Islanding Detection Strategy for Wind Farm Based on Performance Analysis of Passive Indices Having Negligible NDZ

: Distributed generation (DG) resources integration into power system results in environmental and economic beneﬁts. However, technical challenges may create many problems for the distribution system. Islanding detection is the topmost technical perspective regarding distribution system protection. This paper devised a passive islanding detection strategy that employed voltage phase angle (VPA). The VPA is selected after the performance assessment of 6 passive indices. Comparative study proves that VPA has the best accuracy and sensitivity compared to other indices parameters. The proposed technique is employed on a generic system that easily distinguished islanding situations from non-islanding cases such as load increment, load decrement, capacitor energization, capacitor de-energization, motor starting, motor unloading and various types of faults switching scenarios. The protective method is simple and has a quick interpretation algorithm as compared to other existing methods. The study is carried out on IEEE 1547 general test system in MATLAB/SIMULINK environment. The proposed strategy has nearly zero non-detection zone.


Introduction
Distributed energy resources (DER's) are an integral part of power systems as their inclusion is to reduce environmental pollution, improve system flexibility, reduce power losses, meet the load demands and increase system efficiency from economic and technical perspectives [1]. DER's (generally consist of solar plants, wind farms, mini hydro's turbines, biomass, fuel cell and geothermal energies) generate power at a smaller scale compared to conventional power resources, also refer as distributed generation (DG) [2]. However, excess DG inclusion in the power system and their unpredictable nature may lead to technical problems for the loads as well as DG itself. Some of the technical problems are unsynchronized reclosing, power quality issues, system security, maloperation of protection schemes, system stability and reliability, islanding and voltage regulation [2][3][4].
Unintended islanding condition is the one of chief alarming state from a technical viewpoint for power system operation. A fault is identified by the security scheme of the grid but not by DG protection scheme, failure operation of equipment, malpractices, an act via nature and human mistake are the main reason behind unintended islanding condition [5]. In the islanding situation, DG is still energizing the local load in response to grid supply disruption. Islanding is an unsolicited condition in a power system that originates safety concerns for workers, power quality issues for load and unsynchronized closure that harms generation and supply services [6]. A standard for islanding detection of these methods was high and have almost zero NDZ. Though, the usage of more indices makes the algorithm slightly complex. Some recent contributions have been considered in the literature including VPA techniques. Passive methods have been developed in [31][32][33][34][35][36][37][38][39] to minimize the NDZ and tripping time. In [40], the active islanding detection method for inverter type DG is employed based on voltage phase angle. A difference between the instantaneous and nominal voltage phase angle (VPA) of a distributed generation (DG) is applied to inverter-based interface control. However, inconsequential power quality issue is still present in this method. The active method for inverter base DG has been presented in [41] uses voltage phase angle of inverter-based DG as a feedback signal to change powers references. However, insignificant power quality issues still exist. In [42], the passive islanding detection method has been developed by combining under frequency (UF), over frequency (OF), rate of change of frequency (ROCOF), phase angle difference, rate of change of voltage (ROCOV) and rate of change of phase angle difference (ROCOPAD). This method has the advantages of zero NDZ and fast tripping time. However, the algorithm becomes complex due to using multiple passive parameters. The communication-based method has been used in [43] by employing proposed parameters of voltage phase angle difference and rate of change of voltage phase angle difference (ROCOVPAD). Zero NDZ, fast detection time and no power quality impacts on the system are the advantages of this method. However, the use of GPS and wireless modems is economically not good from an economical perspective.
The abovementioned passive islanding detection methods are either suffer from one of the issues like NDZ, power quality issue, large tripping time or have complexity in the algorithm. Further, the comprehensive performance analysis of passive indices has not been considered for possible worst-case scenarios of islanding and non-islanding. Previously, the passive islanding detection methods show that a lot of in-depth analysis has been carried out on rates of changes. The few techniques are based on the analysis of indices but in-depth performance analysis of methods has not been anticipated regarding the selection of the most sensitive indice at nearly zero NDZ.
The paper is organized in the following way: Section 2 describes the power system description, analysis of passive indices, the proposed methodology and validation of selected parameters on a generic test system. Section 3 represents the simulation results, comparison along with NDZ assessment. Lastly, the conclusion is provided in Section 4.

Materials and Methods
The power system in this study comprises of doubly-fed induction generator (DFIG) wind farm, utility grid, parallel RLC load, grid and wind farm transformers altogether connected to 11 kV, 50 Hz distribution system. Two circuit breakers (CB Grid , CB DG ) are connected to DG and grid respectively. DFIG contains an induction generator heaving wound rotor and PWM AC/DC/AC converter based on IGBT. AC/DC/AC converter provides variable frequency to the rotor whereas stator windings are directly linked with the power grid. Simulation parameters of the system are given in Table 1. These parameters are adjusted and varied to set desired testing cases. IEEE 1547 generic test system [44] is employed for validation of islanding detection technique performance as shown in Figure 1.
The control scheme of the DFIG can impact the behavior of different parameters during islanding events and abnormal conditions. The behavior of parameters can become unpredictable if control parameters deviate from default settings. The impact of the control scheme of DFIG on parameters mainly depends on the type of control and islanding detection strategy used.
The basic configuration of the DFIG wind turbine scheme is shown in Figure 2a-d. The DFIG control systems have two portions: mechanical control for wind turbine blade pitch angle and electrical control for DFIG. The controlling of DFIG is achieved through the control of voltage frequency converter (AC/DC/AC) that further consists of control of grid side coveter (GSC) & control of rotor side coveter (RSC) [45,46].
The basic configuration of the DFIG wind turbine scheme is shown in Figure 2a-d. The DFIG control systems have two portions: mechanical control for wind turbine blade pitch angle and electrical control for DFIG. The controlling of DFIG is achieved through the control of voltage frequency converter (AC/DC/AC) that further consists of control of grid side coveter (GSC) & control of rotor side coveter (RSC) [45,46].    • RSC is responsible for the regulation of stator active and reactive independently.

•
Irrespective of the direction and magnitude of rotor power, GSC maintains the DC link voltage.

•
The wind turbine controller is responsible for controlling the blade pitch angle that measures the mechanical power extracted from a wind turbine.
The basic configuration of the DFIG wind turbine scheme is shown in Figure 2a-d. The DFIG control systems have two portions: mechanical control for wind turbine blade pitch angle and electrical control for DFIG. The controlling of DFIG is achieved through the control of voltage frequency converter (AC/DC/AC) that further consists of control of grid side coveter (GSC) & control of rotor side coveter (RSC) [45,46].    In our proposed method, a separate relay with synchro-phasor measurement functionality is used at a single DG connection point. However, when multiple DG's will be used then separate relays must be employed for every DG connection point. A multiple In our proposed method, a separate relay with synchro-phasor measurement functionality is used at a single DG connection point. However, when multiple DG's will be used then separate relays must be employed for every DG connection point. A multiple DFIG's network has employed in [6] used four separate relays for each DG connection point. Contrary to this, some inverter base DG has used the islanding detection control schemes added in the inverter control for gaining the cost-efficiency benefits. The inverterbased control schemes can be active or passive. However, the designing of inverter control schemes for islanding detection is complex as compared to passive methods. The proposed method in this study is independent of any type of inverter-based control.
In this work, 6 different passive indices are considered for analysis such as voltage, frequency, active power, reactive power, power factor and voltage phase angle. These 6 parameters are inspected on the power system under analysis as presented in Figure Table 2. The absolute values (magnitudes or phase) are noted for all considered indices after numerous islanding and non-islanding events are shown in Figure 3a-f.
After careful investigation of passive indices (voltage, frequency, active power, reactive power, power factor), it has been noted that the magnitude/phase of passive indices are intermixed for islanding vs. non-islanding scenarios as shown in Figure 3a-e. However, the voltage phase angle as shown in Figure 3f presents a considerable picture. Voltage phase angle differentiate islanding operations from non-islanding events.
Appl. Sci. 2021, 11, x FOR PEER REVIEW 6 of 17 DFIG's network has employed in [6] used four separate relays for each DG connection point. Contrary to this, some inverter base DG has used the islanding detection control schemes added in the inverter control for gaining the cost-efficiency benefits. The inverterbased control schemes can be active or passive. However, the designing of inverter control schemes for islanding detection is complex as compared to passive methods. The proposed method in this study is independent of any type of inverter-based control. In this work, 6 different passive indices are considered for analysis such as voltage, frequency, active power, reactive power, power factor and voltage phase angle. These 6 parameters are inspected on the power system under analysis as presented in Figure 1 Table 2. The absolute values (magnitudes or phase) are noted for all considered indices after numerous islanding and non-islanding events are shown in Figure 3a-f.
After careful investigation of passive indices (voltage, frequency, active power, reactive power, power factor), it has been noted that the magnitude/phase of passive indices are intermixed for islanding vs. non-islanding scenarios as shown in Figure 3a-e. However, the voltage phase angle as shown in Figure 3f presents a considerable picture. Voltage phase angle differentiate islanding operations from non-islanding events.  On the other hand, the main concern can be highlighted regarding rapid normal frequency fluctuations when the penetration level of DG's will increase. This can tend to the maloperation of passive methods. Maloperation of relay can be expected at severe sensitive settings and less setting that can result in large NDZ. The main aim of performance analysis is to determine the power indices that can observe the minor disturbances proficiently. The performance analysis of power system parameters has assured the capability of a selected parameter in terms of moderate threshold setting without causing maloperation of the scheme. Parameter used without performance analysis could be vulnerable to maloperation. The selected parameter gives a clear picture that it will give a maloperationless strategy and differentiate islanding from a non-islanding operation. Our proposed method has nearly zero NDZ because we avoid a less sensitive threshold setting. Hence, without performance analysis of power system parameters selection of threshold is very difficult.
Assessment of passive indices presented above demonstrates that voltage phase angle (VPA) has the best capability in terms of performance and sensitivity among all other passive parameters. Therefore, VPA is employed in the islanding detection process. The flow chart of the proposed strategy is shown in Figure 4. The proposed method measures absolute VPA at every half cycle. The strategy is activated when Equation (1) is satisfied:  On the other hand, the main concern can be highlighted regarding rapid normal frequency fluctuations when the penetration level of DG's will increase. This can tend to the maloperation of passive methods. Maloperation of relay can be expected at severe sensitive settings and less setting that can result in large NDZ. The main aim of performance analysis is to determine the power indices that can observe the minor disturbances proficiently. The performance analysis of power system parameters has assured the capability of a selected parameter in terms of moderate threshold setting without causing maloperation of the scheme. Parameter used without performance analysis could be vulnerable to maloperation. The selected parameter gives a clear picture that it will give a maloperation-less strategy and differentiate islanding from a non-islanding operation. Our proposed method has nearly zero NDZ because we avoid a less sensitive threshold setting. Hence, without performance analysis of power system parameters selection of threshold is very difficult.
Assessment of passive indices presented above demonstrates that voltage phase angle (VPA) has the best capability in terms of performance and sensitivity among all other passive parameters. Therefore, VPA is employed in the islanding detection process. The flow chart of the proposed strategy is shown in Figure 4. The proposed method measures absolute VPA at every half cycle. The strategy is activated when Equation (1) is satisfied: where (VPA) measured is the measured absolute mean value and (VPA) threshold is the predefined threshold. For (VPA) threshold , phase magnitudes of VPA during islanding and non-islanding is measured at power mismatches. Then a comparison of phase magnitudes of islanding and non-islanding is made so that which event shows higher or lower magnitudes. For our study, islanding events magnitudes are lower than the non-islanding events. That's why Equation (1) has been developed. The threshold selection is based on the specifications of the power system and has been found using the hit and trial process. where (VPA)measured is the measured absolute mean value and (VPA)threshold is the predefined threshold. For (VPA)threshold, phase magnitudes of VPA during islanding and nonislanding is measured at power mismatches. Then a comparison of phase magnitudes of islanding and non-islanding is made so that which event shows higher or lower magnitudes. For our study, islanding events magnitudes are lower than the non-islanding events. That's why Equation (1) has been developed. The threshold selection is based on the specifications of the power system and has been found using the hit and trial process. Magnitudes/phase of the balanced or unbalanced three-phase signal is calculated with the help of sequence analyzer block in MATLAB/SIMULINK environment. The positive, negative and zero sequence components can be examined one by one or can be in combined formed at PCC (point of common coupling) and is expressed by Equation (2): where index V1, V2, V3 are the positive, negative and zero sequence components and Va, Vb, Vc are phase voltage signals. "a" denotes complex operator as in Equation (3). Analysis of harmonics is optional and can also be formed by providing "Harmonic n". A Fourier analysis is employed on a three-phase input signal for one cycle of the specific frequency that is based on a sliding window concept. At the specific fundamental or harmonic frequency, phase values Va, Vb, Vc are estimated. Then positive, negative and zero sequence components are obtained with help of transformation. The default parameter setting for the sequence analyzer block is tabulated in Table 3. Magnitudes/phase of the balanced or unbalanced three-phase signal is calculated with the help of sequence analyzer block in MATLAB/SIMULINK environment. The positive, negative and zero sequence components can be examined one by one or can be in combined formed at PCC (point of common coupling) and is expressed by Equation (2): where index V 1 , V 2 , V 3 are the positive, negative and zero sequence components and V a , V b , V c are phase voltage signals. "a" denotes complex operator as in Equation (3). Analysis of harmonics is optional and can also be formed by providing "Harmonic n". A Fourier analysis is employed on a three-phase input signal for one cycle of the specific frequency that is based on a sliding window concept. At the specific fundamental or harmonic frequency, phase values V a , V b , V c are estimated. Then positive, negative and zero sequence components are obtained with help of transformation. The default parameter setting for the sequence analyzer block is tabulated in Table 3. The parameters measured values in Figure 3 are representing the absolute mean values of selected indices for post islanding and non-islanding events. In our proposed scheme, 3-phase rms voltage is computed initially and then its mean and absolute measured values are determined respectively after that.
Assume a basic two-network three-phase system as shown in Figure 5. The phase to neutral voltages for a balanced three-phase system with phase sequence abc is given by Equations (4)-(6) respectively.
where V an , V bn , V cn represents the line to neutral voltages of three-phase voltage signal phases a, b and c. The Equations (4)-(6) represent just a basic phase angle relationship between phases. In a normal mode of operation, the voltage of each phase at PCC is balanced and 120 • apart from each other. However, the islanding mode of operation will cause the deviation from nominal value depending upon islanding and abnormal events. The phase magnitude of any phase is almost 0 • in normal conditions. The second and third will be at 120 • and 240 • phase apart. In our proposed method, whatever the value of the 3-phase signal during balanced, islanding or abnormal conditions, we have used the absolute mean value measured value for better analysis.  The parameters measured values in Figure 3 are representing the absolute mean values of selected indices for post islanding and non-islanding events. In our proposed scheme, 3-phase rms voltage is computed initially and then its mean and absolute measured values are determined respectively after that.
Assume a basic two-network three-phase system as shown in Figure 5. The phase to neutral voltages for a balanced three-phase system with phase sequence abc is given by Equations (4)-(6) respectively.
where Van, Vbn, Vcn represents the line to neutral voltages of three-phase voltage signal phases a, b and c. The Equations (4)-(6) represent just a basic phase angle relationship between phases. In a normal mode of operation, the voltage of each phase at PCC is balanced and 120° apart from each other. However, the islanding mode of operation will cause the deviation from nominal value depending upon islanding and abnormal events. The phase magnitude of any phase is almost 0° in normal conditions. The second and third will be at 120° and 240° phase apart. In our proposed method, whatever the value of the 3-phase signal during balanced, islanding or abnormal conditions, we have used the absolute mean value measured value for better analysis.

Results
The proposed strategy is evaluated by considering the IEEE 1547 system as shown in Figure 1. Islanding and abnormal cases are initiated at 5 s once the power system is stabi-

Results
The proposed strategy is evaluated by considering the IEEE 1547 system as shown in Figure 1. Islanding and abnormal cases are initiated at 5 s once the power system is stabilized. The threshold value for this study is set as 29.20 • (degree). The threshold is adjusted in such a way that magnitudes of non-islanding events become greater whereas magnitudes of islanding events become less than the threshold.

Islanding Detection at Small Power Mismatch
In a small power mismatch situation, a power mismatch of 0.001 MW and 0.001 MVar is considered between the load and DFIG. The response of this situation along with a trip signal is shown in Figure 6a,b. The (VPA) measured in this case is 29.16 • which is less than the threshold. Detection time in this process is 0.0928 s Hence, the protection strategy easily illustrates this case as an islanding operation.

Islanding Operation at Large Power Mismatch
In this scenario, the grid delivers active and reactive power of about 1.93 MW and 1.92 MVar respectively. (VPA)measured recorded for this situation is 13.17°, still less than the threshold. Islanding is detected in 0.0276 s for this event. The response of this case is shown in Figure 7a,b. Consequently, the protection strategy identifies this condition as islanding and sends a trip signal to the DFIG breaker.

Load Increment and Decrement
A parallel RLC load of 1.95 MW and 1.2 MVar is incremented and decremented to check the working of the proposed technique. (VPA)measured for increasing and decreasing load are 30.90° and 29.47° which becomes greater than the threshold. Thus, the detection technique easily discriminates this event as non-islanding. The behavior of this scenario is presented in Figure 8a,b.

Islanding Operation at Large Power Mismatch
In this scenario, the grid delivers active and reactive power of about 1.93 MW and 1.92 MVar respectively. (VPA) measured recorded for this situation is 13.17 • , still less than the threshold. Islanding is detected in 0.0276 s for this event. The response of this case is shown in Figure 7a,b. Consequently, the protection strategy identifies this condition as islanding and sends a trip signal to the DFIG breaker. threshold. Detection time in this process is 0.0928 s Hence, the protection strategy easily illustrates this case as an islanding operation.

Islanding Operation at Large Power Mismatch
In this scenario, the grid delivers active and reactive power of about 1.93 MW and 1.92 MVar respectively. (VPA)measured recorded for this situation is 13.17°, still less than the threshold. Islanding is detected in 0.0276 s for this event. The response of this case is shown in Figure 7a,b. Consequently, the protection strategy identifies this condition as islanding and sends a trip signal to the DFIG breaker.

Load Increment and Decrement
A parallel RLC load of 1.95 MW and 1.2 MVar is incremented and decremented to check the working of the proposed technique. (VPA)measured for increasing and decreasing load are 30.90° and 29.47° which becomes greater than the threshold. Thus, the detection technique easily discriminates this event as non-islanding. The behavior of this scenario is presented in Figure 8a,b.

Load Increment and Decrement
A parallel RLC load of 1.95 MW and 1.2 MVar is incremented and decremented to check the working of the proposed technique. (VPA) measured for increasing and decreasing load are 30.90 • and 29.47 • which becomes greater than the threshold. Thus, the detection technique easily discriminates this event as non-islanding. The behavior of this scenario is presented in Figure 8a,b.

Capacitor Energization and De-Energization
A capacitor bank of 2 MVar is connected and disconnected from the power system under study. The switching of this event is shown in Figure 9a,b. The (VPA)measured for connection and disconnection of the capacitor bank is 29.35° and 30.51° which are greater than the threshold. The proposed technique, therefore, defines these switching cases as non-islanding cases.

Motor Starting and Unloading
An induction motor with a bearing capacity of 400 hp is started and unloaded to check its impact on the protection method. The recorded value of (VPA)measured for starting and unloading are 29.97° and 30.83° which are greater than the threshold. Thus, the scheme precisely recognizes this event as an islanding condition. The scenario is shown in Figure 10a

Capacitor Energization and De-Energization
A capacitor bank of 2 MVar is connected and disconnected from the power system under study. The switching of this event is shown in Figure 9a,b. The (VPA) measured for connection and disconnection of the capacitor bank is 29.35 • and 30.51 • which are greater than the threshold. The proposed technique, therefore, defines these switching cases as non-islanding cases.

Capacitor Energization and De-Energization
A capacitor bank of 2 MVar is connected and disconnected from the power system under study. The switching of this event is shown in Figure 9a,b. The (VPA)measured for connection and disconnection of the capacitor bank is 29.35° and 30.51° which are greater than the threshold. The proposed technique, therefore, defines these switching cases as non-islanding cases.

Motor Starting and Unloading
An induction motor with a bearing capacity of 400 hp is started and unloaded to check its impact on the protection method. The recorded value of (VPA)measured for starting and unloading are 29.97° and 30.83° which are greater than the threshold. Thus, the scheme precisely recognizes this event as an islanding condition. The scenario is shown in Figure 10a,b.

Motor Starting and Unloading
An induction motor with a bearing capacity of 400 hp is started and unloaded to check its impact on the protection method. The recorded value of (VPA) measured for starting and unloading are 29.97 • and 30.83 • which are greater than the threshold. Thus, the scheme precisely recognizes this event as an islanding condition. The scenario is shown in Figure 10a

Fault Switching
Fault types such as three-phase to ground (ABCG), three phases (ABC), two phases to ground (ABG), single line to ground (AG) and double line (AB) are imposed on the power system to check the effectiveness of the method. A fault is initiated for a short duration of 0.04 s with a resistance of 50 Ω.

Assessment of NDZ and Comparison of Existing Islanding Detection Strategies
NDZ is the main criterion that reflects the effectiveness of the islanding recognizing method. It is an area where protection techniques are unable to recognize islanding conditions. For active power NDZ, is determined by [47]: where ΔP is the active power mismatch, V and I are the rated voltage and current respectively, ΔV is the voltage deviation and cos φ is the power factor. The allowable voltage variations in the distribution network under study are 0.9 pu and 1.1 pu. Considering these voltage levels, deviation ΔV is −0.1 and 1.1, respectively. The NDZ region of active power mismatch ΔP studied for this system is +0.20 MW and −0.20 MW.
For reactive power NDZ, is determined by [47]: where V is the rated voltage, fn in the nominal frequency, Δf is the frequency deviation and ωn = 2 × π × f. The allowable range for frequency variation Δf lies between −0.5 Hz to 0.5 Hz. Hence, NDZ of the study system with respect to reactive power mismatch is 0.2128 MW and

Assessment of NDZ and Comparison of Existing Islanding Detection Strategies
NDZ is the main criterion that reflects the effectiveness of the islanding recognizing method. It is an area where protection techniques are unable to recognize islanding conditions. For active power NDZ, is determined by [47]: where ∆P is the active power mismatch, V and I are the rated voltage and current respectively, ∆V is the voltage deviation and cos ϕ is the power factor. The allowable voltage variations in the distribution network under study are 0.9 pu and 1.1 pu. Considering these voltage levels, deviation ∆V is −0.1 and 1.1, respectively. The NDZ region of active power mismatch ∆P studied for this system is +0.20 MW and −0.20 MW.
For reactive power NDZ, is determined by [47]: where V is the rated voltage, fn in the nominal frequency, ∆f is the frequency deviation and ω n = 2 × π × f. The allowable range for frequency variation ∆f lies between −0.5 Hz to 0.5 Hz. Hence, NDZ of the study system with respect to reactive power mismatch is 0.2128 MW and −0.2192 MW. Simulation results also reveal that when power mismatch is 0.001 MW and 0.001 MVar, the proposed scheme working efficiently. Compared to convention techniques of OF/UF (over frequency/under frequency) and OV/UV (over voltage/under voltage), the proposed technique enhances the accuracy and insignificant the NDZ as shown in Figure 12. The analysis of passive indices presented in Section 2 reveals that voltage phase angle exhibits the best performance in terms of sensitivity and islanding detection time. Islanding operation only recognizes when the magnitude of voltage phase angle becomes less than the predefined threshold. Non-islanding events magnitudes remain greater than the threshold in comparison to islanding events. A brief overview of some existing islanding detection methods including the proposed strategies is compared based on detection time, non-detection zone, method type, power quality, algorithm complexity and concept used are presented in Table 4.  The analysis of passive indices presented in Section 2 reveals that voltage phase angle exhibits the best performance in terms of sensitivity and islanding detection time. Islanding operation only recognizes when the magnitude of voltage phase angle becomes less than the predefined threshold. Non-islanding events magnitudes remain greater than the threshold in comparison to islanding events. A brief overview of some existing islanding detection methods including the proposed strategies is compared based on detection time, non-detection zone, method type, power quality, algorithm complexity and concept used are presented in Table 4.

Conclusions
The installation of distributed generation units in the power system creates an islanding situation that is damaging to equipment and grid personnel. This paper presents a passive islanding detection technique employing voltage phase angle. The voltage phase angle is selected after the comprehensive performance evaluation of six different passive power indices. The algorithm initially measures the voltage at the point of common coupling then it computes the measured value of voltage phase angle. Then the measured value is compared with the threshold for a decision regarding the islanding or non-islanding event. The proposed algorithm easily discriminates the islanding operations at small and large power mismatches from non-islanding operations just like load increment and decrement, capacitor energization and de-energization, motor starting and unloading and various kinds of faults switching. The performance of the anticipated strategy is being authenticated and modeled on the IEEE-1547 generic tests system. The suggested strategy is simple and straightforward, negligible non-detection zone (NDZ) and has no power quality impacts, thus making it a better choice for real-time implementation. The proposed method can be applied to any other IEEE benchmark system or custom-made network.