8.125

12040

1100

998

26.40

C-90

0.328

6.969

6.844

8.500

8.125

6.750

C-90

8.010

0.375

3610

677

29.70

6.875

6.750

8.500

8.125

6.750

8.010

5.040

769

7050 9620

33.70

C-90

0.430

6.765

6.640

8.500

8.125

6.640

C-90

8.010

39.00

0.500

6.625

6.500

8.500

8.125

6.500

8.010

42.80

C-90

0.562

6.501

6.376

8.500

8.125

45.30

C-90

11890

1122

0.595

6.435

6.310

8.500

8.125

12950

1183

13540

1237

47.10

C-gO

0.625

6.375

6.250

8.500

8.125

26.40

C-95

0.328

6.969

6.844

8.500

8.125

6.750

8.010

29.70

C-95

0.375

6.875

6.750

8.500

8.125

6750

8.010

33.70

C-95

0.430

6.765

6.640

8.500

8.125

6.640

8.010

39.00

C-95

0.500

6.625

6.500

8.500

8.125

6.500

8.010

42.80

C-95

0.562

6.501

6.376

8.500

8.125

45.30

C-95

0.595

6.435

6.310

8.500

8.125

47.10

C-95

0.625

6.375

6.250

8.500

8.125

29.70

P-lb

0.375

6.875

6.750

8.500

8.125

6.750

8.010

0.430

6.765

6.640

8.500

8.125

6.640

8.010

6.500

8.010

3710 5140 7280 10000

875 1007

714 811

923 1063

12410

1185

13660

1248

14300

1306

5350 7870

940

33.70

P-liD

39.00

P-hO

0.500

6.625

6.500

8.500

8.125

42.80

P-hO

11080

1231

0.562

6.501

6.376

8.500

8.125

45.30

13920

1372

P-lb

0.595

6.435

6.310

8.500

8.125

47.10

P-hO

15430

1446

0.625

6.375

6.250

8.500

8.125

16550

1512

28.00

H-40

0.304

8.017

7.892

9.625

32.00

H-40

0.352

7.921

7.796

9.625

24.00

J-55

0.264

8.097

7.972

9.625

32.00

J-55

0.352

7.921

7.796

9.625

9.125

7.700

9.120

36.00

J-55

0.400

7.825

7.700

9.625

9.125

7.700

9.120

0.264

8.097

7.972

9.625

24.00

K-55

1610

318

2200

366

1370

381

2530 3450

503

1370

381

2530 3450

503

775

32.00

K-55

0.352

7.921

7.796

9.625

9.125

7.700

9.120

36.00

K-55

0.400

7.825

7.700

9.625

9.125

7.700

9.120

0.400

7.825

7.700

9.625

9.125

7.700

9.120

0.450

7.725

7.600

9.625

9.125

7.600

9.120

0.500

7.625

7.500

9.625

9.125

7.500

9.120

4000 5330 6660

36.00

C-75

40.00

C-75

44.00

C-75

1069

49.00

C-75

0.557

7.511

7.386

9.625

9.125

7.386

9.120

8180

36.00

L-80

0.400

7.825

7.700

9.625

9.125

7.700

9.120

568

568

867 957 1059

40.00

L-80

0.450

7.725

7.600

9.625

9.125

L80

7.600

9.120

44.00

4100 5520

0.500

7.625

7.500

9.625

9.125

7.500

9.120

6.950

49.00

1021

L-80

0.557

7.511

7.386

9.625

9.125

7.386

9.120

8580

1129

36.00

N-80

0.400

7.825

7.700

9.625

9.125

7.700

9.120

0.450

7.725

7.600

9.625

9.125

7.600

9.120

4100 5520 6950 8580

40.00

N-80

44.00

N-80

0.500

7.625

7.500

9.625

9.125

7.500

9.120

49.00

N-80

0.557

7.511

7.386

9.625

9.125

7.386

9.120

0.400

7.825

7.700

9.625

9.125

7.700

9.120

36.00

C-90

40.00

C-90

0.450

7.725

7.600

9.625

9.125

7.600

C-90

9.120

44.00

0.500

7.625

7.500

9.625

9.125

7.500

49.00

C-90

9.120

4250 5870 7490

0.557

7.511

7.386

9.625

9.125

7.386

9120

9340

827 925

827 925 1021 1129 930 1040

1271

1149

lbf

CASING DESIGN

13

319

14

15

16

17

18

19

20

21

22

24

23

Joint Strength1 Internal

Pressure

Resistance Buttress

Regular

End

Extreme Line

Thread

and

000

26

27

Ibf

Coupled

Buttress

Thread

Special

Plain

or

Threaded

psi

25

Round Thread Short

6020 6890 7900 9180

Long

6020 6890 7900 9180

10320

10320

10920

10500

11480

10490

6020 6890 7900 9180

6020 6890 7900 9180

10320

10320

10920

10500

11480

10490

Coupling

Coupling

Same

Higher

Same

Higher

Grade

Grade

Grade

Grade

6020 6550 6550 6550

6020 6890 7900 9000

6020 6890 7900 9180 9790 9790 9790 6020 6890 7900 9180 9790 9790 9790

6020 6890 7900 9180

Special

Clearance

6550 6550 6550 6020 6890 7900 9180 10320 10920 11480

6020 6550 6550 6550 6550 6550 6550

Coupling

Thread Short

Long

Higher

Coupling

Gradet

Special

Clearance Coupling

Coupling Higher

Standard

Gradet

Joint

Optional Joint

700

482

635

635

700

566

721

721

700

700

664

820

735

766

744

851

744

786

945

735

892

735

997

1053 1109 1160

490

659

659

659

659

737

737

575

749

749

749

749

737

737

674

852

852

773

852

806

784

798

981

981

773

967

896

784

1093

773

967

962

1093 1152

1152

804

1013

1205

1204

773

532

681

681

737

737

625

773

773

737

737

733

880

804

806

784

867

804

896

784

804

947

6020 6890 7900 9000 9000 8030 9000

Regular

Extreme

Clearance

Regular

Round

905

764 735

1005 967

11020

6780 7370 7370 7370 7370 7370

1045

1013 1129 1189

11020

7370

1100

1239

7150 8180 9380 10900

7150 7780 7780 7780

560

716

716

774

774

659

813

812

774

774

772

925

812

846

823

914

812

941

823

11620 11630

7780 7780

1037

1065 1187

812

12970

7150 8180 9380 10900 11800 11800

1101

1251

854

13630

11800

11620

7780

1159

1300

769

960

922

922

6780 7750 8880 10330

6780 7750 8880 10330

10330

11610

11610

11020

12290

11800

12910

11800

7150 8180 9.380

10900 12250

9470 10860

9470 10860

12620

11800

14190

15020

11800 11800

15780

11800

6780 7750 8880

9470 10860 12620 12680 12680 12680

9470 10860 12620 12680 12680 12680

8030 8030 8030 8030 8030 8030

984

8030 8030 8030 8030 8030 8030

1008

979

1066 1210 1285 1353

1258 1402

1258

967

1237

1120

979

1402

967

1237

1477

1477

1005

1287

1545

1545

967

1237

372

417

579

579

579

579

686

686

434

486

654

654

654

654

688

688

402

452

690

690

690

690

869

869

468

526

780

780

780

780

871

871

871

871

942

279

2950 3930 4460

2950 3930 4460

6490 7300 8120 9040 7300 8220 9130 10170

960 1093

233

6490 7300 8120 9040

960 967

2860

6090 6850 7610 8480

812 960 1093

2860

2950 3930 4460

804

1093

901

24702470

2950 3930 4460

804

244

3930 4460

3930 4460

3930 4460

3930 4060

3930 4460

263

3930 4460 6090 6850 7610 8480 6490 7300 8120 9040 6490 7300 8120 9040 7300 8220 9130 10170

3930 4460

3930 4460

3930 4060

3930 4460

6090

5530

648

847

839

6850 7610 8480

5530 5530 5530

742

947

839

834

1046

839

1007

939

1157

839

1007

5900 5900 5900 5900

678

839

871

871

942

886

6490 7300 8120 9040 6490 7300 8120 9040 7300 8220 9130 10170

6490 7300 8120 9040 6490 7300 8120 9040

5900 5900 5900 5900 6340 6340 6340 6340

6490 7300 8110 8110 6340 6340 6340 6340

864

776

966

874

1066 1180

983 688 788 887 997

895

839

895

839

1007

839

1007

883

895

886 886 886

886 886

917

917

992

932

1001

1001

883

1001

1105

1105

883

1103

1060

932

1222

1222

883

1103

1060

932

749 858

1038

965

1146

1085

1268

883

917

883

992

917 992

883

1060

932

883

1060

932

APPLIED

320

TABLE

7.6MINIMUM

PERFORMANCE

PROPERTIES

Threaded

and

Size Outside

Diameter

in 8%

9%

Coupling

Extreme Line _______________

Grade C-95

Wall

Inside

Thickness

Diameter

in 0.400

in

Drift

Diameter

in

of

Coupling

in

Diameter

Outside

Clearance Coupling

in

Pipe

Diameter

Special Drift

Diameter

in

7.825

7.700

9.625

9.125

7.700

Box

of

Powertight

in 9.120

40.00

C-95

0.450

7.725

7.600

9.625

9.125

7.600

9.120

44.00

C-95

0.500

7.625

7.500

9.625

9.125

7.500

9.120

49.00

C-95

0.557

7.511

7.386

9.625

9.125

7.386

9.120

40.00

0.450

7.725

7.600

9.625

9.120

0.500

7.625

7.500

9.625

9125 9125

7.600

44.00

P-hO P-hO

7.500

9.120

49.00

P-lb

0.557

7.511

7.386

9.625

9.125

7.386

9.120

Body Collapse Resistance

psi

4350 6020 7740 9710 6390 8420 10740

Yield Strength

1000 982 1098 1212 1341 1271 1404 1553

32.30

H-40

0.312

9.001

8.845

10.625

36.00

H-40

1370

0.352

8.921

8.765

10.625

1720

410

8.921

8.765

10.625

10.125

564

10.100

2020 2570

564

859

36.00

J-55

0.352

40.00

J-55

0.395

8.835

8.679

10.625

10.125

36.00

K-55

0.352

8.921

8.765

10.625

10.125

8.599

365

630

40.00

K-55

0.395

8.835

8.679

10.625

10.125

8.599

10.100

2020 2570

40.00

C-75

0.395

8.835

8.679

10.625

10.125

8.599

10.100

2990

8.755

8.599

10.625

10.125

8.599

10.100

8.681

8.525

10.625

10.125

8.525

10.100

3730 4610

1018 1166

43.50

C-75

0.435

47.00

C-75

0.472

53.50

C-75

0.545

8.535

8.379

10.625

10.125

8.379

10.100

6350

40.00

L-80

0.395

8.835

8.679

10.625

10.125

8.599

10.100

8.755

8.599

10.625

10.125

8.599

10.100

3090 3810 4760 6620

43.50

L-80

0.435

47.00

L-80

0.472

8.681

8.525

10.625

10.125

8.525

10.100

53.50

L-80

0.545

8.535

8.379

10.625

10.125

8.379

10.100

0.395

8.835

8.679

10.625

10.125

8.599

10.100

40.00

N-80

43.50

N-SO

0.435

8.755

8.599

10.625

10.125

8.599

10.100

47.00

N-80

0.472

8.681

8.525

10.625

10.125

8.525

10.100

53.50

N-80

0.545

8.535

8.379

10.625

10.125

8.379

10.100

40.00

C-go

0.395

8.835

8.679

10.625

10.125

8.599

10.100

43.50

C-90

0.435

8.755

8.599

10.625

10.125

8.599

10.100

47.00 53.50 40.00

C-90

0.472

8.681

8.525

10.625

10.125

8.525

10.100

C-90

0.545

8.535

8.379

10.625

10.125

8.379

10.100

0.395

8.835

8.679

10.625

10.125

8.599

10.100

C-95

43.50

C-95

0.435

8.755

8.599

10.625

10.125

C-95

8.599

10.100

47.00

0.472

8.681

8.525

10.625

10.125

8.525

C-95

10.100

53.50

0.545

8.535

8.379

10.625

10.125

8.379

10.100

43.50

P-hO

0.435

8.755

8.599

10.625

10.125

8.599

10.100

47.00

P-lb

0.472

8.681

8.525

10.625

10.125

8.525

10.100

0.545

8.535

8.379

10.625

10.125

8379

10.100

53.50

10

Outside

Diameter

and

36.00

Coupled

12

11

Outside

Weight Threads

lbnlft

ENGINEERING

OF CASING cont 10

Nominal

DRILLING

P-lb

32.75

H-40

0.279

10.192

40.50

H-40

0.350

10.050

40.50

J-55

0.350

10.050

10.036

11.750 11.750

9.894

11.750

11.250

11.750

11.250

9.794

11.460

9.694

11.460

J-55

0.400

9.950

9.794

J-55

0.450

9.850

9.694

11.750

11.250

40.50

K-55

0.350

9.894

11.750

11.250

45.50

K-55

0.400

9.950

9.794

11.750

11.250

9.794

11.460

51.00

K-55

0.450

9.850

9.694

11.750

11.250

9.694

11.460

51.00

C-75

0.450

9.850

9.694

11.750

11.250

9.694

11.460

55.50

C-75

0.495

9.760

9.604

11.750

11.250

9.604

11.460

51.00

L-80

0.450

9.850

9.694

11.750

11.250

9.694

11.460

9.760

9.604

11.750

11.250

9.604

11.460

55.50

L-80

0.495

51.00

N-80

0.450

9.850

9.694

11.750

11.250

9.694

53.50

N-80

11.460

0.495

9.760

9.604

11.750

11.250

9.604

11.460

916 1005 1086 1244 916 1005 1086 1244 1031

3320 4120 5090 7340

1088

4420 5300 7950

1390

51.00

942

3250 4010 5000 7120

840

9.894

45.50

10.050

3090 3810 4760 6620

630

1.130

1221 1399

1193 1289 1477 1381 1493 1710 367 457

1580

629

2090 2700

715 801

1580

629

2090 2700

715

3110 3920 3220 4020 3220 4020

801

1092 1196 1165 1276 1165 1276

lbf

CASING

13

DESIGN

321

14

15

16

17

18

19

20

21

22

_______ Internal

Resistance

Pressure

Buttress

Regular

End Round or

Line

__________

Threaded

Thread

and

25

24 Strengthi

000

Thread ____________ Short

7710 8670 9640

Coupled

Buttress

Thread

Long

7710 8670 9640

Special

Clearance Regular

Coupling

_____________

Coupling

_____________

Same

Higher

Same

Grade

Grade

Grade

7710 8670 9640

10380

10740

10040

10040

10040

10040

11160

10380

11160

11160

12430

10380

11230

11230

6340 6340 6340

Clearance

Round

Higher

Thread __________

Grade

Short

6340 6340 6340 6340

10740

6340 6340 6340

Long

Regular Coupling

Special

Coupling

Higher

Clearance

Higher

Standard

Coupling

Gradet

Joint

Gradet

904

1092

927

1042

979

1017 1144

1206 1334

927

1113

979

927

1113

979

1055

1288 1423 1574

1186 1335

963

1288

1103

1288

1423

1103

1412

1574

1103

1412

3520 3950

3520

3530

3520

3520

394

453

639

639

639

639

3950

3950

3660

3950

452

520

714

714

714

714

3520 3950

3520 3950

3520 3950

3520 3950

3520 3950

3520

3520 3950

423

489

755

755

755

55

486

561

843

843

843

843

5390 5930 6440

5390 5930 6440 7430

694

926

926

776

1016 1098 1257

934

1165 1165 1165

294

3.660

4990 4990 4990 4990

5750 6330 6870 7930

975 1032

1032

934

1173

1053

947

934 934

975

934

1047

1038 1122 1286

1032 1173

737

979

825

1074

5140 5140 5140 5140

6460 7120 7720 8920

5140 5140 5140 5140

6820 7510 8150 9410

6820 7510 8150 8460

6820 7510 8150 8460

5140 5140 5140 5140 5140 5140 5140

893

5140 5140 5140 5140

905

1062

5140 5140 5140

934 979

979

979

1027

1161

1161

983

1161

1086

1086

1329

1329

983

1229

1235

1109 1027

1021

983

899

983

987

1119 1210

983

1027 1027 1086

1157

1386

983

1235

1109

847

1032

1078

1078

948

1074 1178

1078

1273 1458

1032 1032 1032

1078

1040 1220

1141

1141

1213

1422

1388 1500 1718

1388 1500 1718

1229 1229 1229

1164

1388

1283

1500

1358

1358

1573

1544

1386

3130 3580 4030

3130 3580 4030

3130 3580 4030

3130 3580 4030

3130 3290 3290

3130 3580 4030

420

700

700

700

700

493

796

796

796

796

565

891

891

822

891

3130 3580 4030

3130 3580 4030

3130 3580 4030

3130 3580 4030

3130 3290 3290

3130 3580 4030

450

819

819

819

819

528

931

931

931

931

1043

1041

1043

5860 6450

5860 6450

5860 6450

4150 4150 5860 6450

4150 4150

756

1160

1041

843

1271

1041

884

1190 1303

804

1228

1228

1345

1345

794

4150 4150

895

975 1092

1236 1383

1383 1515

1383 1515

1041 1041

1096 1095

1086

1283

205

1043

1027

1297

314

5860 6450

1027 1027

1074

1820

5860 6450

1053

1027

983

2280

5860 6450

1032

1074

1820 2280

4150 4150

95 975

804

1106

606

975

934

813

6460 7120 7720 8460

5490 6040

975 975

727

6460 7120 7720 8920

8700 9160 9160

975

5.140

5750 6330 6870 7930

8700 9160 9160

999

770

95

5140 5140 5140

5750 6330 6870 7930

8700 9440 9670

5750 6330 6870 7930

852

770

95

5750 6330 6870 7930

5490 6040

1240 1326 1326

936

254

5750 6330 6870 7930

10900

Joint

927

3520 3950

8700 9440

Optional

976

3520 3950

5750 6330 6870 7930

_______

789

2270 2560

5390 5930 6440 7430

Extreme

Coupling

2270 2560

5490 6040

2627

lbf

Special

Plain

Extreme

psi

23 Joint

1228

1456

1345

1595

APPLIED

322

TABLE

7.6MINIMUM

PERFORMANCE

PROPERTIES

OF CASING

DRILLING

cont 10

Threaded

and

Nominal

Outside

Diameter

in

10

Coupling

Wall

Inside

Drift

Thickness

Diameter

Diameter

12

Line

Outside

Clearance Coupling

in

in

in

in

0.450

9.850

9.694

11.750

11250

55.50

C-gO

0.495

9.760

9.604

11.750

51.00

C-95

0.450

9.850

9.694

11.750

55.50

C-95

0.495

9.760

9.604

51.00

0.450

9.850

9.694

0.495

9.760

60.70

P-hO P-hO P-hO

0.545

65.70

P.110

0.595

Pipe

Diameter

Special

C-90

Grade

in

of

Coupling

Diameter

51.00

Drift

Diameter

in

of

Box

Powertight

in

9.694

11460

11.250

9.604

11460

11.250

9.694

11.460

11.750

11.250

9.604

11.460

11.750

11.250

9.694

11.460

9.604

11.750

11.250

9.604

11.460

9.660

9.504

11.750

11.250

9.504

11.460

9.560

9.404

11.750

11.250

Body Collapse Resistance

psi

Yield Strength

1000

3400 4160

1310

3480 4290

1383

3660 4610 5880 7500

1602

1435

1515

1754 1922

2088

42.00

H-40

0.333

11.084

10.928

12.750

1040

478

47.00

J-55

0.375

11.000

10.844

12.750

737

54.00

J-55

0.435

10.880

10.724

12.750

60.00

J-55

0.489

10.772

10.616

12.750

1510 2070 2660

47.00

K-55

0.375

11.000

10.844

12.750

1510

737

54.00

K-55

0.435

10.880

10.724

12.750

K-55

0.489

10.772

10.616

12.750

2070 2660

850

60.00 60.00

C-75

0.489

10.772

10.616

12.750

3070

1298

60.00

L-80

0.489

10.772

10.616

12.750

3180

1384

60.00

N-80

0.489

10.772

10.616

12.750

3180

1384

60.00

C-90

0.489

10.772

10.616

12.750

3360

1557

6000

C-95

0.489

10.772

10.616

12.750

3440

1644

P-hO

0.489

10.772

10.616

12.750

3.610

1903

48.00

H-40

0.330

12.715

12.559

14.375

54.50

J-55

0.380

12.615

12.459

14.375

1130

853

61.00

J-55

0.430

12.515

12.359

14.375

1540

962

68.00

J-55

0.480

12.415

12.259

14.375

1950

54.50

K-55

0.380

12.615

12.459

14.375

1130

61.00

K-55

0.430

12.515

12.359

14.375

68.00

K-55

0.480

12.415

12.259

14.375

1540 1950

60.00

13%

Diameter

and

55.50

11

Outside

Threads

lbm/ft

11

Outside

Weight Size

Extreme

Coupled

ENGINEERING

68.00

C-75

0.480

12.415

12.259

14.375

72.00

C-75

0.514

12.347

12.191

14.375

68.00

L-80

0.480

12.415

12.259

14.375

72.00

L-80

0.514

12.347

12.191

14.375

68.00

N-80

0.480

12.415

12.259

14.375

72.00

N-80

0.514

12.347

12.191

14.375

68.00

G-90

0.480

12.415

12.259

14.375

72.00

G-90

0.514

12.347

12.191

14.375

68.00

C-95

0.480

12.415

12.259

14.375

72.00

C-95

0.514

12.347

12.191

14.375

68.00

P-hO P-hO

0.480

12.415

12.259

14.375

0.514

12.347

12.191

14.375

72.00

740

850 952

952

541

1069 853 962 1069

2220 2600

1458

2260 2670

1556

2260 2670

1556

2320 2780

1750

1558

1661

1661

1869

2330 2820

1973

2330 2890

2139 2284

1847

Ibf

CASING

13

323

DESIGN

14

15

16

17

18

19

20

21

22

JOInt Strengthi Internal

Pressure

Resistance Buttress

Threaded

psi

Thread

Regular

End Round

Coupling

Thread ____________

Same

Higher

Same

Higher

Line

Short

Grade

Grade

Grade

Grade

6590 7250

6590 6880

8060 8860 9760 10650

Thread

Long

6590 7250

Special

Clearance

______________

or

7660

lbf

Coupled

Buttress

Coupling ______________

6960

000

27

26

Special

Plain

Extreme

and

25

24

23

Coupling

Special

Regular

Higher

Clearance

Coupling

Gradet

Thread Short

Long

4150 4150

692

1287

771

1409

4150 4150

927 1032

1354 1483

1080

1594

1594

1203

1745

1745

1338

1912 2077

6880 6880

6960 7450

7860 7860

7450 7450 7450 7450

7450 7450 7450 7450

477

807

568

931

7860 7860

4150 4150 4150 4150

4150 4150 4150 4150

1472

4010

4010

4010

649

3070 3560 4010

3070 3560 4010

3070

3070

509

935

3560 4010

3560 4010

606 693

1079 1208

5460

5460

5460

869

1361

5830

5820

5830

913

1399

5830

5820

5830

924

1440

6550

5820

6300

6920

5820

6300

8010

5820

6300

1730

1730

2730 3090 3450

2730 3090 3450

2730 3090 3450

2730 3090 3450

514

909

595

1025 1140

1025

2730 3090 3450

2730 3090 3450

2730 3090 3450

2730 3090 3450

547

1038 1169 1300

1038

4710 5040

4550 4550

4710 4930

5020 5380

4550 4550

4930 4930

5020 5380

4550 4550

4930 4930

5650 6050

4550 4550

5970 6390 6910 3400

807 931

1042 935 1079 1208

1440

1877

322

718 905 978 952 1029

909

1140

1169 1300

1496 1598 1545 1650

4930

963

1585

1585

4930

1040

1693

1693

4930 4930

1057 1142

1683 1797

4550 4550

4930 4930

1114 1204

1772 1893

4550 4550

4930 4930

1297 1402

2079

2079

2221

2221

4930 4930

1675

1754

3560

633

1595

1370

3560

675

1529

2077

3560 4010

1877

1151

1912

307

1596

1465

1820

3070 3560

1242

1112 1112

1993 2000

3070

1066

Joint

1745

1980

1517

Higher

Gradet

1594

3070

1011

Line Standard

1370 1370 1370

3070

1042

Coupling

Extreme

Coupling

1151

1980

6300

Clearance

Regular

Round

1754

Optional Jouit

APPLIED

324

7.6MINIMUM

TABLE

PERFORMANCE

PROPERTIES

OF CASING

cont 10

Threaded

and

Coupled

Nominal Outside

Wall

Diameter

Coupling

in

lbm/ft

16

18%

Thickness

not be

Diameter

in

0.375

15.250

75.00

J-55

0.438

84.00

J-55

0.495

75.00

K-55

84.00

K-55

Line

Special

of

Clearance

Drift

Coupling

Diameter

Coupling

in

in

in

_________

Outside

Pipe

Diameter

Body

in

_________

Box

of

Collapse

in

_________

Yield

Resistance

Powertight

Strength

psi

1000

lbf

15.062

17.000

15.124

14.936

17.000

1020

15.010

14.822

17.000

1410

1326

15.124

14.936

17.000

1020

1178

0.495

15.010

14.822

17.000

1410

1326

0.438

630

736 1178

87.50

H-40

0.435

17.775

17.567

20.000

630

87.50

J-55

0.435

17.755

17.567

20.000

630

17.755

17.567

20.000

t63f3

1367

K-55

0.435

994 1367

94.00

H-40

0.438

19.124

18.936

21 .000

520

1077

94.00

J-55

0.438

19.124

18.936

21 .000

18.812

21 .000

520 770

1685

18.542

21.000

106.50

J-55

0.500

19.000

133.00

J-55

0.635

18.730

K-55

0.438

19.124

106.50

K-55

0.500

19.000

18.812

21 .000

133.00

K-55

0.635

18.730

18.542

21.000

of

failure

However

be

can

use of

by

the

stress

Ta

should

table

1480

1500

2125

21.000

/18.936

predicted

combined

for

1480 1685

2125

1490

compute

the

minimum

failure

the

internal

if

external

pressure

will

pressure

be

required

1000

for

psig

applied

API reconmends

the

ing collapse pressure al

Diameter

H-40

mode

the

7.5

ble

Drift

65.00

94.00

zero

Inside

in

Grade

87.50

20

Diameter

Diameter

and

Outside

Extreme

12

11

Outside

Weight Threads

Size

ENGINEERING

DRILLING

The

stress

computed

following

in the

effective

of

yield

determin

for

procedure

presence

axi

significant

strength

uyielde

is

first

by

Solution

and

burst

nominal

a2l

f1

for

ratio

ed

by

the

1490

Thus

easily

the

as

tension

in

3060

The

ratio

of

psi

Example 7.3

below

is

collapse

the

critical

corrected value

must be computed

pipe-body

and

psi

shown

which

K-55

133-lbflft

body tension

been

31.496

is

20-in

for

lbf

collapse

computed most

is

ayieid

for

has already

elastic

lapse pressure

ayield

0yield

It

dIt

the

value

7.6 values

2125000

of

respectively that

ayieide

Use of Table

shows

casing

for

axial-stress

col ratio

tension divid

the

rating

7.12 1000000 Note of

this

yield

or 7.7 sure

For an

collapse

mode

effective

rating

pressure

Thus

the

failure

is

to

Table

7.6b

which 7.6a

the

is

pipe wall

of

for

ayieid

of

for

Eq

pres

failure

ble

limit

7.6b with

of

the

7.5

for

ditions

where

the

the corrected

Compute casing the

axial

of

Example

tension

will

7.3 be

of

plasticity

value

yields the

effective

F1

through

failure

is

given

F5 taken from

7.4

for

pressure

F4

ayjeldFl

F2

F5

collapse-pressure for

1000

in-service

for yield

SL

mode of

transition

factors

F3 ayjeid

rating

ellipse

Fig 7.13 0.6779 Thus

0.67795500037285

The lower

d/t Example

the

or

of

by

required

internal

7.12

is

strength

used

effect

minimum

required

difference

independent

is

abscissa

Eq

of

Uyielde/Oyieid

collapse-pressure

the

the

is

The

computed be

Use

pres

corrected

7.6 can

ignore for

rating

pressure be

be

to in

equations

the

minimum

assumed

have

on the correction

across

collapse

and

strength

shown

The collapse-pressure

sure difference

effective

2125000

ayield

zero The effec

of failure collapse pressure

not

pressure

The API-recommended internal

the

0.47059

ellipse

Eq 7.4b 7.5b and failure Eq 7.4a 7.5a

yield

does

pressure collapse

the

in

determine

to

elastic

of

independent

of

from

obtained

pressure of

then used

mode

the

then used

is

nominal

is

be

internal

an

strength

determine

can

equation

with

plasticity

tive to

that

con

000 lbf Also

372852.991

067

1.989

19.86 7SitO

S41

i1SI

Ta

CASING

325

DESIGN

13

14

15

16

17

18

20

19

22

21

24

23

25

Joint Strengthi Internal

Pressure

Resistance

Threaded

psi

and

Thread

Buttress Plain

or

Thread

Extreme Line

Short

Special

Long

Coupling

Thread

Same

Higher

Same

Higher

Grade

Grade

Grade

Grade

Short

Regular

Long

Gradet

Coupling

1640

2630 2980

2630 2980

2630 2980

2630 2980

710

1200

817

1351

1351

2630 2980

2630 2980

2630 2980

2630 2980

752

1331

1331

865

1499

1499

1630 2250

2250

2250

754

1329

1329

2250

2250

2250

2250

794

1427

1427

1402

1380

1402 1596 2012

2012

1530

1530

1530

2110 2400 2400

2110 2400 2400

2110 2320 2320

2110 2320 2320

1192

2110

2110

2110

2110

2110

824

955

1479

1479

2410 3060

2400 2400

2400 2400

2320 2320

2320 2320

960

1113

1253

1453

1683 2123

2123

For

P-ItO

the

casing

is

next

resistance

API

of

20

the

913

27

through

lowest

d/t

higher

values

the

of

are

than

greater

internal

the

907 1057

corresponding of

pressure

yield

by

5c2

March

1982

for

this

pipe

the

pipe

pipe the

body

1596

1683

strergth

yield

internal

7.6a

1.496 of

grade

steel

having

minimum

which

failure

is

above

is

the

Use

indicated

affected

__ _F5

37285

\31

Wall

Rounding pressure

to

of

rating

Because

the

1012

0.0360

.496

1010

mum

acceptable

psig

The

minimum

axis

corrected

gives

psi

external

in

pressure of

1000

The

collapse

of

Bending

directional

the

wells

failure

effect

angle

casing

other

side

hand

significant

must be

of the wellbore

on

is

forced

axial

of the

bend

in relatively vertical

--

caused

stress that

the

the

favorable

is

to

force

but

for

ne

is

angle

downward

upward pipe move addition of mini

for for

the

considered

deviation

by the

axial

free-hanging

bend

can

be

the

axial

increased

straight

deviation

angle

well

directional in

angle

The dogleg-severity per 100

degrees dogleg

ft

severity

by bending

maximum

is

of the borehole

angle ct

of borehole and

in axial

given

sections the

casing

casing

tension greatly of

axial A...-.l

It

on

On

..t...

axial

increased in

the

Fig 7.14

az on

stress

by

7.13

valid

for

constant

form of

is

length

pure

bending the

along

where

arc with

radius

to

express

the

in

terms

circular

the

pipe length and

bend

the

pipe

of curvature

Fig 7.14

design is

often

convenient

the stress

caused

the

hole with

stress

the

is is

ex

is

generally

illustrated

is

increase

of the pipe

side

moment

curvature

in the

stress in the

considered to

of

between

This equation

re

couplings

convex

at

practice

7zmas21811n

takes

deviation

vertical

which

design is

bending

vertical

of the change

in

angle

the convex

ing

When

resistance

between

friction

In current

unfavorable

length

relation

tensile

of

psig

for

Effect

the

overpull

terms

unit

in

change internal

an

pressure

100010102010 predicted

wall

compensated

is

curvature

per

collapse-

psig

has

casing

and

generally

Note

and

leak

pressure

tension

nearest 10

the

of

friction

ment

pressed

and

internal

of casing

effect effect

movement

pipe

1.989

In

or the

by increased

borehole

the

detrimental

glected

It

7.3.6

12

psi

significantly

and

casing the

gives

PcrGyielde

is

Col

in

coupling

150000

of

strength

yield

the favorable

psi

listed

of the

pressure

yield

formula

elastic

is

mode

transition

anon-API

1SOYS

is

grade

calculated

Bulletin

lower limit

Eq

Col

in

resistance

784

plane

Because

of

Joint

581

listed

strengths

pressure

collapse Courtesy

Optional

Joint

559

2110 2410 3060

orE7

Gradet

Coupling

1200

1630

joint

Standard

Higher

439

2250

Internal

Coupling

Special

Clearance

Higher

1640

5ome

Line

Round

Coupling

Extreme

Clearance

Regular

Coupling

________________

Thread

Buttress

Clearance

Regular Round

27

26

Ibf

Coupled

Special

End

Ei

000

by

bending

increased

axial

equivalent

axial

where

force

caused 17

of an

nrAr

.4

lRwI

.4

l1n

APPLIED

326

RrA9

AL

RA8

A9

ALrA9

__ 212

A8

AL..dn

Ac

ENGINEERING

DRILLING

ijL

EAE

adn2IBadn

fj

ir

80

woo M0

Mc

sn

F0

Shear Force

Fig

7.14Incremental

weight

common

For

be

can

expressed

of pipe divided

foot

per

field

of

bending

by

in

casing

Fig

Eq

units

by

as

conveniently

the

of

density

steel

becomes

14a

where

and

7.15

per

and

foot

lbf/ft

for

The use of

is

in

upset with

When

is

not

will

be

the

Lubinski10 tion

theory

for the

has

axial

within

elastic

dx2

acceptable

couplings

coordinates

spatial

moment

of

inertia

is

of

the

defined

Fig

in

Youngs modulus beam For circular

by

given

current

design is

i.e

the

small

is

be

The equation

several

and

practice

than

the

for

at

length

joint

any given given

is

that

distance

contact

the

wx2

of

size

MMcFayFscXSjfl

the

Owxb

cos

compared

this

the

the

than

shape

situation

borehole of

wall

the

pipe

maximum axial

that

of

the

indicates

moment

bending

the

case

greater of

this

7.17a

with

radius of curvature In

predicted

moment that

shear

the

maximum

by and

near

the

where force

that

applied

stress range

to

Recall of

its

the this that

classical

case

when

to

beam

axial

beam

is

the

bent

material

moment

bending

and

tension

by

the

borehole

wall

of

this

equation

are small

Thus

glected eration

deflec

determine

the

is

of

will

assumed

shown

less

is

by

in close

uniformly

when

7.16 64

accuracy by

of

the in

at

be

of

the

and of

throughout the

symmetry is

Thus

bending

for

the

and

neglected

coupling

borehole pure

is

equal at

side

Fa force

The

last

simplicity

pipe the

the

Point

at the

the coupling

on

the weight

constant

Because pipe

is

7.15 El

OD

large

weight

joint

maximum the

in

analysis

can

is

the

bending

moment

the

is

degrees/100

nominal

recommended

connectors

significantly

and

nil

give

wall

Fig 7.15

diagrams

center of

is

connectors

can

with

casing

irregularities

casing

be

Use of

pipe wall

casing

borehole

Eq 7A3 An shear

the

borehole

at the

constant

stress

in

widely

of lbf

units

has been

when

the

the

at the

only

used

OD

the

l4b

valid

with

contact

will

generally

is

be

felt to

have

respectively

Eq

authors19

in

7.14b

where Fab and

moments

are

the

is

and

Fab64adnw

in

Lj/2

7.15Banding

pipe

ft

cos

well

The area of steel the

caused

stress

directional

wy.8

axial

the

two terms will

under

joint

is

exerted

ne

be

consid

tension

will

be

joint

radius

of curvature

to

radius

the

the coupling

of

of

the

curvature the

pipe

and

Mc

zmax

El

EdI2

7.18

CASING

DESIGN

Solving

Eq

7.18 the

neglecting

327

for

Eq

into

substituting

two terms

last

7a

7.1

and

yields

and

where

FayFscX

Ed

7.17b

an

as

expressed max

have

axial

and

caused

stress

feet

respec is

bending

by

then

Fab

force

axial

equivalent

6KL

64adw

Fab

inches1

of

units

increased

If the

tively

7.22b

tanh6KL Eq

Substituting

El

tj2

gives

where

would

maximum max

In

the

7.1 9a

Ed

casing

El

mum

the

solution

stress

level

In

when

this

used

of

Ed

of

to

is

the

combined

tension

most commonly coupling

sinh KrKr

l9b

KEI

been

for

the

subjected

wall

to

divided

strength

where

to

under

mum

the

by

the

joint

that

the

of

area

than

greater

the

pipe

mini

the

given

is

strength

tension

axial

by

l4O.5cxd

FcrO.95Ajp there

is

of have

round-thread

of the

cross-sectional

thread

used

is

formulas4

API

When

terms

in

strength

joint

strength

joint

El

If

tensional

bending

last perfect

strength

yield

the

yield

sometimes

material

the

in

is

the

The approach

bending

bending the

situation

failure

approach of

on

maxi

the

exceeds

level

strength

rating

subjected

pipe

bending of

of

possibility stress

alternative

axial

and

in

developed

casing

An

the

of

effect

combined loading

the

analysis

steel

express

of

by consideration

maximum

the

the

same

the

create

section

straight

present under

stress

strength

Kx

cosh

in

to

required

discussion

is

max

force

the

was handled

failure

dicated

K2

be

previous

experienced

which

for

7.15

into

2a

Fa

d.2y

17b

no

is

shear

symmetry

pipe-to-wall contact at

the

of the

midpoint

joint

Uyield08

and

nil

is

Ou

suggests

7.23a where

7.20a

--_2 dX

Fcr/Ajp

Similarly to

of

borehole

the

slope of

the

wall

radius parallel

at

the pipe

borehole

the

requires

symmetry

at

the

the

dyfdx

and

borehole

at

the

pipe be

of

the joint

is

to

equal the

Ar/4

parallel

Thus

the

slope

borehole

When

then

area of the

than

less

tension

axial

the

sectional is

the

__

the

boundary

conditions

of

Eq

7.20a

to

the

by

last

KEJ

then

aykld_218.15dn

Eq 7.23b

/KL\

tanh

Ed

\i

These

7.21

empirical

2az max tanhL Ed

tests

perimental with

casing

short

Example 7.6 36-ft

KL1

joint

Upon

solving

common

in

maximum stress

terms

field

of dogleg

units

azmax2l8adn

we

6KL tinh6Kl

expressing

severity

and

the

radius

converting

derive

22a

tional

weilbore

Compute

the

between

contact

between

couplings

round-thread

the

couplings

having

the the

Also

casing casing

load

dogleg

compute

couplings

the

and the

casing

in

the

is

portion

severity

stress

and

stress

N-80 casing the

if

axial-tension

K-55

17-lbf/ft

maximum axial

couplings

maximum axial

contact

the

5.5-in

round-thread

Determine

long 400000-lbf to for

with

7.625-in 39-lbflft

of

from ex

were developed

correlations

conducted

round-thread

of curvature

cross-

thread

perfect

gives

1s2zmax

to

the

eld

0.644

FcrO.9S4jp

divided

strength

yield

auttayi

xL/2

Applying 7.19

strength

pipe wall under

minimum

7.20b dx

d2t21

has

was chosen

abscissa

x0

and

the

Because

point

of curvature to

midpoint

form

this

that

Cyield

borehall

joint

API

subjected of

direc

of 40

ft

uniform

assuming borehole

for

with

wall and wall

strength

of

only the

at

API

APPLIED

328

Nominal

Solution

895000

is

the

ID

of

steel

in

for

strength

this casing

798000

is

strength

7.6 The

pipe body

the

yield

joint

in Table

6.625

is

pipe-body

nominal

lbf

and

the

calculated

cross-sectional

area

Fcr9.50194991902SOO

without

stress

bending

The

additional

caused the

by

stress

Eq

of

the

on

convex

contact

side

with

computed

between

of

Eq the

the

7.13

maximum

gives

for

7.3.7

and

-2l84.O7.6256

total

of

stress

gen

psi42389

psi

it

is

assumed

borehole and

wall

7.22a

that

occurs

must

be

contact

between

at the

only

the the

and

casing then

couplings

Eqs

7.16

used

conditions

on

joint

force

pull-out

metal

The presence reduces

steel

As

its

causes

recom within

yield

This

break

to

it

at

hydrogen

hydrogen

and

ductility

rate

hydro

before

rate

molecular

this

the

form

to

atomic

result

significant

atoms

molecular

present

combine

at

of

is

have

reaction

form gaseous

to

atoms

reduced

is

thc

can

hydrogen

corrosion

by

sulfide

hydrogen

hydrogen

enter

surface

water

When

strength

combine

atoms

of

presence

casing

When

brittle

manner

known

as

called

than

rather

in

sulfide

to

in.4

atoms

Dry

which

occur sulfide

hydrogen

generates

does

not

is

failure

resulting

Water must be present

cracking

reaction

phenomenon

The

embrittlement

hydrogen

corrosion

6.6257l37

of

based

the

is

Ir/647.6254

the

metal

H2

gas

may bining

If

in

upon

these

psi

hydrogen which the

35740 psi6649

these

be

Sulfide

Hydrogen

formed on

some of

649

of

sulfide

effect

major

of

stress

Effect

Hydrogen

are

zmax

for

value

table

must

minimum

the

by

nominal

value

and

casing

bending

Thus

strength controlled

is

the

table

pipe

7.13

wall

borehole

Use

he

of uniform

assumption

the

level

can

bending

pull-out

above

is

nominal

the

lbf

strength

psi

value

this

798000

is

joint

35740

192

400000/11

lbf

in

sq

Because axial

is

strength

and

lbf

is

ir/47.6252_6.6252ll.192

The

joint

ENGINEERING

DRILLING

for

the

hydrogen

embrit

cause

tlement embrittlement

Hydrogen

400000 _______________

30106

steels

high-strength

0.01367 in.i

with

steels

37

fail

not

yield

zmax

22

of

19732

tanh 36736J

psi

nickel

stress

assumption the calculated maximum

axial

to

be

either the

psi55472

joint

assumption

be

to

the

psi

for

strength

with

Eq

for

strength

100000

psi

dogleg

yield

N-80 casing First

is

well

that

the

Eq

100

ft

minimum in

When

Table

can

this

been

ul

There

7.23a

gives

can

psi

be used

l40.547.625

______________

194991

oratory

and

exposed

to

at

100000_800000.8

levels

Because

A1

FCr/Ajp

80000

psi

__

7.23b

does

thread

not

apply

The

this

result

is

valid

in

area under

the

last

centrations Failures

_6.6252 9.501

sq

in

is

7.16

and

followed

contain

steel

hydrogen-

C-90

have

in

17 as

steel

at

are

obtain

Kane

of experimental steel

grades

that

of

were

levels

stress

maximum safe

percent

and

lab

concentrations

various

the

minimum

grades hydrogen

sulfide

stress yield

con

temperatures

from hydrogen after

during

sudden

pressured to

steel

varying

sul

hydrogen

difficult

is

cas

90000

than

abnormally

results

and

and

immediately

by

that

several

exposure

time period

strength

deep

sulfide

expressed

resulting

not occur

fide

the

of

tests

various

is

do

wall

of

grade

increases

yield

high-strength

temperatures

for

strength steel

field

observed

and

casing

greater

L-80 and

as

design

some

presented

Figs

In

casing

hydrogen

various

Shown

with

temperature

wells

fluids

use of

have

in

safely

produced

the

as

that

practical

without

where ex

high-strength

such

grades

general

Increased

higher

special

psi

as

cer

sulfide

steel

applications

casing

minimum

higher

in the

Greer

Eq

75000

selecting

casings

evidence

is

wells

100000

by

RHN

successfully

with

ings

Fcr

perfect

practice

above

selecting

not possible

is

used

7.1

fide

0.95

than

rather

sulfide-resistant

of

specified

applying

is

strength

severity

7.23 Recall

stress

by

such

which

at

anticipated

is

RHN

number

design

for

possible

sulfide

achieved

is

strength

maximum axial

8O000-psi minimum

computed

timate

RHN

will

100F

above

lower

at

carbon

generally

other materials

the

raise

casing

strengths

when

hydrogen

thickness

The

yield

are avoided

posure

35740 psi 19732 For

In

psi

hardness

is

ly

below

90000

cracking

can

occur

can

minimum

with

sulfide

by

in

significant

Common

temperatures

with

alloyed

is

treatments

cracking for this

fail

for

Rockwell

to

that

can

heat

tain

Thus

Steel

especially

below

cracking

This corresponds

64960.Ol 36736

is

temperature

strengths

sulfide

by

low

at

embrittlement

exposure

which

to

no damage

failure During

often

hydrogen

the

is

sul

evident

time period

CASING

DESIGN

329

00

.80 Ill

6-

V.150

6-

uJz 60 LU 661

/1

u..O

40

.t 20

J-55

66.500

PSI

V.5

C-75

00.400

PSI

VS

87.000

PSI

0.0

90.200

PSI

0.5

97000

601

VS

122700

PSI

0.0

000-125

139.500

PSI

0.5

000.140

155.000

PSI

V.150

150200

PSI

96000

PSI

N-SO

MOO

_______________

N-SO

000.05 110

Ct

dooi

o.i

i.o

CONCENTRATION

OF

io

id.o

GAS

IN

H2S

410-OS

100

HS Fig

7.l6Maxjmum

safe

and

casing

stress

H2S

200

level

for

various

grades

of

7.17Maximum

Fig

75F

at

safe

and

casing

300

TEMPERATURE

TESTING

concentrations

VS VS VS

stress

level

various

for

100%

at

temperatures

of

grades

concen

H2S

trations

40 before

35

to

of

results

-J -J

different

time

the

hydrogen

incubation

the

of high

points

stress

failure

to

stresses

applied

Lii

30

called

failure

diffusing

for

Fig

hydrogen

is

shows

7.18

test

RHNs

different

shows

7.19

the

and of

effect

12

concentration

sulfide

period Fig

25 lx

7.3.8

20

exhibit

Lii

15

Applied Yield

field

Stresses

Expressed

lx

As

01

0/

of

Deformation

TIME 7.18Effects

of

failures

TO

stress

for

various

FAILURE level

on

500 hr

time

to

hardness

Rockwell

1000

the

by

that

numbers

deformities to

especially

wall its

tube

that

collapse

-J

est

-J ii

diminishes

such

of

can

the

occurs

be

lowered

by

while

the

25%

to

hole

results

normally

This

resistance

dIt

thin-

ratios will

Thus

downhole

careless

hydrogen

have

the slight conditions

amount

significant

be stress-hardened by resistance

4%

casing

the

into

run

is

casings

hydrogen-sulfide-resistant

the

be

of tong

out-of-round

by

make

to

torque

pipe

or

slips

resistance

affected

is

used

thickness and

collapse

its

1%

collapse

it

the

by

tongs

special

C-90 can

as

If this

by

by

strength can

occur

with high

casing

resistance

the

in in

deformed

is

crushing

Some

for

also

or while

reduction

true

wall

excessive

deformity

considerable

by

will

several

combinations

the

can

location

mechanical

of

by

transported

in is

caused

burst

that

70%

17%

penetrate

adversely

burst strength

shown as

of casing

joint

and equipment

procedure

Mechanical

Any

given

affected

example

much

as

by

marks

is

that

be

can

For

out-of-roundness

H2S-induced

Handling

pipe Tests have

reduced

50100

0.5

field

operations

the

up

Field

properties

in the

significantly

l0

Fig

Effect

Performance

handling

embrittlement

lost

The API Recommended

Practice

for

Care and

Use of

Lii

Yield

Deformation

perienced

Week

to

50100

TIME Fig

7.19Effects various

of

TO

H2S

hardness

poor

Once

FAILURE

concentration

Rockwell

RP5C

Casing

l30/

Level

hr

on

time

numbers

failure

for

dures

casing

shipping

become as

plement

common

lists

and

casing

and

in

design

of problems

Over half are pipe-running

are

principles

familiar with

recommended

causes

tubing

handling

casing-design

should to

with

113

mastered

practices the

good pipe-handling

RP5C1 plan

ex

related

before attempting

student

proce to

im

330

APPLIED

7.4

Casing Design Criteria

The design

of

casing

of

the

surface and

of

the

production

found

are

in

strings

equipment

that

termine

the

exploratory

The

interval

that

To obtain often

is

sometimes

surface

reduced in

to

stages

lower grades must be

leak-free

ditional

of

the

wear

casing upper

depths safe

the

different

steel

of

strings

use

to

as

from

results

and

However

within

casing

must extend

drill

done casing or

weights

savings

and

longer

exposure

of

translation

ad

the

the

line

drill

possible

aquifers depleted

that

Selection selection

respective eration

of of

dients

shown

in

of

of

the

tend

formations 7.20 depth

methods

and

to

gradients be

illustrates

and

these

fracture

presented

in

consid

on

gradients

gradient

data

gra

example

ally

The

pore-

obtained

are

are expressed

as

fracture-gradient

to

when

casing

ing

diverter

MUD

the

CONDUCTOR

stopped

some

the

the

when

the

specified

the

and

can

to

The

of

soil

The

simultaneously pore-pressure

above

based

is

bore

surface casing

and

The conduc

dur

pressures expected around

washing

is

driven the

by

operation

foot

per

outside

is

governed

casing-driving

number of blows

the

often

casing

length

the

on

shallow

the

surface casing

conductor the

gener

conditions

outlined

the

casing-

are

such

the

depth

sustain

and

affect

may show cement job in

that

and

pipe

bore

the

gradients

washout of

the

zones

an area

found

depth

of

be able

of

at

stuck

in

When

types

operations without

ground

resistance

DENSITY

to

conductor

the

kick

no

freshwater

to close

casing-seat

be

prevent

of

and

requirements

weight

must

tor

into

to

If

kick

cause

to

fracture

casing-setting

drilling the

tend

requirements

special

conductor

support

of

EQUIVALENT

these

amount required hole

that

must

design

and

The

good

get

meet

line

regulationsalso

types or

will

to

possible

lost-circulation

plastically

some formation

in

higher

shown

hydrofracture

Also experience

to

are present

between

relationship

Chap

their

fracture

The

penetrated the

and

strings

and

easier

is

it

and

density

take

protection

that

zones

flow

to

requirements

some formation

based

is

generally

pore-pressure

Fig

Depths

number of casing

depths

pressure gradient the

Casing Setting

the

setting the

casing-setting

by

presence

that

the

as

of vugular

low-pressure

beds

salt

Point

blowout

factorssuch the

needed

fracture-gradient

to

causing

where

When

true

ex

intermediate

surface casing

require

impossible

without

underground

Other

to

fluid

the

flow

kick without ex

density

Point

from

fluid

the

Point

mud

drill

will at

pres

formation

at

depth

to

or one

prevent

fracture-gradient is

it

depth

casing-setting

to

density

drilling

opera

drilling

prevent

weakest

the

to

depth

design

provided

is

the

and

the

subtracted

obtain

to

needed to

is

margin

margin

depth

The

least

at

hole and government

string

7.4.1

be

will

set

the

casing

to

fluid

Similarly

intermediate

kick

of

costs

as

Point

to

equal

is

effective

the

weight

pressure

i.e

of

ac

pore

bottomhole

the protective

at least

gradient

to

the

drilling

gradient

the borehole

fracture

pore

well

the

mud

tripping

0.5 Ibm/gal

is

chosen

is

this

carry

posed

from

is

into

fracture

during

is

an

formation

of excess

objective

line also

provide

in effective

margin

psi

Point

at

to

anticipated

formation

depth

string

the

well

to

trip

500

to

the

fluid

the

ceeding

liner-tieback

this

the

shown

of formation

to

the

reductions

used

200

over

To reach density

be

risks

tieback operation

BHP

sure

Point

potential

additional

provide

will

at

lighter

the

that

set

running

for

commonly

to

running

allow

to

tions

cost savings

hole When in

grade

above

margin

depth

program

are chosen

densities

ENGINEERING

vs

plotted

by upward pipe movement

strings

casing

use

the full

trip

the

casing

Additional

the

to rotation

casing

pro

completed

Such

Of course

that

possibility

setting

ceptable

caused

are

planned-mud-density

The mud

pressures

and

density the

plotted

some

In

productive

and

and

types

of

of

weighed against

successful

of

possible

of casing

the

design

loads experienced it

en

must design

grades

by

instead

make

These

staff

to

de

drilling

anticipated

then

string

bottom

the

tension often

an

sections

achieved

strings

the

lift

configuration

coupling

be

can

combination the

and

combination

called

be given

drilled

producing

of multiple

thickness

be

to

for

sizes

well

the

casing

engineering

sizes

size

artificial

in

placed

most economical

the

consist

wall

the

also

the

hydrocarbons

production

engineer

well

the

be

below

casing

desired

the

of

must

drilling

sizes

allow

will

in

ly

bit

if

The number and

are determined

drilling

and

locations

be used

equivalent

representing

specification

type of subsurface

members

consideration

gram of

well

will

quantities

the

usually

gineer by other

of

that

casing

may eventually minimum ID of the

specifications

cases

bottonihole

and

with

program begins

comrnerciaj

of tubing

an

DRILLING

exceeds

is

some

limit

upper

SURFACE

well

Example Jefferson

Parish

LA

is

being

The

for

planned

intended

well

INTERMEDIATE

use of 7-in

the

quires

Determine this

the

depth

depth

objective

of each

string

PRODUCTION lithology

data

production

number of casing

Pore

Fig

l.20Sample mation

relationship pore-pressure

among

casing-setting

gradient

and

depth

fracture

for

gradient

margin

minimum freshwater

when

making

trip the

is

2000

in

re

set

15000

at

needed the

fracture

casing

setting

gradient

wells are given

ft

reach

to

in

and

Fig

margin and aO.5-lbm/gal The

casing-seat selections

length of surface casing aquifers

select

pressure

from logs of nearby

7.21 Allow aO.5-lbm/gal kick

and

safely

casing strings

location

completion

required

to

ft Approximately

the

protect 180

ft

of

CASING

DESIGN

331

TABLE 7.7COMMONLY FOR RUNNING

USED BIT SIZES CASING

of

API

Common Size

Casing

00

Size

Coupling

OD

in

51/2

5.563

61/2

6.050

77A

6% 7% 8% 9%

81/2

7.656

8%

93/4

8.500

97/s

10%

10.625

10

11.750

15

13%

14.375

171/2

16.0

17.0

200

21.0

be

on this

casing

area

It

cement the casing

to

to

required

is

conductor

the

is

in

diameter

91/2

In

11

most

will

bit

of

However

additional

in

circumstances

special

than

in

Example 7.8

maintain

to

The

fracture

design

kick

0.5-ibm/gal

shown

are

15000 This

in

at

11400

ft

of

ft

above

Point

to

13.7 ibm/gal

formation

ft

be

to

4000

at

conductor-casing

Only 2000 freshwater length

would

shale

before

set

these

in

in

permit because

much

larger

common

sizes

can

that

available

are

that

be used

the

is

for

needed

to

the

An

9.625-in

available

to

the

needed

data to

drill

As shown

in

13.375-in

through

per in

presented the

to

Table

Table

after

Ac

determined

12.25-in

the

intermediate bit

12.25-in bit

is

the

pass

see Table

7.7

of

depth

7.8

will

made

be

to is

foot

17.5-in

casing

bit

casings

have

will

of

section

8.625-in

An

desired

is

string

the bottom

drill

select

string

casing

7.7

Example 7.7

in

casing

production

Table of

data given each

will

needed

pass

to

drill

the

usual

the

EQWVALENT

LITHOLOGY

MUD

OENSITY

Ibm/gal

10

the

to protect

have

20

Shale Sand

casing to

be

liner

depth

kick

are

depth

is

casing

set

2000

also is

objective

4000

margin Because

type only minor var

required

FRACTURE

maintain

to

the

\\__.GRADlENr

6000

shale

in

seat

total

sizes

requires

additional

formation

in casing-setting

casing

the

0.5-lbm/gal

the predominant

is

iations

be

to

maintain

to

but

shown

are

sizes

available

readily

final check 7.8 However the required maximum weight

bit

set

Because

would

An

zone

transition

most

be

depth

minimum

this

if

bought

advantageous

is

features sizes

drift

density of

turn

needed

casing

see

appropriate

is is

borehole

cording

to

pressured

ft

However

intermediate

the

have

reached

180

of surface casing

ft

aquifers

in

higher

of

in

bit

Point

forma

the

mud

Point

ft

normally

is

depth

used

is

ft

of

This

4000

set at

to

casing

casing

Point

required

is

depth

7-in

8.625-in

through

lines

to

drill safely

to

Similarly

two

drill

fracture

prevent

depth

required

intermediate

intermediate

set

surface casing

to

plot

permit

These

be

will

is

every to

To

lines

mud

first

plotted

depth

by dashed

turn requires

ft

is

every

17.6-Ibm/gal

11400

11400

at

margin

at

margin

trip

then

line

Fig 7.21

in

of

tions

0.5-ibm/gal

bit

Using

OD

sizes

Solution

ted

types and

bit

bits

make

bit

of casing

in

practice

rather

program

used

commonly

The

the

diameter

drift

the

used

Selection

7.8

than

pass

also

commonly

manufacturers

casing

The planned-mud-density

will

stuck

diameters

drift

of casing

joint

than

drill

casing

and

smaller

bit

every

larger

for

generally

washout

prevent

general

most

7.7 and

the use of the

bits

ID

the

the

more

wall thicknesses

and

that

pass through

than

Only

sandstone

Solution

the

IDs

sizes

casing assures

sizes

strings

getting

7.8 are casing

instances

smaller

26

shale

casing

8/s

20

generally

outside of

the

API

without

bit

used

commonly

safely

Table

consid

similar

of successively

size

casing

various

various standard

variety

conductor

which

in

With

string

are selected

segments

placed in

Tables

24

and

bit size

pipe manufacturer

12 14

121/4

hole

for 81/2

casing

7.7 provides

Shown

83/R

11

well

can

6/4

7.390

9.625

shallow

ing

8% 8%

6.625

the

Table

in 6%

in

5.0

41/2

second-deepest

erations

Used

Sizes

Bit

the

\\ FRACTURE

\.GRADIENT 0.5

\-\

KICK

8000

7.4.2

Selection

The

size

sary

ID of

of

mediate

the

of

well

must

bit

be

the

used

slightly

to

casing

production

neces

the

by

10000

number of inter reach

to

required

the size

and

string

strings

To enable

controlled

is

strings

casing

well the

in the

Casing Sizes

production

casing

objective

the

the

the

depth

be

placed

2000 \\

to

drill

than

larger

the

the

last

OD

interval

of

the

of

TRIP

MAR

\\

casing

\\

14000

The

connectors clearance cake as

on

selected

beyond the

the

borehole

centralizers

lower

portion

string

above

and of

the

This

LESS

lbs/gal MARGIN

OD

of

wall

the

and

scratchers well in

should

bit size

turn

also

coupling

for

casing

The

bit

must

fit

determines

sufficient

provide to

allow

for

inside the

to

drill

the

OBJECTIVE

such

appliances used

DEPTH

mud

the

casing

minimum

size

Fig

7.21Pore-pressure Jefferson

gradient

Parish

LA

and

fraction

gradient

data

for

332

APPLIED

TABLE 7.8COMMONLY

USED

THROUGH Casing Size

0.0.

Weight Per

in

Foot

lbm/ft 9.5

BIT SIZES

API

Internal

Diameter

THAT

WILL PASS

CASING

in

in

10.5

4.052

11.6

4.000

3.875

13.5

3.920

3.795

Used

in

4.560

4.435

13.0

4.494

4.369

15.0

4.408

4283

18.0

4.276

4.151

shown

18.625-in the

13.0

5.044

4.919

14.0

5.012

4.887

15.5

4.950

4.825

17.0

4.892

4.764

20.0

4.778

4.653

23.0

4.670

4.545

6.135

6.010

20.0

6.049

5.924

24.0

5.921

5.796

28.0

5.791

5.666

32.0

5.675

5.550

17.00

6.538

6.4

17.Q

20.00

6.456

of

Once

the

and

6.366

6.24

6.276

6.151

29.00

7%

184

ered

6.094

5.969

35.00

6.006

5.879

38.00

5.920

5.795

20.00

obtain

tend less

often

is

ditions

61/4

of

on

of

causing

29.70

6.875

6.750

33.70

6.765

6.640

39.00

6.625

6.500

tors

criteria

7.600

700

cepts

44.00

7.625

7.500

should

49.00

7.511

7.386

8.845

8.92

8.765

4000

8.835

8.679

43.50

8.755

8.599

8.681

8.525

47.00 53.50

10/a

11

8.379

32.75

10.192

10.036

40.50

10.050

9.894

4550

9.950

51.00

9850

9794 9694

5500

9.760

9.604

60.70

9.660

9.504

6537

9.560

9.404

38.00

11.154

10.994

42.00

11.084

10.928

47.00

11.000

10.844

54.00

10.880

10724

60.00

10772

10616

4800

12.715

12.559

54.50

12.615

12.459

61.00

12.515

12.359

68.00

12.415

12.259

72.00

12.347

12.191

55.00

15.375

15

65.00

15250

15062

75.00

15.125

14.939

84.00

15.010

14.822

14688

14.500

109.00

18%

188

87.50

17.755

17.567

this

text

and of

theffects

the

de

in the

thick

casing

where they occur

stresses

the various

by

prob

occurring

included

reduce

to

design

very low

well

and are too numerous

be

by

Instead

opera

ex

an

for

example

design

in to

mastered

are

of

any

easily

loading

conditions

the

con

the

student

the

other

criteria

company

minimum-cost casing

casing

Once

be presented

text

apply

particular

onomical

casing

this

drill

of current

representative will

practice

able

his

be

felt to

are

To achieve

8/2

8%

that

and

that

coupling

must

prices change

be

used

the

design

for

ec

depths Because

all

detailed

frequently

most

meet the design

will

of

list

prices

81/2

of

text

this

9% 9%

mum

cost

sible

weight

the

per load

API

casing

foot

and

foot

of

and

that

the

Casing

different

different

17

the

for

casing tional

Thus

well

considered that

on

with

General

liner for

each

than

the

meet

in the

the

cost

burst

per

strength

and

slope of

geothermal

and

casing

for

surface

will

casing arctic

will also

can

wells

Alaska

casing

casing

string

criteria the

ob

depth

drilled

and

steam wells

criteria

production wells

casing

Design

intermediate

thermal

the

intermediate

e.g

design

to

production

applicable

for

type of

criteria

north

the

e.g

surface casing

criteria

drill safely

environment

application

wells

to

from those

design-load

permafrost well

injection

ed

will

illustration

increases with increasing

conditions

drilling

liners

11

14

be

that

this

assumed

functions

different

drilling

into

required

strings

are

casing

the

grade

For

will

be

per connector

cost

serve

121/4

have

will

It

minimum pos

the

strength

joint

or

minimum selected

mini

In general

increases with increasing

casing

the

is

with

casing

couplings

example applications

jective

15

in the

criteria

11

10%

when

achieved

design

only 81/2

is

not practical

is

type

77/s

varylwith 16

tend the

be

the

based

is

assumed

is

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7.4.3.1

Surface

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334

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CASING

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while

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jection

7.4.3.3

the

fracture the

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nearly

left

the

if

possible

that

The

initial

production

fail

be

collapseillus

degrees

that

be

tension

considerations

The

are

loading

has an

above

casing

mud

the

near

not

to

casing

ideal for the

greater

7.8 has an

pressure and

pore

will

it

assumed

also

in the

density of occurs

that

and

burst-design

well

well The

assumed

is

is

generally

formation

burst-

production

producing

in the

so

designed

tion

that

to the

equal

produced

tubing

for

Fig 7.24 The example

in

dition

be

conditions

loading

trated

BHP

Casing Example

that

axial

the

that

100000

force of

identical

assume

in

as

which

hole conditions

other

All

are

the

con

no

that

seat

assume

Also

Also

pressure

assume could

lost-circulation

the

of

factor

pore

temperature

zone

next casing

the

as

For simplicity

considerations

lost-circulation

fracture

1.1

methane

5200.012D

to

collapse

of

formation

Formation

psi/ft

equal

is

16

of

weight

of

factor

safety

composed

is

The normal

0.465

is

kick

gas

molecular

Solution 7.4.3.4

any

gas behavior area

and

gradient

that

has

pressure plus an

for

the liner

the

the

full-

of

formation

intermediate

below

next

lost-circulation

Casing With

intermediate

criteria

the

the

calculation

gradient

be supported

gradient

design to

will

the

account

hydraulic

criteria

liner

drilling

siders

to

Intermediate

design-load

the

exposed

to

equal

margin

safety

within

drop

is

pressure

assumed

of

depth

pressures between

seat

determined the

the

permits

The depth of from the fracture

casing

be

to

drilling

string

to

mud

use an

ilenitv

injection

lhm/l

pressure

that

reqer

than

Fit

4_PrnrIi

ri

nfl

racjnn

ripsirin

loans

for

irs

unu1

rnIIuno

336

APPLIED

Thus

the

surface casing

conditions

The externaj pressure formation

design

The

loading

external

casing

on

2775 zero

is

psig

9.3

at the

surface

seat

For the

psi/ft

1860

The

is

internal

psig

2775

is

the

at

casing

factor

ty

the

at

cal

the

severe

if

seat Multiplying

of

1.1

yields

the

ble

the

illustrates

do

The

string

1730

the

psi

7.24b

load of

load

lost-circulation

and

psi

graphi

shown

has

at

in

in

the

burst

zone

of

the

zones

that

could

be

used

1249

has

burst

top of

other casings of

the

design

of

rating

41

of

ft

assumed

is

2933

ft

at

the

then

if

the

the

planned

no

permea

then

depth

zero

mud

the

bottom

casing

be

to

bottom

the

rating

of

2730

psi

the

249716

listed

have

burst-pressure

of

to

ft

internal

3959

of

depth

could

level

The

to

fall

pressure

ft

and

fluid

level

without

at

the

exceeding

differentiai

3959

at the

zero

at

factor

4000

ft

will

be

The

C-75

the

casing

easily

the

this

case

with of

section

68-Ibm/ft

casing

decreases

toward

possible

to

mediate

depth

The

next

To

in

be

Because

the the

the

the

casing

and

68-Ibm/ft

of

will

between

collapse-

the

collapse-

casing

string

2220

of

rating

use

the

at

psi

the

of stronger

bottom

the

selection

casing

bottom

less

the

psi

the

casing

of

of

C-75

collapse-pressure

expensive

string

the

be

will

it

at

casing

surface and casing

The

string

composed

casing

the

made most

is

load

will

an

casing

J-55 or

be

inter seat

K-55

casing

.27a

Fig

string

the

casing

to

determine

68-Ibm/ft

final

most economical

68-lbm/ft

load

the top of

change

of

7.6

load requires

the

2096

Ii and

of

collapse

burst-design

beginning

bottom

bottom

with

collapse-design than

3959

at

Fig 7.26 To meet the

load of

collapse-design

psi

Table

see

these pressures

Multiplying

representation

in at

casing

required

string In

design

shown

is

ft

2107

requirement

casing

burst

design to collapse

psi

yields

graphical

load

68-lbm/ft

example

3959

floated

partially

psi

of

the surface

design

of

tends

permit

of

depth

be

collapse that

4000

of

seat

casing safety

design

representation

to

and

ft

by

at

4000

could

would

design

safely

1915

l93429 1905

3000

this

surface

the

0.0529.33959

2000

fall

in

requirements

1000

run

is

to

the casing

desired

if

casing

casing

internal

zero

the

psig

when

The pressure

ft

ratings

that

Thus

ft

at

Fig 7.25Graphical load

this

near

ft while

used and

is

above

For these conditions within

is

the

encountered

is

Dml3.70.465/0.052l1400/l3.73959

in

excess

Eq lost-

Ta

below

305327304000/3053 All

The

with

normal-pressure

mud Fig 7.21 exposed

calculated

11400

seat

occur

encountered

is

is

con

is

could

that

Fig

Note which

is

is

below

7304000I3053

The J-55 casing

level

unexpectedly

next casing

are

level

problem

0.052l3.74l29

3053

ft

load

collapse-design

in fluid

mud

the

assumed

is

it

13.7-lbm/gal ble

J-55 54.5-lbm/ft

requirements

If

depth

requirements casing

of

depth

circulation

safe

3053

seat is

is

casing density

4000

at

is

psig

for the

pressure

casing

pressures by

casing

which

the

29951860

of 13.375-in

design

used

burst

burst-strength

H-40 casing

the

be

at the

burst-design

H-40 casing

could

psi

1135 these

ratings

that

not meet

psi

of

burst-pressure

7.6

casing

the

comparison

to

burst-design

1249 of

representation

tends

that

surface and

surface and

7.25 to

at

psi

differential

load

the

mud

planned

pressure

1934

maximum loss

the

by

maximum The pressure

the

external

when

external

trolled

0.4654000

the

ENGINEERING

collapse-design hole

the

Fig 7.21

0.0529.34000

nor

the

in

density

to

and

lbm/gal

of

pressure

mud

the

run According

pressure of 0.465

pore

the

at

pressure

the

based

2995 0.055400IJ

mal

for

pressure

is

DRILLING

Point Point

section

F68L1

minimum

consider is is

the

located

possible

at the

located

force

at

balance

p1ApA1

diagram

bottom

the

on

of

length

free-body

of

top of this

the

the

section

C-75 shown casing

C-75 gives

337

CASING DESIGN

PRESSURE

Psig 2000

1000

2S2

ANNULAR MUD

p1

As

2000

AXIAL TENSION

A5

Pi

W1L1

F3

p2IXAS2

BOTTOM OF SECTION

AT

p3AAst 54.5

_____J-55

-5561

Fig

7.26Graphical

of

representation

sample

lb/ft

lb/ft

design

collapse

load

1240 where Fa

is

axial

the

and

P2 are top of Sec

and

bottom

at the

hole

load

areas

between

is

cross-sectional

the

area of

to

given

as

12.4

15

area

of

steel

is

in

in

As

The bore

for

ft

previously

steel

in steel

and

4000

bottom

at the

difference

Secs

the

collapse-

be 29

Sec

Because area

as

top of

has

Sec

the

is

Sec

the

per

the

at

generally corrected

is

the

Fa

2919.44568L1

68L1

above

564

minimum

corrected will

length

collapse-pressure

be

equal

to

L1

is

given

rating

at

the

collapse-load

the

is

so

bottom

that

of

the

to

then

used

in

Fig

68-ibm/ft

for

psi

not

strength

yield

shown

is

Pcr

is

for

to

correct

the

the

Unfortunately function

of

Fa

the

and

collapse-pressure

trial-and-error

solution

col

casing

is

1069000 the

first

rating

procedure

1950 lbf

psi

Table

iteration

4000l.879l950336

68336

used

with

for

Pcr

for

the equation

56422284

lbf

ft

for

rating

and

7.6

gives

is

Fa

An un

equation

be

rat

significantly

collapse-pressure

rating

corrected collapse-pressure

for

the collapse-pressure

by

corrected

present

collapse-pressure

until

continued

and is

this

can

computed

Fa

change

of

rating

40003959Pcr12j07

where Pcr

A3

OF SECTION

tension

axial

root

the

find

The

uncorrected

K-55

Sec

load line

for

collapse-pressure

does

The

L1 L1

used

ing The process

must be chosen

the collapse-design

After inspection of

7.26

L1

is

iteration

first

rating

The

BOTTOM

P3

1A52

steel

and

foot

P2

load

design

lapse

tension

axial

AT

A1

diagram

7.27Free-body

sq in

same weight

zero and

P1

AXIAL TENSION

7.6 and

Fig

r/413.3752_12.4l52l9.445

L1 W2L2

W1

F3

The

psig

Table

lb/ft

Sec

of

length

pressures

is

at

pressure

was determined

the

is

L1

cross-sectional

and

ID of the casing the

the

is

hydrostatic

design

tension hydrostatic

Sec

of

cross-sectional

the

C-75 68

the

J-55 or

pipe-body

Use of 1950

338

APPLIED

TABLE

7.9CORRECTION RATING FOR

OF

SEC

1A

COLLAPSE OF EXAMPLE

Use of

failure

PRESSURE 7.9

Eq

for

the

collapse-pressure

rating

gives

IdeId

OZ/CyIeld

7.6a

ENGINEERING

DRILLING

1929

375

24936

3625

0.0233

0.9881

1926

381

25344

3619

0.0237

0.9879

F4

l\-5

PcrOyielde

1926

1.989

0.989455000

0.0360 \27.86

TABLE

7.10CORRECTION RATING FOR SEC

OF COLLAPSE OF EXAMPLE

PRESSURE

lB

7.9

JLL.

Fa

1540

1106

74644

2894

0.07759

0.9589

1477

1225

82.736

2775

0.08600

0.9542

1469

1240

83756

2760

0.08706

0.9536

Ideejd

cz/ayield

1929 Note

that

psi

correction

the

1469 nominal as

value

table

of

mode

the

7.11CORRECTION RATING FOR SEC Fa

OF COLLAPSE OF EXAMPLE

1T

PRESSURE

having

1130

637

122613

2123

0.1437

0.9204

1040

806

132922

1954

0.1558

0.9130

1031

822

133898

1938

0.1570

0.9122

this

ed is

for

collapse pressure

be estimated

now with

second

Example 7.5 Since the fluid below the point of interest in

level

inside

zero

is

not be

result

in

minimum and

chosen

iter

because

Sec

length the

next be

will

12.5 15

is

and

7.6

the

pipe-body

collapse-pressure

The change

in

the

steel

from

bot

becomes

Point

at

in

the

iteration

method previously

the

would

specified

lbf

Table

psi

area

cross-sectional

The corrected

962000

is

1540

is

rating

long

Sec

61-Ibmlft pipe

for

strength

However

J-55 or K-55 61 lbm/ft

casing

for

The ID yield

pipe

the will

type casing

most economical considered

than

less

length

500 ft

of

1031

can

68-lbm/ft

K-55

use of J-55 or

7.9

additional

an

through

Table

in

as

rating

the

to

applied

unchanged

calculations

values

is

collapse-pressure

remains

failure

the

yields

0.9894

factor

the

7.9

.jjei

UzTyied

of

these

Continuing ation

TABLE

1950

0.9894

PC

AAzi412.515212.41521.958

present

the

sq

in

casing and

and

the

68L 564

Fa

22284

becomes

tension

axial

L958p2

00.0208 1069000

yield

where P2

is

tom See

Table

The

Oje __0.02082

.sj

K-55

0.02080.9894

next

pressure

The lower

Eq

of

limit

7.6b with

the

factors

UyieldFI

d/t F3

jeld

mode of

transition

F1

to

given

is

F5 taken from Table

10

most

7.27b

pressure

of

rating

economical

The

axial

1130

iterations J-55 or

is

is

and

lbf

of

Sec

given

by

is

p1A5i P2L.AS2

in

collapse-

7.6 The

Table

psi

portion

tension

FaWiLi w2L2

further

available

pipe

853000

of

7.4

F4 F2 F5

for

which has an JD of 12.6 15

casing

bottom

the

at distance

for calculations

strength

for

diagram failure

internal

54.5-lbm/ft

pipe-body

1yield

by

the

free-body

shown

in

Fig

p31iA53

56400

68l24061L2 8375661L2 1.989

0.9894550002.991

and

1206

the

4000

L2

24.89 See

The upper Table 7.5 13.375-in

of

limit

Because

casing

is

the

mode

transition the

0.480

wall

of

thickness

Table

7.6

the

failure for

is

37.21

Table

The

68-lbm/ft

actual

daft

meet

than

27.86

most

the

will

burst ft

use range

for

the

by

given

transition

mode

of

1240

calculations

61-lbm/ft

string

economical

for

further

requirements

meet

than

pipe

the

716

casing

in

available

was determined

Furthermore

not

more shallow

the

for

which

casing

2933

casing

0.480

within

is

1879Pcr

7.11

next

48-lbm/ft

13.375

is

Sec

iterations

Sec

for

to

which

of

length

0.0360

0.9894550000.0541

the

burst

ft the

for

depths

J-55 or

is

upper

it

K-55 54.5-lbm/ft

will

716

not

more shallow

requirements

Thus

H-40

previously

be ft

for

depths

necessary of

the

to

casing

339

CASING DESIGN

The

third

tension found

to

in the

step

design

casing

the

satisfy

burst-

and

ments The design-loading ified

be

to

while

contains

shown

in

section

is

check

to

preliminary

condition

when

Joint

Gouge

require

68

was spec

tension

for

run

is

the

design

for

K-55

the

Fig 7.28 The

of

lb/ft

welibore

the

mud

diagram

given

the

collapse-strength

casing

9.3-Ibm/gal

free-body is

the

be

will

design for

requirements

tension

tension

axial

calculations

design

top of each

at the

by

FanEWiLipiAsi where

68l24084320 lbf 6182250142 lbf 54.5l22266599 lbf 6171643676 lbf

w1L1 w2L2 w3L3 w4L4

s2

P3

s3

s4

The tension diagram ed

by

tensions of

the

force

hole near sults

shown

tension

the

Fig 7.29

in

ance extra

joint

of

the

ameter

that for

its

the

ances

are

Sec

conditions

selected

by

caused

economical

of

can

also

by

7.12 An at

specified

can

drift

because

is

of

should that

casing such

has

close toler

would

option

below

bit

the

be

probably

Fig

size

burstWhile of

be

These

shock

considerations

design

casing

and

collapsethese

all

important additional

loading

loading

and

should

loading

changing

were

axial-tension-

conditions

strings

casing

p1 Asi

surface

more commonly

would

features

for

pass casing-

generally

when

drilling

toler cause

mandrel

or order

the

gauge di

the

certainly

the operator

bit

calcu

manufacturers

drift

for

is

Table

from

bit

12.25-in

since

design

student

be

meet

also

Design Considerations

in the

the

select

casing

oversize toler

is

is

that

mandrel

bit

variety

this

loading conditions portant

bit

this

diameter drift

previous section

on

the

than

However

12-in

Special

the

pipe-body

will

used Another more conservative

for

based

K-55

two re

minimum-ID

as

shown

better

in

calculated

than

has

casing-drift

greater

available

7.5

or

lb/ft

bore

the

clearance

bit

casing

use

While

bits

However

used

for

less

is

length

use of

the

the

summarized

clearance

an oversized

casing

In

bit

experience

shorter

passed

the

diameter and

bit

is

string

imperfections

check

be

the

the

minimum-ID

oversize

caution

61

load require

with the most

complete

to

design

the

casing

for

wall

is

compared final

Note

ance

design

The

top of

that

J-55

mul

available

the

and

lated

tension

indicates

load even

section

by

the

and

strengths the

to

lbf

in

of

larger

collapse considerations

design

connectors After

joint

Mud

and

lbf

l0O000-lbf

adding

the

7.6

lbf

each

at

was stuck

casing

the

Table

in

given

from burst and

ed

1.6

lb/ft

lbf

was obtained

or by

selecting

of

Comparison

tension

line

K-55

or

was construct

Fig 7.29

in

axial

the

assuming

bottom and

strengths ments

the

The tension design

boundary tiplying

shown

of

computation

pulling

54.5

O.0529.34000l9.44537614 0.0529.32760l.9582613 0.0529.3l 938l .974 1850 684 0.0529.3716l.974

piAi P2

J-55

are

im

other loading be recognized conditions

internal

can

pressure

7.28Free-body

diagram

for

tension

load

line

APPLIED

340

TABLE

7.12SUMMARY

Interval

Length

Weight

ft

ft

Grade

27604000 19382760

1240

C-75

68

LCSG

12.259

0.009

14.375

J-55

61

CSG

12.359

0.109

14.375

3.125

7161938 34716

1222

J-55

54.5

CSG

12.459

0.209

14.375

3.125

J-55

61

CSG

12.359

0.109

14.375

3.125

C-75

68

LCSG

12.259

0.009

14.375

3.125

OF EXAMPLE

CASING DESIGN Maximum

Coupling

Diameter

Clearance

OP

Clearance

in

in

in

Depth

Section

Bit

size

Hole

casing

size

1132

17.5

is

682 34

in

or 0.031

no

in 3.125

be

may

26

thermal

effects

subsidence

some cases

In

practices

criteria

Coupling

washout

pressure

landing

design-load

822

lbflft

in

is

external

changing and

1225

is

tolerance

Bit

Bit

Drift

034

Joint

Top

ENGINEERING

DRILLING

additional

values

ed

modulus

Youngs

for

this

steel

and

substitut

are

density

becomes

equation

appropriate

78Ozv 7.5.1 Shock

shock

Significant is

suddenly

locity in

ory

resulting

Axial

by

the

develop

stresses

sudden

following

valve

from instantaneously

from

result

closure

ve

sudden

the

where loading

loads

7.5.2

Changing

In

previous

the

on

shock

load

modulus

1v

is

change

the

and

is

in

change the

axial

in

stress

pipe velocity

density

of

steel

Internal

curring

caused is

by

the

Youngs

After average

stand

of

life

this

both

Ibf

internal

operations

the

pressure because

of

sure of

cement

the

and

slurry

wall which

casing

creates

Fig 7.30

have

the

if

can

cement

the

to

the

consequences

pump

causes

casing

an

end

The

placement

by

the

if

of in

the

also

apart

recog

is

field

per

This can cement

is

displacement

an attempt

com

to

surface pressure

load given

axial

but

casing

limits

especially

increased

is

pressure

the

are neglected

the

toward

pres

stresses

casing

generally

burst

the

hoop

the

tendency

within

harden

cement

the

burst

to

exposed

pressure imposed

to pull

loads sometimes

axial

disastrous

plete the

While

and maintained

beginning and

stress

hydrostatic

creates

burst

to

stresses which tend

axial

sonnel

tend

is

casing the

slurry This not only

the

displace

nized

in axial

has been

pump

the

3001 in the

significant

landed

and

to

the

However

cause

changes

oc

with

to

bursting

the casing

after

during

selected

can

also

These

and

during

was

without

were

pressure

and

operations

pressure

stress

in axial

changes

high 2001

pipe

conditions

internal

anticipated

pressure

internal

During cementing

1001

in

Pressure

well Casing

the

internal

in

occur

AXIALTENSION

shock

that

changes

design-loading

well-control

during

changes

ed

section

maximum

the

producing the

modest

casing

7.26a is

Note

ft/sec

for

velocity

based

where

in

is

not severe

is

normally

1v

and

in psi

is

the

Elastic

shock

axial

stopping

string

water-hammer

to

for

equation

casing

if

manner analogous

in

pipe caused to

can

loading

stopped

changes

leads

7.26b

Loading

inside

by

7.27 where

the

is

nor

the

that

sets

rating

ceeded

Cement

out

more

far

causes tends

an to

the

casing

casing Fig

7.29Graphical load

representation

of

sample

tension

response design

is

may to

Hooks law

up

of

rating

inside

the

in

the

be

changing this

can

to

casing

cemented and not

free

be

to

in

in

contract

is

the

or

repaired pressure casing

internal

pres

in the

once

wellhead to

elongate

According axial

ex

drilled

However

pressure

chanees

be

the

thus

elongate

landed

internal

cause

can

in internal

reduction

neither

casing can

stress

tangential

Similarly

cause

the

casing

casing

parted

that

ensure

to

Fig 7.31 an increase

increase

to

tension

must be exer

Caution

casing

operations

than

easily in

contract

sure tends 62386

the

burst

As shown

lbf

of

cementing

the

-37614

ID

cised during

stress

the in to that

CASING

DESIGN

341

are

Cementing

Head

velop Hooks ed with

law

in

Casing

move

of

is

given

free

helical

buckling

casing

above

was

stress

from

Ce

the less

occur

if

the

were

casing

than

free

to

by

zUr0t

taAs

de

to

was land

casing

steel

the

would

that

strain

the

prevent the

strain

suppressed if

maximum axial

the

strength

yield

The

to

of

portion

ment top and

the

applicable

is

tension

sufficient

occurring

the

to

proportional

directly

7.28

p1A where

Wiper Plug

sr

is

given

a2

of

The sum

other

the

and

ratio

previously

stresses

Cement

Poissons

is

defined

the

are

variables

and

radial

as

tangential

by

ro2pe

Tj2j r02

r12

AeAi

AipiAepe Fig

7.30Axial

stress

caused

by cement

displacement

7.29

stress the

and

in

change in

change

and

radial

internal

given

is

caused

stress

tangential

pressure

by

by

ar at24i Elongation

This

would

cause

axial

an

strain

given

by

2---p where

the

given is

in internal

prevented Hooks law

and

pressure is

in

If this to

applicable

stress

tensional

axial

an

decrease

sign denotes

negative

increase

given

length

for

entire

strain

total

strain

the

by

2-p would

develop ratio

Poissons to

force

axial

Substituting for

steel

an

average

and converting

value

from

of 0.3 axial

for

stress

gives

7.30

Fa0.471d2APj Contraction

where INTERNAL IN

PRESSURE TENDS TO CAUSE INCREASE DIAMETER AND DECREASE IN CASING LENGTH

Eq

CASING

7.31Effect

of

internal

pressure

on

axial

stress

positive

increase 7.30

pressure in

Fig

the

given

face

internal

was derived

over

pressure

sign denotes in

in

pressure

given well

When

usually the

increase

uniform

for

length

an

in

tension

for

pressure change

is

caused

in external

uniform

interval by

pressure change

change is

not

change in

sur

uniform

342

APPLIED

Eq

7.30

can

of

the

general

be

still

sure change

the

as

applied exposed

average

long

pressure

the

as

change

known

is

given

is

pres

average

interval

length

have

that

In

hole

washout

by

been

when

Eq

from

7.33

for

of

washout

be

casing

known

be

must

bore

the

because

greatly

resulting

employ

to

clearance

radial

ENGINEERING

especially

increased

enlargement

difficult

it

the

cause

has

Borehole

makes

also

buckle

to

tendency

diameter

DRILLING

7.31

710

Example tension

With

this

mud

in

change

the

relation

average in

density

for

pressure change well

vertical

is

being

of

is

1.3

0.O52ApL

cemented

If

to

of

the

depth

be

as

though

the

entire

In

additional

the

borehole

and

would

ling

wall

helical

The use of

midpoint

the change

356154

pipe of uniform

buckling

Fb

force

Eq

caused

by

Hooks law by buck

to

Lubinski4

stress

cross-sectional

given

of

the

area

the

shown

has

change

pipe caused

by

7.5.3

based

on

mud

the

cementing

uations

operations

sometimes

pressure can

be higher

Fb

in

When the

borehole

confining

clearance

radial

and

Fb

between the

is

the tube

and

force

buckling

at

the

flow

casing

is

the

tually

cement

the

Goins15

introduced

the

following

for

equation

the

force

will

density of in

place

portion

FbuF5Fa

When

7.34 the

called

and

force

stability

defined

is

by

FsA 1pA

0p0

7.35

of

the

mud

of

the

casing

ice

to

above

tive

sign

increase or

sure then

the in

Eq

7.33

in internal

decrease

buckling

will

.Lbu at

point

denotes

in

sion

to

to

ing

buckling

evidence

operations

is

that

total

caused

calculated

is

decrease

tension

axial

not occur

in

and

in

length external

Fb

If

Eq

7.33

by

is

no

buck

The nega for

case

ternal

confining

depth

of

In

an

pres

negative longer

in the

has

in

Sec

7.5.6

casing

strings

Dellinger casing

much more

it

wear severe

and that

is

generally

in sufficient

McLean6 results

in sections

from

de ten

tion

to

string

to

terial

drill

is

of casing

the

is

should

for

the

thaw

alternate

of

pressures

the

have

water been

during

as

used

freezing

As

conditions

permafrost

limit

upper

overburden

the

be used

build excessive

can

models

flow an

salt

of

of

the

stress

to

water

fluids

an

that

pockets

the permafrost

outside

the

environment

from

oil-base

remove

simple displacement

fluids

completion

in this

them with

difficult

and

of pore

practice

must be given

concern

mud

water-base

all

replace

in

water

ver

average

salt

expansion

local

sections

usual

anticipated

main

the

even

full

the

collapse design

computer

pressure

freezing

The

by

volume

maximum

plastic

bed

salt

permafrost

pore

account

freezing

extremely

have

through

the

Thus

can

that salt

ex

at

the

to

the

interest

displace

and is

of

the

penetrating

the

the

permafrost

possible

to

land intermediate

prevent

presented

the

decrease

pressure

meaning As will be discussed sirable

is

Fb

which

set

transmits

it

pres

stress

axial

the

well

the

external

that

casing

in the

density

of

the into

the

above

Complex

determine

to

which take The length change

is

freezing

turns

to

sec

which can

formation

salt

assumed

until

plastically

pressures during it

be

This

plastical

whether

in

changes

mud

flow

changing

through

sediments

the

depending

should

stress

casing

and

ing is

creep

overburden

tical

set

it

plastically

on

sit

through

permafrost

in Also

significant

set

can

ex

this

Other

the external

by the is

that

salt

through

freeze

shut

is

result

sure can

is

or

producing

as

set

is

and

when

casing

during

withstand

caused

that

when

such

casing

thaw

alternately is

than

casing

was selected

encountered

were

pressure

the

could

collapsing

are

of formations

external outside

that

Casing

most commonly

occurs

for left

density

pressure without

ternal

Pressure

conditions

Design-loading

8EIw

where Er

psig

External

Changing

tions

by

7.33

ling

yields

alone

take place

to

p292I

ly and when

where

7.27

of

accommodated

of is

law

level

According

length

Lr

buckling

lbf

356154 p1r12.4592/4

suffi

confines

the

strain

stress

in

behavior

Hooks

by

in

not

strain to

landed the

within

some

permit

pressure

been

not

governed

would

of the

effective

top of

is

permitted

would

were applied over

buckling

of the casing

internal

portion

for

the

force

change

the

shorten

to

L/2

at

by

at

tendency

has

casing

would be converted

that in

total

not be

reduce

in

the

the

prevent

bending

the

change

to

would

helical

only

The

occurs

pressure applied

that

tension casing

The

well

vertical

pressure can

cement

the

axial

the

factor

safety

pump

sur

of

weight

and

surface

and

the

length

event

the

cient

pressure change

interval the

caused

effective lbf

in

from

suspended

the

displace

853000/1.3300000 Thus the average in mud density in

is

300000

is

how much

safely

The

Solution

7.32

lbf

supported

ID of 12.459

an

having

853000

desired

applied

xdx

of

being

casing

be

0.052zip

while

face

Casing

strength

all

the

the

process

of water-base

region of the

is

to

attempt strings

However

water-base and

addi

outer casing

casing

fluid

of

in

it

generally

material

well An

it

ma

may re

additional

DESIGN

CASING

343

where

the

is

axial

an

external

in

Hooks

prevented

and

sign denotes

positive

increase

given

law

increase

an

applicable

is

length

for

strain

entire

to the

total

strain

of

compression

stress

Contraction

in

the

If

pressure

Ae A5

would develop and

steel

of 0.3

Substitution

from

conversion

axial

Poissons

for

stress

to

ratio force

axial

a0.47ldn21Pe where

the

to

posed

the

tension

cient

tion Elongation

7.32Effect

external

of

ii Example in is cemented The mud

mud top

is

to

successive

design

casing

the burst pressures of successively than

the

collapse

desirable Axial

than

collapse

stresses

also

after

pressure of

mud

the

As shown

in

increase

cause of

the

nal is

diameter of

the

casing

the

pressure may cause cemented and landed

tension

to

sure

As

pressure

discussed this

proportional gives

the

change

in

to

can

in

it

axial

and

not

for

to

tangential

axial-

the

could

the

cement

ten

in sufficient

maximum

change

over

result

formations

the

10.75

compute of the from degradation time The pore pres long period of

buckling that

of

14-lbm/gal

above

landed

was

casing

OD

an

containing

outside the casing

left

If the

mud

14-lbmlgal sure of

well

in

area

this

is

to

equivalent

density

Solution

that

Assuming

mud

of

14-lbm/gal

age

pressure change

external

the

of casing

interval

decreased

to

9-lbm/gal

pore

Eq

7.32

and

the

be

If the

0.0529

may

exter casing

The change

148000/2

1040

in axial

caused

sure change

con

to

in

is

stress

given

Eq

by

aver

average

pres

is

psi

by

7.36

this

as

56607

040

_0.47ll0.752_

AFa

lbf

pres The

internal

are

stress

the

fluid

sufficient

free

develop

by

the that

length

in

external

that

given

on

time from

pressure

with

directly

Eq caused

7.29

positive

increase

sign

56607

by

indicates

that

because

lbf

the

of

force

axial loss

the

in

would

external

pressure

by

as

7.5.4

Thermal

Effects

The

example

design-loading

Ae

2Pe

r0t

A5

presented in

Substituting

addi

in

used

effective

the

having

string

vertical

i.e

This

changes

stresses

be

suffi

in

relationships

pres

stress

under

changing

strain

pressure

external

shorten

may

to

suppressed

external

degradation

reduction

the wellhead

previously

in radial

change

in

decrease

to

casing

in

response

cause

the

force

casing

external

stress

Similarly

buckling

prevent

or elongate

tract

casing

the

more

prevent

in axial

9-lbm/gal

tensional

to

landed the

would

7.35

Eq

change

pressure

buckling

estimate

in

change

string

by

increase

compressive

increase

to

average

has not been

casing an

For

degradation

relationship

in is

ft

to

8000-ft

caused

in tangential

in tangential

Even

common example

completed

Fig 7.32

decrease

are

less

is

it

from changing

is

that

strings

innermost

the result

the

strings

inner

undesirable

is

pressure

outside

left

sure causes an

is

external

changing

of

well

the

of

can

larger

the

of an outer casing

burst

though

of

pressure

so

strings

8000

at

sion precaution

mud

pressure

IN

stress

axial

on

pressure

to

7.31

for

ex

length

average

Eq

the

tension

the pressure

casing

the

from

helical

prevent

stress/casjfllY..stretch

DECREASE EXTERNAL PRESSURE TENDS TO CAUSE AND INCREASE IN CASING LENGTH CASING DIAMETER

Fig

compute the casing

Eqs 7.33 through Hooks law to

in

given

to

resulting

to

that

event

entire

then

in If

pressure

the

computed with

density

be used

can

In

be

mud

external

7.32

over

pressure increase

can

change

decrease

external

average

not constant

is

change

in

7.36

sign denotes

negative

increase

an

for

gives

this

expression

into

Eq

7.28

yields

did not consider

temperature

in the ing

the

lie

glected not

after

wellhead life

of

the

casing

Temperature the

However

small

the

well

usually

when

resulting

conditions

axial

the axial

stress is

previously

caused

by changes

cemented and

changes

are small temperature stress

landed

dur

encountered

must

and

can

he

variations

be

ne are

considered

344

APPLIED

in the

of

iations

include

recovery

wells

that

in

completed wells

with in

pleted

ball

volume

The

from

time As

surface

thermal

imposed

extract

tion

arctic

arctic

tensile

stresses

pro

of

Both

strain

mined from

the

for

these

in the

vari

change

temperature

thermal

coefficient

The

axial

of expansion

using

In

6.67x106/F landed axial in

Thus

in sufficient stress

axial

tension than

less

is

stress

the

if

is

to

the

given

casing

the

of the

strength the

7.5.6

Casing Landing

strain-limit

then

steel

and

ample

conditions

axial

landing

the

if

stress

by

stress

to

7.38 force

axial

yields

be

to

modulus with

to

casing

the

exceeding In

practical can

be

this

applied

in the

for

presented did

when

it

ex

the

addi

not consider

casing

the

axial

an

landed

is

the

common

four

lowing

the

when

is

with

for

the

was

tension

in

casing

considered

to

with

the

design

at

was

that

completed freeze point

the

be

fol

the

casing

same tension

the

cement displacement

generally

casing

identified

landing

in

followed

is

in the

axial

landed

is

it

practice

committee

methods

casing

additional

when

casing

the

throughout

significantly

considerable

study an API

early

which

in

placed

Landing

7.39

vary

cases

Obviously when this stress must be considered

wellhead

present

Fa20OAsLT588WT

the

concept

previously

practices

be

will

the

In

an

may

tends

Youngs

not be

calculations

placed

some

In

Landing this

Converting

for

is

change

2O0zT

azEcxT/T

forma

subsiding

loads without

design

casing-design

stress the

value

designing

steel

case

Casing

buckling

sections

yield

industry

stress

low

subsidence

large

cemented and

is

prevent

yield

for

also

is

gives

from subsidence

resulting

with

soil

permafrost

stand

tional

of expansion

coefficient

law

strain

deter

is

7.37 thermal

in the

completed

Hooks

stress

in soft

greatest

The loading

The average

casing

are

jz

ratio

this

7.41

the

of

strings

axial

that

Efl/if

well

being

compaction

occur

Poissons

EjApl 21ajl /.f

thaw

the

oil

the

applying

com

the

around

warm

the

on

and

Ef

Assuming

wells

wells

regions

modulus

formation

the

and

offshore

and

result

and

for

in

earth

subsidence

used

in

gas wells

In

where Youngs

used

permafrost

flow

compression

casing

the

var

wells used

lengths

hot areas

heat

and

local

wells

deep

melted

grows with

induce

of

areas

riser

of

radial

formations

ous

volcanic

permafrost

Ex

procedures temperature

large

geothermal

significant

by

duced

encounter

steam-injection

abnormally

or

caused

casing-landing

will

processes

steam from

ing

and

casing-design

amples

ENGINEERING

DRILLING

the

at

top of

the

cement In

the

estimate

the casing

has not been

landed

in

suffi

the

Landing to

7.35

through to

that

event

tension

cient

helical

prevent

would

the

be

used

effective

then

buckling addition

in

Eqs Hooks

to

7.33

stress

law rela

axial-stress/casing-stretch

casing

at the

Landing

neutral

of

point

axial

freeze point

the

in

casing

freeze

the

at

compression

point

tionship All

may

It

stand the

not always

extreme

is

loading

When to

this

than

stronger

inelastic

so

the

and

design

is

the

body

stretch

failure This

joint

close

thereby

be

the

stress

second

and

considerably

ceed

12.5

limiting

called

preventing strain-limit

wells

all

concept

and where of

are

The

which

Subsidence

Compressive and

vere

Effects

axial

However

significant

times can

result

subsidence

tion

of

the

can

axial

strain

producing

in

fluids

well

in

caused

by

formation

is

and

can

completed

pressure given

design

2Lfl

the

be

through used

drop

because

depletion

also

to

some

for

of

caused

by

casing

permafrost

Lf

below

cases

within

the

ment over not

cy

/Zf

to

the

buckle

exist and cessive

factors

the

to

has

used

are

strings

loads

landing

wells

for

with

selected

being

buckle

above

ex

not

outer casing

to

the

in the

pre

freeze

withdrawn

recently

recommended

not have

above

be

the

entire the

at

study

freeze point

the

Excessive

present top of

when

the

cemented firmly

point

above

that

and

borehole

that

the

ce

determined

They recommended

the

some

washout

when

was

so

buck

in

wear was ex

casing

interval

linked

helical

cement and

whenever possible

any

with

operations

point

casing

casing

performed

drilling

freeze to

the

support

point

API

McLean16

below

drilling to

casing

just

was determined perienced

and

proce

first

does

practice

and

of casing

the

by

freeze

of

wear during

casing ling

at the

because

the

are anticipated

weights

the

by

density

recommended

currently does

it

landing

Dellinger

estimate

7.40 E-l

tension

D-7

Bulletin

ing

Lpl

mud

However

point

Forma

formation reservoirs

se

not

is

casing

loading of casing of

sometimes

equation

the

volumetric

Subsidence

cycle

approximate

occur

generally

in

compressive

of pore

pressure

thaw/freeze

An

of casing

neglected

from subsidence

production

mation

be

was

in the

study committee18

withstand

to

the

two procedures

first

design

equipment

procedure

excessive

mud

the

within

how much ten

to

freeze point

the

standard

strength

vent any tendency

loading can

usually

where

welihead

the

second

which

in

sufficient

amount of 7.5.5

as

The

procedures

lbmlgal

17

new

at

they place

fourth

used

still

commonly used The API recommended that be landed casing in

effectively

are differ

operators

are most

dure

body and

is

de

can

procedures

addition

sion or compression

must be given

are

joints

type of design

relatively

limit

attention

the pipe

to

exceeding

general

In

industry

temperature

casing

yielding can

that

pipe

pipe

the

process

however

selection

joint

the

done

is

Because

these

with

to

casing

without

variations

that

way

design

material

the

limited-strain

such

in

signed

of

to

practical

temperature

strength

yield

be

no

freeze point

land tenden would

effort to prevent making every economical ex washout However they pointed out that placing

CASING

DESIGN

345

TABLE 7.13INTERMEDIATE

CASING FOR

Depth

Internal

Interval

Section

Length

ft

620010000 18006200

01800

tension

enough vent

comes

stuck

suspension

tem

used

is

in

point

the

before

the

can

it

nal

the

is

mord expensive be

formed

the

15

Goins for

has

the

has presented

the

be

casing

needed

on

the

sys

F1

freeze

the

ity

and

that

felt

and

stability

of

tension

7.12

composed

of

10000

in the

casing

F2

at

of

plot

Eq

and

make

of

This

tendency

the

of

of

the

at

where

point

the

perature

30F

in

the

the

over

the

casing

axial

F4

placement

Solution as

593

The casing

in

lbf

59.187

lbf

bottom

bottom

by

to

7.13

l529l.105-i690

.30660.201

ibf

is

bore

the

time

of

to

stability 15

cement

analysis

The

casing

after

will

pressure

Section

40.0

lb/ft

Casing

at

was

15.7

acting

Cement

lb/gal

Slurry

plug

performed

forces

Mud

after

operations

be

lb/gal

cement

cement wiper hardened

vertical

10.0

by

the portion

buckle

drilling

was

mud

Also be mud tem

the

present

the

cement-

borehole

lbm/gal

surface casing

the

Goins

the

the well

determine

tendency

the

when

graphical

recommended

800J6l

10-ibm/gal

circulating

initially

the

when

temperature

during

that

16

the

analysis

and

from

to

depth

have

may

to

ft and

from 10

well

as

string

Subsequently

15000

of

average

Assume psig

in

412I

string

Table

was run

p4

2000 ft of lS.7-lbm/gal cement as cemented i.e with the same

stability

ft

reached

187

with

temperature

15000 at

11

0.05210l

point

casing

an average

the

that

neutral

having

the top of the

cement

held

lbf

and

tangential

well

deeper

raises

the

intermediate

vertical

depth

ing Perform of

2A

38l71.0143870

neu

the

and

radial

the

the

in

was increased

of

1A01

bot

and

line

shown

reached

to

density cause

by

579359 187 342870

of stabil

three sections

in

ft

tension

deepened

was

forces

force

7.35

location

below

occurs

9.625-in the

cemented

plug

slurry

that

the

axial

plot

load

the the

is

the average

to

The casing was landed

wiper

cement

the

0.05210l000059

proce

string

casing

from

determine

to

hole diameter of 13.0

axial

of

Fig 7.33 The hydrostatic

to

use of

the

graphical

the

make

section

of buckling

equal

and

in

F4 are given

may sheath when

cement

force

intersection

line

Example

mud

placement

depth the

The buckling

at

when shown

5792.872.760 421484

the use of inter

stresses

set

13.573

microannulus

the

portion

force

top of each

vs

point is

12.559

72.760

pressure on

They

requiring

addition

axial

the

stability-force

stress

11.454

O.052lO6200j60.201

Locate

tral

72.760 72.760

cement

maximum axial

section

the

Determine

force

is

through

depth

bottom

61 .306

60201

casing

completed F1

sq in

in

loads

suspension

maintain

internal

thus

pre

casing

and

because

and

to

point the

the

the following

the

tom and top of each vs

59.187

A3

sq in

sq

buckle

to

tendency Determine

8.681

Area

A0

released

is

determining

47.0

best

casing

pressure

C-95

hardening

the

in

8.755

is

subjected

casing

between

internal

dure

cement

may increase

casing

8.835

43.5

circulating

or holding

more cement was

pressure

which

the

40.0

C-95

bottom

recommended

they

in

Area

C-95

freeze

to

Ibm/ft

Steel

External

Area

3800 4400 1800

landed

it

while

the use of

be

Diameter

Grade

because

7.12

Internal

Weight

It

not permit

will

e.g when an ocean When is impossible

tension

casing

the

impossible

more shallow depth

to

at

casing

often

equipment

be applied

to

in

was

buckling

EXAMPLE

Fig

7.33Forces slurry

acting

on

casing

after

placement

of

cement

346

APPLIED

The

casing

W1

weights

W3

through

are given

With

by

W1

380040

W2

440043.5

152000

lbf

lbf

of

endpoints force

axial

each

vs

section

calculated

made

is

depth

shown

as

7.34

The next 191400

of

plot

Fig

in

force

the

above

ENGINEERING

DRILLING

ty

force

by

Eq

in the

step

7.35

of

The

depth

the bottom

at

determine

to

is

analysis

function

as

of

the

the

float

stabili

force

stability collar

given

is

and

p1Aip1A01p1A5792.8l3.573 l8004784600 The

graph

axial

balance the

casing

above

the

float

of

the

float

is

constructed and

string

sections

collar

collar

depth

casing

successive

for

below

vs

force

bottom

at the

starting

force

of

lbf

upward

421484

is

by the

solving

lbf

The force the

and lar

since

The

force

12

Pi

the

78626

also

is

force

axial

78614

at

the

force

axial

73386387069516 and

the

force

axial

at

the

the

the top of

at

the

axial

force

at

Sec

force

stability

at

at

Sec

187

is

the

lbf

of

top

Sec

is

8861

the

Similarly

force

stability

lbf

the bottom

at

Sec

of

is

381760.201 322472.760 bottom

the

of

Sec

4791

229787234578

is

and

the

force

stability

at

lbf

Sec

Sec

top of

the

is

80072.760

52960.20

top of

25922684600343826

is

920476810323944

lbf

the

Finally

force

stability

lbf

bottom

the

at

52961.30668 10325634

Sec

of

is

lbf

1000/b

FORCE -00

is

187

225917234578

lbf

the

the

381759

is

lbf

2609161690259226 and

cement

the

21366

281316302682 and

of

top of

force

axial

is

lbf

69516191400260916 Similarly

Sec

lbf

the bottom

at

col

float

lbf

top of

7861415200073386 The

the

is

421484342870 the

force above

stability

0.052l08000j59

and

lbf

lbf

force

stability

78626

100

200

300

400

and

the

force

stability

at

Sec

top of

the

/0

is

STABILITY FORCE AFTER DEEPENING

FORCE CEMENTING

STABILITY

2000

59361.30636354

//

WELLTOI5OOOFT AFTER

I8O0 When

the

AXIAL

AFTER WELL

/ax 5581

AFTER

i//f

FT

NEUTRAL BUCKLING

6000

WELL

POINT AFTER TO

5000

FORCE DEEPENING TO 15000

and

the

sure

6200

-25O2

lbf

105371

of

axial force

and

assume

collar

10000

stability

force

vs depth

the

plotted force

bottom

the

at

of

occurs

the

casing

Note

pressure needed

mud

in

for

Note

also

that

does

for

Ex

hydrostatic it

after

after

cementing

was deepened

from 10 by

begins that

to

30F

pressure

the

the

example corre

the

not

the

to

same

15000

axial

pres amount of

pressure between above

lose

its

bottom

axial

force

was landed However

16 Ibm/gal and

this

internal the

calcula ability

of

the

to

float

harden

to

had

to

the

that

hydrostatic

cement

the

by

straight

buckle

to

tendency

significant

be held

difference

that

The casing

hole

7.34Plot

the

no

is

will

internal to

transmit

as

ample 7.12

collar

are

stability

tbf

4OIbIft

Fig

and

cement hardens

the

cement and

tions

-.cAsuNGsEAT-

oooc

float

Fig 7.34

in

force

axial

there

casing

until

surface

the

CMENT .-

the

Thus

string

sponds 800C

the

lb/ft

FORCE CEMENTING OF DEEPENING FT

at

essentially 43.5

forces

stability

of

intersection

4000

lbf

the

ft

the

average

stress

mud

at the after

surface

the

bore

density

increased

temperature

increased

was changed

To estimate

CASING

the

DESIGN

its

lower axial to

in

change

change

axial

end

of

the

original

ial

stress

First

in

F4

and

F3

forces

casing

change

lower

above

given

end

the in

change

of

the

The

to

casing

assuming

the

net

computed would change

the

cement

would cause

the

i..L

the

to

casing

various

the

totalling

in length

change

is

Thus

changes

length

is

two

in

1.60.603

0.02290.01140.9627

ax

ft

ways If

in the

changes

can

buckling

be permitted

by

0.0526200l6_

for

tendency by

casing

hole

AF3

net

obtained

be

will

pressure

pressure

the

The

move

to

the

then

in internal

calculated

free

is

return

position

in the

the

to

of

tendency

be

first

casing

required

The increase

the

stress will

length

stress

its

347

l0l .014 1961

lbf

wall

decrease

occur

by bending and

in

the

axial

of

portion within

be

will

remainder

stress

this

of

bore

the

converted

to

Hooks law

to

according

will

elongation

confines

the

This

gives and

EA

F4O.052l8OOl61O11O5621 The change

in

F3

might

Sec

cause

to

shorten

L1

by

See

0.0229ft

ed

12.55930x106 sum of the change

the

Similarly cause

and

19614400

A5E

shorten

to

and

F3

ALb

and

is

the

the

is

J..Le

length

effective

converted

steel

age

in

area

to is

1800

13.57330x

Second ft

cause nal

increase

the

would

increase

the

to

casing

pressure

is

the

and

shorten

The length change pressure

stress

The average

Eq

by

7.31

8000

change

and

thus

in

inter

Eq

In

sq in

7.33

the

in

change

length

permitted

by

buck

is

ling

Ar2Fb

as

8EIw

1248

associated

8000

pressure above

tangential

13.573

8000

12.539

average

l08000/2

0.05216

nal

in

1800

12.559

ft

106

radial

given

0.0114

buckling

by

4400

l1.454 800

in axial

decrease

by

was prevent tension The aver that

F4 might

by

6211

permitted

change

length change

given

8000 1961

AL bu

0.603

where LIF3L

-EA

lbf

psi

with

this

change

in

inter

Assuming then

tion

is

that

the

buckling

occurs

clearance

radial

in the

only

bottom

sec

is

A1

zL3

139.625 1.6875

where

the

A1A

average

ratio

above

the

cement

is

and

80006200

of

moment

the

inertia

from

Eq

7.16

is

61.306

11.454

8000

in

sq

I9.6258.835l22.2

in.4

64

f4400\

/60.201\

/l800\

\12.559/

\8000/

II

\8000J

II /59.187

Substitution

\13.573

AJbu

of

these

1.6875 Solving

AL3

the

length

change

34 821

280000

2Fb

0.9627

and

ft

the

change

in

axial

force

30x iO

30X106l2.539 The length change increase

is

given

by

vIAT6

caused

Eq Ef7Y

by

7.37

the

the

expression

2.427x102F

830X106122.240

gives

1248

into

average

AFa

temperature

8000

as

1fl6R nnnirrn

--

icon

ft

for

yields

0.2255.3520.554.7930.2254.364.82 for

values

vffl

tS1r 47v

can

be

expressed

by

bu

348

The

force

axial

at

top of

the

cement

the

The

is

FaFao/Fa

be

to

Sec

of

the

7.34

force

at

the

top

1.306

81662

lbf

at the

top of

cement given

the

force

stability

at

bottom

the

Sec

of

is

by

is

Fb

Fa

Since

cement was deter

the

stability

107Fbu2

1.142x

force

buckling

The

106200172.760

The

Eq

top of

the

lbf

6620016

l.l42xl07FbU2

and

at

105371

is

786 14 2000401 28354

26968

force

stability

mined

ENGINEERING

DRILLING

APPLIED

the

Fs 26968 force

stability

at

l.142x

the

top

of

76273

lbf

22052

lbf

l07Fb2 cement

the

and

Sec

top of

the

at

is

16

is

1800160.201

.306

l0 1800172.760 408053302682

105371

the

Similarly

lbf

force

stability

Fb

105371269681.142 l32339l.l42x107

upon

Fb

and

Fh2

the

at

the

lbf

of

plot

force

axial

the

at

top of

Fb

lbf

force

at

the

Sec

top of

at

the

force

top of

at

bottom

the

Sec

of

rate

of casing

and

tripping

the

conditions

Note

the

That

have

to

the

top

can

be

ex

depth

casing

lines

will

casing

wear

the

force

axial

this

in this

interval

If

operations

tension

axial

Sec

25026

105371

lbf

46974 axial

drilling

Thus

The buckled

ft

the

increase

to

and

from

these

7.34

Fig

force ft

for

depth in

helically

8000

lbf

were

it

by

is

25026800062004046974 The

of

result

possible

at

increase

to

pected

5581

buckle

to

vs

lines

stability

of

depth

cement

the

as

axial

at

tendency of

dashed

of the

is

105371130397

25026 the

is

force

stability

with

intersection

cement

the

occurs

Fa

Sec

of

top

059.187072.7600

Fbu

for

solving

130397

Thus

and

is

lbf

107FbU2

was made

and

Sec

of

187

then

and

bottom

at the

when

the

was

casing

130397

landed

the

lbf

neutral

point

buck

of

is

ling

could

and

the

lbf

is

have

been to

tendency

lowered buckle

to

could

the

top of

have

the

been

cement

eliminated

Exercises

41743191400233143

Discuss

7.1

lbf

functions

the

of

the

following

casing

strings Finally

the

axial

force

at

the

bottom

of

Sec

Conductor

casing

is

Surface

casing

Intermediate

233143

161 80011.l05

231488

lbf

Production 7.2 Discuss

and

at

the

top of

Sec

is

plot ft

is

of

shown

axial as

force dashed

vs

lbf

depth line

in

while

Fig

facture

drilling

7.34

at

15000

Name of

of using

liner

rather

than

string

three basic processes

the

used

in the

manu

casing

7.4

What

is

7.5

Give

the

API

and

the advantages casing

full-length

7.3

23148884600316088

casing casing

the

diameter

three length

range ranges

of

API

of casing

casing specified

by

CASING

DESIGN

349

TABLE 7.14PORE-PRESSURE.GRADIENT GRADIENT

Depth

DATA

FOR

Pore-Pressure

It

AND FRACTURE-

EXERCISE

Gradient

Fracture-Gradient

IbmIgal

_____ 1000

2000 3000 4000 5000 6000 7000 8000 9000

7.21

Determine

7.15 depth

of

gram

calls

12.0

9.0

12.9

sist

9.0

13.6

depth

9.0

14.2

9.0

14.8

of

15.5

termine should

9.0

15.2

9.0

15.6

9.0

15.9

could ations

12.0

16.8

10000

14.0

17.4

11000

15.0

17.8

12000

16.0

the

7.17

18.1

the

Nominaj

Drift

and

based

is

on

or

fluid

of

the

following

area Also

seal

on

primarily

metal-to-metal

the

seal

connectors

casing

whether

indicate

thread

use of

the

compound

threads

and

couplings

string

threads

and

couplings

gins

threads

7.8

the

nominal 7.9

weight

the

J-55

10.75-in

of

0.35

in and

for

rating

thickness

of 45.5

collapse-pressure

10.75-in

in

of 0.40

for

ratings

fol

the

40.5

10.75-in J-55 4.50-in

where the

the

internal

is

7.10

fluid

couplings

and

level

oper

would than

rather

threads and

for

of

the

for

rating

condi

in-service the

burst

rating

body

pipe

yield

of

by

couplings

con

extremeline

intermediate

the

and

factors

of

casing

other

safety

7.9 of

design

9.625-in

the

and

and

factors

other

safety

is

casing

the

Complete

be

to

of

design

other

of

casing

production factors

production

mud

wants

company

to

production data

casing and

factors

this

mar

safety

well

complete

are given

Use

well

for this

in

used

margins

safety

12000

at

The pore-pressure7.14 De in Table

casing

program

other

with

Casing

pipe body

is

ported

being

If the

much

displace

same

the

Example

from

lbf

and

the

of

weight

casing of

factor

safety

pump pressure cement The casing

being

1.4

be

lbf in the

while being

surface

the

burst

applied

safely

rated

3130

is

at

has policy of slacking company when landing the casing after internal

cement

pressure

is

after

bumping

the

on bottom Repeat these

for

released

casing

immediately

the

buckling

to

cement

the

wiper

Exam

for

analysis

30%

off

load the

sup

desired

is

stress

axial

Your

7.12

joints

in

strength

629000

can

atmosphere

ple

effective

in and and

surface

hook

ing Also

plug

in the

the

for zero

the

ID of 10.05

an lbf

suspended

240000

is

7.23

10% of

is

60%

the

drilling

long round

same design Example 7.9

450000

of

collapse-pressure

pressure

tension

axial

that

yielding

the

tension of

and

lbm/ft

Exercise

in

foot

per

considerations

7.9

psi

Ibm/ft

corrected

listed

casings

and

J-55

Determine

11

tions

11.6

axial

same design 7.9

complete

design

to

lbm/ft

the

fracture-gradient

how

51

weight

subsequent

same design

6.625-in

cemented

Ibm/ft

casing

P-hO

Your

7.22

11.75-in C-95 60 lbm/ft 1O.75-in

total

mud De

l2-lbm/gal

5.5-in N-80 casing

of by

con

to

Example

in

using

lbm/ft

wall

foot

per

for

thickness

of 40.5

nominal

casing

design

of

the

using

sign

strength

wall

weight

Compute

lowing

yield

foot

per

having

nominal

7.10

connector

the burst-pressure

Compute

J-55 casing and

body

the

the

.0-lbm/gal

used

and

TC-4S

nominal

having

ft

and

two-step

11

7.21

couplings

threads

Bradford

Compute

casing

and

is

to

in

in

ft

Example

in

string

in

run

area

round

Hydril

the

7.20

round

Atlas

in

used

margins

Long

Extreme-line

used

Complete Example 7.7 Use

Short

Buttress

string and

string

run

the

7.19

sketch

th

label

seal

and

Complete

margins

diameter

Make

7.7

and

weight

pro

casing

J-55 casing

1.125 assuming

6300

occur

Example 7.7 Use

weight

Average

casing

collapse-pressure

weights

threads

7.18

weight

Plain-end

what

the

to

drilling

the

if

nectors

terms

following

of

of

as

in tension

buttress

7.6 Define

which

failure Consider

joint

for

well

lbm/ft be

to

is

at

factor

low

as

For

failure

17

because

design fall

and

ft

depth

change

with

of

production

and

ibm/ft

6300

of

needed

size

string

production combination

16

9.0

bit

surface string an intermediate

for

5.50-in

Ibm/gal

the

surface casing

the

conditions

operating

strength 12

Determine

of

joint short

round

300000-lbf al

wellbore

threads

if

the

casing

load

axial-tension

having

dogleg axial

axial

stress

J-55 casing

in

is

of

40-ft

API

of

Com

ft

uniform

assuming

7.13 ly for

only

caused

at

the

casing

and

the

the

P-I

maximum stress

the

that

temperature

by

poor

the

borehole

wall

and

the

couplings

10 casing

Discuss

the

between

of

effect

field

will

that

be exposed

can to

be used hydrogen

safe

sul

150F that

handling

crushing out-of-roundness will

have

on

5AC

Spec

for

on Bull

Bulletin

on

and

Formulas Pipe

Timoshenko

and

Mechanics

Tubing

Casing Tubing Dallas for

March

and

fourth

Drill

1982

Casing Tubing

5C3

Bull

and

S.P

edition

Drill

API

S.P

J.L the

and

Gere

J.N

Co J.M Book

Theory

New

of Collapse

of

York

Theory

Co

Nadia

Problem

Engineering

eighth

edition

Elasticity

third

42123

1914

Goodier Book

and

10

Applied

McGraw-Hill

to

of

API

and

Casing

Gas

May 1985

Calculations

London

ond

Approach

Strength

and

Oil

1985

Timoshenko

perform-

27

Dallas

Properties

McGraw-Hill

edition

Yield

edition

Pipe 1978

Running

and

Properties

18th

Green

Longmans edition

5C2

and 13

API

Performance

Line

Dallas Feb Goodman

Restricted

edition

11th

Holmquist the

Jr Designing 30 and Nov

Specifications

Pipe

contact

Estimate

at

7.14

between

wall and

assuming casing

16

Bulletin

stress

contact

J.F

Greenip

Oct

direction

3/100

References

to

subjected

portion

severity

for

having

Pipe

borehole

fide

40.5-lbm/ft

maximum

the

pute

maximum

the

I0.75-in

of

New

1961

City

Elastic

Stability

York

Theoretical of Deep-Well

sec

1961

and

Experimental

Casing Drill

350

APPLIED

C.N

Bowers

at

presented

of

Design 1955

the

SPE

Casing

Annual

Strings

SPE

paper

New

Meeting

514-G

LA

Orleans

Maximum Permissible head Trans AIME 1961 175 Ii Kane R.D and Greer J.B Sultide Lubinski

Steels

Strength

12

Patton

Corrosion

CC

Failures Gas

Caring

15

Practices

Lubinski

at

length

Drill-String

by

SPE

Strain

the

Trans

Prevents

J.C

burst-pressure

Annual

Limit

Meeting

SPE

paper

3O-Oct

Sept

of l3.375-in

Design

Recommendations

external

Pe

internal

pi

Par

N-80

of

r0

radius

API

xy pipe area

steel

area

outer

under

area

steel

cross-sectional

steel

area

in

enclosed

pipe

in

ID

of pipe

ID

at

outer

radius

coordinates severity

thread

temperature

OD

change

area

of

of

in

joint

coupling

power-tight

box at

end

position

nominal

joint

ID

Pm

d2

nominal

joint

OD

critical

smaller larger

of

made-up connection

of

of

diameter

of of

mud

of

casing

depth

of

lost-circulation

depth

of

mud

Fab

elasticity elasticity

ultimate

yield

for

the

Ffr

F5

F5 Ften

side

wall

strength

axial

stress

maximum

123 axial

force

to

tending

cause

caused

by

sections

bending

SI Metric

buckling

Conversion

in

3.048 2.54

lbf

4.448

222

1.355

818

1.198

264

force

force

at

ft

coupling

force

lbf/ft

force

Ibm/gal pore

pressure

equivalent

gradient

mud

expressed

as psi

6.894

757

psi/ft

2.262

059

density

thickness

moment

of

Factors

F32/l.8

force

tensional

strength

yield

Subscripts

max

ratio

force

stability

strength

stress

effective

also

frictional

steel

tangential

surface

of

stress

nominal

zone

Youngs modulus

force

formation

density

radial

ar

ault

of

equivalent

the

stress

annulus

modulus

force

for

density

steel

annulus

depth

axial

ratio

gas density

formation

Fa

ratio

a1

Youngs Ef

strain

strain

Poissons

box

joint

depth

Di Dm

strain

Poissons

made-up connection

section

diameter

ft

expansion

density

coupling

at

of

angle

thread

d11

d2

radial

Cr

tangential

section root

degrees/l00

coefficient

strain

body

axial

at

pipe of

by

spatial

dogleg

Pg

OD

foot

per

ID

coupling

critical

diameter

by

last perfect

pipe area

steel

OD

enclosed

pipe diameter

d1

axis

Dallas

nominal

d0

of borehole

weight

of

d2

curvature

inner

temperature

inner

d1

annulus

thickness

area

A5

of

d2d1/2

weight

A0

rating

pressure

clearance

radius

Nomenclature

AJAr

rating

4606 1973

72 Ibmlft

D7

Bull

1955

coupling

pressure

radial

1980

in

Instability

Strings

at

collapse-pressure

i.e

Preventing

Casing

moment

Buckling

Feb

Part

moment

bending

radius

Tubular

101

bending

pressure

Tub

and

Casing

threads

engaged

Oil

Pci Tech

.1

Landing

of

of

High-

J.L Helical Buck AIME 1962 35

Logan

Jan 1980

Part

McLean

1973

and

Packers

Intermediate

Casing

Casing

L1 Trans

published

Use

and

Understanding

Oil

and

the

G.R

Wooley Buttress

18

TB

Cemented

presented

17

W.S in

Better

World

Dellinger tially

of

joint

Dallas

Sealed

W.C

Problems 35 16

Bulk

Pipe

Drill

Care

for

Althouse

of Tubing

Goins

Causes

length

L1

Pbr

Recommended

ling

and

of

Cracking

Environment

Oilfield

Fatigue

for Casing

Stress

El

over

length Bore-

Rotary

Journal

ing RP5CJ API 14

and

Laboratory

1483

and

13

in

AIME 1977

in

Doglegs

of

ENGINEERING

Oct

2-5 10

root

square

DRILLING

inertia

Conversion

factor

is

exact

xc

E0l E00 E00 E03 E02 E00 E0l

cm

kJ kg/rn3

kPa kPa/m

Chapter

Directional

Drilling

and Deviation Control

8.1

and Reasons

Definitions

Directional

for

and

thus

hibit

Drilling

shore Directional

drilling

bore

some

along

Deviation

control

contained

within

nation

This

nisms

the

is

of

process to

trajectory

of keeping

process

associated

excursion

discusses

chapter

with

limits

the

wellbore

the

relative

from

incli

to

the vertical

and

drilling

or

mecha

and

principles

directional

target

deviation

control

However

depth

ess The

bit

the

plane

sociated

with

plane

the

as

deviation-control the

be

rest

drilled

form lake

with

the

far

some

the

wells

can

tive

to

may

the

be

be

in the

direction

The

lake

well field

on

are

planes

the

part

be

as

respectively trajectory-

located

could

plane

angles

and

is

drilled

the

being or

almost

en

of the struc

treated

simply

on the shore To de

drilled

however

will

used

drilling

the only

completed

from

economics

attractive

convenient

rig

as the

X-Yplanes

necessitate

than

In

some

of those

site

or

lake

fixed

drinking

would

wells

directional

where

water

sub-

production

standard is

no

well For example for

bed

approaches

situations there

directional

source

floating

drilling

land-based

the

on

in

from land

and

tices

ed

the expanded field

offshore

and been

only

discovered

ing

8.5

of

done

nal

to

producing

8.6

in

mountains

or

or other build

Fig

well

wellbore

existing

is

another

This sidetracking

fish

to

of

may

the origi

in

for

explore

sectors

adjacent

has

see

prohibit

near-vertical

drilling

Fig

see

horizons

centers

economically

as

obstruction

an

bypass

wellbore

Fig

directional

of cases

population

frequently

drilling

out of an

Sidetracking

application be

and

typical

number

drill directionally

such

features

location

to

Off

the majority

shows

8.3

fields

and

oil

promot

drilling for

In

the

obstructions

topographical

surface

Fig

pad and

drilling

Fig 8.4 Natural severe

directional

beneath

develop

to

way

use

to

additional

the

see

field

8.7

is

no

to

each

use of

the

longer

environmental

and

economic

Strong creased

directional

possible

to

Instead

as

in

offshore

built

from which

only

is

directional

alterna

drilling

is

directional

wlonments

being

for

In

some

by

making roads

drilling

increasing

in

situations

has not been

examole

well must

drilled

and In

be

Not pro

trajectory

and

common

directional

be

but

more complicated

applied

pads

drilling

it

areas

near-vertical

drilling

number of wells can

becoming

drilling

field

installations

in

pressures have

drilling

develop and

surface location

the

re

been

of people

other countries

development

prac

drilling

group

has accounted

activities

drilling

have

the

of

application

platform

California

Later discoveries of in

pro off

moti

clearly

directional special

and

development

directional

fields

drillers

was

offshore

fields

for

and

Mexico

Gulf of

in the

gas

wells

for

ground

directional

called

oil

as

facilities

production

The

such

equipment

directional

equipment

are

the

of

economics

by

grams

lake

and

rigs

drilling

that

restrictions

and

vessels

power

were the spawning

drill

The only way vertical wells could would be from vessel floating drilling or plat

and

less

the

proc either

is

wells

completions

platform be

of

directional

ing

into

plane

structure

Well

lake

not under

that

velop

vated

of

some ver

to

but

example of

typical

Here

ture

is

defined

is

bit

inclination angles

and

situation

under

tirely

deflected

departures

8.2 presents

Fig control

the

vertically

inclination

the

is

direction

called

penetrates

unintentionally

one-dimensional

three-dimensional

is

drilling

see Fig 8.1 The

the

earth with

the

not only

or

purposely

deal with

chapters

of penetrating

process

and

early

shore

The preceding

tical

drilling

The

well-

the

directing

predetermined

some prescribed

horizontal

angle

both

the

is

may be environmental

there

use of

the

directional

areas

where

hot-rock

wells

de

are heine

APPLIED DRILLING

352

ENGINEERING

000

SCALE

Fig

and

8.1Inclination in

the

depth

direction

planes

as

wellbore

proceeds

Fig

plane

8.2Plan lake

view

Fig

typical

how

oil

and

directional

gas wells

structure could

under

be used

to

it

develop

Top

of

showing

View

8.3Typical wells

offshore

development

platform

with

directional

Fig

8.4Developing drilled

wells

field

under

city

using

directionally

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

353

AROUND

Fig

Fig

8.5Drilling

of

directional

beneath

drilled

hard

in

directional

of

wells

14000

farther

deeper

ing

will

initial

other

factors

tory

This for

tory

Fig

equal

that

drilled

the

could

the

influence

how

and

an

the welibore

and

the modified-S

the

Path keeps

hit

tion build

some

inclination

increasing

the

and path

target the

right

path

f-

to

the

the fl.

highest

trajec

the

at

the

lowest

still

RESERVOIR

the

is

the

verti

target

weilbore

angle

less

section

than

For Fig

inclination

target

The angle

more inclina

more The of

8.7Using out

inclination

requires

inclination

OIL

angle

With

the

hold

or through

an

Path

angle

in

OLD

could

build-and-hold

trajectory

modified-S requires

and

trajec

that

target

inclination

the

on

used

initial

trajectory the

requires

S-shape

requires

up

the

penetrates

angle

continuous-build

build-and-hold to

at

target

be

wellbore

trajectory

trajectory

maximum

final

is

buildup

shape

types

second

of geology

will

trajectories

penetrates

is

The

wells

Path

target

given

the various

that

de

to

is

intersect

plan the

directional

maximum

with

the to

three types of the

well

to

effects

BHAs

cally

the

drill

Well Trajectory

economically

explains

wellbore

modified-S

penetrates

directional

propose

include

common

hit

the

to

be

depicts to

trajectory

should

design

section

8.8

even

increasein

directional

any

assemblies

most

drilled

with

reaches

environments

use of

path or trajectory

plan should

bottomhole

the

horizontal

hostile

locations

planning

can

that

or refined

is

metamorph

goals of going

the Directional

in

step

paths

fish

increase

wellbore

The

target

reservoir

developed

development

zonesthe

producing

also

first

the

sign

with

field

and

been

have

drilled of

costs

Planning

The

of

the

other igneous

with extended

waters remote

and

8.2

Wells

the

around

obstruction

projects

are being

ft

As

deeper

be

and

granites

rocks Geothermal

ic

where

wells

surface

major

8.6Sidetracking

FISH

continuousall

the

trajec

of

an the

old well casing

to

explore

and

for

drilling

new

oil

by

sidetracking

directionally

354

APPLIED

AND/OR

Fig

8.2.1

Build-and-Hold

Fig

8.9

tory

intersecting

of

D3

and

kickoff of

depicts

inclination

The

at

target

horizontal is

angle buildup

radius

of

true

curvature

r1

in is

weilbore

wellbore

TYPE

trajectories

of

trajec

depth

TVD

X3 Point

The

vertical

of depth is

of

MODIFIE

ENGINEERING

where

departure

TYD

at

types

Trajectory

simple build-and-hold

at

point

8.8Major

HOLD

DRILLING

D1

degrees

where per

unit

the

TI sin

8.4

OB

rate

length

and

thus

found

Lo8JT_X32D3 D12

r1x 180

OB

Substituting

Eq

into

8.1

8.4 gives

ir

To Fig

find

8.9

900

the

maximum

r1

sin inclination

angle

consider

Ir1

in

that

The maximum

90

case

where

X3

8.5

X32D3D12 inclination

r1

angle

for

the

build-and-hold

is

or

Oarc

ri sini

8.2 The angle

can

be

found

by considering

Triangle

where

ir1

OAB arc

X32D3D12

T1X3 tan

8.6

\D3D1

BA

r1X3

AO

D1-D1

tan

8.3a

The

length

of the

arc

Section

DC

is

and

x0 r1

X3

Tarctan-_ Angle

can

be

found

8.3b

by considering

Triangle

OBC

or

LDC

8.7

DIRECTIONAL

DRILLING

AND

CONTROL

DEVIATION

355

XN Fig

Fig

8.9Geometry

of build-and-hold-type

well path

X3

for

r1

clination

the

can

angle

constant in path CB at be determined from Triangle BCO as

angle

horizontal

departure

at

considering

for

the

Fig 8.10

inclination

mined The length of

8.10Geometry

XN

build

section

which

will yield

The distance dN can

Triangle

OC

new

be deter

where

trajectory

CO

DNDlrI and

the

sin0

horizontal

8.10

XN

displacement

is

tan

LCB

LCB

XNrl r1

and

The can

TVD be

at

cos

8.11

end of the build

the

derived

0r1 1cos

from Triangle

section

DOC

is

D2

which

Fig 8.9

r1

LCB

D2D1r1

tan

The

total

DM

measured depth

The

TVD

for

of

D3

where section

The build

DM

equals

the

plus constant horizontal can

section

vertical

inclination

departure

be determined

to

kickoff

Fig

section

EC

X2

at

by considering

plus

the

build

Triangle

of

To

find

the

along

any

part

gle

consider

measured depth

8.9

and

horizontal

of the build before reaching the intermediate

inclination

departure

maximum an an1e

for

any

part

of

the buildup

is

The

new

8.13

measured depth

from Triangle

at

TVD

of

can

be

deter

PPC

the

DOC

where

X2rirt cos0r1lcos

measured depth

DMNDl mined

8.9

end

8.12

is

8.8

tanO

new

sinG

the

DMPDl

.CP

where

CP CP

cos

8.14

356

APPLIED and

Since

CPDD2DD1

r1

X3

r1 OIlr From X3

r1

Eq

Substituting

8.16 the

The

ft

also

Eq

8.14

DD1r1

sinO

8.15

into

be

used

measured depth horizontal

ft

rarctanO.0261l.5

8.15

can

8050

sin

Jr1X3

8.16

Eq

of

8.14

to

D3

Point

at

DD1

sin

making

departure

8.5

r1

instead

by

Eq

From

cosO

late

8.3a

0.0261

D3D1

cos

Eq

210

tan

r1

Eq

sin

Therefore

DD1 CP

ENGINEERING

DRILLING

calcu-

2865

ft

8053

ft

3558

is

arc

0.35620.84

sin

8.17

PPCP

where

The maximum

Eq

Combining

Eq

8.17

8.9

derivation

preceding

Another

of

way

angle

in

is

only

is

and

X3

for

r1X3

8.19

r1

X3

inclination

X3

Eq

Using

9650 ft 1600

9arc

r1

is

\2865

arc

cost

\D3D1/

ft

ft2655

2865

r1

arc

tan4

8.18

when

D3D1

Oarc

angle

020.84l.519.34

maximum

the

D3

ofr1 D1

terms

yields

Otan

sin

valid

expressing

CP

and

Xrilcos 0DD1 r1 The

inclination

tan

ft

ft

cost

\96softloooft /9650ft1600ft\

7D3D1

1119.34

xsinlarctan

xslnlarctanl

ii

8.19

/J

r1X3

\2865

The measured depth of 19.34 is

ft2655

to

ft/i

end of

the

the

build

an incli

at

nation

8.1

Example location

hold

2655

is

of

build

ft

maximum the

end

of

is

TVD ataTVD

of of

From

r1

9650

to

the

of of

ft

of

the

lake

well

departure

depth

curvature

1915

of

the

ft ft

ft and

to

the

19.34

DM

the

is

the

build

the

the horizontal the

to

and ft

8.1

the

total

using

100

measured depth

Eq

8.14

ft2565

ft

dis-

the

target

R1

Dtar2565

measured depth

horizontal

to

TVD

of

9650

is

the

meas-

ft2565

2865

ft

ft

tan20.84

tan

departure

ft

Eq

ft

1600

1600

measured depth measured depth

total

1915

the

R1

the

end

to

build-and-

The recommended

The kickoff

angle

build

7614 7614

ft

the

under this

Horizontal

of

radius

the

ataTVD TVD

at

drill

For

used

2.0/lOt

at

placement

to

Well

TVD

departure

depth

Solution

be

inclination the

horizontal

ured

for

at

Determine

ft

desired

is

will

trajectory

target rate

It

designated

10091

The horizontal

Eq

8.9

ft

departure

to

the

end

of

the

build

from

is

180

2865ft 2/l00

ft

X2r1lcos 02865

ft

ft

DIRECTIONAL

TVD

At

the

of

1915

2/l00

of

build

AND

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inclination

the

be

determined

1915

at

measured depth

ft

can

ft

ft

CONTROL

DEVIATION

by

rate

at

of

calculating

8.2.2

The

8.10

Eq

using

first

357

ft2865

1600

ft

second

dropor for

ft

1915

sinO

the

812 both

315

Oarc

16.31 \2865

Eq

length

of

were

the

are used

the

build

6.31

to

calculated

can

and

the for

is

and

inclination

derived

to

in

r1 The following

maximum

in

inclination

Fig

K4

In

zero

same

the

equations for

angles

X4

using

arc

6.31

DD

tan

r1r arc cos

\r1r2X41

ft315.5

and

reduced

is

is

Fig 8.11

r2

r1

and

hold

by

X4

r2

r1

K3

r2

r1

build

depicted

r2 which

radius

calculate

to

r2 X4

and r1

build radius

the

8.7

LDC

K3

where

maximum

with drop as

trajectory

r1

cases the

cases

Trajectory the

is

curvewhich

ft/

r1

The arc

type

cases

manner

of

S-shape

for

D4

at

ft

sift

Build-Hold-and-Drop

\D4D1

ft

2.0

The

measured depth

TVD

for

ft 1600 ft

DM315.5

of

1915.5

1915

ft

Xslnlarc tan

is

only

is

0.5

The horizontal from

Eq

ft

more than

departure

ata

the

TVD

of

r1 r2

Lx4

1915

ft

is

found

8.11

r1r2

arc X19152865 The

tan

TVD

8.21

DD

ft

Ol80arc which

D4D1 \1 \r1r2X4/J

1.0cos 6.3117.36

ft

measured depth

TVD

at

ft

7614

of

cos\D4-D1

ft

D4D1

is

8.22

XsinarctanI

LX4r1r2Jj

19.34

DM1600ft

xlOOft 8.2.3

Hold

Build

Modified

7614 ft1600

ft2865

ft

The build

sin19.34

7934

hold

modified

cos19.34

Partial

and

Drop

Hold

Trajectory

drop and hold Fig

partial

type of wellbore

8.13

Consider

path

that

is

the

the arc

length

ft

LcA The horizontal lated

with

Eq

departure

TVD

at

of

7614

ft

is

calcu

8.18 From

X76142865

ft

7614

ships

1cos

the Right be

can

COB

Triangle

the following

relation

written

19.34

ftl600 ft2865

LCBr2 ft

sin

8.23a

sin

19.34 and

19.34 1935.5

Xtan

ft

r2r2 cos 0r21cos

SB4

Eqs The preceding the case where tory can

derivation r1

For the case be

and

example

calculation

is

for

simple build-and-hold trajec X3 for where r1 the maximum angle

K3

calculated

D5r2

8.21

For any of horizontal

/D3D1\ tant

\X3r1

S-shape

curves

for

appropriate

the

by

substituting

measured

be calculated

departures can

the

rewritten

in

build-and-hold

the

for

relationships

depths

the

and

same way by

trajectory

various

the

ge

ometries

arc cos

L..\D3D1

/D3D1\1 \X3r1

the

be

r1

8.2.4

Multiple

When

Xsinlarctan

can

andX5r2lcos0forX4

forD4

they are calculated

by

deriving

0180arc

8.22

and

sin0

8.23b

directional

horizontal

8.20

its

well

departure

dimensions

circular

Targets

If

the

of

being target

may

Targets target

is

the

is

be

circle

planned are

the

given

rectangular radius

is

depth as

and

well

square designated

as

or

APPLIED

358

OF

START

ENGINEERING

DRILLING

BUILDUP

KICKOFF

D4

D3

INCLINATION

ANGLE

OFF

TARGET

-o1-------1-

x4

rX

Fig

8.11Build-hold-and-drop

Sometimes

there

14a and

14b be

can

targets

times and

are multiple targets If

however

in

trajectory to

drill

even

as

that

in

they

are

Fig

14b

though

the

14a most

in

X3

r1

shown

as

favorably

and

Fig

8.12Build-hold-and-drop

with

penetrated

unfavorably

aligned

alterations

could

be

vertical

are

section

be

of the

Fig and

to

X3

r1

and

of

format

What

each

the

are the

in the

directions

alternative

wells

following

The

same

the hit

of

14b

Target

difficult

extremely

Example 8.2

expensive

appears

The direction change

situations

one

required

difficult

where

multiple

14a Some

Fig

case

the

for

r2X4

Figs

by

positioned

trajectories

trajectory

Fig

would

are

they

types of

expensive

where

r1

economically

aforementioned

case

the

for

Well

N15E

Well

225

Well

NOE

to

execute Solution 8.2.5

Direction

In

previous

the

been

reduced

have

to

an

100

of

the

and

west

direction

clockwise

scheme

degrees

in

from due it

is

N18E

157

at the

well

In quadrant

four

N55W

is

8.2 has

to

east

or

15a by

Fig

north The well

18

is

in

523E

target

and

the second

In cite to

first step

to

departs from location

or

and

quadrant should

be

15

is

read

Well

S45W

as

north

the

vertical

from Well 2s surface

three

Fig

sible

200

angle

of

305

100-ft

path

the

exerted by

bit

the

on

could

bit

the

in

this

chapter

the

location

radius

general hole conditions later

plane

bottomhole

the quadrant

with

of

component

down

looking

to

is

determine

Fig 8.1

trajectory

the

the

and

well

planning

view

measured angle of compass

for

account

get

the

in

Y-Z

always read

quadrant

quadrant

and

represents

dimensional

Fig

In

first

Planning the X-Y Trajectory

8.2.6

The

direction

from north

by

in the

quadrant

wells

west For example

compass

is

third

has

with direction

read

are always

Well the

considering

directional

compass reading scheme is used to

quadrant

south

read

All

associated

normal

S2OW for Fig 15d

is

is

Fig

by

90

from

angle

8.15c read

north

the

and

8.15b

is

in

drilling

directions

or

of

east

directional

east

Well

problem

in

Well

and planning

trajectory

departure that

Schemes

Compass

the

all

two-dimensional

horizontal

component

For example

and

Quadrant discussions

and

only depth also

is

section

BHA and

the

the

next

the

surface

Fig

8.16

straight

line

projected

to

because

line

of

factors

of

indicates

certain

configuration other

is

the bulls-eye

plan path tar

pos

influences

the that

is

that

trajectory

between

two-

step

target

The dashed

follow

The

are

geology covered

DIRECTIONAL

DRILLING

AND

DEVIATION

CONTROL

359

The bore of

of

based

usually

are

target

drainage

reservoir

on

When

well

kicked

is

some

trajectory

to

This lead

usually

the

off

local

on

basis

might

cause

As tory

the

elevation

hand

OFF

ture

of

There

-.--4TARGET

path

are of

the

in the

field

on

hand Consider

Fig

8.13Build-hold-and-drop

r1X3

and

and

hold

modified-S

where

r1r2X4

PROJECTED

bit

views

many

to

13

calculator

at the

intersect

niultiple

is

bit

selected

factors

that

bit

LEFT

targets

or

for the

to

can

off and is

TURN

method used

functions by

kickoff

drilled

TRAJECTORY HIT

goes

bulls-eye

to

TARGETS

Fig 8.17

point

A2

zero Fig 8.18

TO

ex

be performed

depicted the

that

three-dimensional

which

as

right-

curva

plane

targets

the

Past

path

walk

vertical the

in

horizontal

clockwise

or

trajec

penetrates

trajectory

trigonometric

kickoff

the

set

and

vertical

calculate

surface

TARGET

to

of

The most common

TARGET

used

and

did not account the

PROJECTED

well

be

can

counter-clockwise

section

kicked

is

TRAJECTORY

8.14Directional

use an older

to

the

typical

and

with

vertical

At

angle

line

generally

thumb More

of

lead

as

are

angle averaging

well

is

the

lead

departure

used

lead

shows

location

ways

WITH

Fig

of

from

the

clination

8.18

design

away

weilbore

the

tendency

The distance from the

after

walk

bit

surface

the

orient

called

or

the

to

is

rule

wells

offset

and

trajectory

is

some

variation

trajectory

or

the

the

through

lease

target

value

planes

left-hand

initial

cursion

of

8.17

the

called

The

----

to the

and

angle

the

that

and

plan

tendency is

or

progresses

Figs and

left

indicates

in the

the lead angle DROP

pertaining

walk

drilling

varies

250 The

analysis

bit

Zplane

the

on

of

the

the

to

direction

walk

bit

of

to

experience

recent research

on

well-

dimensions

criteria

practice

direction

specific is

from

ranges

term

factors

geological

BUILDUP

based

for the

and

size

constraints

boundary

and

tolerance

pass through The

to

trajectory

the

of

zone

provides

area

target

is

D1

The in

shows

the

360

APPLIED

IV

DRILLING

ENGINEERING

IV

1570

III

II

III

Iv

III II

III

II

ci Fig

8.15Directional

quadrants

and compass

measurements

top or plan view of the trajectory Point

on

ticai

section

A1

plan

view

corresponds

ing equations

LDM

the

starting

the angle-averaging

Using

be derived

can

east/west

to

for

the

point

method

the

north/south

the

on

ver the

follow and

coordinates

fnAaA_1\ SiflI\

RAA_1 COS 8.24

and

ML.DM Oil

98

TARGET 1VO

Fig

8.16Plan

view

S1fl

AT Of

9650

8.25 Ft

The

LAKE

IAA_1 sink

TVD

DLXDM where

1.DM

can

be

calculated

by

/AA_1 8.26

cos

is

the

measured depth

increment

DIRECTIONAL

AND

DRILLING

361

CONTROL

DEVIATION

TARGET

NORTH

NJ4

KICK

OFF At

Inclination

N3

00

Kickoff

CLOSURE

DEPARTURE N2

LEAD

ANGLE

EAST K4

Fig

8.18Horizontal

calculation

and

f10\ D2100

cost

ft

\2/

199.996

ft

04

D8000

ft99.996

ft8099.996

ft

ii From 8100

to

8200

ft

/12\ L3lOO 8.17Vertical

Fig

8000 the

8400

to

rate

Calculate

where

ft

of build

the

kickoff

the

turns

direction

the

is

at

rate

The

north

right

lead

8000 of

100

to

the

ft Direction

200

first

held constant

1/l00

of

\21

to

ft

is

to

ft

/2020\

northO.822.463.28

12.46

ft

ft

f12\

and

M3lOO

and

ft

the

ft

and

f2020\ Jcos

\2/

sift

bulls-

set

8200

cos

from

well

the

at

is

ft using

right-hand walk rate of 10/100 is N3OE Assume that the eye

where

for

trajectory

10/100

is

sin

calculation

Total

Example 8.3

ft

2/

jO.90

ft

lead then

Total

east0.30O.9Orl.2O

ft

ft

/1-f 2\ Solution using

8100

Eqs ft

is

8.24

and

and

and

8.25

calculated

coordinates

east

from

Eq

the

TVD

D3100

are calculated

from 8000

ft

99.996

cost

8.26 ft

D8099.9999.9968199.996

L2100

1-1-0\ ft

sift

\2/

Jcos200.82

From 8200

ft ft

from N2OE

100 M2100

For

the

first

point

direction

should

to to

8300

ft

the

direction

not

be

ft

by

1/100

/2021\

4.o9ft

L4lo0ftsin__C05\

Total averaged

changes

N21E

/23\ sin200.30

the

ft

to

northv3.284.O97.37

ft

DRILLING

APPLIED

362

2021\

72-l-3\

M4l00

sini

ft

\2J

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2/

eastl.201.532.73

Total

D4

100

TABLE 8.1DATA

1.53

ND

ft

ft

99.90

Note

that

8300

8400

to

the

ft

direction

further

ft

ft

Angle

Departure

ft

degrees

0.00

0.00

0.00

0.82

0.30

0.87

8199.96

3.28

1.20

3.49

20.1

8299.86

7.37

2.73

7.86

20.33

13.05

otatement

Rourrdoff

ft

East

8099.99

the

ft

North

8000.00

8399.67

errorin

departure

From

8.3

Departure

DM

8000 8100 8200 8300 8400

D8199.99699.908299.896

EXAMPLE

ft

ft

ft

FOR

ENGINEERING

angle

the

of

the

13.97

requireo

problerir

small

very

be

to

4.97

20.1

the

departure

20

be

to

angle can

distances

eanly-departvre

20.85

cause

the

8200

to

calculated

different

changes

N22E

to

L5l00

cos

\2

sin

ft

5.68

ft

rant

13.05

ft

/34\ /2122\ sin___cos

ft

and

360

this

problem

The

ft

97

ft

to

steps

horizontal

choose ft

99.81

cos____

ft

plan

ft

type of

total

each

each

at

departure

triangleA1A2K2

the departure

from

of

target

be

A2A3K3

A4A5K5and the

can

depth

each

A3A4K4 can

angle

from

be

or

two-dimensional

modified

continuous

inclination

triangle

build

and

point

other

and

lead angle

the

estimate

the

of

rate

change

Calculate the three-dimensional by

target

hold an

plan

maximum

the

or

S-curve

and

appropriate

build and

as

information

direction

and

determined

such

trajectory

S-shape

trajectory

calculated

aver

which

follows

as

seems

that

point

Make

Determine

The

no

angle

the target

to

kickoff

Calculate

D8299.89699.81 8399.706

handle

to

way

361

and

are

trajectory

departure

Select

D5l0O

the

the clockwise

359

are

the

358

whereas

From geological or other considerations establish number of and depth radius target targets target

the

east2.732.244

Total

and

quad

example

180

be

trajec

fourth

For

taken

with

planning

360

Logically

continue

359

that

359

be to

is

be

would

and

would

so

must

In

and

quadrant

3600

age

2.24

359

of

observed

is

first

care

special

tation

M5100

near

is

that

tory

average

north7.375.68

Total

/2122\

convention

sign

proper

/34\

the

using

initial

guide This reduces

well

the

number of

to

path

two-dimensional

well

hit

the

plan

as

cal

trial-and-error

culations total

departure

Jtotal

north2 total east2

With

this

total

departure

arc

angle

8.1 the

rate

from

to

going of

tabulation

is

180

of

the

inclination

ft

Calculate

the

method

normal

TVD

ascertain

the

instrument the

first

the

D8000

TVD

8.5 discusses

that

must be known

nation and

using

Eq

8.26

4.08399.70

sin

ft

Example 8.3 showed

tion to

the

tions

shows

8.1

change east

can

is

the

where in

be

us

ft

how of

effect the

in

the

variation

trajectory

determined The departure angle

angle

clockwise

used

Well

well

the

determining

path

and

inclination to

various

in this

tion

inclination

as

the course

gle

obtained

direction

calculate

the

instruments

section

any

/100-ft

rate

increasing

from

the is

manner of

the

These

quadrants

in

the

in

drift

of direc the

north

same calcula

ence

as

line

long

at

in

detail

as

the

all

in

is

all

each

explained

gyroscope in

Sec

void of magnetic is

performed

more

trajectory the

Each

of

techniques

approximations

and

for

calculation the is

sta well

an cor

corrected in

this

are corrected

for

and

techniques

one

be

Assume

gyroscopic

wellbore that

must

interference the

as

direction

must be

8.5

the direction readings

are 18 or the

and

At each

measured

are

stations

All

of incli

where sur

path

A4

and

angles

var

preselected depths

type of survey

magnetic

north

conversion

There

direction

at

trajectory

A2 A3

length between

declination

mining

and

This that

of

to

trajectory

values

that

is

be obtained

Stations

by

to true

drift

at

part

is

some type of surveying

by using

the

can

depicts

are taken

section

Table

chapter

of

Trajectory

and then the

direction

veys

for

plane

this

most

designing

ft

ft5730

direction

measure

stations

Sec

rected

the

for

coordinates

to

ious depths

Fig 8.19

find

in

for

in

radius

5730ft

Then

the

Calculating

The calculate

8.1

Eq

using

100

later

are covered

calculations

foregoing

1100

of build of

r1

curvature

be devised

considerations

practical

north

8.3

Using

well

directional

east

can

trajectory

The

tan total

Table

procedure

wells

directional

The group

the other assumes

that

the

surveys for

deter

main differ uses

straight

the wellbore

DIRECTIONAL

more of

is

ments

It

curve

sources

8.3.1

and

is

approximated

References

some of

for

CONTROL

DEVIATION

beyond the scope

is

method

ery

AND

DRILLING

at

the

of

this

the

end

with

chapter of

curved

seg

derive

to

the

more common

363

ev cite

chapter

ones

Method

Tangential

The simplest method used for years has been the tangen tial method The original derivation or presentation to in dustry and

unknown

is

direction

sumes

the

preceding

at

The mathematics

projected course

remain

angles

DM2

length

inclination

and

8.19

constant

A2

to

the

uses

Fig

A2

station

survey

The Angles

as the

over are

A1

not considered

are

can

It

can

shown

be be

that

calculated

the

north/south

latitude

using

DM

Eq

8.27

for

each

coordinate

course

length

sinacos

LiDM1

8.27 A3

the east/west

Likewise Eq 8.28

DM

coordinate

is

determined

sinx sin1

by

8.28 AT

TVD

segment

D1DM

cos

The

To

calculate

the

Eq

by

8.29

8.29

ci

the

and

dinates

calculated

is

A4

total

north/south

and

coor

east/west

TVD

Fig

8.19Three-dimensional that

ponents

view

comprise

wellbore

of

showing

and

the

parts

com of

the

trajectory

8.30

L1

8.31

and

DDMj

cos /cricri_i

and and

L1

8.32

8.3.2 It

Average

Angle

was recognized

able

that

or the

Angle

Averaging Method

tangential

method caused

The average

angle

considers

the

of

over

the

error by not considering

direction

course

and

D2

and

average

average length

Eqs

8.24 angle

and

the

angle

angles

increment

through

previous

8.26

D2

inclination

and

are

calculate

the

angle

and

method

averaging

cr1 to

and siz

cr2

L2

M2

averaging

relationships

On

/Cr1a1\

LDME 5\

qj_i

the

or

set

can

up

tor Table averaging

MIDM

dinates

/CrjCrj_1 5ifl\

Sifl

of

basis

calculation

program

as 8.2

shows

technique

from

8.24

Eqs

easily

measured

be

on

through

set

of

determine

values

of

steps the

the

form

programmable

sequence to

8.26

in tabular

trajectory

Fig 8.20

hand

used

trajectory

inclination

calcula

in the

and

angle-

coor

direction

APPLIED

364

TOTAL

TOTAL

COORDINATES

DEPARTURE

COURSE SURVEY

DATA

DEPTH

VERTICAL

CALCULATIONS

COORDINATES

AVERAGE

AVERAGE

CLIN

MESUED

Al

DSIN

COS

HI

AZIMUTH

DCOSE

DIRECTION

ANGLE

10

ENGINEERING

DRILLING

1L

SIN

DEPARTURE ANGLE

1M

ETYH

02

ARCTANJ

El

7100

7100

7200

568W

10.1

7300

134

7400 7500

100

S65W S57W

16.3

100

S61W

19.5

710000

100

99

61

11.75

97

90

14.85

100

710000

5.05

96

17.95

7199

66

95

61

7297

80

7394

248

245

17

25

7489

13

248

51

30

63

237

82

30

246.5

241

16

12

-16

57

42

241

-12

43

22

239

-15

87

26

20

29

16

49

54

72

2385 31

42

72

S68W

80

16

-1142-268

75

85

S67W S64W

46

S62W

10

11

12

13

14

15

16

AT

POINT

FOR

Xl

KICK

OFF

POINT

ENTER

VALUE

COLUMNS AT

POINT

FIRST

SURVEY

STATION

OF

ZERO FOR

THROUGH

AVERAGE VALUE FOR USE ACTUAL SURVEY DIRECTION

Fig

corrected

Solution

by

values

the

points

the

Using

depicted in

Determine

survey

the

Table

in

step-by-step

Fig 8.20

presented

coordinates

trajectory

given

is

for

the

and

given

as

form

the the

INCLINATION

Minimum

8.3.3

Curvature

and

A2

and

assumes

D2 and

length

not

A1Q0A1

Fig 8.22 shows veying

stations

overall

angle

A2 in

The

Sec

curved

curved

and of

change

overall

8.4

method

the

can

Method

weilbore

line

straight

course

A2 the

drillpipe

written

is

for

BA2 the

and

POINT

X2

It

follows

that

the

and

0A2

/3/2

tanf3I2

tanj3/2

A1

8.21

and

that

two sur

includes

minimum

/312

0A2

the

A1 B/A1

tan/312//3/2

2//3

tanj3/2

tan/3/2I/3/2

2/3

tan/3/2

and derived

and

curvature

as

BA2 /QA2

cos

factor tion

sin1 SiflcE2U_cosf2_fIJ As depicted A1

AT

course

between

discussed

the

the

by Fig

method /3

at

angles

over

shown

length

This

angle which be

as

A2

and

A1

QA2

method4 uses

FOR CALCULATIONS

method

A1B0A1

The minimum curvature

AND

COLUMN

IN

averaging

Points

COLUMNS

IN

AZIMUTH

filled-

8.20

by Fig

ZERO

8.3

procedure

solution

8.20Angle

DE

BCE

COLUMNS

IN

ALSO

ENTER

DO NOT USE AVERAGE

Example 8.4

INCLINATION WILL

BA2

in

Fig

adjoin

the

8.21 curve

the

straight

segments

line

A1

.8.33

segments

QA2

at

ratios

F2//3 If

/3

is

of

the

is

defined

straight as

line

vs

section

the

curved

tan31/2

less

1.0 Once

than is

sec

where

8.34 0.25

known

radians

it

is

reasonable

the remaining

to

north/south

set

and

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

TABLE

365

82TRAJECTORy

DETERMINATION

COORDINATE

Worksheet

Source

Letter

Value

red

--

specified

depth

angle The

Direction

The

angle

direction

The

length

ends

Course

of

length

The

each

of

the

wellbore

from

surface

its

location

Value

___________ survey

any

to

or Equation

Obtaining

the

weilbore

from

the

survey

vertical

course

survey

measured

in

arithmetic

from

depth

average

the

of

station

one

inclination

angles

the

course

another

to

the

at

-Ax11 and

upper

a10_l

course The

depth

vertical

of

the

of

difference

inclination

Average lower

actual

for

station

Inclination

Course

The

be Obtained

to

difference

in

vertical

of

depth

one

from

station

cosE

to

another True

vertical

Course

The

depth

departure The

summation

the

of

between

distance

course

two

vertical

of

depths

that

points

are

an

inclined

projected

onto

Ed

welibore

sinE

horizontal

plane azimuth

Survey

3600

00

azimuth

Average

North/south

another

course

total

direction

to

east/west

departure

location

below

component

summation

Must

tial

It

is

take

of

tical

even

As

8.4

taken

from

shows the

calculated

calculated

among the

balanced

the

methods

station

sinK

to

in

displacements

the

in

displacements

the

and

to

onto

put

into

each

station

horizontal proper

JN2

point

plane

quadrant

from

O2

station

See

arc

sign

tan

8.37

calculated

are

test

using

been

Eqs

commonly

the radius of

hole

average tangential

the

for

the

the

for

that

the

iden

north/south

and

most

the

accurate

methods

the

for

using

minimum clcilatino

data

method

This

is

why

The differences curvature

methods are so small I1si

results

tangential

and

no longer used

angle

8.21Representation

of

minimum

curvature

tangen

acceleration yield

Fig

FOR TABLE 8.3DATA EXAMPLE 8.4 Inclination

different

Note

error is

balanced and

differently

yields

of

the

TVD

and

six

that

averaging

derived

method

cmilcl

have

method2

note

to

method

considerable

the

one

from

using

F1

that

formulas

compares

tangential

cosK

to

36

TVD

vector

though

which

Table

course

projection

acceleration mercury method method and vector averaging

coordinates

to

course

wellbore

the

mathematical

east/west

the

vertical

vertical

value

be

can

tangential

interesting

trapezoidal

methods

station

sinej_tsina

trapezoidal

method

one

from

A1

methods

method3

method

course

8.35

balanced

the

curvature

the

8.32

calculation

are

of

x1

sinc1_1sinz

departures and

through

Other

ends

degrees

in

survey

__________

from

direction

D/2

used

the

displacement

the

of

of

cos1

total

to

equations

D/2 The

00

negative

sinF

8.30

at

displacement

component

summation

distance

The

TVD

and

is

Shortest

surface

MD/2

D1

from

negative

is

The

west

direction

coordinates

course

course

The

south

coordinate

total

convention

following

fhe

coordinate

direction

Departure

direction

west

value

north/south

Total

clockwise

in

azimuths

of the

average The

coordinate

North/south

east/west

measured

course

arithmetic

coordinate

negative

East/west

of

valuesoulh

course

another

direction

The

negative

East/west

the

The

north

is

that

and

any

of

the traiectorv

DM

Angle

ft

degrees

7100 7200 7300 7400 7500

10.1

13.4 16.3 19.6

Direction

Angle

_______ S68W S65W S57W S61W

ratio

factor

APPLIED

366

from

ture

the

cludes

the

nozzle

offset

of

in

the

a1

to

refer

tables

use

and

8.26

Fig

course

the

clination

and

ci

inclination

cause

A1Cd2

lated in

follow

the

8.4.2

and

new

is

deflected

horizontal

The

direction the

plane

are

vertical

it

8.22A

Fig

curve

tions

weilbore

representing

and

A1

between

Sta

Survey

A2

will

the

-y

and

of

be

will

It

shown

Sec

in

8.5

that

the

systematic

in

shown

direction

AOB

Triangle

is

projected to

to

ODO 3600

represents

an

rotation

etc

Fig 8.27

by

the

parallel

and

rotated

with

0CE OCA

Planes

to

is

the

southeast

Fig 8.29

ACE

Plane

through

normal

MOC

Line

is

AA BB

of radius

circle

cutting

and

If

parallel

Lines

of

wellbore

in

DAB

through

cutting

or

normal

tending

its

will

AE

the

plane

Fig 8.28

and

MOCEM

transcribe

The change angle

plane

cutting

circle

gle

OABE

plane

where

vertical

MOCEM see

Point

to

representation

8.27

Fig

Point

at

Points

through

in

on

wellbore

Change

geometrical

re

wellbore

continue

the

Plane

in

will

directly

If the

would

it

Deflected

new

This is

severity

the Direction

presented

deflect to

direction

which

desired course

of

of

in

an

deflected

change

The three-dimensional

is

new

Point

to

Derivation

trajectory

be

to

were not deflected

course

design

deflection

measured depth are measured With

dogleg

called

to

change

trajectory

is

to to

demon

al

et

and

At

angle

is

Fig 8.26

present

ay

the

offset

necessary

three-dimensional

course

overall

what

to

equations

direction

the

angle

an

and

orientation

deflection-sub

the

and

wellbore

device

ing

bit

design

Later Miliheim the

the

depicts

of

to

ways

kickoff

analyze

in

This

sub

Bit

relating

derive

to

toe bent

bit

the

orientation

how

tool

deflecting

Ouija Board see Fig 8.25

to

of values

particular strated

of

common

the

years

were

the

whipstock

jetting

8.4.1 Orientation For

of

centerline

angle

ENGINEERING

DRILLING

is

the

where

over

errors

in the power the variation differences survey calculation when comparing the multistation methods surveying With the advent of the programmable hand calculator the minimum curvature method has become the most

common

AB t4ni OB OEEB AB

Fig

shows

8.29

Point

to

the

Point

of Line

rotation

and

8.38

transcribes

an

EA

from

radius

angle

-y

It

follows

that

8.4

In

to

force

to

deflect

Fig tail

the

were

ings

bit

mud

Later

change

in

change

in

All

8.6

plane

the

or

deflection will

cause

Fig 8.23b

This

section

and

first

sin

well

explains

inclination

as jetting

discussed

are

how

Direction

de

Survey Rate

Due 100

interval

60

inclination

the

motion

direction

to

The magnitude

the

cause

plane or

drillstem

of

the

to

facethe

deflection

is

Calculation

2000

ft

Vertical

the

direction

the

sub

direction

toolface

by

the

depar

1.628

61

Depth From

North

Displacement

Difference

ft

Actual

2538

998.02

From ft 43.09

165361

0.38

954.72

021

Angle-averaging

1654.18

0.19

955.04

0.11

Radius

1653.99

tangential

inclination

with

Actual

Method

Tangential Balanced

drilistring

controlled

drill-

depar

In

Fig 8.24 showing sub an arrow indicates the

the

ft

at

Total

on manipulating

depend

downward

bit in either

both

north

Difference

methods

Randall1

ft

3/100

build

of

Total

trajectory

and

and

Craig

achieve

to

angle

bits

in

control

to

after

OF VARIOUS

hous

subs or bent

as

tools

OF ACCURACY METHODS CALCULATION

8.4COMPARISON

TABLE

used

tool

Fig 8.23a

whipstock

with bent

deflection

direction

deflection

of

simple

equipped

These

pipe rotation ture

was

bit

The

desired direction

introduced

Sec

ABr

the lead angle or making some method must be used

setting

change

in the

motors

8.23c in

well

trajectory

the

and

Change

off

kicking controlled

Kickoff

the

Planning

Trajectory

of

Minimum

curvature curvature

Mercury

Fufieen.iooi

1653.99 1.15362

survey

iooi

954.93 0.0

037

954

93

95489

0.0 0.0

0.04

DIRECTIONAL

AND

DRILLING

DEVIATION

CONTROL

367

BIT

JETTING

BIT

JETTING

WHIPSTOCK

8.23Techniques

Fig

for

making

The next

OE

and

change

direction

positive

determine

to

is

step

EB

Triangle

in

relationships

EBB Fig

8.28

relates

terms of

EB

angle

EBEBcosa and

to the

as

8.39

EAB Fig 8.29 EB

from Triangle

is

related

to

an-

gle

EBr cos EB

Substituting

Courses

By Drill

Could

Rotating String

Deflecting

Face

High

Side

in

Eq

8.39

forms

Eq

8.40

Positions of

Hole

EBr

cos

8.40

cosa

The

That

Welibore

Tool

Take

To determine

the

and

OE

consider Triangles

OEC

and

OOE

where

Sub

rf tan

13

Fig

8.28

these

last

and

OEf Fig

8.24System

for

deflecting

the

wellbore

trajectory

Substituting

OE tan

and

sin

EB

into

4E sin

Eq tan

atan

two

relationships

8.38

and

for

eliminating

terms

AB

yields

sin

8.41 cos

cos

APPLIED

368

IIILFTTTftI

L11I

42

I4

l7

tr

ir

11111111 HEAULTANT

OIECTON

and

veys sin

atan

sin

8.42

cos

j3

is

The

overall

angle

by

the

change

is

following

directly

related

to

could

reported is

in

huh

course

length

between

index of angle be

meters

degrees/l00

meters or

could

the

change

measured

For if

sur

example

course

be degrees/l00

ft

if

course

dogleg

relationship stock

8.43 Lc

LAST

SURVEY

set

of high

at

side

Determine the new

705 for

with course

direction

tool-face

length

of

setting

10

for

of 450

The

whipright

inclination

POINT

PLANE

EAST

SOUTH

NEW

DESIRED

DIRECTION

Fig

B.26Threedimensional hole

after

Mihlheim

if

length

feet

in

Example 8.5

VERTICAL

the

is

cos length

severity

the

is

and

100

is

tan

_l_t

Board

Ouija

drilling

where Lc

arc

14

ii

CHANGE

Fig 8.25Directional

tan

21

ENGINEERING

DRILLING

deflection

eta.5

of

the

course

of

bore

Fig

8.27Three-dimensional Millheim

eta.5

trajectory

change

model

after

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

369

Using

Triangles

00E

nation

angle

can

EBE

and

Fig

8.28

the

incli

from

obtained

be

OOfcos and

BBEB

sin

BBr1

AOE

in

above

the

equation

yields

sin

cosy

Triangles

From

EB

for

Substituting

COE

and

are

equal

and

A0

in

Eq

equals

OC

AOE

Triangle

OAOC cos

8.28Vertical

Fig

plane

MOCEM

through

a5

MilIheim

after

et

OA 00

for

Substituting

acos

COS

BB

and

sin

cos

8.44

yields

.. .8.45

cos

and

and the

is

the

direction will

whipstock over

course

N15W

is

cause

705

of

total

angle

The curve of

change

of

30/30

aNarc

coscos

13sin

cos

8.46

cos

sin

length

where The

Solution

from

overall

change

angle

be

can

/3

determined

aaNa

8.43

Eq

3lOm

Lc

8.4.4

30m and

the

direction

be

can

change

tanl

earc

8.42

Eq

using

cos7

The

tool-face

Eq

8.45

overall

cos45 The

tool-face

known is

/3

right

of high

and

is

if

of

side the

the

tool-face

hole

the

new

can

the

or

angle

direction selected

be calculated

final

known

or

inclination set

/3cos

cos

Angle by rearranging angles

desired

as

a\l

and

\\

8.48

sinasinf3

also

can

change as

be and

desired

calculated overall

the

if

angle

final

change

new

of

high

direction

sin

yarc

sin

L\ 8.49

sin sinj3

8.4.3

Derivation

The new sidering

of

inclination

Triangle

the

New

N9.7W

Inclination can

angle

AOD

OD

cosaN OA

in

Plane

be

Angle

derived

OAAO

Fig

00-OD

00-AA

OA

OA

by

con

8.27

00 BB OA

in are

values

is

or

the

values

direction

left

is

setting

example

in this

Therefore

are

Tool-Face

and

initial

angles

clination

If

the

angle the

if

of

yarc cos

0.091995.3

tan

Derivation

cos

sin45

sin7tanl arc

calculated

8.47

8.44 Fig

8.29Tool-face

plane

after

Millheim

et

a.5

APPLIED

370

ENGINEERING

DRILLING

SOLUTION

152

60 50

40

.30

10

16

15

14

12

13

10

11

16

INCLINATION

Fig

Eqs 8.42 8.46 848 the

direction

angle

change

and

8.49

can

n.e

new

inclination

and

change

tool-face

be

used

to

8.30Graphical

determine

ciN

overall

angle

Ouija

analysis

AB

Line

the

is

angle

or

left

0B

traversed by Line 8.4.5

Derivation

of

Ouija Board

the

AB

Nomograph

The

graphic type of the

that

technique

Fig

nomograph

same parameters

aN the

and

/3 overall

be

can

for

the small

specifying tities

-y

basis

8.30

of be

can

the

condition

the

angle

determine

to

12

of

on the abscissa iden

to

the

left

radians

in

the

10

to

in

in

/3

16

case

The degrees

this

of

semicircles

concentric

outer semicircle

needle

the

right Placing

draw enough

degrees

scale

in this

angle from left

00

at

compass equal

tractor

/3j3

zero

written

to

to

inclination

original

decrease

cos

aNAB

Fig 8.30 can be created by drawing in per degree at increments of say in the represent the number of degrees

of degrees

By

following

ay

a0A16

are

Line

/3

like

nomograph

than

change

angle

angle

8.30

Fig

tool-face

-yC152 and j30B5

scale

the

sin

in

projected

is

the

as

The number of degrees

overall

the

is

inclination

values

for

equations

less the

condition

Board

where the value

smalli.e

is

Ouija

used

from the derived

as

angle /3

the

is

new

the

is

read

is

at

of high side

right

0B

which Line

at

point

outer semicircle

the

through

case

With

from

right

pro

180

to

increments

and

Example 8.6 /3j3

tan

radians of

10

to

calculate

the

Substituting yields

identities

the following

Eq

into

8.42

and

Eq

8.45

/3

sin

60

ft

on

the

set

tool

the

face

from

go

of

inclination

severity

takes

a/3

Scale

which

measure

the

direction

Also

to that

assuming

the

trajec

abscissa

mark Point

At the

200 from

is

Point

the

project

-y

8.50 cos

cos

aN

line

450 Fig

acos

line

Continue

from

Line

8.31

The end

of length

units

Draw

-y

/3 cos

jetting

from an

and

to

bit to

relationships

tan sin

for

dogleg

tory change

Solution

z.earc

30 the

where

Determine

angle -y

tool-face

Point

to

0B

to

to

depicts

the

of

the

line

this

find

the

graphical

line is

tool-face

is

Point

equal

to

setting

solution

851 sin

cos

2.4 ft4.0O/l00 Xi-l00 j3

ft

6Oft

Lc

and

I1coscrcoscrN yarc

tanLe

sini

8.52

/3sina

In nal

the

nomograph

inclination

which

rasp

angle

ivv.i

Fig 8.30

Example 8.7 the

the

except when Th nrIp

abscissa

ht-n

is

the

and

th

..k.

origi

/30

in

tool-face

Solution

unknown

Using setting

Since and

the

data

and

the

Eq

8.41

Eqs

8.48

is

and

th

of

Example

dogleg

in

terms

8.49

8.6

calculate

severity

of

are

which in

terms

trrv

is

of ..

an it

DIRECTIONAL

AND

DRILLING

CONTIROL

DEVIATION

371

90

110100

70

130

30

10

15

16

14

Q30 Fig

and

only By combining

8.49

in

lations

terms the

of

total

of only

sin

and

and

coscos

Eq

sin

8.41

cos

change

angle

and

f3arc

-y

and f3

can

with doing be

8.31Solution

8.48

Eqs

and

written

in

For

Example

acos

cos

terms

aN

8.4.6

8.53

Eq

in

cos

another

8.51

f3cos

and

form

sin

aN

sin

aasin

Sfl

32

aN

cos

Overall

8.32

or

e2O a3 aNS

8.7

Angle

derived

by

Change Lubinski6

nomograph

for

the

severity

dogleg

.nr

cos52.4

sin5 sin3cos3

and is

determining

Dogleg used

to

the

total

Severity

construct angle

sin.jsin2

\__

sin2

Fig

change

aaN

/Le arc

sin2

8.55

8.54

fr

and

20 f3arc

sin

86

Example

some manipu

aN aN

to

dI.n

oftr

ihinski6

APPLIED

372

OC OB

Step

Old Borehole

BOC

Overall

One

Construct

New

To

Parallel

ENGINEERING

DRILLING

line

the

reptesenting

Borehole

14

12

10

Angle

inclination

initial

16 Tool

Face

Direction

Direction

Hole

of

Side

High

Two

Step

Measure

the

total direction

and

change

angle

change

correct

and new

with

the

0r

vector

ar

16

12

Face

Tool

aN

Step

High

Side

angle

change

12

Three

Measure and

the

the

vector

connecting

direction

of

the

which

vector

the

is

which

total

the

is

tool

face

angle

Left

a16 High

Side

/JRht is1

8.34Example

Fig

and

Eq

using

solution

8.53

the

cos

/3arc

the

using

total

angle

sin7.1

Ragland

diagram

change

is

sin4.3

cos4.3 cos7.lJ2.99 the

Using of the Fig

8.33Basis

of chart

tionship

construction

illustrated

by

is

two

trigonometric

intersecting

rela

planes

after

Lubinski

The

overall

Eq

derived secutive

of

inclination

the

tool-face

sets

cerned

with

basis

geometric

calculated

angle

Eq

by

by Eq 8.50 However 8.51 which is based on

calculated

for

and

Lubinski

Fig

derivation

of

and 8.33 the

jetting to

7.10

run

where

and

the

direction

85

ft

interval

of

the

350

dogleg

85ft

lOOft

is

not

con

depicts

from

N89E

to

S8OE

total

The

8.4.7

angle

from 4.3 over

Ragland

Using

is

8.55

the

total

angle

ed

first step

change

is

7.1

4.3 is

of the

the

are

drawn

12

in

vector

The

last

step

is

to

the

nomo

Board

Ouija used

well

total

In to

For

solve

for

the

using

steps

angle

angle

and

the

new

vectors

example draw circle

is

and

is

tool-face

the

apj

setting

change by the

approximately

around

side

The

vector

determined

and measuring is

always

high

case

direction /3

it

the

inclination

inclination

at

change

represents

particular

initial

change

the

that

This vector

this

the

as

origin

this

vector

hole

the

hole

and

the

of the

/3

as

total

necting

is

problem is The

for the

of

from the The

the

inclination

unknowns

these

find

to

construct

to

initial

are given

To

3.0

in

diagram.7

Fig 8.34 shows

direction

face

unknowns

/2.8

is

the

the

represents

and

sin.jsin2

sum of

same problem as present using the Ouija Board solution

8.30

Fig

by

drilled

change

Ragland

process

solve

to

diagram

tool

arc

change

The change

trajectory the

graphical

parameters

Ragland

the

similar

essentially

in that

The

Eq

the

the

Diagram

Another way of solving by using what is called

the length of Solution

5.7

is

and

the

following

severity

was changed

8.32

110

two con

unknown

inclination

by 2.0

2.99100

graph the

89

calculates

severity

method

Determine

divided

Fig

in

given

1000

is

originally

change

Example 8.8

is

total angle change 2.80 yielding f3 of 3.0 of 3.5l100 ft Using Eq 8.40 the andadogleg severity clination

same

the

is

measuring

direction

setting

the

8.51

angle

inclination

dogleg

as

nomograph

horizontal

origin

aN of

con

length

4.9 point

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

373

540W HIGH

SIDE

30

8.35Example

Fig

16

where face

high side

the

direction

that

drawn

above

the

left

Like

the

8.30

of

and

desired

is

the

of

to

the

tool-

the

if

the

of

right

is

the

D1 of

welibore

would be

the

are

uses

analysis

two unknowns

for

and

knowns

In

Figs

and

are

unknowns

Planning

kickoff

Trajectory

tion

or

of these

or

left

to

the

the

The design

or

left

also

mud motor

or

in special

used used

to

kick

now

to

off or change kick

off

Sec

8.5

depicts

S48W

direction

jetting

sub or bent

used

is

in

If

angle

tool

Sec

will

face

8.5

The torque

the

rotate

always

rotation

left

for

by

reverse of

rotation

can

is

number of

on The

compensated offset

calculated

borehole

in

be

used

can

is

to

for

the

factors

or

torque

that

the

cause

new

to

direc

change

without

or housng correction

When

torque starts

to

drill

by some amount are discussed

torque

tool

face

in

must be

enough

to

effects because

drilistring

estimated

left

reverse

reorienting

the

and

activated to

will

directly

reverse

or the

technique

tool

clockwise

bit

the

of

direction

deflection

jetting

compensate

to

the

deflecting

right

be

side

bent sub However if with mud motor

combination

made

must be

using

Eq

of

the

bit

face

8.56

right

change

bit

is

used

They

are

seldom

are

mainly

ML motor

MLBHA

GmotorJmotor

GBHAJBFIA

out of casing

This

MLdrillstring

56 Gd

is

and welibore

at

from

to

to

the

as

gravity

housing Except

whipstocks

trajectory

or sidetrack

build angle

from

inch-

to the

to

the

defined

side

openhole

in

Fig 8.35

direction

bent

to

with

or

djrec-

with no

change

on whether

depends with

side

to

build

maximum

direction

drop

high

Motor

according

maximum

of high

left

and of

circumstances

discussed

desired

or

right

of high side right

designed

change

direction

build with

change

is

desired

is

plans

any to

change

nation

tool-face

type of

of

corrections any other

depending

Mud

of

Torque

change

trajectory

and

Change

Reverse

for

without

drop

the

Changing

face

rotate

N53W

opposite

some

the

is

the

side

high

and

weilbore

to

mud motor

Compensating

which

of

direction

The

require

diagram

Ouija

wellbore

resetting

weilbore

the

8.4.8

will

to

S48W

is

the

of the

side

whereby

setting

corresponds

depth

direction

tool-face

vector

Ragland

it

direction

at

tion

the

8.33

showing how

low

represent

vector

making

solve

to

the is

side

high

knowns

wellbore

N5OE where N4OE

N3OE

is

vector

the

and

would

case

this

of

protractor

hole However

the

Ouija solution

three

any

example from N4OE

side

high

151

example

For

change

change

measure with

the

direction

original

on

and In

angle

of

N53W

depth

aN

and

The high

D1 to side

where change of

the

is

it

the

hole

32

ri II

trin

Jdriustring

APPLIED

374

where

and

tor

of

moment

the

is

Furthermore divided

ers and

the

is

Sec

assembly

BHA to

the

different

could

drillstring

size

collars

drill

sub

be

stabiliz

problem

or

technique

Calculate

and

7300

was

drillpipe

of

change

collars

the

as

3650

16.60-ibm/ft

7-in

that

drill

11.5 the

drill-

total

psi

angle

Use

for

the

change

if

used

where off

the

the

and

is

set

the

For

deeper

run

making kick

com

amount of

expensive

drilling

type of

surface-

used

be

nation

course

direction

of

150

is

the dogleg

reverse

the

ft

ft and

increase

to

in

direction

at this

Fig 8.35 at kick

the inclina

severity

mud motor

the

that

20

has

length

N53W

at

welibore

for the

2560

is

determine

Assume

to

It

the

desired

is

inclination

and

depth

incli

torque

3600 in

in

Solution 19.2

psi

must

face

some

should

kickoff

kickoff

at

depth

S48W

is

tion

Solution

11.5x 106

doubt

in

drill-

torque

tool

the

for

torque

the

one

used

tool-

calcula

the

reverse

the

torque

sub

the

rotate

the

not

is

orient

monitor

Plan

Example 8.10

to

43800

when

tool-face

indicating

on

can

for

estimate

to

reverse

the

to

transmits

relying

reverse

the

bent

the

that

one

reverse

the

difficult

and

operations

tool

system

shot

for

above

mo

the

collars

106

in

for

IDI

Assume

ft-lbf

Calculate

drillstring

of

ft

drill

1000

torque of

angle

Grade

same properties modulus of steel

the

the shear

BHA

of 7-in

ft

bit-generated has

total

ID

300

pipe and

tor

the

4-in

for

is

it

for

pensation

of

requires

discussed

is

compensate

compensate

single

correct

to

where

offs

ft

also

which

right

guesswork

to

surface recording

conventional sure

Example 8.9

calculation

Without

frequently

position

If the

to

run

measuring

pipe dynamically

57

This

torque

way

to

is

surface-indicating

tional

0MMi_

face

The most foolproof

face

and

drilipipe

bit

8.5

torque

and

needed

is

of

knowledge

element and

drillstring

that

compensation

mo

of

length

inertia

the

according

and

bit is

bottomhole

the

modulus of each

shear

the

Lotor

section

length of

the

is

at

generated

drilistring

LBHA

the

is

the torque

is

of any

length

ENGINEERING

DRILLING

229.6

the

Using

the

arrive

at

dogleg

79 a2

graphic technique

the

a6 y97 8.35

/35.8

and

in

exemplified

values

following

This

the

is

Fig

calculation

for

severity

1.997x104M1.997x104 lbm

in

5.8

xlOO3.87/l00

ft

150

/12

in.\

2.396

x1000ft-lbf

Since side actual

2.396

of

360137.3

iO

3.96x

drilipipe

1000

ft-lbt

would

direction

8.36

shows

the

in

\ft

for

the

ning

BHA later

case

of

8.57

sub or any

However

wellbore give

first

part

is

at

at

the

to

of

the

the

the

drillstring to

rotate

reactive

more

In

the is

torque

left the

depths

for

the

caused

by

can

3000 to

amount

be

the at

especially

friction

inclination

is

control

to

course

bent

considera

ft

where

Eq

8.57

the

can

of reverse torque

achieved is

desired

side

if

SOft

the

the

given tool

of the hole and

made

the

course

change for

The

dogleg length

in

face

can

in

be

far

the

do

to

to

is

this

8.10

the

/lOO

11.61

were 200 ft the dogleg Once

and

length

maximum

way

is

casing

design

Example

severity

100 ft

direction

course

easiest

If

length

by to

run

in

cause

and

dogleg

the

regard

problems can

the

making

problems Better

would be only 2.9f

limited

higher

is

of

also

it

for

changes

without

serious

Fig

where

inclination

trajectory

cause

accordingly course

the

kickoff

the

huusing

result

is

the

dogleg

production

the

length

severity

through

change

trajectory

ft whereas

friction

drilistring

drillstring

approximation

the

drillstring

motor

shallower low

longer

the

not include

where

inclinations

ble

or

does other

the

with

drilling

Counterclockwise

Eq

that

causes

can the

for

correction

calculate

and

severity

severity

right

incorrect

the

sub or

direction

Changing

be

and

to

way

bent

maximum tolerable

determine

face torque

dogleg

dogleg

the

one and

the

are

change

wear and

bit

motor

factors

27r

the

of

primary

residual

would

solution

shows

correction

the

the

left

117

dynamic tool face set of high side and the desired

right

the

the

or

the

graphical

torque

8.10

If

to

20

97

346

inclination

mud motor

trajectory

360273.4

and

using

The 4.772

79

at

the

or

right of high

20

be

will

not included

is

be

reverse

Example

xl

Example 8.9 shows

14W

new

well clockwise

the

must be

setting

side

ting

in ibm

12

tool-face

high

turn

to

reverse torque

the

reverse torque

2ir

Iong

desired

is

it

and

If

j3

is

fixed

inclination

no

oriented

direction to the

inclination

only

can

be

change

high or low

change

can

be

DIRECTIONAL

AND

DRILLING

DEVIATION

-WHERE

CONTROL

TO SET THE

375

TOOL

FACE

970 90 70 60 HIG

50

SIDE

10

HIGH SIDE ci

8.36Solution

Fig

The maximum direction change for illustrated by Fig 8.37 Between

is

maximum change

the

tion

90

is

change change

Below

highly

is

change

10

is

setting

1800

1.5

presents

the

between

10

10 curves

at

tool-face

/31.50

for

the

the

the

from

Fig

8.38

setting

with

change

some not

is

/3

angle

can

8.39a

shows

without

bent

sub

amount

of

on

depends

and

the

The

ft

tory

have

in the

field

data

rate

if

all

8.11

bent

39b

The

effect

motor

tables

change

per 100 trajec

are record

done

be

can

the

bent-

present

degrees

parameters this

the

bent

motor

can be derived from

how

the

is

of

above

the

that in

motor

stiffness

to

sub

Fig

mud

configuration

the necessary presents

angle

Fig

applied

published of angle

sub angle

bent

effective

weight

bent

total the

sub and

borehole

BHA

the

axial

Manufacturers sub angles

bent

borehole

geology

the

angle inclination sub

of the

in the

sub assembly

The

with

of

circumstances

certain

combination of

motor

selection

angle although

under

/3

the

deflection

sub

bent

constraints

the

bent

same

requires

the

mud

selected

housing

approach

ed Example

direction

must be

large

sub or bent

sub

for

120 that an 120 would

resultant

bent

bent

the

be

should

sub

direction

maximum

tool-face

between 80 and in

the

inclinations

maximum

y8O and

difference

little

very

reduces

10

specific

setting

direction

At

increases

change

/3

maximum

the

95

though

one

between

flat

for

45

At Even

occurs

are so

make

approximately

45

and

in the

error

to

10

at

inclination

of

inclina

maximum

the

inclination

maximum

for

L5

maximum

the

and

1.50

at

the

the

as

same information

45

to

that

about

is

change

on

50

is

Note

tool-face

1.5

dependent

maximum change

the

3600

is

value

fixed

and

8.10

Example

for

change Both tion

to

try

set

and of

tion

of

the

then

will to

site

the

course

BHA

the

trajectory

must

making

design

inclination

to

respond

in

direc

the

is

practice

between

only holding the Too much curvature

to

in

the

direc

P/20

is

and

S2OE

the

to

be

minimize

bent is

changed the

dogleg /3

In

planning

used

the

trajectory

type

of

change

jetting

bit

when and

jetting

nozzle

for

S85E and

tool

arc

Using

face

size

bit

is

to

which

Eq

cos

severity

be

sub

is

effective

bent

motor run where at

6382

160

right

ft

of

sub at

response

6357 and

is

high side

oppo Solution

must

direction

be extended

for

benefits

change where

the

Example 8.11 Determine

and

direction

direction

some of

thus negating

inclinations

length

an

at

inclination

curvature

original

of

importance

constant

fairly

cause

the

the

inclinations

direction

build

At higher the

low

at

hole

the

show

figures

change

1.07

8.53

sin1

/3

can

sin

be

calculated

cos

cos

as

ft

is

APPLIED

376

CHANGE

Cl Ui Ui

INCLINATION

IN

CHANGE

ENGINEERING

DRILLING

INCLINAflON

IN

CD

Cl Ui Ui

LU

CD LU CD

CD LU

LU CD

uJ CF Ui LU CD Ui

8.38Overall

Fig

0.0

Ui

the

the

Example 8.12

0.00

change

angle

10.0

to

1.5

i3

Miliheim

after

hole

from

inclination

for

and

hydraulics

be analyzed

run can

jetting

used

dogleg

ft

At 1722

clination

of

2.25

The

the

over

severity

interval

drilled

designing

trajectory

S2OE

at

and

the

at

the

bent

sub

25

is

maximum angle

the

the

could

that

change

face

bit

to

formation without

ways

soft

is

enough

restriction

allow

to

be reached

runs

ting

the

bit to

each

If

resisted

4.3/6.0

and

4.3/lOO

maximum

rate

that

implies

ft

of build by

the

Another

bit

is

If

housing bit

the

much

the

The

bent

change

is

displacement

close

Jetting

the

motor length

angle

positive

tion

the

the

affecting

move

to

unrestricted

ft

the

of

way

to

the

bit

have

angle

fixed

same purpose effectiveness

as

of

of angle

rate

sub

Orientation inclination

the

was

nozzle

1940

at

the

was S36E station

of

occurred

direction

with

The nozzle

direction

was

ft

between

change

jet and

/3

and

known of

and

inclinations

ending

the

total

angle

direction

can

change

30

is

5/l00

ft

ft

it

between

big

1.5

the bent the

is

jetted

25

be

the

dogleg

determined

subto pocket

other

the

two

the

ft

that

is

2.75

line

is

at

2.250

the

the

origin

the

other

line

ed

by

at

1722

is

/3

the

to

and

1799

distance

the

aN2.75

knowing and

segments

point of

The dogleg

course

the ft

along

Lc77

length

and

yl22 units

angle

The the

total line

intersection

can

long

77

be

an

from with

calculat

between surveys

ft

ft 100

ft

4/l00 71

from

ft

ft

ft

deflec

depends

line

133.1 130 and

which serves cause

.40a see Figs line from 130 to

2.25

from

line

bent

l8A 0/100

direction

drawing

intercepts

change

6/l00

have

bent housing

change jet

closer

of of

instead also

for

change

instead

by

approach

factor

from or

farther

motor can

For

unrestricted

bits

are

the change

drawing

72

example

the

the

done

is

where

gle

this

and

severity

build of the

the

3.0

last jetting

drilling

the beginning

setting

using the graphical

of

rate

Determine

at

2.75

of ft

ft

ft

This lower

and

Normal

the

1814

run

100

l.5x60/ljO

formation

ft

direction ft

ft

The

at

in The

is

tool-face

The

3.25

S9OE

at

side

drill

Solution

25

The

At 1877

1925 an

at

inclination

an

survey

inclination

the

for if the

with

1877

at

survey

S66E and 4.75

from

ft

last

the

was

inclination

N7OE

was length

and

ft

ft

mud motor

S3OE

different

ft and

were S32W

surveys

run had

N8OE

was

1862

to

The nozzle was oriented

jetting

orientation

the

the

ft

three

at

jetted

1850

ft

is

100

25

has been

ftwas

1799

at

second

direction

5l.07x4.28/100

well

1752

to

1931

to

et

1745

depths

survey

The

to

geology

typical

from

inclination

SIDE

8.37Overall

Fig

of

run

jetting

hole

et

change

SIDE

If

Millheim

after

same techniques

the

1.5

change

45.0

configuration

with Ui CD

of

length

BHA

angle to

on

The measured change

in direction

66

approach

is

can

Using

be analyzed

similar

From 1850

to

from S32W other

the

1862

ft

to

jetting

14

S3OE runs

131.0

DIREC11ONAL

AND

DRILLING

CONTROL

DEVIATION

377

with Drill

Nonmagnetic

Collar

line

slick

Some

Another face Bent

Sub

ductor

or

the

in

the

cable

bit

and

drilling

The

wireline and

ac con

by batteries the

by

tool

and

circulation

tool

located

is

measurements are taken

measurement-while-drilling

called

is

it

and

cable

magnetometers

powered

the

per

surface

tool

This

section

Angle the

near the

drilling

BHA

MWD

Sub

fluid

the

cable

the

measurement

If

tripped surface

inclination

supplied

generator

is

are run on

of

be

braided

the

conductor

direction

can

hole

from

at

are run

line

conductor

the

arrangement

Power

during Bent

to

an

the

tools

measure

celerometers

of

down

gyroscope

way

with

is

while

measurements

power

battery-powered

Sub

Orienting

of

supplying

sand

go-deviled

of

tools

Magnetic on

are run on

tools

reading

the

collars

drill

dropped

gyroscope

mitting the

in the

be

or they can

wireline

steel

or

cable

steel

surface

the

or from

batteries

on

and

urements

the

measurement

various

the

presents

of operation

principles

the

that

factors

affect

tools

meas

the

corrections

necessary

Bit

8.5.1 Fig

8.39Bent

sub

unconstrained

and

constrained

Magnetic

The magnetic

in

wellbore

tion

direction

and

or photographic

1931

to

63 33

.58/100

and

ft

measured

ft

The measured

1.2.7

is

16

From 1925

4.28/1O0

and

this

The

ft

floats

in

the

20

fluid thereby post and of

types

and

units

compass

Fig for

paper

inclinations

the

friction

8.42

shows

various

In

indicator

inclination

the

angle

typical

70

to

minimizing float

the

inclina

shows

direction and

the

the

sensitized

records

either

8.41

Fig

to

on

face

tool

for

arrangement

the center

is

instrument

film

unit

compass

Instruments

Single-Shot

single-shot

between

some of

single-shot

devices

8.5 The

Directional

urement and

of

the

weilbore

measurement

the

nozzle

large

sub

Inclination netic

single-

tishot

and

inclination

tool-face

bent

is

on

or bent and

is

to

an

bit

by

various in

The angle

meas

the

Sec

depths

sample

inclination

70

and

be

measured with

gyroscopic

are self-contained

or

single-

and

are

mag

are

mul

40

30

the

faces

of high

right

right

inclination

tool

of high

inclination

as

are

units

of

20

the

119 and

the

70

17 direction

to

S2OE

JETTED SURV

1722

ORIENT FINAL

1799

174552 S32W 2.25

JETTED SURV

S9OE S3OE

ORIENT 2.75

FINAL

1877

SURV

S36E 3.25

FINAL

8.40Exampleofthreejettingstopswhiletryingtokickoff

S36E 3.25

ORIENT

N8OE

NOTE

Fig

1877

3.0

S2OE

192531

JETTED

186062 1814

and

set

the

1940

DRILLED

wellbore

N7OE S66E 4.75

BETWEEN

lead

JETTING

after

RUNS

Millheim

and

the

side

and

125

unit

as

S36E

S36E

530E

2.25

compasses

of high

right

respectively

78

the

MMO

N7OE

S32W

to

The

565E 49 inclina SI3E The scribe lines

orientation

side

side

80

and

to

orientation

inclination

method of

magnetic

shows

powered

the

from

range

tool-face

20 70

6.5

74

and

that

units

for

line

for the

S8OE

S73E

tion

scribe

readings

indicate

stabilizer

AC

inclination

with

8.3

whipstock

orient

eccentric

70

to

housing

direction can

tools

at

presented

required

jetting

or multishot

All these

determined

direction

one of the calculations

by

Measurements

Drilling

of

trajectory

eta.5

133

or

378

APPLIED

ENGINEERING

DRILLING

Pendulum Circular

glass

Compass Pressure

Cover

O-20

AngI.Campu

Fig

O-70

A/C

AngtsCa.np.u

Unit

8.41Schematic compass

equalization

glass

diagrams unit

UNITS

of

magnetic Kuster

courtesy

PLUMB-SOB

UNITS

Unit

single-shot

angle

Co.

INCL

ONLY

UNITS

Indicated

inclination

Direction

of

450

inclination

orazimuth45 aScilbs

LM

wI$aO

Lii

8.43Pendulum

Fig

Liii

after

unit

eta

Eikelberg

wICoin9..

PEE

S47E

WEE

A/C UNITS

Other

inclination tect

the

Ei LOW

SIDE

Lii

have

ci

Lo-

over

SIDE

inclinometer

the

to

_________

VTo.I

8.42Single-shot

film

courtesy

of

Kuster

Co.

of

until

unit

stops

the

timer

by

ress

of

help

orient

is

procedure vate

instruments

face

line

which

in

the

and

the

suspension

see

unit

with

to

stopwatch picture overshot

single-shot

face the

make

When wifi

The or

timer

on

and

are used

for

that

to

into

the

up the

the

operation

is

is

does

stop

then

when

to

is

with

8.46

prog and

The to it

to

usual

acti

down

surface stop used The sur

instrument

the

Fig

the

well

drop

the

taken

is

instrument

timer

retrieved

drillpipe

not acti

change

and

is

up

When

monitor

activated

motion

indicate

tool

the

tool

unit

of time

picture

trajectory

film

The

period

complete

the timer

unless

started

single-shot

or deviational-control

load

to

drillpipe is

tool

timer

the

watch

the

units

high-range

assembly

for

to

comes

light

directionalthe

set

inertial

comes

unit

the

typical

and orientation

90 minutes or by an

the

that

pendulum

arrangement

Cardan

de

to

unit

compass

The

rose

internal

diagram

either

vate

OIi.iitatIoii

disks

type of

units

main Cardan suspension

on an

landing

Single-shot

PIG

the

moves

is

bottom

triggered

_______

on

measure only

to

lines and

8.44

Fig

UNIT

units

Cardan-suspended

compass

moves

Fig 8.45 LOW

by

dual Cardan-suspended

compass

UNIT

plumb bob

different

inclination

moves

that

G.10

/Sctlb

shows

8.43

Fig

show

units

with and without scribe low side of the borehole

measures

Fig

unit

single-shot

S.10

S.20

wlScflb

and compass

inclinometer

suspended

to 170

for

either

shows

has taken wiretypical

DIRECTIONAL

AND

DRILLING

DEVIATION

CONTROL

379

Running ple

used

can

becomes

tion

Another

solve

SCALE

the

However the case

tool

only

the tool

shoe

knee

housing the

on

MMO

an

If

shadow

that

The single-shot that

the

in

only

tool

of

in the

compass

line

on the outside of the collar

made

is

scribe

the

up

on

line

the

ture

will

tion

of

show the

scribe

correction

makeup tion

is

obtained

is

on

the

regular

face

col scribe

by

tool

orienting tool

of

and

the

pic

true

direc

the

this

graph

When

picture

the

and

single-shot

indicates

collar

of

so

spaced

instrument

are observed

single-shot

method

is

nonmagnetic

an

the

orient

in the

go

MMO

drill

or

mule-shoe

tool

When

considered

This

jetting

identified

which

graph

line

on

superimposed

the

is

An

noted

shadow

to the

collar

nonmagnetic

or bent

has

of the orienting

positions

make-up difference

the

magnets

the mule-

for

single-shot

in

placed

The

of the

in

sub

stabilizer

tool

shaped

lar

location

col

arrangement

the instrument

used

is

graph

the magnets

opposite

is

direction

orienting

used

bit

eccentric

an

and

bent

the

re

tool

mandrel

positioned

nozzle on

of

bottom

the

sleeve

is

up with

line

large

wedge

mandrel ing

to

blade

undergauge

whipstock

is

the

orienting

sleeve

orienting

orienting sub

because

single-shot

nonmagnetic

mule-shoe

tool

the

quickly

mule-shoe

sub or

shows

The mule-shoe

with

either

vacuum

and

rise

temperature face

to

The case

like

case

must be retrieved

To

used

is

film unit

the

film

picture

case

works

and

the

high

black

in the

between

gap

slows

of

too

protective

tool

still

bottomhole-orienting

Fig 8.47

in the is

depths

the inclina

if

pumped down area where the

be

must

sur time

the

shallow

Also

yielding

buildup

of the use

the

quires

tools

sim

is

when

well

the

for

hole

special

vacuum

the

depth

exposed

single-shot

Orientation

lar

the

the temperature

flask having

of

temperature

problem

over

fits

consumed

minutes

deep

data

interpreting is

the temperature

If

completely

that

retard

INCLINATION

taken

is

be

will

for

the

is

the

few

excessive

problem

survey

COMPASS

on

from

range

more than an hour

to

and

time however

rig

run depending

is

vey

tool

single-shot

Valuable

direc

tool-face

orientation

is

the

is

rarely

now

used

8.5.2

multishot

The magnetic numerous

instrument

records

survey

down

dropped

Instruments

Multishot

Magnetic

the

one

in

or

drilipipe

is

is

running

run

of taking

capable

on

either

It

wireline

in

is

open

hole Fig 8.48 Fig

8.44Cardan

suspended

single-shot

to

compass 900

unit

and

after

the

that inclinometer

Eikelberg

instrument

instrument

is

Fig 8.49

collar

netic tishot

unit

compass

for

eta.8

multishot

is

spaced

is

bottom

shows

Fig 8.50 camera sections The watch

component parts and the

cam

rotates

drives

on

the

series

the the

of

gears

of

light

and

landed

trip

out

length of

tool

in the

survey

for

enough

long

is

usually

picture

nonmagnetic is

stand

however

taken

More by

drill

The

the

film

to

be

down

closely

stopping

spaced the

gear

and

turns

drillpipe

During

the

90

the

every stations

pipe

the

motor

taken

the

collars

approximately

uses

Geneva

the

drives

dropped

and

between

camera section finally

watch

the

cam The

timer

connection

electrical

that

of

wound

spring

operate

the

showing

sides

wheel assembly which advances

multishot

obtained

an

motor and

the

is

to

mainspring

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and

batteries

and

of

power

way

nonmag mul complete the

landing both

such

in

to

adjacent

depiction for

rigged

landed

fl

could

movement

be at

APPLIED DRILLING

380

ENGINEERING

IPEARNAO wime

LINE

SOCXET

OVERSHOT

HOLDING

PL.AT

LIFTING

SAIL

ROPE

NOT SHOWN

SOCKET

NOT SHOWN SWIVEL

STASIuZER

STABILIZER

FiNGERS

A1.UMINIJM

EXTENSION

BAR

r.3.4-s-

BRASS

.OCK

MIN

CLOCK SOLiD

BAR

SINKER

MIN

90 STATE

BATTERY

ELECTRONIC

0-10

ANGLE-COMPASS

UNSI

0-.0

ANGLE-COMPA55

UNIT

0-20

INCLiNATiON

0-70

ANGLE-COMPASS

0-70

INCLINATiON

ONLY

INCLINOMEtER

20

STANDARD LOW

SIDE

NOSE PLUG

PLUMS-SOB PtJJMB.505

COMPASS UNIT

SHADOWGRAPPI ORID1lso

UNrr

PLuUB.BOB

NCUNOMETER

10

UNIT

ONLY

INCUNOMTE

SPRING

I1MER

CASE

COMPASS

ASSEMBLY MAIN

FRAME

SPRIP4G_lr

NOSE

PUJG ASSEMBLY

ALUMINUM MULE

SHOE

LANDING BOTrOU

HOLE

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sOLE

ORIENTisO

SLEEVE NOSE

STEEL

SOFT

Fig

SPRING

SUB

ORIENTING

BOTTOM

EXTENSION

l--3-.--5-

MANDREL

HOLE

8.45Typical

ORtWTA11ON

magnetic

BOTTOM

single-shot

tool

with

landing

sub

RUBBER

LANDING

courtesy

NOSE

ASSEMBLY

of

Kuster

Co.

BARS

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

381

desired point and

ment

on

with

when

exposed

the

hours

and

film the

where

is

can

it

and

read

and

of

exactly

were used

is

stopwatch

lower

indi

dial

pictures tool

the

down

broken

is

onto

picture

that

screen

see Figs 8.52A and

are used

readings

units except

in

and

read Special readers

project

easily

knows

the

60 the

and

inclination

single-shot

the

taken

sets

synchron

is

records minutes

dial

completed

developed

be

how

turned

is

many frames

how

and

illustrates

is

frames

Direction the

taken

records

survey

the

count

of

operator

the

The upper number of pictures

Once and

that

picture

dicates cates

so

being

Fig 8.51

take

to

is

picture

The watch

instru

the

timer

the

started

also

timer

the

When

picture

the surface and

at is

stopwatch

ized

for

waiting

assembled

is

that

are

identical

there

those

to

are no

tool-face

readings Multishot Fig

ticular

8.46Typical

single-shot

surveys

are

usually

surveys

and

are

surveys

are considered borehole

the

affected

Collar

Single

in

and

Bent

Face

View

Shoe

mud

with

Via

Mule

Shoe

With

Probe

Sleeve

Orienting

Up

Bent

Lined

Sub

Sub

shoe

Key

Position

Mud

unit

of

drilled

ed

and

the

last drillpipe

into

the

and

The wireline

Existing

more and more

need

for

Centerline

ly

is

in

the

point

Centerline

there

that

is

depth motor

mule shoe

for

orienting

mud

the at

top of

the

The

steering

direction

gate field the

and

in the

The

of the

to

The and

string tool

of

is

that

measure

the

planes be

From

be

to

earths this

up

the

this

and reset

restarted measure

measured by

summed

tech

so high

tripped

means

Direction

and

is

When

sub can

operation

inclination

components can

short

side-entry

the

this

sub reaches

wireline be

the

General

inclination

the

the

new

with

surface

the

out

without

feet

run

The

drillpipe

With care

electronic

uses

let

the

side-entry

can

drillpipe

of

side

hundreds

damaging

retrieved

the

the

the

is

continues

conventionally to

until

leakage

tool

sub and

added

is

Fig 8.54

steering

drilling

pull

sub on

orienting sleeve

in the

added

to

fluid

prevents

where the

borehole

magnetometers

vector

sub

drill

continued

tool

hole

the instrument

reached

steering

into

the

orient

the

need

the

side-entry

that

clipped

to

stand

connect

is

insert

side-entry

be

is

to

risk

is

the

run

is

into

another

tool

90

every

retrieved

and

steering

Fig 8.55 As

drillpipe

used

tripping

drilling

to

seated

can

drillpipe

be

is

tripping

in in

of

can

ft

be

overcome

to

of the

secured

is

kelly

nique

90

is

joints

as

way

side

back

set

circulating

done

is

by

orienting

through this

should

the

arrangement

illustrated

as

is

operation lowered

is

mule-shoe

If

used

is

typical

instrument

tool

after

box

stuffing

wireline

the

the

covered

more eco

and

probe

the

tool

with

stand

every

of

be passed

steering

steering

the

built

the

in

drillpipe

reseated

instrument

side

seated

is

the

the

conventionally

of

be

will

is

direc

magnetism of

wiser

instrument

The top stand

Then

the

is

8.47Arrangement

surveys

sub or housing

schematic

An

and

hole

top stand

added

The

Fig

trajec

surveys

trajectory

factors

bent

The wireline can

ing sub and

New

the

and

sometimes

is

is

tool

mounted on

head

the

Motor

8.53

steering

sleeve

is

Mule

the

single-shot

these

with

tool

steering

wireline

ft

Bent

multishot

of

Tools motor

nomical Fig

Sub

Orienting

Sub

All

the

single-shot

section

Steering

running

Tool

the

single-shot

general

earth

drillstring

this

When Mule

the

and

the

par

Shot

8.5.3

of

on

of

series

multishot

the

than

same instrument

the

than

of

run Because

more representative

inclination

position

wellbore later

of the

by

the

tion NonMagnetic

run with

end

at the is

closer together

surveys

The accuracy Neck

Fishing

Direction

casing

operation

tory of

Top

are run

typically

of hole before

section

flux-

magnetic

measurement to

determine

382

APPLIED

BOTTOM

ENGINEERING

DRILLING

LANDING

ROPE SOCKET

STABILIZER

RUBBER

DRILL

COLLARS

WITH

PINS

BATTERY

CASE

BATTERY

CONNECTOR POSITION

CONNECTOR SHOCK ABSORBER

PROTECTIVE

WATCH

ASSEMBLY

CAMERA

ASSEMBLY

INSTRUMENT

INSTRUMENT

BARREL

ANGLE

UNIT

I-i

BARREL

LOWER PLUG

BALL

ALUMINUM SPACER BAR

fJ1

-LANDING

BOTTOM SHOCK ABSORBER ASSEMBLY

PLATE

Fig

Fig

8.48-_Typical

arrangement

ment

after

for et

Eikelberg

landing

multishot

instru

al

8.49Drop Co.

gives

the

which

to adjust

of

the

out

multishot

directional

face

tool

the

correcting

weilbore

direction

celerometers two of

axes

the

tool

Fig

is

of

the

related

tool to

recorder

driller

Most

direction and

to

70

measured by

is

face

is

data

referenced

gravity and

and

picture

tool-face

tools

angle

Above to

readings

tool-face

steering

be determined

can

magnetometer

the

Figs 8.57A face

below

face

puter with the gle

Inclination

measure the gravity component 8.56 shows the The arrangement

that

the

of

hole

the

typical indicator

constantly Therefore

to

angle

the

WOB

an

the

direction

steering-tool

sense the

near

increases the

bit

and

sur the

tool

even

and

drills

steering

of

inclination steering

bit

the

reading and

accelerometers

mounted

tool-face

ments

com

by

70

ac

along

making

use

tool

to

costs

4000

tory

tool

one

is

face

are used the

ft

sets

Table

of

change

trajectory

are high and

change

is

the

for

to

make slack the

applied

expected

continuous

minor adjust off

weight

on

reverse torque

back

rotates

with control

guesswork

the

constant

can

readings

Kuster

to

the

right

as

off

sub or bent housing rig

operator

the

better

takes

angle

Having

As weight the

tool

of

information

achieve

to

tool-face

amount of reverse torque the

and

steering

courtesy

more

operator

the

mud motor The

of

instrument

survey

8.5

the

mud

for drilling

trajectory out

most economical

when

change

typical

motor

means and bent

especially is

below

steering-tool

when

3000 trajec

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

383

LIGHT

SWITCH

WATCH SECTION

GENEVA

LEVER

MOTOR

1GEAR

KNIFE

WINDING

LGENEvA

SWITCHMOTOR

STEM

WHEEL ASSEMBLY

LEVER SWITCH

TERMINAL

WATCH

FILM

SWITCH

8.50Views

Fig

8.5.4

As

Tools

early

with

as to

ways

logically stand

it

unit

Trajectory

were experimenting during drilling but techno

was

difficult

to

downhole

spinoff of

could

be

that

the

build

to

Various transmission acoustic

During Drilling

tools

that

environment effort

to

inclination

measured during

transmitted

of

companies

log formations

face

tromagnetic

camera

1960s

recognition

be

and

Measuring

lem was

could

watch

for

data

angle

the

of

the

harsh

the

reliable

SPROCKET

CAM

CYCLE

TIME

could and

overcome

transmit the

direction and drilling

and

with

the

prob

pulse

sion

as

used

One of the

An

was

could

the

by

the

setting

the

tool

Time

evolved

is

transmis

the

pressure-pulsecommercial

into

directional

near the

sys

community

drilling

bit to

of the wellbore

teledrift

initial

all

and

to

tool

of run

record

inclination

into

and

range

8.58

Fig

positions

must be made

hole The range

the

transmit

to

surface

the

various transmission

at

the

to

the

sub

Teledrift

be placed

the

Of

drilipipe

commercial systems offered which was designed as

earliest

inclination

before

and

Co.

Kuster

of

pressure-pulse

methods have

often

industry

the

SURFACE WATCH

courtesy

tool

the

methods

tems

that

elec

SPOOL

modulation

data

pressure-pulse

SUPPLY FILM

SPOOL

modulation or cable

depicts

were usedsuch

pressure

TAKEUP FILM

multishot

typical

tool-

the surface methods

DRIVE

is

for

2.5

Intervals

10 Seconds

15 Seconds

Moving For

Are

Lights

On

Film

Exposing

Delay Before

This

Is

An Allowance

Instrument Watch

Lag During

Survey 20 Seconds

Movement

Allowing

Without

Instrument

Of

Drill

Sufficient

or

String

Most

Picture

Affecting

Moves Require For Taking One

Idle

Is

Time

More Shots

While Moving

Minimum Time

15 Seconds

SYNCHRONIZE WITH INSTRUMENT WATCH BY STARTING AT THE INSTANT CAMERA LIGHTS

GO ON C..

ci

i..

i....

..a._.

......I.

..I.

Plumb Bob and Compass To For

Good

Picture

Plus

iI.Ik....

Settle

Allowance

For Instrument Gain During

Iff.

For

Survey

APPLIED

384

Head

Circulating

On

Drum

Near

Face

For

Cable

Floor

Drill

Tool

ENGINEERING

DRILLING

Driller

Ring

Surface Electronics

Inclination Direction

Printed

Results

Stranded Cable

Measuring

Fig

8.52A

Typical

Sun

multishot

film

reader

courtesy

of

NL

Sperry

Co.

Non-Magnetic Tool

Steering

Mule Shoe

Collar

Drill

Probe

Sleeve

Orienting

Sub

Bent

Mud Motor

Fig

8.53Typical

0.5

in

initial

increments

2.5

exceeds During

down

against

the

is

piston

clination

or than

greater trols

the

it

sion

is

Fig

8.52BProjection clination

of

and

one

survey

direction

frame

courtesy

for

NL

determining Sperry

Sun

in

Co

to to

position

of

shaft

is

the

the

reaches

the highest

position

of

the

the

forced by

pressure

where

the

pulses

Signal

strength can

on

depth

the

problem will

reduce

pulses are terials

in

the

pulses are detected

number of pulses and

the

of

arises

the

well

if

to

drilling

is

fluid

signal

150

psi

to

Another

may

plug

the

in is

rings

in

the

picks

strip

and

mud

the

mud

tool

up

chart

depends

of

at

to

surface

that

problem the

signal

from one

the

point

piston

the

to

on

or gas

transmission detect

the

data

to

the

inclination

begins

the condition

air

to

the stop

sending

the

from 60 and

the

recorder

by

bottom

forces

The spring ten

drillstring

prints

there

signal

difficult the

vary

the

As

inclination

pulse ring

up

off

pendulum con

down

pumping

rings

reading

inclination

setting

allowing

When each

the

piston

pulse

spring

if

farther

goes

the

proportional

piston

signal

maximum

upward

seven

is

signal

lifted

is

an

inclination

When

shaft

that

released accordingly

is

bit

The

the position

pendulum

the

outside

the

stopped

bit

2.5

only

keeps

spring

maximum range

the

advance

piston

lowest

terminated

is

setting

increases until

its

drilling

circulation

signal

to

to

If the

report

velocity

the

orienting

For example

made

be

will

fluid

for

15

and

can

teledrift the

tension

needed

and

the

drilling

pressed

2.50

to

tool

steering

between

of

setting

of

operation

either

which

the

that

ma

is

Properly

DIRECTIONAL

DRILLING

AND

DEVIATION

CONTROL

385

Use

Kelly

and

Swivel

For Cable

Drum

To

Down

Feed

Side

Loose

Left

Cable

of

Drill

Side Entry

Sub

Cable

Wire

Sub

Orienting

Sub

Bent

Mud

Fig

and

ings

as desired can

and

pumping

is

are

well

Even

be taken

of

various

the

and

reliable

to

though

The two

tems Fig

8.54Side-entry

sub

ther

most the

for

common

tool

is

positive-

and

still

tools

wide range

MWD system

systems

can

when

read

of

are

drilling

can

drastic

diminished

MWD

has applica

inclination

that

modulated-pressure-pulse

The pressure-pulse into

this

mud-pulse

economical

tool

decisions

point

use has

its

ations

pulse and

the

the

any time

at

Thus

stopped

deviates

run periodically

vent

obtained

tool

steering

As many

wells be

with

however

operated

for deviation-control

before

sub

side-entry

tion

must

Motor

8.55Using

maintained

Probe

Tool

Steering

Pipe

be

available

with that

the are

drilling

the

subdivided

negative-pressure-pulse

and

ad now situ

pressure-

transmission be

made

measures

sys fur

systems

386

APPLIED

DRILLING

ENGINEERING

M3

MAGNETOMETER

Fig

surface

8.57ASteering-tool Sun

panel

courtesy

of

NL

Sperry

Co.

ACCELEROMETER

KEY

Fig

of 8.56Arrangement kelberg eta.8

Fig 8.59 hole sensor and

tion

depicts

the

power

received

are

computer nation

floor

which

section

surface

to

inclinometers

magnetometers with one

meter

is

are

magnetometers correct

and of

obtain

The

of

from

of hole direction

to

the

is

downhole

of binary

signals

that

sure pulses or to indicate

er

logic

positive

tinuous

wave

electronics

side

for

pulser

or

and

on

the

drill

floor

courtesy

angle of

flux-gate

can

be

read

inclino

meas

flux-gate

the

inclination

the

low

from

the

relation

of the

side

hole which

are encoded

they

DflHng

.m.iI..t

smeil

IWVt

8naIbn

signal

Fig 8.60

mud

located

Co.

rig-

with

package

are transmitted

modulated

Sun

readings are needed

measured by the inclinometers Once the readings are measured

through

three

three

derived

low

indicator

Sperry

unit

consist

Direction

the

magnetometers angle

tool

another

values

accelerometer

the

8.57BTooI-face

At higher angles

hence

axis

to

tool-face

and

the direction measurements

position

Fig

information

inclination

correct

obtained

to

incli

surface

MWD

an

accelerometers

hole Tool-face

the

ship is

the

in

At low angles

to

sec

signals

to

and

it

and

direction

90another

needed

urements

to

This

prints

of the gravity inclinometers

approaching

the

data

steering-tool

used

down-

the

pulser

transmitted

the

angle

which

the

and

converts

tool-face

Most sensor packages three

the

Ei

after

NL

and

inclination

displays

At

terminal

similar

display

the

unit

and

to

with

system

sensor-to-signal

processes

direction

transmitted

is

tool

steering

pressure transducer

by that

in

MWD

typical the

unit

sensors

by that

shows

siren

that

into series is

series

of

phase negative

generates

Sn

S9naJs

S1gnaJ

pres

shifted

pals

con

Fig

8.58Operation

of

teledrift

tool

after

Eikelberg

eta.8

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

TABLE

8.5EXAMPLE OF

387

OF STEERING TOOL DATA OF MEXICO DIRECTIONAL

GULF

FOR WELL

OFF

KICK

Bit

Depth High Start

End

ft

Magnetic Seat

ft

820 910 910

1156 1156 1212 1212 1306 1306 1398

The and of

negative

closes

the

fluid

drilling

to the

causing

negative

pressure pulse

133.5

356

13.0

122.1

59.6

50.3

137.3

359

12.8

122.4

59.7

50.6

83.8

309

16.3

115.0

69.6

49.4

62.9

289

16.7

113.5

597

494

and

shuts

tion

must

encode

the

fewest

of one

PDM The

in

detect

to the

The

negative

of

29.7

112.4

58.8

48.9

337

32.7

111.7

58.8

48.8

112.0

330.1

37.3

111.7

58.7

48.9

101.8

322.2

38.5

111.6

58.5

48.7

104.9

320.2

38.7

111.7

58.7

48.7

129.3

342.5

44.0

117.3

58.6

48.9

an

by

the

The

that

small

fluid

that

rotor

rotors detected All

at

batteries

or by

of

valve

them

transmit

and

last less

than

during

bit

100

some advantages

valve

8.6

in that

the

The

the

bit

system

is

about

of

par

for

making

PIT

on

going

is

that

with

by

that

as

are

turbine

debris collars

of

that

and

turbine normally

bit

is

turbine

not

system

rate

after

Gearhart

et

a.9

bit

systems

the

to

the

tolerated

be

passed as

easily

0.5k

VELOCITY

JETS ILl

by

FIG.lb

through the

PULSE

COLLAR

fORILL

RESTRICTOR

ILL

ILL

ACTUATOR PULSER ASSY

have

fluid

The turbine type of

POSflIVE

P2

runs

system

drilling

by

PULSE

ASSY

is

replaced

MWD

of

and

be

NEGATIVE

or

either

most

can

P10.11

1K

PULSER

downhole

the

COLLAR

ACTUATOR

HIGH shift

P3

1-ORILL COLLAR

STA

TOR ILL

ROTOR

fluid

Lost-circulation material could

fRiu

turbine

The lithium batter

pressure loss

flow

MWD

VALVE

gener

logic

MWD

flow

the

powered

pack

battery

stator

The phase

interpreted

full

var

speed

by

turbine-powered

the

8.59Typical

P1

turbine

the

down

systems

the

AND

for

The motor drives

modulated

is

is

PACKAGE

easier

Fig as

mud-driven

time depending on than 300 hours Because

to

the

through

tor/rotor

which

VALVE

SENSOR

pressure

of data

set

BYPASS

and

drillstring

same

the

by re

minutes

to

significant

sensitive

FLOOR

DISPLAY

angle3 exam

positive

transmit

to

is

almost

without

S67E

an

is

pulse and

Battery-powered

they permit

44

the

for

works

actuator

down

fluid

conjunction

over

S67E

RECORDER

opens

set

tool-face

pulse system

powers 300 cycles/sec

hours

change

38

15L 30L 30L 30L 40L 15L

the

with

and

Table

the negative

MWD

less

S68E

brief

time To transmit

mud-driven

to

temperature

32

5L 4L

RIG

the operating

limit

S67E

change

surface and

the

commercial

29

wear and power consump schemes are used to

up or slowing

speeding

S68E

opens

duration

motor whose

wave

2150

50L 50L

S65E

300 psi

to

the

quickly

to

with

in

that

16

3L

S58E

amount

causes

100

The

pulse

how

negative

based

is

actuator

drilipipe

needed

system3

siren

carrier

drill

345.5

119.0

drilling

between 200 and

other

126.7

fl

ates

to

49.1

pressure pulse

generator

turbine

ies

59.2

time required

pulse

turns ies

111.7

direction

pulse system

mud

The

29.5

turn-on sequence

greater than

positive

356

and

are

pulser

flow

be

136.9

115

complex

for

of

positive

pulse can

49.4

to

trajectory

positive the

49.3

59.3

shortest

typically

reading

creating

59.7

111.5

annulus

data

the

time

motor

stricting

111.4

22.7

valve

of inclination

minutes

ple

both

sensor

pulses

check

to

20.0

355

considered

dataincluding ity

353

pressure

Because be

130.0 135.0

Readout

Inclination/Direction

degrees 50.3

discharges

Picture

Magnitude

62.2

in

related

is

Dip

122.1

that

small pressure decrease

degrees

7.4

works

pulser

small valve

Azimuth

degrees

333

950 1031

Inclination

105.4

950

1031

Side

Seat

01

TOR

or

ILL

the

sta Fig

8.60Basic

types

of

mud

pulsers

after

Gearhart

eta.9

388

APPLIED

TABLE 8.6TYPICAL 10 1984

April

1115

AngIe

MDIP67.7586 3946 2602 2526 2560

Amoco

OF

NEGATIVE

Production

Anschutz

PULSE

Tool

Face

TMF

XVZ

128

EX EY

0.019

0.015 1.001 TMF

EB

EC

0.306 0.292

EZ

AFE-West

Lobe

MWD

TEMP DTMP

Elec

Number

Mag

Number 302 203325

INC

0.0

MDC

1.37

RDT

127.98

AZI

110.05

15.0

74.4 49.4

0183.03.MSC

Development

W-20-04

Well

RC

Method

OTF

24.62

1.226

MWDD Field

AB0.0239

24.60

0.4229

12-31-83

370OE

Direction

TGF

1.1097

XY

Survey

P.01

203420

EA

2032 2040 4308

SYSTEM

Ranch

81

Corn

Drift

1538

OUTPUT

ENGINEERING

DRILLING

Number

Survey

130

149

12-31-83

Parameter

DGT

DGT

DGT

Counts

3946 2682 2536 2560 2022 2040 4308

11

14

15

15 15

13 10

Depth

1039700

115 70OE

Angle Direction

Face

Tool

28P 30

15

DAC

DDO

70

DDC CL

4.100

TUD RCN/S RCE/W

10349.45 152.08 243.97

SECTION

287.32

DLSICL

0.12

DLSI100

FT

0.30

PDD TEMP TMF TMF DIP ANGLE

60 74.42 1.1097

XY

.4229

87.7586

ANG CORR DIR CORR MDC

15

OTF

000

An hole of

hand

is

that

electronics

cable

be used

of

the

data

essary

related

stage

to

to

very

in

the

with

tolerant

systems

and

that

drillpipe

which

must

kelly

to

the

and

is

cable

they can

be used

it

to

surface

is

cables

slip-ring

transmit

MWD

tools

slick-line

unit

new generation of and

retrieved

with

Also

developed determine

WOB gamma for

formation

and

outputs

Ad

sensors

of

other

drilling

ray and

downhole

MWD

can

and

overshot

sensors

8.61A

Fig

with

in

is

as

and

used and

are used

are

and

drilling

hole

being

torque

logging sensors

resistivity

system

run

are being

such

parameters

evaluation

an

be

that

typical

logging

trans

with

that

electric the

still

systems

communicate

can

The disadvantage

are

drill collars

electric

are

systems

signal-transmitting

in the

rotating

MWD

designed

conjunction

rapidly

ment on the kelly from the

more

electromagnetic

electronics

are suspended

is

lee

the

down-

the

industries

to

to

specially

hard-wired

handle

and

to

temperatures

and

vantages

downhole

actuator

on

generator

more power

supply

valve

developments

drillpipe

mit

turbine-powered

can

and

the prototype

electric

the it

bottomhole

high Other

in

of

advantage

other

Gearhart

of

Courtesy

the

nec that

arrange the

data

instrumentation

8.5.5

Surveying bore

instruments

direction

on

must be corrected and netic

magnetic field

and

Reference

Magnetic

the for

that basis the

north Fig

Interference

are used of

the

to

difference 8.62

showing magnetic

measure

earths

between

depicts

north and

the

magnetic

the

wellfield

true

north

earths

mag

true

north

The

DIRECTIONAL

AND

DRILLING

GAMMA

DEPTHS

RAY

CONTROL

DEVIATION

AMPLIFIED

389

RESISTIVITY

ANNULAR

TIME

TEMPERATURE

100 COUNTS

PER

SECONO

OOWNHOLE

DEGREES

THOUSAND

FAHRENHEiT200

SHORT

NORMAL

IWSISTIVITY

ON

DIRECTIONAL DATA

BIT

POUNDS

OF

00

TORQUE

M3U

OHMS

WEIGHT

DAY

OF

M3M

OHMS

WEIGHT

SURFACE

hubs

THOUSANDS

ON

BIT

POUNDS

OF

10

100

RIG-LOFFLAND

15.8

5800

15.6

714

15.8

5900

HL1H

841

1ti

1040

6000

15.6

-..4-

349

5736

349

5728

349

5797

352

5659

15.4

351

5690

15.1

349

5726

15.2

350

5957

15.1

350

5990

14.9

352

6027

14.9

352

6038

15.0

352

6082

351

6116

6100

1445

15.2

62

1736

15.0

351

6149

15.1

351

6175

15.1

351

6208

14.9

350

6239

14.7

351

6271

4.8

351

6304

4.8

349

6315

14.8

349

6366

6300

6400

14.0

347

6457

13.8

347

6477

6500

Fig

reacts

compass netic

moved

tion

and

with

changes face

horizontal decreases

how on

ence

mag

netic

the

isogonal

where

The

8.63

the

8.64

much

between

angle

Fig

lines

the

lines

correction

the

and

position

shows

is

survey

angle

sur

MVVD output

multisensor

component of the mag when the compass is

on

Fig

U.S The

the

indicate

depending

is

see

and depends

time

for

angles

declination

made

north

true

of the earth

features

Table

the

reaction

northward Declination north

netic

to

the

field

ATypical

8.61

of equal

magnetic

the

8.7

65%

TX

Christi

and

the

What

quadrant

are

directions

the

is

well

drilling

near

are reading

correction

for

all

the

Corpus in

the

SE

direction

readings

is

The

declination

Because

subtracted

from

it

an

is

angle

east

near

Corpus Christi is 7.75E must be declination

direction readings

the

ever than to

are

Besides

vent

making

special the

care

effects

correction

when

running

of magnetic

for

true

magnetic

interference

north one survey

Such

to

must pre

interfer

netic

and

basic

of

be

and

the

earths

compositions

30%

copper

approximately austenitic

8.65

collars

the

bit

the

and

not

corrosion

and

18% steels

more

both

operations

resistant

that

damage

to

require

to

salt-mud

beryllium

copper

drilling

austenitic

in

mud

are The chrome/nickel

the

does

stress

premature

shows

between

of the

The disadvantage

most

for

steels

for larger

isolates

steels

Monel

considerably

collar

four

13% nickel

to

The

gall causing

collar

above

distortion

containing

alloy

susceptibility

austenitic

Fig

of

are

steel

com

the

separate

and

collars

too expensive

cially

take

drill its

the

mag

minerals

diagenetic to

and

collars

collars

over 18% man manganese bronzes beryllium copper austenitic steels are used to make most non-

and

magnetic

are

7.75E

more than

Currently

steel

an

steel

nonmagnetic with

chrome/nickel

environment

Solution

in

prevent

collars

chromium

on

ganese

You

to

5TM

chrome and

8.13

The

field

nickel

based

Example

to

proximity

spots

formations

and

compass

Monel

be

see

by hot

Nonmagnetic drill collars are used fields of magnetic pass from magnetic low

made

caused casing

storms and

declina

should

be

can

by adjacent

the

high

steels

how

corrosion steel

threads

makeup

tends

espe

torques

compass located in nonmagnetic and the steel collars The nonmag

distort

interference

the

earths

field

magnetic

lines

from

the

field

lines

sections

PER

SECOND

RAY

50

EE

r-

EEE

flinInii

COUNTS

GAMMA

DEPTHS

47M

4500

4400

4300

4200

4100

1100

Fig

GRAVITY

TOOL

8.61

FACE

BTypical

DEGREES

multisensor

360

TOOL

MWD

output

ft/lbs

TORQUE

DEGREES

MAGNETIC 360

FACE

TIME

0.0

0.0

00

OF DAY

1_I

11E

OF

POUNDS1

I-

ON BIT THOUSANDS

00

00

ON BIT

POUNDS

DOWNHOLE WEIGHT

OF

WEIGHT

THOUSANDS

SURFACE

11.1

80

8.9

60

20 25

07 05 09

03

07 07

356

360

366

366

11

11

17

4872

4744

4731

4776 4776

4603

4493

4461

4391

4367

4311

4266

4234

4206 105

4184

110 196 202

DIRECTIONAL DATA

-u

DIRECTIONAL

DRILLING

AND

DEVIATION

CONTROL

391

West

NTNM

East

Declination Angle South

Fig

8.62Earths

magnetic

field

Fig

9o

Fig 8.64-_Isogonc

8O

85

chart

for

the

75

U.S

10

8.63Declinatjon

APPLIED

392

8.7CORRECTION

TABLE

DECLINATION

FOR

Even netic

Direction East

Reading

lems

WesI

Declination

Add Subtract

SW

Add

NW

Subtract

to

Subtract

reading

from to

to

achieve

to

possible

reading

in the

ty below

and

the

collars

quired nonmagnetic

on

welibore

that

are

reliable

zone

the

locate

the

the

in selecting

of

location

and

inclination

the

of

direction

of empirical

compilation

is

number of re

data

number of nonmag

the

where

picked

is

curve

wellbore

the

and

inclination

expected

the

caused

by

direction

the

downward

located

is

direction

used

are

to

needed

Select

to

N4OE on

number of nonmagnetic

the

well

drill

the

north

550

to

inclination

col

drill

data

empirical

N4OE

and

need

the unit

at

direction

charts

the point

Zone

for

falls just

III

Zone 550

at

From

III

inclination

Curve

below

two nonmagnetic collars 10 ft below the center

the

ther

the Gulf

31

-ft

Mexico

of

interference

magnetic

and

30

of

directions

one

with

are used

collars

nonmagnetic

inclinations

tion

the

the

this

Drift

compass

and

31-ft

compass

the latitude at

the

set

already

has

The

There

are and

single-

Ferranti

directional

the

lar

to

kinds

on

cage as

multishot

rotor

external

bly tains

part

and the

motor shock

used

at

of

multishot

AC

electronic

the

error

surveying

make

to

drift

either

is

run

per

the

pole

of the earth

hour which drift

is

no apparent

is

the

tool

gyroscope

holds

clock the

and

drift

first

step

easy

on

the

running

gyroscopic

shows

Fig

8.71

solid

triangle

point

is

cased

to

to

determine

inner

the

always

point

pointed

Because

the

and

of

direction

stays

batteries

direction

is

determined

ing from some point over the wellbore fixed some distance from the wellbore

The lower

part

of

Cardan-suspended

components

for the

long

either

or

to

.JS ii

there are no

The

assembly

the

tool

7/

con

__

gyroscope

gyroscope

and

the

Fig

of

the

stake

bearing

it

rela

is

by making

the

camera assem

at

spin

scale

fixed

gyroscope

orient

zero

the

gyro

as

to

the

known

is

squirrel-

40000 rpm

speed

always

is

survey

bore-

horizontal drives

Fig 8.70

direction face

the

8.72

see Fig

of the reference

direction

tively

in

the

Of

aircraft

surveying

drift

dependent

must

simi

tool

guidance

by

prop

maximum When gy

at

drift

of

effects

is

with casing

gyroscope

is

for

accounting

in

magnetic

sends

must be run on

gyroscope

surface-recording

current

20000

complete

inclinometer

absorber

for

reference

its

the

the

the

Cardan-suspended

shows of

force

and

axis

most common

the

is

speed

runs

forces

Fig 8.69 upper

at

the

gyroscope

horizontal

instruments

gyroscopic

inertial

precise

high-frequency

rotor

the

of

modern commercial

Fig 8.68 depicts scope

the

borehole

or north-seeking

rate

instruments

the

holes

of

when

or

gyroscopes

highly

used

that

gyroscopic

magnetic

because

the

axis

the

surveyed

various

tool

when

used

used

multishot

gyroscope

for

horizontal

the

rotation

the

there

equator

gyroscope The

axis

casing

being

is

of

Fig

axis

gimbal

detennined

the

or

At

survey

or reference

of

inclina

an

at

be

by

amount of

Gulf

in the

collar

S75W

of

is

be

cannot

of nearby

terference

axis

left side

run the survey stations usually are hole with few check shots coming

mainly

caused

the

The reference

gyroscopic

or

right

movement

until

tools

the

done

gyroscope

Gyroscopic Measurement

instruments

the

vertical

its

it is

into

is

various

1.3

approximately

8.5.6

with

forces

frictional

is not as The gyroscope rugged as the mag more carefully and must be handled

When

is

shows

errors

at

drilling

drilled

nonmagnetic

direction

directional

25- 31- and two

for

well

fur

illustrated

is

Fig 8.67 which shows typical of Mexico area when 14-

by

in

by gravi

easier

indicating

with

from

the magnetic

roscopic of

and

horizontal

the

axis

vertical

going

out

and

effect

caused

motor This corrects

servo

to

Unlike

on

The

on

off-center

slightly

about

rotating

counterclockwise

wireline

in

is

for

to

by

by

im

practically

instrument

made the

force

adjusted

netic

Alaska

slope of

The north slope of Alaska

Solution

is

Fig 8.68 The gyroscope

in

gravitational

of the gyroscope

tare

or

either

erly

of

of influences

free

determines on right side The amount of this rotation the The tilt of the horizontal the of gyroscope accuracy sensor that detects any depar gimbal is corrected by

rotating

lars

the

bearings

shows

8.68

be

accuracy

to

commensurate

in

signal

Ezainple 8.14

for the

such

indicated

direction

compensates

would

it

exactly

the

collars

First

Then

Fig

fairly

drill

netic

8.66

on

depends

earth and

the

welibore

the

The

unit

compass

prob survey

be supported

could

Consequently show force

tend

will

gyroscope

above

accurate

obtaining

gyroscope

However

forces

external

reading

If the

center of gravity

its

reading

from

Add

reading

reading at

to

Subtract

reading

from

from

Add

reading

mag

by

introduces unique

very design

with

associated

not influenced

is

gyroscope its

Declination

information

NE SE

the

though

interference

ENGINEERING

DRILLING

8.65Source

of

magnetic

interference

sight

to

stake

constant

DIRECTIONAL

AND

DRILLING

DEVIATION

CONTROL 393

TheEarthis of

requirements of

horizontal

nonmagnetic

drill

data

empirical

magnetic collars

of the

intensity

used

particular

should

area

be used

30collars

60

below

onco

10

18

collar

below

center

30

25

collar

collar

to

below

center

30

60

collars

collar

to

below

center

60

collars

tandem bottom

Fig

Compass

to

18

25

center

determine

Which

set

bit

stebiiieer

60

40

30

hoe

50

60

only

70

wootic

itretw

Spacing to at

Compass below

center to

10

center

curve below

center

60

collars

60

collars

Ongit

weto

hon

Spacing at

center

curve

10

below

to

center

curve

of

curve

collar

8.66Zone-selection

to

cure

oeoc

Spacing

used

Charts

4embly

hole neat

atgle

Compass

is

ctrw

wOh

20

map

length

given area

Data

botton

abos

p4iat

and the geographically hole assembly should fit the

ctroe

below

pted

90

ho

be1w

collats

with

This

for

Empirical

varies

bottom

in

90

map and

charts

to

90

collars

determine

how

at

collars

at

center

center

many nonmagnetic

drill

collars

are

required

courtesy

Smith

Intl

mc

394

APPLIED DRILLING

reference

point

another

ing

shows

the

expected

than

on

100

Refer

to

index

example

setting

index

20

the

spin

axis

aligning

10

inclination

ble

This

be considered the

Again

reference

Eq

instrument

covered

later

case

the

but

object

is

the

3D

is

called

negligi

the

inter-

correction

index must be

determined

is

setting

8.67Typical

direction

interferenceGulf

errors

resulting

Coast courtesy

from

magnetic

8.58

where dr

NL Sperry-Sun

For

8.58 assumed

the

is

example

N2OE

is

must

aligned with

dr

Fig

case

Below

north

correction

index

the

with

and

10

correction Above

1-4

by

3D

the

be

will

the

opposite

is

which

in

axisi.e

spin

gyroscope

until

Dc

direction

Fig 8.72

by

less

up with

lined

is

that

be

to

is

stake

iis moved

thereby

cardinal

the

of two

one

inclination

inclination

presented

200 The

or

sighting

see Fig 8.71 in

Fig 8.72

initially

maximum

the

markeri.e

N2OE

is

If

index

case

the

stake

the

0-

the

reference

the

followed

is

reference

the

some

build

as

other object

referenced

is

such

welibore

example of

gyroscope

procedures depending is

the

or

rig

drilling

typical

When

from

away

ENGINEERING

20

or

hole direction

D3

if the

index

the

S17W

is

is

setting

197

and

determined

as

or

the

dr

follows

19720l77 When

the

north

errors

resulting

Every

making drift

initial

the

be

the

for

adjusted

tool

for

stops

orientation

case

the

and

The

survey

initial

the

inter-

shows

8.73

tool

the

still

called

checks

in the

intervals

sheet

for

survey Note that most of the check stops made going into the welibore only two were made

Once

data

the

made by

8.74

is

values

that

for drift

veying

be

applied

is

the

to

in

of

the

vertical

factor

scale

for

directional horizontal

axis

Fc

correction

which

is is

must

plot

on Fig 8.73 The

survey The minutes

correction

drift

drift correction

the

during time

of

data

drift

degrees

in

will

The range the

the

for

plot

the

are obtained

construction

the

measured

axis

gyroscope

com

out

ing

8.68Typical

or

gy were

roscope

Fig

an

wellbore

minutes

for

data

drift

orien

is

At 10-minute

tool

typical

initial

run

is

gyro

what

to

these

pictures

by keeping

or

oriented

is

CO From

estimated

is

more Fig

be

and

minimized

be

correction

gyro

20

of

dr

will

tilt

for drift

gyroscope

the

checked

is

should as

orientation

drift

initial

well

as

GO

case

with

from gyroscope

177

with

aligned

correction

After the

tation

is

aligned

reading

20

cardinal

be

will

survey of

offset

index

case

scope

the

Fig

vertical

correction

data

to

scale

is

correct the

determined

by

determined

from

sur

taking

Eq

8.59

FcD5j and

by

ments 19.8 the to

above

scaling

For

the case was

26.0

this

the

was

indexed

actually

177.0

and

The horizontal

from

duration

below

and

example presented

the

calculated

survey the

8.59

the

scale

scale

factor

in at

start

101.00

minutes

to

incre

Fig 8.74 Fc is 177.2 rather than

ranges

should

gyroscope

in

end

from

cover for

the

this

19.0 entire

survey

DIRECTIONAL

DRILLING

AND

DEVIATION

CONTROL

395

Fishing device

Rope

connection

Rope

socket piece

Connecting Camera

housing

Battery

6a

batteries

Dry-cell

Multi-shot

switch

Multi-shot

motor

clock

Camera

10 11

Lens

12 13

Pendulum

14 15

Pendulum

16

Circular glass

bulb

Light

housing

Cover glass

Filler

plug

Compass 18

Marking

ring

Cardan for

card

suspension

gyroscope

20

Electrolyte

21

Cardan

suspension

22

Cardan

contact

23 24

Gyroscope

motor

Gyroscope

housing

25 26

Gear

27

Servomotor

28

Converter

29 30

Plug connection

31

Gyroscope

32 33

Rubber

34 35

Safety

36

Gyroscope

37 38

Multi-range

39

Gyroscope

level

switch

brush

unit

Cardan

contact

brush

Nut adjusting

shock

Gear casing fuse

Voltage

Cover

regulator

ON-OFF

Hole

plate

for

telescope

Fig

8.69Components ter

Eikelberg

of

gyroscope

eta.8

compass

instrument

af

switch

voltmeter

battery

connection

40

pin

absorber

adjusting

396

APPLIED

ENGINEERING

DRILLING

Northern

-80

Latitude

-70

--60 40 30 20

10-

10

50 20

30 40

60 70 Southern

80

Latitude

90

15129

63

91215

Deglhr

Fig

8.70Diagram

of

depending of

apparent on

drift

geographical

for

every

latitude

point

on

after

Eikelberg

Earth

al.8

Fig 8.72Sighting

of

reference

object

cY

uTh The sequence

35111

on

ing

the

minutes

20 seconds

are eight

drift-check

which

stops then

coming

the surface tation

is

of

true the

the

8.71Gyroscope

face

this

presents

The and this

first

is

terline

between each

the

CO

correct sects

the

block

as

followed

determined

rate/hour

slope next

slope centerline

at

the

60

be corrected

shots

tool

tool

into

in

the

increments the

survey

errors

Problem

in

8.47

drift

from

this

centerline

.6/hr and

is

so

check

time

drift

scale

check

The

is

plotted

same cen

Next

starting

point drift

with

20 seconds

point

15

plotted

on

the

20 seconds

marking of the halfway of drift time The rate of

minutes

at

20 seconds

minutes minutes

the

by

each

on each

for

two blocks

for

point

rotational

surveying

misalignment

of data checkbetween

off shots

determine

to

center of

true

the

40 secondslasts

entered

is

the

turned

rotational

center

are taken

at

orien

case

is

and

ft

and

ft

any misalignment

The

the

that

survey

type

drift

is

of

stabilizers

records

200

survey

correct

wellbore

direction can

minutes

procedure

the

the

final

survey

of

to

determined and and

inclination

the

At

1815

to

ft

gyroscope

this

end

the

up

ft

1200

the

processed

is

with

survey

lowering

survey

be

the

with the

until

film

can

tool

at

100 at

the

center and

by

Six

of

before

tool

survey

casing

end

are taken

welibore

weilbore

Once

hole

seconds

performed Following

is

every

the

turn

with

begins

20

stops interspersed

was not done on

are obtained the

CO

are taken

the

survey

minutes

out of

At

it

sometimes the

for the

at the

performed

Although

Fig

of events

gyroscope

to

the

minutes

from

the

the by drawing inter point where it

seconds The next new point to the next

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

397

DRIFT

__.r

CUSTOMER

sNoSU73-O601 DATE

L.

READSY

8.2

DATE

AZIM

INDEx NORTH

A2lu

TIME

C.F

02-oo

FILMORIENT

OSo _________

CASIORIENT

07-20

20

_Z 7.i

DELTA

DEPTH

TIME

HOLE DIRECT

liii

I0

___f

ID

07

_______

31Ø.5 ________

____

-1 2CCI372b 3.3 IC

plotted line

straight

drift

average

Fig 8.74

case the

slopes

and

initial

the

is

drawn

minutes

20 seconds

seconds

The difference

tracted

from

rection

point

the

Note

calculated

ment

would

of

the

adjusted correction observed

than

10

g5.oo

.0

--

3Ib.0

surveying

data

sheet

CO

In

this

80 minutes

between

the

CO

between

the

if

drift

the

new

the

curve

drift

at

rate

data

for

will

20

is

sub

drift

cor

lines

line

the

survey

at

minutes

each

survey

calculated

which

87

two

drift-correction

curve

initial

at

the

average

survey to

CO

final

between

gyroscopic

As mentioned er

that

average be added

necting each

the

and

calculated

the

the

on

2.89

Io

The

ending

interval

survey

over

the

data

--

.ICI

oi8.5

drift

057

COs

final

line

straight

the

4.4

is

it

for

rate

and

3L19

31b.o

curve

drift

CO

initial

2o.3L4

lb

8.73Typical

calculated

yield

connecting

2O.l

o8-S

6-20I0 ORfiTr

3.00

IS

020.0

o_

Fig

.1

31.o3 o20oo

Li.o oz.O-J5

--ic

3.O

0.2

353

c2.3 ____

03

c.oSe

353

027.0 _________

-0C0q7 I-25 -oo

---

is

above incre

delta

Con

points

points forms be used

to

the

correct

drift Thne

before

whenever

correction

DIR

oA3

3LJ

3C

77

IHR

2.c7

3f3.8

o7

2O0

i815 RATE HOLE

DELTA HOLE DIR

3q

3.0

o3l-2Ol

Iioo

1200

7..

_______ DEPTH

TIME

77

__ __ Q31 Q4.8i-

1500

172.8

REAL HOLE DIR

177.1

oa

co co

r72 .8

__BOOM

INCL

AZIM

73

END

____

....JJZ

GYRO

TIME

07-20

the

-I

20

CORRECTIOd

_DR

__INCI__

TIME

START

oo

qq

7-

DRiFT

CHECK

-00

NO

___________

REEPTCI.cX

is

DATE

IS

AZIMUTH

GYROSTART

The

SO

8273

E.J

CHECKEDSY

J2

IS

NORTH

LN RuNNo_

SD TRUE

SHEET

242-

cvoo

82-

RUN

DATA

CO

OIL

the

inclination

must be made

to

is

Mm

great

account

for

Fig

8.74Drift

correction

plot

398

APPLIED

8.8DATA

TABLE

REDUCTION

DATE

NO

Read

DATA

REDUCTION

NA

By Obs

Meas

Jo

Hole

05

400

55

500

15

121 30-20

900

31-20

True

foci

TC Corr

-_L--

345

2fl

344.20

20

454i

Hole

Remarks

Direction

_fi5

17

349.5

40

25

342

1-40

1400

43

46-40

1500

40

25

48-40

1600

39

13

51

1700

00

52-20

1800

5940

351 007

25

ZIL

rc

AR

J5E

10 L9

24

11.04

1111

10

02

027.5

41

25

027

41

30

025.5

02

38

65-00

-c 015

NL

of

tilt

remains

the

LA

This be

can

arc

Table

tan

20

rection

the

for

19

41

020.91

19

40

41

403

61

an

the

horizontal

intercardinal

Eq

using

gimbal

correction

8.60

dr0

tan

8.60

that

observed

the

azimuth

gyroscope

by

hole azimuth the

is

cor EQUATOR

cor

intercardinal

each

survey If the true center correction is it would be applied to each survey or corrected azimuth The drift correction

real

yielding

added

final

22

enough

significant

to

8.8

difference

the

true

the rate

or

of earth

nent

of

axis

see

that

to

rotor

the

the is

level

that

and

spin vector

motor

that

of

the

real

gives

eliminates the

the

cor SPIN

measures

the

compo

the

earth

spin

rotor

at

joint

see Fig 8.76 Once

in relation

to

by

the

universal

12000

the

rpm

ROTATION

HORIZONTAL SPIN VECTOR

AXIS

and Fig

8.75Earth trechi

horizontal

EARTH

major

hole

8.75 drives

ER TN

assem

The

gyroscope

gyroscope the

drift

gyroscope

gyroscope

detects

LATITUDE

by

was not applied

or horizontal rate

azimuth

example presented

of

orientation

rotation

Fig

the

the

north-seeking

between

rate

from In

center correction

initial

gyroscope

the

azimuth

type of gyroscope

and the

or subtracted

hole

true

Another

pled

79

22.29

38.1

case while called

is

calculated

shows

8.8 to

rate

2i1

19

40.3

Xcosin0

the

10

Surwe

surveying

level

Acorr

is

34

343

15

Sperry.Sun

and

Acoff

rection

10.3

19

024.5

25

200

of

Couflesy

bly

10

ft

700

7-40

Table

10

28

7300

the

J4.1

ii1

34611

11014

38

-__

711

5_._8p 37 .jUU

4U-4U

__ __

Quad

True

Azimuth

20

L_ LI i1A

355

True

7n

000.5

lcir

31 55

Cnrr

M6.37

350.0

32

Drift

AZ

fl

21

1000

or

365

44

27150

Real Corn

cop

iiiL

700 800

nd

At

000.5

_41_45

28-20

Gyro AZ

10

2c2n

either

_______

UN/OUTRUN

039 040

12

11i

19-20 20-20

Obs

Mm

1c

JiIii 700

7-

lrcl

Deu

Deoth

ic_nfl

rected

__________

SHEET_OF

SHEET

Checked

rune

the

ENGINEERING

SHEET

OPERATOR

JOB

DRILLING

is

cou

forces

and

sensed

by

deWardt10

gyro/accelerometer

after

Ut

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

399

_..-UNIVtNSAI_

..PICKOFF

.OUTER SPIN

SP1N

JOINT TONQUEN

12000

MOTQ

with

JOINT

PCIOFF

_GTNO

axis

tuned

accelerometer

after

rate

Uttrecht

gyro

and

and

pickoffs

TONQU

NOTOP

maintain

to

of angular spin

x-y

free

is

The

to

The

between

the

to

it

the

rotor

the

rate

the

precess

tool

at

When

the

detect

of

earth and

dual-

deWardt10

and

tries

the

case

neces

torque

axis

the

to

tion

the

is

the

that

vector

is

be

The

of

hole

the

tools

the

8.61

Eq

by

low

the

The

vector

gravity

to

the

the

and

wellbore

inclina

known

vector

sinDIg in

of

side

high

hole A1

is

the

around

by

which

and

axis

of

side

since gravity

rotated

horizontal

plane

x-y

the

8.62

axis

hole and

the

the

until

x-y

the

the

axis

plane the

detects

gyroscope

which

between

with

aligned

orientation

accelerometer

the

oriented

is

return

measure

to

relationship

is

given

between

the

derived

the

can

the

to

the spin

8.61

of

by

be

Knowing plane

is

the

which

sin A2 fgarc

arc

axis

show

axis

angle

direction

can

case and

the

A1

sensed

are

the

tan

where the

of

earths

the

position

to

angles

right

still

to

rotation

showed

gravity

proportional

at

is

null

8.77B

tool

Uttecht

axis

is

the

is

case

tool

to

earths

the

the

movement

the

automatically

Farc

earths

ER

vector

spin

Vector

is

/ACCELEROMETER AXIS PLANE

GYRO

right

always

rotor

measured

position

of

Figs 8.77A and with

null

motion

plane

causes

the dynamically

position

rate

VIEw OF SENSOR PACKAGE dual-axis

null

sary

SIDE

8.76A

axis

torques

rotor

x-y planes

tool

AXIS

..aEANINGS

Fig

the

reached

is

the

to

maintain

to

CASC

rpm

angles

8.63

SENSITIVE Fig

8.77AVector eter

of

combined

after

Uttrecht

analysis readings

gyro

and

and accelerom

The angle

deWardtt0

by the

and

HOLE

as

the

rotation

of

the

in

between

angle

from

and

constant

stays SIDE

Y2.HGM

defined

is

and

x-y plane

is

the

horizontal

and

and

the

x1

and

between

angle

plane

to

x1

can

now

be

earth

rate

Te

determined Because

the

known

for

is

TeER The

IZOpdTAL

given

and

electric

surveying normal TN

deWardt

10

the

compass

sensing after

is

follows

as

/x1

8.66

shows

power source

on

rotating

is

tan

Fig 8.78

creates

axis

Y2

of

horizontal

horizontal

the

8.65

azimuth

WELLSO

8.77BMathematically

in

g1

hole

Aarc

Fig

8.64

component

Te2

the

the

latitude

cos0

earth-rate

gy2

component of

horizontal

plane Uttrecht

the

wireline time

is

poles and

the

tool

ing

significant

For

the

gyroscope

CPU

typical

than

As with

higher

the

rate

and

drift

Because

shorter

gyroscope

the

rate

printer

stops

that all

system consisting sonde which is run

gyroscopes

inclination

gyroscope

to

and

tudes

of

70

at

inclinations

not required

are

required

exceeding

the this

for

running

the less

starts

70

nearer

accurate

and

becom at

lati

APPLIED

400

Gyroscopic

Survey

Directional

Another

System

of

type

surface-recording

gyroscope-stabilized

inclination of

stops

and

The

ously

Power

Supply

gyroscope

seconds

checks

culations

microprocessor

displays

tool

on

run

is

the

all

electric

10-minute

performs

results

and

station

survey

conventional

or

an

direction

short

requires

and

with

measure

to

uses

gyroscope

platform

almost

drift

cal

the

all

instantane

wireline and

powered

is

surface

the

at

This

to

correction

single-axis

of accelerometers

set

thogonal

ENGINEERING

DRILLING

8.5.7

and

Surveying Accuracy

Position

of

the

Borehole

the

Teiemetry

Data Section

Data

Fig 8.79

shows

surveyed

four

while

Storage

well

the

separate

Support

of

sition

from

in

Section

Gyro Accelerometer

multiwell

risk

is

Cluster

of

the

ing

sidetrack enter

8.78The

Fig

downhole

after

probe and

survey

Ultrechi

and

surface

Both

equipment

deWardt15

the

700

600

500

400

300

and gyroscopic

200

100

earth

be

100

on

200

the

i-600

drifts

-700

and

run

the

at

of

on

by

excessive

the

800

earth

the

problems

or

the

there

which

can

variation hot

compass

of

on

survey

storms

spots

Also

inclinometer

friction

bearing

to

and

drillstring

of

inclinations

that

leads

to

to

gyroscopes

70

exceeding

shown

or excessive

be

to

major categories

instrument

compass

ex can

times

survey

be

can

five

orientation

assembly

gimbal

inclinations

from lengthy

related

the

inclination

systematic10 refer

compass

SHI

ence

have

subject

error because

measuring

declination

caused

inaccuracies

be

can

drift

magnetic

drag high

resulting

All

by

misalignment

bearing

not be

6297

are

drag errors can occur from improper

surface

cessive

instruments

inclinometer

Gyroscope at the

re

not

collars or inaccurate readings

be

or by and

drilling

does

compasses

position

the major

reading

may

compass

there

intersect

in drilling

weilbore

has

the

caused

nonmagnetic

inaccuracy

400 500

with

north

alignment

300

earth and

the

the

po

other

wellbores

infill

of the survey

position

gyroscope

errors

change

in

where

and

by the surrounding

the

by

Along

L.._..L._

of

in

survey

Magnetic

interference

the spin of

may

SINGLE

new

The conventional

FEET WEST OF SURFACE 800

the

that

inaccuracies

are affected

900

ensure

the

welibore

magnetic

inherent magnetic

_.L_L__L_

critical

of

exact

important

spaced

closely

out and

the

cluster

are

three

wellbore

wellbore

or platform

efficiencies

to

old

blows

Knowing

pad

for

with

the

other wellbores

exactly

target

single-shots

of

the

near

drilling

has been

that

later

well

extremely

directional

intersecting

where sweep

if

to intercept

also

is

and

position

desired point

at

applications

Gyro

magnetic

The

drilled

wellbore

the

borehole

relevant

must be well

of with

drilled

being surveys

particularly

well

blown-out

Gyro

was

gyroscope

becomes relief

plan view

the

times once

and

misalignment

errors

depth 12000

8.80

Fig

shows

that

l000u_

1100

is

example

of

different

magnetic

8.82

Fig

is

single-shots

1400

13000

1500

11OQ

the

target

cated the

the

steel

Fig

8.79PIan

view

of

wellbore

based

on

four

different

surveys

tematic

multishot

with

of

at

tools

Which

in

MWD

all

single-shot

unit

that

of to

the

be

caused

directional

depth with

first

later

with

depth

The

would miss

trajectory

course When

an

two

correct

is

casing

and

was found

the

and

is

with

off

surveyed

tool

the

compass

stabilizer

one

that

was on

the

taken

taken

the intermediate

MWD

the

compass

clamp-on

an

indicated

trajectory

error

data

survey

8.81

Fig

survey

example of surveys shows data on well

while

the

drifts

an

then

well

gyroscopic

excessive

magnetic

surveys

location

checked

and

multishot

magnetic multishot

1QQ

example of

poor

8.83

Fig

1200 1300

an

erratic

surveys the

BHA

multishot

directly

and

was

opposite

consistent

readings

indi

sys

DIRECTIONAL

AND

DRILLING

DEVIATION

CONTROL

401

7000

7000

Inclination

12

10

81

Deg

Total

14

16

18

Direction

20

22

24

SlOW

26

20

30

Muttishot1

Drift

Muttisliot

1ow

aooo

Li

1f4E

5314E

9000

.-

7500 10000

/i 11000

Fig

of

8.82Exarnple

off-depth

Coast

Gulf

for

survey

well

8000 An example be

can

an

mm

equation

where

is

nation

is

north

and

N6OW

and

inclination

8.80Example

of

gyro

survey

with

and

excessive

erratic

drift

higher netic

the

N7OW

N8OW

MuItshot

2354

--o-- Multisct

2328 OS

in the

slope well ___0

and

tion

4000

for

the

lars

in

Solution

implies or west

hot

that

and

and

Alaska

where

Assume

toward

welibore

increases

inclinations

such

latitudes South

the

Pole

error

for

north

at

60

inclina

is

of

strength

2.0

position

also

greater

the

mag

increases

collars

southern

magnetic and

component

the

the the

greater

direction

increases

azimuth

the

the

equator at

and

the

Calculate

the

occur

that

or improper

spots

at

of

strength

the

the nonmagnetic

the northern

Alaska

the

east

deflections

Sea

N7OE

north

and

in

8.15

Example

as

and

equator is

8.67

south or north from

North

the

LIME

tiC Anything

in

compass

or west

east as

Eq

at

jiT

more

in

tiC Maximum

3000

8.67

poles

error field such

tiC Moving N6OW

the

change

ing of the

DIRECTION

40

south

error field

magnetic Fig

compass Wolfe and

by

actual is the incli compass deflection azimuth and MF is the magnetic field

the the

which varies between the

N4OW

the

Drift

Checks

N2OW

derived

AE

LCsina sin 8500

on

interference

magnetic

to

11

deWardt

43/4E

of

related

because

of

10.2 the

col

drillstring

The azimuth

error

is

calculated

with

Eq

8.67

/2\

50G0-

LICsin60sin70

22

Azimuth error0.l596 6000r

57 .295

Fig

8.81Example

of

poor-quality

survey

0.1596 10.2/

rad

/rad9 14

The maximum survey error can be estimated with Fig is based on typical for good measuring and and good and poor magnetic sur poor gyroscope surveys 8.84 which

veys to

east/west

construct

Fig

Table

8.84

8.9

shows

the

typical

values

used

I-

402

APPLIED

TABLE 8.9TYPICAL

VALUES

FOR

Relative

MEASURING

True

Depth

ERRORS

Reference

Misalignment

Inclination

degrees

degrees

0.03

0.2

2.0

0.2

0.5

Good

1.0

1.0

0.1

0.5

1.5

Poor

Magnification Magnification

2.0

0.3

c2

c3

degrees

degrees

Magnetic

0.5 2.5 0.25

1.5

sin

5.05.0

sin

sin

sin

cos

Shot

Single

Example 8.16

Data

Magnetic

0.1

1.0

Weighting

MWD

degrees

0.5

Compass

Magnification

Ito

Good Gyro

Gyro

Drillstring

Error

Poor Gyro

ENGINEERING

DRILLING

Muitishot

FojecUon Based

on

iBa

of

error

Trajectoiy

Determine

the well

for

maximum expected

the

described

below

Assume

gnetic

ve

and

poor

magnetic

survey

that

good

are available

survey

Intermediate

Wells

Fig

to

5000

to

6500

of

surveying

before

multishot

hole

running

does

not

with

intermediate

agree

with

mul

magnetic casing

single-shot

where and

surveys

30

ft

0.0075

The

tion

MD

ft/ft

8.84

5000 ftxo.0018 1500

3500 ftxo.0140

this

method

the

30

for

ft

inclina

error

survey

ft

MD49ft

ft/ft

69

With

6500

to

ft

MD11

ft/ft

from

interval

5000

MD

ft/ft

MD

ft/ft

ftxo.0075

build

first

maximum

the

is

the

MD

ft/ft

and 0.014

following

constant

average

According to Fig ft shows 0.0018

the is

300

to

ft

5000

to

MWD

vertical

ft

10000

to

Solution

8.83Example tishot

5000 6500

100 meters

Departure

inclination

ft

for the

error

poor

193

is

survey

ft

LL

As

stated

an

previously

random

not

tematic

ellipsoid

from each

directional

three Co

of

different

the

well

MWD

the

was determined

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of the wellbore

on

survey

that

the

from

derived

inclination ellipsoids

real

the

the

at

basis

weilbore

convention

at this

the

surveys Later it was found that the actu come within few feet of the blowout weilbore

did

In

depth

CC

-J

for

sys form

station

calculated

ally al

Fig

depths

ellipsoids

was south

Co

error

be

to

appear

survey

amount of depth 8.85 shows the

the

reflecting

LL

and

errors

surveying Data

this

most accurate

case

The mathematics of

axes

the

the

single-shot

surveys

predicted

trajectory needed

for

are

ellipsoid

the

of

calculation

presented

the

three

Wolfe

by

and

deWardt 10

20

30

Average

Fig

8.84Chart and

to

poor

determine

magnetic

deWardt

40 Hole

lateral

and

50

uncertainty

gyro

60

70

80

Inclination

surveys

for typical

after

Wolff

good and

To minimize stand

calibrated

tions

expected

surveying

to

assure

Deflection

Sec

8.4 explained

change and is

the

reached

can

use

how

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to

make

for

severity

setting

positive

plotted

whipstock

principles

dogleg

tool-face

be

run back

and over

test-

direc to

the

inclination

all

the

overlapped

Tools

Whether

used

is

should

be

and

repeatability

8.6

change

be

should

tools

inclinations

comparison

data should

directional

sections

range

for

all

of

All multishots

highest point possible and

errors

the

over

are

determining

new

inclination

ways

displacement

trajectory

or

the

of

angle

implementing

motrr

jetting

total

same Once

the

all

are various

controlled

mud motor

bit

angle

direction trajectory

PDM with

it

One bent

DIRECTIONAL

AND

DRILLING

DEVIATION

CONTROL

403

1000 9000

TVD 10500 Later

900

ouu

Legend Ui Ui

MWD Single

Shots

MS 2429

Bottom

MS

Top

2429

MS 2354

Top

MS 2354

Bottom

700

.Gyro

MS 2375 MS 2375

Fig

2f00

2000

1900

1800

1700

1600

Top

FEET

Bottom

8.85Plan signed

view to

of various intersect

WEST OF SURFACE

surveys

run

in

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well

relief

blowout

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stabilizer

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PDM

of

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sub or an bit

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also

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8.6.1

The for

and

tion

bit

bit

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plug

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ventional by

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drill

Forcing

the it

8.86Openhole

whipstock

bit

is

the

ordinarily continues

reaches depicts

The bit

bly

entire

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normal

bit

in the the

arc

of

top

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the

set

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the

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8.88

of

wedge

wedge

whipstock

Fig

wedge

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the

by

the

the

pin

rotation

set

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begins

well

as

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assembly through

operation whipstock

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pulled

then

line

con

by

whipstock toe

it

cement

center

the

direction

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to

the

whether

top of

rotation

Fig 8.87

stop

hole opener

and

bore

the the

until

an

hole with running

depth

the

to the

applied

wedge in

the

mule-shoe

the

when applied

bit

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continues

with

cut sideways

to

the

whipstock

ing Fig

the

collar

is

the

to

or

desired

With

ac

mode whipstock When the of

bottom and

to

diagram

selected

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in the

fit

start

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move

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the kick-off

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survey

enough

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at

nonmagnetic

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effect

of the weilbore

oriented

single-shot

oriented

use

deflection

Fig 8.87

the top of the

to

depth

is

to

at the

positioned

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of the toe

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Fig 8.86

whipstock

enough

chosen

locked

is

whipstock

and

needed

small

is

then

used

widely

whipstock

wedge

that

whipstock

in

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trajectory

of operation

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to

cording

first

wellbore

the

principle

used

tools

factors

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openhole

the

various

principal

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typical

of

describes

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trajectories

to

again

drilling

is

assembly

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to

the

original

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drilling

resumed

is

pulled

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hole size

BHA

Fig

8.88

and

finally

and

pilot

The

kick-off point

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well-

assem

run and

APPLIED

404

ENGINEERING

DRILLING

Whipstock Original Sto Hole -S

Whipstock

Wedge

Directiohi/

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of

New

of

Whipstock

Hole

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100

flOOft

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In

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of

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Fig

Hole

8.87Diagram

of

retrievable

whipstock

operation

8.89A

Fig

Whthstock Closed

In

Isitioe

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nck1

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with

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to

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tArection 01

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is

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whipstock

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when

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drilling

bit to

down

slide

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fill

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Fathn9

the off

entire

whipstock

achieved

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borehole

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because

II

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WlsipStOCk

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can

be

8.89

used to

proceed

to

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out the

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deviated

impossible

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bottom

of

whipstock

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of the hole

kick

if

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usually

of

diagram

jet

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assembly

away

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bottom

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hole entering

in the

fill

drilling

washes

fill

hole Fig

the 0901

with

with the

Even

rotate

to

assembly

the

whipstock

and then

can

seat

properly Fig

8.88Drilling

with

retrievable

Even

whipstock

to

the

the

driller

the

change

The the

when

hole

the

critical

whipstock

culation

stock

too has

toe

is

orientation stage

occurs

wedge high

started

firmly

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and

or

bit

can

the

rock lose

continue

on

not

to rotate

when

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seated

careful

the bit

is

the

to

the bottom unseat

bit off

the

leaves

the

too

soft

and

curvature

drilling

nearly

of

the toe

the

wedge end the

of cir

whip-

straight

DIRECTIONAL

AND

DRILliNG

CONTROL

DEVIATION

405

Miii

Sheirn SwthCaaI

Lag

NOW

W.Otw Aposknaty Abos

ft

MpS10d

Of

Top

spstsk

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on

8.90a

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the

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with

the

window

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too

ly

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the

in

experience

are

almost

in

hard

very

Locking the

in

used and

run the

to

rocks

are too high

temperatures

never

however

circumstances

as

window

very complicated

required

is

seat

whipstock

Cutting

casing

the

whipstock side

with

the

into

packer assembly

mill

packing

ahead

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the

Cutting with

casing

bit

tricone

through

casing

is

trajectory

certain

such

ful

mill

whipstocks

the

changing

packer and

starting

and

tools

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the

date

where

weilbores

in

use

mud motors

for

ensure

to

that

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similar

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with

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the

out of casing

sidetracking

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motor

follow

to

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section

mud

accommo

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drilling

with

with

trajectory

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large

conventional

The most common method of

proper still

are

window

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bent

to

to

di

sub or bent

housing

When 8.6.2

Casing Whipstocks

Another

type of

the openhole

like

routinely 12

at

whipstock

sidetrack

to

described

of

is

run on

into

the

the

the

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bit

stock

forces

bit

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of

dow the

taper

drag lon is

bit mill

mill

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bit

assembly

out

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to

accommodate dressed

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with

12

to

watermelon

applied

the

and

casing mill

side

mill

is

conventional

mills

tricone

waterme

When be

or

used

the

hole

to

ream

in

8.92

30-

section

mill

run

is

the casing cement

to

leave

the

is

mill

cemented

the

the

it

After

must be

with

arms retracted

the

in

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arms are extended

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isolate

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that

operation

bottom

to

section

coupling

milling

hole

At

wellbore

slows

section

the

casing

the operation

set

below

old

or another

below

60-ft

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into

mud motor

milled

well

shows

plug

from the casing is

to

milled

is

is

section

through

which

vibrate

number of couplings

the

normal

Fig 8.91 shows Fig

casing

immediately

start

be

must be selected

bonding the

that

should

milled

of the

the

the

milled

sec

new

open

hole

section

appropriate device

deflecting

new

start

used

is

Fig

one

8.92

and

BHA and

cement

thereby minimizing

win

pulled

and

bit

can

chosen

tion

BHA

better

Assuming

of

and

conventional

ahead

with

to

up and jam Either

torque

must be cemented remedially

section

of casing

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to

casing

may

mill

the

should

mill one

portion

cement bonding is The rotating mill are inevitable

unsupported and

section the

cement or

no

is

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the

progress

and

the

cement behind

for

poor milling problems

whip-

long Once out hole Then that

assembly

drill

dia

or

make the casing

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are used

ft

pilot

to

is

locked

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is

the

taper

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through

drills

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Fig 8.90d The

about bit

kick

milled

Fig 8.90c

sidetracking

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cut

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Fig 8.90e

tripped

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for

the

starting

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to

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assembly

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the

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8.90a

run

is

et

the use

for

retrievable

set

used

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making

casing

mill

out of

pulled

mond

side

see Figs

starting mill

mule-shoe

The whipstock

whipstock

starting

then

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technique packer

used

is

whipstock

on wireline for

either

Un

whipstock

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packer

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tion

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is

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considering

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or

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out the

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in the

drilling

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casing/whipstock short

more

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through

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sometimes

new

wellbore

of

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making

it

the

of

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the

is

wear

difficult

window

too

to

APPLIED

406

8.6.3

Jetting Bits

Another

8.93

is

In jetting

drilling

assembly

and 25

ate

the

the

jetting

shows

can

hydraulic

didates other

for

of

degree

making

ted

TUBE

ASSEMBLY

and

section

times

this

collars

used

in

in

the

hole of

reduce

the

pocket

can

to

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than

of

Fig

8.91Typical A-Z

section

Intl

Tool

miii

with

arms

retracted

courtesy

of

made

be

Cmot.d

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kms

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depth

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take

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ad

secondary

has been

trajectory

ahead

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alterations

trajectory

operations

same BFIA drill

more economical

is

jetting

slight

established wells

in

place

shales

is

ble

10

to

the

or

familiar

that

two-cone

jet

are is

in

be that

the success

clination

exceeds

to

of

the

20 1.-

build

an

rock is

jetting

until

the

sandstone

the

to

slower

not one

jetting

is

drilling

possi

curve

can

the

that

signifies

begins

survey

n1

of

interval

previous jetting another

The

inclination

area normal break

drilling

low

very

The harder the rock

the

drilling

at

indicates

jetting

the

desired

impossible

procedure

jetting After

continued

tt nnn.1o

in

is

jetting

another

for is

the

to

possible

is

particular

until

formation drilling

If

direction

usually

depths

minutes

direction

virtually

primarily

break

and

selected

is

used

are

assembly

general

specific

shallow

evaluate

tho

in the

more shale there

will

resumed

mal

kick-off

drilling at

building

than

operation

sandstone

is

oriented maintain

to

20

in

is

less

jetting to

jetting

for

well

too

pumps

rig

and

is

The kick-off depth

operation

set

ft

prepare

can

good is

be applied can

jetting

single-stabilizer

nozzle

large

in

to

not

are

drilling

trajectory

sandstones

Sob

To

Off

first

miii

that

original

alternating bit

ting

to

section

of

the

mud motor An

jetting

inclinations

8.92Using

to

is

regular

Off

Mod

To

Fig

which

rock

can

jetting

conducive

jetting

after

normally

solution

practical

change is

Typically

Cn

is

Co. have

soft they

conventional

advantage

to

running

vantage

those

at

jet

Some

use of smaller

the

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more hydraulic energy

the geology

If

be

which

to

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used

when

curved

well path

than

level

some

much

too

the

Most medium-strength

with

jet

principal

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can

to

may

shales

pressures and to

rate

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direction

away

assembly

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best

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erode

vertical

oo

and

the

eroded

be

the depth

limits

cut

same size

circulation

amount of

jetted

desired

the

nearly

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for jetting

cemented it

be

problem can be overcome by

drill

didates

to

are

rocks

soft

in

jet

where jet

on

sandstones can

stabilizers

return

Even though PIECE ASSEMBLY

to

begins the

Fig 8.94

the

is

cemented

rocks

Very

difficult

it

rotation

is

the

continued

is

jetting Sandstones

for

soft

success

change

again and

influence

Unconsolidated

of very

evalu

to

achieved

importance

are weakly

that

jetting

types

in

next available

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limestones

litic

of 20

depth

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the

start

is

taken

is

This procedure change

most important

used

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oriented

is

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into

operation

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the

is

be

more

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Geology ting

is

desired

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survey

fluid

borehole

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proceeds

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drilling

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ft

to

assembly

jetting

sequence

the

of

interval

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required

of

see Fig The mule-

jetting

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without

drilling at that

reached

is

bottom

distance

setting the

of

of

trajectory

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line as

energy

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the

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conventional

ft

until

in

out of

for

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the

hydraulic

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to

AND

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ed

PISTON

to

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means of changing

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ENGINEERING

DRILLING

be

When

interval

th

in

nor

run the

to

in

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DIRECTIONAL

AND

DRILLING

407

CONTROL

DEVIATION

Valve

Assembly

Joint

Universal

Fig

bit

8.93Jetting

Section

Bearing

Bit

Fig

and

direction as

quire

four

should

favorable

the

of

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that

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at

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in the

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short

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the

curvature

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the curvature

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drilling

con

can

within

is

con 30

assembly

use of the

ft

PDM

bent

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advancement and

the

in trajectory

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used

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and

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for

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Displacement

housing or eccentric

mo

straight-hole

drilling

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jetted

problem

detected

the

prob

Positive

motor

Dyna-Drill

The most important

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intervals

dogleg

than

8.6.4

the

must

desired kick-off

device

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feet

formation

deflecting

being

However

created

is

jetting

depth

technique

with

drilling

that

is

re

can

few hundred

over

to jetting

this

number of jet

Hence

attempts

shallow

at

interval otherwise

Sometimes

found

appear

drawback

major be

as

many

intervals

ting

is

inclination

mud

positive-displacement

typical

courtesy

change

trajectory

8.94Jetting

Fig

8.95A

Sub

PDM

The

began

to

tional

tool

Since

as

is

then

PDM

cross

is

section

based of

and

1966

U.S PDM has

in the

be used

directional

both

The

to

in

was developed

PDM

the

and on

the

typical

years

later the

direc

primarily

as

been

worldwide

straight-hole

used

drilling

Moineau principle half-lobe

profile

tool

Fig 8.95 The

PDM

APPLIED

408

ENGINEERING

DRILLING

11 Uo

rti Moore

Radrat

Stator

Boarrog

Rotor

TRrut

Lower

Beoreg

ill

8.96a

Fig

Dump-valve courtesy

bly

dump

valve

and

in

gins

fluid

ports

and

of

the

used

is

out of

the

hole

forces

the

of

8.96b

the

circulated

causing

the

rotor

ber to

chamber

to

the

bit

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withstand

radial

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bit

of

the

is

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to

ent

replace

on

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the

Fig

PDM

thorough

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rent tool

vulnerable

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load coupling

fail

to

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continuous

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of

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hydrocarbons

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dition

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fuels

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fuel

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at

in the

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each

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drive-shaft

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of

becomes

related

indicator

points

less

than

stators

ed

short

usually

is

Bearing

by to

while

that

attack oil

by

mud sys the ad

by

thrust

that

or

the

weak

erosion of

fluid

loading of and

bearings

made

are

life

bearing

is

factor

limiting

link

mudeither

normal

the

motor

exceed

not

during

longer

PDM

drilling Early

straight-hole

in

low pressure drops across the bear to similarly low ings thus bit pressure drop was limited values about 250 psi Higher caused drops ero pressure designs

permitted

sion of

the

only

at

Newer

bearings bearing

PDM

and

1500

to

operate

Unusual

psi

at

in

wear

less

or

of

off-

on-

the usual wear

is

materials

bearing

bearing

pres

and reaming

washing

attrition

1000

operating

low

wear Normal

PDM

most common means

the

aspect

bearings

through to

technology

are than

factor

significant

past

the

The which

sealed

flow

permit up

WOBcan hasten wear Abnormally high WOB accelerates

Advances

making

designs

considerable

as

abnormally

bottom

in

while

mud

control

to

nonsealed

up

bottom

mode

used

restrictor

differentials

sure

the

com

be

can

life

of

operating

the universal

the

excessive

changes

enough

changes

trajectory

running

rotor

chemical

point

run

because

trajectory

make

multi-

pressure

the higher to

components

systems

in

and

speed

tend

or on-bottom

When

practicessuch

elastomer

of

off-bottom

quality-

essential

phase

the

attrition

motor stage ac

reduced

is

rotational

train

fail

nonsealed

lubricated

depend

motor housing Sta

lower

to

aniline

PDM

the

drive

related

pressure drop

resiliency

winterized

compounds

dieselis an invcrsely Fuels with

to

typically

which

It

and

psi

deformation the

around

seal

subjected

gels

across

motors

system Motor bearings can

run downhole

each

motor because

and

formulated

securely

are

and

However

less

is

stage

bearings

strict

the

must have

turn freely

correctly

are

of

rubbing

rubber

stator

Bearing

problem

the

of multilobed

torques

the

This

because

the

thus are for

per

joint

wear

com

of key

after

they

and

portion

to

tially

hydraulic

primarily

joint

companies

hydraulic

tent

to

rotating

there

histories

regularly before

parts

the

the

against

inspections

effective

which

and

bearings

universal

permitting

at

are used

bit

limited

is

thrust

provide an

tors

rotat

to

when

and

rotor

Fig 8.96d

the

guards

bottom

the

pressure drops

stator

motors

drop

transmitted

8.96e

loads on

lobed

from cham

is

connected

is

the

procedures

subjected

pound

stator

8.96c

celerate

Fig

to

fluid

the

operating

service

stator

rotor

stator

the

Fig

the

most often

the

assurance

bit

of

as

sub

Rotating-bit

Excessive

be

Because

stator

torque

maintain

conduct

to

Operators

it

to

important

ponents

from

closing

the stator

pass

bearing off

stator

componentssuch It

to

normal

life

joint

flows

it

8.96E

operating

wear

Universal

circulation

thereby

imparts

joint

the

is

while

fluid

in the

bearings

and

the

Fig

lation

through

rotor

fluid

upper-thrust

when

loads

fluid

Rotation

axial

An

sub

down

the

which

to

and

the

bypass

piston

universal

by

sub

ing

to

turn and

to

motor

Multistage

Fig 8.96a When

the

directing

eccentricity

assembly

Dyna-Drill

that

has

stator

of

PDM

more lobe than

the

rotor

the

fluid

cavities

The

rotor

has

called

two lobes or

design

sive

is

has one

is

rotor as

the

that

the

half-lobe

lobe or

motor

2rl

teeth

key

stator

thus forming rotor

tooth

always series

has one

of progres

turns

temperature diesel

in the

of aromatic

155F

are

8.68

fuel

soluble

con

poten

shown of The

in

Fig

half-lobe

following

diameter

8.97

PDM

information

has

dr

and

an

Fig 8.98 shows The rotor pitch been

provided

by

Baker

er

eccentricity the

and

pitch

u1r Service

is

as

lead

equivalent

Tools

Co

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

409

--

1/2

PDM

Lobe

.-

3/4

PDM

Lobe

9/10

PDM

Lobe

//

II II

64

8.97Cross

Fig

section

ameter

and

of

half-lobe of

eccentricity

PDM

the

di

the

showing

PDM

8-100----Muttilobe

Fig

designs

eta.8

Eicketberg

after

rotor

and 2RatDrF1tctr

n0P5

2xP0

For ...._.__1tOr

example

PDM

half-lobe

in

rotor are

the

1Ldn_ 0iSte

8.69c

same while

the

the

the

lead of

and

pitch

lead

stator

the

twice

is

pitch -.1

fL

Rem

In addition

St

and

8.100

and

tth

bit

speed

of

8.98A

cone

PDM

half-lobe

the

showing

stator

and

rotor

5/6

low

lobes

speed The

enough

to

per

roller-

What

the

is

lead

stator

Lsr

stator

of

rotor lead

pitch

34-lobe

PDM

with

7-in

pitch

rotor 314

is

in bit

bits

Lr and 112

PDMs

Figs 8.99

number of

the

as

decrease

in

pitches

Example 8.17

NumboILokes

shown

as

runs with journal-bearing

straight-hole

de

there are multilobe

increases

proportionate

some multilobe

mit lengthy Fig

PDMs

profiles

Motor torque with

increases

0neStaa

half-lobe

to

with

signs

9/tO

Rotm/Stifc

2000i

Solution

jS

The

stator

is

pitch

to

equal

the rotor pitch

375 1200

s00

PstPr7

HflH

jL2ri

The rotor Tcica

Each

number

refers

Fig 8.99Characteristics ter

to

various

of

make

particular

of

multilobe

PDM

Lr7

af

profiles

wavelength distance

revolution are equal al

to

the

equal

to

the

pitch

times the

number

to

the

pitch

times

number

in

in.X32l

Jurgens13

The the

is

teeth

rotor

POM

of

axial

lead

DSeed of

to

in

of

the

rotor

The

rotor

lead

Lr

is

tooth

advances

during

For any

PDM

the

rotor

pitch

and

and

stator

leads

are proportion

rotor

full

rotor

stator

L77

in

The

x428

8.69a

8.69h

point

starting

termine the

LrnrPr

the

in

pitch

number of teeth

a1r1st

equal

is

teeth

the

that

while the

one

lead

stator

stator

rotor

This

times

the

specific is

equal

distance

for

PDM-design

calculations

displacement to the

snrxnstXP-XA

the

cross-sectional

fluid

is

per revolution area of

the

to

de

of

the

fluid

advances

8.70

APPLIED

410

6112

HP

RPM

Positive

bRaVe

Motor

Displacement

FT

MOTOR

STAGE

DATA

-LBS

FOR

POSITIVE

ENGINEERING

DRILLING

3-STAGE

l2IN

DISPLACEMENT

MOTOR

2400 CI.41AE5

BASED

Nd

DYPM1BBTEA

2200

TESTS

2000

1000

1600

1400

200

1000

000

-600

400

200

MOTOR-PRESSURE

AData

8.101

Fig

for

motor

The

fluid

6-in

four-stage

courtesy

cross-sectional

of

positive-displacement

area

is

approximated

1.75-in

ameter and

2n51 8.71a

465

the

of

half-lobe 8-in.-OD 2.5-in

eccentricity

rotor

is

positive-displacement

Dyna-Drill

torque

rotor

24-in

What

psi

the

of

the

pitch bit

total

is

pressure drop

flow

at

speed

di

rotor

of

600

of

Eqs

rate

gal/mm

where de stator gear

OD

Eq

Solution

PDM

half-lobe

with

S.I

12-in

three-stage

courtesy

Example 8.18 Find

by

n12 For

for

motor

PDM ird

BData

8.101

Fig

Dyna-Drill

DIFFERENTIAL-P

8.72b

A2erdr

8.73c

by

combination

0.0531

erdpqLp

developed

is

8.73b

and

3.OMqp

8.71b

8.73c

57.754q/erdrp Bit

speed

is

simply

the

flow

rate

divided

by the specif

displacement

ic

0.0531

Nb

The

231

bit

speed

is

in

given

is

Eq

by

2074

ft-lbf

8.72b

8.72a

Nb where

.752.5240 80465

gallons

per minute

and

cubic

in

is

330rpm

1.752.524

erdrp

inches

600

57.754

57.754q

revolution

per

The

bit

of

speed

PDM

half-lobe

is

equal

to

from

Notice 57.7S4q

8.72b erdrPr

Also

decreases

torque

power output

Eqs

ing

to

8.70

obtained

hydraulic and

by

mechanical

relating

horsepower

8.72a

to

input

Eq

yield

and

8.73a

1714

pump

8.73b

rpm

exceeds

measured

80%

multilobe

rate

in

foot-pounds

for

inch

mass

Motor

half-lobe

and

/.p

efficiency

PDMs

decreases

speed if

ec

zero

is

implied and as

thus reducing

and

is

clearly

8.6.5

rarely

Turbines

for

use of all

were

turbines

drilling

Soviet

as the

the

8.72a

The

pressure drop

be

speed

This

by Figs 8.lOla

of is

and

the

with

linear

stator

made

is

across

the

mo

the elastomer

torque increases

small portion bit

only

should

fluid

nonlinear

to

bypass

effect

as

8.lolb

Turbines

meas

70%

the

Eq

by

section

PDM

of

speed

i.e

motor

of

length bit

as

increases

shown

O.8O

PDMs

the

deforms allowing O.O133flfl0pALpij

is

the

is

of an elastomer

pounds per square

eccentricity

8.74

Ideally

3.O64qzXpE

in

as

directly

rotary

Pst

tor

ured

of

substitut

8.73b

Xj

where

is

torque

independent

horse

qXLp

5252

PDM

that

is

is

where

MXrpm

and

zero then motor torque number of motor stages is

The is

8.73c

to

centricity

Motor torque

Eq

proportional

in

Union

used

first

increased

1959 for

50

in the

from

Soviet

65%

60%

1953

turbines

Currently to

Union in

of

all

in to

1934

are used

drilling

The

86.5% of in

the

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

411

Unlike

lop

over

PDM

the

8.103

typical

rate the

input

timum

820

turbine Turbine

Section

cone to

rock

bits

and

cutter

PDC

mond

bits

Stage

bits

have

roller-cone

amond

bits

bit

turbines

use

them

of

designed

so

ward

turbine

Turbine Section

If

formation

WOB

al

Rotor

Stationary

that

the

correct

of

monitoring

speed

can bit

is

made

turbine

dowthole

drill

is

torque

motor

of

testing

crease

to

proportional

are

life

bearing

as

the

must

durable

newer life

the

be achieved

194 500

This

10

Fig

8.102Typical

1959

In side

the

bines

1%

the

Soviet

are used

North

the

Sea Soviet Union Fig enters

8.102 the

one

stator

part

of

the

drilling

Union took place

drilled

to in

the

the

in

not

although

shows

one

turbine

and

is

as

in

with

parts

much

typical

turbine past

the

Baker

the

as

Tool

to

torque

pump

the

materials the

and

rate

balanced

extend

the

Tur

but

than

of

less

pressure

because the

bit

to

help prolong

roller

bearings to

promises

hours

for

design stators

The and

TURBODRILL

RATE

the

fluid rotors

compose one stage The lower main thrust-bearing section

Fig 8.103Typical

torque/power

curves

for

in

turbine

Europe and in

the

speed

pump strokes

turbines

they are

with

differen

standpipe

be balanced as

to

than

out

France

with

LB/GAL

FLOW MUD

at

and

torque

turbine

the

track of

bearing

and

i.e

with

Co.

turbines

southern

travels

rotor

of

U.S in 1960 U.S has been

more extensively

top sub and

courtesy

design

successful

first

were introduced

of footage

They

turbine

DIRECTIONAL

as

drilling

LENGTH GALJMIN

axi

output

run

7-3/4W

the

given

appropriate

optimize

proportional

by keeping which

not

for

the turbine

PDM

operating

to indicate

monitored

down

the

section of

selected

performance to

be used

be

to

keep

for

is

is

drive

speed Clearly without some means

much harder

Because

affects the per Rubber bearings were

run can

can

with

drill

This approach

with slower speeds

for the

and

thrust

operator

Rubber bearings

The

the

formations

also

the

bit

designed

operating pressure

speed

can

against

as

di

certain

load balances

thrust

fluid

torque and

it is

PDM tial

Bearing Section

the

used

Dia

much

as

usually

bits

motors

axial

allowance

balance

successful

sumes Stator

and

power

Rotating

the

properly

to

roller-cone

tur

turbine

types of

who

Union

speeds

diamond

match

to

particular

significantly

of the

velocity

the

three-

use with

turbines

difficult

mud

lower

for

for

with

bearings

turbine that

is

it

and

polycrystalline

suited

used

of

efficiency

Two-

loads and

new

better

build

to

the

impractical

Soviet

thrust

operation

torques

axial

the

principally

The type of formance

and

in the

of

similar

significantly

are

with

designs

has forced

for

because

engineers

is

op

an

reaching

ex

not been

bits

which

rate

The torque and power curves

high

are

pump

the

curve

range

therefore

Diamond

bines

power shows

higher

require

pump varies

reduced

is

where

8.104

and

Fig

speed and power

turbine given

optimal

is

conditions

of torque

the

output

narrower speeds

drilling

drill

Even

the

turbine

much

At lower

For

rpm Fig

straight-hole hibit

curve

directional-drilling

power

at

power output

of operating

range

500 gal/mm

is

turbines

conmon

shows

for

the

limited

only

turbine

ENGINEERING

DRILLING

APPLIED

412

Fdj Torque

Pkwe

Pruk

PP

Speed

HhH Stator

/9 /9./9

RPM

Rotor

Fig 8.104Typical rate

of

for

torque/power

curves

500

10-Ibm/gal

gal/mm

turbine

pump

at

mud

view

8.105Side

Fig

of

turbine

single-stage

after

JUrgens 13

The

torque of any

stall

turbine

can

be

determined

with

Eq 8.75s l.38386x

51H1M

10

Wq2Ih

tan 3n3

.8.75

where hydraulic

31H

circulation

Eq

tan

13

gal/mm

rate

of

tan

13nsWmN

4.46x1O471H31M

lbm/gal and

in

vane

Fig 8.105 shows the side The runaway bit speed with

r2h

stages

mud weight

height

8.79

angle degress

number of

Wm

Eq

yields

\23lflv

efficiency

blade

exit

13

ns

8.78

MM5

efficiency

mechanical

Eq

Expanding

view of

8.79 of

single

turbine

can

turbine be

stage

where

calculated

8.76 r2

________

K2

NbS.85nv where an

is

blade

tan f3q/r2h

the volumetric

and

medi

the

is

turbine

it

torque

is

to

that

apparent turbine

speed

the function is

of

the

that

and

K2K3K1

8.77

It

turbine

stall

can

and

with

constant

8.75

bit

And if

if

Eqs

torque 8.75

slope and

is

and

equal 8.76

to

are

constant

combined

times

bit

where

and

speed

K1

Eq

is

the rate

constant

to

KINb

8.78

that

states

torque

and/or point

drive

land

as

8.79

the

the

that

that

all

as

mud

of

other

the

weight

bit

rate

for

stages

variables

speed

will

and can

are

increase

the

and

on

precluded

some

the

offshore

Eq

increase

the

held constant the

rigs

overall

the flow

overall rates

use of turbines drilling

linear

8.104

increasing

The necessity of higher pump

is

torque

increases

However

number

given

the

Figs 8.103

addition

decreases

the turbine

rigs

in

depicted

This assumes

then stall

M1

speed

8.79

turbine

Eq

mud weight and pump

implies

torque

from

be seen

of stages

torque torque

i3n5Wq

re

where

M1

tan

form

MMtSBxNb instantaneous

4.46x104qflM

K3

radius

From Fig 8.104 lates

efficiency

tan

23lqV

8.76

torque

required

on most until

the

DIRECTIONAL

DRILLING

AND

CONTROL

DEVIATION

413

As

torque

4700

motor

the

as

sure increases

use

the

tor as

of

influenced the

bit

This

used

developed

3700

3950

06Observed with

4200

and

mid-1970s

finally

sizes

IADC

accommodate

to

an

for

torque Series

bines than

Once

ever

the

5-1-7

overthrust

C3

bit

constant

C4

bit

constant

Eq 8.71 and from Eq 8.70

the the

if

known

their

upgraded

drilling

drilling

rigs

Now

can

The

power can

the

two

is

the

be be

across

pressure drop of

of

ciency

8.19

turbine

the

information

lowing

Number Radius

Determine

presented is

also

tooth

by

Eq

on

function

the

overall

Warren4

determined

12%-in

motor

ft

by

Fig

8.103

to

and

wear

tooth

to

drilled

shows

8.106

Fig

torque

section

drilling

3484 and 4510

such

for

of the data

for

relationship

between

data

the

analysis

From

run

bit

C3 C4

constants

the

are obtained

bIt wear

IR\

effi

The

1000 lbf

relate

derived

cites

bit

regression

efficiency

mechanical

the

in

bit

is

calculated

\3.7919.17

fol

Nb db

dbWb

known

8.81

0.0021L/

and

bit

K2

diameter

wear

where From

the

is

1.67

K3

the

slope

bit

stages 100 blade3.0 in

ivO8o

the

db

weight

ft/hr

of of

Solution

8.80

wear

rpm

speed

in

and

Example Problem

bit

dimensionless rate

bit

Wb

run tur

turbine

can

output

hydraulic

ratio

of

relationship

power

the

dimensionless

Nb

footage

mechanical

and

tricone

well

bit

before

by

is

deeper

more

torque/speed

the

the

section

4450

contractors

drilling

U.S and Europe

the

known

in this

where

predicted

12/4-in

is

indicate

torque with

The

tool

14

penetration

both

can

db Wb tooth

Depth

pump

later

motor

formation

given

the bit

therefore

the

should indica

MWD

or an

covered

between

pres stand-

driller

C4

3450

8.1

be

will

Warren

by

and

torque

drill

to

200-

Fig

bit

relationship

torque is

the

by

the

torque

advance

to tool

wireline orienting

torque

The

downhole

indicator

output

the

Therefore

pressure or

primary

face

tool

decreases

standpipe

standpipe

motor torque decreases

the

also

pipe pressure

the

increases

torque

torque curve

ft-lbf/rpm mechanical

in

presented

Because

the

slope

can

efficiency

Fig 8.103

fies

is

Warren

Eq

the

total

also

8.80

footage

cites

see

with

drilled

8.107a

Fig

5-1-7

this series

work

other experimental

that

veri

and

and

is

be calculated

The

K15.85iv

of

rotate

can the

overcome

to

quired tor

WOB and

the

against

with

Rearranging

adding

term

stator

the

specific

Eq for

is

experiences off-bottom

the

bearings and

formation

1.38386x105nsWmqE11r2

PDM

the

torque

8.76

torque

and

bit

diameter

8.68 combining

off-bottom

re

ro

that

the

against

torque required bit

the torque so

it

rotational

to

the

friction

drill

bit

given

speed and

with

Eq

torque

8.80 yields

1.675.850.80 1.38386

10

5100105000.453.02

qp

K3

0.27927.9%

efficiency

at

500

K3

gal/mm db Wbftoothwear

8.6.6

the

Using

Straight-Hole

where

PDM

and

for Directional

Drilling

Drilling

with

because

the

the

PDM

is

much

surface standpipe

easier

than

pressure

Nbdh/

with

reflects

turbine the

PDM

K3 0.636erdrPs

Pm

8.82

APPLIED

414

and

Pm

1S

tion

of

the

off-bottom and

stator

pressure can

reflect

torque

the

if

all

the

for

reflect

the

by

of

variation

motor

the

are considered

losses

is

PbI the

the

8.83

standpipe

PPDM

loss

loss

If

circulation

given

bit

rate

pres

pressure differ and

loss

the

all

the

is

Pdl

the

is

pressure of

the

annulus

fric

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bearings

pressure

pressure of

pressure of

constant

the

drilistring

PDM

of

the

is

the

is

ence

and

PDM Pbl Pal

where sure of

caused

pressure drop

rotor

pressure

PdI

Pc11

DW

the

ENGINEERING

DRILLING

Pal are

pressures will

Psp

directly

PDM

LhJ

driller sees while drilling with Fig 8.108 shows what PDM when there is no noticeable sideforce on the bit

The Psp true

is

with

will

for

go

nonlinear

As

penetration

the

the

increase than

While

the

driller

decrease

The

If

plied

and In

the

torque

bent 8.107Results

of

three-cone

bit

tests

to

verity

torque

relationship

for

the

Pressure

Circulating With

Bit

Bottom

and

Circulating

out of it

of

overcoming

PDM

housing or

developed

the

as

part

as

the

the

all

formation friction

PDM

bent

in

sub

assem

directional cuts

ap

long

bypass

that

the

internal

of bit

to

will

is

PDM

of

with

drilling

rate

too

assumed

is

will

caus

weight

fluid

the

the penetration

by

the

and

ps

position

circulating

discussion

the

much

stall

brake

increased

is

penetration

too

the

and

torque

and if

tripping

In directional

is

the

speed

the

the

causes

not exceeded

is

is

Esp

rate

through

WOB

If

in

because

out of

sideways

vertical

This

plane used

torque

additional

PDM

by

torque

related

is

to

the

as

Pressure

With

Bit

mr

Drilling

Bit

Ott

Drilling

Reactive

Torque aad

i500

/4500

the

the

less

is

response

increases and

stall

left

strength

bits

rotary

Pressure

With Off

and

bit

bly torque

total Circulating

is

developed

PDM

bit

allowing

foregoing

is

the

the

Fig

break

necessitating

rate

line

out

also

off

will

rock

of penetration

WOB

the

PDM

discussed

is

WOB

in

feeds

bit drills

motor

the

can

seals

by

the

diamond

natural

and

bits

reason

go up Conversely harder formations The

maximum Psp

If the

This

Psp

root

torque

The

bits

pump-off

penetration

driller

maximum

ing

in

stops adding

as

decrease

0.2

PDM

increased

increase

to

Psp

in

the square

to

the

is

the

increase

equivalent

proportional

WOB

and

variations

bit

added

is

diamond

for

pressure

increases

rate

decrease

for

an

in

when

later

torque

and

torque

diamond

natural

increase

be cOvered

WOB

as

linearly

for polycrystalline

or

for

bits will

decreases

TiMRPM.D

nearly

cones

but not

jets

for this

DW

up

roller

Reducing

Torque

MmVIbMmfMs

500

1500

8.84

2v0\

where

\\/5

\/

\ro/00

Mm

When t900

p3

1500

psi

1750

Side

1cR

Side

High Lell

Right

Right

LeD

tE

With But

ThaI

Motor Not

Bit

With

Drillirrg

t35

roel

As

is2

with

tool-face

PDMtypicalstandpipe

indicator

the

culation

following with

begins

the clockwise

to

and

the

monitors

PDM

As

clockwise

the

bit

the

the

tool

bit

responses

Mmj

torque

the

with

occurrences

rotation

bearings

right

readjustment

engages As place

Face

Dit

is

torque tool-face

bent

angle he

sub

see

ob Cir

Fig 8.108 off bottom As the motor

reacts

of

stator

the

face

rotor

to

begins the

engages

the

against

side

of

counter

rotate

and

occurs

the

borehole

Drills

counterclockwise the

bit drills

off

of

rotation the

left

the

as

finally the

rotation

tool

bit

face

face takes

decreases

If

DII

ii

Fig 8.l08Drllling

bit

sidecutting

rOy

Face

t50

Drilling

with

is

is

ion

ray Face

driller

surface display

serves

Right

00

Tool

Initial

directional

Mb

M5

Side

High

fly

ron

eo

and

torque

psi

on High

motor torque

is

motor-friction

\sai

pressure

and

the

data

use

this

than

he

are obtained information can

with

the

frequently to

advance

enough the

coarser-reading

bit

the

driller

can

more accurately

pressure

gauge

If

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

415

DR

PUMPED

OFF-BOTTOM

FLUID

LLI NG

OFF

PUMP PRESSURE

PSI

WEIGHT INDICATOR

PUMP-OFF

635PSIx25.11N2

1520018

FORGE

LB

10000

ROCK

2555

PRESSURE DROP

PSIx1OIN21O000

1000

PSI

605

LB

8.109Pressure

circulation

by

the

of

fluid

drilling

15.200

lbs

605

data are obtained

the

MWD

most

is

drilling

sidecutting

the

orientation

running

of

soft

bit

the

inclination

um

the

tool-face

with

as

bit

are

the

are

obtained

when

bit

can

be

With

the

direct

to

occurs

usually

50

Fig 8.110

so severely

the formation

medi

is

and

used

PDM

or

bit

diamond

of

polycrystallinc

two

the

the

brake of

pump-off

and

in the

of

design

WOB to WOB at the tive

of

ence

the

the

work the

field

the

hook with

that

what

is

bit

just

force

hook

Fh

off

drilled

the

to

of

pump-off force

load and

the

standpipe

off

Pdo lated

bottom

pres re

not define

pressure

wered

is

by

the

ob

pressure drop

Eq

across

the

how

hook

4ob

drilled

and

is

off

The of

plots

the

until is

done

At 0.0

linearly

until

to

hook

and

increase

causes

the

in

the

off is

re

bit

9000

as

the

lbf/595

bit

data The

and

lbf

its

its

8.86

pres Fig 8.112

to

load

as

reached

is

psi

addition

pump-off force

sq in

hook

of

indicated

is

the

almost

increase

of 595

the

lowered

is

pump-off area

15.1

psi

dulled

standpipe

noted

bit

Further

ahead

drill

to the

slope of

9000

be

that

is

lbf

9000

bit

the

continues

vs

pump

pump-off point is lo

hook

the

difference

pressure

load of

When

drillstring

is

point

pump-

WOB

the

lbf

As

0.0 psi

is

pressure

load and

pump-off

the

carefully

of

plot

true

As

or

off

lA

of

one

point

the

the

in

drills

it

pump-off clearly

lB

WOB

no

the

the

by of

the

determined

Fig 8.112

indicates

pump-off area increased

to

25.1

in As

the

example is

in

Fig

2525

8.110

psi

pump-off point lbf The bit pressure drop

shows

at

hook

is

8.86

PbPdoPob

is

found

psi

0.0

is

drill is

8.11

replotted

load

pressure with

bit

this

pressure

sq bit just

the

see Fig hook the

starts

change

with the

can

bit

Fig

be until

However

the

Fd0

the standpipe

the

drilled

8.11

slowly

shows

to

that

that

just

test

WOB

vs

discernable

load the

0.0 psi There

is

advanced

weight

time does

at

between

difference

so be

will

bit

drill-off

standpipe

8.85

and

be locked the

be

can

1920

is

pressure

The pump-off force

pressure can

in

8.85

tdo F0h

The difference between bit

bit

pressure and

new Fh

the

and

Their

tests

laboratory

bottom F0b and

off

force

pump

the

0.0 lbf

is

pressure drop

sure are recorded

pump-off test Eq

force bit

pressure differ

pump-off force can be obtained the

bit

circula

the

pump-off

verified

called

the

to

pump-off area of the

desired

piston

controlled

the

pump-off

load with the

l0-9-in

with

how

l000-psi

equates

Warren5

and

obtain

to

pressure and weight

pump-off

effective

bottom

load

controlled

is

This

the

can

the

the

bit

motor

amount of effec

the

illustrates

causes

by observing

for

the

bit

and

field

at

fluid

of

the surface

8.109

Fig

across

showed

sures lates

bit

the

lbf

Winters in

be applied

drilling

across

10000

determination

in the

off

bit

hook

which

at

how

and

two ways

off

tion

and

Winters

after

determined

the and

how

shows

The pump-off

used

is

combination

must be considered

system

weight

16

var

orientation

required

oscillation

bits

With

drag-type

diamond the

LB

bits

the

greater

oscillates

is

average

aggressive

Drilling

When

and

pressure

Warren

lbf

8.6.7

22050

in2

Fig 8.110Purnpoff

for

readings

tool-face

face

greater than

is

and

the

tool

This

the

angle

sometimes

900 The

visual

the

inclination

effect

more than

that

however

infrequently

the use of

25.1

psi

difficult

The higher

ies

only

tools

38000

15950

WEIGHT-ON-BIT

caused

differential

PSI

635

TRUE Fig

LB

15950

BIT

jPb2S2S

psil92O psi605

psi

the

determined

load of

15200

APPLIED

416

ri

2817

-J

ENGINEERING

DRILLING

2445 Pit

432

3300-

Mud

Motor

Presiure

0.iI

I.

01

C.

2800 1950

Ac

.2

Lb 4.51

432

Psi

13

1950

Lb

flrillof

Dale

Drilling

Deta

i5

Mm

Time

15

10

Fig

8.11

lADrill-off

The

true

an

standard

81/2-in

crossflow

is

0.0

still

of the

bit

lbf

at this

calculated

is

three

8.87

values

presented

Fig 8.110

by

the

area

pump-off

is

15200

A0 If the

605

known

are

sq in

psi

the

off-bottom

the

WOB

true

8.110

shows

for

2555

is

the

pressure can

rate

Pb2555

38000

is

The

psi

bit

lbf

and

the

psil920 psi635

off-bottom

that

The

actual

2060

psi

cation

of

The

the

psi

motor

for

sary

pump-off force

is

lar plot

Fb635 and

the

psix2S.1

WOB

true

Fig 8.113 time

the

PDM

and

bit

Note

was lowered until

of 100

off

the

WOB

stant

T8

of

210 rate

when

sure and

to

psi until

again

WOB

the to

type of

bit

The torque

the

and

this

case

by multipli

pump-off area

the to

amount of torque neces drill

bits

torque and rate

in

calculated

relationships

three-cone

pump

minus

psi

Fig

bits are

drag

8.1

l4A

penetration

rotary

type

particular

for

is

rate

of

simi

typical

vs

WOB

speed

arrows

shown

is

indicate

by each

weight

off

with

0.0

lbf

WOB

Co CO

when

the

1540 psi At T2 the

caused

for

WOB

13400

reached applied

increase

T7 the the

The

to

pressure

drill

As

increased

of

in

Ad

decreased

until

the

changed

T6 psi

drilled

slope

causing and off

of

driller

the

the

giving at

300-

the

stand-

motor

fairly

20

10

con

reached

standpipe

slacked

51

bit drilled

Then

decline

The

to

reaching

the

pump-off point was again rate

string

WOB

2270

bit

to

lbf

the

was noted

point

the motor of

pressure and

was

standpipe

pump-off

T4

was again

pipe pressure

Lp

downward

was off bottom

bit

standpipe

pump-off point

T5

housing

slowly causing

psi

given

and

be

can

relates

bit

2060

pump-off point

WOB

ip

for

pressure of

standpipe is

dia

sidetracking

bent

pressure was

T3

WOB

ditional

the

slacked

the

for

the

at

bit

diamond

at

lbf

with

drilling

with

that

driller

At time T1 The off-bottom

crease

lbf 22061

example of

typical

mond

lbf

those

of

stall

pressure

is

3800015939

Wb

Ls.p

in.15939

sq

to

stall

1540

i.p

given

motor

psi which is 520 psi The is motor sq in The actual any

26

is

lbf

pressure drop

pressure above

formation the

bit

pressure of

the

standpipe

13700

is

weight

example shows the principal operat motor and diamond-bit system The

field

of the

features

response

The standpipe

stalled

psi

typical

torque

the excessive

was 820

is

pressure drop

motor

the

T9

was 2880 psi and the Ep

be

which

apparent

at

pressure

pump-off area

in

example

drag Then

bit and

pump-off force 2060 psi The

pump

pump

any

drilling

WOB

surface-indicated pressure

reached

ing

determined Fig

of hole

This

pump-off area and

Warren16

and

Winters

after

was no

but there

times

because

lbf

25.1

pump-off

with

Pb the

of

The pump-off

point

Fh

For

8.111BPoint

Lb

1000

Weighton-Bit

bit

Fig

WOB

A0

area

with

test

30

WeightOnBit

1000

40

Lb

at

pres

off weight

Fig

8.11

2Slack-off bit

test

data

with

21/4.in

flat

profile

radial

flow

DIRECTIONAL

FEB

3000

84

I21f4

CO

SUMMIT

DIAMOND BENT

7-.314

10600

AND

DRILLING

DEPTH

450

1PM

417

UTAH

SIDETRACK

HOuSING

CONTROL

DEVIATION

MUD

8.6.8

BIT

MOTOR PPC

11.5

OIL

on

Effect

MUD

When 2500-

Standpipe Pressure

of

Drilipipe

PDM

can

be

the

used

is

pressure causes fect

Change

Elongation

an

related

in the

change of

elongation

the

internal

drilipipe

This

drilistring

ef

by

PSI

zW pXA

2000-

ip

2i

_____

Fd21

ExA

ExA5 1500-

8.88

KLB

where

tL

change

in

pipe A8.113_Drilling

with

diamond

sidetracking

bit

and

For

ratio

of

area

steel

area Fd

for

for

of

ratio

106

29

steel

0.3

steel

in drill-

the

is

the

is

drillpipe

and

is

the

drillpipe 5-in

Eq

drillpipe

8.88

reduces

to

At

Bit

RPM

850

iW

q2W

LW

8.89

IL

2.76x1071

\15.82x107

-O.832A/N

8795TFA

20

in internal

change

drillpipe

Poissons

the

is

length

the

Youngs modulus

the

IWb

in drilipipe

cross-sectional

internal

is

of

length

Constant

is

the

is

the

is

drilipipe

psi

Diamond

change

bent

mud motor

housing

the

A1

pressure Fig

is

WOB

2000

Whr

8.20

amp1e

CO

of

ft

5-in

10

1000

10

15

20

WeightOnBit

Fig

8.1

14ADiamond-bit at

850

25

1000

and

torque

causes in

tain

indicated

Solution

With

slack-off

weight

analysis

what

How

off 0.95

slacks the

is

of

ft

psi which

155

much must be

15000

WOB

indicated

off

drilled

This

causes an

main

to

WOB no

zpO

motor pressure

in

change

the

is

io

15.82x

Wb

rpm

driller

increase of

an

WOB

increase the

the

35

lb

rate

penetration

30

slack-off

If

drillpipe

It-lb

0.95

lbf

10000

15000

An

lbf

the

increases

ft0.08

15000

lbfWOB

10000

increase of

This

ft

so

must be

drilled

155

of

Lp

causes

WOB

155 i07

psi/2.76X

off

maintain

to

psi psi

10000

WOB

II

.2 1500

8.6.9

The

the

Design

in

hydraulics

across

does

bit

the

planning

PDM

is

and

executing

used

such

that

way

not exceed

the

the pres manufac

15

turers

WeightOnBit

1000

8.114B130.stage

turbine

limits

and

power

the

enough

supplies

pressure and

lb

to

rate

Fig

steps

when

change

sure drop 10

are

following

trajectory

for

PDM

With

Change

Trajectory

Planning

with

diamond

PDM

Select bit

and

size

mations

the

trajectory

Trip the

with

enough

type necessary and

Once select

motor throughout

to

the

cause

motor

appropriate

power

both the

the

to drill

trajectory

bit

and

bent

sub

to

circulation

change

trajectory rotate

bit series

given

of of

the

for

change

hydraulics

depending

are

on

designed the

desired

change the

remainder

bit of

motor the

BHA

bent into

sub the

mule-shoe hole

sub

and

APPLIED

418

limit the Hole

Diameter

Hard

d12.5-13.5

in

In

such of

life

motor

arid

15

Mud at

hole and

Siltstone

610

Average

ft/hr

wth

BHT

115

with

to

sidetrack

from

interval

below

61/4

with

19

in

50

Users lbff

be

10820

safe

two

the 10.900

S89E

the

at the

pipc

reduce

to

basis

at

515E

of

the

before

8.21

Example

the

static

sub or bent-housing and

the

worked

pipe the

Start the

up

Advance

tor

this

the

can

changing

the

tor to

hold

and

used

over ia

and

direction

course

of

replace

required

that the

to

does

not

PDM

and

omit

is

the

use to

is

when

The

ft-lbf

Pump 332

rates

longer keep

run multiple

the dogleg

severity

to

from

use

cement bit

for

program

needs

the

8.115

at

the

bent

ft

of 325

to

housing

tool

runs

long

is

angle

Ta

see

the

be the

shortest

drive

TABLE

the

8.10TYPICAL

MOTOR USED

FOR

SIZES

SIDETRACKING

OD Type

in

Length StatorlRotor

It 23 24

91/2

26.5

may be

9/

1/2

33

1/2

23.8

/2

24.9

1/2

21.0

1/2

26.5

best

This assumes

differential

gal/mm

top of

the

offers

plug will

the

used

for

734-in

the

Type

This motor

maximum torque

pressure

450

miss

rpm

incli

predetermined

drill

proper

minimum

over to

choices

hp with

maximum

the

off

possible

21

73.3

ft

motor

shortest

the angle

eight is

to

220

PDM

higher

-in

to

the

operation

done

be

will

the

not

the

the

criter

with

12

bent-sub

run

sidetracking

trajectory

dogleg

start

used

select

that

to

pressures

sidetrack

mo

housing

top of

the

regular

the

to

well-

Grade

be

can

Next

salt

should

old

This ensures

salt

the

covers

the

the

the

the

fish salt

8.11

sub

50.8

the

sizes

motor which develops

the

above

number of possible motor types and

of

of changing

Of

around

where the kick-off

rerun

S84E 10820

at

over

this

bent

is

cement plug from

hard

report

new welibore

the

the

12.5

ft

motor

used

Fig

get

siltstone

motor the bit and

91/2

tool

ft/hr

eniul

directions fish

19.50-Ibm/ft

of hole approximately

fish

the

displaced

above

ft

good

range

and

Because section

that

or

severity

bent

housing

required

fish

hard

200

91/2

change

rates

30

to

between

tool

arrangement trajectory

section

10900

Such

while build

that If

exceed

the

in this

oil/water

doglegs

change

bent

is

readjust

change

length

is

strategy

indica

step

possible

BHA

next

the

little

the dogleg

as

8.10

indicated

is

the

the hydraulics

be

deflection

obtained

is

section

constant

as

over

length

nation

drilled

over

bit

If Step

that

direction

To control

course

If

make

bent-

bringing

readjusting

unplanned

the general

to

If

severe to

and

tool-face

very

must keep

bles

down

the

level

interaction

cause plan

mud

torque

surface

the

with

vary

penetration

the

to

harder

the top of the

are

could

chance

change

then

bent-sub

at

and

the

There

the

be

drill

siltstone

drill

varies

and

5.0-in

is

salt

type of

that

to

the

by

to

and

ft

4.5

laterally

consistently

to

expected

torque

reactive

the

The

siltstone

diameter

sidetrack

the top of

bit

the

the

the

and/or

driller

section

controlling

any

least

1-1-1

design

adjusted

desired

at

cement

be

trajectory

inclination

ing

face

direction the

the

100%

10820

the

First place

good

is

face can

the

there should

exceeds

change

bit

final

Generally inclination

the

with

rates

with

The top of

of

drilipipe

and

8.4

orient

driipipe up and

drillstring

bit/formation

the

the

until

to

pressure

tool

ted however

Or

until

correctly

ment of the

face

bit

implies

performed

the

circulating

rate

standpipe

the

of

transmit

to

motor by

circulation

the

by

knee

motor

the

motor by orienting

the

moving

friction

of

Sec

in

presented

torque

starting

while

surface the

calculations

hard

low-fluid-loss

and

optimum

top of the

the

there

the reactive

for

face

tool

at

fish to

size

the

is

at

4.00

diameters

Series

On

in the

decided

is

salt-and-siltstone

If

SB7E

allowing

It

situation

drill

the

wellbore

at

drilling

Solution

10

for

The to

for

Surveys

an

bore The

ft

situation

are stuck

continue

to

Penetration

ft/hr easier

ft/hr

Depth

8.115Wellbore

and

extremely

respectively

Design

To be

is

in

S87E

without

is

is

The mud

inclination

and

ft

ft

and

10

salt

13.5

the

Fish

Thrget

stabilizers

economically

welibore

mud

is

The average

and

900

last

Drillpipe

sion

Fig

ft

from

100%

for

salt

to

10600

varying

Pumps

the

fish the

11 .6-lbf/gal

existing

i11cations 10P130

the

shows

115

Fig

ing

2National

retrieved

around

Ocp

of

be

two

and

bit

cannot

section above

10

to

drilled

Based

lb/9a1

scosdy f70

of

Inclination

Total

interval

Iii Example 8.21

of

the

ft

Salt

10820

be optimized

run must

maximize

Siltsone

II 10600

Top

bit

to

210411/h

/11/1/

at

the

cases

the

ENGINEERING

DRILLING

is

bit

of

1160

360 at

psi

230

to

DRECTlONAL

AND

DRILLING

CONTROL

DEVIATION

TABLE

8.11TYPICAL

419

OPERATING

PARAMETERS

MOTORS

VARIOUS

FOR

TYPE Tool

Pump

Recommended

Size

OD

Hole

in

Rate

Size

Maximum

gal/mm

in

mm

max

91/2 91/2

121/4

11

Maximum

Differential

920

580

2065 3400 4490 6850

370

85-185

Bit

Box

Range

580

185

Horsepower

ft/Ibf

90-180

Connection

Thread

Torque

Pressure

Range

to to

Speed

Bit

Sub Down

Length

Weight

ft

Ibm 750

ito

32

31/2

in.-Reg

17.4

36

to

73

41/2

in.-Reg

19.8

1760

49

to

97

23.0

2430

to

137

in..Reg

24.6

85

to

170

6/ 6% 7%

jn..Reg

69

in.-Reg

26.6

3970 5950

2/

mn.-Reg

20.8

470

to

12

300

600

75-150

465

to

171/2

425

845

80-1

60

465

525

1050

65-130

465

80

190

325-800

580

320

20

to

52

/8 9/

100

240

245-600

580

585

27

to

67

31/2

in.-Reg

170

345

200-510

580

1015

39

to

98

41/2

in.-Reg

24.0

1760

9/8

200

475

205-485

580

1500

58

to

138

41/2

in.-Reg

26.6

245

635

165-380

465

66

to

151

26.5

230-380

810

to

270

in.-Reg

33.0

120-250

465

to

256

6/ 6% 7%

in.-Reg

635

2085 3730 5385

in.-Reg

30.0

2160 2800 5200 7300

to

16.8

400

17

to

41/4

to

26

TYPE

to 61/4

/8

to

8/8

to

91/2

to

12

91/2

11

171/2

121/4

to

171/2

395

to

26

525

1055

163 123

840

21.5

TYPE 41/4

to to to

91/2 111/4

60

145

340-855

580

245

16

40

2% in.Reg

415

21

to

53

31/2

mn.-Reg

17.5

39

to

98

41/2

mn.-Reg

25.0

1760

41/2

/8 9/

80

185

270-680

580

170

345

200-510

580

1015

8%

to

10%

160

395

140-480

465

27

to

91

91/2

to

121/4

200

475

160-400

465

12

1475

45

to

112

to

171/2

240

610

135-340

465

59

to

148

171/2

to

290

690

115-290

465

2280 2990

65

to

165

100

150

380.580

625

412

29.8

to

180

250

350-482

360

480

32.0

to

44.1

801

44.5

to

65.7

50.8

to

67.6

to

142.1

to

202.8

26

995

680

in..Reg

21.9

1585

in.-Reg

23.8

mn.-Reg

24.9

in.-Reg

26.0

2430 3970 5950

2/8

mn.-Reg

22.5

530

31/2

in..Reg

19.9

911

in.-Reg

19.9

1582

in.-Reg

21

in..Reg

26.5

in.-Reg

33.2

2350 4350 8100

6/ 6/ 7%

TYPE

4%

37/a

to to

61/2

12

to

9/8

250

350

292-431

360

97/s

to

12

325

450

230-332

360

to

171/2

500

800

200-420

360

to

26

800

1200

125-188

360

determine

Next motor

and

to

for

horsepower enough

with

drilling

Table

of

the

pump

rate

operating

PDM

which

8.81

the

to

is

in

75/s

the

for

needed

to

the

keep

drill-

needed

collars

is

19000 lbm

ncI 1.

10-P-l30

pump 448 gal/ mm and 85% me efficiency

rate the

is

number of

95.7

lbm/ft30

0.80

ft/collar

will

be

will

factor

safety

tension

bit

within

drill collars

penetration

maximum WOB

pipe

6% 7%

73.3

20%

because

41/2

bearings

450 gal/mm

well

is

134.8

45.5

the

8.3

collars

operating nine

For convenience

pump how many how much torque

maximum

salt at

the

the

bit

the

To determine consider

the

maximum recommended

volumetric

efficiency

of

5-1-7

the

112 strokes/mm

100%

this assumes chanical

that

714-in at

for

requirements

1160 1775 5666

drive

to

necessary

pressure across

Series

shows

8.10

pump

range

the

provide

the pressure-drop

satisfy

and

8%

12 17

9%

77/s

might

necessary of

15

be

needed

used This

leaves

to

drill

pipe with

an

ft/hr

With

maximum PDM

the

Eq

torque

collars

and up

sure

pump

the rate

of

ft

three

annulus

minus

448

gal/mm

of

could

stands

l9.5-lbm/ft

5-in

in The pressure

ID of 4.276

drilistring at

10330

the

bit

are

losses

arid as

XH

be

drill-

in the

PDM

pres

follows

is

15ft/hr

l160I3.79l9.7-.J

loss through

Case

45

ft

of

4-in.-ID

standpipe

55

ft

of

3-in.-ID

hose

ft

of

3-in.-ID

swivel

ft

of

4-in -ID

kelly

in

332rpm12.25

surface

Pressure

40 l2.25Wb

where The is

116

mud

19000

Wb drill

collars

lbm/ft

or 95.7

in air lbf/ft

lbf are and

73%

in

0.825

Reciuse

OD by

in

xl 16 lbm/ft

1QOO

ID The in

1bfre

11.5

weight

Pressure

loss

through

drillpipe

Pressure

loss

through

drill

Pressure

loss

up the

drillpipe

Pressure

loss

up the

drill

psi

710

collars

collar

24

equipment

3-in

ID

annulus

psi

89

psi

161

annulus

psi

56

psi

lbm/gal

neetkd

nd

Pressure-loss ft

cinvi1

calculations

are

based

on

power-law

niodel

yield

value

sf9

Ibfl

APPLIED

420

The

total

lated

as

for

pressure drop

24

psi710

89

psi

10600-ft

the

psi

161

BOTTOM

OFF

cacu-

is

string

LOAD

56

psi

ENGINEERING

DRILLING

BEARiP

TiQo

LBS

psi

____________

040

To design

the

maximum bit of

basis

the

maximum 20000

of

WOB

lbf

for

bit

pressure

run

5000

as

of

drop

to

lbf

the

use of

the

lbf

12000

on-bottom

the

lbf

for

bit

bit

Because

this

lbf

BEARING

Fig

WOB

nd

8.1 16F-Iydraulic

Fig

8000

load

bearing

WOB

be

will

The

The

much

total

would

be

standpipe

pressure

at 450

follows

as

before

loss

mud

actual

weight

Total

PDM zp

1040 psi motor torque

for

standpipe

500

psi

360

psi

1900

pressure

psi

psi

Ibm/gal

The next that

is

step

miss

will

the

to

design

top of

and

ameters which means

pressure

10

500

loss

will

ibm/gal

435

psi

11.5

psi

ibm/gal

be

The nozzles should

mud

of

weight and

be sized

11.5

i%2..jn

for

Table

lbm/gal

nozzles

of 8.12

are required

to

435

psi

shows the

give

is

that

no and

S15E

8.12PRESSURE

JET

turn

right

NOZZLE

plan

would

should

be

not

will

151515

151516

151616

161616

161618

161818

181818

181820

gal/mm

0.5177

0.5415

0.5653

0.5890

0.5412

0.6934

0.7455

0.8038

sq

in 578

in

sq

sq

in

sq

In

sq

in

528

485

446

377

420

606

554

508

468

430

635

581

533

491

440

665

608

558

450

696

636

460

727

665

470

759

sq

in

sq

old

offset

desired for

call

be

the

the

to

old

by two for

target

right

turn

with

therefore

ensure

that It

the

away

change

borehole

drop

new

the

must be

PSI

in

sq

in

182020 0.8621 sq

in

322

279

240

208

395

338

292

251

414

354

306

264

514

434

371

321

584

537

454

388

610

562

474

405

694

637

586

495

423

202020

202022

202222

0.9204

0.9048

0.0492

sq

in

sq

in

sq

in

183

160

141

219

192

168

148

229

201

176

155

276

240

210

184

162

336

289

251

220

192

169

351

302

262

230

201

177

366

315

274

240

210

185

480

792

724

664

612

516

441

382

328

286

250

219

193

490

825

754

692

637

538

460

398

342

298

261

228

201

500

859

785

721

664

560

479

414

356

310

272

237

209

510

894

817

750

690

583

498

431

371

322

283

247

218

520

929

849

779

718

606

518

448

385

335

294

257

226

530

965

882

810

746

629

538

465

400

348

305

267

235

540

1002

916

840

774

653

559

483

416

361

317

277

244

550

1039

950

872

803

678

580

501

431

375

329

287

253

560

1078

985

904

832

702

601

520

447

389

341

298

262

570

1116

1021

936

862

728

622

538

463

403

353

309

272

580

1156

1057

970

893

754

644

557

480

417

366

319

281

590

1196

1093

1003

924

780

667

577

496

431

378

331

291

600

1237

1131

1038

956

806

690

597

513

446

391

342

301

610

1279

1169

1073

988

834

713

617

530

461

405

353

311

620

1321

1207

1108

1020

861

736

637

548

476

418

365

322

630

1364

1247

1144

1053

889

760

658

566

492

432

377

332

Size

32/Too

ri

Nozzle

Area

sq

ri

di-

weilbore

fish

direction

risky

bit

wellbore

AREA

SIZE

FlowRate

________ 410

of

to

planned

re-enter

NOZZLES

JET

side

simple

change

two

new

the

sidetrack

the

least

of the

the

should

wellbore

inclination

THROUGH THE

LOSS

the

old

the

borehole

TABLE

is

at

by

side

the

Because

from

ap-

in from

fish

the

0.78

diameters

and

proximate

that

change

bit

bit

24

about

for

trajectory

the

The minimum average

well

Nozzie

the

Pb

10

21%

including

courtesy

gal/mm

Drilistring

Maximum 500

balance

pressure

weight

8.12

pressure

weight

bit

is

motor

as

actual

mud

for

and

thrust

yna-

should

short

be increased

WOB

lbf

BtAftNGLOADJ

BOTTOM

ON

LOAOIlOLBS

at

psi

maximum

must be corrected

Table

750

balanced the

bearing load can

17000

of

i.p

5L

the

The

maximum recommended

the

psi

load

PSI

the

on

balance

20000

is

bearing

If

500

be determined

application

500 psi

of

run correctly

bit-weight

on-bottom

differential

at

not exceed

this

4600

is

bit

and

thrust

the

of

lbf

desired

for

that

motor

should

pressure drop

hydraulic

shows

8.116

PDM

optimum

ended

open

pressure

circulating

psi

Ceorrecy

iii

Dyrra

Drill

DIRECTIONAL

AND

DRILLING

TABLE

CONTROL

DEVIATION

5.13DEFLECTION

ANGLE

Bent-Sub

Hole

Angle

in

degflOO

11/2

21/2

5/8 11/2

21/2

bent-sub

dicted

right

on

Based total

safe

angle

and

turn

change

ft

dogleg

deg/l00

9/8

harder formations as

respond be

based

old weilbore

the

220 ft

over

severity

The

the

is

bit

is

so

121/4

reactive

the

Because tion

2220 440

to

100

ed

The current inclination nation tain

drop what total

be

the

tool-face

4.4

of

change

and

to

setting

main

maximum

achieve

change

Eq

First

calculate

the

tool

face

be

ample

The

is

lesser in

The

1153

will

the

tool-face

setting

maximum direction

of

153 can

change

12 of

right

be

the

high side with

calculated

Eq

8.42

-in

/4

1.75

100

tan4.4

sin153

EarctanI sin4 tan4.4

cos4

safest

plan

8.6.10

The

the

tool-face

should

tool

start

sidetrack

the

more than enough

is

Because

target

watched

the

and

120

is

to

select

drill

corrected

which

will

re

1.5

bent

than

less

would

be

bent

sub

that

2.0 100 ft 73%-in PDM in

of approximately

on

sub an

yield

ft Because

is

response

obtain steering

to

bent

should

ft

to the

90

design

change

8.13

2.5100

of

the

angle

hole

be adjust

ze

of

last part

an

setting

be

to

to

be

face

WOB

need

and

the

fric

no

tool

torque response

will

change

toward

tool-face

From Table With

face

tool

direction can

the

smaller

give

with

tries

for

the

set

run

setting

not be observed

will

face

tool-direction

slow

sult

the

wellbore

the

to

cos4.4cos2

set

calculated

head

ing

sin4 sin4.4

to

few

allows

reactive

264

calculated

the

be

tool

near-maximum

probably tool

5-1-7

Series

proper

to

initially

the

the

at the

be

with

bit

the

and

steering

calculation

observe

and

115 215 300 430

PDM that

plan

the

to

153

of

5000r

17

always

to

torque

friction

than

less

setting

8.48

yarccosl

of

setting

to

direction

with

should

angle

incli

Assuming

is

and

230 3045

the

torque

engage

full reactive

cause

will

reactive

20000 lbf The

face

l045

15

requires

would be wise

it

N48E

at

and

tool

the

from

torque

ft

200 300 430

131/2

500 200 330 415 530 145 230 330 500

10%

significant

that

deg/100

3045

500 115 200 300 400

that

pre on

Angle

in

It

230

9/

fl

Deflection

Size

deg/l00

3045

10%

9/

Angle

in

ft

230 330 430 l45 300

5045

away from

drop

100

the

SIZE

Hole

Deflection

Size

Angle

in

230 330 430 530

7/

Hole

Deflection

Size

deg/lOOft

330 445 530 3O0 415 500

would

design

Hole

Angle

in

not always

will

Therefore

2100-ft

in

sidetracking

assembly

AND HOLE

in

in

61/2

Deflection

Size It

4O0 430 530 3O0 330 400 5OO 2OO 230 300 330

11/2

remembered when

Hole

Angle

in 41/4

the

in

Deflection

Size

degrees

FROM BENT-SUB ANGLE

RESULTING

BENT-SUB ASSEMBLY

___________ 31/8

421

sub

angle

the formations those to

nearly

are harder and

included

in

1.5

the

run

of

change

would give an angle change

Table

the

8.13

the

sub

bent

cos153

87.8 The

reactive

culated

1160

from

for

torque

Eq

8.57

the

bit

with

and

the

PDM

can

maximum motor

l1.5x 106

lbf

125160

psi

32.8

in in.4

3240 346

with

turbine

and

required

flow

bine be

at

the

136

torque

264

to

2ir

be

ure

that

is

that

the

PDM

is

omitted

because

its

short

length

less

rates

at

will

must

more complicat

is

be

chosen

must be able

rig

pressures

of operating

In

the

that

will

at

given

deliver

operator and

speed

the

tur

the

operate

the

addition

turbine

for

to

maximum horsepower

achieve

unlike related

the to

is

bit

is

is

neither

to

very

the

must

torque most

familiar

of

the

only is

to

the

way

meas

surface-reading

turbine with

nor

speed

properly

torque

control

bit

pressure

performing

andor

speed

needed

the operator

PDM

the standpipe

turbine

certain

downhole

tachometer Note

drilling

turbine

bit

time

Because 4.6

the

The

maximumefficiency

capable

ranges

4.61

PDM

than

in

in.4

with

Drilling economically ed

in

and

for Directional

Drilling

be cal

torque of

ft-lbf

13920

Turbine

Use of

Straight-Hole

accurately

the formations

un in

APPLIED

422

advanced

the

bines have of

soft

not been

Blade

because

sive

turbine

of

the

such

turbine

as

more

is

likely

and

successful

be

to

making

in

eccentric

sub or bent

Face

Three

After

Blade

the

the Force

Side

is

and

with

BHA BHA See

assembly The turbine

economi

how

too

difficult

and

bit side-

less

does

8.7

bent

as

rotate

drillstring

stabilizer

This system for

of

part

used

frequently

is

to

see

bit

not

achieved

is

eccentric

Sec

the

oriented

is

is

changes

near

drillstring

can

PDM

as

change

turbine

change

the

tachometer

trajectory

blade

de

properly

with

the

the

trajectory

begun

controlling

building

on

undergauge

housing

desired

rotation

speed

successful

trajectory

stabilizer

117 The

Fig Tool Stabilizer

is

dictate

combination

bit

One way of making controlled use an

bit

bit

tricone

changes

trajectory

formations

areas

In

with

aggres diamond or other type of drag bit the

as

turbine

signed

used

tricone

mentioned

previously

PDMs

as

been

not necessarily

with

problems Where

bit

be

have

For most

changes

changes tur

trajectory

used

widely

make successful though

trajectory

force

as

diamond

polycrystalline

making

turbines

ever operating Five

new

the

and

off

formations

bits to

cal

of

designs

bits For kicking

ENGINEERING

DRILLING

of

description

with build

ing

normal 8.117Eccentric

Fig

stabilizer

and

Feenstra

after

Kamp17

knows

ly Even

with

turbine

the

with

the

This

the

such

WOB

right

outside

to

the

turbine

and

watch

and

stalling

optimum

thorough must

operator

from

the slow

for

Union

Soviet

the

it

keep

ensure

reason

To emphasize ten

to

the

the

experience

constantly

another

is

of

capabilities

Eq

of

torque

and

BHA

8.78

rewrit

bits

22

is

similar

overcome

to

torque

for

relationship is

to

any

friction

8.5-in

an

drag

the

Neglecting

the

yields

$19500

polycrystalline

bit

rela

following

cost

8.90

M8.537-f-203x_-___dbWb

tained

at

crease

the

constant

penetration speed it

is

ance the

and

to

kept of

rate

causes

at the

peak

turbine

hook-load tricone

in drilling bit-speed

Properly competitive

the

If the

of

the

arid

the

indicator bit

with

torque

bit

speed

to is

is

with

in drilling

PDM

drilling

the

and

the so

rotary

bit

using

system

pressure gauge

with

turbine

in

many

drilling

can

be

situations

economically

especially

the

theoretical

has

bit

vis

plastic

lbf/100

ft

sq

bit

costs costs

hours Rig

16

is

nomograph

dull

is

about

flow

propriate size

of

7-in

for

the

and

rate

of

torque

of the

sq

in Assume diamond

the

bit

new

of 850

speed

rotary

Select

and

number of

stages

for

area

of

diamond

the

bit

ap

the

that

flow

un

bit

half

rate

total

constant

at

and

rate

penetration

new diamond

the

pump-off area of 10

the penetration

when

to

turbodrill

time

torque

characteristics

rpm The that

the

7-in

is

ft

Example

in

as

15

is

salvage

Fig 8.118A

rig

The diamond

hour Round-trip

conditions

least

at

provide

Solution that

the

mum

Refer turbine

power

provide

the

2.0

to

2.5 hhpfsq

with

it

as

will the

850

the

the

turbine bit

to

in

the

found

and

as

in

number of

25000 lbf 50% additional

dulls

in

Fig 8.ll8A to

rpm The nomograph

information

that

take bit

at

nomograph requires 440 gal/mm to

calculate

Roughly assuming

the turbine

50%

17520

are graded

lbm/gal

value

$4400

costs

der downiiole

requires

indicator engineered

bit

16.2

yield

of

depth and

ft

same

the

is

the

at

run

to

8-in

where

that

perform

Unlike

Use

economical

is

it

in

reduction

optimal

or using the standpipe

type

50 100 150 and 200 stages The turbine maximum horsepower at about 850 rpm Fig

pressure-drop

and

decrease

not obtained

in

will

both

not controlled

power curve bit

WOB

reduces

The

main

are

weight of

in turn

rate

penetration

increase

the

the addition

levels

the

mud

and

size

torque which

turbine

and

speed

bit

bit

with

14A shows

8.1

stroke

bit

reac

or counterclock

left

situation

140

to

density

and

cp

$800/hr

is

ft/hr

120

gauge

rotating

develops

pump

drill

assuming

$500 per

turbine

tionship

If the

in

6-2-7

Series

bit

the

gives the

this

on the

dependent

some of

average

8.21 The oil-mud cosity

torque

bits

usually

-in

and

Mi

The

degrees

reduces

it

counteracts

drillstring

whether Example 8.22 Determine diamond bit with turbine in Series 6-2-7

diamond

varying

to

component

tendency

The

bit

to

and

turbine

the

for

directional

turbines

as

Nb

the

BHA

the

rotary

torque of

reactive

of

part

most

conditions

drilling

acceptance

consider

the

as

to drill

Europe

problem

Unlike

Rotating

tive

wise

used

drilling

or counterclockwise

left

direction

and

commonly

systems

drilling

strong

size

is

directional

will

its

Table drill

be applied

weight

to

pump-off

develop and

to

its

Fig

find

maxi

8.1

14A

8.14 collars

required

initially

maintain effect

and

bit

that

torque

increases

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

423

Calculate

20%

safety

81.3

lbflft

collars

the

factor

37500

nc 87.3

Using

bit

tion

of

from

113

80

determine

ft/hr

which

required

440

at

Use of

bit

at the

dia

the

in

hhp/sq

is

Lp

psi

8.114A

Fig

18 2.0

hhp

442

to

equates

of

for

required

minimum gal/mm

of

lbf

rate

penetration

mond

using

stands

collars6

17.9

lbf

buoyed weight

having

ft/collar0

lbf/ft30

37500

for

required collars

for

the

equa

yields

1440216.2

0.9830.91

Aqrr

sq in

8795442 The

EXAMPLE GIVEN

Mud FIND SOLUTION

rat

Circulation

erlgflr

St

At

graph

at

irtsnsoctlon

ttSD

PSI

horonpow.r Dl

10

4S0

GPM

torque

St

circulation

and line

should

Can

drop

wilt

end

6PM

the

IncA

of

to

ot

010

PrOj.ol

010

read

preseur

.tint.rS.ctiOn

down

from

line

the

ceeding

motor

Stage

dashad

Following

and

50

for

Speed

LBfOAL

LBFT HP

210

speed

OPtS

450

1200

Dl

andr.ea read

poem At

waight

torque

and

on

turn

the

the

drop

8.ll8ASeven.inch acleristics

turbine

size

of

the

liners

at

of

limit

pressure capacity

system For

culating

rat

is

motor

Baker

than

larger

that

of

the

in

sq

are run

It

depends

pump

in the

ex

without

rig

drilling

other

all

0.91

440 gal/mm

and

in the

components

on cir

tOIlOW

cirVuletlon

RPM

drilling

courtesy

no

be operated

pressure

to

6-in

install

and

strokes/mm Fig

be

turbine

IB2OAL

pressur

Operating

Enter

450

operating

Service

10-P-I 30

the

The

liners 125

only

good

pump

pump

rated

is

be

will

strokes/mm

choice to

140

required

char

Tools

440

gal/min-i-3.7

125

efficiency

strokes/mm

The pump so

pump

gal/strokexO.95

3705

is

rated

3900

to

psi

will

be

psix

0.95

pump

maximum with

psi

maximum

the

6-in

planned

liners

standpipe

pressure Cl

3900

Now

calculate

culating

component

the

system

for

Surface

bore

RPM

Drill

collar

Drill

bit

Drill

collar

Fig

8.118BOne-stage

turbodrill

characteristics

Total

psi

bore

psi

psi

No

Stages

psi

ftllbf

50

800

680

100

1340

150

1890

Turbine

hp

Bit

Weight

ibm

310 456

3089

psi

Rate Torque

24

442 annulus

RANGE 8.14TURBINE OPERATING SELECTED FROM FIGS 8.114A and 8.118A

Turbine

in the

219

psi

psi

TABLE

Turbine

losses

fluid

1638

psi

annulus

Drillpipe

pressure law

power

equipment

Drillpipe

factor 3705 psi

safety

of

Penetration ftlhr

110

13.5

12.2

1360

220

24.5

24.1

2040

330

32.5

29.3

cir

APPLIED

424

TABLE

PRESSURES

8.15DRILLSTRING

LOSSES

FLOW RATES

AT VARIOUS

Drill

coflar

Drifi

bit

77

bore

annulus

collar

annulus

Drilipipe

Available

gal/mn

pressure

Available

power hp

for

psi

The pressure 50-stage with

gal/mm the

losses

in the

60

117

188

207

369

576

24

48

91

144

207

391

561

203

mud

16.2-ibm/gal

probiem

solved

is

problem cannot

be

and

800

This does

that

solved

too great

turbine

until

it

is

for

not be

can

anaiyzed

2512

3668

2153

1193

37

339

377

207

about

even

440

mean

that

clear

278

ing

mud

to

is

the

analyze

system

circulat

the

flow

rates

Add

the

such

component

100 200 300 400

as

component

losses

each

for

pressure Plot

standpipe

horizontal

line

at

losses

pressure

and

determine

to

flow

at

500 gal/mm

the

total

stand-

rate

each

at

the

flow

calculated the

plot

flow

standpipe

and

note

rate

at

the

rate

available

turbine

be and

was designed

to

the system

to

curve

is

not

and

and

cquals

14

8.15

flow rate

procedure

and

is

shown

is

applied

18A

8.1

water Notice tp1

of 275

more power

the

Fig that

psi

for

For

bit

the

be

wili

liners

repre

18B

based

is

power occurs

for water

Therefore

mud

16.2x

l0-P-130 rated

is

if

and

possible

pump

the

adjust at

300

choice

good

140

to

in

hhp/sq

gal/mm

-in

is

but only

strokes/mm

required

102

pump

gal/strokexO.95

efficiency

strokes/mm

tur

The pump

the turbine must

ever

95%

and

contractor

3950

rated

is

although

4645

operator

agree

and

of the

5-in

with

psi

of

because

psi

hose

4645

to

psi in

limitations

is

4413

this

case

liners

not

how

both

psi

to

of the standpipe

swivel

see

problem

The optimal

flow

rate

gal/mm

as

rate

at

which

the

to

downhole motor

power

tem rate the

at

the

such

as

will

turbine reduced

55

is

200 hhp

stages is

system

Figs 8.119A

speed to

Fig

avaiiable

is

8.1

from

power conversion

to

only hp

18A 575

with

19B shows the

stages

that

at

turbine

WITH

sys

8.16SYSTEM PRESSURE AT VARIOUS FLOW RATES DIAMOND BIT TFA OF 0.42

DROP SQ IN

other flow

no

Available

the

resultant

and

153

hp

300 gal/mm

system Assuming

factor

TABLE

horse

more strongly at shows that at 300

rpm and 150

flow

delivered

in the

something

horsepower

the

is

is

inechanica

larger drillpipe

Fig

115

approximately

That

horsepower

changing to

is

19B

8.1

Fig

mechanical

power

this

conversion

Without

switching

gal/mm

377

for

The nomograph

bit

with

in

most hydraulic

bit

affect

for

shown

that

roughly develops

Flow

Rate

gal/mm 100

Lp psi

Bit

90

Standpipe

Slandpipe

Pressure

Pressure

psi 289

psi

Available Hydraulic

Horsepower

hp

3661

214

200

361

1066

2884

337

300

811

2156

1794

314

400 500

1443 2254

3586 5346

364

85

the

exceed

and

300

to

turbine

8.1

peak

l6.2-lbm/gal

give 2.5

to

300 gal/min3.1

agree

turbine

in

graphically

than

the

stage of

one

the range

deliver

can

to

which

for

particular

this

to

Fig

for in

operate

situation

psi

The pump

liners

ly

The foregoing

to

turbine

that

pump

the

diamond

of the

flow

the

necessarily

different

characteristics

now

problem matched

is

7/8.3314

The corre

operated

which case

in

operate

the

which

at

pressure

1714

power on

considered

Table

000 rpm

that

limi

would

equals

by

pressure drop

may

It

power

the

in

with

Fig hp The

turbine

particular

previously

becomes

It

118A

in

153

its

selecting

This

with

gal/mm

system

flow

divided

occurs This be

the

is

sized

rate

mismatched

should

pressure

should

the flow

available

each

turbine

designed

on 300 gal/rmn

102 at

power

available

it

graph

separate

rate

per minute

which

at

which the turbine

sponding

bine

vs

hydrauiic

pres

between maximum

flow

pressure available

maximum

the flow

standpipe

On

pressure

times gallons

psi

Locate

the difference

on the same graph

plot

available

with

the

available

remaining

rate

available

and

in this

sented

4i

Mark

rate

maximum recommended

standpipe

Compute rate

bit

Resize

Determine sure

gal/mm

the

pressure

and

325

300

at this

to

were no standpipe-pressure

with

18B shows

8.1

turbodrill

at

vs

pressure

the

several

of

one

suited

200-stage

7-in to

Compute

there

optimal

than

less

as

entire

if

be

becomes

properly

even

best

is

the

run The

system

pipe

that

11

377x0.55207

hp

tation even

Fig

The correct procedure

272

2908

at

psi

2021

1552

foliows

be

1401

243

133

3483

consumes

31

92

797

are

system

which

turbine

gal/mm

23

37053089616

turbine

the

500

at

gal/mm

20

78

AvaabIe

pressure

400

at

19

16.2-lbm/gal

the

is

gal/mn

878

222

standpipe

8.22

460

psi

the

300

at

11

bore

Drilipipe

Total

200

at

gal/mm

equipment

Surface

Drill

100

at

PROBLEM

psi

Pressures

Components

FOR

ENGINEERING

DRILLING

kel

DIRECTIONAL

DRILLING

AND

DEVIATION

CONTROL

425

The

of

2.5 hhp/sq

at

300

at

required

diamond

the

in

bit

to

X56.7

be

reduced

2.5

hhp/sq

142

hhpxl714/300811

2.5

give

provide

810

is

psi

in

hhp/sq

in.142

sq

to

of

pressure drop

gal/mm

in

must

bit

the

hhp

ci

minimum culate

the

Table

With

to

200

Flow

Fig

8.ll9AStandpipe

300

Rate

400

500

300

at

annular

vs

flow

cuttings

the

turbine

mud

flow

through

285 gal/mm

zp

bit

table

previous 4000

730

Bit

hydraulic

which

be adjusted by

Available

and

marginal 81

turbine

psi

of

Pat

pressure

in the

2.1

turbine

hhp/sq pressure of

calculated

is

the

thus giving

diversion

the

of

shown is

available

because

5%

more than

bit psi

horsepower

the

be

no

the

op

its

important

therefore

811

at

and

least

the

than

is

sys

decided

cleaning

bit

at

through

flowing

psi

will

is

divert

See

rates

the

is

it

turbine

the

cleaning

to

of

rate

but

adequate

Bit

rather

in

flow

recal

A.f flow

various

at

operate

provide

the bearings be

0.46-sq-in

gal/mm

designed

is

will

of

to

to

transport

cause rate

the

optimal

260

gal/mm and

rate

gal/mm

pressure

the

about

to

Now

required

is

pressure drops

system

reduced

design

sq in

pressures using

shifted

operate

timal 100

for

the

has

tern

0.46 A11 of

system

16

psi

fluid

as

3000

1875

ci

Calculate

2000

number

the

PE

1875

Lp1

14

of turbine

stages

psi

1000 .0

psi/stage

CO

1875/14134

LPELp1 200

300

Flow

Rate

The

gal/mm

7-in

turbine

available

Fig 8.119BAvailable

and

pressure

stages

500

vs

power

as

Determine flow

in

is

readily

turbine 130-stage power output of 8.118B that one turbine stage develops

Fig

maximum

18B

8.1

tool

the

rate

Note

Fig

in

represented

130-stage

of

0.87

hp

300

at

water

with

gal/mm

Therefore 900

0.87

800

100

16.2

.7

\Turne

with

hp/stage

RotarV

1.7 Even

Break

500

130

hp/stagex

mud

l6.2-lbm/gal

600

LL

lbm/gal

lbm/gal/8.33

stages

223 Hm

at

deliver

221

bit

the

Point

The

turbine

130-stage

400

compared with to

300-

in

18A

Fig

turbine

is

mismatched

200

must

It

153 hp

the

This does

the

this

now

determined

be

that

the

however

in

system

mean

not

at

hp

turbine

200-stage

tool

good

not to

will

with

Fig 50

100

200

150

Feet

250

300

350

400

Drilled

8.1 for

curves This

and

figure

Fig

8.11

9CAnalysis

of

cost

per

footrotary vs

turbine

drilling

penetration

20000-

to

penetration the

of

bit

15

14B

shows

is

ft/hr

the

whether

at

35000 20

of

rates

26000-lbf of

the

dulled over

bit

so the

the

be

the

130-stage

7000

about

the turbine

range will

assume

ft/hr

an

average

run Also

torque turbine

the

bit

is

stalled Peak

achieved

are

by

lbf is

Remember

decrease

and

rate

at

21

economical

l30-stage

lbf

to

entire

will

on

bit

that

indicates

bit

highly

is

example

penetration

new diamond

off and

pumped

diamond

natural

bit

200-stage

it

100

turbine

the

referred

that

about

the

in

of

when

half

penetration

remember

the

rate

that

rate bit

APPLIED

426

decrease

will

torque

WOB

be

must

50%

by

increased

as

the

bit

dulls

the

run

throughout

ENGINEERING

DRILLING

therefore maintain

to

Regular

DII

turbine

force

off

is

result

that

is

WOB

final

the that

the

to

WOB

be about

should

should

be about

calculation

original

50%

bit

the

as

maintain

more weight

still

initial

Also diamond

power

increase about

to

likely

thus requiring

peak

at

operation

bit

36000

lbf

which

for

six

stands

calling

dulls

The

torque

23000

Pipe

pump-

and

lbf

means of

Heavy

drill

Weight

Dirlipipe

collars

The bit

applies

still

rotary

cost

drilling

per foot

the

using

Series

6-2-7

is

Drilling Jars

time

trip

timerig costbit

rotating

cost

crot

Drill

Srrialler

feet

drilled

Collars

16 hr40 hr$800Ihr$4400 Sub

Crossover

$Ift

140

for

The

the

ft

cost

While

cost

foot

per

foot

per

for

the

Shock

timerig cost

bit

feet

eeuLri-000pONENr BIIA

drilled

Fig the

Assuming foot

per

16

rate

penetration

for

Stabilioer

Bit

cost

timeturbine cost

rotating

Sub

Brie

Near

rotating

Tool

is

SiCC

trip time

MWD

Drilling

$390

is

turbine

Clurbine

costs

Smaller

Measurement

410 and

To

Collars

Drill

120

120

and

140

8$800Ihr

15

averages ft

8.120Bottomhole

assemblies

the

ft/hr

are

$19500

hrs$500/hr

C120 120

$356/ft and

C0 $3 17/ft The break-even bination and

is

at

interval

for

drilled

turbine

even the

at

average

12

ft/hr

95

can

be

5.6 hours

the

take

drilled

with

and

turbine/diamond-bit

to

foot

per

the equation

interval

decreases

7.9 hours

cost

l9C shows

8.1

Fig

The

ft

calculated

rate

com

turbine/diamond-bit of 84

for

penetration will

it

for

ft

the

interval

per foot

cost

point

for

point

drilled

less

drilled

break-

the

of

84

than

ft

If

15

to

interval

combination

of

break

to

even Side Force

Negative

8.7

Principles

The

BRA

of

drill

shock

and bit

sub

heavyweight depicts In

with ski

the drill

and

two

of

portion

the

construction

collars

causes Bit

the

is

trajectory Its

BHA

of the

bit

and

could

be

drillpipe or

the

that

drillstring

simple having be

may

causes

the tendency

of

consequently

it

affects

lilt

droppirg

the

wellbore drill

only

complicated

bit

having

increases reduces

tendency building

More bit

tilt

negative

WOB and side

force Side Force

Negative stabilizers

magnetic

collars

collar

reamers

drillpipe

and

jars

regular

telemetry crossover

drillpipe

unit

subs

and

BRAs

earlier

days

collars

between

Angle

Fig 8.120

called

of drilling

was the most showed

that

the

slick

common the

assembly

bit

borehole

centerline the

Borehole

bit

of

tilt

bit

centerline

and

BRA

angle

centerline

Later Lubin

pendulum

assembly

Fig

8.121Example

of

bit

tilt

for

pendulum

SHA

is

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

427

la

Diameter

of

Collar

Drill

Moment

Of

Round

For

Fig

8.7.1

the

BHA

slick

ahead

drilling

an

at

inclination

al

alpha

be

used

can

became

for

because

popular

shown

were

control

deviation

of

effective

directional

some

in

BHAs

Multistabiizer

and

drilling

later

deviation

for

attempts

as

BFIAs

All

the

of

BHA

the

the

that

that

casing

wears

can

Bit

tilt

BFIA can

any

of

properties the

if

be is

or

is

exert

cuts

the

BHA

in

factor

WOB

bit direction

and

formations

The curvature

transmitted

of

ry

the

to

direction

softer

the

more

bit

works on the either

bit

of

On

bit

the

bit

the

can

be

with

of

of

hole

cylindrical

used

in

cylinder

or

in the

thick-walled

for

axi

inertia

components

thick-walled

inertia

the

collars

moment

center

cylin

follows

as

expressed

the

drilling as

represented

column

of polar

The

polar

moment

of

inertia

for

the

cylinder

and

Jirde4dj4

the

J21

or

8.92

accurately

of

trajectory

inclination

the

are

well-

influ

that

the

bit-tilt

the

movement

the

harder

ample

rock

the

bent

Calculate

6-in

round

the

and

axial

with

collar

J6 respectively and for an ii and J11 respectively

11-in

polar

moments

246-in

ID 16

collar

3-in

with

of and

ID

Solution

the

16602.1875/6462.5

in.4

housing

sub however

mechanism

8.23

for

trajecto

beat

with

side-force

centerline

8.121 The

controls

tilt

hand

and

Fig

predominates

principle

or

tilt

other

force

side

tilt

see

bit

BHA

the

some

causing

in drilling

especially

of

centerline

the

rock the more the

the

and

and

component

BFIA mechanics

in

softer

the

their

described another

ences

in

and

collars

the

inertia

is

bit

com

64

wellbore

the

determined

the

and that

d4 d4r

to

are so

formation

be

metals

8.91

hole

given

drill collars

of

dimensions

inertia

determined Most

be

parts

forces

for

of

types of

forces on

side

touching

and

the

turn

and

stabilizers

each

size

shape

and

angle

wears

blades

stabilizer

displacements

for

and

the

wellbore

the

makes

bit that

an

equipment

pipe or

speed

the

contacting

physical

known bore

Furthermore contact

forces and

the

at

hold

Sometimes these

the

the

rotary if

it

mechanically

wears

The

force

or casing

formation

great

or

or right

left

side

makes

cause

build or drop

and

shape of

square

der

Collars

representation

the weight

dictate

see Fig 8.123 The axial moment

control

bit

the

moment

BHA could

The

Inertia

Drill

Column

consisting

borehole

collars

Inertia

Tubular

the

BHA

is

of

Of

Square

behavior

From 8.122Typical

of

inclined

elastic

For

8.123Moment

8.122

an

pose

Fig

Collars

Statistics

Fig in

Moment

Inertia

Drill

or both

J6262.5125.O

in.4

may

exist This

section

will

design

and

elastic

behavior

for

the

present

performance of

BHAs will

analysis drillstring

rotation

fnmec

he

will

BHA

analysis

Most of the

apply

to

on

were1

that

principles

The properties

simple

more complex

stabilizer

the

2D the

of

will the

BHA

static

qt the

the

and

single-

bit and

and em-i

uif

the

govern

provide

drill

system The

inclination

hrieflv

that

m41430

J112715

in.4

in.4

basis multiIn

collars of

effects

direction thin

l1.043.04ir164715

Ill

BHA

govern

bit

eetinn

Example

an

order

of

11

in

the

If

differene

8.24

magnitude

IDs

irreikl

in

he

the

moment

of

inertia

by increasing both

the

examples

cnvill

11

is

OD

increased

from

are neglected 1.-

iS

in

to the

APPLIED

428

TABLE

8.17TYPICAL

OF SOME COMMON

PROPERTIES

ALLOYS

Metal

Density

Poinl

Ibm/cu

Base

Cast Ni

Carbon

Iron

Resist-Type

Cr-Mo

Steels

Cr

12

Elasticity

106

psi

Yield

Thermal

Strength

Strength

10

1O

psi

Steel

cm

Brinnel

i/sq

Hardness

ft/F/ft

2760

491

2150

449

2250

456

2500

491

2720

484

29.2

89

47

29.0 13.5

60

40

30

10

21

18to60

8to40

29.9

63to84

40to56

to

100

66

to

30

10

15

19

to

70

70

13.0

27.4

85

35

72

9.4

160

28.1

90

42

74

9.4

165

85

40

74

Stainless

316

2550

501

Stainless

317

2550

501

Worthite

Alloy

20

2650

501

25

Cr-12

Ni

Steel

2650

501

25

Cr-12

Ni

Steel

2650

501

2525

503

800 Base

165

75

160

80

57

78

8.0

28.2

88

33

78

8.0

165

28.5

82

43

93

8.0

184

32

48

12.6

48

10.1

50

32.5

20

160

Alloys

Monel

400

2460

551

26.0

81

Monel

k-500

2460

529

26.0

160

Nickel

200

2640

556

30.0

67

22

85

600

111

44

2600

526

31.0

36

103

8.6

40

Hastelloy

2460

577

31.0

131

56

135

6.5

23

Hastelloy

2380

558

29.8

121

58

133

7.3

23

2590

515

27.0

155

87

124

7.0

2600

515

31.0

178

122

122

6.92

2450

513

30.6

154

91

92

2500

538

28.0

172

87

98

8.6

61

11.5

150

95

230

Alloys

Nimonic

80 X-750

Inconel

26

Retractaloy

31

Haynes Alloy Other Metals Aluminum

1220

170

10.6

28

25

Titanium

3135

281

16.0

85

63

6200

1205

51.5

200

Tungsten

in.4

18.7 creased

in

to

the

If

ID

in

moment

the

6-in

the

example

decreased

is

is

materiaj

to

material

pipe can

strains

when

linearly

01 Mud 01 Mud 7.75W OD Mud

strain

and

stressed

of

in the

be

elastic

region

beyond

pulled

the

Note

that

that

of mild

and

values

the

steel

and

time

the

in the

is

elastic

its

that

limit

5.0

Motor

65

Motor Motor

TUNGSTEN

and 10 in

resulting

Table

51.49

the

ID

psi

2.5

8.17 10

aluminum

the

however

failure

possible

of

drillstring

Sometimes

some common

of

modulus

double The modulus

the

20

that

.0

Most of

region

deformation

presents

amount of

the

amount of stress This assumes

given

Elookes-law are

relates

340

in

20

Youngs modulus

176

131

59.6

to

only

185

250

6018

in or 4.6%

plastic

300

50

140 27.4

to

501

Super

BHA

BTUh

Micrortms

2590

Inconel

the

Conductivity

304

Incoly

sq

psi

Resistance

Stainless

Nickel

in

Tensile

Alloys

Low

Steel

of

ft

_____

Iron

Modulus

ENGINEERING

AND METALS

Electrical

Melting

DRILLING

alloys is

and

nearly

metals

one-third

modulus of tungsten

slightly

decreases

of the

moment

of

called

the

is

nearly

with an

increase

and

modulus

temperature

The product of

is

elasticity

8.124

BHA

is

of the

plot

stiffness

inertia

of

of

the

material

of various

function

as

components

stiffness

OD

El Fig

drillstring

and

and

10

Outside

Example 8.24 lar

having

an

Determine the

OD

of

106

lbf/sq

of

stiffness

in and

an

ID

Solution

EI51.5x

irf6.25

in.4

in

2.1875 64

3.80x 10

sq

in.-lbf

in.41

tungsten of

11

ID

2y16

in

col

Fig

8.1

24Drill.collar

Diameler

stiffness

in

after

Millheim19

DIRECTIONAL

The

air

mined known

However

even

calculated

the

chined

air

grooves

creased

so

the

air

Determining stabilizers

air

collar

can

can the

form

the

so

more

When hole

because

of

the

the

than

elliptical

BI-IA

air

other

de

downhole

ge

cross-sectional the

reason air

of

calculated is

weight

may

that

not be

the

uni

component

The buoyancy

determined

from

in

placed

correction

of

be

8.93 Fig

8.125Tangencies

where

is

nent and

Wm

the density the

is

Example 8.25

OD

Each

is

10

collar

of

the metal of the of

weight

mud

the

BIA compo units

in consistent

of 45 steel collars Determine the weight in ID is 36 in and is 490 lbm/cu is

31

long

ft

and

mud

the

weight

is

16

is

is

the

inclination

of

490

String

sq

point

\144

45

in

sq in

31

bit in

in

ft

and

the

air first

and

feet

is

the

at

is

the

negative

BHA

whose

25

is

ft

ibf/cu

in

force

98.6

is

weight

of

inclination

an

tangency

Ebf/ft25

side air

and

length

ft

ft

lbf/gal

8.33

ft

lbf/cu

ibf/cu

ftJ/489

ft

lbf/gal

sin4

String

Mud

in

74.l

ibf

W5B If axial

16

337909

lbm 1490

lbm/cu

ponent

lbm/gal

ft-8.33

Ibm/gal

lbm/cu

ft

-i-490

ibm/cu

ft255255 Ibm

pipe bending

as

FB

force be

the

Eq BHA

slick

BHA

caused

by gravity

determined

FBO.5WcLTBC

has

sfl

and

typical

negative

At

the

pendu

component bit

this

the

load

axial

force

com

must be considered

Fig

bit

positive

load

axial

zero an

to

force

is

and

applied

component of any BI-IA moments occurring over the

Active

refers

portion

main tangency 8.95

Timoshenko

Each

applied

bending

positive

bending

low

Fig 8.125 depicts lum assembly

is

the the

BHA

BHA

weight

called

8126 shows the

can

of

98.6

lsqft

ibm/cu

in the

lbm

of

Slick

slick

62.4

\4/

337909

x62.4

for

ft

x102 _3.062

Weight

the

FB

fir\/ lbm/cu

collar

BHA between 125a and Fig

The welibore

lbm/ft

Air

in

of the

weight

Determine

mud

9-lbm/gal

Solution

ponent

BHAs

pendulum

angle

8.26

Example

Solution

Weight

the

of tangency

point

to

side

and

slick

the length of the

ibm/gal

of

for

8.93 where

8.7.2

WOB

the

can

factor

LT

ft

Length

Load

fluid-filled

buoyancy

the

by

Axial

p-W

Bc

whose

Tangency

LT

component may

the

Wb

is

reduced

is

Eq

has been

circular

component

weight

and

actual

shape

than

ma

they have

componentssuch

component

cross-sectional

any

the

from

differ

outside

known

subs telemetry col

the

Another

Wb

this

up with elevators

BHA

driilpipe

deter

less

weigh

ends

picked

motors shock

vary with length

weight

be

are

length can

both

at

of other

weights

thick-walled

wear on

be

OD

be

collars

drill

example

for

if

toolsis more complex ometries

OD and

drill collars

the

if

rearners

lars jars

ID

weight

or

that

most round

round

429

area and length are

For

the

if

the

can

component

cross-sectional

11

CONTROL

DEVIATION

BHA

any

see Table

be determined

can

as

of

weight

the density

if

AND

DRILLING

shows

both

which

are

to

all

one active

parts

BHA

with

the

To determine must

assess

portion of the

of

the the

BHA be

point

and based on by Jiazhi20 method of Three Moment Equations

presented

21 the

and

negative

functions

of

WOB

the

positive

or applied

components load

axial

com

FB0.5WCBCLT

from

8.94

Pn0.5W.BLT

sin

cos

aFJLT

8.95i

430

APPLIED

Example 8.27 Load

Axial

BHA

slick

Determine

0-

for

building

for

negative

and

tant

side

have

force

of

ODs

An

mud

9.2-Ibm/gal

forces

for

0-

and

lbf and

525-lbf

in

8.75

is

BHA

the

525

the

start

Plot

the

resul

the

formation

steel

collars

weight

9.2

is

3.2

is

estimate of

WOB

will

and

26-in IDs Mud

and

initial

30000-lbf

side

components

diameter

Inclination

Solution

of

the

considering

drill bit

7.0-in

lbm/gal

force

side-force

positive

WOB

At what

formation

The

forces

resultant

30000- 50000- 70000-

10000-

WOB

and 80000-lbf

the

ENGINEERING

DRILLING

The

40

ft

made

is

of

weight

the

for

drill

case

the

collars

in

is

Direct

sqft

ir

_____7.02_2.1882

4144 8.126Slick

Fig

Note

of using

sis

and

Eq

with

8.95

radius

unknown

is

to

the

both

bit

X489

the

drill

the

bit

the

is

can

FB

lbm/gal

8.33

lbm/gal

/489

lbm/cu

axial

clear

x62.4

lbm/cu

ft

ft0.859

is

of

sides

positive

before

ft

lbm/cu

1489

force

side

lbf and the in. Because

and

negative

lbm/ftB

9.2

force

is

collars

ftB

lbm/cu

analy

side

lbf PB

force

in

sq

in

changed

BHA

building dropping

side

must be determined

it

load

axial

is

in

practice

indicate

the

load on of

in

equations

with

Jiazhi

by

mean

to

sign

sign

FB

or compressive ance

and

load

used

the present

positive

negative

In

axial

convention

sign

be consistent

to

without

Wl18

the

that

BHA

sq

be

WB

the

180.859

101.4

lbm/ft

cal

culated

The

clearance

of

in the

drill

collar

is

related

0.0729

t0.58.757.0in

by

12

fO.Sdbdd

of

the

the

bit

and

dd

is

x40 must

one

solution

initially

lbf0.510l.4

guess

the

ftcos

27977

3.2

LT If the guess agrees with the length cal Eq 8.97 Eq 8.95 can be used to calculate force for slick BHA with constant inclination collars

of

lbf

tan 40

27977

by

drill

lbf/ft

diameter

the

length

side

and

of

collars

drill

culated the

diameter

the

is

For Jiazhis gency

8.96

P30000

where db

ft

ftI

L4.18x

i09

lbf/sq

0.5

lbf

ft5.63x103

ft4

same diameter

the

0.69

24E1

LT4

WB

where Xis

3tan

8.97

0.69

sin

69 transcendental

function

related

by

Eq

8.98 and

uu 8.98

where

is

in

radians

and

is

given

LT 1244

by

l8x

l0

/p\5 u---\EI

49.2

8.99

mined

load on

the

collars

Pc

can

be

deter

by

PcPBO.5WCBCLT

tial

cos

the

49.2

40

LT

second

estimate and

8.100

LT

lbf/ftl24sin

calculated

estimate of

initial

l0

ft40.0729

ft

10.25

3.2

ft

Because compressive

ft5.63

lbf/sq

101.4

The

1.24

the

does

calculated

44.6

not agree

estimate of

ft

value

the

with

the

average

should

be

of

ini the

used

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

431

TABLE 8.18RESULTING SIDE FORCES AND TANGENCY LENGTH FOR VARIOUS WOB Formation

Weight

525

Force

Ibf

147

iterations

side

force

50.8

431

48.0

51

474

45.3

519

42.9

543

41.7

the

at

FB0.5l0l4

bit

found

is

lbf/cu

ft48

LT48.O

of as

ftsin

nations

ft

.4

ft/48

BHA

solutions the

3.2

must

ing of

the

indicates

sign

of formation

lbf

with

525-lbf

net dropping

forces

and

formation

421.2

with

tendency

forces

of build tendency

lbf

force

high of 18

for

calculations

other

the

8.127

Fig

bending

or

ponents

also

is

are

BHA 525-lbf

The build

of or

hold

When

side-force

the

or

tilted

what of

the

like

the

mation

mum

is

Just

the

are

so

force in

will

is

lbf at

are

525

what weight

the

lbf

offset

technique

com

of most

by

the

lbf

BHA reached

is

WOB

until

which

the

are

collars side

generates lbf

at

WOB

formation angle an

to

forces

mat

no

equilibrium

formation

force

force

side

negative

7-in

to build

bit

the at

lbf

If the

going

is

on

stabilizers

which

147

of

no

calculation

wellbore

used

is

BHA

slick

low

80000

slick

angle

influenced

the

by

tool

of

rates

at

the

example

previous

the

no

WOB

assume

gle

For

which

slick

BHA

estimate

cease

will

the

in

building

an

Solution

Assuming

not change

calculated

the

length

will

tangency

substantially

5250.5101.4

lbf/ft48

ftsin

will

bit

inclination

12.46

Because canted

is

some

inclination

The

and

to

that

magnitude of

strength

will

be

the

sub

bent

clination

positive

would

this

the

Example 8.28

600

for

the

which

for it

is

drilling can

be

cases

many

especially

was

BHA

with

again

it

maxi

not obtain

the

designed

in

harder

bit

tilt

and

rates

the

the

when

the

ft/hr mechanism of

effects

BHA

stiffer

larger

In

100

predominant

mitigate

true

given

exceeding

200

the

from

formations 10

to

100

To determine

curvature

of both

Analytical

BHA

cumbersome

soft

are

ft/hr

collars

the

bit

the wellbore solutions to

of

and

such

use with

tilt

the

as

the

the

bit

drilling tilt

can

one must know

BHA

Jiazhis

varying

III. 1oce

Negative

200

medium-hard

to

effects

FOaCe

BeOdB

bit

run

significant

and

on

to

medium-hard

near the bit

and

weights

of the bit

and

build

moder

bit

component

direction

direction

housing

formations

soft

When rates

behavior

400

This

tilt

to

this

example

drilling

soft

is

BHA

deflection

as

curvature

side

and

i.e

and

the

low

Essentially

not the only

resultant

directly

formations very

of

bent

the

tilt

the

strong understand

nearly

slight

based

is

for

force

start

very

com

force

that

foregoing

angle

formation is

side

would be

there

the

force

inclination

some

in

of

for

The

force

appears

to

the

in

formations

the

curvature

at

bit

drop

tendency

influence of

the

side

hard

for

case

10 ft/hr

It

formation

force

even

to

zero or negative the

0-lbf

formation

tendency to

suit

better

effects

8.18

8.28

Example

negative

would be required

tendency

building

Table

in

formation

WOB

vs

with

of

results

525-lbf

force and

plotted

WOB

for

and

side

positive

80000-lbf

ate

of the

plot

force

particular

and

found

results

are

WOBs

formation

O-lbf

the

yield

8.75-in

from

ter

is

Similar

an

in

the

example

previous

ranging

inclination

of

case

special

In

are used

The negative

finite-element

with Jiazhis

2D

ideal

of

curvature

the the

dynamic

mechanics the

to

insight

of

BHAs

used

lbf

BHA

basic

the

one

tilt

However

be considered

give an

mon

ft

bit

or similar algorithms 2021 To be truly accurate

In the

93.8

describe

ed

ftcos

calculate

to

3.2

will

x0.0729

and

directions

To

the

ft48

lbf/cu

and

BHA

follows

BHA f30000 lbf0.5101

51.9

392

18

value

the

yield

ft

378

133

30000 50000 70000 80000

The

Ibf

94

10000

Successive

LT

F5

lbf _____________

lbf ____________

Force

Formation

F5

Bit

on

are

10

the

near

be the

bit

30

20

Weight

40

on

Bit

50

60

70

10005

difficult

wellbore

inch-

Fig 8.127Results

of

BHA

calculation

for

slick

BHA

80

APPLIED

432

desired

is

strong

hole

-OD

collars

7-in

the

An

use

that

collars

8.29

3.2

to

so

assuming wellbore

tolerable

formation

Tangency

used

OD

maximum 525-lbf

the

be

collar

for

971-in.-diameter

and

offset

the

and

larger

can

be

welibore

they can

as

large

with

angle

8.75-in.-OD

in the

drill

diameters

Estimate

mud

inclination

lbf

as

to

is

larger

collar

2%6-in.-ID 9.2-Ibm/gal

are

alternative

with

Example

of

of 525

force

safe

low

maintain

to

formation

ENGINEERING

DRILLING

inclination

force

Solution

/sqft\

ir

525

lbf

Jde22.8l252sq

4144 x48

de9.67

in.-OD

collars

would be

could

but

size

cannot

increase of

be

be

the

is

one

the

hole

If the

With

point

farther

use

the

the

up

obtained

stabilizer

pen

control

to

to

is

possibility

BHA be

can

has

that

the

L1

BHA

Single-Stabilizer

to

applied

with

other

well-

97/8-in

wellbore

the tangency force

for

large

length

The same type of Again

of

length

more negative

tangency

too

14-in

the only

move

to

collars

12

enlarged

dulum assembly

be

in

tangency

stabilizer

welibore

8.7.3

used

3.2

ft0.859sin

in.95

The 9.5-in bore

Ibm/cu

ft489

in

\sqin./

one the

must

estimate

calculated

for

performed

analysis

BHA

single-stabilizer

tangency

LT2

length

in

BHA

slick

see

that

length

The unknown

agrees

8.101

Eq

LT4_2e2e1j_4mlLT_ q2x2

can

8.128

Fig

8.101

q2x2

moment

bending

from

calculated

is

the

FB

relationship

L2J

2intV1j/2j--

q1L12

q2L23J1

Ll

4L1i Fig

6Ei1f1

6E11f1

8.102 L12

WiB

where of

weight and to

W2 the

The 8.103

L1L2

the the

is

point

weight

of

of

from the

the

collars

bit

sin

is

to

from

the the

the

stabilizers stabilizers

tangency

coefficients

and

W2B

sin

drill collars

W1 and

V1

can

be

calculated

from

Eqs

8.104

Wi_ 3F

11

sin2u

2u2

8.103

8.128Typical

single-stabilizer

BHA

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

and

Solution is

2u

2u

8.104

tan2u1j

40

that

for

or

from the

of

8.98

Eqs

bit to

Coefficients

the

and

8.99

stabilizer

and

from

the

the weight

We2r149.6

of

and

lbf

estimate

initial

shown

is

the

for

below

collars

L2

Note

mud

in

B0.839

are determined

u1

the

considering

and

the

calculation

stepwise

WiB

W.1

where

WOB

For 30000-lbf

The

ft

from

collars

stabilizer

to the

WiBl49.6

lbf0.839

125.5

lbf/ft

point

tangency

E4.176x109

lbf/sq

l9.55xlO3

ft4

ft

xi

/ft\ where

P1

0.5

PC\5 uj_ Eq

8.96

is

of

collar

d2

is

and

er

used

to

calculate

where d5 the

is

diameter

clearances

the

diameter

the

of

the

of

collars

for

each

the

stabiliz

that

achieve

in

12

l2.258.Oin.O

300000.5125.5 29691

tangency

-1-0.5125.5

The compressive with

Eq

8.103

ft40

lbf/cu

ft5

lbf/cu

ft

ftcos

l026900

lbf

ft\ load

for

the

first

section

calculated

is

and

29691

4.176x l0

PB

PcI

ft

ft5 ftcosl0

lbf/cu

and

O.5d d2

17708

lbf

P23OO0

fI0.5dbd

P2

ft

ft

P20.5k

El

section

0.00130

l2.25l2.2l875in

in

12

lbf/sq

0.5

lbf

ft9.55

l0

ft4

6.82x102 while by

the

load of

compressive

second

section

given

is

40

PB WiBL

Pc2

the

8.105

Eq

ft\

0.5Wc2BcL2cos 26900 8.105

If the

be

estimated

used

to

value

calculate

of the

L2

LT Eq

equals

side

force

at

8.106

can

5.20x

bit

the

PItI

EBO.5BWILI

L4.l76x1o

sin

8.106

x13

estimated value

LT

of

and

L2

the

new

LT

and

until

repeated

of

assigned the

same

does

L2

value

not agree should

calculation

be

with

the

value

an

average

of

procedure

should

be

ft9.55x103

x23

101

tan0.0682

0.0682 1.00185

tan0.5200.520 1.12117

0.520

L2Lr

W2

__________________

sin2x0.520 8.30

Example

Consider

building

BHA

the

stabilizer

first

l2% in

All

ID of

26 in

weight

10.5

is

Calculate

20000

the

case

is

5.0

drill

ft

and

collars

the

have

in The diameter of the

the

30000

of

inclination

angle

the

weilbore an the is

_______

1.142

20.520

single-stabilizer

which the distance between

on

the

12.21875

an

ft4

0.0682

L1 If the

lbf/sq

0.5

lbf

OD

of

8.0

stabilizer

10

bit

and

diameter

and

is

in and blade

the

_____________

V1

20.0682 20.0682

tan2X0.0682

is

mud

1.00124

lbm/gal bit

side

forces

40000

and

FB

for

50000

WOBs lbf

of

10000

______________

20.520 20.520

__________

tan2x0.520

1.08025

434

APPLIED

and

OF BIT SIDE VARIOUS WOBS

FOR

125.5

sin 1002l.8

lbf/ft

lbf/ft

40l.08025

1.00124

21.8

lbf/ft5

Tangency

Length

FORCES

Moment

Bending

L1

bit

Ibf

Ibf

tt

10000

3.030

669

15410

Therefore

2m1

on

Force

Side

Bit

Weight

ENGINEERING

8.19SUMMARY

TABLE

q1

DRILLING

tt.Ibt

20000

3044

66.2

15466

30000

3058

65.5

15522

40000

3.072

64.9

15579

50000

3086

64.2

15638

ft2

______

21.8

lbf-ft40

ft3

nique

used

culate

the

between

1.12117

45

The

Example 8.31 however

in

the

63.987x iO

in.0.00130

lbf-sq

This

ft

is

ft2

As

force

between

30

i07

in.0.001300

lbf/sq

17708

35

and decreases

to

achieve

ft-lbf

in.0

Ibf-sq

0.00130

17708

LT 21.8

414318

Ii

and

85

ft

lbf/ftl.12l17

loads of

10000

The

ft

L2

not equal

52.75

should

ft

be

used

the

next try

FB

show

will

LTL2 65.5

that

and

ft

ft5 ftsin

lbf/sq

lbf0.00130

Table

8.19

as

L3

BHA

case

the

and

of

must be

to

occurs

55

tan

and

the

indicate

between

60000

collars

drill

stabiliz this

calculate

can

force occurs

L1

be

also

can 8.131

depicts

and

L2

lbf

the

75

For

the

maximum

80

for

ft

bit

The

the

the

point

estimated

with

typical

two-

and

lengths

between

distance

L3

of tangency

is

and

slick

solved

known

are

first stabilizer

stabilizers

stabilizer

in the

the

lbf

Fig

and

second

and

the

between

unknown

single-stabilizer

solu

initially

10

15552

ft

5ft

3058

second

and tions

that

29691

and

first

bit

The

pendulum

predict

tangency

between

BHAs

building

becomes

value

BHAs

technique

the

and

60000

to

two-stabilizer

stabilizer

tries

that

10000

occurs

bit

cannot

algorithms

Two-Stabilizer

between

Successive

the

Jiazhi

wellbores

force

side

Jiazhis20

the

between by

loads of

bit

negative

8.7.4

Therefore

does

for

stabilizer

force

called

is

bit

The maximum pendulum or nega at the point where the drill

BHA

smaller-diameter

lhf/ftl.121

ft/lbfLr2l.l42

21.8

assembly

maximum pendulum force when maximum negative side that the

lO

243.987

If the

side

the

reached

is

solution

Other

cah

achieved

is

maximum negative

tangency

BHA

force

BHA bit

from

away

side

the

11

negative

force

bit

neutral

30

side

gency

m14318

called

beyond

assembly

bit

0-lbf

ft

to

tangency

or positive

building

moved

is

be used

where

occurs

causes

stabilizer

tive

er The

in

bit

or dropping

collars

L2

stabilizer

the

is

positioned

ft40 Therefore

for

the

and

single-stabilizer

Because

can

point

and

the

assembly

negative

LT4r65.45

the

near

bit

stabilizer

to

up

ft side

63.987

data

same

511

lbf .0

summarizes

the

solutions

to

according

bit

weight This

solution

20000 lbf

lbf

and

reduces

to

the

60000

8.130

BHA

is

the

for

similar

that bit

side

tangency

bit

stabilizer

lbf

code2

the

shows

8.129

Fig

tance of

indicates

increases

the plot

was used

side

from

BHA for to

the

additional

from

force

from

length

force the

bit

cited

6/z-in

as for

in

65.5

to to

function

WOBs

of

these

of

3086

64.2

of

ft

dis

80

Distance

The

From

Bit

To

Fig

finite-element

plots

70

90

10000

Example 8.31

collars

generate

WOB

3058

tech-

Fig

8.129Side 8-in

force

vs

collars

pendulum 101/2-Ibm/gal

Stabilizer

collar

length

mud 10

It

12-in

hole

inclination

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

435

Tangency

U-

80 Distance

8.130Side

Fig

Three be is

in

the

and

mined As and

f2

bit

8.96

the wellbore

given

Once

force

side the

and

can

inclination

types can

tangency

M2

can

length

be

deter

calculated

between

clearance the

be

100

material

correct and

ft

12-in hole

length

mud

diameters and

two moments M1

the

Eq

in

collar

Stabilizer

collar

10-Ibm/gal

solution

the

obtained

to

Bit

pendulum

collars

different

used

vs

force

6-in

From

90

the

stabilizers

and the welibore

last collar

are

L2

by

O.5d DS2

and

DC3

O.5db Eq

107

can

be

used

FB0.5WBLl

to

the

calculate

P1f1/L1

sin

bit

side

force

m1/L1 8.107

Everything

mine

mated L3 value used

is

m2 of

known

value agrees

m2

in the

can

L3

with be

Eq

in

of

LT

used

bit-side-force

8.108

except

m2

must be estimated in in

Eq Eq

8.108 8.108

the

and

To deter If

the

esti

equivalent

m1

can

be

calculations

4m2L32W3 8.108 q3X3

and

qWB where

11

sin

or

q3X3

Fig

8.131Typical

two-stabilizer

BHA

APPLIED

436

The given

for

relationships

8.109

Eqs

by

the

V1

moments

-oo

are

m2W2 LI2 L211

---V2 LI2

q2L2

q1L1

second

8.110

and

L2Il

2m1

and

first

ENGINEERING

DRILLING

-500

6EI1f1

xI

u.

X2

4L12

L12

e2

6E11f1

8.109 L12 700 20

1000

Bit

60

lb

L212 8.132Effect

adding

of

lars

x2-

on

Weight

Fig

q2L22

50

L3I2

v2

2tfl2

12-in

stabilizer

mud

9-Ibm/gal

100

hole

col

8-in

inclination

q3L33I2 x3

4LI 6E1f3

60-ft

8.110

and

8.1

be

can

from

calculated

04 where

Eqs 8.98 8.103

or

Also

can

be

For

the

five

that

Wi U1

for

applies

Ls1n2u

P2

Lr

length

1.57

u2

no

is

tan2u

and

When at

the

BHA

This

occurs

analysis

and

no

bit

the

and

bit

cases

and

first

the

the the

collars

cos

c5

8.111

tral

tained 0.5

Wc2 L2 Icos

In

this

Even

0.5

w3L3

in

W2 BcL2

with

basic

lcos

8.113

the

is

for

W013

or between

can

reach

must be result

and

component

and

If

the

solution

no

blade

technique

the

static

point-contact

two does

neu is

lengths

in

be

tangency

or between

2D

hole

tangency

wellbore

length

that

which

stabilizer the

only

tangency

assumed

those

all

and

and

diameters

hand

stabilizer

calculators

and

the

can

manner

the

restrictions

into

insights

certain

collar ble

is

analytical

it

configurations

BL1

there

where

length

ob are

stabilizers

used

vide

and

below

and

ignored

112

PB

two-

Pci

not allow

usually

side-force

directional is

point

are

P3

The

and

in

stabilizer

first

This technique

not give

L1

tangency

1.57

u1

much

too

Adding

because

stabilizers

B1

P2O

does

handle

and

PB

final

the

tangency

Furthermore

gauge

solution

tween

the

stabilizers

constant

P2

and

at

1.57

technique

cannot

between

two

the

Wci BcL1

and

u3l.S7andp310 curvature

PB

as

The same

Ui 1.57

and

final

long

as

u21.57

when u3

This

when

except

solution

only

the

at

except

When

and

1.57

u2

has no

except

where

Pi

with

P1

and

valid

is

stabilizer

Pc2

solution

expanded those

compression

in

is

no solution

where

BHA

stabilizer

of

algorithms be

can

including

technique

no solution

is

in-

effect

two-stabilizer

foregoing

1.57

I3HA

single is

there

and

2u1

the

there

the

no solution

is

when

the

2u1 PcI

2u

of

part

and the

by Jiazhi2

there

Lr

solution

the

lower

the

the

stabilizers

BHA

slick

length

two-

the

stabilizer

reducing

BHAs

multistabilizer

tangency

by

with

proposed

Ui

means

force

analyzed

four and

three

vs

The second

single-stabilizer

scheme

the

handle

to

the

slick

I3HAs

single-stabilizer

inclination

force

bending

positive

The V1

10

at

side

negative

for

solution

pendulum assembly

the

creases

and

the

pendulum assembly

stabilizer

the

shows

8.132

Fig

f2

6E12f1

for

mechanics

help explain different

applied can

multistabilizer

pro

BHA

BHAs

why

hole sizes

WOB

be used

can

number of

technique

of

to

Certain

solve

the

problems

behave

inclinations

programma slick

single-

DIRECTIONAL

8.7.5

BHAs

has been

by Walker22

and

inclination

bination these

and

3D

one- and

Other

two-stabilizer

techniques

and

BHA

developed solve the

Apostal2

case

Both

side-force

techniques

components

variable

curvature

437

Analysis slick

by Millheim

direction

weilbore

also

and

com

holds

gauge

yield

They

BHA components Unlike the analytical solution more generalized solutions can handle situations in

which

tangency

between

the

creases

WOB

in

between

occurs

stabilizers

force

the

well

as

creation

the

and

bit

the cases

as

of

stabilizer

or

which

in

in

additional

points

tangency 133A

Fig which

in

of

8.13313

shows

which

the

the

Fig Hole

curvature

force case

also

for

build

the

bore

the

may

vature can

also

ream out

bit

the

that

is

pendulum

yond

the

bore can

sub

drill

with

this

is

can

run

force can

the

affect

is

BHA

the

the

3.343

Fig

8.133BTangency ng

in

Example 8.31

bit

521

8t/2

But

814

lb

Bit

lb

between 100

assembly

and

bit

stabilizer

inclination

90-ft

build

WOB

30000-Ibf

when

angle

build angle

that

is

of

the

the

7Oft

be

well-

stronger

than

8.114 and

C2 deg/ft 100

degrees/

is

the

resultant

ft

S.F

BHA

97/8

effect

curvature

response

lb

BHA

the

reduce to

effect

where C1 deg/lbf-ft

force

j.J

Bit

587

curvatures

as

The curvature

side-force

side

Bit

lb

has been

C2l00 bit

143/4

and

greater

just

contribute

bit-tilt

l2l/4

by

usually

pendulum

point of equilibrium to

with

angle Even to

adequate

cause

in

Cur

more than

is

reduce

the well-

back

bounce

to

the

torque

original

example

hole

in

side

effects

good

has

cur

caused

harder formations

called

that

housing

trajectory

significantly

As

especially

formation

When

reverses

of

responds

increased

the

WOB

30000-Ibf

the

the

of

BHA

bent

or

ahead

usually

bottom

response

The harder

forces

side

curvature

the

later

curvature

sembly

the

bent

mud motor in

wellbore

Hole the

to

hole

hole curvature

soft

hole

the

used

the

is

with

with

changed

of

BHA

inclination

from

hole

97/8-in

speed

was designed

it

resulting

8.135 of

or the

which

for

of hole curvature

effects

is

that

accelerate

BHA

causes the

WOB

consequences

the

collars

stabilizer

inclination

also set

constant

Fig

various

63/4-in

and

bit

and

length

inclina

configuration

reach

to

stop rotation to

formation

mud motor

that

that

120

hole condition

section

BHAs

building

the

of

cause

may not be able bit

see

pendulum

affects

given

essentially

in

BHA

by

manner counter

If

run

is

hole can

the

BHA

and

remain

between

8.133ATangency

BHA

of

shown

is

Fig

WOB

the

to

for

equilibrium

constant

is

BHA

created

vature of

ft

12

in

stabilizers

curvature

of

inclination

BHA

response

0/100

inclination

conditions

Whenever not been

of

rate

two

geology penetration rate

curvature

average

the

Fig

angle

increasing

how

shows

cases

stabilizer

building the

of

the

inclination

90-ft

influence

reach

to

try

configuration as

long

new

can

8.134

and

bit

between

effect

Fig

conditionsi.e

BHA

the

of constant

BHAs

and

length

occurs

pendulum

the

two-stabilizer

significantly bit side

two-stabilizer

between

pendulum

shows

tion

the

occurs

tangency

133C

Ail

shows

tangency

because

to

the

presented

three-dimensional

handle

for

technique

CONTROL

DEVIATION

BHA

Multistabilizer

solution

of

AND

DRILLING

of

Determine the

162

lbf

where

0.000l/bf-ft

is

tilt

and

20000 resultant

and

hole curvature

bit

angle

side-force

the the

is

bit

tilt

by

lb

WOE

S.F

30000

962 lb

SF

lb

WOB

40.000

1.002 lb

lb

WOB

bit

side-cutting

caused

0.025/ft

for

855 lb

the

Fig

8.133CTangency hole length

6-in

resulting collars

from

10

increasing

inclination

WOB 70-ft

81/2ifl

tangency

APPLIED

438

ENGINEERING

DRILLING

Solution

162

0.88IlOO

BHAs

8.7.6

8.136

Fig

600

to

solved

9-in

and

WOB

for

effect

on

bit

30000-lbf

side

force

WOB 14

121/4-In

constant

clination

in

achieved

12345

as

with

This

relative

to

of

ence

much

In harder

of

when

for

rocks

the

The

some

Response

ered holding

the

regain

8.135Data

showing

constant

inclination

8-in

complete

almost

with an

unaffected

used

depending

on

is

and In

how

the

stabilizers

walled

lars

possible

the

to

off the wellbore

as

As

the

building

30-

be 30-

These

the

the

for are to

BHA in

Fig

assembly is in soft

drill collars

for and

objective

Thick-

drill

collars

regular that

50-ft

mid-stabilizer

BHA

especially

replaces

to

used

No

middle

given

in

consid

the

Similarly

fewest

50-ft

assemblies

are generally

the

to

BHAs

dropping

gauge

stabilizers

wall

all

moderate

even

in the

accomplish

for

of

could

weight

drillpipe

need

from

diameter

medium-building

use

75-ft

geology in

the

to

drilling to

to

build

slight

They

under

directional

or heavy

eliminating

to

to

is

of

that

BHA

8.137

from

tilt

larger

than

building

on

hold section

how much

practice

With

three-stabilizer

stabilizer

responsive

modern

mations

Fig

slight-

especially

less

The two-stabilizer

bit

build

achieve

can

usually

collar

function

in the

as

as

Rates of

response

of inclinations

undergauge

lbf

responsive

BHA

rates

assemblies

by

inclination

is

depends

the

collars

WOB

to

5000

used

are

general

see

of

BHAs

wellbores

intermediate55-

varies

range

is

8.136

the

assemblies

with

as

tilt

90-ft

generate

also

those

not

Gulf

most

than

less

assembly

of the

diameter and

increases

situations

BHAs

size

influ

the

common

the

that

assemblies

building

of of

force

side

in the

for

single-stabilizer

of build with

rate

be

rate

collar

sensitive

bit

by

collars

The

increases

assemblies

is

response

than

wellbore

inclination

Fig

drill

assemblies

clination

BHA

that

BHA

ft

changes

fairly

in.the

11

90-ft

30/100

to

bit

12-in

to

of

building

smaller to

building

ANGLE

are

ft

9-

less affected

is

more responsive

is

the side

can

ft

the

the

drilling

were very

90-ft

approaching

the

90-ft

Addition

greater

were used

in

to

the

and

2/l00

collars8

the

directional

drill collars

single-stabilizer

response

hole

the

assemblies

rocks

to

5Il00

the

by

the

more

generate to

smaller

The

tilt

of

sometimes responding

The

by

where

increases

not so

drill collars

building

of

were

by

assemblies size

bit

days

smaller

in softer

cases

tilt

6-in

to

Such

in

can

collar

on

diameter

the

earlier

Mexico

in

from

inclinations

from

building

caused

is

bit

In the

1400

these

increase

the

by

collars

angle

presented

generated

is

assembly

of build ranging

depending

build

for

side-force

drill

These

lbf

lower

at

building

Rates

WOB

8-in

inclination

algorithm

force

side

except

single-stabilizer

force

BHAs

the

19

BHA

building

30000

of

shows

for

of

finite-element

The most building its

collars

BHAs function

as

Angle used

commonly

Fig 8.137

building

with

Millheim

hole

the

Inclination

various

angle

A-in wellbore

12

8.134Curvature

for Building

presents

of

response

Fig

ft

inclination

building

/lbf ft 0.025/ftl00

Ibf0.000l

hold

the

drill

col

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

90 Highest

1522

30

Response

Building

439

30

30

Tendency

Negative

30 5_20i 30

30

30

12_i5

55.75

l-i

tbt

30

12-t5

55-5

1215

3050

To

Much

To

BHA

Holding

Achieve

Positive

On

Stabilzer

Undergauge

Tendency

Tendency

2I

As

Positive

From

Vary

Negative

Special Us

As

30

30 Can

Can Respond No Depending

30

30

8.138BRAs

Fig

for

holding

inclination

angle

30 Lowest

Be

Can

1tvI

Response Considered

Assembly

Drooping

the

inclinations At lower

inclinations

shows

8.137

Fig

with

changes more

side

BHA

this

that

the

at

level

of

responsive

building

BHAs

where

inclination

force

the most

is

for

tendency and generate

the

angles

higher

tendencies

side-force

8.136BRAs

Fig

for

building

inclination

BHAs

angle

placed the to

six

drill

WOB

and

dropping

shows

for

the

heavy

are to

drillpipe

the

have

of

too

drop

stabilizer

satisfy

the

control

BHA

is

holding

Using has no

most

BHAs

force

At lower

BI-IA

five-stabilizer

side

8.139

Fig

deviation of

with

the

building

slight

four-stabilizer

change

see

All

or

BHA the

as

in

holding to

BHA

BHA

the

Also

Figs

angle

variation

No

in

five

effect

on

how

At higher

angle the

near

side

positive

where

example that

normal

the

second

undergauge

BHA

actually

to

designed

build

the formation

opposing

rapid change way as to prevent Minimal bit tilt as well as stiffness helps maintain

also

bit

of

force

side

the

under-

tilt

bit

characteristic

in bit

for

are such

slightly

such

bit-

for

BHA

slight

an

the

the

holding function

as

inclination

BHA of

is

the

WOB

small

change

See Fig 8.140

inclina

inclinations effective

of

is

shows

inclination

of

required

Also

slight

inclination

drop

slight

more than added

is

torque

they have

collars

when

used

quickly

causes

in inclination

rather

angle

is

tendency

much

four-stabilizer

The holding

or hole conditions

geology

BHAs

Fig

too or

Fig 8.139

8.138

three

Angle

inclination

drop

either

The

least

for

Inclination

or

build

angle

neutrality

ever

the

edge

or

Holding

tendency

stabilizers the

enough

stabilizer

near-bit

the leading

last stabilizer

do not maintain

8.139

increases

tion

the

or

to

characteristics

they minimize 8.138

and

collars

bit

face

requirements

BHAs

Holding

has bit

blade Beyond

BHAs

8.7.7

from the

ft

stabilizer

the

BHA

building

to

8-in

function

as

stabilizer

or building

force typical

depicted second

gauge

in

three-

tendency

or dropping

add

can

the

so

used With

are

usually

negative

stabilizer

system

rotary

BHAs

fifth

Assembly ing or

in

or

stabilizer

is

the

eroding

is

near-bit

formation this

can

which

the

If

conditions

undergauge

8.138

Fig

tendency

dropping

of

iety

No

have

dependent stabilizer

around

BHA

can

build

either

the

on

and

bit

respond

var

becomes

similarly

the to

500

.2_P ___________________.______

.0 .0

31

51

U31

Cl

-300

ieee 20

30

8.137Side-force gle

for

response

building

as

BRAs

function referred

00

20

50

degrees

Inclination

Fig

40

Inclination

of to

inclination in

an

Fig 8.136

Fig

8.139Bit

side

angle

force for

tendency

holding

50

40

degrees

as

BHAs

function referred

to

of

inclination

in

Fig 8.138

60

APPLIED

ENGINEERING

DRILLING

440

rate

ate

under

200-

BHAs

8.7.8

8.142

Fig

LL

_0

100

-400

to

the

greatest

the

make

8.140Bit

side

40

30

On

force

as

Bit

50

exist

inclination

at

dropping

two

dropping

Table

between

shows

8.20

WOB

of

BHAs

for

holding

at

is

38.6

ft

the

the

from

90-ft

12-in

higher

in

and

As

the

collars

and

bit

tangency

BHA

pendulum the

for

points

For ex

inclinations

wellbore

the side

negative

with 8-in occurs

tangency

bit

the

second which the stabilizer As previously discussed increases the negative 30 ft from the first stabilizer

The dropping

force

side

near-bit

stabilizer

inclination

500

for

that in

100

the

the

in

and

sizes

The

achieves

more of

reduction

collar

at

except

wellbore

the

No

BHA Nos

more and

causing

shows

it

at

BHA

this

Angle

lb

collars

higher

moder

assemblies

stabilizers

response

increases with

bit

Inclination

approaches

it

hole sizes

ample

at

of

tendencies

the

common

with

where

at the

TO

conditions

drop

Dropping

BHA

stabilizer

various

1000

function

60

for

contact

first

will

indicates

presents

90-ft

those

conditions

inclination

force 20

Weight

Fig

75-

clinations

500 10

Fig 8.141

various

If

BHA

this

inclinations

100

BHA

pendulum

30-ft

stabilizer

used

for

angles like

used

BHA No drilling

and

with

assembly

when

Except

directional

control

ation

is

drop

the

undergauge

initiated

is

higher

at

type with an undergauge

for the

pendulum

BHAs

are used

They

in

are discussed

the

are

more

rarely

devi

for

on

section

that

subject

U-

500

TABLE

Tangency Inclination

Degrees

-1000 20

10

30

On

Weight

40

Bit

1000

60

50

30-ft

77/9-in

614

Pendulum 10

lb

Hole Collar

Assembly

30Oto5O

ftWOB

Point

8-in 21/4

30

POINTS

TANGENCY

8.20PENDULUM-ASSEMBLY

Hole Collar

to

50

to

50

to

50

to

30

to

50

1000

lbf

12-in

Hole Collar

8x2V4

300

50

to

20 40 Fig

8.141Effect

of

No

geology

on

hole

121/2-in

performance

of

mud

9-lbmfgal

Holding 8-in

BHA

60 80

collar 45-ft

Pendulum 10

20 40

Maximum

7590

60

BRA

80 75-90 60-ft

Pendulum 10

6075

30

20

60-75

40

80

3060 90-ft

Pendulum 10

-j

BHA

3O

30-75

UG

20 40 60 80

Fig

8.142BRAs

Assembly

18 18

600

60

3010 2030

3050 to

30

20

Oto5O

20

for

dropping

inclination

Assembly

30Oto5O

20

to

50

to

50

to

50

to

50

50

50

45 18

to

30

60

to

50

10

60

to

50

60

to

30

to to

50

Oto5O

2450

20Oto5O 2001050

30 20 20

50

to

to

50

20Oto5O

45 45 45

to

30

60

Dropping

18Oto5O 18Oto5O

2020

3060

Special

45 45 45 1830

30

Dropping

6-

Assembly

45Oto5O 45Oto5O 18Oto5O

to

50

Oto5O Oto5O

20 20

Oto5O Oto5O

40

to

10

3020

to

50

to

50

30 30

Oto5O

300 2010

OtoSO

20

to

24 24

OtoSO Oto5O

38.6

to

50

38.60

to

50

to

50

to

50

38.6 38.6

50

OtoSO

38.60 25.710

to

50

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

441

TABLE

8.21COMPARISON OF LOW RPM RESULTS BETWEEN STATIC BHA ALGORITHM WITH AN EQUIVALENT TORQUE AND FULL DYNAMIC SOLUTION

The bit

Side

Force

Side

Direction Solution

Speed

Rotary

50

Dynamic

quasi

100

Static

Dynamic

100

quasi

Dynamic

125

Static

Dynamic

125

quasi

Dynamic

and

Ibf

tain

bf 809 819 880 895 955 919

Dynamic

50

Static

Force

Inclination

1934 1934

orbital

decreases

see

rio

longer

approximates

full

3D

dysamic

the

143

followed

The each

by

increases or

speed

inertial

can

the

cause

in

inclination

side

to

and

energy of

component

force

with changes

change

slick

BHA

with

total

torque

The

bit

tricone that

the

collars

drill

motor

rotary

The

BHA

the

inclination

the

direction

to

this

rotate

is

system

forces

sidered ing

friction

be

to

125

tial

of

the

if

If the

be

can

Table

8.21

solution

and

full

50 100

and

50- and

to

gives

solution the

the

by static

than

rpm

100

quasi-

neglects iner

3D

dynamic

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as

The

for tricone

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at

two

solutions

the

left

NO 26

BIT

This

torque

100RPM

110RPM

120RPM

180RPM

turn

the

25

bit

24

left

self

can

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resultant

have

80.94/255.38

resolve

the

23

have

er

11

force

direction

35.19/115.38

tendencies the

Determining

BHA

ing

BHAs

10.55/34.61

1.02/23.08

Fig

side

forces

tion

of

stant

not

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stabilizer

WOB

increases

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bit

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the

side

friction

speed

Notice

and

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yielding

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build

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func

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to

bit

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been BIT

BIT

BIT

8.143Effect collars

of

rotation

after

on

Millheim

orbital

and

path

9-in

Apostal23

friction

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BIT

bit

Fig

it

hole

7-in

on

diameter

Bit-face

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torque

type

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is

left-direction

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on

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greater the tendency increased

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right-direction

con

friction

3.52/11.54

tendency

right-

8.146

building

assembly

can

forces

assembly

inclination

and

in this that

multistabilizer

slick

60-ft

for

building

side

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8.145

Fig

algorithm

Fig

for

for

as

easy

8.147

at the

forces

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as

see

assembly

be predicted

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will

could

it

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components

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and

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11.42/253.84

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left or dropping

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84.45/215.92

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with

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8.6

dynamic

reactive

are building

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single

Sec

for

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81.9S/28t46

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DISTANCE

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125

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Apostal23

error

rpm

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MrdMhfMbscMdcMds Rotation

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8.7.9

cer

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1825

1847 1497 1815

friction

side-cutting

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the

generates

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drill collars as

changes

Fig

orbit

of

load on

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friction

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torque

energy that

path

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and drillsthng

Solution

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APPLIED

442

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lb

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Left

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ENGINEERING

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Negative STABILIZER

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of

function

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Building

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8.147Inclination

Fig Bit

FRICTION

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rpm

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left

cy

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posite

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/.LB

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Fig 8.148

direction

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direction force of

friction

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Multistabilizer

tion

8.144Rotation

as

constant

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increases

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Fig

bit

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at

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ing two

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COEFFICIENT

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nitude Staivlizer

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01

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8.32

Example

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building

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Determine that

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1200

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of

direction

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ed

in this section

rules

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procedures

analytical

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strong negative stabilizer

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15

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Dependent Magnitude

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8.146Rotation

the

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or Right

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of

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the

have

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to

force

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/ecause

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Solution

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2000 1500 1000

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8.145Rotation

lbf

ft-lbf

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Direction

formation

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Fig

direction

SHA

causing

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the

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ing dropping and of

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be estimated

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inclination

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the

Accurate

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predictions

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DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

be

Ni

be

ISO

l00

as

THE

bit-force

BIT

AT

THE

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forces and

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all

varia

displacements

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hole curvature

torque

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configuration

type penetration rate hole shape and other factors Even the mud properties and hydraulics can affect the fi

BIT

LINES

nal

SOLID

make

drilling

of

10

.9

FRICTION

the

function

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and

of

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direction

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assembly

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bit

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overall

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of and

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controls

system

used

is

the

component

previous chapters

chapter

overall

how

and

trajectory

of

of each

in the

in this

of the

geology and other

subsystem

drilling

presented

understanding

bits

bit

presented

system

COEFFICIENT

an 8.l48lncljnation

directionaj

BHA BHA

of the

system An understanding

drilling the

of

total interplay

factors

STABILIZER

tendencies

trajectory

LIMOS

The

Fig

that

BHA

the

influencing

bit

ILINAd

__iiii

1.0

BROKEN

use of an algorithm

the bles

nIorio AT

443

about the

directional-drilling

engineering

constant Millheim

8.8

Control

Deviation

Apostal23 Directional

which tion

sucker-rod

failure

the

with of

departure

At

limits

and

within as

problems

when

caused

damage

were thought

tubing

to

some

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sucker

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limiting

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such

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deviation

for

first

specifically

or horizontal

predescribed

rubbed

was used

drilling

concerned

is

the

rods

greater

0.8

wellbore 200

of

the

the

from crossing

ado Bit

Face 191

1200

considered even

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inclination

the

control

reasons

the

the

severity

The

of

practice

drilling

inclinations

to limit

is

in

the

welibore

the

keeping

as

or remaining

lines

directional

though

sc6d

lease

boundaries

drainage

hP20

________

1000

such

for

angle

-600

0.4

experience of

use of deviation

principal

clination

-800

Later

magnitude

doglegs

The

0.6

400

inclinations

was not

cause

within

specific

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target

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departures

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might

small

dashed 0.2

20

40

60

On

Weight

89

Bit

1000

This

100

section for

practices

ations Fig

8.149Side lbf

and

force

17-in

bit

for

tilt

hole

geological

mud

10-Ibm/gal

force

of

200

inclination

in

to

26

al

deviation

than

hole are and

200

that

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quire

arid

trajectory

the

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for

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ii_

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Sde Bit

1000

Foce Td

WOB

dashed 0.2

20

40

60

Weight

On

80

Bit

1000

100

lbfin

lb

8.150Side

10-Ibm/gal

and

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mud

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hole

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Fig 8.149

inclination

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holes

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For an

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for

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of

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diameters provide

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the

8-

bit

Fig

forces

of

significantly

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Both

WOB

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the

bit

hole

in are used

12

same data with geological forces

forces and

drilling

100000

to

increase with

geological lar

to

reservoir drainage

problems

BHA

usually

angle

tion force

17/2-in If

WOB

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and

that

Deeper wells

the ft

from the larger size of the make the bit drill to necessary

ditions

501.9

100

factors

deeper

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planned

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12

gener

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diameter

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than

less

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control

Deviation

-800

to

wear and OA

in

multiple casing

intermediate

severity

wells

of the surface and

26 in

to

require

larger

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from

and

geologies

development

portions

ft

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wells

complex

situ

drilling

hole

large-diameter

Control for Drilling Wellbores

exploration

10000

08 200

deviation-control

typical

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Deviation

most

In 400

the

drilling

Large-Diameter 1.00

with

contending

controlling

8.8.1

Fig

present the

will

lb

The

four

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force

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side

150

and

bit side

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for

Collars with

200

11-

more

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lbf 12-in force

However

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col and even

APPLIED

444

12-in

the

____________

collars

build

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if

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86o 300

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some

until

Cl

________________ ______________

_____________________

04

_______________

_________

lum

In

lars

alternative

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the

inclination

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the

side

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ID

forces

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through -1200

0.2

pendulum

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20

40

60

Weight On

1000

BHA

8.1514Single-stabilizer

mud

the

hole

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and

homogeneous

_________

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varied

l52A

Figs

to

hard

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that

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30

that

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formation

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the

fairly

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is

strength

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the

significant

are

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the

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on

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forces

geological

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The pendulum

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large-diameter

lb

171/2in

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ft

ft

IC

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Deviation

100

offset

Fig

the

used

8.15

0.4

80

Bit

from

ft

______________________________________________

-1500

120

and

120

as

8.150

same cases

the

is

big

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the

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8.149

60 90

at

placed

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for

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by Figs

-900

as

pendu col

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l5lA through

Figs

bit

increase

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where be

can

lengths

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larger-diameter

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to

to

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angle

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common

0.6

300

enough

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0.8

The

ENJGINEERING

DRILLING

better

effects

usually

300

results

Fig 8.153 0.6

deviation-control

04

--

02

-600

If the

.__________

-oo

will

Oil

TiC

dashed

20

40

80

60

Weight

On

oo

Bit

8.151BSingle-stabilizer

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ration

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strong

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geology

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The use of hole

in

aspects

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that

In

the

the

-300

8.22

bles 0.2

_____

5066

20

40

60

Weight

On

Bit

80

1000

mud

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171/2-in

be

boxes

and

drag

BHAs

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difficult

Ihe

hole

10-Ibm/gal

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torques during

out of

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drilling

make breaking

Moreover

of

Ta

joints

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unstable wellbores

in tripping

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with

makeup

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100

lb

and 8.151CSingle-stabilizer

can

the

times

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true

larger

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If the

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of

virtues

formance Fig

some of

of excessive

multistabilizer 0.4

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the

be

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is

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surface

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at risk

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the

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06

Sde

configu

practices

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reduce bit

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ate

-900

the

break

drilling Stabilizers

deviation-control

large-diameter

especially

300

ci

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operating

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10-Ibm/gal

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---

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is

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geo

the

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600

the

drill

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rate

building

lb

171/2-in

for

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100

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Fig

bit

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12-in.-OD

11- and

some constant

at

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Figs

and

forces

9-

forces

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packed

build isoo

large

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the

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inclination

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-0.2

with

geological

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logical 1200

show

holes

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Ca--.--c--------

----

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in

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-300

the

presents

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BHAs

multistabilizer

pulled

that

The

undergauge into

the

hole

DIRECTIONAL

DRILLING

AND

CONTROL

DEVIATION

445

1.2

-30

15 300

Aj10.1A 0.I Co

300

O.6

30

30

600 0.4

Cl

-900 0.2

50 1200

30

I.-15 1500

0.2 20

40

ID

80

Weight

On

30

j_3o

lr1

Bit

1000

lb

18-in

Stabilizer

1/32-in Fig

BHA 17-in

8.l52ATwo..stabjljzer 50

hole

10-Ibm/gal

mud

Gauge

ft Stabilizer

and

inclination Collar

BHAs

8.153Packed

Fig

1.2

used

for

Length

Under

deviation

Pony

Length

control

1.C1_ 300

BHAs

Multistabjlizer

without -300

or

bit

This does

tilt

not -600

in

_z

900

-0

build

as

Usually

affect

slick

severe

dogleg

it

is

is

easier

to

with

packed

drilled

newly TOt

1500 20

sc ttU

the

the

place

curvature

BHA

than

the

as

poten

BHA

packed

into

casing

nearly

Also

with

less

will

Variation

BHA

BHA

force

BHA

packed

packed

much

bit side

section

of hole

pendulum or

slick

BHA 0.2 40

60

Weight

On

80

Bit

1000

The

lb

8.152BTwo-stabilizer

BHA

171/2in

hole

10-Ibm/gal

mud

BHA

selection

of

pends

on such

factors

phy

depth

100

of

constraints Fig

that

pendulum

or

1200 Svie

in the

constant

at

not

does

it

for

tial

will

it

does

lithology

much 0.2

angle

mean

not

0.6

WOB

use of extreme

the

permit

appreciable changes

incurring

hole

drilling-rig

8.8.2

and

on

are associated with

tions

that

with

cause

Such

to

deviation

stratigra

dogleg

be

severity

times those

all

or small

control

problems

medium-hard

to

and

conditions

where there

folding and

is

of

on deviation

large

forma

angles

dip

are usually

rang-

present

CA

300

risk

factors

Control

Deviation

interbedding

90

to

and

and

bearing are

de

wellbores

trip

Of

greatest

medium-soft

significant

from

ing

and rates

wellbores

Forces

forces

Geological

the

whether

Geological

0___O2.__1Q1___________ 300

forces

capabilities

have

effects

geological

3.2

larger

geological

inclination

inclination

control

drill

to

desired penetration

and

fishing

as

faulting

0.6

Fig 8.155 600

most of

depicts

wellbores

the

anticlinal

typical

trend toward

04

ture Cl

900

th

the

For dip angles bit

build angles

to

is

opposite tendency

02 20

40

60

Weight

Fig

8.l52CTwo-stabilizer inclination

On

Bit

80

1000

tOo

less

to

dip

more than about

the

bit

tends

reduced 45

750

and

lb

the

the

bit

dip

to

when

follow

the

of

beds

90

to

but

at

between

angles

strike

The

the

are 80

dip

struc

strike

formation

the

At formation

tends

the

tendency

the

to

beds

the

of

the

occurs

downdip

600 When rate

penetration

45

about

of

crest

perpendicular

drill

follow

to

than

where

structure

the

of

for

the

mation

BHA 17-in

hole

10-Ibm/gal

mud the

The magnitude of the dips amount of interbedding Another

strength direction tion

of

attack

156A

the

position

angle is

complication

vary with

an

of

the

depth

The

of

the

well

with

the

bit

example of

formation

the

dictate is

the that

on

the

dipping

typical

formation

dips and

variation

in

strike

dip

structure

is

of

dip func

and

formations

series

and

hardness

overall

the

Fig

geological

446

APPLIED

The

156B ments

has been

the

dip

and

severely

little

the

On

Weight

and

Bit

1000

the

Fig

BHA

8.154AThree-stabiljzer

mud

50

17-in

hole

10-Ibm/gal

inclination

Below

weilbore that

ability

to

drill

dipping

beds

the

tinue

build

angle

to

equilibrium bit side

arid

8.7.4

packed

4000

and

ture -0.1

change

balance

um

into

tend

all

to

drop

formations

On

Weight

Bit

1000

curvature

that

are

pendulum

angle

even

hole

10-Ibm/gal

mud

those of

to

sandstones

they

change

in direction

tion

BHAs

con

will

achieved the

This

resultant

discussed

Sec

in

curva

some

until

or

major

the

the

overlying

will

it

pendulum

are

remain

inclination

angle

usually

hard Any

and

inclina

an

if

being

slight

penetrat

whether unchanged is used Starting drop

BHA

or packed

will shale

much

slow

used For example

probably slick

the

sediments

be

harder formations

medi

sediments

overlying

will

of

BHAs

dips of

the

the

and

packed

limestones are

inclination

BHA

the

uniform

inclination

of

in

change

interbedded

and

more than

dip

when

occurs

ed

prob during

equilibrium

and

though

lb

171/2-Ifl

in the

is

an

fairly

slick

er and

regardless of

BHA

8.154B---Four-stabjljzer-

Fig

this

similar

are

The underlying

8000

on

shales

the

strength

-03

reach

trend

strong

between

will

continue

is

as

the

inclination

the

force

BHA

and

the

not change

pendulum

of

interface

occurs

Drilling 6000

If

will

great

pendulum

changes

Above

formation

the

are

dips

very

Tertiary

direction

equilibrium

on

depends

force

and

until

is

flat

the

there

direction

slick

there

direction

updip

interface

are

formations

slick

change

and

0-I

12

the

through

and

wellbore

sediments the

fairly

If

dip

will

strike

the

the

angle

the

on

in

highly

hard

may not be too drastic Once

0.3

.0

and

that

50

as

are

main structure

between

is

the

through

drilling direction

2000

the

shales

through

where

to

Triassic

the

unconformity

used

is

structure

high

sediments

very

the

more than likely

perpendicular

0.5

the

unconformity

the

also

of

tendency

BHA

borehole

of

are

as

dips

only

dip direc

westerly

and

Below

in direction

vary

or packed

lb

Jurassic

drilling

bit-building

formations er

the

shales

having

anticlinal

an

is

causing

sedi

Tertiary

surface

with

The Cretaceous

while

During

60

faulted

uniform

fairly

50

Fig

directions

dip

erosional to

ENGINEERING

medium-soft

is

unconformity

thrust

terbedded

dips and ft

an

dip of

eastern side

the

4000

over

regional

Below

tion

various

initial

deposited

slight

11

caused

that

events

DRILLING

mud motor

requires

0.5

8.8.3 6.n

Cola

Theoretical

Investigations

Pertaining

______________________ 0.3

Deviation

to

Control

2000

95 Ca

Lubinski

and

as

to

Woods24

defined

the

index

anisotropy

.0

way

o.i

bit

account

deviate

to

for

when

the

the

rock

properties

4000

Their

ly

6000

in steeply

tors

to

tried

0.3

Rollins25

0.5 20

40

60

80

On

Bit

1000

In

dipping

50

inclination

BHA 17-in

that will

bit

theory

in

variety

by and

Murphey

by

normal

fail

investiga

proposed

material

brittle

to

subjected

to

this failure

formations

hole

10-Ibm/gal

mud

downdip

who

deviation

ory

that

theory

is

Knapps

states

steeply

bit

the

bedding

leads

that

not

bit

theory does

dipping

in

soft

formation

consistent

theory

deviate

to

to

minia

with

Sultanov drilling

in

by

formation

will

deviate

field

and

see

Fig

not explain

beds

theory presented

drilling

hard

dipping

trast to

in

illustrates

suggests

secting

the

cause

miniature-whipstock

Fig 8.158

This

that

whipstocks

8.157 The 8.154CFjve-stabiIzer

researched

downdip

Other

of

cause

abrupt

lb

ture

Fig

further

forces

change

ISO

planes Weight

whipstock

explained

compressional

deviation

the

that

not explain

miniature

and

Cheatham26 0000

could

formations

dipping

postulate

ways The

of

_____________________________

however

theory

deviation

forces

geological

Knapp27 and

results

In

Shandalovs28 soft

inter

downdip

formation

con the and

-V

11111

UI

rr

000 000

005

eeOc eeoc

000

Ji

-- -rr

.c

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PJP4

aac.aa

000

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00

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00

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rnr.o

arrrU

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rorroroA

a0a -o

I-

-I

I1

I-

C-

448

APPLIED

TABLE

8.23MAKE-UP

TORQUE FOR

CONNECTION SIZE

BORE

TYPE

4-1/2

API

API

NC

IF

or

50

or

10098

HOLE

900 5-1/2

2-14

or

OPEN

22800

6.1/2

29500

API

COLLAR

213116

35500 38000

7.1/4

IOLE

35500 32500

7.1/4

SIZE

40

56

3000

26

500

32500

32500

40000

--9---

48000 40000 SlOoo

48.000

45

46000

46000

7-3/4

65/S

66015

API

7-1/2 7.3/4

----

000

57

65/S

HNO

NC

---

54000

72.002

.L 300 IF

.1/4

56000 66 000

8-I

rlpoq

83/4

74.000 74

.300

74.000 API

FULL

S.lt

0011

FOR LARGER

00s NOT SHOWN ADD

9-i/I

9I/i

PI

NC

70

9I/4

10%ASSTATED

9-hi

INNOTE2

13

NC

77

I6o.o.p

51000

N-NO

TI

CS. Not 7S/S

016015

API

.000

66000

63000

07000

63.000

7000C 7000W 70000

67000 67000 67000

670L

67000 18000 60.000 60.000 90003

7800. 91000 83030 AJ3J. 75070

88301

1CI3 0730

7-5/5

480

63000

9.99.

67000 71000

75000

75020

113000

138000

1.9Q2.

P909189

note

torque for

/2

PIN PIll

128000 178000

PIN

80000 7L000 79000 79000 79000

80

72000 65500

72000

53

000

53000 53003 .000

.000

112500 126500

99

090 PIN

00

so

00

7L000 74.900 74000 74000

PIll PIll

PIN

So 60

000

108000

I.29 129.000

123000

112500 128500

112.500

too

328500

S80

FACE

72000

93000

S7000

maximum

the

If

diameters

larger

112000 129000

92500 110000 128000

recommended

for

these

are

used

machine

face

tables torque

and If

ow

valuss

use torque

torque

the

faces

84

are

values not

in

con base

faces

91

.000

112500

II

is

torque

increased

133000 133000

60000 71000

34

100O soo

10-I/N

NOte

connections

low

SO So

I44i .%R0

60.6

66500

91

Notation

under

PIN

307000

53.000

r-50 1000

30-3/4

shown

low

PIN

80

iiio

6095

S.

with

PIN

90000

PIN

4--.9I/I 9I/i

H-SO

lace

PtN

90000

65000

To

111/4

nictions

50

000

53000

306000 123j00

39.000

II

full

PIN

j.9.4.2L

107000

SSS00 85000

112500 128500

90

diameter

500

PIN

TtT55

63.000

72

338000 923000

10-1/4

largest

75000

PIN

PtP

72000 55500 86000

9-6/4

5.

8-S/S

P14

jQ

95000 95000

9- 6/4

API

PIN

66500 66500 66500 66.500

86

ll

88000

10

S-S/I

PIN

72000 72000

107000 122000

PIN

000

76000 76000 76000

137000 172000

WITlil

67

PlO

I5000 00000

40

floE

516019

AOl

63.000

S-t/4

S.

7-S/S

PlO

63000

53000 63.000

iot

801

59000 59000 59000 59000

100000 100000 300000

LI

PIN

_9Q_

15000 68.000 101.000 105000 105000 135000

Pt

10I/N

0.90

.000

56000

60000 71000

6XNNW.IONS

80 P9

19

P19

.000

SE000

0Il

S.

PlO

PIN

90

990

or

49500 49500 49500

PIN

10I/I

SS/S

opo

61000

91/4 9I/i

P6661

API

PIN

61

0-90

85/S

IN

509

.000

65033

8I/i

lots

PIN

65

9I/I 9I/i Sb

.000

61000

-3

75/5

.000

42

40O0

68030 68000 68003 5600. 66001 70030

5300C 63.030 71.500

5-1/2

.000

42

53000

WITH

51/4

42

54000 64.033 CS0t15

10_I/2

LSNOS

P19

54000

/4

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lox pri

56000

10

.10-

IN

SO

500

17

107000 1071.0

10-I/I API

3000

8400

9.3/I

6-S/S

50000

IN

46Q00 47000 47000

.000

81/2

API

53000

000

8.1/I

SI/i

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73/4

61

000

I--C-pop

48000

7-I/O

lotS

API

o003

IN

32500 40500 n.cao 41

I0000 45.000 5.000

7-1/2

.000

26500 26500 26500

30.000 30.003

32000

49

7-1/4

MEMBER -i1

79

-T5--65--

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SNEAK

34

500

7.1/2

OPt

in

_______

500

j.0ii

or

Full

DRILL

_._._i2

Still-IF

51/2

OF

ft-lbf

22800

6-3/4

$T8EANtI9E

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6-1/4

2-12

COLLARS

DRILL

ENGINEERING

DRILLING

on

shown used

member

pin

this or

indicated

PIN

82000 82000

77000

PIN

77000

P19 50I

.000

300.000 itsooo 108000

PIN

98000

IOhSOO

PIN PIN

903500 332000

312000 129000

132000

800

92500 110000 128000

501

129000

92500 310000 128000 column

82000

92500 130000 126.000

indicates

from

shoulder

cross

on

500 500

section

boo

area is

fronl

3/4

smaller

on

the

DIRECTIONAL

DRILLING

AND

CONTROL

DEVIATION

449

was

panded

Bradley

formation

or

T2

At time

T3

time

from the updip The force to was derived

of crack

side

from

than

create

below

the

the

with

and

removed

side of

side

either

pul tooth

side

updip

downdip

the

on

chip

sin

to

formed and

is

more volume

with

for

brittle

formation

into

loose on

left

is

ex

later

imparted

immediately

is

breaks

chip

with

is

force

tensile

crater

T4

bits tooth

angle

zone

plastic

and

the

preferred chip summarizes McLamores

vertical

wedge

At time

dip verized

at

T1

with

wedge

called

is

of

interaction

mation At time gle

It

downdip devi

and

updip

McLamore30

by

Fig 8.159

theory

the

both

explain

proposed

initially

by

idea of

does

that

theory ation

tooth

the

McLarnore

by

2rpD

sin

cos

7r/2

41

8.116

41

cos2

where the

for

is

downdip

tion

the

is

structure

anticlinal

control

that

can

cause

deviation

problems

and

41

is

the

the

the is

tendency not

to

angle

considers

Cheatham29 tion

under

imply sistent

downdip with

deviation

field

theory the

in

updip Again

steeply

presented fracture

plastic

The conclusions

wedge

single

deviate

will

downdip

Another

half

of

41

internal

41

is

rp1

along

the

friction

equals

to is

plane

of

for

penetra

the bedding

relative

minus

rock

wedge

hole Pj

the

angle

and

wedge

the

angle

of

dip

the

of

the

the

41

bot

the shear of

failure

anisotropic

rock

formation

deviate

explained

equals

of

depth

wedge

anisotropic

The deviation hard

intersecting

the

the bottom

to

hole P2

the

strength of Fig 8.155Typical

is

the bedding

is

plus

side

updip

included

relative

dip angle

tom of

the

side

in

all

cases

This

dipping by Smith

having

the

is

the

can

force

chip

lesser

will

amount

be

calculated

form on of

the

fracture

by

Eq

side

of

8.117 the

as

wedge

force

and

work

their

too

that

rpD

forma

of of

beds

suming

COS

cos

8.117

FDEV ir/2

incon

cos2

observations

2O6Oft

Fig

8.156ATypical causes

cross

section

deviation

of

control

complex problems

geology

that

Fig

8.156BProlected information

dips

based

on

Well

and

geophysical

450

APPLIED

Vertcal

Fv MIniature

Force Force

Horizontal

FH

ENGINEERING

DRILLING

Whipstocks Fv DeviatIon

Causing

Threshold

__

Time11

Force

din Planes

TIME

Fv Time

Tensile

or

Pulverized

Fv

ChIp-__

Fig

Time

c7

8.157Miniaturewhjpstock

theory

after

Crack

_F

Zone

Plastic

T3

TIME

14

Rollins25

Forces

Reams

Bit

Down

The

Formation

Softer

8.159Preferred

Fig

the

In

be

stiff

0-lbf

WOB

shorter

theory

Knapp27

after

45

20 is

of 35

for

to

45

McLamores affects

the

the

greater

bed

to

implies force

tendency

the

to

for

bed

and

that

wedge

large

angles

the tendency

deviation force

30

theory

McLamore

wedge

30

with

downdip

the

between

by for

updip

for

deviation

the

that

dips of

force

that

more

being

calculated

shows

negative

is

shows

shifts

angle

gle

for

there

160b

tendency dip

and

deviation

30

were

160a

Fig

positive

dip Fig tion

Fig 8.160

8.115

more than

the

of

parts

dips

of

down angles

the

the

tooth-wedge the

an

wedge

wellbore

Sec

8.8.1

wellbores collars

using BI-IAs Drilling

12-in.requires be in

used is

if

the

subtracted

with

control 8-

to

for

6- to

from

the

10-in is

large-diameter

12-in-diameter

intermediate-sized

fishability

6-in

with

length of about

deviate and

locations

surface

natural

bottomhole

which

is

found

now

in

the

opti

that

the

toward

updip

The

pseudotarget

knowledge of from surface to

surface location certain

de

8.155

Fig way

drill

the formations

all

be going

to

to

to

cause while

used such

requires

target

of encountering

is

be

will

times

Many

depth

well

of

strikes

in

will

well

are

speeds

bit

location

the dips and

of

positioned

of the surface

positioning

total

rotary

of the

tendency

the depth

over

is

strategy

forces

dip

different

chosen

is

in

but

direction direction

This

Control

deviation

presented

wellbore

the formation

shows

the

General Deviation

maximum pendulum

used The correct

is

mum WOBs

expectation 8.8.4

motor

to

updip

drill

its

hole

used

be

have

maximum pendulum

how much

termine

the

The narrower

at

is

stiffness

is

displacement

transi

40

collar

most situations using low WOBs to control devia not economical turbine or positiveexcept when

tion

Eq

force

side

angle

maximum

the

ft In

Both

should

formation

the

lesser

80 ft while

would have

collars

the

formation

inclination

an

negative of

would

collars

of about

length

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pendulum

fan

to

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drill collars

forces are greater than

Because

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severe

to

from building

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case level

8-in

WOBs

low

the formation

with

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moderate

offset

keep

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to

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fishing

situations the smaller to

with

difficult

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drilling

enough

Even

forces

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many

not

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collar

largest

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with

after

Dip

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--

Fig 8.158Soft-to-hard

model

formation

chip

McLamore30

Down

-Causing

on

Acting

Wedge

the

holes77/8

collars Larger

not

wcllbore

concern diameter

collars

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drill to

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determine

usually

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drilling

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is

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undefined

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denictM

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ing

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flanks

Fi2

when

when

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is

Such

mis

of

new

geology great

domes

complex

X.156

structure

deal of fault and

structures

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DIRECTIONAL

The

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more applied WOB than would be drill collars As discussed previously of

magnitude

the

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causes casing

worn pipe key seats and production problems rods and tubing is Ac dogleg severity the same practices used in drilling cordingly directional failures

with

sucker

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it

minimize

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dogleg

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ation

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ected

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ured

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by

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8.160Chip direction McLamore30

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Cretaceous

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tory

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ing

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.700

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building

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10000

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8.24

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ture

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6000

Well

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the

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In

to

required

Table

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The formation

the

surface location

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29-lbm/ft

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well

156A You

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bottomhole

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geophysical

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surface location

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position

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information valley

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to

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rates

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ft

surface location

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therefore

To do this wants

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south of Well

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1400

33 Your company

Example

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in the

shows

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5000

of

of

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depth of

build

of angle

rate

at

0.3l00

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limestone

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0.2

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the

ft

continues

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The

ft

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Fig

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11800

given

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depth

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0.7/100

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0.6l0O

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optimum

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CONTROL

DEVIATION

the horizontal way to determine departure of from the bottomhole to the target surface lo

best

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AND

DRILLING

ft

the

APPLIED

452

EXAMPLE Hole

ON WELL

8.24OFFSET INFORMATION

TABLE

and

Sizes

Casing

FOR

8.33

ft

third

and

sic Hole

Size

Size

Casing

in

13%

17/2

in

12/4

in

9%

in

Surtace

in

4020 9290

in

to to

4020 9290

ft

Rate

12450

It

1800

Over

Formation

Geology 600

Dip

Tertiary

30

1800

Tertiary

20

Over

Inclination

ft/fir

Average

2801

Tertiary

to

3405

Tertiary

3405

to

4020

Top

would

4020

to

4558

Cretaceous

35

4558

to

5240

Cretaceous

33

5240 5800

to

Cretaceous

37

to

5800 6350

6350

to

7010

Cretaceous

can

the

three

be

7010

to

7500

to

8100

24

12.5

and

20

16.0

20 20 16 24 28 32

and

17

19.5

40

8.5

Jurassic

in

an

to

the

holding

horizontal

required

TVD

at

of

determine

and

approaches

optimal

5239

ft

and

designed

to

maximize

to

ft

could

tion

with

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results

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The

maintained

and 55

second

the

final

optimiza

achieve an

is

39.0

of

the

adjustable

could

of build probably

inclination

BHA

building

should

ft

stabilizer

rate

constant

the

type

slip-on

two-stabilizer

between 45

of

build

overall

an

If the

depth

constant

WOB

the

build

continuous total

to

maintain

achieved

spacing

desired

The

continue

Cretaceous

Cretaceous

the

Continuous Build

at

be

0.5/l00

50

and

ft

would

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BHA

20

10

of

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the

building ft

The measured depth

ft

13298

1The

Case 11/20

12

of

Interval

14

to

2801

ft

10280

of

achieve

will

examine

one

2/lOO

trajecto

The dips predicted At that departure

ft

little

very of

TVD

at

12450

is

us

which

cause rate

40.50

at

at

ft

Let

Interval

Depth

40.5

of

inclination

Average

to

build

departure

Penetration

600

would

clination

ft

11180

to

point

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Drilling_Results

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depth using

Depth in

base

the

8419

at

12896

is

build-and-hold

toward

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section

measured depth

the drill

to

kickoff

the

Triassic

that

at

in

is

possibility

ry assuming

Sizes

ft and

2540

is

departure

ENGINEERING

DRILLING

at

total

be

depth

Triassic

7500

Jurassic

is

Triassic

8100

8640

to

Jurassic

The

acceptable

for

this

plan

amount of extra casing

total

589

is

necessary

ft

and

15

23.0

44

and

12

27.0

47

Case 2Build-and-Hold

50

would

Triassic

8640

9290

to

Jurassic

9290

9805

to

28.0

and

Jurassic Trisssic

9805

to

10500

and

Jurassic

55

30.0

8.5

ft

start

final

to

measured

1147010

15.0

11800

55 50 50

33.0 35.0

7.0

37.0

12.0

is

Assemblies

Interval

to

the

ous-build

Quantity

4020

9.521

3.0-in

8.0-

12

23A6-in

x23Arin

6.55.0-in

4020

to

9290

121/4-in

ft

to

11800

8.0-

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12

6.5-

x2/-in

8.5-in

ft

36

Drill

Collars

Drill

Collars

Driltpipe

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Grade

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23g6-in

5.0-in

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third

It

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tained

Pump

Depth

on

It

1000

Bit

Ib

Rotary Speed

Pressure

psig

Pump

Mud

Rate

Weight lb/gal

80

3434

850

9.2

55

80

850

9.2

12

2900

70

75

3458 3433

850

9.2

12

12

3405 4020

70

70

3532

850

9.2

12

70

70

3456

850

9.2

12

4.558

55

70

3431

600

9.2

12

70 70 70

600

9.4

15

600

9.4

15

3491

600

9.4

15

3390 3443

between

second second

the

this

program 22.5

formation

the

hold section can

below

forces

the

Because

lies in the inclination

to

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and the

south

the

main

be

Jurassic

the

would have

would

require

strong tendency back

going

and

bit

drop

some type of building

to

motor run

making

possibly

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to

the

correct

to

direction

25

55

used with

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lead and

cp

600

55

could

spacing

Max

plan

build section

the

the

the

Viscosity

1800

5240 5800

BHA

constant

section

probably

Drillpipe

gal/mm

How for

continu

the

for this

over

Parameters

Weight

depth

Collars

assembly Measured

for

used

between

ft

30-ft

with

that

against

This Drilling

8539

and

measured

stabilizers

doubtful

is

Triassic Drill

15

to

Collars Collars

TVD

ft

the

suitable

maintained

with

The problem Drill

bit

65-

12

and

stabilizers

be

three-stabilizer

of

spacing

bit

30

5.0-in

9290

Grade

Collars

Drill

would be

could

To hold angle

bit

TVD

BHAs

case The

approach

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imum

Equipment

17-in

ft

8424

at ft

build

would continue

ft

continuous-build Bottomhote

22.5

of

At 12450

depth

The

ft

4039 and

ft

which requires 446 ft of extra casing inclination is 16.5 less than that final

12896

ever

0.5/l0O

at

ft

inclination

Triassic

1050010 11050 11050 to 11470

4039

at

at

Starting

Triassic

Case be

3Build

and

to

start

possible

build ing

2/lOO

at

BHA

spacing ing

is

Before

55

7040 7500

55

70

9.4

15

65

3393 3438

600

60

500

9.4

15

the

8.100

60

65

3.489

500

9.6

15

achieved

8640

60

65

3420

500

10280

9.6

9290

60

65

3550

600

9.6

18

stant

total

reached

terval

ft

18

9.805

35

75

3401

600

9.6

18

848

10500

40

70

3427

350

9.5

15

11500

40

70

3451

350

9.5

15

8-in

11470 11800

40

70

3471

350

9.5

15

35

70

3481

350

9.5

15

for It

ft

of

extra

holding approach

be

would

casing

much

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which

40.5 of

used that

in

the

might

to

70-ft

build

in

ft

required This

the

In

this

mostly

hard

inclinations

been

con

held

also

program

in the

maintain

have be

case in

the

calls

limestone

40.5

The main drawbacks

higher to

should

13298

but mostly

Case

lead

be

casing

easier

to

penetrated

is

should

of

build

Jurassic-Triassic

the

This angle

measured depth

with 8-in

hole

with 60-

single-stabilizer

of

of

TVD

might rate

strongly

if

harder limestone

the

long hold section

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bottom

the

and

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as

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two-stabilizer

ft

8419

at

Starting

8419 ft and to the 12-in hold

work

6350

is

in

ft

used

might

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Hold at

with

the

to this

would cause more

more time-consuming

trips

and

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

TABLE Measured

damage from key would need to be

8.25CALCULATED

Depth

Depth

TVD

North-

ft

fi

South

600

453

599.98

East-

Vertical

West

Section

It

0.00

5.24

5.24

1800

1799.69

0.00

31.41

31.41

31.4

1.50

0.0

2800.29

0.00

59.80

59.80

59.8

1.75

0.0

3405 4020

3403.97

0.00

2.00

0.0

4018.59

0.00

101.03

101.03

101.0

2.00

0.0

4558 5340 5800 6350 7010 7500 8100 8640 9290 9805 10500 11050 11470 11800

4555.59

0.00

133.97

133.87

133.9

5.00

0.6

5332.56

0.00

222.39

222.39

222.4

8.00

0.4

5789.60

0.00

274.47

274.47

274.5

5.00

0.7

6335.79

0.00

339.11

339.11

339.1

8.50

0.6

6984.73

0.00

459.39

459.39

459.4

12.50

0.6

7459.66

0.00

580.00

580.00

580.0

16.00

0.7

8031.09

0.00

762.92

762.92

762.9

19.50

0.6

8534.37

0.00

958.64

958.64

958.6

23.00

0.6

9123.47

0.00

1233.34

1233.34

1233.3

27.00

0.6

9580.28

0.00

1471.14

1471.14

1471.1

28.00

0.2

10188.14

0.00

1808.08

1808.08

1808.1

30.00

0.3

10657.09

0.00

209545

2095.45

2095.5

33.00

0.5

11005.29

0.00

2330.31

2330.31

2330.3

35.00

0.5

11272.26

0.00

2524.28

2524.28

2524.3

37.00

0.6

and

seats

stuck

drilled

in

The analyses

79.56

pipe and harder

the

that

79.56

footage

for

limestone

the

trolled

of

in

The build

risk

be

danger

that

and

the

seating

close

to

79.6

FNL

line

and

other problems

from responding

system etc

should

The foregoing

There

those

the

optimal

book

to

ways

engineering and

deductive

by

the

of

as as

drilling

the

drilling

ft and

6000

I-low-

bit

mud

the

direc are

presented and

can

bet

text

using

good

greatly

enhance

operations

Derive

off depth

8.2

Plan

face

Order

Dept

on

solutions and

8.19

for

r1

build-and-hold

location

Setected

is

at

of

rate

are

order

640-acre presented

SPE

31656

section

here

X3

directional

For

is

complete

780

2000

measured depth

TVDs

of

depths

at

8.5

whose

ft

from

solutions

contact

the

r2

necessary

r1

horizontal

ft

north Book

X4

of

to

path

r1

be

2/l00

for

vertical

How

well

for

If the

ft

to

How

end

with

long an

is

how much

the

tal

departure

at

7100

measured

TVD

is

Eq equa

the

and

depth

is

string

to

ft

will

you have

If the

be run and

shoe

to

what

should

purchase

10200

drilling

TVD is

hole

the

inclination to

of

target

Rate

ft

of drop

where

3100

is

2100

maximum

the hold section

needed

hold and

build

rate

10200

the

is

casing

casing

ft

kick-off depth

the

and

bottomhole

the

at

measured

relationships

departure

much

is

target

build and

and

program using which

TVD

casing

the

to

Also derive

the

the

include

reached

the

and

Use

ft

TVD

any

what

intermediate

ft

of ft

and

5500

is

8100

of

angle

X3

TVD

measured depth where the kick

build and

the

the

calculate

directional

relationships

any

bulls-eye

TVD

hold and drop

and

at

or

inclination

maximum required should be 2/l00 It

build

at

target

at

the

of

calls

build

to

trajectory

ft

6248.19

Your plan should

end

the

departure

Plan

and

sur

SPEs

the

tions

drop

to

the

3100 5100 7100 TVDs of 3100 5100

for

2474.94

and

and

8.21

ft

horizontal

depth

trajectory the

ft

departure

Derive

.6

and

4380

is

5636.19

are

TVD

any

ft and

maximum

following

for

well

at

of 20/100

build

1206

X3

r1

from the surface location

ft

It

measured

build-and-hold

reached

Eq

for

8.20

departure

Plan

inclination

build

respectively

Eq

horizontal

of

to

depar

of 5450 6000 TVDs of 5450

at

11255

depths

to calculate

necessary

returns

Exercises 8.1

ft

Derive

TVDs

Maximum

937.73

is

max

following

horizontal

end

is

ft

depth

measured depth

at

at

line

10500

is

Kick-off

target

TVD

at

measured

9141.22

8.3

the

Answer

ft

3402

are

respectively and

the

measured depth

departures

sound

in this

ft

and

south

the

target

measured depth

measured depth

and

to

FEL

line

from

the

to

build and

the

8600

and

26

possi

presented

principles

system

of

horizontal

few of

engineer

drilling

key-

well By applying

any

analyses

treating

logic

success

drill

end

building

no absolute way of drilling well However there

is

to the

east ft

1.5/lOO

be

and

build

8600

8.4

shales

the

and

also

the

of

ture

risks

are only

from

is

manner of

the

the

1250

is

FEL TVD

ft

of build should

end

the

motors

the

keep

selection

minimize

deduced

and

or deviation-control

drilling

the

careful

that

2000

and

from

ft

location

2450 ft Your plan should include imum inclination angle reached

used

instability

desired

in the

approaches be

can

Chap

tional

ter

and

planning

could

that

be

is

stabilize

hole

causing

in

shale

the

could

hole There not

of

necessary

through

liniestones

would

base

1000

and

whose bottomhole

is

reamers be

program

the

complete

would enlarge

bilities that

drill

stabilizers

harder

the

hole

ever good

in

in

mud program

the

would

continuous-build

the

needed

assembly

To

also

stabilizer

at the

roller

3-point

reamers

con

be

stabilizer

sandstone

or straight-bladed

in

might

would

require

These

limestones

spiral

second

the

with

build

could

from the lead

the abrasive

stabilizers

the hard

regular

of

be

always

forces

the

approach be used

cart

could

adjustment

that

attractive

formation

the

farther

would

Cretaceous

stead

the

or

to

most

indicate

assemblies

BHA

the

of

through

Drilling the

Because

by

easily

the

is

building

effects

closer

either

of these cases

program

WOB

angle

ing

ft

0.2

2801

two-stabilizer

optimal

01100

1.00

5.2

Rate

Simple

Dog-Leg

degree

It

FSL

continuous-build

Inclination

Departure

ft

mations Conclusion

OF WELL

TRAJECTORY

the

of

ft plan

8210

horizon

APPLIED

454

8.26COSTS

TABLE

FOR

Case Cost

Subsea

of

Per

Completion Cost

$75

DEVELOPMENT

FIELD

Case

Case

$7

$60

Million

Million

Well

$500

Offshore

of

Million

ENGINEERING

DRILLING

$15

Million

$280

Million

Million

Platform

Cost

Drillship

of

Jackup

Semi-

or

submersible Cost and

of

$35000/Day

$120000/Day

Semi-submersible

Jackup

Semi-submersible

$40000/Day

$30000/Day

$80000/Day

None

Can

or driliship Rig

Drilling

Support

Full

On

$80000/Day

Fixed

Special

Platform Considerations

of

because

considerations

needed

to

from surface

go

How

section

hold face

TVD

to

of

l/l00

Case

Water

Depth

1200

ft

Gulf

Water

Depth

120

ft

Pacific

Water

Depth

680

ft

Northern

work

has defined

any

drilling

voir

analysis

owns

ny

Sea

offshore

of

discovery

Derive

the

to

necessary

hold and drop

build

r2 X4

r1

and

rt

X3

measured depth

the

calculate

Eq

relationships

Also derive

the

and

equations horizontal

departure

9010

is

14100

ble

should

casing is

is

TVD gin

at

the

TVD How

of

all

of

build

and

kick-off

of

shoe

the

much

casing

is

and

required

to

if

ft

intermediate

the

how much casing

build

and

departure

should

What

the is

the end

from

the

of

surface

the

for

equations using to

relationships

Eqs

calculate

build 8.21

the

20

ft

depth

is

1500

ft

Rate

The desired horizontal

surface

location

maximum

at

inclination

TVD

of build and departure

is

9075 ft reached How of

drop

3100

is ft

2/l00

from

What much

Kick

is

casing

drop

8.26

under

an

seismic almost

being cannot

locate

shipping

lane Reser

the

structure

with

You

have

determine

to

drill

to

permission

from Blocks

lane

shipping

the four

Your compa

on the plot

Note

the

eco

best

This problem

the

is

study

to

will

the

be

subsea

drilling

and

and or

completions various

the

gives

econom

Wells

semisubmersible

use

for

determine

to

some

drill

to

conditions

set

plat

for

Cases

and

all

the

drill

wells

the

or

drill

the

to

wells

and

com

movable

with

You

them subsea

drill

wells and

vessel

drilling the

all

complete

discovery

must

do

following

Calculate surface

13%-in to

and

the

platform

some of

drill

movable

others with

vessel

to

platform

them subsea

plete

the

set

from set

cover

7-in

casing the

casing

surface

the

the

the casing casing to

cover

to the

overpressured to

total

location

depth

on

costs

3500 build

ft

Below

is

the

basis

TVD and

8500 the

well

well

section

interval

each

for

each

for

trajectory

cost

Size

Cost

in

$/ft

20

105.24

the

13%

74.58

the

9%

44.73

is

and

the

indicated

field

as

You

lane

Fig 8.162 summarizes the results well Determine whether you would

TVD

target

bottom

problems

to

wells

Calculate

departures

structure

within

approaches

Determine

hold drop and 8.22 Derive

anticlinal

this

part of

drop

to

the

are

build

made

drilling

later

horizon the

and

horizontal

in

the

the

be

of

rate

Further

Fig

assignment

develop

Table

drilling

drop

what

top and

the

8.161

the

your

whether

of

all

form

with

and

different

2O-in

measured depths and inclination angle 8.10 Plan modified where trajectory must intersected at constant inclination of off

is

maximum possi

the If

at

target

is

first

of

tar

the

the

2/lOO

is

drop

Where

the beginning

at

modified

the

top of

52

is

end

at the

depth

hold and drop

departure

the

measured depth

and

ft 14100 8.9 Write all

hold

to

what are the horizontal

casing

departure

tal

run

and

needed

TVD

hole drop

be

to

the

build

the horizontal the

rate

be

for

angle

and

ft

The

ft

What

which

for

trajectory

well using

directionaj

interval

has been

dictates

to

4i.e or

8.8 Plan

get

The ics

MD

ft

at

sur

from

producing

see

structure

outside

to

referred

8.7

8.10

the shipping

locations

It

nomics

8.22

the

Blocks

10

and

build-and-

the

discovery

lane

under

bottomhole

North

offshore

shipping

anywhere

8.161Plot

Fiq

Mexico

of

9420

departure

Problem

active

completely

Case

If the

and

of

needed

is

ft

An

8.12

case

end

the

casing

nay

the

8.11 Repeat of

9355

horizontal

the

and

to

much

9075 ft

between

logged

TVD of

year

environ

of

mental

is

None

only

drill

months

28.82

of

setting

intermediate 9%-in ft

of

casing

TVD the

and

casing

DIRECTIONAL

Using

the

time needed

to

inclination for

AND

DRILLING

information

700

is

each

drill

Table

in

well

455

8.27 determine

each

for

80

Case

for

CONTROL

DEVIATION

Case

for

Case

8.13 Replan

N25E

18

and

to offset

sary

should

be

18

of

lead

constant

until

constant

depth

8.14 Given termine

the

two

intersect

much

of

Radius

of

Horizontal

TVD Radius

of

Factor

Case

Time

to

Drill0.015

DM-42

Maximum

Inclination

Factor

Maximum

150

will

the

Plot

0.9

10-24

1.0

1.0

1.0

1.3

1.2

1.5

1.5

1.7

2.0

2.0

2.5

6O08O0

well de well

to

require

target

Sea

Unconsolidated

to estimate

walk

bit

3550

the

10900

8.28

to

the

to

total

account

walk

bit

Siltstones

100

to

ft/hr

for

Sandstones

the

60

8.29 determine

the

How

8.17

Derive

the

lead

you have

must

to hit

each

method Eqs 8.27

tangential

30

10130

10

to

method

gential

TVD

clude

Did the wellbore

coordinates

gle

The

See

the

target

Table

8.30

of

trajectory

presented

TVD

in

and

averaging

Answer

is

7800

for

the

Massive

Pay

60

through

to

Days

Problem

ft

Sandstone

Oil

Next

in

the

8.21

rived

How and

8.18

up

do

the

is

the

8.20

results

angle-averaging

to

much

10310

at

for

Problem the

Maximum

The

an

39

angle-

at total

Well

Discovery

Drill

the the

of the and

compare with those of methods

ft/hr

Case

84 days

Case

37

Discovery

well

the

days

110 days

Well

Each

in

Case

is

22

information

offshore are

using

Tables

TVD

the

is

ft

total

coor

angle the

8.25

2140 is

The

the

1.0 Cal and

determine

balanced

tangential

methods

from two wells

point

8.32

how

far

The survey

from

drilled the

apart

well-

data are found

surface location

of Well

Well

20

Determine

the

Determine

the

and

inclination

ft

sub causes

setting

the other

determine

closest

of

the

Is

data

survey

and

east

bent

Tool-face

de

method

The

the

8.31

motor from ft

with

platform

at their

due

well

the

comparable

8.23 Using an

method from

tangential

method hint assume data from Problem 8.18

of

trajectory

method

balanced

the

the survey

culate

in

the format

the

Derive

the

well using

minimum-curvature

for the

8.162Discovery

minimum-curvature

depth differ

the

departure

Inclination

Fig

bores

procedure

8.18

there

ft

calculate

the

the

data

is

the

It

100

ft

Top

l3E

of

difference

19.03

In

Water

The

ft

determine

method

Gas

ft.0.1

the

surveying

between

is

and

trajectory

in

the

coordinates

departures

data presented Problem

TVD

east/west

total

of

tangential in

method

Determine

in

How

step-by-step

and

In

600

direction

method

departure

the

target

departure of

With 120

Case

8.22

basis

departure

minimum-curvature

dinates

the

horizontal

tan

data

angle-averaging

on

the

radius at

the

using the

ft/hr

target

coordinates

and

TVD

survey

well

the

horizontal

north/south

intersect

east/west

with ft

well

the

departure

circle

method and

8.20 Set

survey

and

The difference

in

ence

in

total is

target

8.19 Using

of

trajectory

north/south

total

top of

the

Sandstones

Shales

ft

of

iop

ft/hr

and

8.29 8.18 Determine

Thin

ft/hr

Ptessured

Normally

Contact

much

10

ft

through

amount of

extra

to

right-

of bit walk for the trajecto you must buy because determined for Problem 12 Use radius you target ft

ft/hr

Shales and

Overpressured

Limestones

of 150

30

ft

by

casing ries

Shales and

determine

8.24

Eqs

angle-averaging

Table

ft/hr

ft

8.26 8.16 Using

60

to

ft

8450

8.15 Derive

ft/hr

ft

Table

lead

300

Tertiary

Shales

ft

target

Divide

amount of

the

and

ft

walk

hand

Sands

S7OE

100

in

Floor

ft

ft

4250

second

data

offset

amount of

total

two

the

Case

0.9

6220

Hint

Factor

0.9

24-48 48-60

of

Inclination

Case

0010o

ft

bulls-eye

target

Case

Inclination

is

because

drill

10400

departure

top of

to

Factor

Inclination

bulls-

target

offset

to

3570

target

target

Direction

Target

Maximum Maximum

Inclination

D-95

S75E

departure

of

D-9i

DriIl0.013

ft

an

following

bulls-eye

top of

to

DrillO.016

to

must you buy

casing

Horizontal

TVD

the

to

Time

ft 8.4 at 8085.27 Problem 8.13 at

10491

is

Time

for

ft

data from

with

the

needed

of lead necessary

Direction

Target

of

Problem

For

walk

right-hand

be

will

casing

trajectory

targets

How

of

10

of

8.12D

Case

N7E

of

PROBLEM

Case

neces

lead

direction

inclination

radius

is

amount

the

ments

50-ft

10423.16 ft measured depth

8085.27

The

an

rate

within

hit

amount of

the

FOR

of

direction

target

walk

bit

eye How much extra the bit walk Answer measured

as

expected

what

At

8.4 using

N25E

of

left

the

held

reached the

Problem

8.27DATA

TABLE

the

Maximum and 60

case

an

angle

of high side

right

new

change

inclination

N5W of

Answer

angle

to

2260

3.5/100

for

ft

N6.7E Problem

8.24 8.26

tangential

of

wellbore

at

8520

tool-face ft

for

setting

to

sidetrack

out

motor run of 220 ft The

456

APPLIED

TABLE 8.28OFFSET DATA

FOR

PROBLEM

DRILLING

8.14

Measured Dogleg Depth ft

Inclination

degrees

646

TVD Direction

ft

Vertical Section

1468

0.5

S6OW S61W S71W S6OW

1963 2429

0.25

S16E

1963

35.6

0.25

2429

34.8

2861

0.25

N45E N22W

2861

33.1

2958

34.3

3056 3154 3252 3320 3417 3514

37.8

955

1206

2959 3057 3155 3253 3322 3420 3518 3616 3714 3812 3910 4008 4157 4281

4404 4528 4649

2.25 4.75 6.75 7.25 8.5 10.5 12.5 14 15.5 17.5

20 20 20 19.75 19.25 19.5

4771

19.75

4891

20.75

5018 5193 5368

20.5 20.75 22.25

5461

22

5492 5592 5653 5718

21.5 20.5 21.5 21.25

5781

20

5874 5998

18 17

6181

17.25

6397 6614 6737 6835 6933

17.5

7031

14.5

7129 7227 7325 7423

13.5

18.75 18.25 17.5 15.75

12 10.5 8.75

7521

7619 7717 7815 7913 7966 8965 10605

6.25 4.75

3.25 2.5

S2OW S2OW S15W S2OW S17W S25W S25W S23W S22W S19W S20W 319W S21W S21W S22W S23W S24W S25W S27W S28W S3OW S31W S32W S31W S33W S33W S33W S34W S37W S35W S34W S38W S36W S39W S38W S37W S37W S36W S35W S37W S36W S37W S37W S38W S42W S43W S47W S8OW S65W

646

15.6

955

25.6

1206

29.4

1458

32.5

43.4 52.6 60.5 73.4 89.2

3610 3705 3800 3894 3987 4127 4243 4359 4476 4590 4705 4818 4937 5100 5263 5349 5378

379.3

5471

749.3

5528 5589 5648 5736 5854 6029 6235

771.1

1002.6

6441

1070.1

6558

1109.1

6651

1139.2

6745 6840 6935 7030 7125 7223 7320

1167.3

108.2 129.8 153.7 180.1 210.0 258.6 299.2 339.4

418.2 458.1 498.8 542.8 603.7 667.4 702.2 713.6

794.7 816.8 847.1 884.3 938.1

1192.8 1216.5 1238.1 1257.3 1273.6 1287.1

7418 7515 7613

1298.4

7711

1321.4

7763

1324.0

8761

1375.0

10398

1425.4

1307.8 1315.2

East-West

North-South

Coordinate

Coordinate

14.6 24.0 28.0 31.2 32.4 30.4 30.0 31.9 33.2 35.0 37.9 40.6 45.4 52.3 60.2 68.8 77.5 86.8 97.2 114.8 130.0 145.3 161.1 177.1 194.1 212.3 233.0 262.9 295.4 313.7 319.7 338.7 350.6 363.5 375.8 393.4 415.3 445.8 483.7 524.4 548.1 566.8 583.9 599.3 613.4 626.0 637.2 646.9 654.9 661.7 667.4 672.3 676.4 678.3 729.0 828.3

8.5

Severity

I100 0.0

13.8 15.5

0.65

17.0 20.0 20.5 18.6 18.7 22.1 27.8 37.2 45.1 57.7 72.3 90.2 110.9 134.3 160.5 190.2 238.1 277.7 316.6 354.9 391.7 429.0 466.3

0.20

0.06

0.10 0.09 0.06 2.23 0.23 2.57 2.10 0.89 1.69 2.04 2.08 1.54 1.72 2.06 2.57 0.46 0.0 0.34 0.48 0.33 0.33 1.01

506.0 559.9 615.1

0.33

645.0 654.8 685.2 703.5 723.4 741.9 766.5 796.7 841.1 893.3 947.2 978.2

0.48

0.42 0.88

1.98 1.23 1.63 0.34 2.06 2.39 0.94 0.20 0.56 0.64 0.87

1001.7 1024.0 1044.4 1063.4

0.82

1081.1

1.54

1096.5 1109.7 1120.5 1129.5 1137.0 1142.7 1147.3

1.58

0.76

1149.1

1.46

1174.4 1161.3

1.81 1.27 1.05

1.79 1.79

1.53 0.82 0.77

0.23 0.14

ft

ENGINEERING

DIRECTIONAL

TABLE

AND

DRILLING

WALK

8.29BIT

CONTROL

DEVIATION

DATA

FOR

PROBLEM

457

the

8.16

Depth

ft

Inclination

Case

degrees

Il00

TVD 3550

0-

6220

3550-

0.1

0-80

left

0.1 0.2

0-10 10-30

8450

0.1

left

left

0.10

left left

0.0

0.1

50-80

0.0

0.0

01

0-10

0.2 0.3 0.1

10-30 30-50 50-80

right right

1.0

right

1.4

left

8.40 Generate for

overall

be

to

sary

direction is

3.0/100

S3OE

the

original

can

be

obtained

below

4/100 length

setting

if applicable

right

tures

in

right

right

1.0

right

right

0.7

right

8.42

changing

The

8.28

inclination

Derive

dogleg

much

and

ft

tool-face

from SlOE

direction

original

before course

angle

change

8.45

DeriveEq

8.32

Derive

fast

right

to

25

without

tool-face

left

42

is

the

the motor

3.00/100

run

direction

the

low

should

be

the

reverse

for

What 250

ft

ty

The

to

the

dogleg

of course

make

to

ting

be

is

necessary

Repeat

this

if

What

maximum 266

ft

of

Problems

change be

the

made over set

tool-face

would

length

severi

dogleg

correction

course

incli

N66W

is

is

much course

no

the

drop

permissible

Assume

ft

to

direction

should

How

change

Answer

torque 8.35

desired

severity

the

were 3.5/l00

You want

new

length

this if

S79W

of

direction

back

for

8.36 Repeat

times

and

directions

Problems

2sinf3/22

bore Table 8.37

and 8.34

using

8.55

and

cos

8.38 Calculate 5.0-in drill

650 ties

Grade

as

the

Answer 8.39 Problem trajectory

Assume 8-in

total

ID

angle

collars

8.53

change and

drillpipe

earth

measured 8.38

ble

using

gives It

of

for

of

Use

has

shear

is

60

the

Tool

from data

is

roll or

top of

the

from

the

instrument

alpha is hole Ta

the

rate

gyroscope

5.8

error of

compass

is

Earths

positive

165

with an

well

in

are

location

The measured

the

5.8

is

resultant

and

the

collars

and

drillstring

at

32

and

the

error

of

ft

of 8-in of

torque

same proper modulus for steel

of

direction is

13.7

between

N75W

dip these

8.51 Determine

the

is

angle

the

error

10.5 is

of

location

at at

60

an

the

dip

strengths

magnetic

the

com of

inclination

44

and

Was

N78W

the

BHA

surveys

maximum survey

error

for

the

fol

the

How

much reverse torque could be expected 8.33 if an 8-in mud motor were used for exnecterl

the

at

What

lowing

directional

to

The

and

30

Answer 11.3 jzT pass unit 8.50 The measured compass

cos

ft

ft

ft

direction

north

direction of

and

strength

181.97

correction

66

191.7

positive

single-shot

magnetic

Ta

Answer

data

from the readings north latitude of The

and

there

that

well-

the

while

data

and

at

positive

noted

inclinations

of

Raglarid

11050

bit-generated

motor

is

sup and

of the hole

measured

the

start

the

angle

Hint

1200

up

clockwise

shal

8.35

TVDl590.9

inclination

sides

is

on

the

gyroscope

l5.042/hr

and

com

the

trajectory

ft

gyroscope

is

1.0

is

gravity

rate rate

spin

low

the

of

taken with

changed

8-in

the

Eq

the

departure

the

Calculate

and

well

Determine

depthl800

direction

described

collar

Table

tool-drift-check

the

ft

wells drill

TX

the

multishot

latitudeN645.4

WV

drill collars

were taken

Houston about

reverse

2j

19.5-lbm/ft

246-in

collars ft-lbf

the

from

data

calculate

lists

8.42

Houma LA

Parkersburg

30-ft

one

gyroscope

the

Problem

center

near

and

8.36

measured

inclination

the

the

lists

magnetic 8.33

Eq

for

S47E

and

data

directional

gyroscope

well

end

of

diagram 8.37 Derive

below

Problem

Bank MT Answer

nonmagnetic

Zone

general information

8.49

Board nomograph

Ouija

the

drilling

ft

directional

from 8.26

for

Cut

WY

WY

Casper

how many

Multishot

length

8.24 8.25 and

30 sec

locations

locations

following

CO

to

8.48

at

nation

the

mu

the

for

set

data

N3OE survey

the

maintaining

correction

the

at

8.34 Answer

unit

plies

ble

and

is

following

OH

none

Rifle

necessary Table

is

make

to

drill

What

ft

Assume no

be

from

and

Evanston

multishot

the

Determine

8.47

measured depth

and

TX

Tyler 8.46

torque and

declination

for

pass

has not turned

motor must At

inclination

losing

below

setting

f3

making

by

N33E

of

N42E

to

trajectory

severity

dogleg

8.41

the target

hit

4835 ft the inclination 15E How many feet must

correction

Eq

8.33

the

at

Marietta

S28E

8.45 Correct

in

8.S3fromEqs 8.41 8.45 and8.48 8.54 from Eq 8.53

lead of

initial

the

from

8.52

Eq

enough

correct

of

Eq

8.31

8.33 An

to

Long

are

Derive

from

direction

and

Table

in

CA

making

by

/31.0 8.30

TX

Beach

S37E

is

making

by

found

the

8.164

Fig

in

pictures

from

direction

and

inclination

declination

for

McAllen

to

15 /31

11

Inclination

inclination

the

information

pic

20

faceN55E

card

compass

card

Inclination

in Fig l65 The timer pictures between pictures 8.44 Correct the single-shot survey

jet

allowable

in

onds

severity for

setting

maximum

obtain

to

8.38

for

tool-face

compass

single-shot

tishot

severity

dogleg

the

faceS34W

the

Determine

8.41

Eq 8.50 from Eq 8.41 Eq 8.51 from Eq

Derive

8.29

the

the

if

300

the is

purpose

How

weilbore

and

and

direction and

Answer

tool

Determine

single-shot

neces

for

tool

directionN22E

0.0

is

and

inclination

8.163

directionS45E

0.2

It

the

right

right

N60W

is

Figs 8.37

to

of

65

8.41 Determine

ft of

ft determine

while

drop

direction

below

whose

run

ting

the

course

kept

8.27 For of

and

change

be

to

30

/3

and

drilipipe

collars

similar

changes

to

Fig

face

the

right

survey is

heavyweight drill

figures

angle of

clinations

8.43

inclination

49.3-lbrnlft

26-in.-ID

right

0.1 0.2 0.2

right

8-in

right

0.0

0.2 0.5

twelve

right

0.0

left

30-50

8450-10130

right

0.0

0.1 0.2

10-30

right

3-in.-ID

should

torque The drillstring Grade ft drillpipe 1000

19.5-Ibm/ft

of 5-in

direction

the reverse

offset

5-in

of

what

In

ft-lbf

to

oriented

consists ft

right

0.2 0.4 0.3

right

0.2 0.2

0.0

0-10

0.1

0.10

right right

50-80

Case

/100

00

right

30-50

6220-

Case

IlOOft

ft

1350

is

dip

be

maximum

for

2000

to

the

3000

to

5000

to

toruue

at

well

2000 3000 5000 8000

good magnetic

assuming ft

ft ft

ft

survey

vertical

10 35

40

constant

build

constant

build

average

APPLIED

458

TABLE

8.30SURVEY PROBLEM

Depth

md

degrees

Inclination

Direction

100

1.20

N11.9W

200

1.12

N1.8E

300

56

400

0.52

N26.1E

500

0.65

N21.5E

600

0.67

N28.9E

700

0.58

N23E

800

0.60

N29.1E

900

0.50

N21.7E

1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000

0.67

N21.7E

0.74

N22.3E

0.58

N5.4E

0.60

N14.5W

0.51

N5.6W

0.45

N23.7W

0.62

N22.4W

2100 2200 2300 2400

N28E

1.04

N2.7W

2.39

N0.3E

4.10

N1.6E

5.85

N2.2W

7.44

N1W

9.60

N1.7E

DATA

DRILLING

FOR

8.18

Depth

md

Inclination

degrees

Direction

5300 5400

46.47

N9.1E

46.62

N9.5E

5500 5600 5700

46.95

N9.2E

47.49

N9.9E

47.93

N10.2E

5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 8000 8100 8200 8300 8400 8500 8600 8700 8800 8900

48.55

N9.6E

49.18

N1OE

49.69

N10.1E

49.79

N9.4E

48.95

N10.3E

50.12

N10.7E

49.95

N10.8E

50.35

N10.7E

50.93

N10.5E

50.19

N11.1E

51.87

N11.7E

53.01

N11.4E

53.72

N12.1E

53.47

N12.6E

53.72

N11.8E

52.62

N12.7E

53.75

N12E

52.41

N12.5E

52.90

N12.4E

52.44

N12.9E

51.59

N12.3E

51.74

N12.2E

50.56

N12.7E

50.65

N12.3E

49.93

N12.6E

50.06

N12.2E

50.42

N14E

50.75

N15.5E

51.15

N15.3E

51.79

N15.1E

51.72

N15E

52.13

N15E

9000 9100 9200 9300 9400

52.60

N14.4E

52.90

N14.5E

9500 9600 9700 9800 9900

53.05

N12.4E

52.18

N12.1E

11.9

N1E

13.86

N2.9E

2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600

16.47

N5.8E

19.8

N5E

22.56

N4.2E

24.88

N4E

26.19

N5.6E

29.28

N4.3E

32.52

N2.8E

35.7

N1.3E

38.64 41.16

NilE N4E

42.75

N4.9E

42.45

N2.4E

3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200

42.43

N2.7E

42.47

N2.5E

43.10

N2.7E

43.66

N2.9E

44.23

N3.3E

44.73

N3.4E

45.03

N3.4E

45.55

N3.1E

45.92

N2.5E

46.16

N2E

46.55

N1.4E

51.44

N12.8E

46.9

N0.6E

10000

50.84

N12.5E

47.23

NOSE

10100

50.79

N13.1E

47.41

N0.7E

10200

50.93

N13.2E

46.05

N5.8E

10300

50.94

N13.8E

46.08

N9.3E

10400

51.10

N13.5E

53.02

N13.9E

53.18

N13.4E

53.67

N12.9E

54.09

N12.4E

54.14

N13.1E

ENGINEERING

DIRECTIONAL

AND

DRILLING

DEVIATION

TABLE

CONTROL

8.31SURVEY

459

DATA

FOR WELL

APROBLEM

8.23

Measured Depth ft

Dogleg

degrees

Direction

ft

Vertical Section

East-West

North-South

Coordinate

Coordinate

360

0.3

0.3

0.25

S25W S36W

416

0.1

0.25

N3W

596

0.6

0.6 0.8

N6E N52E N34W N32W N3OW N44W N54W N47W N42W N45W N47W

903

3.9

0.7

360

0.25

416 596 903

1.5

1245

1.25

1698 1966 2064 2162 2260 2358 2456 2554 2652 2750 2848 2946 3044 3142 3236 3330 3424 3517 3640 3734 3829 3927 4025 4123

0.75 2.5 4.25 5.25

8.25 9.25 10.5 12 14.75 17 19 21 22.5

24 23.75 26.5 26.75

27 26.75 27.5 26.5 26.5 26.5

4221

26.5

4319 4449 4663 4914 5012 5110 5208 5302 5549 5736 5985

25.75

6201

27.75

6455 6639 6734 6853 6944 7038 7130 7254 7379 7505 7630 7752 7967

26.5

26.5 26.25 26.27 27.25 25.5 25.5 27.5 27.75 27.5 27.5

26.5

26 24.75 24.25

23 21 16.75 13.25 10

5.75

8121

8439 8502 8596 6810 8967 9283 10835

TVD

Inclination

4.25 5.5 5.75 4.75 3.75 3.75

0.7 0.7

Severity

/100 0.0 0.75

0.0

0.06

4.7

0.41 0.32

1245

6.5

3.3

11.9

1698

11.4

4.5

19.7

0.31

1966

18.9

0.4

26.1

0.65

2064

24.5

31.0

1.79

2161

32.6

2259 2356 2453 2549 2645

43.0

106.7

2741

129.3

2835 2928 3020

156.0

3111

255.1

3198 3283 3368

291.7

3451

411.7

3561

467.1

3645 3729 3817 3904

509.6

N44W N46W N47W N47W N45W N42W N44W N49W N54W N57W N58W N56W N54W N53W N52W N5OW

3992 4080 4168 4284 4476

684.8

N51W N51W N52W N5OW N52W N51W N49W N49W N49W N48W N43W N39W N16W N19W N21W N15W N15W N13W N13W

N48W N47W N49W N52W N53W N52W N52W N5OW N48W N46W N43W N41W N42W N44W

55.9 70.8 87.6

186.1 219.4

330.0 370.2

552.9

15.4 25.4 35.9 47.4 61.2 77.9 97.7 120.2 146.0 174.8 204.3 234.9 266.4 297.9 338.6 368.3 397.3 426.8 456.6 487.0 517.9

37.5

1.55

44.3

2.08

52.6

1.59

63.2

1.28

75.4

1.37

88.7

1.58

104.0

2.82

122.1

2.31

142.4

2.13

163.7

2.29

185.8

1.57

208.4

1.65

232.3

0.79

257.9

2.08

285.2

1.00

323.2

0.76

353.5

1.46

385.6

1.24

419.0

1.12

450.9

0.91

482.4

0.0

513.3

0.91

549.2 591.1

543.0

0.88

582.1

0.57

659.5 735.9

648.1

0.43

728.7

0.53

766.0 797.6

760.9

1.36

790.9

2.88

830.6 865.2

817.2

2.19

1204.8

840.9

2.56

1.31 5.5

961

902.5

0.21

949.7

0.51

597.4 641.1

728.5 771.6 828.7 923.6

4701

1034.6

4789 4876 4965 5049 5268 5434

1078.7

5654 5846 6072 6236 6322 6429

1647.4

6512 6598

1935.1

6683

2006.5

6801

6922 7045 7169 7290 7504 7658 7975 8038 8132 8345 8501

2221.8

8816

2242.3

10365

26 75

1122.2 1163.9

1511.9

1034.5 1128.7

1015.6

0.37

1610.3

12092

1075.2

0.24

1724.5

1145.7

0.52

1197.4

0.48

1224.1

0.70

1256.2

1.05

1279.7

0.71

2046.2

1301.1 1364.9 1397.3 1436.9 1466.4 1495.7 1522.5 1553.9

2078.3

15787

2103.5

1597.8 1611.8 1621.9 1635.0 1641.1 1648.8 1650.0 1652.7 1659.2 1662.9 1668.6 1691.4

1387.5

2.58

1399.6

2.40

1408.6

1.03

1421.4

0.84

1428.5

0.67

1443.3

0.38

1447.1

2.00

1454.6

1.34

1474.5

0.30

1468.4

0.63

1511.1

0.32

1610.0

0.0

1399.6

1805.7

1897.8

1972.4

2121.9 2135.3 2153.6 2163.0 2179.0 2182.6 2190.0 2209.1

2330.4

1303.4

1.58

1325.1

2.32

1350.1

3.44

1370.8

2.83

ft

460

APPLIED

TABLE

8.32SURVEY

DATA

FOR

WELL

BPROBLEM

823

Measured Depth ft

Dogleg

TVD

Inclination

degrees

454

Direction

ft

Vertical Section

515

1.75

N15W N32W

515

1.9

606

2.75

N2W

606

5.1

728

2.5

728

10.2

910

2.75

N34W N25W

910

18.3

1093 1310 1685 1787

2.5

N3OW

1092

26.3

1.5

1309

33.6

1684

40.6

1786

41.7

1853

1.25

N22W N3OW N8OW N55W

1852

42.6

1951

2.5

N62W

1950

45.7

4.25

N69W N64W N58W

51.0

104.6

0.25

0.75 0.5

454

0.9

2049 2147 2245 2343

10.5

N62W

2441

11.5

N57W

2048 2146 2243 2339 2436

2539 2637 2735 2833

13.25

N55W

2531

125.1 148.9

2931

21

2626 2720 2813 2905 2996 3050 3139 3228 3338 3447 3559 3666 3772 3880 4042 4204 4339 4504 4608 4690 4776 4862 4949 5035 5122 5209

1456.1

5331

1518.9

5525 5606 5736 5933 6128 6298 6388 6479

1617.7

6.25 8.5

15.5 17.5 19.75

3029 3089 3187 3286 3410 3533 3660 3782 3904 4028 4215

28.25

4401

29.5

4557 4746 4866 4960 5058 5156 5254

29.75

23.5 24.75 26.25 26.5 27.25

28.25

29 30 30 29.5

29.5

30 29 28.5

28 27.75

5352 5450 5548 S6B6 5904 5996

27.25

6.141

26.5

6360 6577 6764 6862 6960 7058 7156 7254 7352 7450 7548 7646 7744 7842 7940 8322 8515 9288 9328

25.75

10325 10385 11105

DRILLING

28.25 27.75 27.25 27.75 26.75

25.25 24.25

23 20.25 18.75 16.25 15.25 13.5 11.75 10.75 9.25 7.75 6.5 5.25

2.5

2.5 2.5 2.5

N55W N58W N59W N58W N59W N61W N61W N61W N6OW N6OW N55W N53W N52W N52W N5OW N5OW N5OW N5OW N5OW N5OW N46W N42W N39W N36W N33W N33W N33W N31W N31W N31W N28W N26W N24W N25W N23W N24W N24W N24W N21W N22W N19W N16W N15W N14W N13W N1OW

59.3 71.2 86.7

176.0 206.1 239.0 274.8 298.2 338.3 380.2 433.6 488.4 546.6 604.0 663.2 724.4 816.3 907.2 983.8

1076.5 1135.6 1181.6 1228.5 1274.9 1320.7 1365.7 1410.8

1658.9 1722.5 1816.2 1906.0 1980.5 2017.7 2051.9

6571

2082.7

6665 6759 6854 6950 7046 7142 7239 7337 7434

2110.6

2267.2

N5W

7815 8008

N19E

8.781

2289.9

8821

2290.2

9817 9877

2293.1

N19E N64E N64E N64E

10596

2135.7 2158.5 2178.5 2196.1 2211.5 2224.3 2235.0 2243.7

2274.7

2292.4 2283.2

East-West

North-South

Coordinate

Coordinate

0.3 0.7 1.7 3.5 7.6 11.4 14.7 18.0 18.9 19.8 22.6 27.8 36.0 47.0 61.0 77.1 94.6 114.5 137.7 164.4 193.5 225.1 246.4 283.3 321.7 370.5 420.1 470.8 518.1 565.7 614.6 686.7 756.9 815.9 887.5 933.1 968.6

Severity

/100

1.0

0.0

1.9

2.47

5.3

1.66

10.7

1.20

17.9

0.26

25.4

0.18

32.2

0.48

38.8

0.20

39.4

0.56

39.8

1.25

41.5

1.29

43.9

1.83

47.4

2.09

53.5

2.42

61.6

2.15

71.1

1.41

82.9

1.84

96.8

2.29

112.2

2.22

128.5

2.32

146.4

1.32

165.8

2.58

178.0

2.49

198.5

1.53

219.8

0.23

247.4

0.70

276.0

0.81

308.3

1.86

342.7

1.00

379.3

0.91

417.4

0.0

475.8

0.59

534.7

0.0

584.3

0.14

644.3

0.12

682.6

0.41

712.3

1.06

1003.6 1035.8

743.9

2.03

777.3

2.00

1065.6 1093.1 1119.0 1144.0 1178.8 1232.1 1253.8 1287.3 1334.7 1377.2 1410.2 1426.5 1441.2 1454.3 1466.2 1477.1 1486.4 1494.2 1500.9 1506.0 1509.9 1513.0 1515.3 1520.8 1522.0 1519.1 1518.9 1498.7 1496.3 1468.1

812.1

1.45

848.0

1.50

885.6

1.75

924.2

0.50

977.6

0.35

1063.0

0.48

1099.1

1.08

1154.8

0.15

1238.7

0.69

1322.0

0.46

1392.9

0.70

1428.7

1.34

1461.6

2.90

1491.6

1.57

1518.6

2.55

1542.9

1.01

1565.4

1.94

1585.3

1.80

1603.2

1.18

1619.4

1.62

1633.4

1.54

1645.1

1.28

1654.9

1.28

1681.8

0.59

1691.0

0.28

1714.4

0.21

1715.1

0.0

1737.9

0.19

1739.0

0.0

1752.8

0.0

ft

ENGINEERING

DIRECTIONAL

DRILLING

AND

DEVIATION

Fig

CONTROL

8.163Single-shot

461

compass

card

Problem 8.41

for

pictures

1II 4850

5469

5253

5858

6075

Fig

6260

8.164Single-shot

compass

Time

124500 124520 124525 124555 124625 125325 125355 125425 125455 125525 125555 125625 125655 125725 125755 125825 125855 125925 125955 126025 126055 126125 126155 126225 126255 125325

Depth

ft

card

off

Clock

on

Tool

Problem 8.42

for

pictures

TABLE 8.34DIRECTIONAL

Direction

Maximum

of Well

338 25 S25W N65W

8914 8914 8884 8854 8824 8794 8764

DATA

8.46

Inclination

Location

32 62 48 35 70

N6OE

Dropped

WELL

PROBLEM

FOR

Comments Clock

6726

6511

TABLE 8.33SURVEY DATA FOR PROBLEM 8.43 Survey

5641

Corpus

TX CA

Christi

Beach

Long

Sea

North North

AK

Slope

Boss

Australia

Strait

On Bottom Wait Pull

Stand

1/3

Out

Pull

Stand

2/3

Out

Pull

Stand

Out

Wait Pull

Stand

Pull

Stand

Pull

Stand

Out 2/

Out

Pull

Stand

1/3

Out

8.674

Pull

Stand

2/

Out

Pull

Stand Out

8554

Wait

8554 8524 8914

Wait

ft

Stand

Pull

Stand

Pull

Stand Out

veyed with

1/3

2/3

Out Out

Stand

1/3

Out

8.23

are

area

1650

is

kick-off

and

For

38.6

ft

Wells

the toe of

toward

N75W

the

run What program

is

for

the

were sur

and

well

directional

heat

makes

impractical

the hole

severity

Can

Wells

for

error

survey

is

whipstock the

run The

to is

100

final

drilling

foreman

ge

posi

kick-off

12%

ft

In

be pointed

inclination

the the

and

in Design where the whipstock

size

orientation

hot

in

turbines

program using an open-hole is 2.5 and the direction dogleg

sur

for the

good gyroscope

multishot

motors ft

error

survey

inclination

acceptable should

assuming

drilling

where

displacement

depth

gyroscope

magnetic

You

othermal

probable

the probable

is

Problem

initial

On Bottom

poor

What

8.54

the

Problem 8.47 Answer

for

8.53

tive

Pull

Pull

7.7

and

Wait

8644 8614 8584

Determine

data of

Out

8734 8704

Wait

8.52 vey

be Write

is

S45E

what to

start

achieved

up

The

direction the in

bit

one

whipstock

APPLIED

462

10

15

16

17 Fig

8.35GENERAL

TABLE True

azimuth

north

The

index

north

Gyro

was

Gyro

ended

at

at

WELL

FOR THE

for

Problem

TABLE

SD 277

is

picture

8.43

8.36TOOL

Start

Check

Number

129-00

Orient

Film

Case

End

13-00

129-00

End

277.00

Start

297.7

Corr

20.7

10-20

128-20

277.40

297.6

20.2

0-0

127-00

277.80

297.5

19.7

Orient

been

Problem

at

Surface

head

in

direction

The weight

51

and

tracking

8.56

the

give

is

departure

information

3200

ft

bond

the

850

8500

indicates

ibm/ft

drillpipe and

lars Both

12

pumps

are

9-in

and

9.8 lbm/gal

tol160ft

bit

t4..j

These 1425

ft

Plan

jetting

to the

direction

ft

250 The

1500ft

is

has

that

10450

ft

1200

4.5-in

Mud can

1630to

with

and

BHAs

jetted

1700

Jetting to

jet

coh

5-in

should at

be

1050

1850ft program

500

16.60

drill

6-and

weight be

0-00

277.8

5-40

278.7

21-20

Direction

________

115

171

25

127

21

102

805

89

60.5 60.8

30-40

220.9

34-00

221.1

44-20

60.0

49-40

60.9

60-40

98.1

64-4

98.9

73-00

68.6

77-40

69.8

87-20

92.6

92-00

93.4

99-00

FH

Hole Inclination

2550

102

3635

100

3840

118

37055

131

in

horizon ft

Azimuth

is

the

off

necessary

trajectory hydraulics

program

the

23/-in.-ID

9-P-100

stroke length are sands

8.47

side

the

kicking

S72E

is

hhp rig

7.75-in.-OD National

is

TVD

the

that

hole

for

program

target

for

2090

for

procedure

475

1600

pocket

of

Above

ft

step-by-step

jetting

12%-in hole The

liners

225

operation Design

PROBLEM

poor

The formation from 3600 to 6100 good shale Choose the best method for sidetracking

weilbore

to

3200

to

shows

log

looks

gumbo

tal

The cement-bond

lbm/ft

from 4800

bonding log

is

sidetrack out of Well

to

assigned

Time

17-40

measured depth of 5000 ft and to of S6OW The casing size is 1O% in

8.23

FOR

Gyro Depth

25

8.55 You have

CHECK

Drift

IS

13-00

Case Gyro

DRIFT

8.47

197

is

azimuth

started

DATA

PROBLEM

IN

8.165Multishot

14

20

19

18

ENGINEERING

13

12

11

DRILLING

type

Case 10

Surface

103-40

107.3 108.0

113-40

91.2

117-40

91.8

123-40

297.4

127-00

297.5

930

102

45

58

DIRECTIONAL

DRILLING

AND

DEVIATION

TABLE 8.37MULTISHOT FOR PROBLEM

Time

Measured Depth

8.57

GYRO DATA

17-in

If

25

drill at

Hole

Minutes

Azimuth

and

8.58 You

with

Azimuth

motor The

displacement

62-in

rotor

diameter

3250

at

drilling

ft-lbf

across

395

12-in

and

drilistring

125-in

pitch

Answer

with

ft

psi

positive-

BHA

the

to

torque

required pressure drop

4.555-in

are

5325

requires

the

is

half-lobe

eccentricity Gyro

bit

what

ft/hr

three-stage

Observed

Inclination

Degrees

463

8.47

Observed Corrected

CONTROL

consist

Centers

of 3-20

10

97

4-20

05

88

5-00

05

99

119.9

6-00

05

106

178.7

6-40

10

98

238.0

10

97

292.5

7-40

the

following

350.0

2890

56.9

Data

360

17

Series

two

17-40

25

25

127

60.5

standpipe

22-00

50

25

132

24.8

gal/mm At

23-40

75

25

140

344.1

2040

25-20

100

20

136

332.5

26-40

125

20

135

326.0

27-40

150

25

127

312.2

29-00

175

15

128

271.5

30-00

200

20

124

247.8

and

30-40

225

20

102

220.9

The

35-00

250

25

101

187.4

is

What

are

plastic

lbm/100

275

05

92

147.3

37-20

300

07

76

114.8

38-20

325

05

158

108.0

tor

39-20

350

30

138

100.8

6.25

40-40

375

40

108

42-00

400

20

106

96.5

43-00

425

96

63.4

450

30

92

58.0

44-20

475

05

89

60.0

51-20

500

20

90

74.5

8.60 of

speed

is

teeth

The

8.61

12

25

94

93.1

600

14

25

93

89.8

55-20

650

17

30

92

84.7

Hole

56-40

700

20

15

94

92.5

Power

58-00

750

22

35

94

91.2

Maximum

59-40

800

24

20

99

97.0

102

98.1

65-40

900

27

30

100

87.6

67-00

950

29

96

98.5

68-00

1000

30

55

95

78.0

69-20

1050

32

30

98

89.0

70-20

1100

32

30

103

72-20

1150

34

25

102

92.6

73-00

1200

36

35

100

68.6

the

the

What

are

What What

8.62 You have

81-40

1350

42

05

98

77.9

86-40

1550

36

87-20

1600

38

93-00

1650

94-20

1700

95-40

1750

39

10

132

99.3

97-40

1800

40

40

130

99.8

99-00

1700

37

55

131

106-00

1400

55

111

103.1

117

97.2

40

118

92.6

38

15

124

37

55

130

93.3 108.0

be

15840

43

105

and

bit

motor

to

meet

the

ft

in

100

hp 500

pressure

multilobe

or

exact

length

psi

motor

multilobe

If

and

diameter

You

are

vendor from

the

surface

of

pitch

cal

to

is

from

to

drill

the

No

of

10

second

the

second

the

to

Sea

Beaufort

the

of optimizing

well

well

positive-displacement this

would and

well

intervals

be

tR

con

the

the

The

cored

economi

using

only

Analyze

round-trip time

available

rate

Whale

total

in the

charge

this

developed

data ignore

information

you

whether

data

the

previously

cepts

in

in

are planning

depthusing

Determine

by analyzing

island

you

persuade

well

flow

the

drilling

first

engineer

While

to total

mud motor

the

is

man-made

drilling

tries

completed

just

program

drilling

of

function

as

speed

This

ft

from

drilled

drilling 107.3

ft-lbf

motor torque

maximum motor torque

to

85-40

pressure drop

bit

79.3

75.1

diameter of

2484

the

65.9

40

the

the

98

1500

and

mo

multilobe

stator

is

97

80.0

of

is

15

102

18

to

17

to

the

50

106

10

is

rotor

the

39

10

point

PDMs

16

half-lobe

it

38

43

Ibm/gal

what kind

1300

43

13.5

following

1250

1450

lbf

15000

at

yield

Answer

theoretical

to

50

79-00

1400

the

in

11

is

differential

80-40

83-20

lbf

positive-displacement

range

Consider

104.2

84-20

and

cp

psi

%-lobe

12%

size

Is

the standpipe

of 9.5 and

rotor and

the

235

motor

of

Length

50

is

the

specifications

550

25

15

pitch

is

Design

53-40

850

gal/mm

maximum torque on

stator

Compare 34 and

52-40

60-40

948

is

rate

pressure

gal/mm With

25000

at

weights

is

the

motor

following

the

ft

three

the

up

WOB

pump

the

1040

is

pumping

standpipe

1150

speeds

mud

for

What

in

across

78.7

43-40

with

of

one

psi

viscosity

sq

8.59

pumping

bit

the

bottom

off

36-00

and

1840

pressure

rate

the

and

jets

25000-lbf

and

psi

WOB

pump

the

with

2240

is

and

two %2-in

are capable

bottom

15000-lbf

and

psi

that

drillpipe collars

drill

with

bit

pumps

pressure

off bottom

bit

1-1-1

gal/mm On

1250

24.7-lbm/ft

9.5x3l25-in

of

%2-in jet You have to

5-in

of

ft

ft

actual

following times

is

57.9

108-40

1100

32

25

110

111-40

800

34

20

109

113-40

500

30

102

91.2

120-00

200

20

142

69.6

79.9

and

depth

but

lution and is

on

their

not

it

types are given

may

limited

the

to

What of

350 and 450 1hm/al

are

to

along is

with

analyze

the

correspond

as

provided other

so

possible

of

types

PDMs

performances The choice of used Table 8.39 previously

those and

data

wellbore

speed

be wise

corresponding

available

8.63 bit

$47000/day

is

ratings This information

ing

the

rig

PDM

Three

118.4

cost

Table

8.40

provides

bits lists

information

location the

7-in gal/mm

torque 200-stage for

power turbine

mud

pressure

drop and

operating

weight

of

9.0

at

300

and

16

464 APPLIED

TABLE 8.38SAMpLE Station

Ay

Ax

0.01543

0.01543

13.14122

0.02072

0.01739

13.12538

0.02019

0.02406

13.12611

0.02871

0.02678

13.22877

0.02745

0.03390

13.16444

0.03675

0.03084

13.23515

0.03701

0.03701

13.29530

0.04343

0.03644

13.28324

0.03924

0.04677

13.26710

0.04783

0.04460

13.35932

11

0.04499

0.05556

13.29692

12

0.05810

0.04875

13.37359

0.05671

0.05671

13.43029

14

0.06610

0.05546

13.42072

15

0.05882

0.07009

13.42063

16

0.07010

0.06537

13.49879

0.06305

0.07786

13.43055

0.07874

0.06607

13.49760

19

0.07575

0.07575

13.55629

20

0.08473

0.07109

13.53810

10

13

17 18

8.64

Design

turbine

maximum power 400

is

for

designing

and be

an

to at

operates

of

are

Fig

pump

rate

8.1

330

is

8.66 Your at

starting

diamond

and

mum

drill

fective

area

ft/hr

to

It

of 0.37

The

thinks

two options

effective

that

will

the

reducing thus

you

reduce

time of 100

system

of

133-hour

asks

the

hours

parasitic

power

losses

drill-

to

mud

Dilute

the

lieved

to

mated

PV 21 YV 32

500-bbl be

safe

is

Option

string

of 7-in

are

options

0.22624

0.97534

column

less

than

$52400

to

dilute

and

to

treat

what

with

the

320

5.25

310

46.55

5.5

317

46.4

5.75

3.09

46.55

5.90

320

46.35

6.15

315

46.50

6.35

320

the

and

include

and

rig

and

the

8.67

bit

0.40

is

of

sity

it

bit

in

sq

13.5

see Table Did

test

How

The

is

is

run

is

to

at

turning

at

rate

100

rpm

drawworks

the

lbf

8-in TFA

measure

do

natur of

the

den

based has

oil

pumped

being

table

is

What

The

ft

of 285 At

an

locked

is

bits pump-off

the

drill

off

to

the

pump-off point or was

prematurely there

is

at the

the

is

pump-off

is

the

WOB and

the

300

flow

of

there

at

0.45

true

bit

sq in

of 9.0

gal/mm

l4000-lbf

rate

at

bit

the

to

in

WOB

14000-lbf

increased

is

pump-

l4000-lbf

indicated

at

drop

pump-off force

slack-off

is

at

the

indi

300 gal/mm

14000-lbf

indicated

gal/mm

much weight

diamond

density

WOB

bit-pressure

10000-Ibf

8.68

380

true

the the

if

Estimate

of

is

at

bit

the

nozzle area

apparent

much pump-off force

Estimate

bit

there

is

drop

pump-off area of

the

is

What

WOB

bit-pressure

WOB

dicated

3-in

mud

bit

much

point What What

be

cost

mud

information

8.41

with an

18858

much pump-off force

How off

cost-

will

cost

estimated

8.42

stopped

How

of

the

Table

in

performed

14000

test

the

is

and

of

for

either

turbodrill

$18000 The

has provided

drilling

rotary

for

expenses

point

will

esti

The

in

$14700

time required

rig

$500/hr

at

of

found

depth

lbm/gal

drill-off

the

test

at

force

either

is

drill-off

diamond

al

cost

hours

tool

180-stage

and

aimed

costs

mud

bottomhole

improvement

will

Other

cost

The turbine manufacturer

that

su

bit

16

is

and

down fuel

net

time

collars

inspection

laying

WOB

ef

the

Renting

in

20%

effect

can

to approximately

reduction

1450-psi

rate

indicated

of

increase excessively

will

but

delivery

round-trip

the

no

4.95

46.5

$500/hr

at

circulatory

that

46.25

up

How

shows

investigation

315

pressure

picking

natural

preliminary

4.60

1.59520

bore

Your

320

46.10

0.34312

the turbine

10 Ibm/gal

drill collars

4.35

1.29363

mately Rent

309

45.95

1.02263

only

more

to

4.10

0.15586

peak

run

to

system of

density

317

45.8

1.00045

cated Option

310

3.75

psi

pump-off in over the

for

3.50

45.55

1.58048

the

in the

45.3

1.40603

The

an

whether

more hhp

320

gal/mm

lbf

have

rate

time

or less Both

available

making

pump

The maxi

diamond/turbine

drilling

3.25

0.25742

natural

time Your

drilling

determine

to

section

12-lbm/gal

will

penetration

hours

315

45.45

0.97261

The

3825

sq

3.00

you recommend

in

that

320

45.7

0.11037

shale

is

16

to

2.75

about

corresponds

in and 12

expected

133

He

sq

speed

19.50-lbm/ft

bit

309

45.5

1.02337

10.0 lbmlgal

indicate

the

that

7-in

25000

that

2.50

including

and

about

that

torque

316.99

45.35

1.53068

option

department

require

from about

increase

too costly

will

2.25

should

shafts

collars

drill

310

45.11

0.28081

penetration

bit

1O-P-l30

5-in

319.99

1.80

0.68%

bit

8-in

an

pressure

research

the

is

has

rig

liners

estimated

is

and requires

pervisor

and

turbodrill

x2-in

bit

attain

interval

The

weight

with

8O-stage

35

the

nozzle area

will

800-ft

at

TFA

power

of

are

ft-lbf

800-ft-thick ft

standpipe

tests

WOB

an

13600

of

allowable

turbine

at

of

25 YV

0.45-sq-ft

true

of

to

7-in

string

Laboratory

be

is

mud

the

you are using 534-in

pipe and

the

goal depth

PV

mud

gal/mm

on

bit

300

1.55

2750 bbl

This turbine

torque

45.26

45

1.31285

1.01953

Alpha 315

mud volume

8-in PDC

power

1.06336

Inclination 1.25

rate

efficiency

approximately

Az

The

You

8.48

45

bits

78%

overall

Gx 0.11446

pump

lbm/gal

6-in PDM Fig lOlA 18A that has two connected

combination

turbine

of

the

the

type of

of

new

torques

8.65 What

10.0

is

and

FOR PROBLEM

Gy

8/2-in

rpm

mechanical

efficiency

with

drill

with

drill

1500

weight

overall

hydraulic able

oil

output

mud

gal/mm

to

is

DATA

ENGINEERING

DRILLING

should

be

WOB

at

test

performed of

at

depth

The

drilling

lbm/gal The

is

and

rotary

applied

is

table

to

get approxi

300 gal/mm with

10680

mud

is

being is

ft

an

The

water

based has

pumped

turning

8-in TFA of

at

at

75

rate

rpm

DIRECTIONAL

AND

DRILLING

CONTROL

DEVIATION

TABLE

PDM

Hole

in

Bit

gal/mm

Size

in 7/8-

mm

9/8

91/2.121/4 91/2

121/4.171/2

111/4

171/2.26

91/2

121/4.171/2

111/4

171/2.26

Speed

Range

max

Differential

Maximum

Pressure

rpm

psi

185

370

90-180

580

315

610

75-150

465

395

335

90-145

640

525

1055

70-140

520

1500 2000

2400 4000

90-145

44

70-140

36

OD

Hole

Pump Rate gal/mm

Size

in 8%-

Range

percent

2540 4030 6160 8850 8350

44-

87

70

70

58-115

12000

Bit

Speed

Range

Differential

106-170

72

118-236

73

79-127

72

88-176

73

Maximum

Pressure

Horsepower

Efficiency

ft/lb

Range

percent

psi

100

240

245-600

580

200

475

205-485

580

245

635

145-380

465

2090

395

740

195-365

695

525

1055

120-250

465

3890 5380

9/8

171/2.26

Maximum

Torque

rpm

121/4.171/2

111/4

585

67

27-

1500

Length

Weight

Ib

ft

83

20.0

59-108

86

26.6

59-152

88

26.9

145-271

90

32.8

123.256

90

32.2

840

2160 2800 5200 7300

Type

Tool

Maximum Recommended

size

O.D

Hole

in

Pump Rate gal/mm

Size

in

61/4

mm

Bit

Speed

Range

max

Differential

rpm

39-

98

27

91

345

200-510

580

8%-

9/8

160

395

140-480

465

995

200

475

160-400

465

1475 2280 2210 2990

240

610

130-340

465

9/2

121/4.171/2

395

900

140-325

290

290

685

115-290

465

Number

Bit

in 26.00

Cost Type 1-1-1

17.50

1-1-1

17.50

1-1-6

17.50

1-1-4

17.50

1-1-4

12.25

1-1-1

12.25

1-1-4

12.25

1-1-4

12.25

4-3-7

12.25

5-1-7

11

8.5

12

8.5

13

8.5

MC2O1 MC2O1 MC2O1

14

12.25

2-1-5

12.25

5-1-7

16

12.25

5-1-7

17

12.25

5-1-7

18

8.50

19

8.50

1-3-5

Length

Weight

ft

Ib

85

23.6

1770

1770 2430

85

21.7

46-113

87

23.6

56-148

90

24.6

59-137

90

24.6

65-165

89

26.6

3970 3970 5960

A-i

Bit

Size

percent

1015

170

Whale

Efficiency

Range

121/4171/2

for

Horsepower

ft/lb

9/8

171/2.26

Maximum

Torque

psi

91/2

111/4

Maximum

Pressure

/8

91/2121/4

15

Efficiency

ft/Ib

max

91/2121/4 91/2

10

Horsepower

mm

7/8

Bit

Maximum

Torque

Maximum Recommended

size

No

8.62

Type

Tool

Data

FOR PROBLEM

Maximum Pump Rate

Recommended

size

O.D

PDM

DATA

Type

Tool

PDM

8.39AVAILABLE

Depth out

ft

9100 6300 6300 6300 6300 5700 5700 5700 8000 8000 9000 9000 9000 4000 8000 8000 8000 4400 9000 9000 9000 9000 9000 9000

1600 1800 2280 4300 6300 6500

Drilling

Flow

Speed

Rate

Hours

Ib

rpm

gal/mm

29

3000

120

Time

ft

1200

840

200

15000

80

800

480

15000

350

700

45000 40000

200

1000

125

950

2020

19

2.000

21

200

15000

2550

66

12250

1050

48

1200 950

12300

50

12350

50

12400

50

12400

12

40000

13

45000 45000 45000 25000 25000 25000 25000 45000 45000 45000 35000 35000 25000 25000 25000 25000 25000 25000 25000 35000

15

1150

61

14330

750

59

15000

700

49

15150

150

18

15200

50

15250

50

15300

50

10

15350

50

10

15400

50

10

20

8.50

21

8.50

22

8.50

23

8.50

24

8.50

MC2O1 MC2O1 MC2O1 MC2O1 MC2O1 MC2O1

15450

50

10

25

8.50

MC2O1

9.000

15500

50

10

26

8.50

MC2O1

8.50

5-1-7

9000 4400

15500

27

15840

Bit

WOB

Footage

7700 8650 11200

13550

Program

50 340

20 56

80

480

130

530

125

550

80

550

80

550

75

275

75

275

75

275

80

550

80

560

80

560

75

570

90 75 75 75 75 75 75 75 75

275

90

310

Pump Pressure

psi

1900 2300 1800 3400 3450 2700 3400 3350 3300 3470 2000 2000 2000 3470 3450 3450 3450 3400 2200 2200 2200 2200 2200 2200 2200 2200 3400

Types

of

Nozzles

18-18-18

Cement

20-20-20

DrI

20-20-20

PDM

18-18-18 16-18-18 12-12-12

DrI

Cement

12-12-12 12-12-13 13-13-13 13-14-14

TFA.5

TFA TFA

Coring

.5

Coring/RR

.5

Coring/BR

14-14-14

Reaming

14-14-14 14-15-15 15-15-16 10-11-11

DrI

Cement

TFA.5

Coring/RR

TFA TFA

.5

Coring/RB

.5

Coring/BR

TFA.5

Coring/RB

TFA TFA

Coring/BR Coring/BR

TFA.5

Coring/RB

TFA

Coring/BR

.5

10-11-11

11800

TVD

466

APPLIED

TABLE 8.39AVAILABLE

DATA

FOR

PROBLEM

cont

8.62

Assemblies

Bottomhole Intermediate

171/z-in

Interval

BuiIdng

1800 17172

2280

ft

Bit

12

lnt

500

Delta

PDM

Sub

Bent

8-in

NMDC

8-in

DC 6.5-in DC

Jnt

8-in

Jnt

Shock

NMDC

WI81400

Jnt

8-in

Jnt

8-in

35 Jnt

lb

5-in

Clamp-on 65

121/4-in

Intermediate

6100-19950

Slight 81/z

Bit

Sub

8/z

NB Stab

Jnt

8-in

NMDC

MWD NMDC DC

HWDP 6-in DC Clamp-on NM Stab 5-in

from

ft

from

ft

NM

ft

Wt

Air

Ibm

93500

Ibm

Dropping

Jnt

6-in

short

Jnt

81/2in

Stab

Jnt

6l/2in

DC

DC

12

Jnts

Air

Wt

HWDP

5-in

73000

lb

Stab

first

Wt 93500

Air

Clamp-on NM Stab 40 above first

Stab

Jars

first

Clamp-on 45

Stab

first

Jnt

Jnt

15

NM

above

8-in Stab Jnt 6-in DC 24 Jnt 5-in HWDP

Stab

Full

Jnt

ft

It

Shock

8-in

30

DC

HWDP

Production

12-in Bit NB RWP Stab

Gauge Jnt 8-in

5-in

Clamp-on

first

Wt93500

6.5-in

Jnt

Interval

Holding

Jnt

NM

DC

8-in

Jrrt

35

NMDC

8-in

Jn

first

above

ft

81/2-rn

II

NMDC

8-in

Jnt

HWDP NM Stab

ft

36

Jnt

NMDC

Clamp-on 30 above

Air

Stab

Sub

MWD

DC Jnt 6.5-in DC

HWDP

Jnl 5-in

Air

Jnt

ft

Bit

NB RWP

MWD

Jnt

35

Sub

6100

to

171/2-in

Stab

Shock

NMDC

8-in

MWD

4300

ft

Bit

NW RWB

Interval

Building

4300

to

171/2-ifl

Dynadrill

11/20

Interval

Building

2280

to

lb

Casing Depth

Hole

Casing

______________

200

0-

26.00

30-in

1600

17.50

20-in

0-

6300

12.25

13%

9%

8.50

14500-15840

Program

Interval

Geologic

Conductor

0-

0-15000

Overview

Size

in

ft

Below

Surface

Below

Intermediate

100

Intermediate

Prod

7-In

11800

Liner

Permafrost T-5

ft

Coals

Sag

into

River

TVD Geology Overview

TVD

Estimated

Subsea Maker

Formation Kelly

Bushing Bottom of Permafrost

Tertiary-Cretaceous

T5

Pebble

Pro

Delta

Delta

Shale

Kuparck Kingate

Sag

kelly

ft

Bushing 50

Coals

Cretaceous

Measured from

Depth

fI

River/Shublik

1600

1650

1600

1650

5100 6400 8925 8050 8400

6218 8395 11991 12303 12780

11050

14942

lvishate

11200

15132

Lisburne

11600

15629

Mud Mud wt Interval

0-

ft

lb/gal

1800

10

PV

Ib/100

sq

ft

YV

lb/i

00

14

20 20

1800-

2280

9.9

14

2280-

4300 6300 8650

9.7

14

20

9.5

14

20

9.5

10

15

9.3

10

15

11200-12400

9.6

12

18

12400-15000

11.5

16

18

15000-15500

10

12

18

12

18

43006300-

8650-11200

15500-15800

9.5

sq

ft

DRILLING

Overview

ENGINEERING

DIRECTIONAL

DRILLING

AND

DEVIATION

TABLE

CONTROL

467

840WELLBORE

LOCATION

FOR

PROBLEM

8.62

Dogleg Measured

Depth

ft 100

Inclination

degrees

True Direction

0.00

N0.OOE

1000

0.00

N0.OOE

1000

0.00

N1.OOE

1000

3.00

N1.OOE

6.00 9.00

2000 2100 2200 2250 2350 2450 2550 2650 2750 2850 2950 3050 3150 3250 3350 3450 3550 3650 3750 3850 3950 4050 4150 4250 4350 4450 4550 4650 4750 4850 4950 5050 5150 5250 5350 5450 5550 5650 5750 5850 5950 6050 6100 6200

Vertical

Depth

It

100

Vertical Section

Severity East-West

0.0

0.0

1000

0.0

1800

0.0

1899

N1.OOE N1.OOE

North-South

I100

0.0

0.00

0.0

0.0

0.00

00

0.0

0.00

2.5

0.0

2.6

0.00

1999

10.1

0.2

10.5

3.00

22.6

0.4

23.5

3.00 3.00

12.00

N1.OOE

13.50

N1.OOE

15.50

N1.40E

17.50

N1.80E

19.50

N2.20E

21.50

N2.60E

23.50

N3.OOE

25.50

N3.40E

27.50

N3.80E

29.50

N4.20E

31.00

N4.50E

23.50

N4.80E

2098 2197 2245 2342 2430 2533 2627 2709 2800 2899 2987 3074 3159

3400

N5.1OE

35.50

N5.40E

37.00

N5.70E

38.50

N6.OOE

40.00

N6.30E

41.50

40.1

0.7

41.7

50.7

8.9

52.8

2.99

74.8

1.4

77.8

2.00

102.1

2.2

106.2

2.00

132.8

3.3

137.9

2.00

166.6

4.8

172.9

2.00

203.7

6.7

211.1

2.00

244.0

9.0

252.5

2.00

287.4

11.8

297.0

2.00

333.8

15.1

344.6

2.01

383.0

16.9

394.9

1.51

434.4

23.2

447.3

1.51

3242

487.9

27.9

501.9

1.51

543.7

33.2

558.7

1.51

601.7

38.9

617.5

1.51

661.7

45.1

678.4

1.51

723.8

51.9

741.3

1.51

N6.60E

3324 3405 3484 3562 3637

788.0

59.2

806.2

1.51

43.00

N6.90E

3711

854.1

67.1

873.0

1.51

44.50

N7.20E

3784

922.2

75.6

941.6

1.51

46.00

N7.50E

84.7

1012.0

1.51

N7.70E

94.3

1083.6

0.51

47.00

N7.90E

47.50

N8.1OE

48.00

N8.30E

48.50

N8.50E

49.00

N8.70E

49.50

N8.90E

50.00

N9.1OE

50.50

N9.30E

51.00

N9.50E

51.50

N9.70E

3854 3923 3992 4060 4127 4193 4259 4325 4389 4453 4516 4579

992.2

46.50

52.00

N9.90E

52.50

N10.1OE

53.00

N10.30E

53.50

N10.50E

54.00

N10.70E

54.50

N1O.90E

55.00

N11.1OE

55.50

N11.30E

55.75

N11.40E

55.55

N11.60E

6.300

55.35

Nii.80E

6400 6500 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800

55.15

NJ12.OOE

54.95

N112.20E

54.75

N12.40E

54.55

Ni12.60E

54.35

NJ12.80E

54.15

1063.2 1135.3

104.1

1155.8

0.51

1207.8

114.4

1228.5

0.51

1280.9

124.9

1301.8

0.51

1354.7

135.8

1375.6

0.51

1429.1

147.1

1449.9

0.51

1504.0

158.7

1524.8

0.51

1579.6

170.6

1600.2

0.51

1655.7

182.9

1676.1

0.51

1732.5

195.5

1752.5

0.51

1809.8

208.5

1829.4

0.51

4641

1887.7

221.9

1906.7

0.51

1966.1

235.6

1984.6

0.51

2045.2

429.7

2063.0

0.51

2174.7

264.2

2141.8

0.52

2204.9

279.0

2221.0

0.52

2285.5

294.2

2300.7

0.52

2366.7

309.8

2380.9

0.52

2448.5

235.8

2461.5

0.52

2489.5

333.9

2502.0

0.50

2571.7

350.4

2582.9

0.25

2653.7

367.1

2663.5

0.25

2735.5

384.0

2743.9

0.25

2817.2

401.2

2824.1

0.25

2898.6

416.6

4904.0

0.25

2979.9

436.3

2983.6

0.25

3061.1

454.1

3063.0

0.25

N13.OOE

4702 4763 4622 4882 4940 4998 5055 5083 5139 5196 5253 5310 5368 5426 5484 5542

3142.0

472.3

3142.1

0.25

53.95

N13.20E

5601

3222.0

490.6

3220.9

0.25

53.75

N13.40E

3303.3

509.2

3299.5

0.25

53.55

N13.60E

3383.7

528.0

3377.0

0.25

53.35

N13.80E

3463.9

547.0

3455.9

0.25

53.15

N14.OOE

5660 5719 5779 5839

3543.9

566.3

3533.6

0.25

52.95

N14.20E

5.899

3623.7

585.7

3611.1

0.25

52.75

N14.40E

5959

3703.3

605.4

3688.4

0.25

52.55

N14.60E

6.020

3782.7

625.3

3765.3

0.25

52.35

N14.80E

6081

3861.9

645.4

3842.0

0.25

7.900

52.15

N15.OOE

3941.0

665.8

3918.4

0.25

8000 8100 8200 8300 8400 8500 8600 8700

51.95

N15.20E

6019.8

686.3

3994.6

0.25

51.75

N15.40E

4098.4

707.1

4070.4

0.25

51.55

N15.60E

4176.7

728.0

4146.0

0.25

51.35

N15.80E

4254.9

749.2

4221.3

0.25

51.15

N16.OOE

4332.9

770.6

4296.3

0.25

50.95

N16.20E

4410.7

792.1

4371.0

0.25

50.75

N16.40E

4488.2

813.9

4445.4

0.25

50.55

N16.60E

6142 6204 6265 6327 6390 6452 6515 6578 6642

4565.5

635.8

4519.6

0.25

ft

468

APPLIED

TABLE

8800

8.40WELLBORE

50.35

N16.80E

50.15

N17.OOE

49.95

N17.20E

49.75

N17.40E

49.55

N17.60E

49.35

N17.80E

49.15

N18.OOE

48.95

N18.20E

48.75

N18.40E

48.55

N18.60E

48.35

N18.80E

48.5

N19.OOE

10000

47.95

N19.20E

10100

47.75

N19.40E

10200

47.55

N19.60E

10300

47.35

N19.80E

10400

47.15

N20.OOE

10500

46.95

N20.20E

10600

46.75

N20.40E

10700

46.55

N20.60E

10800

46.35

N20.80E

10900

46.15

N21.OOE

11000

45.95

N21.20E

11100

45.75

N21.40E

11200

45.55

N21.60E

11300

45.35

N21.80E

11400

45.15

N22.OOE

11500

44.95

N22.20E

11600

44.75

N22.40E

11700

44.55

N22.60E

11800

44.35

N22.BOE

11900

44.15

N23.OOE

12000

43.95

N23.20E

12100

43.75

N23.40E

12200

43.55

N23.60E

12300

43.35

N23.80E

12400

43.15

N24.OOE

12500

42.95

N24.20E

12600

42.75

N24.40E

12700

42.55

N24.60E

12800

42.35

N24.80E

12900

42.15

N2500E

13000

41.95

N25.20E

13100

41.75

N25.40E

13200

41.55

N25.60E

13300

41.35

N25.80E

13400

41.15

N26.OOE

13500

40.95

N26.20E

13600

40.75

N26.40E

13700

40.55

13800

LOCATION

FOR

PROBLEM

8.62

DRILLING

cont

6705 6769 6833 6898 6963 7028 7093

4642.6

858.0

4593.4

0.25

4719.5

880.4

4667.0

0.25

4796.2

902.9

4740.2

0.25

4872.6

925.6

4813.2

0.25

4948.8

948.5

4885.9

0.25

5024.8

971.6

4958.3

0.25

5100.5

994.9

5030.4

0.25

7159 7224 7290 7357 7423 7490 7557 7625 7692 7760 7828 7897 7965 8034

5176.0

1018.4

5102.2

0.25

5251.3

1042.0

5173.7

0.25

5326.4

1065.9

5244.0

0.22

5401.2

1089.9

5315.7

0.22

5475.7

1114.0

5386.3

0.22

5550.1

1138.4

5456.6

0.22

5624.1

1162.9

5526.6

0.22

5698.0

1187.5

5596.2

0.22

57716

1212.4

5665.6

0.22

5844.9

1237.4

5734.6

0.22

5918.0

1262.5

5803.4

0.22

5990.8

1287.8

5871.8

0.22

6063.4

1313.3

5939.9

0.22

6135.8

1338.9

6007.7

0.22

6207.8

1364.7

6075.2

0.22

6279.7

1390.6

6142.3

0.22

6351

1416.7

6209.2

0.22

6422.5

1442.9

6275.7

0.22

6493.5

1469.2

6341.9

0.22

6464.3

1495.7

6407.8

0.22

6634.8

1522.3

6473.4

0.22

6705.0

1549.1

6438.6

0.22

6775.0

1576.0

6603.6

0.22

6844.7

1603.0

6668.2

0.22

6914.1

1630.2

6732.4

0.22

6983.3

1657.4

6796.4

0.22

7052.1

1684.8

6860.0

0.22

7120.7

1712.4

6923.3

0.22

7189.1

1740.0

6986.3

0.22

7257.1

1767.0

7048.9

0.22

7324.8

1795.6

7111.2

0.22

7392.3

1823.6

7173.2

0.22

9390 9464

7459.5

1051.7

7234.9

0.22

7526.4

1879.9

7296.2

0.22

9538 9612 7687 9762 9836 9912 9987

7593.0

1908.2

7357.2

0.22

7659.3

1936.6

7417.8

0.22

7725.4

1965.2

7478.1

0.22

7791.1

1993.8

7538.1

0.22

7856.6

2022.5

7597.8

0.22

7921.7

2051.3

7657.1

0.22

7986.6

2080.2

7716.0

0.22

10063

8051.1

2109.2

7774.7

0.22

N26.60E

10139

8115.4

2138.2

7833.0

0.22

40.35

N26.80E

10215

8179.4

2167.4

7890.9

0.22

13900

40.15

N27.OOE

10291

8243.0

2196.6

2948.6

0.22

14000

39.95

N27.20E

10368

8306.4

2225.9

8005.8

0.22

14100

39.75

N27.40E

10444

8369.5

2255.3

8067.8

0.22

14200

39.55

N27.60E

10521

8432.2

2784.8

8119.4

0.22

14300

39.35

N27.80E

10599

8494.7

2314.3

8175.6

0.22

14400

39.15

N28.OOE

10676

8556.8

2343.9

8231.5

0.22

14500

39.95

N28.20E

10754

8618.7

2373.6

8287.1

0.22

14600

38.75

N28.40E

10831

8680.2

2403.3

8342.3

0.22

14700

38.55

N28.60E

10910

8741.4

2433.1

8397.2

0.22

14800

38.55

N28.80E

10998

8802.3

2463.0

8451.6

0.22

14900

38.15

N29.OOE

11066

8862.9

2492.9

8506.0

0.22

15000

37.95

N29.20E

11145

8923.2

2522.9

8559.8

0.22

15100

37.75

N29.40E

11224

8983.2

2552.9

8613.3

0.22

15132 15232 15332 15432 15532 15632 15732 15832

37.68

N29.46E

11249

9002.3

2562.5

8630.4

0.00

37.18

N29.46E

11329

9061.7

2592.4

8683.3

0.49

36.68

N29.46E

11409

9120.4

2622.0

8735.6

0.49

36.18

N29.46E

11489

9178.4

2651.2

8787.3

0.49

35.68

N29.46E

11570

9235.7

2680.0

8838.4

0.49

35.18

N29.46E

11652

9292.3

2708.5

8888.9

0.49

34.68

N29.46E

11734

9348.3

2736.7

8938.7

0.49

34.18

N29.46E

11816

9403.5

2764.5

8987.9

0.49

15840

34.14

N29.46E

11823

9407.9

2766.7

8991.8

0.00

8900 9000 9100 9200 9300 9400 9500 9600 9700 9800 9900

8103 8173 8242 8312 8382 8453 8524 8594 8666 8737 8809 8880 8953 9025 9097 9170 9243 9317

ENGINEERING

DIRECTIONAL

DRILLING

while

ahead

drilling

WOB and

The

at

10

slack-off

test

with

ft/hr

22000-lbf

about

run

is

CONTROL

DEVIATION

raised

is

drilistring

then

AND

1.0

ON TABLE 8.41DATA TOOL FOR PROBLEM

indicated

off

ft

469

measure the pump-off

to

Mud Weight

force 10

WOB

Standpipe

Indicator

Pressure

1W

1265

270

300

1250

290

500

1250

How off

310 330

1265

300

350

What

dicated

val

under

bit

with

1825 Elapsed

WOB

1925

Time

Indicator

4300

1975

mm

7300

2025

8.42DATA FOR PROBLEM 8.67

10300

2065

24000

2125

bit-pressure

drop

there

is

pump-off force

at

the

produced

is

pump-off area of

the

WOB

true bit

ft/hr

with

the

after

that

the

this

sq

8.69

bit

valid

in

the

that

test

bit

and

indicated

is

being

WOB

is

1690

diamond

24000

in averaged sq

ft/hr

bit

current

entire

Both

interval

the

faster

bits

drilled

the

is

have

typically is

Answer

better

685

psi

at

lbf

rate

and

of

the

8-in

an

380

580-psi

differential

increased

pressure

Indicator

Pressure

mud motor is of

bit

to

and 1.0

operated

Thus

97% of From has

power

peak the

pressure

Does

the

of

lbf

Explain

enough

SPP

Off100

conclusion whether

the

bit

pump-off force

and

from Part

result

that

optimal

its

565/580x

psi

determine

drop

to

On-bottom

valid

pump-off plot

significant

9000

this

Is

force

appears

it

close

very

poweri.e 1175565

peak

do not expect

pump-off

little

TFA

in

We

torque

is

pressure

mud motor Lp

the

therefore

sq

being

standpipe

because

SPP 1740

bottom

mean

the

that

has

bit

pump-off force

how

bit

pressure drop

rated

to

at

1.0 sq

produce

TFA

in

4000

lbf

of

have

can

pump-off

force

from the discussion in Problem 8.69A mud motor was being operated 97% ef Now with the benefit of the pump-off plot de

psi

that

appeared fectively termine

it

how

the

1190

tor

2500 4000

1190

mum

1175

the

5000

1175

lbf

6500

1200

8000

1325

with

9000

1410

changes

1450

if

tells

bit

that

us

torque torque

8.70 You

at

the

are

for

motor

rated

drilling

is

rate

with

to

at

at

2540

12-in

ft-lbf

of

is

of

Fig

The

35000 lbf You

mo

maxi

Determine

WOB

PDM

1000 gal/mm 6100 ft-lbf What

with

mud

pressure

an applied

run

actually

this particular

differential

example

drilling

from 4200

motor was

literature

580-psi

in this

circulating

you are

the

efficiently

The published

1175

1000

11000

on-bottom

proportion

much pressure drop from bit rated at the

the

off-bottom

the

in

1740

that

Initially

Standpipe

0.0

know

than

greater

gal/mm

standpipe

WOB lbt

We

condition with

performed

24000

at

1650

radial-flow

pumped

maximum power

9000 9000

bottom

1650

pres sure is 1750 psi The TFA of the bit was 1.0 sq in when new and has drilled 493 ft The mud motor is rated to

produce

9000

52

22000

in the

that

body polycrystalline diamond compact bit run on 6%-in positive-displacement mud motor at depth of ft The mud is oil based 11168 with density of 7.8

ibm/gal

10000

38

same inter

indicated

in

matrix

The

10500

30

1610

the

22 000-lbf

lbf is

22

20000

drills

18650

11000

WOB

conclusion

slack-off

11500

19

1550

at

50%

salvageable

15

18000

of

same diameter and number of diamonds and

4.0

bit-

12000

1510

22000-lbf

12

2490 2490 2485 2485 2485 2480 2480 2475 2475

15500

there

conditions

pump-off area of

psi

14000

13000

is

shows

record

comparable

at

Pressure

Ibf

bit

the

nozzle area

are

Is

the

by

the

bit

pump-

ofi

the

Standpipe

13000 10

pump-off point

the apparent

offset

appears

38488 43294

3000

compared with 10

It

2160 2429

TABLE

WOB

An

1906

2000

much pump-off force

is

28303 32073 36078

1725

is

What

1668

1575

is

How

1446

24769

1800

drop

What

21470

1475

much

lbf

22089 25764 29723 33964

1300

the

psi 1240

1375

point

pressure

lbf 18407

1000

much

How

psi

1033 1205 1390 1588 1800 2025

Axial Thrust

Drop

Thrust

_______________

Ibm/gal

Pressure

Axial

Drop in

250

12

Ibm/gal

Pressure

Rate gal/rn

0.0

Locate

Flow

psi ________

0.0

8.66

180-STAGE

bottom

the

have

24000

1O1B

bit real

torque

WOB

4000

ft

APPLIED

470

TABLE 8.43DEFLECTIONS MEASURED TESTING MUD MOTORPROBLEM

IN

Test

Bending Plane

ENGINEERING

DRILLING

8.74

Test

Loading

xx

YY

Turbine

of

6%-in

OD

with zero

bit

8.71 off

wells

PDM

bine or use in detail

BHA

the

shots

single

reverse

pected the

current

8.72

Give

Derive

moment

of

of

to the

ment of

inertia

8.74

of

for

at

0.347

0.448

0.498

0.357

0.351

0.498

0.499

0.355

202

lbf

at

0.362

0.510

0.519

0.372

0.366

0.520

0.521

0.370

303

lbf

0.340

0.478

0.485

0.348

0.340

0.478

0.485

0.348

in

own

its

at

weight

0.505

0.363

0.355

0.498

0.506

0.364

101

Ibf

at

0.517

0.525

0.378

0.369

0.518

0.526

0.378

202

lbf

at

0.383

0.538

0.547

0.393

0.383

0.539

0.547

0.393

303

rotated

900

and

and

then

45

releveled

before

the

two

tests

lbf Hole

economics

for

kicking

Depth

Diameter

ft

in

tur you jet use you kick off Describe kick

off each

well

tool-fall

You

MWD

the

and

to

14500

171/2

14500

to

18000

171/2

18000

to

22000

81/2

171/2

to to to to

3600 6500 5000 25000

7000 2000

TABLE 8.45COORDINATES FOR PROBLEM 8.86

polar

Answer

and polar

mo

kelly

measured

deflections

equivalent

in

test

Well

12A

Well

13A

Well

14A

Well

15A

Well

16A

Well

17A

Well

18A

Well

19A

Well

20A

Well

21A

using

stiffness

8.43

Table

8.500

to

and

the

collar

inertia

lbm

air2980

26

to

to

research

to

steering

inertia

drill

of

lbf

2500 5000 3500 2000 4000 1000

26

4000 6500

to

Force

economics

best

of

ex

and

headings have

will

on

or simply

tool

steering

4000 6500 8500

to

Give

details

supplying

as

and

at

TABLE 8.44FORCES FOR PROBLEM 8.85

10-in.-

35660

is

lbf

repeated

Will

to

the

were

Assuming

WOB

real

of

joints

Answer

in

Sec Sec Sec Sec Sec Sec Sec Sec Sec Sec

1320

FNL FWL 500 FWL 440 FNL 2640 FWL

12

200

11 11

400

12 12

11

FSL

and

FEL

and

FSL

3960 2640 and 1000 and

440

and

2640

and 800

FNL FEL FSL

FWL

3960

FNL and 600 FEL

1320 1320

FSL

and

3690

FSL

and

100 FEL

2640

FSL

and

300

FEL

FSL

in

148228

5.5370570

in of circumference

Iirr4/4ir3.53

circle

weight

0.497

in

is

own

its

0.369

hexagonal

shows

rotation

solid

lbf

moment

axial

turbine

90

101

will

CircumferencexD22 or

0.339

square

radius3.525

Outside

0.478

moment

for

Calculate

Diametera7.05

0.477

motors

information

following

Weight

0.336

Note the

for

mud motor

ing the

0.340

kick-off

axial

8.166

Fig

0.475

use

JL4/6xd4/32 the

0.466

determine

inertia

8.73 Derive

0.331

estimated

torque

tools

0.324

and

MWD

use

costs

single-shot

0.456

8.12

will

your

will

you

0.455

the

Where

you

for

procedure whether

0.320

strategy

Problem

for

0.324

collars

force

the

0.452

lbf/ft

drill

pumpoff

Develop

your

use

steel

0.444

0.354

was

24.7

drillpipe

by 3-in.-ID

0.315

in.4/4

between

121.26

supports

in4 Structural

steel

E30x

106

psi

Weld

Dial

Gauges

Answer

ii

2.1707x109

8.75

Determine

following

drillstring

the in

air

and

weight

the weight

for

-4or t36

the

mud

16.2-lbm/gal

124

Drillpipe

2520

ft

of

5-in

Grade S135

Drillpipe

6520

ft

of

5-in

Grade

t34

or

148

or

160

186

or

222

248

or

296

Heavy-weight

850

drillpipe Drill

collar

620

collar

500

ft

ft

tool Drill

Stabilizers

5-in

of

6Y2-in

of

in

ft

12-in

8.76

0.18

Determine

the

static

H90

stainless

OD

8.23-in

BHA

II

H90

Fig

6%-in

6%-in

joints

Four 5.5

Bit

Range

joints

ft

tool

of

Series

drag

of

by

the

drilistring

and

of

0.15

constant

30

coefficients is

ID

5-2-4

of

Problem 8.75 assuming drag and 0.22 where the weilbore

steel

2t46-in

at

8.166Deflections

measured

Problem 8.74

in

testing

mud

motor

DIRECTIONAL

The

inclination

Mud

rig

ing is

You

where

the

weight

745

is

drill

hold

it

You

slick

BHA

The

80

wellbore

bit

mud

the

at

alu

are

the

be

45000

Assume

built

placed

385

is

under

one

that

to

stabilizer

steel

bit

drill

The

collars

weight

9.8

is

Ibm/gal

is

What

of

obtain

to

5500

You

ft

achieve

and

achieve

WOB and

one- and tions

for

forces

can bit

of

Ibf

start side bit

to

would

side

BHA

drill collars

lbf

for

appro

the

the

to

two-

an

lbm/gal and you

X23/-in.-ID

to

build

will

use

two

first

drill collars

for

BHA

side

calculate

was used

derive

forces

the

tangency

BHA BHAs WOBs of 10000

derive

to

the

bit

shales

at

20

the

the

inclinations

and

point

side

with

bit

OD X2916-in.-ID are

and

10

drill

300

collar under

1/32-in

determine and

side

20000

lbf

73%j_ mud All

bit

97/8-in

and

the

90-Ibm/gal

gauge

60

10000

lbf

20000 lbf

and

BHA

For

and

BHA length

and

length with of

with

length with

an

an

463.4

in

in

the

side

the

of

inclination

inclination

the

the

of

side

force

side

30

side

WOB

force

30 WOB

force

is

741

force

is

10 WOB

of

inclination

of 603.7

of 466.7

an

in

of 609.6

length

BHA

For

WOB

100

is

of

lbf

is

of

723

of

237

10000 lbf

in.

and

sandstones out size

about

is

well

and

the

mation

side

Series

15 at

45000-lbf

5-2-4

limestones

42

bit

at

12

in The

ft/hr

listed

in

ft

cited

where drilled

each

have

TVD

ft

best

should

are

bit

an

follow

the

be

es

and

well

if

angle

hit the

to

3400 ft/hr

at

of

and

target

3450

internal

strength

cohesive

penetra

70 rpm

of

bedding

of

dip

29.0

The

individual

an of

drilling

speed

friction

with

milltooth

your plan

the

formation

deter

explain

ft

which

after rotary

shows

cohesive

variable

at

ft

be

accomplish

to

Hole

Example

in

should

is

target

TVD

ft

those

as

plan

drilling

15100

location

ahead

at

75

to

new

is

4000 for the

155

develop

is

BHAs

drilling

400 The

location

would

same

the

plan

information

and

for

the to

ft

The top of the

depth

be

the

Design

increased

core

15.0

to

156B

total

was experienced

rate

asked

trajectory

You

surface

see Fig

location

where the surface

State the

8.45

Fig

and

sizes

casing

offset

0.50/1000

to

must

location

been

in

to

to

You

ft

each

bottomhole

the

Target

14000

Table

in

at

You

8.87

at

the well

for

8.44

than

22000

to

Calculate the dip

coordinates

Table

less

drillstring

your selections

for

Fig

test

deep the

by

ft and

18500

to

Design conditions

exploration

ft followed

be

will

of Well

maintain

hole

The hole

fl/hr

22000-ft

The well

ft

at

4000

to

12 -in

operating

1/1000

drill

hole

give reasons

to

dolomite

to

ft

north

forces

forces

8.86

and

shales

No

8.138

and

26-in

22000 ft

bits and

depth

hit

bit

and

ft/hr

3500-lbf Fig 8.142 No 8-in Series 6-1-7 bit 22 incli

14500

to

to

300

BHAs

timate

Fig

planning

are

hole

8.156A

and

60

BHD

assembly

with

8-in hole

have

No

8.136

12V4-in at

l2%-in

limestone and

starting

17-in

tal

Fig

wedge was found

core

the

strength

equation

rp1AB 2apt

of

250 lbf

20000

gumbo 13

to

elliptical

siltstone

drilling

drilling

to

of

is

assembly

gauge 8.85 You

angle of

inclination

12

is

washing

sandstones

nation

current

an

is

assembly

60-rpm speed

of

60-rpm speed

soft

drilling

90-rpm speed

WOB

to

decision

drilling

size

fol

the

for

gauge

is

Offset

with

rotary

assembly

Hole

ft/hr

hole

Dropping

tion

BHA

es

your

Fig 8.136 No l10-rpm speed 17-in Series

75-rpm speed

clination

break

For

place

and

your

WOB

overgauge building

drilling

Holding

WOB

is

for

inclination

inclination 300

The

ft/hr

8.88

lbf

bit

building

your strategy

Answer

WOB

tendency

reasons

give

WOB

to

inclination

mine

30

collars and

bit-walking

slightly

20

70-ft

8.33

60

exact

in.

were

three

following

of

stabilizers

is

30000-lbfWOB

the

equa

directional

your

sizes

drill

10000-lbf

1-1-5

35000-lbf 5-1-4

ft

as

three-stabilizer

at

the

and

assembly

Hole

shale

force

use

be

20

at

force

30000

and

of

BHA

two-stabilizer

8.82 For

Determine

Series

well

TVD

at

l4A in throughout

10.5

same method

to

ft

better

What

is

is

8-in.-OD

of the

necessary

force

size

stabiliz

first

single-stabilizer

be

it

X23/16-in.-JD

the

Using

4500 use

Would

weight

twelve

the remainder

8.81

of

assembly

The hole

9-in.-OD

stands

that

lbf

you between 15000

build

mud

the

portion

rig

WOBs

it

collar

operating conditionsi.e

the

Slick

hole

slant-hole

or

if

directional

8500

2500

used

drill

to

State

number of

situations

97/8-in

solu

in the is

same

the

of

ft

bit

the

departure

100

building

above

high-angle

100 ft can

your

at the

stabilizer

ft

are

drill

need

you

3.5

stabilizer

six

have

If

with

drill

priate

to

build of

achieve

to

344

and

horizontal

inclination

second

parameters

desired

is

force

side

if

gauge

All other It

the

8.78

under

8.80

be

will

Problem

A2-in

er

8.84

25

8.79 tion

8.12

stabilizers

lowing

force

side

drill

Mud

gauge

The

where should

lbf

100-lbf

316-in.-ID

bit force

97/8-in

formation

the

assuming

by

in

is

with

ft

If

maintain

to

734 -in.-OD

stabilizer

15

to

build angle

and

lbf

7450

at

drilling

bit to

stabilizer

Problem

speed

depth

WOBs WOB will

BHAs

the

all

Design

for

timate of

1214

is

this

what

At

ft

with

again

45000 lbf

and

and

force

build or drop

1650

at

26-in.-ID

by

wells

ment of

diameter

8-in.-OD

load

Single-stabilizer

was

causing

with

joint

8.83

drill

the

angle

8.78

the

tool

constant

at

471

slant-hole

Assume

the formation

If

the

30000

inclination is

each

with

is

collars

with

lbm/gal

along

thirty-six

will

lbf

drilled

drilling

CONTROL

DEVIATION

12.8

lbm/gal

have

20000

of

are

10.2

you

minum

was is

inclination

is

in and

well

weight

distributed

equally

8.77

AND

DRILLING

where

and

rameter

are empirical and

constant

For

the bedding

and

mum

Tests

where

planes

show

Determine

is

the

the

constants

cohesive

rock

is

orientation

angle

strength

mini

is

A6035 B2035 a30

whether

the

tendency

is

to

pa

between

drill

and

updip

APPLIED

472

or

Answer

downdip of

side

8.89

from

ctdh

600

Refer

be

leviate

the

about

said

8.90

70

the

Refer

to

F2F1/F

that

wedge

curve

Problem

8.88

for

the

formation

tooth

24

chips

al

can

be

variance

strength

from

00

90

to

H.M

Oil and

Gas

28

Jr

tion

Pet

Eng

and

B.V

Randall

March

J.E Harvey R.P

of Various

Directional Survey

SR

An

G.J

Wilson

Survey H.L

Taylor

and

Calculations

Millheim

K.K

and

and Three 8339

and

Las

Vegas

How

Lubinski

SPE

1979

Approach

243 Well

to

Post Analysis

Annual

Technical

31

Bradley tion

That

Is

SPE

paper

Conference

and

Gearhart

MWD 10

World

Feb

Oil

K.H

Report

O.M

Knight

Dec

Tech

Prod

1982

Mud

G.W and DeWardt J.P Survey Accuracy Improved New Small OD Gyro World Oil March 1983 6166 C.J.M

Wolff

and

Cagle

al Casing

et

Measuring

Model

Error

Systematic

J.P

DeWardt of

Sidetracks

Borehole

Methods

Pet

and Well

MB

velopment of

posium

1978 14

TM

Warren

Tech

Pet

IS

firms Baker

the

GmbH

Products

Diamond

Factors

Tech Made

Affecting

and

Dec Easy

Derivation

of

233950

1981

Pet Eng

of

Deviation 251

Pet

TM

paper

for

Torque

and

on-Bit

17

Annual

Oct

58

Technical

Feenstra

and

Directional

Roller

in

presented Exhibition

De Sym

at

With

An

SPE

1982

the

New

Orleans

Millheim series

Jiazhi

W.A

Exhibition

Technique

Drilling

Directional

Nov

beginning

Bottorrthole

Column

and

paper

the

San

for

Sept

Theory

ternational

Weight-

1984

Association

International

1983

the

Francisco

Continuously

at the

presented

March 1921 Woods H.B How to Determine Size Oil and Gas June 1954

K.K

Meeting

paper on

Drilling 1978

Assembly

SPE

10561

Petroleum

1922

rotor diameter

DMN

Timoshenko

22

Co Inc New York City 1936 Walker H.B Downhole Assembly World

Oil

June

1977

of

Elastic

5965

of

steel

md

in

Nov

drilipipe

factor

deflection

compass

increment

depth total

measured depth

new

measured depth

Dtur

direction

measured depth

total

of

depth

D2

wedge

TVD

at

rotor

eccentricity

end

to

target

penetration

of

the

buildup

section

Youngs modulus

EM

hydraulic

efficiency

mechanical

efficiency

ER

Earths spin vector

Drill of

Fc

correction

Fd

ratio

FB

side

FR

factor

and

and

Oil

ending

Problems

Gas

at the

Engineering

Stability

Design

of

section Oil-

1979

by

Beam-

Beijing

McGraw-Hill

Increases

the

SPE In

HM LIHM

March

Book

ROP

line

section

vs

curvature

bit

magnetic strength

field

of

angle

of

index

setting

axial

straight

ratios

of vane

height

eight-

OD/ID

bit

modulus

resultant

12

1982

at

and

10405

Feb

factor

drillpipe

force

shear Best Hole

Solved

presented

of

the

index

moment

moment clearance

of

magnetic

error

field

change

of

inertia

inertia

between

bit

and

drill

Natur

Trans

of Penetra

Wedge

the

Eng

in

1321

diameter

stake

is

21

Theory

13

area

correction

dr

Bit

Lift

Hydraulic

and

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Rock

area

actual

Contractors

Drilling

Lubinskj

part

paper

of

From

Forces

drillpipe

bit

and

Cone

the True Determining SPE 11950 presented at

Conference

Kamp

1971

force

TM

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Technology

Drill

20

Warren Diamond Bits

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well

19

for

SPE

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18

and

Winters

Anisotropy

Strength

Nov

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Porous

correction

intercardinal

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2629 16

Deviation

db

Eh

Variations

10960

Conference

Rock

Tech

Anisotropic

buoyancy

DM

Zaved

Forces Arising

36366

1977

Bc

Sept

150008

SPE

Deviation Anisotropic

Role

W.B

Condi

Ucheb

Vyssh

depth

GmbH Christensen Diamond GmbH Celle FOR Sept

Tools

Deviation

of Geological

Izv

of an

399

cross-sectional

Inspection

1984

Warren

Bits

Technical

nual

Oil

Vetco

Sept and

Winters

and

J.B

Indentation

of

Hole

106

Cheatham

A5

LID

Position

Down-Hole MotorsTechnological Status Trends paper presented at the 7th International

JUrgens

Effects

in Russian

ASME Series R.T The

Failure

Control

Helps

Shandalov

1961 and

1976 13

Concept

Deviation

Tooth

Bit

Bit

internal

is

Drill

Trans

11316

Pulse

2301-06

1981

Uttecht

UncertaintyAnalysis

12

and

Pet

Diamond

Christensen

GmbH

lnspection

Zierner

Systems

by

11

GmbH

Tools

Oil

Vetco

and

4453

Nomenclature

corr

firms Baker

GmbH

Deviation

1966

area

Dogleg

95104

the

March

Cost

Their

and

Data Diagram Drilling Handbook Editions Technip Paris 1978 334 338 Eickelberg et al Controlled Directional Drilling Instruments and Tools paper at the 9th presented International Symposium

ucts

Cheatham

of

Prod

171

163-64

109399

Ragland

of

Worth

16768 J.B Jr Hole

Angle

Drill and

Techniques

Program

Assembly

Hole

AIME

Directional

AIME

Trans

Dec

Tech

the

Affecting

Holes

Straight

1959

McLaniore

2326

Sept

Severe

Computing

Eng

Utilizing

30

Pet

Boreholes

Rotary

Soc Pet Eng

New

Razved

Smith

al

Dec 1972 474-88 H.B Evaluating Zaremba

Pet

F.H

for

To Model

93543

1972

Systematic

Bottombole

at the

presented

1957

on

Trans

Comparison

an Approach

871-76

CM

Gubler

Dimensional

Exhibition

1968

Directional Wells

Planning

and

Aug

Soc

H.D

Eddy

Method

Aug

Mason

Surveying

and

Models

Improved

Pet Tech

Survey

29

and

1965

Sultanov

Single

Tech

Pet

Analysis

Calcula

1976

Walstrom

Error

Directional

of Bottomhole

Effect

Bit

237

Oil

Geol

J.T

Nov

Behavior

Knapp

tions

References

in

Dog-legging

CE

Murphey

AIME 27

The of

Trajectory

1953 22242 Are and

Rollins

World

Craig

and

API

Prac 25

the

Woods H.B Factors

and

Lubinski Inclination

should

MC

Apostal on

232338

String

dips

and

Dynamics

the

26 Plot

K.K

Millheim

1981

of

for

What

problem

23

Assembly

range

symmetrical

60

hole deviation

natural

over

updip

upward

OfF2Fl/Fmin

with

bit

the

deviate

that

indicates

formed and

should

Note

on

form

should

values

the

zero This

are

wedge

160

30

to

hole

the

Fig

to

should

chip

and

hole

the

ENGINEERING

DRILLING

collar

1973

DIRECTIONAL

AND

DRILLING

north/south in

change course

Lr

LT

new

bit

of

teeth

on

stator

teeth

on

rotor

rotor

in

across

internal

the

bit

angle

Metric

plane of

internal

wedge

3.785

412

hp in

7.460

43

2.54

ibf

4.448

Wb

weight

on

bit

change

in

weight

of

Earths

spin

rate ft

Wc

weight

of

mud

the

ibm/cu on

bit

Conversion

390

E01

026

02

846 264

psi

6.894

757

in

6.451

factor

is

exact

E0l E03 E03 E0l E00

1.459

1.198

sq

Factors

4.788 1.601

ft

along

the anisotropic

E00

Ibmlgal

collars

weight

departure

of

222

arc length

zWb

rock

half-angle

gal

coordinate

component

anisotropic

friction

818

ibf/sq

Wm

the

1.355

ft-lbf

curvature

horizontal

angle

failure

3.048

lbf/ft

Te

of

Conversion ft

displacement

east/west

of

strength

included

pressure

rate

of

inclination ratio

pressure

pitch

circulation

azimuth

rock

pressures

SI

specific

in

the

bit

driilpipe

standpipe

on

pitch

stator

radius

load

standpipe

drilled-off

change

severity

maximum

shear

drop

buildup angle

efficiency

stages

or compressive

off-bottom

of

angle

Poissons

pressure

bottom

angle

angle

change

speed

axial

to

azimuth

lobes or

change

blade

dogleg

number of lobes or

pressure drop

5DC

the

angle

tool-face

-y

at

relative

angle

inclination

overall

moment

Lp

ob

section

generated

Pb

Pdo

inclination

length

bending

dip

hole

measured surveys

between

arc

tangency

bit

bedding

exit

of

number of

Pb

adh

length

lead

length

number

Nb

coordinate drilipipe

length

torque

Mb

473

lead

rotor stator

LD

CONTROL

DEVIATION

E0i E02 E00

E00

kJ

m3

kW cm N/rn

kPa kg/rn3 kg/rn3

kPa cm2

Appendix

of Equations for

Development

Non-Newtonian Liquids Rotational

Bingham fluid

follows

Newtonian is

stress

torque

stress

at

of

the

the

fluid

main

and

solid

As

varies

inversely stress

stress

at

yield

at

shear

the

the

The

by

means

when

the

flow

of

is

so

than

increased also

to

in

r2

df

re the

greater

model

plastic

than

the

yield

for

point

is

dw dr

this

.r dr

the

and

viscosity

in

with

pounds force per 100 sq 300

to ft

field

values

the

the

changing

units

Bingham

generally at

the for

plastic

apply the

the

fluid

which given

the

that

only

rotor valid

300-

r1

of centipoise

of and

yields

300

0N

A-2b

Two

stress

readings

viseometer

are

to

used

must

solve

and

ties

for

be the

Normally

Substituting

the

made

with

the

two unknown 300- and

these values

in

rotational

fluid

600-rpm

Eq

proper readings

A-2b gives

is

for

and

follows

shear

of units

occur and

following

and

is

in

Eq

for

and

4.2

the

300 ________ 300

300 ______

300

3OOi

300

the is

and

by

4.45

0600

600

yields

Solving

360.5

A-l 2rhr3jL

dr

27rN/60

Table point

yield

600 equation

at

yields

r3

the value

shown

and

TTy /ApY Combining

the

A-2a

Substituting

r2

IAp

Bingham

A-i

of

and w2

r1

so

than

will

viscometer

slurries

point

360.5

2irhjz

shear

the

bob

the

the

assumption

600-rpm rotor speeds The shear stress at any

Eq

at

If

stress

that

further

greater

the

bob

the

will

shear

the

between

follow

cement

in

walls

the

zero

/1

rotational

This and

separating variables

point

attached

greater is

developed that

at is

velocity

if

occur

fluid

flow

between

fully fluids

4.45

rotor

region

fluids

the

of the radius

fluid

entire

model

Eq

always

the

equations

characterizing

developed

at

of

body

rigid

square is

occurs

slip

angular

movement

the torque

If

stress

of

point

drilling

bob

the

yield

will

the

r2 Thus

shear

the

the

movement

as

the

than

less

portion

from

seen

with

that

no

that

viscometer

the

Initially

such

that

but

move

the rotor

throughout rotor

be

particles

rotor

fluid

so

bob

will

can

shear

the

fluid the

is

no

increased

near the

rotor

that

then

ii

is

occur

the to

applied

is

until

down

break

to

Assuming

unlike

shear

to

begin

enough

large

model

plastic

and

yield

inner cylinder

the

torque

will

is

between

forces

small

Bingham

not

that

applied

cohesive

the

will

fluid

Viscometer

Model

Plastic

that

in

viscosity

tions

these and

two equations yield

point

simultaneously

leads

to

the

for

following

plastic

equa

APPENDIX 475

ipOJO3J

A-3

The

ion

TyO3OO.Lp

A-4

shear

if

standard is

viscosity dial

obtained from

reading

from

the

by

plastic

by

300-rpm

used

is

spring

simply

the

obtained

is

point

torsion

the

subtracting

dial

and

reading

the

subtracting

the

the

which

yield

reading

and

gel

static

Bingham

rotor

speed

speed

of

600

point

of

yield

A-i

of 300

rotational

fluid

plastic

rpm and

rpm

viscometer dial

gives dial

Compute

contain

reading of 12

reading of 20

the

plastic

at

viscosity

structure

at

begins

rotor

using

usually

and

Eq

gel

4.45

However

do

tend

and

fluid

evaluated

after

movement

be

related

bob

at the

specified at

rotor the

dial

gel

bob

the

near

to the

radius

static

measure

done by turning the dial reading at which

can

strength

at

fluids

left

to

is

the

noting

point

stress

if

practice

fluid

drilling

This

closely

drilling

gel

to

to

cement

yield

shear

the

common

is

of

broken

is

The

It

period

speed

with

values

and

computed

cx

an

is

model

plastic

the

begins

time

strength

waiting

slow

ing

of

Bingham

correspond

slurries

A-4 stress

fluids

drilling

Thus

movement

period

the

not

Eq

600-rpm shear

the

shear

does

cement

for

follow

of

fluid

and

zero Usually

not

rates

generally

viscosity

Example Problem

do

low

at

600-rpm

dial

300-rpm

plastic

300-

the

of

rate

slurries

Thus

of

from

computed

point

yield

trapolat

reading

1.725

of

and

fluid

the

360.5

5.08

Solution

The

plastic

is

viscosity

given

by

Eq A-3

/2p20l28cp The

yield

point

is

1284

given

per 100 sq

Eq A-4

by

Bingham be

obtained

can

by

to

at

fluid

given

Eq

using

be rearranged

in

present

model

plastic

A-i

and

that

speed

A-2a

follows

of

rotation

the

the

can

A-2a

Equation

in

1\

1.06

Ir

/1

Eq

with

A-l

yields

low

at

caused

by

lower

than

600

or

100-

2r3_

the

the

point

that

body of for

2irN/60 and

viscosity

pounds

values

foree

yield

w2

point

per 100

sq

ft

to

and

shown

and

changing

field

units

of

in

Table

the

4.2

units

centipoise

of

di

dr

in

rate

5.066N r2

is

six-speed

3-

not

so

stan gel

reading

the

factor

follow

Eqs

the

the

applies fluid

stress

A-3 and

A-4

be

obtained

bob

and

Eq

rotor

the

to

fluid

Thus we

be

by

360.58

be rearranged

42izr

ln

irh

479

A-5

r12

r22

may

not

rotor r2

give

r2/r1

is

of

is

if

known

will

not

apply

assumption

have

to

rotor

may

pur

low shear rates

estimated

speed

at

can at

the

A-2b the

at that

the

the

this

can

in

or

readings

be

for

which

attached

of the fluid

A-2a can

dial

is

can

also

point

Equations

valid

is

300

at

readings

thus

above flow

rate

much

be

viscometer

yield

6-rpm

shear

will

viscometer

Eq A-2b However and

the

rotational

and

and

dial

between fully

rotational

viscosity

the

to

in

360.5

3.174

do

annulus

and

Eq given

1.0

the

dial

so

Usually the

3.174

shear

The

precisely

2Thr22

r3

the

point

yields

rji

Thus

shear

the

4.9

_____ dr

r1 r2

for

shear

rate

from

speed

developed

of flow

If

use of

flow

rotor

_i

the

to

equal ft

sq

often

quite

shear

200-rpm

developed

rliP value

very

to

significant

plastic

similar

through

4lnr2/r1

Using

per 100

made

rates

rpm

and

pose

r12

the

the

of pounds

containing

numerically

fluids

viscous

computed

r12

is

be

drilling

available

dr

units

truncated

is

viscometer

force

not considered

is

rectly

equation

field

usually

of

spring pounds

cannot

generally

1.06

factor

reading

torsion

Since

ln

this

to

Bingham plastic model at low shear rates plastic viscosi values ty and yield point obtained from the 300- and 600-rpm dial readings may not characterize the fluid cor

360.5

Combining

dial

strength

give

7rhli

units

A-6b the

practice

dard rate

stress

yields

ft

sq

In

shear

ft

Tgl.OO

lbf/100

that

The

shear

the

Converting force

A-6a

.72452

2T3.801

the

The

disappear

equal

to

the

be

The fully yield rigid

when yield

APPUED

476

Combining

two

these

angular velocity

and

equations

for

solving

rotor

the

300 rpm

of

speed

deviate

yields

from

greatly

Normally In

2k the

Using

and

pounds

for

r1

and to

point

per 100

ft

sq

in

Table

field

units

4.2

the

changing

from

taken

of centipoise

of

2ir300

does

not that

and dial

300

at

in

and

units

bob

seconds

index

two readings

these

the

at

511

fluid

obtained

are

rate

of

consistency

viscometer

Substituting

shown

r2

for

yield

force

and

the

index

rotational

2irN/60

viscosity

r2/ri.....

r1

values

value

the

behavior

A-7a

shear value

Newtonian

to

corresponds

the

the

ENGINEERING

DRILLING

Eq

flow-

readings of

600

and

A- 10

rpm

yields

360.5

and 60

2irhK

yields

tn\1 N20.6-2-

\1

A-7b

\r2/nj and

Since

the

model

plastic

obtain

in

use

and

shear the

of shear

rates

estimate of

often

is

it

the

the

Bingham difficult

proper value

of

to

2ir600 60

in

of

power-law

rotational

fluid

visconleter

between is

given

L7n7Jj

by the

Dividing

dr

Combining

for

solving

model

of

fluid

Eq

behaviorwith

second

equation

the

by

flow-behavior

the

n3322

this

060J\

2irhK

bob

the

do.\

rK

360.5

yield

Model

stress

rotor

follow

not

may

Eq A-7b

Power-Law The

low

at

meaningful to

point

fluid

drilling

first

index

and

equation

gives

iogOIO3

A-12

4.45 the

Solving

yields

first

for

equation

the

index

consistency

gives

360.50 15.1

Kr1

Separating at r1

is

0.2094300

the

noting

angular

of the rotor

w2

that

velocity

the

angular

at r2

is

velocity

the angular

we obtain

At

glance

first

from

puting

/360.5

dw

fl\

fl

ri

and

variables

zero and

velocity

A-8

\drl

27rhr2

I/fl

dr

However

plex

A-9

2rhK

denominator

that

appears

it

the viscometer

of

note

this

dial

that

relation

readings the

if

are

equation

the

is

com com

for quite

numerator

and

multiplied by

1r1

then of

Integration

this

/360.5

_____

equation In

0\

71\2

gives

03 15.l_ \r1

/\/

300

2irhK It

A-b

shown

be

can

values

close

seconds

Eq

A-b

be

can

to

rearranged

Using

give substituting

the

5.1

0300

2w2

360.501/n \2ThK

Combining 27rN/60

for

this

w2

with

equation and

solving

0.2094N

for

Eq

A-8

the shear

substituting

rate

where

has

timeter

If

cm2

yields

510

\r2 nI

Similarly

2/n

second

value

drilling

of

for

at

300

value

in

the

shown

forr1

rpm

equation Table

in

fluids shear this

generally rate

range

is

of

has

value

not very values

between

511

above

and

4.2

yields

A-13a

For

example

of dynes

units

desired

is

per seconds

in

dynes

centipoise

then

per is

per square

second given

per

cen 100

by

0300

if

A-13b

is

per square

desired feet

in

then

units

of

Kis given

pounds

force

per

by

0.5 0.0106

sensitive

for

to

equal

511

A-il

1.0 The

rate

approximately

is

this

value

or equivalent

_.......

dr

For

the shear

Sun

dj

and

that

one

to

to

the at

511

0300

A-13c

Appendix

Development of

Annular Flow for Non-Newtonian Fluids

for

Bingham

Plastic

Developing

flow

Model

stress

less

than

down

the

conduit

plug

Ya

the

Also

the

Fig B-i

shear

in

stress

having

At

slot

fluid

move

the

must

Ta

stress

plastic

the

must

point

yield

Bingham of

portions

the

shear

for

equations

because

complicated

Eq

Flow Approximations

Slot

must

as

layer

be

used

to

B-3a

the

according

must

be given

of

velocity

given

and

dp/dL

by

YYa

B-3b

the

B-3b

Eq

plug

The

be

can

region

YYa

at

obtained of

velocity

the

by

plug

is

by

B-l

TaTyToYajj

Tb

of ya

dL

to

dp

outer

terms

be expressed

dpf

The

the

can

v-y22yay evaluating

at

in

also

plug

of

4.57 Thus

Likewise

rr

express

Thus Eq

to

equal

behave

is

shear

rigid

inner be

fluid

of

layer

the

shear

the

plug

stress

Ya

aPf

2z

dL

bYYa

B-3c

by In

the

the

dp

fluid

region

Bingham model

the

enclosing is

defined by

outer

Eq

of

layer

4.41a

the

plug

Thus

B-2 dv

dpf T0

In

the

plug the

the

shear

fluid

region

enclosed

Bingham model stress

defined by

is

in this fluid

by

the

region

is

inner

Eq

given

layer

4.41c

of

Thus

by

After separating following

dv

dL

dy

the

and

variables

expression

for fluid

we

integrating

obtain

the

velocity

dp

r0ry

T0

dL

dy

B-4a

dL After the

variables

separating

following

expression

v-y2

dp

for

constant

veinrity

is

of

known

we

integrating

obtain

velocity

The

TyToY

integration to

he

ern

this

vU

v0

B-3a

must

be

zero

since

the

Po

Wi

qn

T0

of

constant

boundary

dL

The

and fluid

integration

condition

condition

to

Eq

of

zero

B-4a

yields

ufl

dL

dL

can

be

evaluated

velocity

and

using

at

yh

Eq

B-2

using

the

Applying to

define

478

APPLIED

Fig

this

Solving

expression

vh

for

B-iLaminar

flow

of

Bingham

gives

dp1

B-5 dL

dp1

2Ybh

dL

this

Substituting

simplifying

The

expression

for

into

Eq

B-4a

and

dpj

2p

yy

2yby2ybh

dL

Each and

B-4b

plug

of

velocity

the

evaluated

given

is

Yb2

vp

also

plug region at

YYb

Thus

must be the

given

by

of

the

velocity

2Ybhh2 dL

of the

vdy

first

three

summed is

required

Eqs

wvdy

B-3c

Integration

of

this

r0 and

dL

this

T0T2

70r2

dpf\2 \dLJ

dpj\2 \w.J

Solving

this

on the

the

the

flow

improper Integrating

can

right

be

evaluated

However

rate integral

on

by

gives

parts

the

less

left

is

_hYidY

2YaydY

2y2

equation

2y2 2ybydy

gives

and B-4c gives

equation

expression

2r0rh

the

this

Yb

equation

Eqs B-l B-2 and

B-5

in

terms

of

and

using

yields

1l__2_ q.L 2r 2\r0 l2

B-6a

dL

\ii for

g_

becomes Expressing

yields

defined by

is

dy Wvdy

_.fhydvdy_.O

Wdp1I

Yb2 2ybhh2

terms of

if

by parts

dp1

In

slot

wv

integrals

obtain

to

integrated

YbYy B-4c

Ya2

the

through

by

2jtLp

Equating

rate

qWvdy

algebra

Eq B4b

flow

total

yields

vh2 The

slot

in

plastic

ENGINEERING

DRILLING

shear

stress

at

For

the

conditions

applications

usually

the shear

encountered

stress

at the

in rotary

wall To

is

drilling

more than

APPENDIX

479

B-2Laminar

Fig

twice the be

without

this

Dmpping given

by

and

point

yield

neglected

Eq

term and B-5

the

term

last

introducing

Eq

B-6

of

can

significant

error

expression

for

the

substituting

in

flow

r0

yields

q---T l2 W7z

the

4.55a

and

with

in

the

of

the

must move

B-2

At the

of the

to

down

the

yield

Fig

stress

Also

must behave

of

center of

than

shear

the

rp

the

the conduit

point

yield

tube

circular

plug

the

less

stress

the case

in

near

flowing

plug

rigid

As

equation

fluid

shear

as

radius

equal

the

have

that

point

in

flow

slot

of

portions

the conduit

pipe

shear

the to

according

Eq

4.51 Thus for

expressions 4.55b

fluid

derivation

slot

stress

dL

Eqs

the

plastic

must be

dp

Combining

Bingham

W7

and

for

given

by

dpc

B-6b gives

Eq

B-7 dL

qr2 ir

dpj

_r12r2__r12

In

the

fluid

dL

Bingham stress

71

Tr22r12r2 r1

region

model

in this

fluid

the

velocity dient

13

flow

and

rate

solving

in

for

terms

the

l2jz

of

mean

flow

pressure

gra

the

frictional

field feet

we

units

per

fmm

consistent

of pounds

second

units

per square

inches

and

to

by

rdp1

pounds

force

4fLp

per

100

sq

plastic

of

constant

Substituting

of

fluids

through

for

the

pipe

is

integration

condition this

laminar quite

Ty

flow of

similar

to

4/Lp

dL

of

boundary

B-e

200d2d1

equations

obtain

the

velocity

dL

upf the

we

integrating

fluid

ft

Ty

The derivation

for

centipoise

The

l000d2d12

and

variables

expressions

B-8a

more convenient

inch per foot

boundary

Bingham

the

shear

B-6d

r2r1

obtain

dL

the

2dL

dr

following

3r

13

r2r12

Converting

Thus

T1LpTv After separating

dL

given

plug

circular

4.41a

gives

dpf/dL

dpf

is

region

Eq

by

B-c dv

Expressing

the

enclosing

defined

is

lip

zero

is

obtained at

velocity

condition

in

the

Eq

using pipe

B-8a

the

wall

gives

480

APPLIED DRILLING

this

Solving

for

equation

gives

twice be

---

Substituting

this

for

expression

vr2 dpf

4/UdL

Eq

in

vt

B-8a

without

Eq

by

ivr4

yields

term

this

given

rr

dL

3/U

for

of

r3 given

rrp

the

B-8b

plug

region

be

can

rr

at

Eq

by

B-9a

the

at

can

error

significant

for

expression

yields

B-9b

B-7

Eq

into

obtained the

Substituting

B-8b

and

flow

the

and

velocity dient

Eq

Eq

in

term

substituting

evaluated

il73

/2

velocity

last

r2--2--rr

B-8b

evaluating

and

4.61

the

introducing

dpf

Expressing

The

and

point

yield

Dropping

T__r

dL

4/2

the

neglected

ENGINEERING

rate

terms

in

for

solving

the

of

mean

the

frictional

flow

pressure

gra

gives

dpf/dL

by

expression

dpf

87y

81.ipi

B-9c

at

evaluating

yields

r2

dL

4/2

from

Converting

dp

B-8c

of

units

field

second

per

consistent

pounds and

inches

units

force

pounds

more convenient

to

inch

per square

feet

centipoise per 100

we

ft

sq

obtain

The

total

flow

rate

the

through

pipe

is

defined by

ji

dpj

B-9d

dv

q3

vrdrn- Vj

vdA2ir3

dL

r2dr

ir

l500d2

225d

dr

The term

zero

is

r0 and

at

The

rr

Also

at

the

in-

wall wall

tegral

shear

can

rate

be

and

the

Bingham

plastic

from

shear

the

frictional

appropriate

For

equation

in

obtained

circular

fluid stress

at

the

pipe

at

the

pipe

pressure

gradient

pipe

dv

r2dr dr

Yw is

zero is

rate

because given

dvfdr

Thus

for

the

CT

dpj-

of

this

equation

IV

Eqs

this

4.61

and

7rr4

in

equation

B-7

terms

of

and

using

this

Poiseuille

law

for the

This the

means

yield

For

the

that

point

to

the

shear

cause

conditions

ing applications

the

to

equal term

in

to

the

familiar

zero Note brackets

stress

at

the

also

that

approaches wall

usually

pipe is

given

encountered at

the

as

is

force

per 100

units

feet

per

to

see

we obtain

sq ft

B-to

Similarly

for

annulus

an

the

shear

rate

by

r2r1

l2/2V

r2r12

j2

After simplifying

and

changing

to

field

units

we

obtain

zero l44v

must exceed

in rotary

wall

consistent

r2rjJ

d2d1

stress

pounds

from

of seconds

Hagen

flow

shear

wall

dL

B-9a reduces

and

dp1

\rw

\.rJ

expression

approaches

for circular

rY\l ry\4

11

rr0 that

inches

at the

dL

Note

units

field

r__1S9.7L

yields

dpf

changing

more convenient

96i

r3

dL

Expressing

After simplifying and

ond

irr

dpf

2dL

r2dr

gives

q-r4

Ty

i2

r3dr-71Ty

dL

Integration

dpf

---

flow

by

ql iv

zero

is

TT

drill

more than

for the

annulus

239 5-

B-i

APPENDIX

481

Fig

Power-Law The

annular

tions

for

fluid

in

flow

of

power-law

fluid

slot

in

Model flow

proximated

B-3.-Laminar

of

closely

narrow

the

The

slot

narrow

fluids

power-law

using

slot

shear

given

is

can

also

stress

ap

vo

\2

dpfLKdL 1/n

equa

dL

for

power-law

Eqs 4.42

by

be

flow

less-complex

4.57

and

B-12a

4.58 The constant

dv\

rK

dv

the boundary

----I

II

dy

of integration

n-I

condition

that

can

v0

v0

evaluated

using

dy

fh

dpf

be

yO

at

\lI-I-1/n

vo

T0

1dPfLKdL dL

As

discussed

used

to

B-3 we

shear

in

distance

and

geometry

is

that

flow

for

of

the

is

of

theological

by

zero

Bingham

linearly

consequence

Also

slot

and

changes

is

independent the

Newtonian

stress

slot This

describe see

for

previously

models

plastic

inspection

yh/2

at

the

with

Solving

flow

yields

for

and

v0

dv

dL

dL

shown

hi2yh

B-12a

\l1/n

11IL

ll/flLK

dL

is

Eq

Fig

dpj

dv/dy

in

Thus

T0

as

result

models of

-K

Also

the

substituting

in

positive

This

B-3

Fig for

means

the

h/2 that

absolute

the

gradient

velocity

and

is

negative

dpfh\lI/n

for

KdL2J

value

n--I

This expression

can

be

to

simplified

dy

does the

not

have

shear

over shear

stress

each

first

must

equation

half of

stress

TKI

continuous

the

equation

slot can

be

For

derivative he

integrated

the

h/2

simplified

yh/2

dpf\

and

dL

piecewise region

11/n

-v

The flow the

total

rate

flow

B-12b

0yh/2

in the

rate

is

dpf

2dL variables

given

h/2

and

integrating

11/n

\2

0yh/2

q/2vdAW Separating

HI L\2

11/n

the

/dv\

dpf

I/n

to

dy

dL

at

gives

vdy

by

region

which

is

half

of

482

APPLIED

where v0

-LYn

j_

dL

the

11/n

h/21/h\

velocity

Eq

to

integration

Since

B-15a

to

corresponding

the

for

zero

is

boundary condition

11/n

of

r0

at

velocity

the

walls

constant

the

is

fluid

ENGINEERING

DRILLING

fluid

wets

the

pipe

Applying

this

rr

yields

lI/n

/h

-Y

\2

idPf\I/n dL 2K

I/n

and

Integrating

dp

\K

this

simplifying

equation

1/n

yields

W7l

1/n

Thus

is

v0

given

by

dL

242/n

B-13a

1/n

2K dL

the

Substituting

Eqs 455a

and

for

expressions 4.55b

Eq

into

V0-

and

ftli

for

given

by 1/n

B-13a gives

dpf\l/n 711

\K

Substituting

dL

for

v0

in

Eq

B-15a

yields

2r2r1

r22r1 U2

value

this

I/n

42/n 2K dL B-13b the

velocity

and

dient

dpf/dL

I/fl

rate

in

for

solving

terms the

of

mean

flow

pressure

gra

the

frictional

gives

The flow rate

vdA

is

given

by

v2iurdr

2K42/nt2

dpc

B-14a

r2r1

dL

2KdL from

Converting field

consistent

units

more

to

rw2r_r2dr

convenient

11/n

we obtain

units

Integrating

dpf

Ki

dL

l44000d2d1

this

equation

yields

21/n\n .0.0208

I/fl

ir_Jf 2K dL

11/n

B-14b The

derivation

laminar similar

B-15b

1/n

flow

Expressing

V0

flow to

equation cularpipe

TK

the

pressure

power-law

derivation

The is

31/n of

of

the

shear

given

of

stress

by

for

loss

fluid the

equation

in

slot-flow

power-law

Eqs 4.42 4.51

dv\

dv

rdp ...._J

dr/

dr

2dL

and

pipe

for is

the

quite

pressure-loss fluid

in

and

velocity cir

dient

variables

and

integrating

flow

the

Expressing

dpf/dL

rate

in

for

solving

terms the

of

frictional

the

mean

flow

pressure

gra

gives

4.52

dpj

2KP3

1/n1

B-16b

rw

dL Separating

B-16a

gives from

Converting field

I/n

units

consistent

units

to

more convenient

we obtain

dpf\.1

.2K

dL 1/

rv0

B-iSa

dpj

KiY

dL

l44000d

/3l/n\n B-16c \0.04161

APPENDIX

be

483

The shear

rate

obtained

from

appropriate circular

in the

frictional

power law shear

stress

fluid

at

the

pipe wall can

pipe wall

at the

pressure gradient

equation

and

the

Similarly given

for

an

annulus

the

shear

rate

at

the

wall

is

by

For

pipe 1/n

yw 2K

dL

/w 2K

dL

2K42/n r2r11

2K

I/n

2K3/nn ___________

After

and

simplifying

more convenient

field

__________

changing units

we

from

consistent

units

After simplifying and

changing

more convenient

units

from

consistent

units

to

to

obtain

field

we

obtain

48V21/n B-17

d2d

B-18

Author Index Edwards

1.11

Eenink Althouse

W.S

American

Coldset

199

Production

Co

Amoco

342

Apostal

ARAMCO Nat

Co

17

L.N

Berry

R.F 98 FaulR 111 Faust L.Y 256

224

288

Wi

Bielstein

218

Farris

Fontenot

E.J 222

225

291

395

Foster

292

S.R 446

Knight

O.M

R.B

Bird

115

Inc

Koomey

24

297

111

Lamb

422

I.E 171 J.B 28 283

A.G

Fredrickson

W.M

Laird

144

119

140

Lewis

R.L

268

Logan

J.L

342

Lubinski

326

342

371

372

426

29

292

297

446

144

Lummus J.L

219

MacKay

209

119

222

Blasius

225

Gamier

W.A 27

Wi

Bore

Bourgoyne

AT

Jr 225

219

224

264

265

296

Bowen

Inc

Tools

C.N J.E

Brantly

18018

179 230

233

217

G.H

Burcik

El

115

J.F 250

Butts

H.B

Industries

28

Gearhart

C.M 364 Matthews W.R 279

157

342

290 107

111

156

125

345 309

307

Grim Gubler

R.E 84 F.H 366

W.C 207 208 22 222 G.M 178 179 McClendon M.T 26 262 295

A.B

Metzner

Halliburton

J.M

Campbell

N.L

Carr

214

Cerkovnik

Harris

194

195

Jr.

446

Cheatham

i.B

Chenevert

M.E S.F

Chien

84

177

178

288

Christman

R.C 98 R.E 171

Clark Clark

F.W

Cole

J.T

146

Cullender

Geological

150

152

M.H

147

R.A

366

365

149

222

209

214

Hydril

Co

B.J 214 Corp 266

278

279

Soc

T.B

Dellinger

Myers

G.M

287

288

NL NL NL NL

289

204

Co 215

20

194

196

202

242

.29

Assoc

D.G N.A

Dodge Dodge Doherty

Dowdco Dresser

84

Jiazhi

342

Johnson

152

153

119

137

W.T 200

400

107

of

Well

Oil

Contractors

401

402

176

Jorden

by

429

430

434 436

R.K

277

278

P.H 250 J.R 259

Jones

111

Inc

Manufacturing

iurgens

279

176

84

Baroid

Hycalog

201

200

23

Equipment

Rig

25

Shaffer

26

Nadia

310

Norton

Christensen

Patton

CC

191

192

290

Eckel

J.R

119

129

Eddy

H.D

359

365

291 157

193

199

284

289

Co

261

290

J.L

257

297

232

M.C

Co

250

280

B.V 359 R.L 217

365

C.A

Pratt

256

255 295

Petroleum

Phillips

Powers 260

329

ES

Peterson

280

229

13

412

16

Randall

Kamp

248

180

39

196

B.A

179

201

Industries

Durrett

178

284

280

288

i.P 399

Wardt

437

250

287

H.C.H

Darley

428

267

Murray

365

Pennebaker

A.A

369

224

223

Intl

Daneshy

368

443

T.C 84 P.L 39 176 C.E 446 A.S 209 222

Murphey

277

M.K Tool

366

442

216

R.V

Hughes

176

153

Mondshine

20

Houston

276

B.C

Cunningham

147

153

Oil

310

E.R C.E

Hughes

111

Moore

359

Hottman

Hoover

297

Hubbert

ir 359

Crittendon

292

39

Laboratories

Craig

182

179

291

HOMCO

293

106

40

J.L

Holmquist

111

CF

Colebrook

292

Mobil

87

151

R.P

Harvey 449

176

Services

R.W L.M

Hanks

115

Mitchell

E.L

Haden

226

216

K.K

43844 405

152

J.N

Middleton Millheim

Cagle

289

Maurer

369

368

137

119

288

L.J 268 269 296 39 McCray McLamore R.T 449 450 451 McLean J.C 342 McLean R.H 157

207

S.i 222 225 J.F Jr 300 Grecr i.B 329

251

284

298

297

McClure

K.E

Greendip 169

84

Mayes

J.N 308

Goodman

449

Industries

Mason

387

Goodier

L.A 288 Div Dresser

Magcobar

Gere

115

Burst

Gearhart

S.P

MaePherson

Green

l.A

Burrows

Gatlin

Gray

176

230 223

18

287

217

A.J 222 39 207

J.M 309 Goins W.C Jr

234

39

Bruce

Burkhardt

272

326

W.B

Bradley

297

268

218

Bowers

E.M

Galle

147

Boatman

Eaton

387

144

AD

Black

De

450

286

Birch

Core

157

156

Kobayashi

iC 200

Feenstra

Benit

383

W.A

Knapp

18

85

Aspdin

382

Kendal

443

13

207

Armstrong

379

396 Estes

Supply

224

223

378

Eickelberg 201

M.R 84 119 137 M.C 437 441 442

Annis

217

J.G 222

297

222

Reed

WA

422

231

Rock

RD

329

Rehm

Katz

D.L

115

Reynolds

Kaufman 230

Reed

Kane

Kelly 298

256

279

284

Co

Bit

W.A

261

E.B

289

290

297

Rogers Rollins

272

H.M

446

295

277

145

Reynolds 288

202

262

256

366

450

279

258

INDEX 485

Texas Sabin

K.J

Sample Sariento

179

180

Security

Rock

Security

and

Bits

Drill

Tools

J.F

Wilson 279

429

430

T.R

Sifferman

G.W

399

400

Smith

M.B

449

Young

R.V

147

225

Co

Tool

Speer Spicer

J.W H.C

Standing Stokes Streeter

Sutton

212

214

van

Lingen

Vidder

286 Vidrine

M.B

Sultanov

Sutko

203

156

G.G V.L

N.H

222

Di

222

224

225

Zamora

147

H.A 176 Walker H.B 437 Walker R.E 178 WahI

Walstrom Taylor

H.L

Texaco

Inc

364

West Whalen

218

219

224

264

265

296

234

J.E 359

T.M

SS

A.M

Zapata

Offshore

Ziener

179 365

413

415

281

283

256

H.E

262

Zanier

Zaremba

446

Warren

Jr 217 233

227

115

ill

F.S 230

223

173

161

D.L

446

344

176

Smith Smith

40 230

39

lexas

Uttecht

402

401

G.R

289

416

415

Woods A.B 217 Woods H.B 426

446 261

365

Woodall-Mason

213

of

260

288

G.J 359 C.J.M

Wooley

O.J 259

Shirley

Wolff

176

287

Winters

308

260

286

Shandalov

D.G

Willis

215 Shairer

CE

Williams

40

Timoshenko

TOTCO

26

232

D.J 277 S.P

Timko

256

Works

G.A

JR

Tube

181

F.J 169 Div 203

Schuh

Iron

Tibbitts

111

416

441

279

Co

H.B

K.H

295

277

366

387

368

369

Subject Index Alloys Abbreviations

in

213

condition bit

Abnormal

formation

wear

246

pressure

BOP

pressure

260

gradients

300

Abrasiveness

formation

Absolute

of

method

Accelerator

210

pipe

for

well trajectory

146-148

377

382

log

ITT

Acoustic Acoustic

Additives

cased

wells

hydration

110 383

Calcium

indicator

muds

28 41

definition

of

77

98

control

101

94

Joint

96-98

Joint

97 101

control

93

Radioactive

97

RP RP RP RP

102

96 102

tracers

102

98-100

Retarders

98

time

Slip

98

control

93 94 102 chloride 98 99

Sodium

chromate

flour

Filtration

Adjustable

choke

Adsorptive

332

392 237

lignite

Sid

28 45

of

of 49

61

Tests

363

446

through

106

tubing

Non-Newtonian

for

fluids

477483 Fluid element

Friction

diagram

free-body

for

gradient

pressure

loss

and

line

drilling

casing

of power-law

flow

pipe

fluids

fluid

well

during

slot

in

control

119-122

Pressure

prediction

Pressure

profiles

23

121 119

122

162

24

mean 169

Velocity

effective

Velocity

equivalent

Velocity

mean

170

177

140

155

connectors

of

diameter

166

167

flow

in

149 in

loss

pressure

141

151

141-145

152

165-169 as

Represented Shear

rate

Shear

stress

141-143

slot

wall

at

143

of

profile

144

143

wall

at

American

see

Dispersion Matrix

139

165

Petroleum

Institute

95 99 and

100

other

302

153

relation

Arctic

332

Atlas

wells as

Austenitic

drilling

fluids

well cements

Water

loss

42

86-99

cement

89

47

Weight properties

305

65

389

86

density

Sediment Shale

302

performance

65 92

Average Bulk

92

90

connectors

55 56 steels

Autoclave

126

122

substitute

types

Bradford

data

porosity

porosity for

couplings

249 248

273

casing 303

133

182

181

344

clay

cement

Attapulgite

344

42 44

176

Archimedes

39

255

time

viscosity

152

Asbestos

39

80

rigs

transit

Newtonian

ASTM

strength

of

Non-Newtonian

operations

39

46

101 163

in

150

149

for

181

Apparent

committee

casing

extension

equations

155

caring

liquid

180

pressure

Laminar

40

for

170

Frictional

150

goods

4A 4D 4E

154 162

loss

Frictional

API

Content of

Yield

Cementing

Frictional

for

Water

API

index

Equivalent

cementing

Testing 441

359

76

of oil

point

Velocity

Std

438

method

Annulus

program

cut

Standards

Std 76

250

definition

definition

and

tubular

162

434

of

definition

care

1140

Squeeze

400

indicators

for

330

84

65

437

366

Preventer

lOB 89 111 l3B 84 274 53 25 39

Study

431

328

111

practice

of casing

13A

17

16

327

thread

Bull Sec

Spec

shale

77

pressure

drilling

Algorithms

by

327

310

328

111

80

268-273

BHA

27

averaging

Pressure performance

305

round

strength

lOB

Std

25-27

101

formulas

Spec

128

of water

Adsorption

302

strength

Spec

control

processes

65

Spec

69

piles

data

481

computing

102

66 67 64 65

control

circulation

for

94

61

control

Anchor

Flow

303

fluids

drilling

multistabilizer

logging

477483

45

loss

9B

19

86

cement

press

Spec 101

control

60

specifications

5A 39 SAC 349 SAX 39 9A 39

93

of

Flow

Spec

99

silicate

Chemical

102

Analysis

Geometry

42 43

form

report

Specifications

102

hydrocarbons

for

70

11

Sodium

Viscosity

ratings

33

data

mud

Recommended use

Paraformaldehyde

Alkalinity

cost

Prod

102

Pozzolan

42-53

tests

properties

101

81

lignite

Fluid velocity and

specifications

couplings

circulation

Alkaline

Derrick

Filtration

102

Ilmenite

25-27

310

equations

303-306

Connectors

Formulas

101

Gypsum 98 99 Hematite 93 94

111

80

139

Filter

102

101

93-95

99

and

91

Annular

requirements

arrangements

pressure

Equations

93-96

93-96

perlite

Filtration

Alkaline

manifold

bentonite

mud

Flow

Drillpipe

92-94

earth

Hydrazine

98

89-92 physical

89

of

Anisotropy

48

control

Gilsonite

331

91

Drilling

97

Expanded

Alignment

types

Diagnostic

cements

Diatomaceous

Alaska

classes

Cement

310

Testing

Analysis

364

properties

39

250

chloride

Density

Adiabatic

340

for

ASTM

Amine-treated 100

325

94-96

Bentonite

Density

methods

325

of

10-324

Society

Aniline

Drilling

Additives

95 99

strings

97

Sodium

330

casing

302

Cement

of

of

Amine-treated

Angle

Collapse

method

position in

for

Sante

Silica

308

effect

305-307

Materials

performance

Chock

definition

Settling

Summary

305-330

tools

of water

Sand

of

use

328

325

311

rating

330

329 of

effect

combined

Stress

American

landing

277

solids

Nylon

25

39

Casing

shale

transmission

Activity

Air

and

Casing

in

of

effect

Acoustic-type

Lost

pressure

Casing

logging

Solid

Burst

of

effect

329

24

of

350

386

31

travel

energy

Acoustic

Lost

Dl0

308-310

sulfide

Tension

grade

109

Activity

D7

308

307

pressure

Hydrogen

81

349

Casing

actuators

Acoustic

Active

Bull

Collapse

325-328

of

effect

pressure

Field handling

349

99

45

of

definition

Acoustic

on

56

344-348

23 24

Accumulators Acidic

39

cementing

398-400

149

350

330

Casing

98

Burst

API

arrangement

Bull

Care

calculating

365

cement

for

Accelerometers

219

238

definition

roughness

Acceleration

218

formation

218-220

Constant

Of

Bull

5C1 5C2 5C3

Bull Bull

for

Average

stack

55

Institute

57 58 66-71

Barite

Bending

148

sheet

Petroleum

81

428

of

criteria

octahedral

Airierican

300

250-252

Abnormal

214

213

muds

oil

properties

turbulence

Alumina

Abnormal

247

typical

Alternate

bit

describing

of

control

Alkalinity

threads

and

66

INDEX 487

Axial

force

see

Bits

At

of

top

Change

cement

in

Vs

depth

Axial

load

429

moment strain

Axial

Stress

441

of

wear

Of

of

of

310

123-125

333

213

229

219

Cone

334

340-344 of

definition

325

tension drill

time

Rotating

124

condition

casing

of

339

casing

311

333-335

342

345

347

348

327

328

209

rake

Backup

of bit

casing

Bag-type

194

of swivel

274

216

333

76

method

well

190

221

225

414-417

Diamond

cutter

205

366

365 195

bearing

Baskets

on

Bearing

assemblies failure

Bearing

wear

Factors

for

Grading

194

194

232

198

415

Dull

evaluation

Evaluation Face

cutter

219

bits

220

219

cutter

bits

of

213

209-2

of

torque

219

218

14

374

441

204-209

number

199

198

PCD

192

profiles

226

227

penetration wear

230

Total

231

234

219

213

195

horsepower

229

230 192

217

classification

210

156

157

Life

of

Belgian

212

of 219

220

limestone

238

218

charts

389

421

422

429

Force

Journal

326

in

Bengum

210

rams

Block

and

310

381

403 405

422

427

Bent-sub

373-375 406

414

377 416-418

375

418

366

367

373-377

385

402 403

421

405

381 414

417 418 421 422 427 431 Bentonite 53 55 57 61 64 65 69 72-75 81 89 92-97 100 Berea Bid

sandstone

222

Birigham

plastic

plastic

model

133

134

136-139

155

161

t69

474-481

Biopolymer

wear

Operation

of

430

150

151

101

Orientation

of

Penetration

rate

475

233

42 14-4

261

127

131

150-153

264

130

214

215

156

240

180 259

194

196

198-201

240

efficiency

221

236

403

411 414

Record

side

forces

single-cone data

33-35

430

PCD

23

23

Rotating

25

panel

24

for

24 25

arrangements

29

113

prevention

271

correlation

of casing

strength

cement

in

305

422

437

100 400-402

position assembly

434 inclination

443

for

slick

358

399

angle

BHA 375

438

431

376

436

4-44

Dropping

inclination

General

discussion

377

400

422

426-430

451-453

BHA

236

bit

Configuration

216-218

192

BOP

26

control

Building

190-192

431

11

108

22

of

of

Calculation

415

lines

of

definition

25

yield

for

program

16

Algorithms

226

441 Positive

cut

Bottomhole

260

210

9-11

10

preventers

Above

diamond

Polycrystalline

factors

of

Remote

Borax

221

driller

307

415

366

for

147

definition

Borehole

221

240

23

Definition

Body

240

weight

236

Profiles 65

113

237

450-453 guidelines

line

Stack

129

220

life

236

of

and

Blowout

analysis

236-240

Optimum

477-480 Birigham

Off-center

228

fluid

velocity

68

specifications

434

442 450

selection

235

226-228

445

Ram-type 229

218

429-432

graphical

228

227 233

411 413-417 419 431 433 434

390

squeeze

Boatman size

Optimum

223

241

158-162

Nozzle

406

240

202-204

217

force

of of

efficiency

Blowout

237

197

457

arrangement

Blowout

407

215

441

size

Nozzle

angle

subs

440

Nozzle

431

214 side

Negative

436 366

195

tooth

426

tackle

Internal

212

218

221

211

441

formula

Blind

Bloocy

375-377

196

bearing

214-219

240

Makeup

240

Milled

101

housings

384

Life

25

piping

of casing

Stresses

Bent

432

347

326

casing

Stresses

429

212

198

of

Performance

Slip

406

204

combination

on 217

382

Mechanical

156-162

402 403

TFA

function

Block

373

area

exponent

199-203

241

367

238

Weight

229-232

131

366

211

Weight

Schematic

203

129-131

379

Moment

Bent

202

Jetting

Bending

Of

force

Insert Jet 224

223

Impact

of

359

212 Grading

443-446

207

190-200

Types

Line

218

211

233

of

235

number

Average

425

232

227

variations

Turbine/diamond

Blasius

237

of

teeth

417

413

flow

on 212

226

437-439

Tooth

436-443

240

plastic

431

design

Weight

mechanism

416

239

239

Failure

IADC

roller

427

Walk

of

Hydraulics

240

207

equation

214

194

403

weight

Tooth

Torque

196

cutter

236

229

profiles

192

roller

Threshold

Tooth

192

237

drag

or tn-cone

234

193

422

236

441

Tilt

191

195

232

cutter

422

224

balance

force

Hydraulic

for

guide

403

224

223-225

212

Heel

219

for

236

201

193

221

Gauge wear

roller

Steel

431

216

191

Dull

Guides

220

affecting

Formula

195

bits

213

212

Exponent

198

indicator

216

232

drag

PCD

Floundering

for

bit

for

233

layout

drag

Flat-bottom

212

of

for

Constant

308

105

casing

Bearing

of

450

194

Speed

Typo

Feature

307

equation

Code

57 58 66-71

barite 97

of

F3

Stabilizers

205

433-435

442

of

Smith

Three-

426

199

210

190

Failure

Barlows

232 422

stone

core

198 sulfate

195

199-203

198-201

230

Diamond

Drag

for

trajectory

Ball-type intermediate

81 93 94

194

prevention

of

405

Drag

107

plug

tangential

Barium

of

features

Diamond

204-208

muds

oil

friction

Side rake tooth

422

pressure

calculating

Side

beneath

accidental

Double-cone

23

221

196

on 431

force

437-440 443-446

221

221

Double-blade

17

Balanced-activity

Balanced

195

pressure

preventers

Balanced

of

definition

34

220

209-214

of

Three-cone

196 gas

197

215

of

orientation

Diamond

Background

221-226

241

33

of

number

Side

194

211

mechanism

Design

310

of casing

209

wear

Crater

of

237

305

338

Strength

227

216

240

terminating

Series

204

angle

208

Damage

123

drilistring

337

200

Cutter

123

drillpipe

194

of

angle

offset

208 123

collar

237

231

230

194-199

208-212

230

Run

clearance

Cored casing

Loading

Bail

212

198

of

190

195

Clearance

347

Ratio Axial

326-328

bending

casing

346

Back

202-204

195

240

238

Button

of

Roller cutter

221

for

number

Reynolds

216

195

213

Bearing

220

344

192

assemblies

Chip

by

Determination

Of

of

bits

drilling

194

Bearing

427

inertia

341

Rotary

of

Selection

Caused

in

also

rake

Balling

345

Axial

in

Back

347

343

Axial

in

348

403

405 434

angle

353 406

440

374 417

436-445

375 418

488

APPLIED

inclination

Holding

427

BHA

Multistabilizer

440

439

angle

426

Introduction

437

analysis

438 of

BHA

BHA

Slick

back

Braden

Breakdown Breaker

BHA

pressure

definition

Brinell

108

of

108

237 wire

10

rope

328

270

Buckingham

11

Carnot

145

of

buoyancy 125

Helical casing long

Case

125-127

122

of

slender

125

rod

19

269

shale

Build

353-357 Bumper

sub

270-272

451

28

29

factor

Effect

on

buckling

Force

due

123-125

337

to

Collapse

122

334

333-336

casing

from

external

of

333

easing

of casing

305-308

333

rating

307

308

311

336

340 Resistance Button

of casing

threads

Buttress

310

195

bits

and

connector

303

313

317

315

305 of

axial

BCSG

couplings

304 319

306 321

323

324

300-350

cement

97

tension

of

344

100

102

79 in

lignosulfonate

cement

318

332

339

340

72-74

Effect

of combined

Exercises

348

of

trajectory

well

collar

339-349

349

349

350

of

exchange

smectite

Of

clays

Of

shale

302-305

casing

drawworks

In

302

301

350

Il

12

capacity 56

clays 53 268

Of

shale

Of

solids

274

cuttings

52

72

chemical

as

additive

for

mud

lost

and

303

322

312

323

331

338

336 after

slurry

325

of

300

sulfide

sulfide

on

329

331

332

334

liner

332

335

330

345

305

pressure

335-337 340

307

339-343

345

308 347

344-348

98

for

99

90-103 89-92

classes 85

85

Compressive

86 103

89 91

strength

95-101

Construction

89

86-88 designations

industry

90

of

Contamination Exercises

253

108-110

requirements

Cements

Consistometer

with

107

105

104

Compressibility

resistant

300

103

110

requirements

Composition

329

100

105

Two-stage

Clinker

effect

328

342

104

103

plugs

95 99

Additives

342-344

106

circulation cement

Settling

API

buckling

107 106

strings

Accelerator

24

106

107

Volume tension

332-339

Intermediate

106

Multiple

Time of

placement

345

axial

of

105

103

Stage

on

106

110

string

Squeeze

325

103-105

settling

Liners

106

casing

100

Evaluation

mode of

333

302

through

99

Casing

Reverse

in

additive

Cementing

on 325-328 334 stress on 310

acting

circulation

101

346

hanging

Leaky

properties

of casing

Standarization

Delayed

casing

transition

Landing

309

special

330-339

Plug

of bending

333 muds

332-339

collapse

320

Effect

Internal

302

performance

Criteria

Inner

316

Intermediate

100

332-339

60

340-344

burst

of

314

335

soaps

of

Considerations

Caustic

333

performance

73

acid

Calculating

310

33 1-339 for

diameter

Hydrogen

73 99

Montmorilloniie

Treated

casing

Annulus

loads

Hydrogen 98

94

Lignosulfonate

Sodium

61

contaminant

design

criteria

Helical

Naphthenic

330

330

of

Design

Head

Calcium

Hydroxide

323

330-339

Design

Grade

383

in

310

on

depth

considerations

Functions

Chloride

333

332

331

Design

Floating

302

405

strength

Cation

303 322

selection

Design

Float

307

transmission

drillpipe

As mud

of

310

of

303-307

for

Failure

303

309

selection

References

of

loading

300

of

strength

Nomenclature

343

effect

setting

cement

method

320

stress

Criteria

Free

and

347

429

conditions

318

of

design

Cathead

316

310

305-330

103-105

100

resistance

Forces

Cable

345

334

pressure

312

341

332-335

collapse

Manufacture

Collapse

Drift

343

Pressure

342

311

343

99

on 340

330

tensile

Cellophane

conditions

Pressure

API

310

339

Conductor

339

335

Yield

325

305

Collapse

casing

306

Loading

of

loading

Connectors

of casing

pressure

334

Casing

122-127

Conductor

of combination

of

333

338

342

Couplings

Failure

Transition

326

Compressive

175

Burat Design

310

of

344

302

301

Tieback

Weight

347

ratio

Combined

125-127

334

string

396

334

429

principles

design

tension

335

452 31

determination

Correction

In

Stress

Axial

Cementing of wellbore

trajectory

362

stress

General

Axial

of

331

328

394

346

Buoyancy

Buoyancy Axial

222

of

stress

Buckling

396

compass hold

fluids

drilling

302-305

couplings

Whipstocks

Bending

cuttings

and

of

128

transfer

of

strength and

332

331

effect

Tensional

Nomenclature

110

104

111

for

111

362-366 Loading Calculations

Example Calibration

example calculations

beads

270

problems

See

Manufacture

Minimum 312-323

331

of 330

stress

300

301

of

of

needed

348

Logs 291 292 Of sediments 248 Brunton

379

378

333-336

selection

tensile

Threads

orientation

333-335

density

Average

pendulum

marble

340-344

of drillpipe

selection

Ultimate

Axial

126

Sizes

301

300

wells

manufacture depth

Surface

energy

of

Setting

Steel

335-339

332

deep

factor

Subsidence

395

75 Joule

301 for

Strings

Casing

342-348

Tendency

101

100

horizontal

capacity

Carthage

Definition

cellulose

305-330 310-323

summary

Seamless

113

Buckling Effect

19

325

properties

Standarization

cement

392

and

Carrying

theorem

of

contaminant

270

Cardan-suspended

Carnallite

hardness

Safety

mud

Cardan-suspended

107

Bromoform

in

gyroscope

strength

21

hydroxyethyl

CMHEC

force

Production

63

Carboxymethyl

of

Performance Performance

definition as

Carbon-tetrachloride

definition

Overpull

351

Programs

of pipe

24

of of

271

Islands

dioxide

62

295

derrick of annulus

Carbon

density

292

109

107

437

squeeze

plug

Bridge

427-429

bulk

291

Arctic

Capacity

434-436

definition

plate

Breaking

Of

Caliper log

Capacity

definition

head

Bradenhead

432-434

column

tubular

Two-stabilizer Bounce

Bulk

286

Cantilever

429-432

of

Statistics

441-443

drillstring

Single-stabilizer

Of

curve

California

Canadian

Rotation

Of

Calibration

ENGINEERING

DRILLING

conditions

of

of

301

performance

339 302 properties

Permeameter 86 Placement Plugs

88

techniques

103

References

104 111

106

for 107

103-110

108

INDEX 489

Testing

86-89

Uses

85

of

Volume

102

98-100

Retarders

Standardization

Collapse

89-92

of 103

16

Centrifuges Charged

108-110

107

105

58 68

formation

69

of

definition

252

of of

Analysis

mud 60 mud 47

Emulsifiers

75

Flocculation

of

Potential

61

solids

steel

Of

tubing

API

of

58

91

Chien

U.S.A

227

correlation

Chip

clearance

Chip

of

direction

Chloride

176-179 bit

concentration

250

Chlorites

Choke

line

Choke

manifold

Christman

Chrome Chrome

mud

of

50

323

330

334

25

arrangements

288

correlation

73

Chrome/nickel

steels

26

292

291 of

definition

lignosulfonate

Pump

in

well

of

12-17

27

164

113

rotary

Compaction

effects

rotary

process

42

exchange

Complex

liquid

54-56

of

Extenders

drilling

High-yield Hydrated Kaolinite

65

Strength

of

rock

in

Yield

Clearance Clinker

in

57

55

of bits 204

polymers

64

152 Collapse

bit

classification

333

of

friction

81

function

146

207

147

208

150

153

275

of

casing

333-337

loading 339

conditions

of

casing

315

317

operation

of

and

drilling

equipping

1978

wells

33

foot

per

Basis

454 32

drilling

of

drilling

Drilled

221

Drilling

formula

index

of

128

127

energy

hit

run

Vs

bit

weight

casing

209

137

90

354

362

equiment

mud

chemical

62

dioxide

63

sulfide

casing

Critical

flow

rates

Critical

Reynolds

62

15

Crossover

of

wear

446

451-453 330-339

design

turbulence

for

number

102

151-154

cements

casing

334

bronzes

215

63

empirical correlation

426

subs

Crowfoot

193

opening

profile

192

191

ratio

factor

Cutting

structures

Cutting

transport

of

insert

ratio

bits

177-183

analysis

Cation

exchange

capacity

Mercury

pump 268

340

Moisture

content

Mud

of

definition

195

104

389

365

of bit

orientation

Cuttings required

beryllium

tooth

150

149

194

62

of

bit

175

173

for

Cutter

of

62

bit

beneath

Criteria

Curvature

agent

335-339

332

332-334

sediments

Crittendons

451-453

61

Oxygen

332

161 of

trajectory

water

334 liner

221

flow

Creeping

79

of

332 with

casing

casing

mechanism

208

industry cement

353

237

speed 306

of

selection

Intermediate

Crater 127

134

rotary

casing

Crown

Correlations

and

strength

86-88

angle

Contraction

220

Intermediate

Surface

127

fluid

209

239

For

Cretaceous

89

426

425

335

476

Treating

Cored

basis

drilling

Production

of

Concentration

Copper

Per-day

Couplings

312

drilling

Contamination

design

197

of

Hydrogen

of rock

resistance

335

194

removal

Hard

198-200

263

development for

Equation 330

323

322 in

Carbon for

field

Coupling-thread

303-307 321

332

221

gas 274

Connectors

Calcium

342 Collapse

65

64

three-digit

Culebrook

211

Contaminants

79

Cohesive

331

depth

Contaminant-removing

85

carboxymethylcellulose

196

208

wellbore

angle

262

179

62

280-285

of bit

angle

Continuous-build

65

54

Coefficient

300

casing-setting

offset

Contact

71-73

178

empirical rings

Formula

Cost

transport ratio

casing

Conductor

designations

cement

tar

estimating

measurement

Construction

56

176

182

Louisiana

for

cuttings

Consistency

65

Mayes

181

Consistometer

bentonite

of

308

strength

momentum

251

For

Of

mass

exchange

empirical

152

flow and

load

geostatic

of

muds

95-101

233

of

cation

Wyoming

of

Conservation

Substitutes Water

221

excess

Conservation

268

56

Smectite

288-291

McClendon

Cost

250

53 250

262

Corrosion

89 91

Conservation

in

261

Walker

433

definition

56

284

293

344

casing

cement

181

Sepiolite

of

of

Connection

274

268

and

181

55 57 54 60

Montmorillonjte

256

Rehm

Zamoras

430

319

Low-swelling

Code

54-57

65

Flocculants

86

125

loading

loading

200

to

fluids

279

291

176-182

Turbulent

Connection in

Berry 288

Kelly

Pennebaker

components

Strength

Cone

montmorillonite

and

284

278-280

261

Shirley

and

Moore

85

cements

fluid

drilling

Conductor of

viscosity

251

illite

Encountered

CMC CMC

69

on

Johnson

328

289

116

103

Conductivity

54

water

Diagenests

65

effect

and and

bending ratio

342

models column

of

cements

180 53

capacity

Concentration fresh

60

153

288-290 computer

Computer model

particles

stress

195

plug

Complex

optimal of

casing

effective

292 Matthew

150

149 152

290-292 for

MacPherson

360

182 292

Metzner

pore

358

181 291

empirical

Eaton 288

Jorden

scheme

Yield

rigs

drilling

Commercial

formation

250

Clays

Cation

on

247-250

measurements

Load

41

288

Empirical

69

For

Compass

Stress

Association

310

casing

65

278

Compass

Axial

drilling

fluids

drilling

Of

constant

on

54-56

Compressive

196-203

bits

Compaction

Of

Classification

Of

clays

Of

74

163

pressure

System

effect

stress

and

time 278-280

271

and

Dodge

330

string

pore pressure

transit

176-179

Crittendon

225

224

casing

Compression

Operation

Boatman

Christman

194

feeder

and

256

Compressibility

389

163

pressure

and

271

pressure

pore

time

interval

and

pressure

cuttings

284

322

320

overbalance

pore

formation

shale

and

shale

transit

Between

303

318

of

formation

Chien

sandstone

Composition

61

Circulating Drillpipe

316

radial

Compensator

29-31

lignite

337

309

of casing

314

pressure

268

24

334

zero

is

Commercial

451

65

phenol

Between

333

resistance

Combination

formation

density

Hottman

194

preference

Chlorinated

182

181

325 stress

312

Combtned

Chevron

10

differential

261

interval

310

Cotton types

308-3

311 axial

d-exponent

pressure

bulk

and

261

Between

19

115

Collectors

77 cement

306

pressure

343

305

pipe

Collapse

mud

in

76

of water

Requirements

Coal

drillpipe

When

Additives

Of

casing

Of

Rating

Chemical

external

Of

Of

d-exponent

pressure Between

from

74

Chelation

Between coefficients

empirical

309

used Failure

requirements

Centralizers

pressure

Determination

balance

Variable-density 270-273

268

269

273

268-270 balance

268

212

490

APPLIED

Cuttings

optimization

transport

of

Cycle

pump

179

14

effects

criteria

Coupling

Darcys

45

Data-telemetry Decanting

centrifuge

of

Declination

void

Deflection

392

Positive

367

406

PDM

and

straight-

PDM

mud

change

417

elongation planning

with

change

for

Turbines

and

directional

straight-

421-426

drilling

410-413

Whipstock

casing

Whipstock

openhole

405

402

cement

Of

mud 59-61

Organic

101

Degradation

of

72-75

106

Of

brine

Of

CaCl2

on

effects

251

pressure

mixtures

Of mud

52

mixtures

54

Of NaCI

196

81

muds

oil

cement

slurry angle

Departure

direction

92-94

362-364

of

definition

365

of

Derivation Direction

change

wellbore

board

Ouija

Tool-face

angle

370

371

fluid

Dilution

of

Derrick specifications

and

39

ratings

Barge

10

11

10

portable load

Desanders Design

mast

load

10

78

distribution

of

pressure

special

changing

381

jetting

pressure

Landing

344-348

changing

358

362

11

for

of

of

correction

394

Drift

correction

plot

diameter

turbine

With

whipstocks

364

316

318

332

339

340

Drill

blanks

Drill

collar

Drill

collars

360

and

421-426

and

BRA

234

264 on

mud

Station

26

effect

contrDl

Air

density

28

16

submersible

see

Bits

Bits

responsibilities

209

425

for

351-353

for

443453

402426 reasons

cost

472

time

calculating

trajectory

of

113

173

190

210

Diagnostic

see

352

353

Disodium

ethylenediaminetetraacetic

cement

131

137

236

237

330

453

also

Mud

of

176

42-53

82-84

muds

muds

72-75

84 75-82

53

tests

54 on

effect

bit

penetration

22 1-226 84

References

muds

bits

Laminar

54-72 113-189

hydraulics

nozzle

50

129

water-base

Inhibitive

Jet

129

122-127 183-188 flow

size

129-131

through

156-162

selection

flow

in

and

pipes

annuli

137-144 98-102

Displacement

of cement

Displacement

of drillpipe

slurries

20

Models 113

85

127

tests

Exercises

coefficient

34

35 1-453

capacity

Buoyancy

Discharge

34

36

32 41

117

fluid

Drilling

472

34

directional

Waterbase trajectory

33

33

example

example

engineer

rate

362-366

example

32-37

Properties

473

32

rate

time

Pilot

239

33

example

formula

108

Oil

221

32

example

time

Nomenclature change

220

analysis

program

Exercises

377402

planning

210

426

Carrying

trajectory

for

450

448

210

Drilling

Drilling

366-377

Dispersants

331

430

447

parameter

Drilling

453472

EDTA

127

441

312 324

450

428

126

solids

Drilling

deviation

reasons

tools

wells

191

438

Rotating

426-443

Deviations

Directional

303

definition

Drillability

Trip

403-406

Deflection

well

398

322

Predictions

410413

and

well

397

397

320

stiffness

Drilling

407

assembly

and

397

of formation

Bit

199

406

drilling

Exercises

232

396

394

Drillability

Drilling

413417

of

394

of casing

314

Penetration

bit

With

392

Drift

Contractor

366

358

for

PDM

196

12

388

Example

With

acid

340-342

67-69

drilling

With

194

223-225

401

Barges

353-362

342-343 internal

81

31

of

Reading

References

casing External

80

133

387

384

designed

193

221

11

362

Drift

Drillers 252

251

mud 58

derivation

Bits

of

action

Contract

scheme

Of

51

considerations

on

sticking

in

Quadrant

Of

equivalent

effects

352

Nomenclature

Maximum

Total

383

27

57

system

Measurements

Jackknife load

86

rigs

351

192

profiles

191

422

Costs

planning factor

85

definition

hydraulic

Kickoff

Cantilever Efficiency

99

pressure

solids

190

415

Drilled

pressure

Dilatant

224

bit

wedging

204-208

432434

93-96

C2S

pore

Definitions

370

369

216

210

density

principles

nomograph

193

191

rigs

369

angle

441

101

Bottomhole

inclination

236

224

201

drag bits

silicate

233

control

366-369

New

232

199

bits

earth

Directional

of

230

205

LWL

365

67

Departure

Or

cutter

Directional

66

Additives

Leg

Diamond

Change

control

Density

API

414-417 422-426

Angle

52

solutions

205

198-201

405 core

Cutter

bits

Drift

232

layout

190

403

Direct

52

additives

pore

225

Diamond

12-14

drilling

198

399

Direction

54

solutions

Of mud

formation 252

formation

221

Direct-drive

pore

440

216

Differential

246

on

stone

formation

287

286

Differential

Of

bits

Diesel-electric

Density

In

bit

421

bit

PCD

Drawworks 446-450

251

250

Differential

environment

443-445

BRAs

effects

Diamond

Dicel

343

cementing

depositional

247

102

102

mud

Delayed-setting Deltaic

99 100 64 69 70

retarder

446

investigations

Diamond

368

pumps drag

in

bit

Drag

445

pendulum

Dicalcium

As

Doubles

450453

449

445

Diatomaceous

Deflocculants

Double-cone

Drag

366

402 418

205

Problems

194

403-440

343

of

326-328

28

sonar

Double-blade

drilling

forces

pressure

152

correlation

374-376

Double-acting

351

wellbores

of

340

casing

definition

control

Diagenetic of

effect

pressure

of

Large-diameter

Use

407-410

casing

445

443

335

342

for

conductor

Metzner

severity

Doppler

332

340

control

Theoretical

417421

Turbine

339

Geological

413-415

drillpipe

PDM

407

415-17

displacement

Trajectory

Dogleg

332

condition

Definition General

402

motors 402

330

332-339

well

Deviation

366

and

Dodge

of

of 331

criteria

for

153

selection

selection load

Development

directional

Standpipe

Weight

332-335

421

drilling

332-339

332-339

selection

Design-loading

magnetic

offset

with for

hole

391

tools

Drilling

on

and

362

jetting

system

310

24

300

370-372

Design

389

angle

Deflection-sub

hole

depths

Sizes

16

of

interference Deflection

27

description

15

angle

Declination

PDM

Setting

Diverter

casing

selection

selection

344

line

ENGIN4EERING

theory

energy

Diverter

331

systems

schematic

Bits

88

344

343

for

Grade 261-263

law

Distortion

effects

Thermal Design

d-exponent

340

loading

Subsidence

65

CyflocTM

Shock

DRILLINIG

rheological

Nomenclature Pressure

188-189

13

1-135

INDEX 491

Annular

well

during

operations

control

in

Hydrostatic

columns

Dull

complex

in

bit

Dump

fluid

115-118

Hydrostatic

of steel

Ductility

119-121

columns

gas

219

calculations

positioning

A2

Viscosity

27

of vessel

28

fluid

plastic

47

rates

Yield

A2

point

Casing

design

113-114 due

Surge

to

vertical

movement Pump

164-172

pressure

control

pipe Earth

schedules

operations

welt

for

162-164

188

References Turbulent

flow

in

and

pipes

annuli

144-154 particle

Viseometer

slip

rotational

Conduit

circulation

154-156

Mean

Jackup self

Platform

contained

5-7

system

34

organizations

Model

operation

29

180

264

233 of

definition

Offshore

of

block

Of

derrick

237

265

12

36

115

125

127

345

348

453

144

analysis

of

36

24

recorder

35

plots

35

time

36

PDM 228

Definition

229

bit

Establishing

standard

flounder

crossilow

point bit

234

416

210

309

Average Buckling

428 78

19

Collapse

19

pressure yield

11

Electromagnetic

transmission

of

Schedule

method

259

310

325

311

302

334

340

19

for

drillpipe 417

79

stability

Energy

balance

Engine

power

128

164

for

181

Lime

wait-and-weight

Drillship

3-5

Drillstem

valve

Mud 25

pressure

losses

Drillstring

rotation

441-443

multishot survey

Dropping

assembly

Dual-axis

accelerometer

Dual-axis

gyro

Dual-axis

inclinometer

424

instrument

434

Error 382

of

annulus

399

stress

Eugene

bit

of

Island

411

117

389

TVD

at

horizontal 356 horizontal

end

to

of

356 measured

at

TVD

measured

to

end

values

121

330

of

of

quadrant

Direction

well

368

and

compass

358 for

tendency

building

442

Displacement

at

TVD

horizontal

356 pressure

while

Dogleg

severity collars

to

209-214

422

change

BHA

50

Drill

422

of build

356 toal measured Depth Diamond bit with turbine

schemes

282

215

area

of bit

428

of

direction

376

177-179

formation

413

429

stiffness

correction

Direction

dye wear

of

weight

angle

Direction

149

281

259-276

Evaluation

179

49

116

Black

teeth

Estimation

127

117

concept

histograms

Europe 28

an

concentration

drilling

399

tungstorl

economy 116

density

Eroded

152

149 density

concept

Erioetirome

Drilistring

Collar

356

233

225

Matrix 27

432

steel

356

177

mud

for

tendency 442

OD

Depth

BHA

451

Collar

build 85

433

direction

Departure

437

assembly

of

building

129

375

response

410

Bottonthole

Depth

Diameter

164

forces

speed

values

127

velocity

Density

164

side

80

of Portland

state

Circulating

circulate-and-weight

Bit

374

resultant

Departure

output

Isle

of

79

109

401

effective

reading

78

muds

oil

Circular diameter

163

sub

Declination

for

and

deviation

total

error

angle

BHA

45

25 258

and

drilling

design

EMF

formation

of casing

Annular

pressure

Circulating

method

method

mix

92 requirements

change

Collar

Equation

13

volume

Bit

Bit

Equivalent

12

Schedule

388

systems

England 19

pressure

19

Drillpipe

for

90

control

Bent brake

88

density

of

Azimuth

auxiliary

86

110

301

of easing

welding

Electromagnetic

Emulsion

19

tendency

Capacity

Upset

21

mix

Angle

of

88

cores

clinker

of

Slurry

Slurry

resistance

Emulsifiers

displacements

of cement

consistency

yield

302

Elongation 19

lengths

adding

98

cement

Directional resistance

plasticity

by

Slurry

340

of casing

welding

force

110

time increase

composition

31

Elongation

307

335

casing

Portland

flash

of

345

body-yield

hematite

347

Drillpipe

Tongs

260

428

actuators

Ellipse

331

analysis

Density

301

227

surface

342

89

test

Analysis

Drop

chart

Electric

Ellenburger

at

331

depth

Cementing

10

428

Electromotive

needed

cement

selection

Surface

383

414-417

displace

Stability

310

292

drawworks

Team

Joints

325

of

definition

Electromagnetic

needed

strings

Cements

Eleetrohygrometer 1-40

processes

of casing

Strength

system

Electric

Electrical

operations

Internal

122

126

fluid

308

301

Problems

API

mud

in

theory

Electrical

325

328

pressure

to

170

302 data

259-268

With

Pump 169

287

Elasticity

minimum

pressure

strength

Setting

tackle

309

Theory

351

With

283

of easing

failure

310

rating

325

Permeability

Rock

301

Performance

Spool

in

and

302

308

311

331

factor

For

343

328

rating

Collapse-pressure

Size

rod

in

change

pressure

Number

velocity

strength

Modulus

exploratory

Operations

Drilloff

Weight

Limit

Marine

pressure

External

149

drillstring

Collapse

Drilling

Rotary

422

Elastic

Typical

Trip

of

Elapsed-time

Tender

Burst

311

176

Weight

Efficiency

tendered

Semisubmersible

Mud

392

391

289-291

ratio

Yield

Platform

max

288-292

258

stress

Viscosity

drive

max

stress

122

annular

Stress

electric

force

Axial

Collapse

388

field

diameter

load

initiating

Power

398

Axial

Joint

Hook Matrix

Direct

by

stabilizer

135-137

rigs

Time

Eccentric

127-129

Diesel

Rig

correlation

173-183

Classification

Pad

magnetic

Eatons

nonstatic

Drilling

176

Earths

conditions

Well

sensed

gyro/accelerometer

Effective

Velocity

Well

forces

110

251

Bingham

columns

liquid

of cementing

Evaporites

Example

filtration

Dynamic in

Hydrostatic

218

12-14

pumps

Dynamic

Evaluation

213

107

bailer

Duplex

114-115

328

evaluation

drill

Efficiency 413

370

372

nonmagnetie well

374 needed

392

mechanical

of

turbine

APPLIED

492

Flow

area

diamond

for

sizing

bit

422 Inclination

and

impact nozzle

pressure

356

431

Bit

moments

Buckling

427 for

plan

Moments Radius

of

356

PDM

lead

429

Side forces Sidetrack

pump

from

casing

optimum

for

design

Tubing

Density

126 to

116

Stator

and

lead

PDM

pitch

of tungsten

Mud

also

equivalent

134

Surface

of

of well

location

of kick

Density Drill

position

collar

Yield

seat

Survey

Formation velocity

126

buckling

370 Drillpipe

positive

displacement

mud

average

velocity

128

in

Drillpipe

Trajectory

coordinates

of

well

frictional

144

in

loss

pressure

147

between

fluid

pore

and

pressure

fracture

261 269

Density

average

Density

mud maximum

bulk

Density

of cuttings

Density

of

shale

Drillability

288

271 270

cuttings

410

motor

between

fluid

resistance

to

length

plates

134

d-exponent

minimum

collar

prevent

setting of

Torque

of

point

402

error

Tool-face

mud

128

in

451 Drill

120

fluid

average

128

134

plates

409

drill

annulus

between

fluid

plastic

plates

casing

in

drillstring

of

145

drillpipe

132

density

at

428

collar

and

Viscosity

of fluid

in

average

pipe

displace

115

pressure

flow

Velocity

121

Stiffness

collapse

Turbulent

182

viscometer 181

ratio

Viscosity

see

Density

418

collar

137

135 433

430

130

drill

Fann

rate

Transport

across

pressure

index

Consistency

409

160

prevent

Cement

427

inertia

of curvature

Rotor

374

wellbore

drop

to

Shear

158

sizes

minimum

length

Kickoff

131

force

Bit

polar

angle axial

Inertia

Bit

ENGINEERING

DRILLING

264

parameter

Gradient

formation

Gradient

vertical

290

fracture

364 laminar

Drillpipe Trajectory

of

well

flow

Turbine Turbine

361

and

rate

mechanical

flow

turbulent

or

145

in

Drillpipe

efficiency

pressure

163

schedule

164

of

Weight

on

steel

surface

Well

429

collars

WOB

bit

417

axial

stress

Drillstring

axial

tension

vs

depth

123 451

positioning

Drillstring

fluids

Drilling

123

in

Drillstring

bottom

at

pressure

of

129 78

of

Activity

API

barite

in

API

barite

needed

66

density

API

water

Calcium Caustic

154

to

to

required

Fann

viscometer

Flow

behavior

Flow

pH

raise

45

solution

load

Density

of

mud

Density

of

mud

Kick

mix

in

Mud

Properties

Mud

Soda

ash

Solids

50

53

71

apparent

Viscosity

plastic

Volume

mud

44

drop

Pressure

at

of bentonite

of

in

drilled

of

brine

of

mud

Volume

of

old

discarded

54

mix mix

mud

Bit

run

cost

well

130

of Galle

to

loss

rate

Penetration

rate

Rotary

speed

Rotary

weight

Water Drilling

44

point

Pressure

API

loss

Annulus

flow

Annulus

frictional

gradient

Annulus in

Annulus Axial

Pressure

in

Pump Pump

152

to

tension

drillstring

Pump pressure

loss

in

by

rate

at

wall

average

123

depth

in 123

drillstring

vs

143

for

128

169

tubing

collapse

drill

bit

115

operating

conditions

teeth

mud

by if

settling

displace

maximum

240

cement

diameter 175

at

pipe

wall

at

wall

of annulus

144

11

horsepower vs

rate

cycles

20

Pump

factor

14

Rotating

Trip time

rate

11

derrick

11

speed

Pump

Excess

rate

of

power

output

Tension

circulation

Shear

33

factor

of engine

Hoisting

Hook

Shear

11

time

Engine

175

stopped

219

131

116

casing

218

228

32

load

Penetration

particle

228 207

processes

program

Bit

Efficiency

to

240

rock

optimum

inertial

horsepower

suspended Sand

of

drilling

Drilling

swab

pressure

change

exponent

dull

Weight

hydraulic

from Sand

shale

exponent

Rotary

158-160

pressure

154

velocity in

149

149

shear

stress

in

pattern

frictional

143

Annulus Axial

47

hydraulics

in

optimum

strength

Derrick

Pressure

67

in

235

154

loss

surge caused 172 effects

be

234

233

225

Time

147

144

pipe

Woods

and

drillability

Penetration

Weight

152

212

230

Formation

of

in

207

rock

dull

and

static

gradient

frictional

Pressure

54

of

when

149

143

and

225

resistance

equation

drillstring

238

foot

equation

Efficiency Yield

per

160 plates

220

of Bourgoyne

Cohesive

Shear

frictional

rock

220

constant

optimum

Coefficient

140

frictional

Pressure

annulus

Volume

kill

bit

of

bottomnhole

Pressure

solids

72

Volume

to

across

circulating

64

problem

fraction

wear

life

Exponent

bottom

of

friction

Bit

Young

between

Pressure

annulus

in

drill

116

158

bit

viscosity

Pressure

72

Volume

in

114

static

of

sizes

for

219

internal

Description density

249

207

166

required

line

average

218

129

44

fracture

of

Angle

134

63

Viscosity

Viscous

Mud

trend

overburden

Abrasiveness

120

equivalent

density

Plastic

47

loss

surges

flow

156

294

292

bits

drilling

Bearing

154

284

281

272

for

vertical

Stress

145

Nozzle

filtrate

content

Spurt

in

69

treatment

normal

121

53 constant

maintaining pit

of

Salinity

content

Pressure

density

turbulent

density

117

71

fraction

72 Montmorjllonjte

fracture

257

246 279

Pressure

Rotary

of

273

249

272

formation

mud

249

cuttings

formation

265

121

or

pipe ejected

shale

249

vertical

constant

149

49

in

components

solid

surface

172

density

well

required

gravity

mixing

fluid

Killing

59

Low

of

Porosity

122

pressure

by

Laminar

lime suspended

Hydroclone

Porosity

clay

57

types

134

fluid

annulus

effects

54

various

at

of

effective

54

mix

in

pattern

Hook

caused brine

Free

index

137

rate

in

48

units of

decline

262 shear

stress

Pressure

288

252

weight

equation

Inertial

various

117

255

average

maximum

137

135

51

of

of CaCl2

Density

116

density

time

density

Porosity

166

47

concentration

Concentration

156

travel

Overburden

increase

67

loss

mud

Equivalent

71

fraction

Matrix

Mud Mud

413 Weight

292

291

422

stages

overburden

factor

time

vs

static

in

vs

depth

depth

depth fast

Casing

design

348

109

349

33

plot line

plot

cementing

Exercises 143

plot

34

11

33

INDEX 493

Cements

111

110

235

Drillability

Directional

and

drilling

280

Factor 82-84

Drilling

fluids

Drilling

hydraulics

Formation

pore

resistance

Fracture

and

pressure

fracture

Tester drilling

Rotary

drilling

Expanded

bits

nozzle

Extemal

93-96 bit

casing

333

336

240-244

processes

perlite

Extended

37-39

101 230

229

308

resistivity

fracture

pore

Abnormal

Differential

initial

Example Failure

mechanism

Of

bits

Of rock

204-208

136

viscometer

Fanning

friction

Fanning

acid

Fatty

Feature

numbers

Ferranti

of

73

Additives

102

101

Fineness

of

test

code

of

point

law

of

PCD

Fles Float

collar

Float

shoe

279

128

Prediction

Subnormal

profiles

192

of

351

of

Viscosity

of bit

234

with

73

227 231

226

well logs

240

of

Diagram

Generalized bit

Through Through

jet

Through

Flue

Fluid

129

nozzle

129

bits

22

control

74

Fluid migration pore

252

pressure

Flux-gate Fly

effects

ash

Foam-type

formation

253 386

381

drilling

displacement of

settling

drag

curves solids

in

bits

207

208

209

mud

58

Formation

rate

221

effect

water

on

bit

penetra

49

content

stuck

of cement

slurry

muds

oil

pipe

for

81

345

344

Freshwater

aquifers

Freshwater

muds

331

330 70-72

factor 153

Correlation for

circular

Definition

146

Empirical

173

178

disk

model

fluid

power-law

153

Friction-factor/Reynolds-number

rela

174

173

128

term

Friction

loss

Friction

reducing

cement

for

agents

nose

bearing

198

195

concept of

149

Frio

trend

Fuel

consumption

279

258

276

275

analysis

data

274

logging in

data

analysis

gradients

Galena

as

of

mud

42

287

formations

prediction

Willis

addi

control

density

Galling

of casing

Galvanic

probes

threads

303

62 277

counts

ray

288

Cut

102

27

293

Deviation

methods

288

291

288-292 equation

292

Trap

factor

119

121

efficiency

Gaseous

Gauge 288

of

definition

Kick

correlation

system

77

66

Blowouts

268

349

and

viscosity

Chromatograph

correlation

power

rig

of

Gas

analysis

pressure

pressure

Funnel

Gamma 275

extension

Christman

of

definition

tive

drilling

335

283-285

274

268-273

273

gas

58

drilling

capacity

analysis

54 155

equations

263

262

while

pressure

or losses

drop

140

correlation

matrix stress

exchange

138

166

150

246

gradient

MeClendon

correlation

137

gradient

Pressure-loss

effective

265

drillstring

Pressure

content

289

pipe

of casing

relationship

analysis

Hubbert

on

tension

mud

in

288-290

Mud Mud

Fracture

balance

axial

point

258

Moisture

Eaton

Characteristics

lime

Free

Drag

time

performance

330

force

correlation

Kelly

Drilling

Fracture

15

fluid

equation

Free

141

fluid

Fourbles

114

325

model

259-268

on

113

line 339

307

Pressure

Drilling

Fracture

Force

tion

261

262

Cuttings

96

balance

Forced

and

137

magnetometers

Force

stress

Johnson

pressure

Rehm

Cation

81

block

traveling

using

284

284

Formation

130

gradient

sensor

Tensional

Fugacity

129-13 nozzles

and

element

Friction-type

matrix

and

Zamora 130

fluid

98

Matthews

Vertical

96

level loss

476

181 68

centrifuge

pressure

dust

Fluid

137

system

parallel

Flowing

134

index

block

271

drilling

and

Normal

Behavior

276-285

calculations

correlation

transit

279

Flow

on

acting

Frictional

Interval

associated

change

289

254-259

pressure

278-280

61

forces

load

tiOn

Hottman 64

slot

277-279

285

281

particles

montmorillonite

Floundering

64

60

clay

fluid

For

Equivalent

active

Of

283

265

264

narrow

268

using

Boatman

vessel

of

On

247

Verification

105

causes

Definition

Of

281

272

101

in

113

284

time

268

zone

Flocculation

Common

257

246

105

drilling

crown

259-276

of

Bourgoyne-Young Floating

Of

Freeing

253

of

transit

transition

123

element

vertical

Friction

Formation

104

fluid

139

337

87

calculations

262

308

drillpipe

268

correlation

drilling

272

336

123

For

Freeze

interval

element

burst

For

288-290

slurries

28-31

joint

250-252

Berry

while

fluid

collars

Free-hanging

247

and

265

Normal

bit

drill

body

246

61

tension

casing

Defined In

thermodynamics

Flat-bottom

114

stratum

pressure

Gradient

438

cement

axial

Tension

measurement

From

oil 76

Flash-setting

For

298

Example

or

annular

For

288-292

292-294

diagram

For

For

estimating

252-285

permeable

284

262

algorithms

434

431

80

89

cement

BHA

Finite-element

in

Estimation

69

411

element

278

Direct

cement

for

60

55

For

252

336

Matthew

279

86

for mud 64-67 muds 64 65 80 81

First

By

136

262

298

Abnormal 275

fluid

Additives

Fire

per

control

Fillration

Of

on

330

drilling

42 45-47

press

fluid

Formation

74

effect

gel

France

234

estimating

246

References

329 of

testing

Of

199

198

bits

257

282

effects

Nomenclature

Normal

of casing

formance

Filter

148

lignosulfonate

handling

Field

146

79

252

335

258 for

290

142

data

drilling

Methods

392

tool

Ferrochrome Field

78

251

BHP

246

288

287-292

of

Fragile

294-298

Gradient

147

factors

soap

182

137

146

equation

From

209

208

bits

251

effects

281

Fluid migration

cutter

250

shut-in

279

of

correlations

Free-body

problems

272

Exercises

200-209

rolling

Farm

265

285-287

247-250

density

to

Equal

Using

247

effects

pressure

Verification

effects

Diagenetic

282

pressure

correlation

correlation

Prediction

pressure

246

Compaction

12-324

283 profile

Kelly

291

275

salinity

correlation

Berry

288-290

Pennebaker

233

of

and

281

Fracture

Water

Formation

XCSG

303-307

connectors

Of

290

81 conductivity

Formation

305

pressure

threads

drag

279

285-287

definition

Water

Water

340-343

Extremeline

278

294-298

Rotary

and 292

291

Matthews

gradient

resistance

Resistance

288

281

Fluid pressure 183-188

MacPherson

261

constant

453-472

238

236

deviation Drillability

control

drilling

wear

Grading

definition

334

of

of 212

213

of

114

335

definition

fluid

of bit

Determination

274

117

15

of

274

494

APPLIED

Gel

Drawworks

60 61 Initial 42 475 Progressive 60 Fragile

44

10-minute

86

Tobermorite Gel

42 59 60

strength

Geneva

61

forces

Geological control

475

175

deviation

247-250

load

fill

Hole

washout horsepower load

258

340-344

347

355-358

departure

of

Horizontal

matrix stresses

356

355

and

286-288

of

selection

Intermediate

casing

Intermediate

casing

334

332 with

filter

Hubbert

332

liner

335

Surface

Humic

inclinometers

Gravity

vector

shoe

mance

240

of

386

Impact bit

394

401

Mexico

area

249

252

351

Gypsum

force

Power

98 99

cement

101

muds

Gypsum-treated

GO

orientation

Gyroscope

definition

weight

and

bit

two-step

auxiliary

Hydrogen

flame

Hydrogen

sulfide

Effect

for

328

329

detector

62

PDM

Half-lobe

407-410

Steel

Halliburton Halliburton Halogenated

performance

casing

329

test

Heating

value

mud

of of

teeth

Hematite

29 161

152

342-344

mud

as

ditive

density

High-pressure

89

High-yield

clay

Histograms

Block Derrick

303

302

material

bottom

55

57

177

system and

drilling

tackje

178

Change

in

well

in

of

drill

collars

121

density

163

117

compaction

forces

axial

pipe

stresses

liquid

in

drillstring

at

73

75

73 of

398

394

correction

342

106

105 241

203

300

331

332

with

liner

332

305

307

casing

335

74

42

345

casing

Internal 25 pressure

335-337

Combustion

Yield

neutral

columns 114

columns

pressure

115-118

115

113

at

pore

From

247

Ion

246 calculation

of

113

Ions

Contractors 208

199

280

290

times

transit

254

common

For

19

48

296

Definition

114

table

time 277

transit

207

of drillpipe

Drilling

196

of

angle

atomic of

347

rigs

417

rock

pressure

308

345

engine

pressure of

Assn

Interval

335

339-343

diesel

IADC

point

292

fluid

mud 333

Subsurface

171

pressure

cementing

Intermediate

Intl

123

string

columns

8-11

mast

74

202

bits

Interval

In

58

muds

72

definition

Intercardinal

119

Sedimentation or portable

gel

Friction

on

Pore

Initial

Drillpipe

252

on

gas

surge

water-base

Casing

mud

to

Effect

complex

of

441

energy

lnhibitive

333

Effect

In

in

260

259

log

effects

31

system

definition

International

In

223

hydraulic

solids

368

change

172

260

due

Of

Indirect

flOP

Change

Equations

91

of error

ad

failure

335

116

on

386

379

of casing

limestone

334

124

Effect

381

378

period

Intermediate

125

74

HSR

sulfate-resistant

cement

108

squeeze

muds

High-salinity

Hoisting

control

66

28

of angle

Insert

123

Hematite

reading

Lignosulfonate-treated

328

118

117

foreign

and

top

Concepts

93 94

additive

Index

122

Bottomhole

96-98

High

on

123

casing

cement

as

At

195 of

pressure

Balance

151

of bit

buckling

62

51

28

number

Hydrostatic

fluid

fuels

compensator

Hedstrom

50

of

definition

water

head

402

377

Calcium-treated

330

to

resistant

grades

Hydrostatic

Acting

271

hydrocarbons

Hardness

102

402

Inner-string

Resistant

HALAD-91M 101 HR4TM 99 100 HR12TM 100

Halliburton

True

Incubation

63

casing

480

140

382-384

370

Units

274

329

law

353-358

High-salinity

contaminant on

443

369

Inertial

embrittlement

365

363

415

366

Inertial

67

brake

11

Hydrogen

352

New

Inert

306

58 59

15

As mud

159-161

of

path

351 431

329

of tooth

connectors

drawworks

Hagen-Poiaeuille

366

of

Induction-electrical

Hydrocyclone

362

Surveys

355

of

362

Indiana

optimum

366

of

direction

Measured

420

rate

218

102

392-400

168

439 439

387

Inclinometer

drillstring

on

effect

217

14

149

Hydrazine

392

in

of

Inclination

Thrust

Hydrodynamic

Measurement

holding

Low 432 Maximum

130

bits

jet

pump

of

Hydril

for

Limiting

bits

jet

233

Hydraulics

Gyroscopic

Compass

through

mud

of

394

398

azimuth

122

body

232 424

through

398-400 394-396

392

flow

Representation

wear

Gyro/accelerometer

158

forces

Hydraulics

402

Gyro compass

Gyroscope

73

building

Higher

156

output

Radius

hemihydrate

for

Equilibrium

412

foreign

in

156

bit

jet

on

flow

in

Pumpoff

101

359

kickoff

Control

131

438

392

103

85

131

perfor

Power

area

for

of turbine

acting

Horsepower

on

400

At

Definition

parameter

of

definition

angle

Constant

cement

muds

in

Alignment

Check

77 of

97

control addi

density

solids

Change

60

shale

Efficiency

196

driller

289

288

64

of

54

94

additive

66

BHA BHA

47

Hydraulic

105

104 for

Helical

mud

60

equation

reaction

Forces

195

Guidelines

Gulf

size

399

seals

of

Design

Gravity

Coast

nozzle

bit

46

definition

clays

Hydration

158-162

selection

Heel

as

274

structure

Willis

acid

Hydration

332-334

analysis

Gulf

335-339

332

casing

casing

Graphical

Heave

Ilmenite

Inclination

press

and

Hydrated

Production

Hard

cement

41

284

cards

274

268

as

correlation

gas detector of

251

Ilmenite

Inactive

Johnson

127

250

tive

House HTHP

17

121

114

Equation

31

bundle

Hot-wire

swivel

115

218

gas

lllites

278-280 101

211

Behavior

362

charts

210

Definition

Hottman

93-95

Gooseneck

Gunk

286

displcement

344

Wells

387

227

classification

platform

Ideal

Horizontal

Hose

353

Gilsonite

Guide

Ice

291

Projects

Grease

11

451

275

Gradient

Gyro

law

bit

199-203

260

259

Horizontal

Geothermal

Grade

IADC

265

156

Hook Hooks

399

of

definition

Hook

446

445

55

Geostatic

Hole

12

398

428

causing

problems

Georgia

azimuth

383

379

gear

74

11

Hole

ENGINEERING

DRILLING

matrix

fluids seismic

product present

records

constant in

materials and

254

sea

255-258

of water water

74

44

INDEX

Isle

495

of

85

Portland lines

isogonal

chart

isogonic

of

definition

U.S

for

389

391

24 26 27

Kill

line

Kill

mud

Knippa

29-31

Magnetic

162-164 222

basalt

collar

426

429

Collar

Interference

388

389

392

394

401 Multishot

381 Jackknife Jackup Jet

derrick

Lafitte

rig

Lambs

bits

Flow

129-131

through

Hydraulic Hydraulic Nozzle Bit

size

force

power

130

selection

hydraulic

Graphical Jet

Known

Jet

hydraulic

Jet

impact

force

235

nozzles

Jetting

379

238

of

402

367

403

Joint

373

375-377

407

406

of

mode

failure

APi

for

of

Leak-free

of

Formulas

306

Of API Jorden

327 coupling

bits

196

328 261

correlation

Shirley

bearing

237

test cement

Leaky

fault 253

Least

240

Leonardite

sediments

446

Monel

51j0TM

59 61 64

mud

cementing

Liquid

kick

25

339 25

340

307

119

of

Lost Detection

22

in

control

circulation

Dogleg

33

370

derivation

change

371

366-369

372

new

angle

board

for

65

333

81

nomograph

Kelly

correlation

definition

load

content

of

71

402

401

errors

cement

annular

fluid

Mean

annular

velocity

87

slurry

velocity

170

140

154

155

167 for

directional

drilling

392-400

compass

multishot instruments

379-381 references

and

interfer

388-392 instruments

single-shot

377-379

derivation

of

derivation

381

tools

Surveying

accuracy

borehole

400-402

Tools

for

382 and

measuring

dur

trajectory

383-388

drilling

while

MWD

of

position

377

tool

drilling

385

386

400

388

415

413

336

335

281

Deformities

283

291

field

Center

Efficiency

of

turbine

of

pump

balance

Energy

255-257

266-268

277-279

283 oil

272

284

mud

Low-pressure

squeeze

Low-swelling

clays

286

248

273

flow

pump

for

typical

properties

orange

alkalinity

108

Mica

53

flakes

lost

bulk

273

Methyl

blue

well

determining

Metals

Methylenc

25

calculating

268-270

75

128

366

291

289

13

413

419

system

for

365

trajectory

12

412

424

on

volume

330

pump

equation

method

Mercury

246

sys

tackle

of casing

mud

Stresses

area

and

of

Mercury Prevention

block

Efficiency

Horsepower

gulf coast

Low-collojd

of

tem

of

48 57 64

circulation

428 81 72 additive

56 101

diagram

Reverse

torque

pensating Tool-face

256

333

Advantage

101

371

Ragland

387

323

area

Blowout

Low-viscosity

Kickoff

321

224

369 Duija

306

301

Hudson

27 Louisiana

366

severity

Inclination

277

255

load

Efficiency

296

372

371

overall

orientation

Direction

319

muds

32 37

State

Bit

291

286-289

derrick

Measurement

304

field

South

change

trajectory

change

317

control

Island

292 Port

Angle

couplings

303

zone

Offshore

158

330

and

283

289

Mechanical

Lafitte

119

drilling

operations

119

Margin

232

281

time

Mean

ing

and

oil

circulation

Eugene

121

Identification

Kickoff

332-335

Louisiana

163

162

315

Lost-circulation

119-121

of

density

Liquid

area

324

120

zone

Lost

well

of casing

connector

313

Kick

In

coast

gulf

343

threads

LCSG

453

Contaminated

230

278

10

of

Steering

342

round

Long

17

seating

119

107

119

conditions

Loading

sub

Gas

and

14

assembly

Fluids

106

267

266

Saver

Fluid

travel

Magnetic

103

18

Drive

Definition

Stresses

Matrix

Magnetic

26

Definition

Key

of

218

271

coefficient

Matrix

Magnetic 74

301

of

of Louisiana

Lithology

Cocks

257

stress

ence

definition

128

268

250

17

73-75

73

Liners

Kelly Bushing

127

256

166

muds 73 59 61 73 74

Liners

27-32

special

models

Gyroacopic

389

clays

34

fit

schematic

42

Mathematical

Water

Lignosulfonate-treated

Lime

funnel balance

Measurements

Lignosulfonates

Kaolinite

253

61

452

451

riser 28-32

Mud density 288 289 Solids line of mud

98

193

equipment

Hook

stress 288 curve

302

28

Marine

Survey

or casing

principle

Lignites Jurassic

359

330

operation

operations

Marine

Equivalent 10

drums

292-294

Leaky

Lignins

191

slots

well trajectory

116

as

301

288-290

344-348

of

Least-square

241 Junk

340

drawwork

well

Maximum

144

for

382

casing

drilling

Matthew

143

equations

tieback

Leakoff

305

round-thread

and

Journal

332

connector

Definition

144

362

strength

Cost

141-143

slot

as

377

of

Matrix

139-141

on

angle

pipe

annuli

determination of

points

Lead

304

and

model

of casing

Landing

vertical

377-380

232

viewing

237

pipes

model

Shear-rate

connec

to

shale

Manufacture

Mass

145

392

389

Manometer

Marsh

482

pipe

represented

Summary

threaded

143

481

due

Non-Newtonian

Lap

pull-out

in

Newtonian

304

connectors Joint

407

143

165-169

flow

Annulus

131

fluid

Mancoa

389

of equipment

132

circular

movement Laminar

404

efficiency

tions

181

instruments

Marine

139-143 fluids

pressures

166

155

155

loss

fluids

in

Surge

179

change

366

Patterns

231

157

whipstock

Joint

power-law

156

purpose

bits

Jetting

Of

156

236

trajectory

Jetting

Newtonian

horsepower

230-232 Jet

non-Newtonian

Of

velocity

152

annuli

Of

158

151

pressure and

pipes

157

needs

cleaning

Maximum

144

158-162

156

force

132

of

Frictional

388

Single-shot

Magnetometers 479

478

fluid

379

377

Reference

Surveys

plastic

Equations

ln

275

140

flow

Definition

157

156

analysis

impact

131

156-162

268

logging

equation

Of Bingham

131

horaepowcr

maximum

mud

in

Laminar

Impact

Louisiana

field

time

Lag

instruments

382

for angle

of well

404-407

of

372

373

mud

motor

plastics

plugging

water

16

zones

com

derivation

418

362

in

Milled

bit

tooth

202-204

373-377

359

Microfossils

369 366

218

370

374

MacPherson

and

288

292

291

Berry

correlation

and

210

268

cutters

212

214

195 215

197 217

229

Milligrams Miniature

cuttings

per

liter

whipstock

definition

theory

of 446

48

450

496

APPLIED

Minimum

Circulating

Curvature Matrix

289

stress

content

Miocene

255

87

slurry

257

277

278

301

Mississippi

345

MOCEM

Clay/water

1-73

place

369

Clinging

through

42

plastic

134

136-139

144

161

169

261

233

wear

237

233

264

Complex

127

133 155

150-153

41 of

72 74 107 59-61 64 67 70

of

180

drilling

Control

342 optimal

ratio

180

264

265

233 rotary

process

256

257

218 271

150

155

278

127 169

232

281

131

237

181

127

Static

Power

law

Soil

127 169

152-155 Sediment

237

to

121

well

Solids

71

176

144

481483

476

compaction

Three-dimensional

change

trajectory

MSR

sulfate-resistant

89

cement

Modified Modified

261-263

41

Entrained

solids

drillability

parameter

264

Modulus

of bit

209

359

428

205

criteria

Free

223

221 circle

graphical

206

analysis

of

121

136

80

81

gases

58

57-60

filtration

as

42

additive

principle

agent

soda

agent

sodium

Moisture

Content

Molality

of

Molarity

definition

Moment

of

agent

zinc

log

of

48

Gas

separation

Gas

separator

428

62

correlation

Mooring

sizes

134

mandrel

403 405

413

Hydrogen

419

Hydrostatic

62 for

rig

Additives Analysis Balance Calcium Carbon

in 41

275

64-67

69

Cation

80

treated dioxide

87

268-270

Contaminant

62

of

capacity exchange

113

176 of clays

capacity

53 additives

Chemical analysis

Chloride

60 of

Concentration

61

density

solids

control

additive

41

in

164

73

of

card

391

462

picture 384

463

data

392

381

402

BHAs

442

436 437

427

444-446

387

systems

NaC1

concentrations

Logging

data

Logging

service

Logging

mud

Negative

side

388

various

in

units

434

time

436

275

Shift

268-273

of

analysis

260

day

in

in

Stress

Newtons time lag

control

solids

line

of

density

of

54

65 71

Newtonian

Newtonian 136-144 Newtonian

at

429432

bit

441 442

450

point

144-153

circulation

440

387

386

pulser force

Definition

268

275

Mixtures

Negative

Neutral

Log gas 276 26 27

Maximum 50

74

73

Logger

Lost

47

389

output

335

333

pressure

as

162

Kill

268 Chemical

MWD

52

Lime

72-74 as

106

Contaminant

Lignosulfonate-treated

86

264

technique

359

targets

Multistabilizer

MWD

75 as

276

42 44

417

63

Inactive

52 60 61

63 Carrying

74

66 solids

180

179

sub 379-381

cementing

Surveys control additive

density

sulfide

Ilmenite

Mud Active

51

of

441

418

sidetracking

parameters

jackup

59 60 64

151 or

regression

Gyroscope

66

421

operating

Mr Mel

test

High-salinity for

64

42 44

of

133

Film reader

Gyro

as

cuttings

54-75

point

Multiple

optimal

180

problem

Compass

73

29

used

torque

Motors

275 26

15

Hematite

176-182

patterns

Motor

on

effect

transport

Yield

carbonate

basic

Multishot

Gypsum-treated Hardness

63

63

Multisensor

276

Gaseous 251

148

factor

as

bicarbonate

62

Treating

Multiple 274

system

Gas

Clays

friction

Moore

detection

48

274

268 Moody

274

analysis

Gas

of

53 55-57 61 53 250

Montmorillonite

273

cuttings

427

inertia

Montmorillonite

Motor

Gas

shale

definition

ash

66

407

additive

53 54 63

of

test

Treating

Multiple-string

Moineau

67-72

control

Treating

384 control

density

68 70

74

Mule-shoe

41

as

effect

51 pilot

70 71

70-72

in

control

Water-base of solids

entrained

50 53 60

Viscous

49

58

solids

and

Viscosity

64 65 22

settling

Functions

288

Criteria

117

15

lime in

Galena failure

118

127

as 116

control

Freshwater

207

density

as

type

Forced

207

117

gases

233

indicators

Foam

292

elasticity

failure

225

testing

Flow

362

of

65 Still

330

Field

of wellbore

trajectory

and

density

Filtration

357

in

drilistring

circulating

181

127

265

354

57

by maxi

content

Starch

density

51

suspended

387

64 73

Engineer

Equivalent

d-exponent

353

on

of

386

Systems

129

91

Modified

of

weight

Equivalent

Moderately

effect

solids

67-69

71 74

81

Solids

58

in

solids

122

368

drilling

Drilled Effective

247

247

mechanics

366

133-139

42-53

of

tests

of

12

117

of

kill

of

efficiency

175

Solids

154

114

Dilution

131

particle

Siren

Diagnostic rate

content

Sand

Screening

137

53 53

Sand

120

169

Penetration

51

289

Required

133

12

13

119

Mixtures

58

403

volumetric

Maximum 288 Mean 164

fluid

in

387

380

Salt-water

121

solids

222

types

Retort

117

437

103

mum

136-144

481

132

and

57

116

for

range

turbine

Pump

180 annular

381

417

14

Pits

Pump

67

373-376

405-411

68

330

283

132

176

Non-Newtonian 144

230

373-377

75-82 size

Pulser

117

66

solids

Effective

Kick

Mathematical

mixture

Equivalent

drilling

163

drillstring

of montmorillonite

Effective

181

base

Particle

Powered

additives

drilled

estimating

261

Newtonian

in

of

367

402

Preflush

Effect

transport

Empirical

343

Average

of

torque

470 Oil

293

components

366

385

Polymer

Average

Young

for

180

Mohr

170

Density

474-480

264

computer

Drilling

Mohr

169

61-64

Degradation

265

Computer cuttings

131

238

and

Bourgoyne

Mohr

167

constant

of

53

content

reverse

Motors

72-75

Bingham

Bit

54

in

384

Deflocculants

Models

Motor

67

Contamination

vertical

Montmorillonite

42

382

encountered

Cleaners

Compressibility

301

41

of

Composition

334

Microannulus

12-17

system

Classification

Clays

of cement

trend

284

290

288

stress

Principal

Water

364-366

method

ENGINEERING

DRILLING

123

126 in

state

law

fluids

166 model 150

126

steel

of

motion 130

137

131

136

173-175

127 155

viscosity

131 169

151

132 176

140

INDEX 497

Nominal

for

weight

threads

casing

and

Or

total

303

couplings

Nomograph

board

Ouija

derivation

angle

371

tory

Overbalance

223

Definition

Non-API

casing

Non-API

grades

connectors

Nonmagnetic

drill

392-394

fluids

Non-Newtonian

144

42

130

132

132

133

137

Nonsealer

219

bearing

drilling

on

penetration

gradients

Pressure

trend

246

of

content

of

Of mud

cement

87

slurry

44

additives

of

Solubility

223-225

rate

Ca2

of

264

283

of

casing

force

Overpull

mud

Oxygen

as

of cementing

properties

Oxygen

scavenger

in

points

73

sheaves

mud

of

Normalizing North

62

in

Strength

102

Yield

305

tension

312

strength

and

316

BHAs

Packed

Sea

on

279

velocity

Nozzle size

65

Parasitic

of hydraulics 230

rate

equation

velocity

of

selection

in

size

In

solids

mud

in

58

water-base

muds

ppm

definition

million

per

Piston

core

Pit

volume

Pit

volume

436

440

442

432

434

444-446

Off-center Offset

208

bit

214

215

194

197

209

Offshore Ohaus

wear cones

bit

of

211

221

exploratory

In

balance

Bit

Oil

41-43

muds

Materials

Companies

OCMA Oil-in-water Oil

muds

Oil

phase

Oilwell

74

79

muds 76 79

80

of

functions

277

limestones

278

As

on

effect

bit

Bit Bit

time

Rotary Ordinary

Organic

polymers

Orientation

Osmosis

of

102

102

through

sand board

diagram

366

Efficiency

of

mud

Efficiency

of

turbine

pump 413

affecting

259 211

weight

bit

for

data

Pore

224 bit

to

increasing

rotary

226

Percent

mix

Percussion

definition

tool

definition

used

of

in

94

of

of

Pore

of

90

air

drilling

48

236

403

422

muds 300

330

414

225

233

234

333

methods

pressure

for

estimating

252-254

of

254-259

using

pressure

well

259

drilling

plots

decline

Hudson

210

411

222

gradient

pressure

253-255

bits

441

logs

276

277

constant

Porosity-dependent

Port

341

PCD

221

Porosity

16

291

427

inertia

diamond

Verification

288-291

definition

290

216-218

While

weight

28 29

417

Prediction

correlation

by

286

ratio

344

Introduction

increasing

system

tensioning

198-201

238

to

377

196

Pore 264

107

technique

units

194

Polymer

weight

296

32

415

231

182

352

190-192

hydraul

260

213

response

Percent

bob

Polycrystalline

221-236

response

Pennebaker

Perlite

to

180

107

moment

Polar 240

226

speed

12

placement

Poissons

231

179

351

trend

Plug

343 232-236

152

offshore

Pneumatic

Reynolds

10

rig

cementing

Plumb

309-3

casing

44 60 64 70-72

150

Plug

229

Normalizing

Overall

and

weight

for

Typical

368

235

progresses

hydraulics

208

370-373

259

type

speed

relationship

Typical

475

Pleistocene

231

of

Factors

474 Platform

num

Reynolds

wear

bit

of 428

42

134

Platform

formation

bit

semipermea

76 77 77 250 93 94 97 98

232-236

equation

bit

358-362

342

133

31

of

Low

pressure

226-229

rotary

as

Normalized

x-y plotting water

ics

221

of bit of

well

449

flow

Viscosity

229

Logs

415

membrane

Osmotic

Ouija

366

91

61

Orthophosphates Oscilloscope

101

101

of bit

89

cement

drilling

deflocculants

Ottawa

with

Expected

Organic

ble

with

Equations

240

speed

rate rate

Change

Effect

238

Fracture

22 1-226

properties

conditions

number

240

weight

Drilling

240

221

230

229

characteristics

Change

Effect

220

life

373-377

237 rating

Deformation

230

220

Optimum

and

well trajectory

of

guides

Collapse

Salt

fluid

Decreases

226

rate

change

trajectory

Bit

230-232

function

ber

403-405

conditions

penetration

300

54

affecting

221

Penetration

284

theads

casing

Plastic

content

clay

wear

Operating

406

shipstocks

Operating

type

Penetration

oil

shale

Openhole

tooth

Bit

Formation

41

75-82

casing

Oolitic

Bit

35

factors

hydraulic

Drilling

55 emulsion

of

Oligocene

Assn

119

cements

303

directional

x-y

with rate

273 Oil-base

equipment for

353-362

34

depth

Reduction

moisture-determination

The 33

260

259 vs

Plot

Penetration

drilling

for

weight

trajectory

rate

formation

Logs 200

monitoring techniques

417-421

Penetration 224

223

sandstone

22

Planning

450

451

Obernkirchener

268

indicator

indicators

couplings

BHA 426 429

437

165

150

103-110

of

bits 201

Pendulum

149

23

position

Plain-end

PCD 102

additive

320

platform

Placement

68

140

equations

Rams

159-161

range

weighted

Parts

156

loss

308 137

Racking

48 277

logs

cement

156

maximum

bit

Partical

222

250

sieve

Deformation Eccentricity

Flow

102

losses

pressure ion

For

129

156

density

frictional

Partial

velocity

Nuclear

Nylon

411

effect

penetration

Nozzle

401

366

offset

Nozzle

Parasitic

451

444-446

Paraformaldehyde

Nozzle

318

338

Pipe

plates

61

Dakota

North

328

264

224

rate

Pacific

250 North

324

48

of

penetration

American

53 54 63

74

Pipe-body

contaminant

322 definition

cement

10

systems

92 Normality

API

of

91

tests

64

56

93

requirements

types

Pilot

325

49

alkalinity

Physical

Pickup 68

centrifuge

of

function

55

249

342

283

rate

as

Photomicrographs

Physical

247

61

72

materials

stress vertical

45

45

223

222

rate

224

282

88

45

Paper

268

Overpressure

277-279

282 Water

rock

264

Reduced

Overflow

247

256

line

and

223

Overburden

333

pressure

42

Phenolphthalein

Effective

258 pore

Pressure

86

223

on

Normal Formation

on

332

Determination

fluid

drilling

Effect

Static

roller

344

260

Effect

Range

model

169

342

Permeameter cement

Permafrost

pH

234

474-483

Non-Newtonian

144

of cements

trajec

Meter

permeability

113

fluids

175

389

403 behavior

drilling

of

Effect

379

well

376

224

Dynamic

305

collars

401

Non-Newtonian and

302

374

of pressure

370-372

of

of

change

372

271 field

249

parameter

276

280

283

276-285

APPLIED

ENGINEERING

DRILLING

498

cement

Portland

246 of

Composition Diatomaceous

93-96

earth

98 99

402

407-411

Positive

side

Positive

mud

Potassium

PDM

forces

at

14

431

430

bit

386

pulser

12

cement

In

mud

262

indicator

linear

Power-law

exponent

Power-law

fluids

Power-law

model

50

208

152 127

481

131

169

482

176

476

255

256

fracture

Preferred

32

costs

254-259

pressure

287-292

pressure formation

chip

449

theory

formation

250-252

268 in

Annular

downhole

leakoff

Surface

pump

Surge

113

Surge

inertial

outside equation

Drilling

308

333

312

305

internal

335-337

334

23

See

bits 244

drilling

processes

Circulating

drillpipe

Circulating

pump

casing

Production

liner

calcu

Example

301

19

Collapse 308-3

10

craters fluid of

the

301

of

19

Drillpipe

Drop

across

External

305

325

bearing

Relative

roughness

Relaxed

163

casing

337

334

247

fluid 417

130

420

305

308

333

336

340-343

209

253-285

Formation

estimation

schematic

hole

of

while

drilling

Formation

gradient

Formation

in

Formation

osmosis

Reverse

torque

335

234

246-285

336

287

extension

Fracture

259

methods

260

for

271

288

efficiency

of

types

278

284

285

Pressure

loss

140

141

148

150

152

156

163

166

171

176

181

Frictional

loss

for

Frictional

loss

in

144

145

160

162

12

12

157

143

flow

for

well

control

161

169

from

cement

displace

condi

operating

proper 161

counter

Stroke

record

275

bending

172

squeeze

Hydrostatic

236

263

265

415 416 and

PDM

419

133-139

176 476

Rheopectic

fluid

definition

time

analysis

Rig

113-119

121-125

163

426

weight

in

drill

415

of casing

59

61

73

133

190

bits

cutter

208-212

230

237

emulsifier

Rotary

drilling

222

194-199

216

195

bearing for

221-226

241

240

outer

Rosin

329

328 200-209

221

shear strength

Bearing

144

481-483

number

mechanism

failure

oil

muds

198 79

bits

wear

factors

affecting

219

220 326

Exercises

240-244

244

solids

71

72

245

236-240

Bottomhole of low-gravity

Quebracho

144

37

hardness

Nomenclature

Quality

137

212

gauge

Rockwall

Roller-type

278

108

136-144

481

131

127

law

202-204

97

cement

pressure

with

12

efficiency

force

132

169

229

Pumpoff

474-480

264

131

133

Roller

of 268

Pumpoff

261

133 155

132

Rock

22

12-14

of

131

127 150-153

Non-Newtonian

Rock

12-14

Stroke

Volumetric

155

Power

displacement

positive

160

42

176

Ring

tions

231

230

bit

144

127

152-155

of

of

233

Operation

High

of

definition

169

14

for

136-139

155 Gradient

motor

169

162

to

Selection

Pure

annulus turbulent

mud

of

plastic

134

150

116

casing

ing

106

cementing

process

Newtonian

schedules

Pumpability

147

102

404

models

Bingham

12

efficiency

Triplex

estimating

287-294 Frictional

131

horsepower

Single-acting

335

Fiacture Fracture

114

403

250

number

Rheological

12 268

BHA

382

out

Reynolds 156-158

Reciprocating

zone

75

slick

98-100

whipstock

Reversing

Mud

236

transition

pore

294-298

278

gradient

for

cement

for

15

Mechanical

Rated fluid

mud

oil

forces

Reverse

12

Liners

Pressure

288-290

259-276 Formation

254

side

Reverse-circulation 132

13

operations

Formation

definition

108

Overall

129

bit

204

200

of pipe

431

430

Pump

Hydraulic

306

164

corre

empirical

capacities

fluid-loss

Retrievable

definition

dampener

Factor

164

333

40

262

Retarders

61

Pseudoplastic

Horsepower

subsurface

Distribution

347

163

115

312

39

265

coefficients

McClendon

and

Relative

335-339

332

definition

60

gel

Pseudoplastic

Pulsation

308

345

163

fracture

413

analysis

Resultant

Production

Pulling out

336

307

339-343

and

298

373-377

Casing

188

pressure

drilling

340

333

pore

Rotary

Rehm

426-443

examples

Progressive

130

305-308

84

hydraulics

lation

259

333

129

472

drilling

fluids

Regression

172

lations

of

307

BHA

350

146 Problem

casing

of casing

171

167-170

of

349

Ill

Rotary

115

types of

213

for design

Regression

effects

127

117

drillstring

172

165

300

zone

343 rating

113 in

58

422

421

operations

Drilling

293

collapse

119-122

Balance

Burst

Reaming

Directional

342

164

Swab 164

Principles

275 278 transition

Backing

Burst

equation

resistance

247

77 250

Absorptive

torque

gas

Formation

Preventers

246

formation

Abnormal

Reactive

246-247

hydrostatic

Surface

392

gyroscope

of hydrocyclones

point

Cements 420-425

413-418

Tubing

Abnormal

cas

from

260

252

and

29

67

Casing

450 Pressure

cut

Real

127

Prediction

formation

cement

Subnormal

96

well control

for

Standpipe

Surface

216

196 204

23 24

or north-seeking

References

Subsurface

100

195

23

of

types

59

415

250

373

analysis

preventers

Rated

transmission

displace

off

366

373

372

of bit

cal

398

162-164

to

vector

Rams

116

ing

Ram

385

383

365

217

277

schedules

Pump

efficiency

Pozmix cement

Of

238

estimating

modulation

Pump

133-139

19

18

drilling

234

333

330 for

operations

153

relationship

Of

233

for

well trajectory

angle

310

102 method

diagram

Ragland

Rake

225

300

plots

Pump

Seal

93

277-279

308

pipe

347

tracers

culating

Rate

method

481-483

Pozzolan

256

262

steel

345

of curvature

Ragland

methods

Pulse

75

134

152-155

system

pore 246 247

252-285

montmorillonite

Power sub

Radius

77 250

279

343

Radioactive 333

line

gradient

of

stress

341

285

284

Pore

chromate

Power-law

trend

Osmotic

98

Potassium

Of

gradients

Pore

Potassium

Power

Normal

387

Radial

420

424

formation

282

335

108

squeeze

Normal

335

333

nozzles

jet

drillstring

Pore

75

Potentiometer

260

mud 333

Normal

450

414-422 pumps

chloride

In

144

101

motor

Positive-displacement

252

through

Low 93-96

displacement

376

Loss

86

mixtures

gypsum

Positive

in

usage

Losses

of

Pozzolan

247

Hydrostatic

99

Manufacture

With

86

85

Prevention

damage

assembly of

accidental

237

236 bit

237

INDEX 499

Selection

of

speed

bit

and

weight

rotary

Equations

237-240

Penetration

rate

for

135

affecting

fluid

model

Non-Newtonian hydraulics

Bit

tooth

Bit

type

Rotor

and

bob

rate

present

dimensions

137

for

230

229

fluid

properties

221

characteristics

178

Operating

conditions

Penetration

rate

References

226-229

equation

232-236

244

failure

Rotor

lead

Rotor

pitch

mechanisms

Failure mechanisms

204-209

of

drag

bits

used

148

by

At

wall of annulus

For

210 sandstone

222

209

of

roller

Of

cutter

481 on

evaluation

On

conduit

wear

Grading

bearing

Grading

gauge

Grading

tooth

wear

212

wear

357

212 212

run 220

221

affecting

214-219 Bit

weight

on

effect

of

rate

wear

217 Hydraulics

of

rate

on

effect

of

rate

on

effect

line

Sand

particle

of

rate

218

equation

Santa

219

190-194

PCD

diamond

191-194 Roller cutter Standard

system

cost

39

power

Schematic

5-7

monitoring

hose

Rotary

power

233

21-26

Setting

depths

235

27

of bit

Optimum

240

236 14

of

of

Selection

tooth

of

Sensors

Rotary

torque

during

Rotating

BOP

Rotating

time effect

Rotation lars

441

Rotation

of

Rotational

241

on

33

34

orbital

path

of

col

measurement

in

57

Bottom

view

of test

331

and

couplings

303 317

bit

431

304

319

306

321

323

vs

Side

collar

pendulum

length

435

rake

of bit

195

194

351

Sidetracking

353

420 421 93 94

flour

Silica

433-435 450

tetrahedral

373

55

56

16

gas

12-14

pumps

PCD

405

102

sheets

tetrafluoride

400

bit

192

profiles

Single-shot

wear

slurries rigs

card

461

pictures

Film disks

378

Gyroscope

392

216

Typical

101

Surveys

27 tool

436

386

136 instrument

61

74

Sizes of

control

98

cement

of cuttings

178 380

379

compass 284

Density

272

44

plot

442

test

Slick

assembly

Slick

BHA

Hydration

98

Porosity

trend

From

offshore

From

south

screen

Slip Slip Slot

277

time line

277-280

joint

429-432

436

388 for

program

drilling

lines

80 331

28-31 173-183

velocity flow

Sloughing

281

284

t42

equation

of

268

of

269 87

92-94

Slurry density Smackover

Smith Soda

F3 ash

t65 479

shale

Slurry consistency

Smectite

67

332

331

451

Examples

Miocene-Oligocene

15

of

416

426

Definition

273

Louisiana

282

shaker

274

281

Texas

Overpressured

209

412

selection

427

Slip-and-cut

data

resistivity

432-434

452

apparatus

data

377

line

406

444

impact

of casing

Slack-off

Slick

285 285

of

factor

Shale

441

403

402

RHA

11

definition

Formation

transit

400

Single-turbine stage

plot

Shaker

42

381

Single-tooth 74

381

operation

Single-stabilizer

56

Conductivity

wells

Diagnostic

385

381

442-446

441-446

Interval

441-443

drillstring

429

315

on

force

Silicon

209-214

velocity

Factor 265

drilling

viscometer viscosity

313

Compass

Conductivity

Shale

Apparent

55

bit

340

426

connector

Side force

Shale

25 of

339

threads

Single-acting

steering

clay

Settling

18

17

round

Silica

247

of

tooth

217

wear

237-240

table

thickening

model

330

cement

in

Sepiolite

manufacturer

Rotary

Short

Side

301

cement

133

sub

Side-entry

and

thixotropic

105

and

133

fluids

joints

Single-cone

bit

Shadow-graph

by

for

437-440

332-339

Sepiolite

systems

217

Recommended

220

406

Semisubmersible

239

227-229

Function

time

Shoe

220

332

331

Setting-time of

pseudoplastic

rate

fluids

324

332-339

332-339

Semi-solid

26

transmission

rate

for

434

casing

Sequestering

on

fluid

416-418

405

Self-sharpening

system

definition

Exponent

power-law

plastic

27-32

speed

Effect

for

237

100

237 Rotary

rate

307

of casing

on

Grade

Weight

system

function

219 219

compaction

Selection

control

shear

subs

58

manufacture

effect

Sizes

17-21

equipment

Well

Rotary

casing

Couplings

of

Well

fluid

loading

305

40

marine

Special

mechanism

connectors

for

Newtonian

Shock

195

assembly

bearing

mill

for

7-12

system

system

Rotary

roller

Sediment

Nomenclature References

journal bearing

Selection

system 40

56

mud

in

Sealed

Section

12

solids

98

rate

CSG

bearing

time

37-39

Hoisting

295

291

microscope

Sealed

Seawater

32-37

3-5

team

Exercises

12-17

shear

Shock

105

Seamless

analysis

rigs

Drilling

196-200

Bingham

rheopectic

stopped

channel

Sealed

Sealing

of

process

Circulating

Drilling

175

42

of

for

shear

Vs

diameter

mud

electron

194-200

classification

drilling

Drilling

Vs

if circulation

Scratchers

rate

135

51

maximum

Barbara

190-200

Polycryatalline

pressure

134

dilatant

by

settling

Screening

Rotary

mud

of

screen

Sand

Vs 74

of

definition

377

suspended

Scanning

wear

33

of

frictional

132

214-217

available

Drag

Rotary

content

Sand

liquid

139

shear

Vs

423

55

water

muds

Sand

419

250

175

height

wear

Rig

of

217

wear

Tooth

Salinity

Sand

speed

Tooth

gradient

wear

218

217 Rotary

Types

on

effect

354

fluid

333-336

factor

Salinity

Saltwater

353

wellbore

Vs

362

358

Safety

211

factors

of

trajectory

wear wear

Static

209-214 214

213

bit

Terminating Tooth

wall

to

gradient

Abnormal

in

482

479

477

point

particle

475

474

476 481

fluid

182

Relation and

131

fluid

yield

falling

209

208

Selection

143 178

relation

than

141

Failure mechanisms

32

wall

power-law

Less

204-208

bits

en

208

stress pipe

Exerted

drilling

207

rock

At

Equation

146

pipe

Springs

of

144

143

determination

Empirical

thumb

gineers Rush

181

409 of

of

136

409

Roughness Rules

in

374

steel

23

Strength Shear

22 1-226 Standard

Formation

Rate

135

136 Shear

of

Rams

137

221

Drilling

Rock

Shear

136

model

fluid

230-232

wear

138

Modulus

Newtonian

221-236 Bit

136

474-476

factors

trend clays bit as

301

55 232

mud

treating

agent

63

482

500

APPLIED

Sodium

Stands

Acid

SAPP

pyrophosphate

Bicarbonate

mud

as

59-64

62

Chloride

in

102

in

Bentonite

Gel

in

decahydrate

Well

cement

downdip

mechanics

and

93

fluids Solids

of

effect

Control

drilling

unweighted

Control

in

weighted

53

71

71

type

70

muds muds

weighted control

for

57-60

Strength

variance

muds

weighted

pipe

Strip

67-72

67-72

Stroke

pump

68-70

of low-gravity content

71 70

solids

function

as

72

Subnormal

71

Subsea

pH

of

72

procedure

73

280

Soundness

of

China

South

Pole

cement

Sea

103

89

33-36

279

Texas

410

411

of

Definition

300

Leakoff

pressure

293

barites bentonite

Porosity

constant

257

268

Pump

Watch 55

Sphericity

86

173

potential

log

46

loss

Squeeze

cement

definition

Spontaneous

283

100

103

Squeeze

packer

Stability

analysis

Stability

force

assembly

125

108

Surge

chamber

Surge

pressure

342

Due

to

vertical

In

345

346

348

237

396

400

429

432-444

377

Typical

pressure

Standardization

of

Standardization

of

105

Standpipe

movement

Swab

casing

113

designed

364

borehole

365

of

165

167-170

view

Definition

cement

Power

definition

91

of

14

Texaco

Gibbons

barge

drilling

75 258 259 280 290 297 301 389

285

coast

gulf

283

284

area

248

266

284

290

291

267

344

ball

446

449

450

340

343

344

control

to

pertaining

investigations

deviation

on

Wells

332

of

87

time

of

Three

19

roller

for

stabilizer

437

WOB 437 various WOB 431

Cements

89 91

bit

cutter

403

bit

194

416

417

441

moments bit

method

equations

weight

226

227

221

222

236

Thribbles and

slurry

97-101

or tn-cone

234

bit

of cement

time

422

344

processes

definition

Three-

17

increasing

428 casing

Thickening

Threshold

Length

C4AF

25

Three-cone

17

14

90

From

51

aluminoferrite

86

Threshold

Between

50

hardness

94 95

91

92

42 44

51

content

Thickening 17

requirements

requirements

45

viscometer

Recovery

Tangency

content

44

determination

Effects

accuracy

164

pressure

Gooseneck

AP1 89

by

industry

51-53

retort

Conductivity

171

pattern

302-305

drilling

requirements

420-425

42

balance

Sand

50

42

funnel

Thermal

Cutaway 413-418

of clays

47-49

concentration

Theoretical

400-402

Bail

89 90 Water

382

469

tool

Physical

pipe

filtration

capacity

analysis

Marsh

Thaw 172

Swivel

180-Stage

Construction

380

418 426 427

104

Standpipe

Classes

14

165 effects

azimuth

Surveying

379

405-407

cementing

Chemical

20

19

subs

Stabilizers

of

hydraulics

drilling

Survey

Stabilizer

exchange

277-279

164

inertial

fluids

drilling

50

pressstatic

Chemical

Texas

to

strength

88

of

49

filter

85

400

169

Due

and

86

diagnostic

Texas

definition

86-88

soundness

Tetracalcium

164-172

127

plot

421

multishot

magnetic

Definition

95 99

108

280

278

383

Equation

47

cementing

107

for

operation

310

452

446

cement

Rotational

392

gyroscope

of casing

strength

103

Water

tachometer

305

53

pH

342

pressure

Recording

72

molds

Specimen

113

332-335

330

343

342 in

strength

sediments of

Mud Mud

Casing

Reading

For

distribution

328

422

Specifications

For

344

340

pressure

257

269

of

Examples

hydrostatic

of casing

340

45-47

casing

pressure

Sulfide cracking

shale

Spalling

Tensional

AP1

247

Surface

Frio trend

Union

339

Chloride

Subsurface

401

conditions

Cation

fluid

8-11

305-307

Alkalinity

pressure

on

344

340

line

Permeameter

installation

effect

Subsurface

pipe

Tests

247

test

South

Soviet

of

definition

principle

log

14

of 107

31

Subsidence

302

casing

334

339

Fineness

barges

formation

ln

89

of

equipment

steel

Consistometer

23

definition

drilling

drilling

Testing 329

24

definition

Submersible

determination

Ca2

of

of

ln

Tertiary

safe

of

operations

liner

86

cement

451

maximum definition

19

333

332-335

89

cement

Stripping

Stub analysis

of

428

metals

of

stress

Pipe-body

machine

testing tests

429

89

drillpipe

Loading

about

172

particle

level

344

concept

movement

Strength

Stress

unweighted

Centrifuge

of

and

Diagram

413-415

design

426

or unit

44

strength

Design

208

gauges

101

386

column

alloys

Of

343

Tension

421-426

PDM

the

Strength

control

Solubility

of

definition

calculation

61 98

383

Of cement

drilling

Streamlines

freshwater

for

weight

Tensile

Of

175

turbine

settling

of low-gravity

Vs mud

Solubility

173

Strain-limit

Fraction

Solids

127

192

material

law

Strain

70

calculation

Quality

drag bits

Using

81

muds

oil

Example

Solids

382

310

347

stress

gel

Tensile

Using

Determination

For

384-387

of

Stokes

68

systems

For

definition

381

Straight-hole for

equipment

muds

10-mm

conditions

308

pipe

trajectory

59

Telemetry

409

cutter

of

Teledrift

409

tools

Stiffness

113

60

systems Control

Solids

pitch

345

Tensional

slick

428

for

equipment

Quality

lead

Stator

Steel

118

117

Stator

mud

of

content

conditions

Steering in

for

steel

366

Tannins

Steady-state

94

entrained

gases

450

247

model

hydrocarbons

Solids

446

theory

343

363

solution

440

343

stress

stress

Method

102

441

432

assembly

Tangential

Hoop

47

rates

431

pendulum

341

structure

BHA

100

Solid

441

Quasidynamic 99

cements

Soft-to-hard

Stage

65

45

Filtration

64

Tetraborate

South

control additive

algorithm

Filtration

see

Polyacrylate

Sonic

Point

filtration

BHA

of

Length

Compressive

BHA

64

102

Montmorjllonjte

Silicate

98 99

cement

Chromate

Spurt

as

of

definition

146

Static

CMC

Carboxymethylcellulose

Soil

chart

Starch

agent

treating

of driflpipe

Stanton

ENGINEERING

DRILLING

Thixotropic

209

force in

27

drilling

fluid

Thread

compounds

Thread

run-out

definition

303

303

133

429

233

INDEX 501

Tie-back

dcfinition

liner

Time

mud

in

delay

Time

301

casing

Tieback

for

110

for

line

drilling

462

check

Tool-face

orientation

Tool-face

setting

418

377

379

370-372

Tooth

376

of

variations effect

height

vear

on

of

Guide

time

chart

milled-tooth

of

bits

Tooth

for

wear

of hydraulics

Effect

of of

tooth

218

bits

218

219

413

flow

413

TFA

area

of bit

412

218

planning

Control

470

directional

for

well

during

drilling

directional

353-357

hold

Build

hold

Build

hold

and

357

Direction

451-453

quadrants

and

Multiple

357

targets

358

358-362

422-424 criteria

Turbulent

430

functions

Between

145

laminar

and

circular

flow

turbulent

Mode

of casing

Transition

zone

above

Formation Higher

253

Transmission

in

plot

flow

169

145

pipe

147

for

pipes

and

in

of

pattern

electron

152

stress

of pipe

geometry

equations

149

equations

145-148

Power-law

model

152-154

BHAs

Two-stabilizer

pendulum

289

290

165

flow

on

25

system

283

65

polymers

222

sandstone

137

136

rotational control

cement

for

muds

oil

of

101

102

80

diesel

75

oil

drag

Volume

173

requirements

171

cement

of

108-110 to

Volumetric

efficiency

pump Of pump 419

12

412

turbine

330

zones

lost-circulation

Vugular

434-436

437

444

Wagner Walker

104

cementing bit

291

19

of

Two-stabilizer

of

248

279

Viscous

Of

155

fluids

number

289

291

pattern

stresses

Of mud

150

Newtonian

definition

288

165

trend

Viscosity

148

flow

annulus

Viscometer

Of

150

150-152

flow

pressure-loss

154

50

profile laminar

Viscosity

annuli

criteria

model

annular

Type

325

286

Overburden

Virginia

connections

105

178 Walnut

198

268

89

turbidimeter and

179

181 lost

shells

91

correlation

Mayes

176

182 circulation

additive

101

of

gradient

pressure

Shale-density Transitional

254

angle

gradient

Vinyl

turbulence

plastic

flow

solution

stresses

Vieksburg

models

surface

in

laminar

for

EDTA

Vibrational 155

146

Extension

Two-stage

penetration

abnormal

338

285

pressure

in

155 loss

equation

flow

176

182

292

445

geothermal

Increase

325

failure

278 of

Definition

310

309

casing

profiles

Additives

Simplified

Twist-off

of

152

circular

of

181

correlation

Overburden

In

fluid

iii

175

fluids

165

Matrix

For

pipe

173-175

Mayes

179

Vertical

147

174 176-182

fluids

and

178-183

ratio for

correlation

Deviation 450

155

pressure

181

Vertical

152

summary

148

Collapse

Moore

Versenate

132

Frictional

fluids

drilling

176-179

transport factors

139

flow

Frictional

Transition

correlation

Velocity

422

Turbulence

of

capacity

Friction

426

423

Turbodrjfl

365

trajectory

slip

Non-Newtonian

410-413

deviation

412

for

method

176

Walker

149

compass

353

Transcendental

209

91

operating

range

Bingharn

wellbore

216

423

control

Alternate

358

schemes

Into

motor

Turbulent

build

204

combination

and

gyro 399

readings

particle

Carrying

224

combined

well

Cuttings bits

160

hold

357

Continuous

268

182

drilling

penetrator

223

of

averaging

Newtonian

tool

bit

Resistance

and

drop

Modified

Of

451

drop

partial

column

liquid

limestone

178

Patterns

and

16

15

degasser 387

analysis

Chien

195-197

Non-Newtonian

well Build

414

381

427-429

in

86 89

deflection

To

In for

planning

use

carbide

Definition

383-388 Trajectory

chamber

actuator

Velocity

354-357

234

Equation

measuring

19

drillpipe

250

area

accelerometer

115

statistics

192

229

36

452

pressure

Correlation

451-453

353-362 Tools

352

351

well

363-365

for

Planning

377

373

for

of deviated

Coordinates

Data

191

Torque

Trajectory

Change

348

TVD

carbide

Operating

411

turbine

279

416

Vector

330

characteristics

419 for

curves

237

column

Drilling

PDM

Power

x-y

Tubular

As

well

265

391

thread

coast

Variable-density

Turbine

Converters overthrust

west

of handling

22 25 33

depth

Diamond

Of

U.S

calculating

Turbidirneter

214-218

because

363-365 451

Tungsten

217

Torque Of

Standard

chart

12-14

collapse

217

217

height

218

Equation

127

361

217

speed

rotary

of

definition

4.44

vertical

19

Effect

Effect

230

of

weight

isogonic

U.S

Vector

operations

Tungsten

bit

293

Vaurion

pumps

Tubing

roller-cutter

rate

of

Effect

229

214

of

operations

increased

113

238

235

Parameters Rate

214-219

affecting

Dullness

289

Vacuum

stabilizers

True

Factors

288

75 248-250

264

275

22

Tripping

for

57

area

259-262

Utah

33-36

Triplex

212

Total

Tanks

216

214 211

of

411

definition

22

drilling

Time

rotating

19

407

270-273

of tooth

rate

coast

255

Valve

Time

dragged

Grading

86

gulf

252

U.S

204

of bit

function

Cone

85

93

cement

operations

gas 274

Trip

In

of bits

214-217

wear

C3A C1S 85

86

Trip

responsibility

design

391

of

375

19-21

pusher

Tooth

452

270

drilling

Trip tanks

joints

U.S

451

aluminate

421

402

446

silicate

389

States

68

of

definition

413

mud

for

63

Litc_wateTM in

Trip

United

calculating

of centrifuge

rate

of drillpipe

Upset

365

needed

Trichloroethane Trinity

386

indicator

373

414

386-388

Tool-face

As

370

for

sediments

Tricalcium

369

angle

382-384

Tooth

Triassic

Tricalcium

drift

Tool

method

agent

Underfiow 178

definition

well trajectory Treating

182

178

contaminant

definition

Tool-face

Tool

velocity

47

service Tool

ratio

Transport

86

gel

Ton-mile

Transport

Trapezoidal

cementing

42

apparatus

Tobermorite

268

logging

requirements

Titration

107

of

Water

275

268

Activity

259

Ultimate

272

302

182

micrograph

tensile

of casing

328

Undercompaetion 56

strength

Underground

Base 234

blowout

119

in

calcium

and

sodium

78

chloride

muds

41 43

Content

control

Content

of cement

in

54-75 oil

muds

slurry

87

81

90

92

APPLIED

502

Of

41

emulsion

of

Schematic

79

Surface

250

hydration

Phase

50

of

definition

Hardness In-oil

76

of cementing

materials

94 log

283

mills

Wedging

64

polymers

Watermelon

exponent

Weight

function

73

405

of

action

Weight

bit

drag

of bit

cutter

227

of bit

233

205

228

235

236

239

WOB

bit

on

Weight

411

413-417

431

433

382

419

434

389

390

421 422

430

436-443

445

Weight

Well

in

74

to

using

154 formation

verify

of

percent

Weight

Conductivity

measurement

Introduction

276

transit

system

Well-monitoring

unit

Well

test

trajectory

of

334

332 with

casing

liner

Control

332

335 Production

conditions

in

of

control

Annular

well

operations

Initial

conditions

Pump

pressure

162- 164

during schematic schedules

Wire 119-122 119 for

373

279

379

Ton-mile

Of

308-3

of

180

10

310

failure and

alloys

casing

324 428

metals

302 306

steel

Youngs

Zamoras

309

308

327

328

341

modulus

286

326

340

344

428

on 11

empirical

correlation

262

263

of diameter lines

usage

179

of

10

strength

of

151

378

rope

Projection

44 59 60 64

134

283

definition

Measurement

133

477

344

368

overshot

Breaking

mud 42

90

475

474

strength

417

trend

Wireline

of

Of

79

366

Wildcat

128

Point

Of 75

agents

Wilcox

pressure

80

79

agent

128 127

79

402-405

129

of fluid

54

of

definition

Point

Yield

of

definition

clay

Of cement

Collapse

muds

oil

nonstatjc

balance balance

363

Definition

Wetting

Of

Mode

Whipstock 116

manometer

Energy

335-339

332-334

casing

as

Mass

332

casing

91

70 71

364-366

curvature

Reversal

Surface

364 363

362

89

methods

Wettability

casing

Intermediate

Yield

schedules

363

averaging

Tangential

of

26-28

for

Minimum

additive

90

selection

Intermediate

cement

of

358-362

259

calculation

to

planning

277-280

Well-monitoring

Well

280-285

56

techniques of well

trajectory

277

time

stimulation

diffraction

X-ray x-y

Interval

65 69

114

circulation

initiating

55 57

89

21-26

system system

logs

416 bentonite

Wyoming

127

Introduction

definition

Well

fluid

Angle

450-453

Well

control

Well

pressures

pressure

Soluble

Well

Well

Well SP

from

computed

Resistivity

downhole

drillstring

muds

oil

Requirements

Wyoming

119

of and

ENGINEERING

DRILLING

rig

10 floor

Zero Zinc

basic

agent

spin

axis

of gyroscope

carbonate

62

63

as

mud

392 treating