Optimized Protection of Pole-Mounted Distribution Transformers against Direct Lightning Strikes

: Direct lightning strikes on overhead phase conductors result in high overvoltage stress on the medium voltage (MV) terminals of pole-mounted transformers, which may cause considerable damage. Therefore, introducing an e ﬃ cient protection strategy would be a remedy for alleviating such undesirable damages. This paper investigates the optimized protection of MV transformers against direct lightning strikes on the phase conductors. To this end, ﬁrst, the impacts of grounding densities (number of grounded intermediate poles between every two successive transformer poles) on the probability of overvoltage stress on transformer terminals are investigated. Then, the implications of guy wire, as a supporting device for ungrounded intermediate poles, on reducing the overvoltage stress on transformers, are studied. Finally, the role of a surge arrester in mitigating the overvoltage stress of non-surge-arrester-protected transformer poles is scrutinized. The investigations are conducted on a sample MV network with 82 wood poles comprising 17 pole-mounted transformers protected by spark gaps. To provide in-depth analysis, two di ﬀ erent poles, namely creosote- and arsenic-impregnated poles, are considered under wet and dry weather conditions. A sensitivity analysis is performed on grounding distances and on a combination of guy wire and grounded intermediate poles while taking into account soil ionization. The results provide a clear picture for the system operator in deciding how many grounded intermediate poles might be required for a system to reach the desired probabilities of transformers experiencing overvoltage stress and how the surge arrester and guy wires contribute to mitigating undesirable overvoltage stress.


Introduction
A medium voltage (MV) distribution network with overhead lines may experience high overvoltage due to direct lightning strikes. Such transient overvoltages are the primary source of damage to MV equipment, especially power transformers. They cause stress on the insulation system that gradually results in failure or severe damage [1]. The results of a survey on transformer reliability by Cigre Study Committee A2.37 [2] show that the largest numbers of failures are caused by natural disasters. In this report, since all the transformers were protected by surge arresters, the failure rate due to lightning was around 3%. Furthermore, the highest failure rate can be attributed to design, manufacturing and aging, with 32%, while 29% of causes remained unknown. This high unknown failure rate and even the failure rate corresponding to the aging category might be the result of the accumulation of prior small damages due to transient overvoltages [1,3].

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Investigating the impact of different grounding spans (spans between two successive grounded intermediate poles) on the probability of overvoltage stress.

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Investigating the impact of guy wire, installed at the ungrounded poles, on the probability of overvoltage stress at the adjacent pole-mounted transformers.

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Modeling the transient performance of the grounding system by using a nonlinear resistance for soil ionization due to large lightning current.

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Investigating the impact of surge arrester(s), installed on the MV side of the transformers on mitigating the overvoltage stress of the adjacent non-surge-arrester-protected pole-mounted transformer.
The remainder of this paper is organized as follows. Section 2 presents the simulation setup for different components of an MV distribution network. Primary parts of the sample system are validated in Section 3. Detailed information on the case studies and the primary assumptions are provided in Section 4. Section 5 provides simulation results and in-depth analyses. Section 6 presents the concluding remarks and prospects of future works.

Simulation Setup
This section provides detailed information on the simulation setup related to a part of a typical 3-phase medium-voltage (MV) network. The components to be modeled in Electromagnetic Transients Program-Restructured Version (EMTP-RV) [28] are direct lightning impulse, wood poles, metallic cross arm, insulators, overhead lines, earthing system, guy wire, spark gap, and surge arrester.

Direct Lightning
In order to model the behavior of direct lightning in a software environment, a current source is used. In this paper, a Cigre current source is utilized to simulate the behavior of direct lightning [29]. The required parameters to produce the direct lightning impulse are presented in Table 1. Table 1. Parameters of direct lightning [13].

Parameter Symbol Value
Maximum current (kA) I max 27.7 Front time (µs) t f 3.83 Maximum steepness kA µs S m 23.3 Time to half value (µs) t h 77.5 Figure 1 depicts the direct lightning impulse generated by using the Cigre current source available in the EMTP-RV and by applying the values presented in Table 1.  Time to half value (μs) 77.5 Figure 1 depicts the direct lightning impulse generated by using the Cigre current source available in the EMTP-RV and by applying the values presented in Table 1.  Figure 2 presents the dimensions and different parts of an MV wood pole. The wood poles for 3-phase overhead distribution lines-see Figure 2a-are modeled by a parallel resistor-capacitor circuit, while the metallic cross arms-see Figure 2b-are modeled by inductors [13]. The capacitance for this 7 m pole is 5.36 pF [30], and the value per unit length of inductances (to model the cross arms) is 1 μH/m. Cross arms of grounded poles are connected to the footing resistance via a lead wire (Figure 2e), while, for ungrounded poles, the lead wire is removed. The resistance of the pole highly depends on the weather conditions [31]. In this work, poles with two different impregnation materials, namely creosote and arsenic, are studied under wet and dry weather conditions. The resistances of creosote-and arsenic-impregnated poles under wet conditions in November, are 580 kΩ and 28 kΩ, respectively, while, under dry conditions in August, both poles are considered to have similar resistances of 1400 kΩ [31]. Note that these resistances also depend on the geographical characteristics and the above values have been used due to their applicability in Finland.

Wood Poles and Cross Arm
The occurrence of a flashover down the wood pole is modeled via a voltage-controlled switch. When the voltage over the pole exceeds the critical flashover voltage (CFO) of the pole, the switch is closed; otherwise, the switch remains open. Under the wet condition, the CFOs for creosote-and arsenic-impregnated wood poles are assumed to be 320 kV/m and 160 kV/m, respectively, while, under the dry condition, the CFO for both poles is assumed to be 400 kV/m. The arcing resistance for poles is set to be 80 Ω. In high voltage studies, the CFO of two or more components in series is the summation of the CFOs of each component [21]. Therefore, in the case of grounded poles, the CFO is simply the CFO of insulators-see Section 2.3-while, in the case of the ungrounded pole, the flashover voltage depends on the combined dielectric strength of the insulator and pole connected in series, which is the summation of the CFOs. It is noteworthy to mention that, if an ungrounded pole is supported by guy wire, the total CFO is the CFO of the insulator plus the CFO of the pole corresponding to the length from cross arm to the guy wire connection point.   [13]. The capacitance for this 7 m pole is 5.36 pF [30], and the value per unit length of inductances (to model the cross arms) is 1 µH/m. Cross arms of grounded poles are connected to the footing resistance via a lead wire (Figure 2e), while, for ungrounded poles, the lead wire is removed. The resistance of the pole highly depends on the weather conditions [31]. In this work, poles with two different impregnation materials, namely creosote and arsenic, are studied under wet and dry weather conditions. The resistances of creosote-and arsenic-impregnated poles under wet conditions in November, are 580 kΩ and 28 kΩ, respectively, while, under dry conditions in August, both poles are considered to have similar resistances of 1400 kΩ [31]. Note that these resistances also depend on the geographical characteristics and the above values have been used due to their applicability in Finland.

Wood Poles and Cross Arm
The occurrence of a flashover down the wood pole is modeled via a voltage-controlled switch. When the voltage over the pole exceeds the critical flashover voltage (CFO) of the pole, the switch is closed; otherwise, the switch remains open. Under the wet condition, the CFOs for creosote-and arsenic-impregnated wood poles are assumed to be 320 kV/m and 160 kV/m, respectively, while, under the dry condition, the CFO for both poles is assumed to be 400 kV/m. The arcing resistance for poles is set to be 80 Ω. In high voltage studies, the CFO of two or more components in series is the summation of the CFOs of each component [21]. Therefore, in the case of grounded poles, the CFO is simply the CFO of insulators-see Section 2.3-while, in the case of the ungrounded pole, the flashover voltage depends on the combined dielectric strength of the insulator and pole connected in series, which is the Energies 2020, 13, 4372 5 of 35 summation of the CFOs. It is noteworthy to mention that, if an ungrounded pole is supported by guy wire, the total CFO is the CFO of the insulator plus the CFO of the pole corresponding to the length from cross arm to the guy wire connection point.

Modeling the Insulator
The insulators, which are located between the conductors (overhead lines) and cross arm-see Figure 2c-are modeled by considering a parallel resistor-capacitor circuit, where the values of capacitance and resistance are set to 80 pF and 25 MΩ, respectively [22].
On the other hand, it is necessary to simulate the flashover phenomena, which may occur over the insulators by lightning strikes.
In this work, the length of the insulator is 18 cm and a time-dependent model is used to model the behavior of the insulator closer to the practical situation. To do so, the flashover voltage is approximated by Error! Reference source not found..  (1) where is the flashover voltage in kV, a and b are arbitrary parameters that can be adjusted via laboratory test and, in this work, these parameters are set to 400 and 700, respectively; is the insulator length in m, and is the elapsed time after lightning strike in μs [22,32,33].

Overhead Line
In order to simulate the behavior of the overhead lines for the sample 3-phase MV network under direct lightning conditions, J. Marti's frequency dependent (FD) line model is used [34]. This model is available in the library of the EMTP-RV, while the technical data need to be prepared for the overhead lines. The DC resistance and outside diameter of the conductors are set to 0.509 Ω/km and 0.6 cm, respectively. The length of each span is 80 m, while, for the end points of the network, long overhead lines of 15 km are considered.

Earthing System
In order to have a more practical model, the ionization of the soil needs to be taken into account-see Figure 2g. Footing resistance is nonlinearly proportional to the value of current, such that, for low currents, there will be a constant resistance, while the resistance of a ground electrode may decrease due to ionization of the soil. In this paper, the footing resistance under high impulse current is calculated by (2) [24].

Modeling the Insulator
The insulators, which are located between the conductors (overhead lines) and cross arm-see Figure 2c-are modeled by considering a parallel resistor-capacitor circuit, where the values of capacitance and resistance are set to 80 pF and 25 MΩ, respectively [22].
On the other hand, it is necessary to simulate the flashover phenomena, which may occur over the insulators by lightning strikes.
In this work, the length of the insulator is 18 cm and a time-dependent model is used to model the behavior of the insulator closer to the practical situation. To do so, the flashover voltage is approximated by (1).
where V f lashover is the flashover voltage in kV, a and b are arbitrary parameters that can be adjusted via laboratory test and, in this work, these parameters are set to 400 and 700, respectively; l is the insulator length in m, and t is the elapsed time after lightning strike in µs [22,32,33].

Overhead Line
In order to simulate the behavior of the overhead lines for the sample 3-phase MV network under direct lightning conditions, J. Marti's frequency dependent (FD) line model is used [34]. This model is available in the library of the EMTP-RV, while the technical data need to be prepared for the overhead lines. The DC resistance and outside diameter of the conductors are set to 0.509 Ω/km and 0.6 cm, respectively. The length of each span is 80 m, while, for the end points of the network, long overhead lines of 15 km are considered.

Earthing System
In order to have a more practical model, the ionization of the soil needs to be taken into account-see Figure 2g. Footing resistance is nonlinearly proportional to the value of current, such that, for low currents, there will be a constant resistance, while the resistance of a ground electrode may Energies 2020, 13, 4372 6 of 35 decrease due to ionization of the soil. In this paper, the footing resistance under high impulse current is calculated by (2) [24].
where R is the footing resistance at high impulse current, R 0 is the footing resistance at low current, I R is the current through the footing resistance, and I g is the current required to initiate the soil ionization gradient, E 0 . In this work, for grounded poles, R 0 is assumed to be 17 Ω [35,36]. The limiting current I g is calculated by (3).
where ρ is the soil resistivity, and E 0 is the soil breakdown gradient. In this paper, it is assumed that the soil resistivity and soil breakdown gradient are 75 (Ωm) [37] and 400 kV/m [29,37], respectively. It is noteworthy to mention that, in EMTP-RV, an existing current-controlled nonlinear resistance is used to simulate the behavior of the earthing system [28].

Guy Wire
A guy wire is a tensioned cable designed to support the poles by enhancing their stability. More often than not, guy wires are used in the dead-end, transformer poles and also in the angles of the line route. Guy wire is modeled by an equivalent constant parameter (CD) line model with a surge impedance of 450 Ω [38,39]. Guy wire earthing system can be modeled as a constant resistance since the current conducted through this wire is relatively low and does not initiate the soil ionization [40]. However, in this work, due to considering the arsenic-impregnated pole under the wet condition, which has a relatively low resistance, the earthing system described in Section 2.5 is used. The distance of the guy wire from the metallic part of the cross arm is 2 m. It is worth mentioning that, for the guy wire earthing system, the footing resistance is considered to be 40 times higher than the pole grounding resistance [38].

Spark Gap
A spark gap, which is used to protect the transformers by limiting the overvoltage amplitude, is modeled via the disruptive effect (DE) method. When the amplitude of the voltage over the spark gap exceeds the critical flashover voltage between the terminals, it triggers [41]. In some works, a simple voltage-controlled switch is used to model the behavior of the spark gap [13,14]; however, in this paper, the DE method in (4), which presents a more precise result, is used.
where the k, V 0 , and D are an empirical constant, the onset voltage of primary ionization (kV), and the disruptive effect constant (kV µs), respectively. In this paper, V 0 = 112 kV, k = 0.97, and D = 0.01 are used to simulate the behavior of an 8 cm sphere-sphere spark gap.

Surge Arrester
In this paper, the frequency dependent behavior of the metal oxide surge arrester is modeled according to the guidelines provided by the IEEE Working Group 3.4.11 [42]. To do so, a resistor (R), inductor (L), and capacitor (C) circuit, namely RLC circuit, presented in Figure 3, is used, in which two nonlinear resistance Ao and A1 are separated by an R-L filter. The required information to simulate a surge arrester is obtained from [43] and the voltage-current (V-I) characteristics of the nonlinear resistances are derived from [42].

Transformer
In this work, a delta-star (∆ − Y) 22/0.4 kV transformer is modeled in the EMTP-RV environment, according to Cigre Guidelines [44]. Figure 4 shows the basic building block of a transformer for one phase in EMTP-RV, while Figure 5 presents the 3-phase transformer model in which the capacitances on the primary side, between the primary and secondary sides, and on the secondary side have been considered, which play a crucial role in high voltage transient studies.

Sample Network
The sample MV network in Figure 6 consists of 81 wood poles, and the length of the spans is 80 m. The length of the lines at both ends (e.g., FD line 1) is set to 15 km. The network has 17 polemounted transformers at every five spans (400 m). The first transformer is placed on pole #1, and the next on pole #6, and so on, while the direct lightnings are applied on every three spans, e.g., pole #1, pole #4, and so on.

Transformer
In this work, a delta-star (∆ − Y) 22/0.4 kV transformer is modeled in the EMTP-RV environment, according to Cigre Guidelines [44]. Figure 4 shows the basic building block of a transformer for one phase in EMTP-RV, while Figure 5 presents the 3-phase transformer model in which the capacitances on the primary side, between the primary and secondary sides, and on the secondary side have been considered, which play a crucial role in high voltage transient studies.

Transformer
In this work, a delta-star (∆ − Y) 22/0.4 kV transformer is modeled in the EMTP-RV environment, according to Cigre Guidelines [44]. Figure 4 shows the basic building block of a transformer for one phase in EMTP-RV, while Figure 5 presents the 3-phase transformer model in which the capacitances on the primary side, between the primary and secondary sides, and on the secondary side have been considered, which play a crucial role in high voltage transient studies.

Sample Network
The sample MV network in Figure 6 consists of 81 wood poles, and the length of the spans is 80 m. The length of the lines at both ends (e.g., FD line 1) is set to 15 km. The network has 17 polemounted transformers at every five spans (400 m). The first transformer is placed on pole #1, and the next on pole #6, and so on, while the direct lightnings are applied on every three spans, e.g., pole #1, pole #4, and so on.

Transformer
In this work, a delta-star (∆ − Y) 22/0.4 kV transformer is modeled in the EMTP-RV environment, according to Cigre Guidelines [44]. Figure 4 shows the basic building block of a transformer for one phase in EMTP-RV, while Figure 5 presents the 3-phase transformer model in which the capacitances on the primary side, between the primary and secondary sides, and on the secondary side have been considered, which play a crucial role in high voltage transient studies.

Sample Network
The sample MV network in Figure 6 consists of 81 wood poles, and the length of the spans is 80 m. The length of the lines at both ends (e.g., FD line 1) is set to 15 km. The network has 17 polemounted transformers at every five spans (400 m). The first transformer is placed on pole #1, and the next on pole #6, and so on, while the direct lightnings are applied on every three spans, e.g., pole #1, pole #4, and so on.

Sample Network
The sample MV network in Figure 6 consists of 81 wood poles, and the length of the spans is 80 m. The length of the lines at both ends (e.g., FD line 1) is set to 15 km. The network has 17 pole-mounted transformers at every five spans (400 m). The first transformer is placed on pole #1, and the next on pole #6, and so on, while the direct lightnings are applied on every three spans, e.g., pole #1, pole #4, and so on.

Model Validation
This section provides adequate information and analyses to validate primary parts of the system, such as spark gap, transformer capacitances, insulator flashover, as well as surge arrester.

Spark Gap and Transformer
In the literature, several approaches have been proposed to obtain a good approximation of the DE parameters such as k, , and D. However, the best way to adjust these parameters is to have some experimental data. In this work, an 8 cm sphere-sphere spark gap, presented in Figure 7, is used [45]. In order to validate the proper functionality of this spark gap, a nonstandard 125 kV overvoltage impulse is used. In Figure 8a, the green curve shows the applied impulse in a laboratory, while the blue curve stands for the applied impulse modeled in EMTP-RV.
To adjust the parameters of the DE method, more often than not, some approximation methods are used, although these methods may not always give an accurate result. As an example, in [46], these values are estimated by determining the critical flashover voltage (CFO) as = 0.86 × CFO, = 1.29 × 10 • CFO, and k = 1 that results in = 106.1, = 0.1.59. By considering these values in our work, the spark gap was not triggered under 125 kV applied impulse and the transformer experienced the overvoltage presented in Figure 8a, while the experimental measurements show that the spark gap is triggered-see Figure 8b. Therefore, in this work, first, the is estimated via the method proposed by the Cigre Group [47] ( ≈ 0.9 • CFO ≈ 112 kV), and then a trial and error method is used to find a better agreement with the laboratory results.

Model Validation
This section provides adequate information and analyses to validate primary parts of the system, such as spark gap, transformer capacitances, insulator flashover, as well as surge arrester.

Spark Gap and Transformer
In the literature, several approaches have been proposed to obtain a good approximation of the DE parameters such as k, V 0 , and D. However, the best way to adjust these parameters is to have some experimental data. In this work, an 8 cm sphere-sphere spark gap, presented in Figure 7, is used [45].

Model Validation
This section provides adequate information and analyses to validate primary parts of the system, such as spark gap, transformer capacitances, insulator flashover, as well as surge arrester.

Spark Gap and Transformer
In the literature, several approaches have been proposed to obtain a good approximation of the DE parameters such as k, , and D. However, the best way to adjust these parameters is to have some experimental data. In this work, an 8 cm sphere-sphere spark gap, presented in Figure 7, is used [45]. In order to validate the proper functionality of this spark gap, a nonstandard 125 kV overvoltage impulse is used. In Figure 8a, the green curve shows the applied impulse in a laboratory, while the blue curve stands for the applied impulse modeled in EMTP-RV.
To adjust the parameters of the DE method, more often than not, some approximation methods are used, although these methods may not always give an accurate result. As an example, in [46], these values are estimated by determining the critical flashover voltage (CFO) as = 0.86 × CFO, = 1.29 × 10 • CFO, and k = 1 that results in = 106.1, = 0.1.59. By considering these values in our work, the spark gap was not triggered under 125 kV applied impulse and the transformer experienced the overvoltage presented in Figure 8a, while the experimental measurements show that the spark gap is triggered-see Figure 8b. Therefore, in this work, first, the is estimated via the method proposed by the Cigre Group [47] ( ≈ 0.9 • CFO ≈ 112 kV), and then a trial and error method is used to find a better agreement with the laboratory results.  Figure 7. Adjustable sphere-sphere spark gap [45].
In order to validate the proper functionality of this spark gap, a nonstandard 125 kV overvoltage impulse is used. In Figure 8a, the green curve shows the applied impulse in a laboratory, while the blue curve stands for the applied impulse modeled in EMTP-RV.
To adjust the parameters of the DE method, more often than not, some approximation methods are used, although these methods may not always give an accurate result. As an example, in [46], these values are estimated by determining the critical flashover voltage (CFO) as V 0 = 0.86 × CFO, D = 1.29 × 10 −6 ·CFO, and k = 1 that results in V 0 = 106.1, D = 0.1.59. By considering these values in our work, the spark gap was not triggered under 125 kV applied impulse and the transformer experienced the overvoltage presented in Figure 8a, while the experimental measurements show that the spark gap is triggered-see Figure 8b. Therefore, in this work, first, the V 0 is estimated via the method proposed by the Cigre Group [47] (V 0 ≈ 0.9·CFO ≈ 112 kV), and then a trial and error method is used to find a better agreement with the laboratory results. To this end, as suggested in [47], the Energies 2020, 13, 4372 9 of 35 k is considered to be lower than 1 and then the parameter D is adjusted. Therefore, in this paper, the parameters are set as follows: V 0 = 112 kV, k = 0.97, and D = 0.01.
On the other hand, the performance and triggering of the spark gap highly depends on the characteristic of the transformer, especially the capacitances on the primary side (C1), on the secondary side (C2), and between the primary and secondary sides (C3) of the transformer-see Figure 5. To obtain these values, laboratory tests are required. Interested readers may refer to [48] to obtain a complete report on the laboratory setup and measurements of transformer winding capacitances. The extracted capacitances are as follows: C1 = 1.378 nF, C2 = 0.002 nF, C3 = 3.513 nF, Figure 8b presents a comparison between the behavior of the spark gap against lightning overvoltages by making an experimental laboratory test [49] and the result obtained via the DE method simulated in EMTP-RV. As can be seen in Figure 8b, the result of the DE method is in very good agreement with the laboratory test. It is noteworthy to mention that the small peak after the primary peak in the applied impulse is due to the induced voltage on the standard voltage divider of the laboratory as a result of the electromagnetic fields associated with the high voltage impulse [50]. More information regarding the applied impulse and the validation of the spark gap can be found in [45].
Energies 2020, 13, x FOR PEER REVIEW 9 of 34 [47], the k is considered to be lower than 1 and then the parameter D is adjusted. Therefore, in this paper, the parameters are set as follows: = 112 kV, k = 0.97, and = 0.01.
On the other hand, the performance and triggering of the spark gap highly depends on the characteristic of the transformer, especially the capacitances on the primary side (C1), on the secondary side (C2), and between the primary and secondary sides (C3) of the transformer-see Figure 5. To obtain these values, laboratory tests are required. Interested readers may refer to [48] to obtain a complete report on the laboratory setup and measurements of transformer winding capacitances. The extracted capacitances are as follows: C1 = 1.378 nF , C2 = 0.002 nF , C3 = 3.513 nF, Figure 8b presents a comparison between the behavior of the spark gap against lightning overvoltages by making an experimental laboratory test [49] and the result obtained via the DE method simulated in EMTP-RV. As can be seen in Figure 8b, the result of the DE method is in very good agreement with the laboratory test. It is noteworthy to mention that the small peak after the primary peak in the applied impulse is due to the induced voltage on the standard voltage divider of the laboratory as a result of the electromagnetic fields associated with the high voltage impulse [50]. More information regarding the applied impulse and the validation of the spark gap can be found in [45]. The performance of the spark gap in a network is verified in Section 3.2 jointly with validating the behavior of the insulator.

Insulator
Whenever the voltage across the insulator is larger than the flashover voltage calculated by (1), a flashover occurs. That is, under very high overvoltage conditions, an insulator may experience frequent flashovers. Let us investigate different situations for the insulator and see its performance. To do so, the lightning is applied on phase a (see Figure 6) of an intermediate pole adjacent to the transformer pole. Figure 9a-c present the flashover occurrence across the insulators corresponding to phase a, b and c, respectively, while Figure 9d demonstrates the performance of the spark gap in protecting a pole-mounted transformer against lightning impulses. In these figures, the gaps among the bar-like overvoltages stand for the flashover occurrence, and a larger gap means a longer flashover time. Figure 9a-c shows that, by striking the lightning at a pole, frequent flashovers occur across the insulators, and the highest flashover voltage occurs across insulator a (i.e., insulator used for phase a), which is the phase that the lightning strikes. However, from Figure 9d, it can be seen that, for this phase, the spark gap is not triggered. This happens since the time of each flashover across insulator a is comparatively high (see the gaps in Figure 9a); then, the area under the overvoltage curve (which represents the integral part in Equation (4)) is not large enough to trigger the spark gap (see the red bar-like overvoltage waveform in Figure 9d). For phase 2, the spark gap is not triggered since the flashover voltage is always below the onset voltage of primary ionization, which is 112 kV The performance of the spark gap in a network is verified in Section 3.2 jointly with validating the behavior of the insulator.

Insulator
Whenever the voltage across the insulator is larger than the flashover voltage calculated by (1), a flashover occurs. That is, under very high overvoltage conditions, an insulator may experience frequent flashovers. Let us investigate different situations for the insulator and see its performance. To do so, the lightning is applied on phase a (see Figure 6) of an intermediate pole adjacent to the transformer pole. Figure 9a-c present the flashover occurrence across the insulators corresponding to phase a, b and c, respectively, while Figure 9d demonstrates the performance of the spark gap in protecting a pole-mounted transformer against lightning impulses. In these figures, the gaps among the bar-like overvoltages stand for the flashover occurrence, and a larger gap means a longer flashover time. Figure 9a-c shows that, by striking the lightning at a pole, frequent flashovers occur across the insulators, and the highest flashover voltage occurs across insulator a (i.e., insulator used for phase a), which is the phase that the lightning strikes. However, from Figure 9d, it can be seen that, for this phase, the spark gap is not triggered. This happens since the time of each flashover across insulator a is comparatively high (see the gaps in Figure 9a); then, the area under the overvoltage curve (which represents the integral part in Equation (4)) is not large enough to trigger the spark gap (see the red bar-like overvoltage waveform in Figure 9d). For phase 2, the spark gap is not triggered since the flashover voltage is always below the onset voltage of primary ionization, which is 112 kV in this paper-see the blue waveform in Figure 9d. However, for insulator c, the situation is different, and the area below the overvoltage curve is large enough to trigger the spark gap and protect the transformer against very high overvoltage stress.
Energies 2020, 13, x FOR PEER REVIEW 10 of 34 in this paper-see the blue waveform in Figure 9d. However, for insulator c, the situation is different, and the area below the overvoltage curve is large enough to trigger the spark gap and protect the transformer against very high overvoltage stress.

Surge Arrester
The functionality of the utilized surge arrester can be verified by applying the direct lightning and monitoring the residual voltage under the nominal current. The surge arrester model is validated by performing a simulation-based test under the standard 10 kA current impulse (8/20 µs) and comparing the results with laboratory tests, provided in [43]. The obtained result from the simulated model in EMTP-RV shows a residual voltage of 67.32 kV, see Figure 10, which is in resounding agreement with the 67.5 kV residual voltage reported in [43].

Surge Arrester
The functionality of the utilized surge arrester can be verified by applying the direct lightning and monitoring the residual voltage under the nominal current. The surge arrester model is validated by performing a simulation-based test under the standard 10 kA current impulse (8/20 µs) and comparing the results with laboratory tests, provided in [43]. The obtained result from the simulated model in EMTP-RV shows a residual voltage of 67.32 kV, see Figure 10, which is in resounding agreement with the 67.5 kV residual voltage reported in [43].
Energies 2020, 13, x FOR PEER REVIEW 10 of 34 in this paper-see the blue waveform in Figure 9d. However, for insulator c, the situation is different, and the area below the overvoltage curve is large enough to trigger the spark gap and protect the transformer against very high overvoltage stress.

Surge Arrester
The functionality of the utilized surge arrester can be verified by applying the direct lightning and monitoring the residual voltage under the nominal current. The surge arrester model is validated by performing a simulation-based test under the standard 10 kA current impulse (8/20 µs) and comparing the results with laboratory tests, provided in [43]. The obtained result from the simulated model in EMTP-RV shows a residual voltage of 67.32 kV, see Figure 10, which is in resounding agreement with the 67.5 kV residual voltage reported in [43].  Now, let us consider the performance of surge arresters in the sample network. To do so, first, direct lightning is applied on the intermediate pole adjacent to the transformer pole (see Figure 11a), and then direct lightning is applied on the transformer pole ( Figure 11b). As can be seen in Figure 11a, the measured overvoltages for all three terminals are below the residual voltage, while, in Figure 11b, when the lightning directly struck the transformer pole, the surge arrester experienced a steep overvoltage with an amplitude of around 80.34 kV. However, immediately, it starts its proper role and the overvoltage is reduced below its residual voltage level, which is a natural behavior of surge arresters against steep lightning strikes [12]. The cases presented in Figure 11a,b verify the proper functionality of surge arresters under normal and critical overvoltage conditions, respectively.
Energies 2020, 13, x FOR PEER REVIEW 11 of 34 Now, let us consider the performance of surge arresters in the sample network. To do so, first, direct lightning is applied on the intermediate pole adjacent to the transformer pole (see Figure 11a), and then direct lightning is applied on the transformer pole ( Figure 11b). As can be seen in Figure  11a, the measured overvoltages for all three terminals are below the residual voltage, while, in Figure  11b, when the lightning directly struck the transformer pole, the surge arrester experienced a steep overvoltage with an amplitude of around 80.34 kV. However, immediately, it starts its proper role and the overvoltage is reduced below its residual voltage level, which is a natural behavior of surge arresters against steep lightning strikes [12]. The cases presented in Figure 11a

Case Studies
This section provides detailed information about the primary assumptions and case studies. To perform in-depth analyses of the protection level of pole-mounted transformers, several case studies are conducted. As mentioned before, two types of wooden poles, namely arsenic-and creosoteimpregnated poles, are used for investigations. These poles have been selected since the arsenicimpregnated (AI) pole shows the greatest variations in resistance according to the weather conditions-28 kΩ in November and around 1350 kΩ in August-while the creosote-impregnated (CI) pole experiences the least variations in resistance-580 kΩ in November and 1400 kΩ in August [31]. The primary goals of the following case studies are (a) to define the effectiveness of grounding distance between two successive grounded poles, (b) revealing the role of guy wires in decreasing the amplitude of the lightning overvoltages, as well as (c) investigating the effectiveness of equipping up to two transformer poles with surge arresters on the transient condition of non-surge-arresterprotected transformer poles. In this work, the following assumptions are imposed: a. All transformers are protected with spark gaps. b. All the transformer poles are grounded, and, like practical cases, in transformer poles, the transformers and the pole have a shared earthing system. c. The position of direct lightning has been varied and applied after every three spans, and the amplitudes of the voltages on the primary side of transformers and for all the three phases are measured. d. For the sample network, three primary configurations are considered. These configurations are (1) network with wet creosote-impregnated poles, (2) network with wet arsenic-impregnated poles, and (3) network with dry creosote-/arsenic-impregnated poles. It is noteworthy to mention that, since under dry conditions, both the networks with creosote-and arsenicimpregnated poles show relatively similar resistances, only one test is accomplished for them under this weather condition.
In this work, and in order to extract the probability of MV pole-mounted transformers being subjected to overvoltage stress, the following case studies are conducted.

Case Studies
This section provides detailed information about the primary assumptions and case studies. To perform in-depth analyses of the protection level of pole-mounted transformers, several case studies are conducted. As mentioned before, two types of wooden poles, namely arsenic-and creosote-impregnated poles, are used for investigations. These poles have been selected since the arsenic-impregnated (AI) pole shows the greatest variations in resistance according to the weather conditions-28 kΩ in November and around 1350 kΩ in August-while the creosote-impregnated (CI) pole experiences the least variations in resistance-580 kΩ in November and 1400 kΩ in August [31]. The primary goals of the following case studies are (a) to define the effectiveness of grounding distance between two successive grounded poles, (b) revealing the role of guy wires in decreasing the amplitude of the lightning overvoltages, as well as (c) investigating the effectiveness of equipping up to two transformer poles with surge arresters on the transient condition of non-surge-arrester-protected transformer poles. In this work, the following assumptions are imposed: a.
All transformers are protected with spark gaps. b.
All the transformer poles are grounded, and, like practical cases, in transformer poles, the transformers and the pole have a shared earthing system. c.
The position of direct lightning has been varied and applied after every three spans, and the amplitudes of the voltages on the primary side of transformers and for all the three phases are measured. d.
For the sample network, three primary configurations are considered. These configurations are (1) network with wet creosote-impregnated poles, (2) network with wet arsenic-impregnated poles, and (3) network with dry creosote-/arsenic-impregnated poles. It is noteworthy to mention that, since under dry conditions, both the networks with creosote-and arsenic-impregnated poles show relatively similar resistances, only one test is accomplished for them under this weather condition.
In this work, and in order to extract the probability of MV pole-mounted transformers being subjected to overvoltage stress, the following case studies are conducted. In this work, the probability of overvoltage stress on the primary side of the transformer, i.e., the probability that the overvoltage amplitude, on at least one phase of the transformer, exceeds the critical overvoltage, is calculated by (5).
where π V≥V cr is the probability of overvoltage stress on the primary side; V i is the highest voltage among the three phases measured on the primary side; V cr is the critical voltage; Λ app is the set of poles on which the direct lightning is applied (in this paper, Λ app = {1, 4, 7, . . . , 82}); n i is the number of transformers in which at least one of the phases exceeds the critical voltage under applied lightning on pole i; N tr is the total number of pole-mounted transformers (in this work, 17), and N app is the total number of poles under direct lightning-in this work, card(Λ app ) = 28.

Simulation Results and Discussion
It is assumed that four different stress levels exist for the transformer, although the transformer is essentially under stress if the voltage at the MV side of the transformer reaches above 125 kV, which is one of the standard impulse withstand voltages used for testing the transformer insulation [51] and is applied for the understudy transformer [52]. Therefore, to provide adequate information, besides studying the probability of overvoltage amplitudes above 125 kV, the probabilities of transformers experiencing overvoltage amplitudes above 150 kV (to study the severe cases), above 85 kV, as well as above 30 kV are studied.

Case 1. Distribution Network with Grounded Transformer Poles
In the MV distribution network, to ensure electrical safety, the transformer tanks are grounded. Therefore, this case is considered as a benchmark for the sake of comparison. Tables 2-4 present the probabilities of transformers being under four different overvoltage stress levels (above 150 kV, 125 kV, 85 kV, and 30 kV) respectively for three network configurations, namely network with wet creosote-impregnated, wet arsenic-impregnated, and dry poles. Table 2. Number of transformers with at least one phase reaching the critical overvoltage level. Case 1, wet creosote-impregnated poles and grounded transformer poles.  Results presented in Tables 2-4 show that, although all the transformer poles are grounded, under direct lightning conditions, in several tests (applying direct lightning on different poles), one or two transformers experience very high overvoltage stress (above 150 kV) while, in all tests, at least one transformer is subjected to overvoltage stress above 30 kV. Additionally, it shows that the number of transformers under high overvoltage stress (above 125 kV) is the same as very high overvoltage stress, except for the network configuration with wet creosote-impregnated poles: when the lightning directly strikes pole #28, three transformers experience overvoltage stress above 125 kV while only two transformers experience overvoltage stress above 150 kV. Figure 12 depicts the probabilities of transformers being subjected to different levels of overvoltage stress. As can be seen, in this case, the probabilities for the different system configurations (wet creosote, wet arsenic, and dry poles) are almost the same. The main reason is that the intermediate poles (poles between two successive transformer poles) are ungrounded, and on the other hand, the dielectric strength of 7 m pole under the wet and dry condition and with both the impregnation materials (creosote or arsenic) is large enough to prevent any flashover. That is, any lightning strike on one of the intermediate poles travels toward the nearest grounded pole (which is the transformer pole in this case), and a flashover on the insulator occurs. It can be seen from Tables 2-4 that, in some tests, only one transformer experiences low overvoltage stress (above 30 kV). This happens when the direct lightning strikes the transformer poles (i.e., poles #1, #16, #31, #46, #61, and #76), and, according to the combination of dielectric strength (see Section 2.2), flashovers on the insulators are discharged via the grounded cross arm.  Since this case served as the benchmark, the overvoltage curves at the three terminals of the transformer mounted at pole # 36 are captured in Figure 13. In this figure, the lightning is applied on the adjacent pole of the network with dry poles. As can be seen from this figure, the overvoltage stress at terminal c is much higher than the other two terminals; therefore, for the sake of clarity and not repeating similar concluding remarks, in case 2, case 3, and case 4, only the overvoltage stress at terminal c of this transformer will be considered as the basis for providing in-depth analysis. Since this case served as the benchmark, the overvoltage curves at the three terminals of the transformer mounted at pole # 36 are captured in Figure 13. In this figure, the lightning is applied on the adjacent pole of the network with dry poles. As can be seen from this figure, the overvoltage stress at terminal c is much higher than the other two terminals; therefore, for the sake of clarity and not repeating similar concluding remarks, in case 2, case 3, and case 4, only the overvoltage stress at terminal c of this transformer will be considered as the basis for providing in-depth analysis.
Since this case served as the benchmark, the overvoltage curves at the three terminals of the transformer mounted at pole # 36 are captured in Figure 13. In this figure, the lightning is applied on the adjacent pole of the network with dry poles. As can be seen from this figure, the overvoltage stress at terminal c is much higher than the other two terminals; therefore, for the sake of clarity and not repeating similar concluding remarks, in case 2, case 3, and case 4, only the overvoltage stress at terminal c of this transformer will be considered as the basis for providing in-depth analysis.

Case 2. Distribution Network with Grounded Intermediate Poles
In this case, the three primary network configurations (see Section 4, assumption d) are investigated under several sub-configurations by considering different grounding densities as follows. This case is used to deduce the impact of grounding densities (number of grounded intermediate poles between two successive grounded poles) on the amplitude of lightning overvoltage as well as on the probabilities of transformers experiencing different overvoltage stress levels at their MV terminals.
Tables 5 and 6 respectively stand for the results of grounding one intermediate pole between two successive transformer poles for the network with wet creosote-and wet arsenic-impregnated poles against direct lightning strikes, while Table 7 presents the results for the dry condition.
By comparing Tables 5-7, respectively, with Tables 2-4, one significant difference is that the number of transformers under severe overvoltage stress (overvoltage with an amplitude above 125 kV and 150 kV) has been decreased. On the other hand, a comparison among Tables 5-7 shows that by applying direct lightning on different poles, the numbers of transformers experiencing an overvoltage stress level are almost the same for similar tests, which can be justified according to the large-enough dielectric strength of the 7 m wood poles under different conditions that prevents any flashover and fast overvoltage discharge to the ground. To visualize such similarities, Figure 14 depicts the probabilities of overvoltage stress on the MV terminals of transformers under different network configurations. As can be seen from this figure, the probabilities of transformers experiencing overvoltage amplitude over 150 kV, 125 kV, and 85 kV are exactly the same for all three network configurations, while, for overvoltage amplitude over 30 kV, the network with wet arsenic-impregnated poles, compared with the other two network configurations, shows slightly better performance (with 0.42% lower probability).   depicts the probabilities of overvoltage stress on the MV terminals of transformers under different network configurations. As can be seen from this figure, the probabilities of transformers experiencing overvoltage amplitude over 150 kV, 125 kV, and 85 kV are exactly the same for all three network configurations, while, for overvoltage amplitude over 30 kV, the network with wet arsenicimpregnated poles, compared with the other two network configurations, shows slightly better performance (with 0.42% lower probability).     Figure 16 presents a comparison among the probabilities of overvoltage stress higher than 125 kV for three different network configurations according to the effects of different sub-configurations (grounding densities; see Section 5.2, first paragraph). Comparing Figure 16 with Figure 15 shows that there is no significant difference between the trends, where the highest risk belongs to the case  Figure 16 presents a comparison among the probabilities of overvoltage stress higher than 125 kV for three different network configurations according to the effects of different sub-configurations (grounding densities; see Section 5.2, first paragraph). Comparing Figure 16 with Figure 15 shows that there is no significant difference between the trends, where the highest risk belongs to the case in which only the transformer poles are grounded, and the best performance belongs to the case in which at least three intermediate poles are grounded. Moreover, by comparing Figure 16 with Figure 15, it can be seen that, for different network configurations in case 1 (grounding only the transformer poles) and sub-configuration C2.1, the probability of transformers being under overvoltage stress above 125 kV is slightly greater than or equal to the probability of transformers being under overvoltage stress above 150 kV. That is, for case 1, the probabilities in Figure 16 for wet creosoteand wet arsenic-impregnated poles are 0.42% and 0.21% higher than the probabilities in Figure 15, while for dry poles, the probabilities are equal. For case 2 and sub-configuration C2.1, for all network configurations, the probabilities in Figure 16 are 0.21% higher than the probabilities in Figure 15. Consequently, if a system operator is willing to keep the risk of high overvoltage stress below 2% and 1%, one and two intermediate poles need to be grounded, respectively; meanwhile, to eliminate such overvoltage stress, three intermediate poles need to be grounded.   Figures 15 and 16, respectively, the probabilities of the transformer experiencing overvoltage stress are slightly higher. However, the main difference is in the mitigation trend, where, for the overvoltage stresses above 150 kV and 125 kV, by grounding one intermediate pole between every two successive transformer poles, the probability of the transformer experiencing overvoltage stress decreased below 2%, while for this overvoltage level to keep the probabilities below 2%, at least three intermediate poles need to be grounded. On the other hand, by grounding all intermediate poles, the probability of transformers experiencing overvoltage stress above 85 kV is 0%, i.e., there is no risk of such overvoltage stress at the MV terminals of the pole-mounted transformers.   Figures 15 and 16, respectively, the probabilities of the transformer experiencing overvoltage stress are slightly higher. However, the main difference is in the mitigation trend, where, for the overvoltage stresses above 150 kV and 125 kV, by grounding one intermediate pole between every two successive transformer poles, the probability of the transformer experiencing overvoltage stress decreased below 2%, while for this overvoltage level to keep the probabilities below 2%, at least three intermediate poles need to be grounded. On the other hand, by grounding all intermediate poles, the probability of transformers experiencing overvoltage stress above 85 kV is 0%, i.e., there is no risk of such overvoltage stress at the MV terminals of the pole-mounted transformers.
pole between every two successive transformer poles, the probability of the transformer experiencing overvoltage stress decreased below 2%, while for this overvoltage level to keep the probabilities below 2%, at least three intermediate poles need to be grounded. On the other hand, by grounding all intermediate poles, the probability of transformers experiencing overvoltage stress above 85 kV is 0%, i.e., there is no risk of such overvoltage stress at the MV terminals of the pole-mounted transformers.    Figure 18 presents a comparison among the probabilities of overvoltage stress above 30 kV for three different network configurations due to the impacts of different sub-configurations (grounding densities). As can be seen from this figure, by grounding one intermediate pole, the highest impact is for the network with arsenic-impregnated poles, which experienced around a 0.84% decrease in the probability of transformers experiencing overvoltage tension above 30 kV. Moreover, it can be seen that by grounding all intermediate poles between every two successive transformer poles, the probabilities are decreased to a great extent; for the network with wet creosote, wet arsenic, and dry poles, compared with Case 1, decrements of around 4.62%, 4.83%, and 3.78% are obtained, respectively. In Figure 18, unlike the results obtained for other overvoltage stress levels (above 150 kV in Figure 15, 125 kV in Figure 16, and 85 kV in Figure 17), grounding intermediate poles does not have a significant effect on mitigating the overvoltage stress above 30 kV. Moreover, for the configuration with four grounded intermediate poles in which no transformer experiences overvoltage stress above 85 kV (see Figure 17), still 6.3%, 5.88%, and 6.51% of transformers in the network with wet creosote, wet arsenic, and dry poles respectively experience overvoltage stress between 30 kV and 85 kV (see Figure 18). Nevertheless, it is noteworthy to mention that, due to the internal insulation of the medium voltage transformers with the basic insulation level above 125 kV [51], such overvoltage stress does not result in immediate failure and its cumulative negative effect over time may be negligible, though a concrete conclusion on this topic requires profound investigation. Figure 19 provides a comparison among the overvoltage stress at terminal c of the transformer, mounted at pole #36, under different grounding densities for the network with dry poles. The blue curve, which represents case 1 (only transformer poles are grounded), shows that the overvoltage is so high that the spark gap is triggered, and a service interruption occurs. By grounding only one intermediate pole, the amplitude of the overvoltage at terminal c is decreased by around 10.73% (15.79), and such unwanted service interruption is not happening anymore, while the overvoltage stress is still above 125 kV. Additionally, it can be deduced that, as the number of grounded intermediate poles increases, the amplitude of overvoltage decreases such that by grounding all intermediate poles, the overvoltage amplitude is decreased to 40.27 kV, which is a significant enhancement. network with wet creosote, wet arsenic, and dry poles respectively experience overvoltage stress between 30 kV and 85 kV (see Figure 18). Nevertheless, it is noteworthy to mention that, due to the internal insulation of the medium voltage transformers with the basic insulation level above 125 kV [51], such overvoltage stress does not result in immediate failure and its cumulative negative effect over time may be negligible, though a concrete conclusion on this topic requires profound investigation.

Case 3. Transformer Poles with Guy Wire
In this case, the three primary network configurations (see Section 4, assumption d) are investigated under four different sub-configurations by considering various combinations of grounding densities and guy wires. These sub-configurations are as follows.

Case 3. Transformer Poles with Guy Wire
In this case, the three primary network configurations (see Section 4, assumption d) are investigated under four different sub-configurations by considering various combinations of grounding densities and guy wires. These sub-configurations are as follows.    By comparing Table 8 with Table 2, it can be seen that supporting all intermediate poles by guy wires results in a reasonable decrease in the number of transformers experiencing overvoltage stress above 150 kV. When the poles are supported by guy wires and the lightning is applied on poles #13, #19, #28, #43, #49, #58, #64, #73, and #79, compared with the case without guy wires (in Table 2), the number of transformers experiencing such overvoltage stress decreases by one, while applying the lightning on pole #34 shows even better results, where no transformer experiences such overvoltage stress, which is two transformers less than the case without guy wire (in Table 2). Moreover, comparing Tables 9 and 10 with Tables 3 and 4 shows similar positive impacts of using guy wires on decreasing the overvoltage amplitude at the MV terminals of the transformer. To present the impacts more clearly, the probabilities of overvoltage stress on the MV terminals of transformers for sub-configuration C3.1 and under different network configurations are compared with each other in Figure 20. As can be seen from this figure, for the overvoltage stress with an amplitude above 150 kV (as the most likely stress for causing sever failure during the specified time period), when guy wires support the intermediate poles between two successive transformer poles, the probabilities for all three network configurations, i.e., wet creosote, wet arsenic, and dry poles, are decreased by around 2.52%, 2.31%, and 2.52%, respectively. Moreover, Figure 20 shows that, for other overvoltage stress levels, the guy wires provide some protection against direct lightning strikes, although this is negligible in some sub-configurations.  Another observation in this case is that the guy wires show better protective performance for overvoltage stress with an amplitude above 150 kV than the other overvoltage stress levels. The main reason for such behavior is the occurrence of flashover down the wood pole since, by installing guy wires, the total CFO, which is the combined CFO of the insulators and the wood pole corresponding Another observation in this case is that the guy wires show better protective performance for overvoltage stress with an amplitude above 150 kV than the other overvoltage stress levels. The main reason for such behavior is the occurrence of flashover down the wood pole since, by installing guy wires, the total CFO, which is the combined CFO of the insulators and the wood pole corresponding to the length from cross arm to the guy wire connection point (i.e., 2 m in this paper), is lower than the CFO of the similar case without guy wire (a 7 m wood pole). This situation will be elaborated more by investigating the flashover occurrence on the intermediate poles under three network configurations and for case 1 and sub-configuration C3.1. Tables 2-4 show that when direct lightning is applied on pole #34, for all three network configurations, two transformers on poles #31 and #36 experience overvoltage stress above 150 kV. Therefore, to see the impacts of guy wires, the flashover occurrence on the intermediate poles between transformer poles #31 and #36 (i.e., poles #32, #33, #34, and #35) are studied for case 1 (no guy wire for intermediate poles) and sub-configuration C3.1 (all intermediate poles supported by guy wire). It is worth mentioning that the studies are conducted under the dry condition, in which the wood poles have the highest CFO, e.g., 400 kV/m compared with wet conditions (see Section 2.2).
As mentioned in Section 2.2, the flashover occurrence over the pole is modeled by a voltagecontrolled switch. In this paper, to verify the flashover occurrence, the switch status and the current flow through this switch is monitored. In case 1, monitoring the switch status shows that the direct lightning does not result in any flashover down the wood poles, and this is due to the high CFO of the structure (combined CFO of insulators and the 7 m wood pole). However, for sub-configuration C3.1, the situation is different since the combined CFO is lower than the case without considering the guy wires, since the distance from the cross arm to the connection pint of the guy wire is 2 m. Details of flashover occurrence for the intermediate poles of the dry network configuration are depicted in Figure 21. Figure 21a-d present the current flows through the voltage-controlled switches of four intermediate poles, namely #32, #33, #34, and #35, respectively, due to flashover occurrence as a result of direct lightning strike on pole #34. As can be seen from this figure, for a short period of time, several flashovers frequently occurred down the poles toward the guy wires. It is noteworthy to mention that higher amplitudes of current flow through the switches show that the poles experienced higher overvoltages. Among the aforementioned intermediate poles, pole #34, unlike the other intermediate poles, experienced two discontinuous periods of frequent flashovers because direct lightning was applied on this pole. Moreover, the flashover discharge currents of the intermediate poles show that not only does the highest discharge current belong to pole #34 but the first period of frequent flashovers lasts longer, i.e., it starts at around 5.7 µs and ends at around 7.3 µs. Meanwhile, for pole # 33, which has the second widest frequent flashover period, it starts at around 6.2 µs and ends at around 7.2 µs. All in all, as can be seen in Figure 21, when flashover occurs from the cross arm toward the guy wire, the current associated with overvoltage is discharged via guy wires and, consequently, the transformers mounted at poles #31 and #36 in sub-configuration C3.1 experience lower overvoltage amplitude than the same transformers in case 1-see Figure 22. Figure 22 depicts the overvoltage waveform of terminal c of the transformer, i.e., the terminal which is experiencing the highest overvoltage stress, among others. As can be seen from Figure 22a,b that, considering guy wires, the overvoltage amplitudes experienced by the transformers mounted at poles #31 and #36 are 16.99% and 14.97% lower than the overvoltage amplitudes of the case without guy wires. The main reason that the spark gap is not triggered for the transformer can be found in Section 3.2.
overvoltage amplitude than the same transformers in case 1-see Figure 22. Figure 22 depicts the overvoltage waveform of terminal c of the transformer, i.e., the terminal which is experiencing the highest overvoltage stress, among others. As can be seen from Figure 22a, b that, considering guy wires, the overvoltage amplitudes experienced by the transformers mounted at poles #31 and #36 are 16.99% and 14.97% lower than the overvoltage amplitudes of the case without guy wires. The main reason that the spark gap is not triggered for the transformer can be found in Section 3.2.  overvoltage amplitude than the same transformers in case 1-see Figure 22. Figure 22 depicts the overvoltage waveform of terminal c of the transformer, i.e., the terminal which is experiencing the highest overvoltage stress, among others. As can be seen from Figure 22a, b that, considering guy wires, the overvoltage amplitudes experienced by the transformers mounted at poles #31 and #36 are 16.99% and 14.97% lower than the overvoltage amplitudes of the case without guy wires. The main reason that the spark gap is not triggered for the transformer can be found in Section 3.2.   For other grounding conditions of overvoltage stress above 150 kV (green and black bars), the guy wire does not provide any support against lightning overvoltage. This is mainly due to the functionality of grounded poles in the mitigation of high overvoltage stress. Each lightning strike chooses the shortest path with the least dielectric strength toward the ground, and when the number of grounded intermediate poles increases, the discharges occur more easily through grounded poles; this means that the overvoltage amplitude does not reach the CFO of guy wire-supported poles to trigger a flashover. Moreover, a comparison of the probabilities for all overvoltage stress levels shows that the best performance belongs to overvoltage stress above 150 kV, which most likely triggers the flashover discharge.
without considering guy wires, while the patterned bars represent the probabilities of under-stress transformers when the non-grounded intermediate poles are supported by guy wires. In this figure, for overvoltage amplitudes above 150 kV, when no intermediate pole is grounded, the guy wires show their best performance. That is, the probability of transformers experiencing such overvoltage stress when considering guy wires (blue patterned bar) is decreased by around 2.52%, compared with the similar grounding condition but without guy wires (solid blue bar). By increasing the number of grounded intermediate poles (from blue bars toward black bars), the impact of installing guy wires (at the non-grounded intermediate poles) on mitigating the overvoltage stress is decreased. For example, under overvoltage above 150 kV, when one intermediate pole between all transformer poles is grounded, considering guy wires for non-grounded intermediate poles (patterned orange bar) results in around a 0.84% decrease in the probabilities, compared with similar grounding conditions and without guy wires (solid orange bar). For other grounding conditions of overvoltage stress above 150 kV (green and black bars), the guy wire does not provide any support against lightning overvoltage. This is mainly due to the functionality of grounded poles in the mitigation of high overvoltage stress. Each lightning strike chooses the shortest path with the least dielectric strength toward the ground, and when the number of grounded intermediate poles increases, the discharges occur more easily through grounded poles; this means that the overvoltage amplitude does not reach the CFO of guy wire-supported poles to trigger a flashover. Moreover, a comparison of the probabilities for all overvoltage stress levels shows that the best performance belongs to overvoltage stress above 150 kV, which most likely triggers the flashover discharge.  Figures 24 and 25 compare the probabilities of pole-mounted transformers experiencing different overvoltage stress levels before and after considering guy wires and under different grounding densities for the network with wet arsenic-impregnated poles and dry poles, respectively. The main difference between using guy wires in the networks with wet creosote-impregnated poles and wet arsenic-impregnated poles is that the wet arsenic configuration has lower CFO. That is, wet arsenic poles require lower overvoltage amplitude than the wet creosote poles to trigger the flashover discharge (see Section 2.2). However, dry poles show stronger dielectric characteristics and, consequently, higher overvoltage amplitude is required for triggering a flashover down the pole toward the guy wire. Comparing the probabilities of overvoltage stress above 150 kV in Figure 25 and Figure 24 with Figure 23 shows that, for sub-configuration C3.1 (patterned blue bars), the guy wire decreases the probabilities in all three different network configurations by more than 2%, which is a considerable performance for such inexpensive devices. For arsenic-impregnated poles and with no grounded intermediate poles (blue bars in Figure 24), the guy wires provide great support against  Figures 24 and 25 compare the probabilities of pole-mounted transformers experiencing different overvoltage stress levels before and after considering guy wires and under different grounding densities for the network with wet arsenic-impregnated poles and dry poles, respectively. The main difference between using guy wires in the networks with wet creosote-impregnated poles and wet arsenic-impregnated poles is that the wet arsenic configuration has lower CFO. That is, wet arsenic poles require lower overvoltage amplitude than the wet creosote poles to trigger the flashover discharge (see Section 2.2). However, dry poles show stronger dielectric characteristics and, consequently, higher overvoltage amplitude is required for triggering a flashover down the pole toward the guy wire. Comparing the probabilities of overvoltage stress above 150 kV in Figures 24 and 25 with Figure 23 shows that, for sub-configuration C3.1 (patterned blue bars), the guy wire decreases the probabilities in all three different network configurations by more than 2%, which is a considerable performance for such inexpensive devices. For arsenic-impregnated poles and with no grounded intermediate poles (blue bars in Figure 24), the guy wires provide great support against direct lightning even for overvoltage amplitudes above 85 kV where, compared with the same grounding condition in the absence of guy wires (solid blue bar), considering guy wires results in a decrease of around 2.31%.

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Energies 2020, 13, x FOR PEER REVIEW 25 of 34 direct lightning even for overvoltage amplitudes above 85 kV where, compared with the same grounding condition in the absence of guy wires (solid blue bar), considering guy wires results in a decrease of around 2.31%.   (Figures 24 and 25, respectively), the probabilities decrease to 0.21%, which is similar to the case with two grounded intermediate poles. However, for the network with creosote-impregnated poles and one grounded intermediate pole, supporting the non-grounded intermediate poles with guy wires decreases the probability to 0.42%, which is slightly higher than the probability obtained by grounding two intermediate poles. Figure 26 provides a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different combinations of grounding densities and guy wires of intermediate poles for the network with dry poles. The red curve, which represents the overvoltage waveform for subconfiguration C3.1, compared with case1 (the blue curve), shows that, although considering four guy Energies 2020, 13, x FOR PEER REVIEW 25 of 34 direct lightning even for overvoltage amplitudes above 85 kV where, compared with the same grounding condition in the absence of guy wires (solid blue bar), considering guy wires results in a decrease of around 2.31%.   (Figures 24 and 25, respectively), the probabilities decrease to 0.21%, which is similar to the case with two grounded intermediate poles. However, for the network with creosote-impregnated poles and one grounded intermediate pole, supporting the non-grounded intermediate poles with guy wires decreases the probability to 0.42%, which is slightly higher than the probability obtained by grounding two intermediate poles. Figure 26 provides a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different combinations of grounding densities and guy wires of intermediate poles for the network with dry poles. The red curve, which represents the overvoltage waveform for subconfiguration C3.1, compared with case1 (the blue curve), shows that, although considering four guy  (Figures 24 and 25, respectively), the probabilities decrease to 0.21%, which is similar to the case with two grounded intermediate poles. However, for the network with creosote-impregnated poles and one grounded intermediate pole, supporting the non-grounded intermediate poles with guy wires decreases the probability to 0.42%, which is slightly higher than the probability obtained by grounding two intermediate poles. Figure 26 provides a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different combinations of grounding densities and guy wires of intermediate poles for the network with dry poles. The red curve, which represents the overvoltage waveform for sub-configuration C3.1, compared with case1 (the blue curve), shows that, although considering four guy wires between every two successive transformer poles decreases the amplitude of overvoltage, it is still high enough to trigger the spark gap and cause a service interruption. However, by supporting  Figure 19), results in a considerable enhancement in the overvoltage protection against direct lightning, i.e., 11.67 kV decrease in the overvoltage stress. Similarly, by comparing Figure 26 with Figure 19, it can be deduced that other combinations of guy wire and grounded intermediate pole also reduce the overvoltage stress on the transformer terminal.  Figure 19), results in a considerable enhancement in the overvoltage protection against direct lightning, i.e., 11.67 kV decrease in the overvoltage stress. Similarly, by comparing Figure 26 with Figure 19, it can be deduced that other combinations of guy wire and grounded intermediate pole also reduce the overvoltage stress on the transformer terminal.

Case 4. Considering Surge Arrester for Some Transformers
In this case, the three primary network configurations (see Section 4, assumption d) are investigated under two different sub-configurations by equipping two or four pole-mounted transformers with surge arresters. These sub-configurations are as follows.
C4.1. Equipping two pole-mounted transformers with surge arresters (2 SAs). To do so, the total spans are divided into three. Therefore, the transformer poles are poles #26 and #56. This subconfiguration is studied for all different grounding densities presented in case 2. C4.2. Equipping four pole-mounted transformers with surge arresters (4 SAs). To do so, the total spans are divided into five. Therefore, the transformers protected by surge arresters are located on poles #16, #36, #56, and #76. This sub-configuration is studied for all different grounding densities presented in case 2.
This case is used to evaluate the impacts of equipping some transformers with surge arresters on the probability of transformers experiencing different overvoltage stress levels. Although the surge arresters are quite effective in protecting the transformers against overvoltage stress [45], their high capital costs prevent equipping all the transformers in a medium voltage network with these devices.
Tables 11-13 present the number of transformers experiencing different overvoltage stress levels after striking direct lightning on different poles of the sample distribution network under three primary configurations, namely the network with wet creosote-impregnated, wet arsenic-

Case 4. Considering Surge Arrester for Some Transformers
In this case, the three primary network configurations (see Section 4, assumption d) are investigated under two different sub-configurations by equipping two or four pole-mounted transformers with surge arresters. These sub-configurations are as follows.
C4.1. Equipping two pole-mounted transformers with surge arresters (2 SAs). To do so, the total spans are divided into three. Therefore, the transformer poles are poles #26 and #56. This sub-configuration is studied for all different grounding densities presented in case 2. C4.2. Equipping four pole-mounted transformers with surge arresters (4 SAs). To do so, the total spans are divided into five. Therefore, the transformers protected by surge arresters are located on poles #16, #36, #56, and #76. This sub-configuration is studied for all different grounding densities presented in case 2.
This case is used to evaluate the impacts of equipping some transformers with surge arresters on the probability of transformers experiencing different overvoltage stress levels. Although the surge arresters are quite effective in protecting the transformers against overvoltage stress [45], their high capital costs prevent equipping all the transformers in a medium voltage network with these devices.
Tables 11-13 present the number of transformers experiencing different overvoltage stress levels after striking direct lightning on different poles of the sample distribution network under three primary configurations, namely the network with wet creosote-impregnated, wet arsenic-impregnated, and dry poles, respectively, where two transformers are equipped with surge arresters and none of the intermediate poles are grounded.   By comparing Table 11 with Table 2, it can be seen that, by equipping two transformers (at poles #26 and #56), the number of transformers experiencing overvoltage stress has been decreased only when the lightning is applied on the poles adjacent to these transformers, such as poles #25, #28, #55, and #58. For example, when the lightning strikes directly pole #25, the number of transformers experiencing overvoltage stress above 150 kV and 125 kV is decreased to zero, while, without considering surge arresters, one transformer experiences such overvoltage stress (see Table 2). Also, Table 2 shows that, when the lightning is applied on pole #28, before considering any surge arrester, the numbers of transformers under overvoltage stress above 150 kV and 125 kV are two and three, respectively, while by installing surge arresters, only one transformer experiences such overvoltage stress (see Table 11). Comparing Tables 12 and 13 with Tables 3 and 4 shows a similar positive impact of considering surge arresters on mitigating the overvoltage stress at the MV terminals of some transformers. To present the impacts more clearly, the probabilities of overvoltage stress on MV terminals of transformers for sub-configuration C4.1 and C4.2 under different grounding densities and for three primary network configurations (see Section 4, assumption d) are presented in Figures 27-30. In all of these figures, for each primary configuration of the network, three different conditions are studied, such as without surge arrester (case 1, presented by solid bars), with two surge-arrester-protected transformers (sub-configuration C4.1, presented by patterned bars), and with four surge-arrester-protected transformers (sub-configuration C4.2, presented by diagonal stripes). Figure 27 presents the probabilities of transformers experiencing overvoltage stress above 150 kV under different grounding densities. As can be seen from this figure, for the case without grounded intermediate poles (only all transformers (Only Tr) grounded), considering two and four transformer poles results in some mitigation in the overvoltage stress. By protecting two transformers with a surge arrester, both the networks with wet creosote-impregnated poles (blue bars) and dry poles (gray bars) show around a 1.05% decrement in the probabilities of transformers experiencing overvoltage stress, while for the network with wet arsenic-impregnated poles, it results in 0.84% decrement. On the other hand, in this figure, the best performance for all network configurations is obtained when four transformers are equipped with surge arresters where, compared with the scenarios without surge arrester (solid bars), the networks with wet arsenic poles and dry poles show a 1.68% decrement in the probabilities and the network with wet creosote poles shows a 1.47% decrement. Figure 27, compared with the similar overvoltage stress level (above 150 kV) in Figures 23-25, shows that considering guy wires for all intermediate poles results in a better outcome than equipping four transformers in the network with surge arresters. Needless to say, and as concluded in case 2, by grounding only one intermediate pole, a great enhancement in the protection level of the transformers is obtained. On the other hand, as can be seen in Figure 27, after grounding one intermediate pole, using surge arresters slightly decreases the probabilities, while grounding two intermediate poles means that the surge arrester does not have a supportive role against direct lightning strikes, and in one scenario (gray diagonal stripes), it negligibly increases the probability of overvoltage stress.  Figure 27 presents the probabilities of transformers experiencing overvoltage stress above 150 kV under different grounding densities. As can be seen from this figure, for the case without grounded intermediate poles (only all transformers (Only Tr) grounded), considering two and four transformer poles results in some mitigation in the overvoltage stress. By protecting two transformers with a surge arrester, both the networks with wet creosote-impregnated poles (blue bars) and dry poles (gray bars) show around a 1.05% decrement in the probabilities of transformers experiencing overvoltage stress, while for the network with wet arsenic-impregnated poles, it results in 0.84% decrement. On the other hand, in this figure, the best performance for all network configurations is obtained when four transformers are equipped with surge arresters where, compared with the scenarios without surge arrester (solid bars), the networks with wet arsenic poles and dry poles show a 1.68% decrement in the probabilities and the network with wet creosote poles shows a 1.47% decrement. Figure 27, compared with the similar overvoltage stress level (above 150 kV) in Figures  23-25, shows that considering guy wires for all intermediate poles results in a better outcome than equipping four transformers in the network with surge arresters. Needless to say, and as concluded in case 2, by grounding only one intermediate pole, a great enhancement in the protection level of the transformers is obtained. On the other hand, as can be seen in Figure 27, after grounding one intermediate pole, using surge arresters slightly decreases the probabilities, while grounding two intermediate poles means that the surge arrester does not have a supportive role against direct lightning strikes, and in one scenario (gray diagonal stripes), it negligibly increases the probability of overvoltage stress.  under different grounding densities and three different sub-configurations, such as without considering any surge arrester as well as considering two and four transformers with surge arresters. Similar to the overvoltage above 150 kV, under both overvoltage stress levels above 125 kV and 85 kV, the surge arresters are triggered and start protecting the transformers. This can be seen mainly when only all transformers (Only Tr) are grounded and all the intermediate poles remain ungrounded. For example, in Figure 28, after considering two transformers with surge arresters, the probabilities in the Only-Tr sub-configuration decrease by around 1.05%, 0.84%, and 0.84%, respectively, for the network with wet creosote, wet arsenic, and dry poles, while by equipping four transformers by surge arresters, the probabilities are decreased by about 1.68%, 1.47%, and 1.47%, respectively. A similar condition can be observed for the probabilities of transformers experiencing overvoltage stress above 85 kV in Figure 29. Another observation in Figure 29 is related to the protection enhancement for sub-configurations with two and even three grounded intermediate poles that cannot be seen for overvoltage stress above 150 kV (in Figure 27) and above 125 kV (in Figure 28). respectively, for the network with wet creosote, wet arsenic, and dry poles, while by equipping four transformers by surge arresters, the probabilities are decreased by about 1.68%, 1.47%, and 1.47%, respectively. A similar condition can be observed for the probabilities of transformers experiencing overvoltage stress above 85 kV in Figure 29. Another observation in Figure 29 is related to the protection enhancement for sub-configurations with two and even three grounded intermediate poles that cannot be seen for overvoltage stress above 150 kV (in Figure 27) and above 125 kV (in Figure 28).  Unlike the three previous overvoltage stress levels, the overvoltage stress above 30 kV shows an unpredictable behavior where considering surge arresters in some scenarios results in increasing the probabilities of transformers experiencing such overvoltage stress. However, this can be justified by considering previous cases. Surge arresters are mainly used to protect the power system equipment against overvoltage phenomena by limiting the overvoltage amplitude or discharging the surge currents associated with surge overvoltages [53]. Therefore, in the sample MV network, these devices are not triggered for overvoltage stress around 30 kV. As a result, and as can be seen in Figures 27-29, the surge arrester is triggered for overvoltage levels above 150 kV, 125 kV, and 85 kV, and the amplitude of overvoltage at the MV terminals of some transformers is decreased to a level below 85 kV, which is accumulated as the probability of an overvoltage stress level above 30 kV. respectively, for the network with wet creosote, wet arsenic, and dry poles, while by equipping four transformers by surge arresters, the probabilities are decreased by about 1.68%, 1.47%, and 1.47%, respectively. A similar condition can be observed for the probabilities of transformers experiencing overvoltage stress above 85 kV in Figure 29. Another observation in Figure 29 is related to the protection enhancement for sub-configurations with two and even three grounded intermediate poles that cannot be seen for overvoltage stress above 150 kV (in Figure 27) and above 125 kV (in Figure 28).  Unlike the three previous overvoltage stress levels, the overvoltage stress above 30 kV shows an unpredictable behavior where considering surge arresters in some scenarios results in increasing the probabilities of transformers experiencing such overvoltage stress. However, this can be justified by considering previous cases. Surge arresters are mainly used to protect the power system equipment against overvoltage phenomena by limiting the overvoltage amplitude or discharging the surge currents associated with surge overvoltages [53]. Therefore, in the sample MV network, these devices are not triggered for overvoltage stress around 30 kV. As a result, and as can be seen in Figures 27-29, the surge arrester is triggered for overvoltage levels above 150 kV, 125 kV, and 85 kV, and the amplitude of overvoltage at the MV terminals of some transformers is decreased to a level below 85 kV, which is accumulated as the probability of an overvoltage stress level above 30 kV. Unlike the three previous overvoltage stress levels, the overvoltage stress above 30 kV shows an unpredictable behavior where considering surge arresters in some scenarios results in increasing the probabilities of transformers experiencing such overvoltage stress. However, this can be justified by considering previous cases. Surge arresters are mainly used to protect the power system equipment against overvoltage phenomena by limiting the overvoltage amplitude or discharging the surge currents associated with surge overvoltages [53]. Therefore, in the sample MV network, these devices are not triggered for overvoltage stress around 30 kV. As a result, and as can be seen in Figures 27-29, the surge arrester is triggered for overvoltage levels above 150 kV, 125 kV, and 85 kV, and the amplitude of overvoltage at the MV terminals of some transformers is decreased to a level below 85 kV, which is accumulated as the probability of an overvoltage stress level above 30 kV.  Figure 31 presents a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different grounding densities for the network with dry poles and considering two surge arrester protected transformers, respectively. By considering two surge arresters, the nearest surge arrester to the transformer pole #36 is placed at pole #26 (see sub-configuration C4.1). From the red curve in Figure 31, which presents the overvoltage waveform under no grounded intermediate pole, it can be seen that the overvoltage amplitude, compared with case 1, is decreased by around 3%, while the spark gap is still triggered. The peak values presented in Figure 31 compared with similar grounding densities in case 2 (see Figure 19) show that the decreases and increases in overvoltage are negligible, and, consequently, if the surge arrester is far from the location of the lightning strike, it might not enhance the network's protection against lightning overvoltages. On the other hand, a comparison with the results of case 3 (see Figure 26) shows that guy wires are much more effective than the impact of a surge arrester placed far from the lightning strike location.    Figure 31 presents a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different grounding densities for the network with dry poles and considering two surge arrester protected transformers, respectively. By considering two surge arresters, the nearest surge arrester to the transformer pole #36 is placed at pole #26 (see sub-configuration C4.1). From the red curve in Figure 31, which presents the overvoltage waveform under no grounded intermediate pole, it can be seen that the overvoltage amplitude, compared with case 1, is decreased by around 3%, while the spark gap is still triggered. The peak values presented in Figure 31 compared with similar grounding densities in case 2 (see Figure 19) show that the decreases and increases in overvoltage are negligible, and, consequently, if the surge arrester is far from the location of the lightning strike, it might not enhance the network's protection against lightning overvoltages. On the other hand, a comparison with the results of case 3 (see Figure 26) shows that guy wires are much more effective than the impact of a surge arrester placed far from the lightning strike location.  Figure 31 presents a comparison among the overvoltage stress on terminal c of the transformer at pole #36 under different grounding densities for the network with dry poles and considering two surge arrester protected transformers, respectively. By considering two surge arresters, the nearest surge arrester to the transformer pole #36 is placed at pole #26 (see sub-configuration C4.1). From the red curve in Figure 31, which presents the overvoltage waveform under no grounded intermediate pole, it can be seen that the overvoltage amplitude, compared with case 1, is decreased by around 3%, while the spark gap is still triggered. The peak values presented in Figure 31 compared with similar grounding densities in case 2 (see Figure 19) show that the decreases and increases in overvoltage are negligible, and, consequently, if the surge arrester is far from the location of the lightning strike, it might not enhance the network's protection against lightning overvoltages. On the other hand, a comparison with the results of case 3 (see Figure 26) shows that guy wires are much more effective than the impact of a surge arrester placed far from the lightning strike location.  Figure 32 considers similar sub-configurations as Figure 31, but the network has four surge arrester-supported transformers. By considering four surge arresters in the network, one surge arrester is paced at pole # 36 (see sub-configuration C4.2). This case shows a significant difference not only with case 1 but also with similar grounding conditions in case 2, case 3, and case 4 with two   Figure 32 considers similar sub-configurations as Figure 31, but the network has four surge arrester-supported transformers. By considering four surge arresters in the network, one surge arrester is paced at pole # 36 (see sub-configuration C4.2). This case shows a significant difference not only with case 1 but also with similar grounding conditions in case 2, case 3, and case 4 with two surge arresters. As expected, the surge arrester, by absorbing extra energy from the lightning, decreases the overvoltage stress at the terminals of the transformers and consequently shows the best performance among all other sub-configurations. That is, when a surge arrester is placed near the lightning strike, it significantly increases the protection level of the network. In other words, to have such a strong protection level in a network, all the transformers need to be protected by proper surge arresters, which is certainly a costly action.
Energies 2020, 13, x FOR PEER REVIEW 31 of 34 surge arresters. As expected, the surge arrester, by absorbing extra energy from the lightning, decreases the overvoltage stress at the terminals of the transformers and consequently shows the best performance among all other sub-configurations. That is, when a surge arrester is placed near the lightning strike, it significantly increases the protection level of the network. In other words, to have such a strong protection level in a network, all the transformers need to be protected by proper surge arresters, which is certainly a costly action.

Conclusions
This work has investigated the role of protecting devices which aim to provide optimized protection of medium voltage (MV) distribution transformers against direct lightning strikes on the phase conductor. To this end, the roles of grounding densities of intermediate poles, guy wire, and surge arresters on mitigating the overvoltage stress on the MV terminals of distribution transformers have been thoroughly studied while assuming that all transformers are by default protected by spark gaps and all transformer poles are grounded. It has been shown that grounding the intermediate poles (even only one intermediate pole) can significantly decrease the risk of overvoltage stress on the MV terminals of distribution pole-mounted transformers for all four considered stress levels above 150 kV, 125 kV, 85 kV, and 30 kV. The best outcome is achieved when all poles (transformer and intermediate poles) are grounded; however, this might not be the optimal practice. Additionally, it has been witnessed that supporting intermediate poles with guy wires significantly decreases the probabilities of transformers experiencing high voltage stress. However, when the number of grounded intermediate poles is increased, the performance of guy wires is inferior to the better performance of grounding. In other words, guy wires show better performance when none of the intermediate poles are grounded or the number of grounded intermediate poles does not exceed two poles between every two successive transformer poles. On the other hand, equipping some transformers with surge arresters provides great support only for the adjacent transformers, such that even equipping four transformers out of 17 does not provide the protection that the guy wires provide for the network. That is, its support for the network would be significant when most of the transformers are equipped with this device.
All in all, the obtained results, presented in several tables and figures, as well as the provided interpretations, can serve as a reference table to provide a clear picture for the wooden pole-based

Conclusions
This work has investigated the role of protecting devices which aim to provide optimized protection of medium voltage (MV) distribution transformers against direct lightning strikes on the phase conductor. To this end, the roles of grounding densities of intermediate poles, guy wire, and surge arresters on mitigating the overvoltage stress on the MV terminals of distribution transformers have been thoroughly studied while assuming that all transformers are by default protected by spark gaps and all transformer poles are grounded. It has been shown that grounding the intermediate poles (even only one intermediate pole) can significantly decrease the risk of overvoltage stress on the MV terminals of distribution pole-mounted transformers for all four considered stress levels above 150 kV, 125 kV, 85 kV, and 30 kV. The best outcome is achieved when all poles (transformer and intermediate poles) are grounded; however, this might not be the optimal practice. Additionally, it has been witnessed that supporting intermediate poles with guy wires significantly decreases the probabilities of transformers experiencing high voltage stress. However, when the number of grounded intermediate poles is increased, the performance of guy wires is inferior to the better performance of grounding. In other words, guy wires show better performance when none of the intermediate poles are grounded or the number of grounded intermediate poles does not exceed two poles between every two successive transformer poles. On the other hand, equipping some transformers with surge arresters provides great support only for the adjacent transformers, such that even equipping four transformers out of 17