Open access peer-reviewed chapter

Innovative Differential Protection Scheme for Microgrids Based on RC Current Sensor

Written By

Ali Hadi Abdulwahid and Adnan A. Ateeq

Submitted: October 2nd, 2018 Reviewed: February 26th, 2019 Published: May 13th, 2019

DOI: 10.5772/intechopen.85473

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The modern power system and future ones include several intelligent devices. It also integrates renewable energy sources, energy storage, energy microgrid control system, hybrid networks, and smart grids with the wide application of information technology and communication. The most crucial goal in the smart grid application is improving safety reliability within the network. Recent studies have recommended the development of smart grid technology that enhances the reliability of electric power systems increases efficiency and improves the detection of faults for protection; this will reduce the duration of interruption of the number of customers affected by the outages. Moreover, smart grid technology decreases the power loss of energy usage and improves the efficiency of the system. And protection is one of the most important challenges facing smart grid deployment. In this chapter, protection for smart grids using differential relays is presented. The differential scheme is a very reliable method of ensuring the safety of protected areas. This chapter discusses the differential relay parameters with various fault conditions. Therefore, the protection scheme affirms the rapid separation of the fault zone to reduce damage to the equipment. The simulation results show that the method is effective and reliable.


  • microgrid
  • reliability
  • renewable energy sources
  • power grids
  • power distribution
  • differential protection

1. Introduction

The latest revolution in the electricity network technology is called smart grid (SG). Smart grid term describes the future intelligent electric power that using digital technology to monitor and control. In other words, smart grids integrate information and communication intelligently to improve the electricity delivered to customers. It will also enhance safety and reliability, and financial control services in the system. A smart grid is a version of the future power grid that employs advanced equipment and services together with intelligent monitoring, control, communication, and intellectual protection. It is referred to as a revolution in the future of electric power grids because by using applicable technologies, it is a modern and integrated system. With increased energy demands and the expansion of renewable energy sources, power grid systems must be moderated and improved. The smart grid will integrate all types of electric power sources, and accommodate all means of energy generation and distribution to meet the future demands of energy and its technologies [1].

Quality of power delivery is a significant goal of the smart grid that will provide a variety of needs and options at different costs. Furthermore, smart grids will provide advanced monitoring and control by employing intelligent equipment such as digital sensors, electronic switches, smart energy metering, and creative and advanced communication systems. Its data acquisition and control systems include interactive software, real-time control, and power flow analysis. All different types of renewable energy sources will be interconnected with the energy grid system to improve quality, reliability, and stability by using intelligent and advanced devices. Providing advanced technology such as the smart grid requires a smart and intelligent protection system to improve the efficiency of power delivery to customers, and to reduce outages. Employing the smart grid allows energy consumers to be active participants by providing information and options to control the electric demand balance [2].

The microgrid is used to provide customers with economical and reliable power resources and to make effective use of them through the formation of a smart grid structure during the disturbance. However, the protection of microgrid is a challenging task [3, 4, 5]. This chapter discusses the application of differential protection schemes. Issues related to protection include bidirectional power flow; it also handles the decrease in fault current levels [6, 7, 8]. The power system must operate safely at all times. The main requirements for power system protection include speed, selectivity, sensitivity, safety, reliability and dependability. The reliability requirements of the protection system ensure that appropriate and operable protective measures taken even when certain parts of the protective device may fail [9].


2. Challenges in implementation of smart grids

As shown in Figure 1, the key features of the smart grid offer many advantages and prospects in the power industry, thereby revitalizing the socioeconomic strategies of this sector. However, the extensive applications of emerging technologies, if not considered, have vulnerabilities that may result in disasters such as long-term blackouts, economic failure, and so on. Table 1 provides a brief survey of some of the challenges of smart grid technology [10].

Figure 1.

Future smart grid processing technology.

Technology Challenges Issues
Self-healing action Security Exposed to Internet attacks (spams, worms, virus, and others), question of national security
Reliability Failure during natural calamities, system outages, and total blackout
Renewable energy integration Wind/PV generation and forecasting Long-term and unpredictable intermittent sources of energy, unscheduled power flow and dispatch
Power flow optimization Transmission line congestion and huge investments
Power system stability Decoupling causes system stability issues and causes reduced inertia due to high level of wind penetration
Energy systems storage Complexity Complex customary design module and networks
Non-flexibility Unique designs for all individual networks; no ease of adaptation
Consumer motivation Security Malware, data interception, data corruption, illegal power handling, and smuggling
Privacy Sharing of data causes privacy invasion, identity spoofing, eavesdropping, and other problems
Reliability Grid automation Need for strong data-routing system with secure and private network for reliable protection, control, and communication
Grid Reconfiguration Generation demand equilibrium and power system stability with grid complexity
Power quality Disturbance identification System instability during sags, dips, or voltage variation such as over-voltages, under-voltages, voltage flickers, and other problems

Table 1.

Challenges of smart grid technology.

Extensive research on this technology, which aims to overcome many challenges, has been launched by various universities. The system parameters and configuration of the power grids were investigated more intelligently.


3. Rogowski coil current sensor

The Rogowski coil (RC) current sensor works in the same way as a conventional AC core current transformer. They are not closed loops, making the coils open and flexible, and can be wrapped around the conductors [11, 12, 13]. RCs can immediately respond to the changing currents, down to a few nanoseconds, due to their low inductance. RC has no iron core to saturate, making it highly linear even when exposed to large currents. Linearity also allows high-current RCs to be determined using smaller reference currents. No danger is observed in opening the secondary winding [14]. Power construction costs and temperature compensation are simple [15, 16, 17]. Besides, RC does not use the magnetic core to support two windings. RC is designed with two coils that are electrically connected in the opposite direction, eliminating the electromagnetic field from the outer ring routing. For obtain the current sensor quality, the RC design must meet two important criteria; the first criterion, the mutual inductance M must have a constant value for any of the main conductor locations inside the coil loop, which can be achieved if the coil core has a constant cross section S, is perpendicular to the median line and is constructed with a constant turn density n. Second, the effects of adjacent conductors carrying a large current to the coil of the output signal should be minimal. The following formula defines mutual inductance M:

M = μ o n S E1

When the core has a constant cross-section S, μo is the permeability of the free space, and the winding line is perpendicular to the midline m, with a constant density n. The output voltage is proportional to the measured rate of change of current, as shown in Eq. (2) [18]:

v t = μ o nS di t dt = M di t dt E2

Where M is the mutual inductance of the coil, also called the sensitivity of the RC. The CT iron core has a nonlinear characteristic and is therefore saturated when a high current or a direct current component is present in primary current. When CT is saturated (that is, the CT ratio error increases), which adversely affects the performance of the relay. Figure 2 displays the equivalent circuit of a current transformer.The current phase angle between the primary coil and the secondary voltage is almost 90° (due to the coil inductance Ls). Figure 3 shows the equivalent circuit of RCs.

Figure 2.

Current transformer equivalent circuit.

Figure 3.

Rogowski coil equivalent circuits.

Rogowski coils are linear and can be used in measurement applications. The oscillatory response of RC can be represented by voltage response and natural frequency, as described below:

V o t = M di t dt = M di t dt . e ξω n t sin ω n 1 ξ 2 t , E3

where ωn is the natural frequency, and ε is the damping coefficient. As a result, RCs can replace conventional CTs for measurement and protection. IEEE Std C37.235TM-2007 [19] provides guidance on the application of RC sensors when used for protection purposes, review the essential characteristics.

  • Accuracy: Rogowski coils can be used for measurement, protection, and control. Traditionally, separate secondary windings are used for measurement and protection. The linearity range of sensors enables the combination of sensors for metering and protection in a single device, thereby resulting in sensors with smaller dimensions.

  • Linearity (no saturation): Rogowski coils are linear over a wide range of currents. No calculation specific to the control for different primary currents is required. Calculation of precision limit factors is also unnecessary.

  • No accuracy versus burden calculation: Rogowski coils are used with microprocessors that have high input impedance. Therefore, calculating the accuracy and burden (no precision and load calculation) is not needed.

  • Size: Rogowski coil devices are compact and can be easily combined with voltage sensors in one device, which is known as Combi sensor. Furthermore, RCs can be integrated into other equipment such as circuit breakers, power transformers, and switches.

  • Weight: Rogowski coils are lightweight, especially compared to conventional current transformers with large cores. A higher weight/size advantage arises from the use of combined units, including both current and voltage sensors.

  • Safety: Low secondary (transmitted) voltage.


4. Proposed method of protection

Figures 4 and 6 shows a single-phase (internal and external) fault differential protection system. Obviously, a pair of current sensors by using RC surrounded the protected area. Since this was a natural trend, differential protection provided protection for system equipment wire carrying current from the RC called a pilot wire.

Figure 4.

Differential relay currents at the time internal fault.

In case of no fault, current input protection unit I p is to be at all times the same to the current going out of the protected zone. Considering current in transformer A, the pilot wire was carrying current as follows:

I AS = a A I p I Ae I AS = a A I p I Ae E4

where aA is the conversion ratio for RC A and IAe is the secondary excitation current for RC A. Similarly, for current in transformer B, the equation is as follows:

I BS = a B I p I Be E5

where aB is the conversion ratio for RC B and IBe is the secondary excitation current for RC B.Considering the equal ratio, aA = aB = a, relay working current I op is:

I op = I Ae I Be E6

When there was a normal operation or the external fault of the system, the relay’s working current I op was very small, but never tends to zero. Nevertheless, within the time the internal fault was in the protected area, the current was no longer equal to the outgoing current. The operating current of the differential relay is nothing more than an increase of the input current as the same as the feed fault.

I op = a I f 1 + I f 2 I Ae I Be E7

The uniform distribution of the line is as shown in Figure 5. Where, co is a shunt capacitance (F/km), go the shunt leakage conductance (S/km), Io the series inductance (H/km) and ro is a series resistance ( Ω /km). The distribution of current and voltage along the transmission line is given by the equations of the current and voltage display in the diagram at the ends of the line.

∂u ∂x = r o i + l o ∂i ∂t E8
∂i ∂x = g o u + c o ∂i ∂t E9

By reducing Eqs. (5) and (6) to their frequency domain,

U m I m = ch γl nm Z c sh γl nm sh γl nm / Z c ch γl nm U n I n E10

Figure 5.

Transmission line model with a fault located inside the two ends.

where sh γl nm and ch γl nm = hyperbolic function , Zc = characteristic impedance , γ = the propagation constant and both are freqency dependent ; l nm = distance from end to end m .

By considering the appropriate characteristic impedance and propagation constant, we can apply the above conversion method to the zero, positive and negative sequence components of the current. In this paper, the “0,” “1,” and “2” subscripts were described as zero, positive, and negative sequences, respectively.

I mk 0 = I m 0 ch γ 0 l mk U m 0 Z c 0 sh γ 0 l mk E11
I mk 1 = I m 1 ch γ 1 l mk U m 1 Z c 1 sh γ 1 l mk E12
I mk 2 = I m 2 ch γ 1 l mk U m 2 Z c 2 sh γ 1 l mk E13
I nk 0 = I n 0 ch γ 0 l nk U n 0 Z c 0 sh γ 0 l nk E14
I nk 1 = I n 1 ch γ 1 l nk U n 1 Z c 1 sh γ 1 l nk E15
I nk 2 = I n 2 ch γ 1 l nk U n 2 Z c 2 sh γ 1 l nk E16

where l mk and l nk = distance of point k from end m and n respectively .

a = e j 2 π / 3
I mka I mkb I mkc = 1 1 1 1 a 2 a 1 a a 2 I mk 0 I mk 1 I mk 2 E17

Similarly, the relationship to current is as below:

I nka I nkb I nkc = 1 1 1 1 a 2 a 1 a a 2 I nk 0 I nk 1 I nk 2 E18

If the fault is outside the protected area or there is no fault in the system, then the phase current should satisfy the following equation:

I mk = I nk E19

where = a , b , c shows the phase from where the current belong to.

The following explanation makes it possible to understand the actual current and the position where the fault and the derivation of the current occur. To calculate the fault location of the current and voltage from the end n,

U f 0 = U n 0 ch γ 0 l nf I n 0 Z c 0 sh γ 0 l nf E20
U f 1 = U n 1 ch γ 1 l nf I n 1 Z c 1 sh γ 1 l nf E21
U f 2 = U n 2 ch γ 1 l nf I n 2 Z c 1 sh γ 1 l nf E22
I f 0 = I n 0 ch γ 0 l nf U n 0 Z c 0 sh γ 0 l nf E23
I f 1 = I n 1 ch γ 1 l nf U n 1 Z c 1 sh γ 1 l nf E24
I f 2 = I n 2 ch γ 1 l nf U n 2 Z c 2 sh γ 1 l nf E25

The differential current is the actual measure of relay operation. In addition, the brake current is one of the avoided currents of the mal-tripping differential relay. The effect of this current has been in breaking the relay.

I B = I mk 1 + I nk 1 E26
I B = I mk 1 + I nk ˙ I f 1 ch γ 1 l fk E27

The effects of the capacitive current can be cancelling with any of the use of the following techniques. Shunt Reactor, Phasor Compensation algorithm, Capacitor Current Compensation, and Bergeron line Model.

In reality, the proposal is a reliable method for the protection system. Since each current transformer and circuit breaker can only declare a line, it is usual to protect by the use of two side current transformers and circuit breakers. The currents on both sides were compared. Under normal conditions or for defects outside the protected area, the current Bas-Bar A is equal to the current Bas-Bar B. Thus, the currents in the secondary current transformer were equal; no current flowed through the relay current. If a fault occurs in the protected zone, the secondary transformer currents of Bas-Bar A and Bas-Bar B will not be the same, and there will be a current flowing through the relay current, as shown Figure 6.

Figure 6.

Differential relay currents at the external fault.

The differential protection ratio, by using a multi-slope feature of the relay was inserted into the new relay for its excellent compromise between reliability and sensitivity. The components of the relay compared the different current I diff (also called operating current), and the restraining current I bias are expressed in Eqs. (28) and (29) [20, 21, 22, 23, 24].

I diff = I As + I Bs E28
I bias = I As + I Bs / 2 E29

where I As and I Bs are secondary RC phasor currents.


5. SCADA systems

It is considered as a means of monitoring and control of power plants also used in renewable power plants and these systems transfer data to the heart of the system which is a master computer and receives orders from many remote terminals; Figure 7 illustrates the structure of the SCADA system, the SCADA system includes the following:

  1. RTUs or PLC which transfers information to the central unit and transfers orders to equipment.

  2. Radio system or satellites to secure communication between central units and distributed areas away from the focal point.

  3. The software package used in the system.

Figure 7.

Network monitoring and control by supervisory control and data acquisition systems (SCADA).

The operation of electricity distribution networks is monitored and controlled by supervisory control and data acquisition (SCADA) systems. SCADA systems are linked through various communications networks such as microwave and optical fiber networks to ensure the functioning of the system. They are used to connect transmission substations with the major generators to facilitate an integrated system. The operation of the methods of communication in the networks of energy is produced by lines along the system with advanced optical networks. The loss of these communication cables is possible and could make the protection and monitoring of the network more complex. Using advanced wireless communication and sensing devices could improve the control and monitoring of the entire system. Intelligent Electronic Devices (IED) for monitoring and control to improve the technology of smart grids, and. IEDs can be installed and distributed within the system to be used for protection and monitoring [24, 25, 26, 27, 28]. These devices are interconnected and can be communicated to the central IED, which is implemented in the substation. On the other hand, IEDs can also monitor and update the electric flow of real-time status and can be used to manage and control the network. Figure 7 shows the monitoring and control by supervisory control and data acquisition system for smart grid technology.


6. System modeling

The simulation of line differential protection is presented in Simulink/MatLab environment, as shown in Figure 8.

Figure 8.

Simulation representation of the differential protection scheme.

It simulates three-phase, the system components are a transmission line with PV arrays (800 kW), Wind farm (9 MW), Resistive load (45 kW, 100 kW), 25 kV distribution Bus, and the utility grid. The proposed settings of the protection scheme for transmission lines from Bus-Bar 7 to Bus-Bar 9, and the information corresponding to the lines are listed in Table 2, where is the rated secondary current. In this study, is taken to be 1 Amp. According to the value of, the following constants are:

I O = 0.3 , I S 2 = 0.2 , K 1 = 0.35 , K 2 = 1.2 ;
Relay setting Range
Differential current setting (0.2–2.0 In)
Bias current threshold setting (1–30)
Lower percentage bias setting (0.3–1.5)
Higher percentage bias setting (0.2–2.0 In)

Table 2.

Relay setting ranges.

where In is the current rating of the secondary current transformer; Io is the differential current at zero bias current; Ibias is the bias current when the relay characteristic starts to change; and K1, K2 is the percentage biases. These constants can be obtained from the relay characteristic, which is used in relay operations. The differential protection operating region is above the slope of the characteristic, and the restraining of the region is below the slope of the characteristic. The dual slope bias technique is used to improve stability through fault and external fault CT saturation to provide further security. To achieve the appropriate setting, the characteristics of the relay to be applied must be considered. Three adjustable values (from the relay manual) are recommended as follows.

The block consists of a relay that is divided into two units, as shown in Figure 9.

Figure 9.

Flowchart for decision block.


7. Simulation results and discussion

Differential protection between the two circuit breaker CBs, are known the local side (CB1) and far side (CB2), the Current Sensors RCA and RCB are installed at the Bus-Bar (7 and 9), to measure the current and voltage per phase. The current and voltage of each phase of the analog signal are converted into digital data using an analog-to-digital converter (ADC). The local side is directly connected to the relay, whereas the far side is connected through the delay block. Channel time delay is set at 27 ms, the output of the differential relay block is binary (0, 1). When disturbances happen in the protected zone, a current difference between the two CBs (local and remote) exists. Thus, the relay sends a signal tripping to isolate the defective zone from the rest of the protection scheme. In this study, we propose that the fault will occur in the middle of the transmission line, starting at 0.3 ms. In the fault parameter block, the fault type is simulated separately using MATLAB. This section investigates the cases of faults (internal and external).

Five cases have been tracked: Case 1, single line to ground fault (SLGF); Case 2, line-to-line fault (LLF); Case 3, double line to ground fault (2LGF); Case 4, three-line fault (3LF); and Case 5, three line to ground fault (3LGF). The main principle of the differential relay should be compared for both ends of the protected area. Modeling for each case is similar through comparison of the current at both ends.

All used case results are indicated in Figures 1024. Three diagrams, namely, remote, local, and differential, are presented in every figure. Remote and local measurements are conducted separately; each colour in this diagram represents one phase, namely, red, green, and blue for phases A, B, and C, respectively. The signal to Trip is represented as a binary (0, 1) measurement depending on the difference between the signals of the two ends for sending the signal to the circuit breaker. In Figures 1023, two types of status are shown: for current differential and the voltage differential, with the fault occurring at t = 0.3 ms.

Figure 10.

SLGF current waveform.

Figure 11.

SLGF voltage waveform.

Figure 12.

2LGF current waveform.

Figure 13.

2LGF voltage waveform.

Figure 14.

SLGF (A) current waveform.

Figure 15.

SLGF (A) voltage waveform.

Figure 16.

Double-line (A and B) fault current waveform.

Figure 17.

Double-line (A and B) fault voltage waveform.

Figure 18.

2LGF (B and C) current waveform.

Figure 19.

2LGF (B and C) voltage waveform.

Figure 20.

3LF current waveform.

Figure 21.

3LF voltage waveform.

Figure 22.

3LGF current waveform.

Figure 23.

3LGF voltage waveform.

Figure 24.

The difference between the occurrence of a fault and a breaker signal.

7.1. Simulation result outside the protected zone

Figures 10 and 11 show the results of an external L-G fault on protection scheme. That is differential relays without sending tripping signal.

Similarly, the results of external fault on the protection scheme in various fault conditions, that is, that mean the relay No sending trip signal to the circuit breaker.

7.2. Simulation result within the protected zone

Figures 1423 show the results of an internal fault for the protected zone. The relay sends a trip signal to the circuit breaker under a faulty condition, and the circuit breaker isolates the zone relay from the rest of the protection scheme.

Figure 24 shows the time differences between the moment of a fault and signal of the breaker during and after the occurrence of the fault (Table 3). Displays the output of our proposed relay measurements; compared with the traditional behaviour in normal operation, the speed of our proposed scheme is less than one cycle.

Measurements Zone relay
Relay output Trip or no trip
The threshold of operation t = 0.3 ms
Decision speed Less than one cycle

Table 3.

Specifications of the proposed relay.


8. Summary

The reliability of the relay protection system can be described in two respects: dependability and security. The reliability of the relay protection system detects and disconnects all faults in the protection zone. The safety of the relay protection system is capable of rejecting all events and transients that are not faulty so that the healthy part of the power system is not unnecessarily disconnected. Differential protection is the preferred solution for widespread use; fault protection for multi-terminal systems becomes very difficult, and fast fault detection of systems becomes very important. This result provides different solutions for transmission line protection. This method is better than distance protection because differential protection requires fewer input data and reduces computation time.

The performance of this algorithm is more efficient than distance relay protection. The disadvantages of the distance on the transmission line and the directional over-current relay are as follows:

  1. If a fault occurs at the end of the line, the relay cannot be disconnected immediately at both ends of the line.

  2. Coordination is achieved by adjusting the time delay of the relays installed on the power line beside the primary protection and backup protection. Therefore, the delay time of the relay operating in each protection zone will slow down the termination of the interference.

The differential protection principle is based on Kirchhoff current law, which has been widely used in the primary equipment protection of the power systems. The general objective of the protection system is to quickly isolate the areas that contain unrest while preserving the rest of the system. The method of protection must meet five criteria to perform successfully: (1) reliability, (2) selectivity, (3) speed, (4) simplicity, and (5) economy.



The author would like to thank the editor and reviewers for their constructive comments and suggestions on this article. This work was supported by the Southern Technical University-Iraq, BETC, and the Huazhong University of Science and Technology-China (no. 01122018).


Conflicts of interest

The authors declare no conflicts of interest.

Author contributions

I would like to express my deep appreciation to Ms. Janan Abd Ali al-Hajji, also to Dr. Shaorong Wang (HUST), who oversaw my studies, and to the editor of books IntechOpen Dr. Ahmed Zobaa and Dr. Alfredo Vaccaro, I have the honor of working with them and join them.


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Written By

Ali Hadi Abdulwahid and Adnan A. Ateeq

Submitted: October 2nd, 2018 Reviewed: February 26th, 2019 Published: May 13th, 2019