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Author's personal copy Electric Power Systems Research 103 (2013) 129–136

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Electric Power Systems Research journal homepage: www.elsevier.com/locate/epsr

Effect of electromagnetic field of overhead transmission lines on the metallic gas pipe-lines Ossama E. Gouda a , Adel Z. El Dein b,∗ , Mostafa A.H. El-Gabalawy c a

Department of Electrical Power and Machines, Faculty of Engineering, Cairo University, Egypt Department of High Voltage Networks, Faculty of Energy Engineering, Aswan University, Egypt c Fayum Gas Company, Member of E–K Holding Group, Egypt b

a r t i c l e

i n f o

Article history: Received 15 July 2012 Received in revised form 13 April 2013 Accepted 6 May 2013 Keywords: AC corrosion Conductive coupling Inductive coupling OTHL Pipeline

a b s t r a c t This paper presents a study of the overhead transmission lines (OHTLs) electromagnetic fields effects on the metallic gas pipelines. The inductive and conductive voltages between the overhead transmission line and metallic gas pipelines, in normal operation and under phase to ground fault condition of the overhead transmission lines, are calculated. ATP software is used to simulate the OHTL under faulty condition. MATLAB program is used to calculate the induced voltages taking into account the effects of various parameters, such as: separation distance between the OHTL and the metallic gas pipelines, case of transmission line (phase to ground fault condition or normal operating condition), the screening factor and the soil resistivity on the magnitude of the induced voltage along the length of the metallic gas pipeline. The method used to calculate the induced voltage by inductive is based on the well known method “distributed source analysis”. Case study, to measure the induced voltage on the metallic gas pipelines from OHTL under normal operating condition, is presented. The comparison between the measured and calculated results shows a good agreement between them. © 2013 Elsevier B.V. All rights reserved.

1. Introduction Corrosion of the metallic pipelines can be described by many ways, such as mechanical corrosion and chemical corrosion. Mechanical corrosion of the metallic pipeline occurred if the pipeline is cracked by over pressure, over temperature, or under temperature. Chemical corrosion of the metallic pipeline occurred if the pipeline is conducted by low activity chemical materials, where a galvanic cell is formed. High activity materials in this cell act as anode, while the low activity materials act as cathode. AC corrosion of the pipeline is a combination of these types of corrosions. This AC corrosion is occurred if there is an induced AC voltage on the pipeline by the interference effect between the pipeline and neighboring power transmission lines. This voltage increases the chemical activity of the pipeline, which acts as anode, hence the corrosion rate increases. There are many mechanisms that describe the pipeline induced voltage by the interference effect. These mechanisms depend on the type of coupling (capacitive, inductive and conductive) between the pipeline and the power transmission line. There are many hazards appear due to the induced voltage on the

∗ Corresponding author. Tel.: +20 1228008458; fax: +20 973481234. E-mail addresses: [email protected], [email protected] (A.Z.E. Dein). 0378-7796/$ – see front matter © 2013 Elsevier B.V. All rights reserved. http://dx.doi.org/10.1016/j.epsr.2013.05.002

pipeline. These hazards can be subject of workers to high potential, damage of the pipeline coating and corrosion of the pipeline body. An actual case study is presented in this paper and actual measurements are carried out. The actual case study is the Fayum metallic gas pipeline in which three transmission lines are parallel or crossing it, as shown in Fig. 1. Fig. 2 shows the Fayoum gas pipeline-power line geometry, which is taken as an actual case study in this paper. Also, this figure shows the variation of the soil resistivity along the length of the pipeline. The leakage and stray currents on the metallic pipelines created by the induced voltages are calculated and measured. Also the rate of corrosion of the metallic gas pipelines that happened by induced voltage is calculated. The pipelines are buried by depth of 1.5 m, according to the Egyptian Petrochemicals Holding Company specifications for the transmission pipeline of nature gas code and the international standards (IGEM) [1,2]. Hence, there is no effect of the capacitive coupling on these buried metallic pipelines because there is essentially no electric field transverse to the direction of the power line at that depth below the earth’s surface [3,4]. Many researches dealt with this topic such as: Dawalibi et al. carried out computations for the analysis of electrical interference between power lines and gas pipelines [5]. Dan D. Micu et al. investigated the evaluation of induced AC voltages in underground metallic pipeline and deals

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Fig. 2. Fayoum gas pipeline-power line geometry.



wires and IZ presents the effect of the ground wires. This mutual impedance can be calculated as follows [8,9]: 

Zph&pipe = Zph&pipe × Ksf

(2)

 Zph,pipe = 0.04935 + j0.14468log10

 where Dph,p =

De Dph,p







= Zph,pipe  ∠

(3)

(xph − xp )2 + (yph − yp )2 , (xph , yph ) are the coordi-

nates of the phase conductor, (xp , yp ) are the coordinates of the



Fig. 1. Fayum gas pipeline geometry, where the three transmission lines are parallel or crossing it.

buried pipeline, De = 658 /f [10],  is the soil resistivity,  depends on the ratio of (De /Dph,p ), hence it may be positive or negative and Ksf is the screening factor which can be calculated from the following relation [11]:

with parameters affecting such interference from double circuit power lines [6].

Ksf = 1 −

2. Pipeline induced voltage 2.1. Inductive coupling between pipelines and OHTLs Pipeline induced voltage, by the inductive coupling mechanism, depends on the load currents of the overhead transmission lines, the separation distance between the overhead transmission lines and the pipeline, and the soil resistivity [7]. The method used to calculate the induced voltage by inductive in the buried pipelines due to the power frequency (50 or 60 Hz) power line is based on the well known method “distributed source analysis”, which is fully explained in [8,9]. In this technique the pipeline and its surrounding earth form a lossy electrical transmission line, which characterized by the propagation constant; , and the characteristic impedance; Z0 . In this technique the inductive voltage is calculated with the help of the longitudinal driving electric field; Ez , which is along the path of the pipeline, and is calculated as a contribution of each phase current. Hence, Ez can be positive or negative, and it can be expressed as follows [8,9]: 

Ez = Iph a Zph&pipe



a

+ Iph b Zph&pipe



b

+ Iph c Zph&pipe

c

+

 

IZ

(1)

where: Iph is the current of each phase a, b and c; Zph&pipe is the mutual impedance between each phase a, b and c of the power line and the underground pipeline including the effect of ground

M12 L2

(4)

where M12 is the mutual inductance between the earth wires and each phase of the power line and L2 is the earth wire inductance. In case of non-homogenous and multilayered soil, other formula for the mutual impedance like that in [12,13] can be used. Finally, the inductive induced voltage at any distance x along the length of the pipeline is calculated as follow [8,9]: V (x) =

Ez (x) 

−Z 1

Z1 + Z0

e−x +

Z2 e−(x−Lp ) Z1 + Z0



(5)

where Z1 and Z2 are obtained by the Thevenin equivalent circuit, Lp is the pipeline sub-section length, where the pipeline is subdivided into many sub-sections, each of them is assumed to be less than 10 km. In this case study, the actual measured value of the soil resistivity for each pipeline sub-section length is used in the calculations; hence the non-homogenous soil effect is ignored in this study. 2.2. Conductive coupling between pipelines and OHTLs In conductive coupling phenomenon, the flowing of the currents through the ground raises its potential. Ground potential decays as the distance from the current discharging point increases. This means that, the ground potential is increased in the domain. Also, as the discharged current increases, the ground potential increases. So, if the buried pipelines are located in this domain, they will be subject to this potential. The ground potential will be very high in case of grounding fault conditions of the overhead transmission

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lines, where heavy currents will flow through the ground in these cases. So, ground potential domain will be increased under fault conditions [14]. Pipeline induced voltage may exceed the coating strength of the pipeline. So, the pipeline coating may be damaged [7]. Actually, all types of grounding faults are studied, and it is noted that; single line-to-ground has the highest short circuit current. Hence, in this paper, AC induced voltage is studied for this type of fault only. ATP software is used to simulate the overhead transmission lines in case of line-to-ground fault condition [15]. In this paper, it is assumed that the line-to-ground fault is occurred at each kilometer along the overhead transmission line. Simultaneous of single line to ground faults at different points are implied. Hence, the fault current is obtained at each kilometer along the overhead transmission line, using ATP software. From these fault currents the induced voltage along the length of the pipeline is calculated. The magnitude of ground potential rise Vg can be calculated as follows [14]: Vg = Ig Rg

Fig. 3. The Cu–CuSO4 reference electrode.

(6)

where Vg is the magnitude of ground potential rise, and Ig is a part of the fault current, which can be calculated from the following relation: Zt Ig = K I 2Rg + Zt sf f

(7)

where If is the total fault current, and Rg is the resistance of grounding system of power lines tower. Assuming each tower has four legs; each leg is grounded with a vertical rod, and then Rg can be calculated as an equivalent resistance of these four vertical rods as follow: Rg =

 8L

4L

ln

r



−1

(8)

where L and r are the grounding rod length and radius, respectively. The total zero sequence impedance of the overhead earth wire and surrounding power line towers can be calculated using the following relation [7]:



Zt = 0.5 Zs +



Zs (4Rg + Zs )



(9)

where Zs is the zero sequence impedance of the overhead transmission line earth wire. The conductive voltage at any point x along the length of the pipeline can be calculated as follows: Vx = Vg

re xl + re

(10)

where re is the equivalent hemispherical ground electrode radius, which can be obtained by the following relation: re =

L

8L ln

131

2r



−1

(11)

and xl is the distance between the grounding grid and the pipeline. 3. Experimental study Pipeline induced voltage is measured using digital voltmeter and copper/copper sulphate (Cu–CuSO4 ) reference electrode. The Cu–CuSO4 reference electrode is a simple electrochemical or galvanic cell like a battery uses a chemical reaction to create an electric current. A cell of this kind is divided into two half cells, each of them contains a reactant in a solution, called the electrolyte [16,17]. One common type of half cell contains a copper electrode immersed in an electrolyte of dissolved copper sulfate, which is shown in Fig. 3. The measurement method is illustrated in Fig. 4. Measurement of potential between a pipeline and a copper/copper sulphate

Fig. 4. Illustration of the induced voltage measurement.

(Cu–CuSO4 ) reference electrode is performed by placing the electrode over the pipeline with the porous plug in firm contact with moist earth. In extremely dry areas the earth around the electrode should be moistened with fresh water to enable good contact and thus eliminate reading error. The soil resistivity, along the shared corridor, around the buried pipeline is measured using the driven rod method. The driven rod method (Three Pin or Fall-of-Potential Method) is normally suitable for use in circumstances such as transmission line structure earths, or areas of difficult terrain [18,19]. 4. Pipeline coating discharge Pipeline coating is deteriorated by many factors. Eddy current is one of these factors, where this current discharges from the pipeline to the soil through the coating by capacitive effect. Coating discharges affect the pipeline coating in case of normal operating conditions, but they have a series effect under fault conditions of the power lines. The resistance, reactance and impedance of the pipeline coating can be calculated from the following relations [20,21]: Rct =

Ru 2rx

(12)

Xct =

e ω2εo εr rx

(13)

where Ru = c e = 10 M, c is the pipeline resistivity, rx is the pipeline radius, εr is the coating relative permittivity, and e is the coating thickness. Zct =



2 + X2 Rct ct

(14)

The discharge current can be calculated by the following relation: Idisc =

Vac Zct

(15)

where Vac is the pipeline induced voltage in steady state conditions or in line to ground fault conditions. It is the sum of the voltage induced by the conductive coupling and inductive coupling in the case of line to ground fault.

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Corrosion rate (g/cm2 yr)

1.2

1

0.8

0.6

0.4

0.2

0

Fig. 5. Pipeline coating air bubbles created by corrosion on Fayum gas pipeline.

0

50

100

150

200

250

300

350

400

450

500

AC current density (A/m2)

5. AC corrosion of gas pipelines

Fig. 7. Corrosion rate according to the current density.

Always underground natural gas coated pipelines are cathodically protected against corrosion threats. Corrosive factors affecting the pipelines are soil resistivity, water content, aeration, pH value, soluble salts content, redox potential and pipeline to earth potential [22]. Usually pipelines coating has small defects after lowering process [22]. Fig. 5 shows pipeline coating air bubbles which are created by corrosion on Fayum gas pipeline and Fig. 6 shows AC corrosion of the same gas pipeline. AC voltage induced on gas metallic pipelines, if they are constructed near to power transmission line creates AC current flows through the coating. Pipelines corrosion is occurred by this AC current, if that corrosion current exceeds the DC current that is supplied by cathodic protection system [22–30]. The current density in metallic pipelines is calculated by the following relation [23]: Iac =

Vac 8Vac = R.A dct

(16)

2 = (1/4)d2 are the spread resiswhere R = /2dct and A = rct ct tance and the area of the circular holiday, respectively. Iac is the current density,  is the soil resistivity and dct is the diameter of the circular holiday. Vac is the calculated induced AC voltage in the pipeline.

Fig. 7 shows the empirical relationship between the corrosion rate and the AC current density. This relation is obtained from many researches. This relation shows that if the AC current density is 20 A/m2 , AC corrosion occurred by rate of 0.2 g/year [24]. 6. Induced voltage in metallic gas pipelines (Fayum gas pipeline: case study) Simulation of the overhead transmission lines under normal operating condition and phase to ground fault conditions are done using ATP software [15] that to calculate the phase current in both the normal and faulty conditions. Then, the pipeline induced voltages due to the neighboring overhead transmission lines are calculated by feeding the outputs of ATP to MATLAB program. Fig. 2 shows Fayoum gas pipe line geometry, where the three transmission lines (El-Kurimate-Cairo power line, Samaloute-Cairo power line, and Dimo-6th of October power line) are parallel or crossing it. The data of these lines are given in appendix A. The Natural gas is supplied to Fayum area, through 72 km steel buried pipeline of diameter equals 16 inch. It is coated by three layers of High Density Polyethylene (HDPE), which has a resistance of 106 /m2 , relative permittivity of 5, and its thickness is 4 mm. The pipeline is buried at depth of 1.5 m in the soil. The soil resistivity varies from 2500 to 100  m Pipeline pathway, is in parallel to three high voltage overhead transmission lines with different separation distances. These distances vary from 35 m to more than 6 km, as shown in Fig. 2.

50

Calculated Measured (summer) Measured (spring) Measured (autumn) Measured (winter)

Pipeline induced voltage (V)

45 40 35 30 25 20 15 10 5 0

0

10

20

30

40

50

60

70

Pipeline length (km)

Fig. 6. Pipeline AC corrosion on Fayum gas pipeline.

Fig. 8. Pipeline calculated and measured induced voltages in normal operating condition of the transmission lines.

Author's personal copy O.E. Gouda et al. / Electric Power Systems Research 103 (2013) 129–136 Table 1 Effect of homogenous and non-homogenous soil resistivity on the induced voltage.

With non-homogenous values of the soil resistivity, 1 = 100  m, d1 = 2 m; 2 = 500  m, d2 = 3 m and 3 = 800

2.9217 2.3861 2.7175 4.9205 31.8935 38.0252 30.4265 4.8874 2.2777

2.9478 2.4074 2.742 4.9561 31.9584 38.0944 30.4903 4.9229 2.2977

Fig. 8 shows a comparison between the measured induced voltage at different seasons and the calculated induced voltage in case of normal operation of overhead transmission lines, along the length of the pipeline. Pipeline induced voltage is measured during different seasons because the power line current differs from season to season. Also the seasonal change in the soil resistivity leads to change in the induced voltage. The induced voltage is calculated and measured in case of loading El-Kurimate-Cairo power line by 664 A, Samaloute-Cairo power line by 1150 A and Dimo6th of October power line by 486 A. Pipeline AC induced voltage is measured monthly according to Fayum Gas Company maintenance plan that to investigate the effect of power lines currents on the pipeline, where these currents change monthly as they change daily but within −5% of the rated values that used in calculations. Also, from Fig. 8 it is seen that the differences between the calculated induced voltages and measured values, which are taken at different seasons, along the length of the pipeline, are very small under the steady state condition. The effect of non-homogenous soil resistivity is calculated using IEEE 80-2000 [31]. The results, given in Table 1, compare the induced voltages at some points along the pipe line. The tabulated induced voltages are calculated using homogenous values of the soil resistivity  = 100  m (which equal the actual measured values of the soil resistivity at these points) and nonhomogenous soil structure contains three layers (1 = 100  m, d1 = 2 m; 2 = 500  m, d2 = 3 m; and 3 = 800  m). It is noticed that the variation between the values of induced voltages, which related to the values of the homogenous soil resistivity and the values of the non-homogenous soil resistivity, at each point along the length of the pipeline is very small. That is because the pipelines are buried in the upper layer. Pipeline induced voltages, by inductive and conductive coupling, in case of line to ground fault of the three overhead transmission lines, are shown in Fig. 9. From this figure it can be noticed that, the pipeline induced voltage increases as the separation distance between the pipelines and the OHTLs decreases. The discharging currents of the pipeline coating due to its induced voltage are calculated using a code (M-file), which is written by MATLAB program in case of line to ground fault. Fig. 10 shows the discharge currents of the pipeline coating in case of single line-to-ground fault of the three overhead transmission lines, individually. From Fig. 10, it is noticed that, the coating discharge reaches to 0.45 mA in case of El-Kurimate-Cairo power single lineto-ground fault condition, it exceeds 0.30 mA in case of single line-to-ground fault of Samaloute-Cairo power line, and it reaches to 0.20 mA in case of single line-to-ground fault of Dimo-6th of October. These currents depend on short circuit current. Also, these currents generate a heat in the coating of the pipeline. This heat represents hazards for this coating.

Pipeline induced voltage (V)

With homogenous values of the soil resistivity =100  m, which equal the actual measured values

9000

El-Kurimate-Cairo Samaloute-Cairo

8000

Dimo-6th of October

7000 6000 5000 4000 3000 2000 1000 0

0

10

20

30

40

50

60

70

Pipeline length (km) Fig. 9. Total pipeline induced voltage in case of single line-to-ground fault of the three power lines, individually.

0.45

Pipeline coating dischargeging (mA)

48 50 52 54 56 58 60 62 64

Induced voltage (kV)

10000

El-Kurimate-Cairo Samaloute-Cairo

0.4

Dimo-6th of October 0.3

0.2

0.1

0

0

10

20

30

40

50

60

70

Pipeline length (km) Fig. 10. Total pipeline coating discharging by inductive and conductive coupling in case of single line-to-ground fault of the three power lines, individually.

The AC current density in A/m2 due to the resultant pipeline induced voltages under normal operating condition is given in Fig. 11. It can be noticed that, there are some points, which are closed to OHTL, that have current densities exceed 20 A/m2 . So, the pitting corrosion usually occurs at lengths starting from 44 km to 46 km and starting from 55 km to 62 km, see Figs. 5 and 6. Corrosion rate can be summarized, for the points that have high current density, in Table 2.

120

Pipeline current density (A/m2)

Position along the pipeline (km)

133

100

80

60

40

20

0

0

10

20

30

40

50

Pipeline length (km) Fig. 11. pipeline AC current density in A/m2 .

60

70

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Table 2 Corrosion rate versus the soil resistivity and AC current density. Pipeline in km

Soil resistivity in  m

AC current density in A/m2

Corrosion rate in g/year

44 44.81 45 46 54.35 55 56 57 58 59 60 61 61.5

1850 1850 1850 300 100 100 100 100 100 100 100 100 100

20 111 41 20 20 24.15 81.5 100 96.45 82.87 76.14 36.15 20

0.2 0.3 0.234 0.2 0.2 0.2 0.3 0.3 0.3 0.3 0.3 0.234 0.2

operating conditions. The calculation method includes the effect of the separation distance between the OHTL and the metallic gas pipelines and the soil resistivity on the values of the induced voltage. Also, the induced voltages along the length of the pipeline, under normal operating conditions, are measured at different seasons and are compared with the calculated values. The measured values depend mainly on the currents of the overhead lines and on the soil resistivity, which varies with the seasons and with each subsection along the pipeline length. Under normal operating conditions, it is seen that there are some points, which are close to OHTL, have current densities exceed 20 A/m2 as given in Table 1. So, the pitting corrosion usually occurs at these points. Suggested method to mitigate the induced voltage at these points is required. From many calculations carried out, it is noticed that the pipeline coating damage depends on the discharge current; hence it increases in case of line to ground fault condition. Also, the obtained measured induced voltages help in finding the points on the pipeline at which it is necessary to install the polarization cell to discharge the induced voltages to the soil. Finally, the obtained results, for the case under study, can be used as a guide for the selection of the path way of the pipeline that has the lowest risk in the preconstruction phase. Appendix A. The following Figs. A1 and A2 and Tables A1–A3 give the configurations and data of the El-Kuorimate-Cairo power

Fig. 12. AC current density of the pipeline in case of single line-to-ground fault of the three power lines.

Fig. 12 shows the AC current densities of the pipeline in case of single line-to-ground fault of El-Kurimate-Cairo power line, Samaloute-Cairo power line, and Dimo-6th of October power line. The line to ground fault currents of these transmission lines are 28 kA, 28.85 kA and 15.48 kA, respectively. It can be noticed that, the current density reaches to 27,000 A/m2 at some points. So, the pitting corrosion occurred immediately. Normally, acceptable range of 3–5 kV are used for fusion bond epoxy and polyethylene coatings [27], and it can be seen from the diagram in Fig. 9 that actual pipeline induced voltages at several points exceed that acceptable magnitude. That means the pipeline insulation degradation occurs, due to the excessive current and (over) heating effects, which is illustrated in the Figs. 5 and 6. For those critical issues, a proposed mitigation and remedial solution should be suggested. There are several different mitigation strategies that are used to minimize impact of power lines on pipelines. Pipeline induced voltages can be reduced using polarization cells. As it is known polarization cells consist of multiple plates of steel arrange, fixed and immersed in 30% Potassium Hydroxide and produce safe DC voltages suitable for cathodic protection, which are distributed along the pipeline and are fixed at the points which have high induced voltage. These cells should be good connected to the ground to absorb the pipeline induced voltage. 7. Conclusions In this paper, the induced voltage along the length of the pipeline, due to inductive and conductive coupling between the pipeline and OHTL, is calculated under both fault and normal

Fig. A1. Power line tower dimensions of 500 kV. Table A1 El-Kuorimate-Cairo power line. Item

Value

MVA Line voltage (r.m.s) in kV Length in km Positive and negative sequence impedance per phase in ohm Zero sequence impedance per phase in ohm No of circuit per tower No of conductors per phase No of ground wires Diameter of a single conductor in mm Spacing between conductor in the bundle in cm Span in meter

575 500 124 3.307 + j14.053 10.75 + j45.67 1 3 2 30.6 47 400

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135

line, Samaloute-Cairo power line and six October power line, respectively.

References

Fig. A2. Power line tower dimensions of 220 kV.

Table A2 Samaloute-Cairo power line. Item

Value

MVA Line voltage (r.m.s) in kV Length in km Positive and negative sequence impedance per phase in ohm Zero sequence impedance per phase in ohm No of circuit per tower No of conductors per phase No of ground wires Diameter of a single conductor in mm Spacing between conductor in the bundle in cm Span in meter

1000 500 209 5.573 + j23.687 18.22 + j77.46 1 3 2 30.6 47 400

Table A3 Six October power line. Item

value

MVA Line voltage (r.m.s) in kV Length in km Positive and negative sequence impedance per phase in ohm Zero sequence impedance per phase in ohm No of circuit per tower No of conductors per phase No of ground wires Diameter of a single conductor in mm Spacing between conductor in the bundle in cm Span in meter

158/circuit 220 90 3.6 + j15.3 12.2 + j50.95 2 2 1 27 30 360

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Author's personal copy 136

O.E. Gouda et al. / Electric Power Systems Research 103 (2013) 129–136

[28] F.P. Dawalibi, R.D. Southey, Analysis of electrical interference from power lines to gas pipelines. Parts I: computation methods, IEEE Transactions on Power Delivery 4 (July (3)) (1989) 1840–1846. [29] J. Bortels, C. Deconinck, V. Munteanu, Topa, A General Applicable model for AC predictive and mitigation techniques for pipeline networks influenced by HV power lines, IEEE Transactions on Power Delivery 21 (1) (2006) 210–217.

[30] R.A. Gummow, S.M. Segall, W. Fieltsch, Pipeline AC mitigation misconceptions, in: Northern Area Western Conference February 15–18, NACE-2010, Calgary, Alberta. IEEE 80-2000, Guide for Safety in AC Substation Grounding, IEEE, 2000. [31] IEEE 80-2000, Guide for Safety in AC Substation Grounding, IEEE, 2000.

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