Stability Augmentation of a Grid-Connected Wind Farm by Fuzzy-Logic-Controlled DFIG-Based Wind Turbines

Md. Rifat Hazari 1,* ID , Mohammad Abdul Mannan 2, S. M. Muyeen 3, Atsushi Umemura 1, Rion Takahashi 1 and Junji Tamura 1 1 Department of Electrical and Electronic Engineering, Kitami Institute of Technology (KIT), 165 Koen-cho, Kitami, Hokkaido 090-8507, Japan; umemura@mail.kitami-it.ac.jp (A.U.); rtaka@mail.kitami-it.ac.jp (R.T.); tamuraj@mail.kitami-it.ac.jp (J.T.) 2 Department of Electrical and Electronic Engineering, American International University-Bangladesh (AIUB), Ka-66/1, Kuratoli Road, Kuril, Khilkhet, Dhaka 1229, Bangladesh; mdmannan@aiub.edu 3 Department of Electrical and Computer Engineering, Curtin University, Perth, WA 6845, Australia; sm.muyeen@curtin.edu.au * Correspondence: rifat.hazari@gmail.com; Tel.: +81-157-26-9266


Introduction
Emerging environmental concerns and attempts to curtail the dependence on fossil fuel resources are bringing renewable energy resources into the mainstream of the electric power sector. Among the various renewable resources, wind power is the most promising from both technical and economic standpoints. The new global total for wind power at the end of 2015 was 432.9 GW, which represents a cumulative market growth of more than 17% [1]. By 2030, wind power could reach 2110 GW and

Wind Turbine Model
In the wind turbine model, the aerodynamic power output is given as follows [4]: where P w is the captured wind power, ρ is the air density (KG/m 3 ), R is the radius of the rotor blade (m), V w is the wind speed (m/s), and C p is the power coefficient.
The value of C p can be calculated as follows [10]: where T w is the wind turbine torque, β is the pitch angle, and λ is the tip speed ratio. Moreover, c 1 through c 6 are the characteristic coefficients of the wind turbine (c 1 = 0.5176, c 2 = 116, c 3 = 0.4, c 4 = 5, c 5 = 21, and c 6 = 0.0068) [24], and ω r is the rotational speed of the wind turbine (rad/s).
where Tw is the wind turbine torque, β is the pitch angle, and λ is the tip speed ratio. Moreover, c1 through c6 are the characteristic coefficients of the wind turbine (c1 = 0.5176, c2 = 116, c3 = 0.4, c4 = 5, c5 = 21, and c6 = 0.0068) [24], and ωr is the rotational speed of the wind turbine (rad/s). The Cp vs λ characteristics shown in Figure 1 are obtained using Equation (2) with different values of the pitch angle (β). When β is equal to zero degrees, the optimum power coefficient (Cpopt) is 0.48, and the optimum tip speed ratio (λopt) is 8.1.  Figures 2 and 3 show the models of the blade pitch control system for FSWT and VSWT [25], respectively. In FSWT, the pitch control system is used to control the power output of the SCIG so as not to exceed the rated power. In VSWT, the rotor speed of DFIG is regulate by the pitch controller so as not to exceed the rated speed. The control loop of the pitch actuator is represented by a firstorder transfer function with a pitch rate limiter. A PI controller is used to manage the tracking error.     [25], respectively. In FSWT, the pitch control system is used to control the power output of the SCIG so as not to exceed the rated power. In VSWT, the rotor speed of DFIG is regulate by the pitch controller so as not to exceed the rated speed. The control loop of the pitch actuator is represented by a first-order transfer function with a pitch rate limiter. A PI controller is used to manage the tracking error.
Appl. Sci. 2018, 8, 20 4 of 24 where Tw is the wind turbine torque, β is the pitch angle, and λ is the tip speed ratio. Moreover, c1 through c6 are the characteristic coefficients of the wind turbine (c1 = 0.5176, c2 = 116, c3 = 0.4, c4 = 5, c5 = 21, and c6 = 0.0068) [24], and ωr is the rotational speed of the wind turbine (rad/s). The Cp vs λ characteristics shown in Figure 1 are obtained using Equation (2) with different values of the pitch angle (β). When β is equal to zero degrees, the optimum power coefficient (Cpopt) is 0.48, and the optimum tip speed ratio (λopt) is 8.1.   [25], respectively. In FSWT, the pitch control system is used to control the power output of the SCIG so as not to exceed the rated power. In VSWT, the rotor speed of DFIG is regulate by the pitch controller so as not to exceed the rated speed. The control loop of the pitch actuator is represented by a firstorder transfer function with a pitch rate limiter. A PI controller is used to manage the tracking error.   where Tw is the wind turbine torque, β is the pitch angle, and λ is the tip speed ratio. Moreover, c1 through c6 are the characteristic coefficients of the wind turbine (c1 = 0.5176, c2 = 116, c3 = 0.4, c4 = 5, c5 = 21, and c6 = 0.0068) [24], and ωr is the rotational speed of the wind turbine (rad/s). The Cp vs λ characteristics shown in Figure 1 are obtained using Equation (2) with different values of the pitch angle (β). When β is equal to zero degrees, the optimum power coefficient (Cpopt) is 0.48, and the optimum tip speed ratio (λopt) is 8.1.   [25], respectively. In FSWT, the pitch control system is used to control the power output of the SCIG so as not to exceed the rated power. In VSWT, the rotor speed of DFIG is regulate by the pitch controller so as not to exceed the rated speed. The control loop of the pitch actuator is represented by a firstorder transfer function with a pitch rate limiter. A PI controller is used to manage the tracking error.

DFIG Model
The configuration of the VSWT-DFIG system, along with its control system, is shown in Figure 5. The model consists of a wind turbine model with aerodynamic characteristics, a pitch controller, a wound rotor induction generator (WRIG), and an AC/DC/AC converter based on two levels of insulated gate bipolar transistors (IGBTs), which are controlled by the rotor-side controller and the grid-side controller, respectively. The wind turbine drives the WRIG to convert wind power into electrical power. The rotational speed (ωr) is obtained from the rotor of the WRIG. A pitch controller is used to control the blade pitch angle of the wind turbine in order to reduce the output power when the rotational speed exceeds the rated speed. The WRIG model available in the PSCAD library is used in the present study [26]. The rotor position (θr) is derived from the rotor of the WRIG. As indicated by the configuration of the VSWT-DFIG system, the stator terminal is directly connected to the grid system. The AC/DC/AC converter is installed between the rotor of the WRIG and the grid system. The rating of the converter

DFIG Model
The configuration of the VSWT-DFIG system, along with its control system, is shown in Figure 5. The model consists of a wind turbine model with aerodynamic characteristics, a pitch controller, a wound rotor induction generator (WRIG), and an AC/DC/AC converter based on two levels of insulated gate bipolar transistors (IGBTs), which are controlled by the rotor-side controller and the grid-side controller, respectively.

DFIG Model
The configuration of the VSWT-DFIG system, along with its control system, is shown in Figure 5. The model consists of a wind turbine model with aerodynamic characteristics, a pitch controller, a wound rotor induction generator (WRIG), and an AC/DC/AC converter based on two levels of insulated gate bipolar transistors (IGBTs), which are controlled by the rotor-side controller and the grid-side controller, respectively. The wind turbine drives the WRIG to convert wind power into electrical power. The rotational speed (ωr) is obtained from the rotor of the WRIG. A pitch controller is used to control the blade pitch angle of the wind turbine in order to reduce the output power when the rotational speed exceeds the rated speed. The WRIG model available in the PSCAD library is used in the present study [26]. The rotor position (θr) is derived from the rotor of the WRIG. As indicated by the configuration of the VSWT-DFIG system, the stator terminal is directly connected to the grid system. The AC/DC/AC converter is installed between the rotor of the WRIG and the grid system. The rating of the converter   The wind turbine drives the WRIG to convert wind power into electrical power. The rotational speed (ω r ) is obtained from the rotor of the WRIG. A pitch controller is used to control the blade pitch angle of the wind turbine in order to reduce the output power when the rotational speed exceeds the rated speed. The WRIG model available in the PSCAD library is used in the present study [26]. The rotor position (θ r ) is derived from the rotor of the WRIG. As indicated by the configuration of the VSWT-DFIG system, the stator terminal is directly connected to the grid system. The AC/DC/AC converter is installed between the rotor of the WRIG and the grid system. The rating of the converter is 30% of the WRIG rating. The pulse width modulation (PWM) technique is used to generate the necessary gate pulses for driving the AC/DC/AC converter. The carrier frequency is taken as 3.0 kHz. The RSC is connected to the rotor winding of the WRIG, which provides variable frequency excitation depending on the wind-speed condition. The GSC is connected to the grid system through a transformer. A protection system with a DC chopper is installed in the DC-link circuit. The DC chopper is controlled by the comparator block, which triggers the DC chopper switch when the DC-link voltage becomes greater than or equal to the predefined limit (V dc ≥ 1.15 pu).

Conventional Rotor-Side Controller
The conventional cascaded controller for the RSC is presented in [23]. This controller consists of four conventional PI controllers to compensate different error signals. The reference reactive power (Q dfig *) is set to zero for unity power factor operation. The active power and reactive power delivered to the grid are controlled using q-axis and d-axis rotor currents, respectively.

Proposed Rotor-Side Controller
The proposed controller for the RSC is depicted in Figure 6. This controller consists of three PI controllers and one FLC. The main motivation behind using one FLC in the inner loop of the cascaded controller is maximization of the reactive power injection. The FLC offers variable gain depending on the system parameters. Due to the variable gain, the FLC can inject reactive power (Q dfig ) more effectively in the fault condition. Thus, the grid voltage can quickly be retraced back to the nominal value. Moreover, the FLC can stabilize a higher rating of the SCIG as compared to the conventional PI-based controller of the RSC in the inner loop.
Appl. Sci. 2018, 8, 20 6 of 24 is 30% of the WRIG rating. The pulse width modulation (PWM) technique is used to generate the necessary gate pulses for driving the AC/DC/AC converter. The carrier frequency is taken as 3.0 kHz. The RSC is connected to the rotor winding of the WRIG, which provides variable frequency excitation depending on the wind-speed condition. The GSC is connected to the grid system through a transformer. A protection system with a DC chopper is installed in the DC-link circuit. The DC chopper is controlled by the comparator block, which triggers the DC chopper switch when the DClink voltage becomes greater than or equal to the predefined limit (Vdc ≥ 1.15 pu).

Conventional Rotor-Side Controller
The conventional cascaded controller for the RSC is presented in [23]. This controller consists of four conventional PI controllers to compensate different error signals. The reference reactive power (Qdfig*) is set to zero for unity power factor operation. The active power and reactive power delivered to the grid are controlled using q-axis and d-axis rotor currents, respectively.

Proposed Rotor-Side Controller
The proposed controller for the RSC is depicted in Figure 6. This controller consists of three PI controllers and one FLC. The main motivation behind using one FLC in the inner loop of the cascaded controller is maximization of the reactive power injection. The FLC offers variable gain depending on the system parameters. Due to the variable gain, the FLC can inject reactive power (Qdfig) more effectively in the fault condition. Thus, the grid voltage can quickly be retraced back to the nominal value. Moreover, the FLC can stabilize a higher rating of the SCIG as compared to the conventional PI-based controller of the RSC in the inner loop. The active power (P dfig ) and reactive power (Q dfig ) outputs of the DFIG are controlled by regulating the rotor winding current. The reference active power (P ref ) is calculated by subtracting the losses (P loss ) from the MPPT output (P mppt ). In the upper loop portion, the grid voltage (V g ) is taken as feedback to regulate the terminal voltage constant at 1.0 pu. The q-axis current (I rq ) controls the active power delivered to the grid, and the d-axis current (I rd ) controls the reactive power delivered to the grid.
In the normal operating condition (V g > 0.9 pu), the RSC regulates the active power delivered to the grid. During a fault condition (V g < 0.9 pu), a comparator sends a signal so that active power transfer to the grid becomes zero. By controlling the power in this manner, the reactive power injected to the grid can be maximized.
The detailed design procedure of the FLC will be discussed in Section 4.

Grid-Side Controller
The controller for the GSC is depicted in Figure 7. This controller consists of four PI controllers to compensate different error signals. The GSC reactive power (Q g ) and DC-link voltage (V dc ) are controlled through d-axis (I gd ) and q-axis (I gq ) current components, respectively. The reactive power reference is set to zero, and the DC-link voltage reference is set to 1.0 pu (1.2 kV). In the normal operating condition (Vg > 0.9 pu), the RSC regulates the active power delivered to the grid. During a fault condition (Vg < 0.9 pu), a comparator sends a signal so that active power transfer to the grid becomes zero. By controlling the power in this manner, the reactive power injected to the grid can be maximized.
The detailed design procedure of the FLC will be discussed in Section 4.

Grid-Side Controller
The controller for the GSC is depicted in Figure 7. This controller consists of four PI controllers to compensate different error signals. The GSC reactive power (Qg) and DC-link voltage (Vdc) are controlled through d-axis (Igd) and q-axis (Igq) current components, respectively. The reactive power reference is set to zero, and the DC-link voltage reference is set to 1.0 pu (1.2 kV).  Figure 8 shows a block diagram of the proposed FLC. The FLC is composed of fuzzification, a membership function, a rule base, a fuzzy inference, and defuzzification, as shown in Figure 9.   Figure 8 shows a block diagram of the proposed FLC. The FLC is composed of fuzzification, a membership function, a rule base, a fuzzy inference, and defuzzification, as shown in Figure 9. In the normal operating condition (Vg > 0.9 pu), the RSC regulates the active power delivered to the grid. During a fault condition (Vg < 0.9 pu), a comparator sends a signal so that active power transfer to the grid becomes zero. By controlling the power in this manner, the reactive power injected to the grid can be maximized.

Fuzzy Logic Controller Design
The detailed design procedure of the FLC will be discussed in Section 4.

Grid-Side Controller
The controller for the GSC is depicted in Figure 7. This controller consists of four PI controllers to compensate different error signals. The GSC reactive power (Qg) and DC-link voltage (Vdc) are controlled through d-axis (Igd) and q-axis (Igq) current components, respectively. The reactive power reference is set to zero, and the DC-link voltage reference is set to 1.0 pu (1.2 kV).  Figure 8 shows a block diagram of the proposed FLC. The FLC is composed of fuzzification, a membership function, a rule base, a fuzzy inference, and defuzzification, as shown in Figure 9.    In the normal operating condition (Vg > 0.9 pu), the RSC regulates the active power delivered to the grid. During a fault condition (Vg < 0.9 pu), a comparator sends a signal so that active power transfer to the grid becomes zero. By controlling the power in this manner, the reactive power injected to the grid can be maximized.

Fuzzy Logic Controller Design
The detailed design procedure of the FLC will be discussed in Section 4.

Grid-Side Controller
The controller for the GSC is depicted in Figure 7. This controller consists of four PI controllers to compensate different error signals. The GSC reactive power (Qg) and DC-link voltage (Vdc) are controlled through d-axis (Igd) and q-axis (Igq) current components, respectively. The reactive power reference is set to zero, and the DC-link voltage reference is set to 1.0 pu (1.2 kV).  Figure 8 shows a block diagram of the proposed FLC. The FLC is composed of fuzzification, a membership function, a rule base, a fuzzy inference, and defuzzification, as shown in Figure 9.  In order to design the proposed FLC, the error of the rotor d-axis current (eI rd ) and rate of change of the eI rd (d[eI rd ]/dt) are considered as the controller inputs. The reference rotor d-axis voltage (V rd *) is chosen as the controller output. In Figure 8, 1/z is one sampling time delay.

Fuzzy Logic Controller Design
The triangular membership functions with overlap used for the input and output fuzzy sets are shown in Figure  In order to design the proposed FLC, the error of the rotor d-axis current (eIrd) and rate of change of the eIrd (d[eIrd]/dt) are considered as the controller inputs. The reference rotor d-axis voltage (Vrd*) is chosen as the controller output. In Figure 8, 1/z is one sampling time delay.
The triangular membership functions with overlap used for the input and output fuzzy sets are shown in Figure  The rules of fuzzy mapping of the input variables to the output are given in the following form:

IF <eIrd is PB> and <d(eIrd)/dt is NS> THEN <Vrd* is PS> IF <eIrd is NM> and <d(eIrd)/dt is NS> THEN <Vrd* is NB>
The entire rule base is listed in Table 1, which includes a total of 49 rules. In the present study, Mamdani's max-min method is used as the inference mechanism [27]. The center of gravity method is used for defuzzification in order to obtain Vrd* [28].

Power System Model
The power system model used for transient stability analysis is shown in Figure 11. The model is composed of a nine-bus main system [29] and a WF. The main system is composed of three conventional power plants: two thermal power plants (SG1 and SG2) and one hydropower plant (SG3). Both SG1 and SG3 are operated under automatic generation control (AGC), and SG2 is operated under governor-free (GF) control. The parameters of the SGs are listed in Table 2. The IEEE type AC4A excitation system model shown in Figure 12 is considered for all SGs [30]. Table 3 lists the parameters taken from [30]. Figure 13 shows a block diagram of the reheat steam turbine governor system used in the thermal power plants (SG1 and SG2) [30]. The hydro turbine governor model system used for the hydropower plant (SG3) is shown in Figure 14 [30]. The parameters of both turbine systems are presented in Table 4 [30]. For AGC operation, an integral controller is installed on the governor system for both SG1 and SG3. The rules of fuzzy mapping of the input variables to the output are given in the following form: IF <eI rd is PB> and <d(eIrd)/dt is NS> THEN <V rd * is PS> IF <eI rd is NM> and <d(eIrd)/dt is NS> THEN <V rd * is NB> The entire rule base is listed in Table 1, which includes a total of 49 rules. In the present study, Mamdani's max-min method is used as the inference mechanism [27]. The center of gravity method is used for defuzzification in order to obtain V rd * [28].

Power System Model
The power system model used for transient stability analysis is shown in Figure 11. The model is composed of a nine-bus main system [29] and a WF. The main system is composed of three conventional power plants: two thermal power plants (SG1 and SG2) and one hydropower plant (SG3). Both SG1 and SG3 are operated under automatic generation control (AGC), and SG2 is operated under governor-free (GF) control. The parameters of the SGs are listed in Table 2. The IEEE type AC4A excitation system model shown in Figure 12 is considered for all SGs [30]. Table 3 lists the parameters taken from [30]. Figure 13 shows a block diagram of the reheat steam turbine governor system used in the thermal power plants (SG1 and SG2) [30]. The hydro turbine governor model system used for the hydropower plant (SG3) is shown in Figure 14 [30]. The parameters of both turbine systems are presented in Table 4 [30]. For AGC operation, an integral controller is installed on the governor system for both SG1 and SG3.            Table 3. Typical values of IEEE type AC4A excitation system.

Parameter Value
The integral controller on selected units for AGC is shown in Figure 15 [30]. The output of the AGC supplies the power load reference of the governor system depending on the speed deviation of the SG (∆ω sg ). The integral gain K i is set to 6.   The integral controller on selected units for AGC is shown in Figure 15 [30]. The output of the AGC supplies the power load reference of the governor system depending on the speed deviation of the SG (Δωsg). The integral gain Ki is set to 6. A WF is connected to the main system at bus 5, as shown in Figure 11, and consists of one VSWT-DFIG and one FSWT-SCIG. In order to reduce computational time, each wind generator is represented as an aggregated equivalent single machine [31,32]. The total capacity of the WF is 100 MW. A capacitor bank (C) is used for reactive power compensation of the SCIG. The value of C is chosen such that the power factor of the SCIG-based wind generator becomes unity at the rated operating condition. The base power of the system is 100 MVA, and the rated frequency is 50 Hz. The parameters of the DFIG and the SCIG are presented in Table 5. A WF is connected to the main system at bus 5, as shown in Figure 11, and consists of one VSWT-DFIG and one FSWT-SCIG. In order to reduce computational time, each wind generator is represented as an aggregated equivalent single machine [31,32]. The total capacity of the WF is 100 MW. A capacitor bank (C) is used for reactive power compensation of the SCIG. The value of C is chosen such that the power factor of the SCIG-based wind generator becomes unity at the rated operating condition. The base power of the system is 100 MVA, and the rated frequency is 50 Hz. The parameters of the DFIG and the SCIG are presented in Table 5.

LVRT Requirement for Wind Power
The requirement of LVRT for wind power is depicted in Figure 16 [33]. The WF must remain connected to the grid if the voltage drop is within the defined r.m.s. value and its duration is also within the defined period, as shown in the figure. If the voltage of the connection point recovers to 90% of the rated voltage within 1.5 s following the voltage drop, all wind turbines within the WF shall stay online without tripping.

LVRT Requirement for Wind Power
The requirement of LVRT for wind power is depicted in Figure 16 [33]. The WF must remain connected to the grid if the voltage drop is within the defined r.m.s. value and its duration is also within the defined period, as shown in the figure. If the voltage of the connection point recovers to 90% of the rated voltage within 1.5 s following the voltage drop, all wind turbines within the WF shall stay online without tripping.

Transient Stability Analysis
Simulation analysis is performed on the model system shown in Figure 11 using PSCAD/EMTDC software. The FORTRAN language is incorporated into PSCAD/EMTDC in order to implement FLC as new component. The simulation time is chosen as 10 s. The triple-line-to-ground (3LG) fault near bus 11 is considered to be a network disturbance, as shown in Figure 11

Transient Stability Analysis
Simulation analysis is performed on the model system shown in Figure 11 using PSCAD/EMTDC software. The FORTRAN language is incorporated into PSCAD/EMTDC in order to implement FLC as new component. The simulation time is chosen as 10 s. The triple-line-to-ground (3LG) fault near bus 11 is considered to be a network disturbance, as shown in Figure 11. The fault occurs at 0.1 s. The duration of the fault is 0.1 s. The circuit breakers (CBs) on the faulted line are opened at 0.2 s in order to isolate the faulty line from the power system. The CBs are reclosed at 1.0 s based on the consideration that the fault has been cleared. The wind speed data applied to each wind turbine is maintained constant at the rated speed based on the assumption that the wind speed does not change dramatically within this small period of time. Simulation analyses are carried out for both the proposed and conventional rotor-side controllers reported in [23] in order to demonstrate the effectiveness of the proposed control system. The simulation results are presented and discussed in the following subsections. 7.1.1. Analysis Using the Conventional Rotor-Side Controller Two cases are considered using the conventional rotor-side controller. The parameters for conventional PI controllers are chosen based on the method presented in the literature [23]. The power rating of each wind generator in Case 01 is DFIG = 59 MW and SCIG = 41 MW (total: 100 MW), and, in Case 02, DFIG = 58 MW and SCIG = 42 MW (total: 100 MW). Different power ratings of the wind generators are chosen, because the objective is to stabilize the maximum possible rating of SCIG by using lowest possible rating of DFIG, while the total capacity of WF is kept constant at 100 MW. In this present study, it is calculated by running the simulation for multiple times with different combinations of power ratings of the wind generators. Figure 17a,b show the responses of reactive powers, which indicates that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage recovers to the rated value quickly in Case 01, as shown in Figure 18a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition. Thus, the connection point voltage cannot recover to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 19.
Appl. Sci. 2018, 8, 20 12 of 24 the proposed and conventional rotor-side controllers reported in [23] in order to demonstrate the effectiveness of the proposed control system. The simulation results are presented and discussed in the following subsections.
7.1.1. Analysis Using the Conventional Rotor-Side Controller Two cases are considered using the conventional rotor-side controller. The parameters for conventional PI controllers are chosen based on the method presented in the literature [23]. The power rating of each wind generator in Case 01 is DFIG = 59 MW and SCIG = 41 MW (total: 100 MW), and, in Case 02, DFIG = 58 MW and SCIG = 42 MW (total: 100 MW). Different power ratings of the wind generators are chosen, because the objective is to stabilize the maximum possible rating of SCIG by using lowest possible rating of DFIG, while the total capacity of WF is kept constant at 100 MW. In this present study, it is calculated by running the simulation for multiple times with different combinations of power ratings of the wind generators. Figure 17a,b show the responses of reactive powers, which indicates that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage recovers to the rated value quickly in Case 01, as shown in Figure 18a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition. Thus, the connection point voltage cannot recover to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 19.    the proposed and conventional rotor-side controllers reported in [23] in order to demonstrate the effectiveness of the proposed control system. The simulation results are presented and discussed in the following subsections.
7.1.1. Analysis Using the Conventional Rotor-Side Controller Two cases are considered using the conventional rotor-side controller. The parameters for conventional PI controllers are chosen based on the method presented in the literature [23]. The power rating of each wind generator in Case 01 is DFIG = 59 MW and SCIG = 41 MW (total: 100 MW), and, in Case 02, DFIG = 58 MW and SCIG = 42 MW (total: 100 MW). Different power ratings of the wind generators are chosen, because the objective is to stabilize the maximum possible rating of SCIG by using lowest possible rating of DFIG, while the total capacity of WF is kept constant at 100 MW. In this present study, it is calculated by running the simulation for multiple times with different combinations of power ratings of the wind generators. Figure 17a,b show the responses of reactive powers, which indicates that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage recovers to the rated value quickly in Case 01, as shown in Figure 18a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition. Thus, the connection point voltage cannot recover to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 19.      Figure 22a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 23, where the system frequency collapses in Case 02 after the WF has been disconnected.      Figure 22a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 23, where the system frequency collapses in Case 02 after the WF has been disconnected.     Figure 22a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 23, where the system frequency collapses in Case 02 after the WF has been disconnected.    Figure 22a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 23, where the system frequency collapses in Case 02 after the WF has been disconnected.
Therefore, the lowest power rating of the DFIG with the conventional rotor-side controller is 59 MW in order to stabilize the 41 MW SCIG. The DFIG can also stabilize the SGs.  Therefore, the lowest power rating of the DFIG with the conventional rotor-side controller is 59 MW in order to stabilize the 41 MW SCIG. The DFIG can also stabilize the SGs.

Analysis Using the Proposed Rotor-Side Controller
Two cases are considered using the proposed rotor-side controller shown in Figure 6. The power rating of each wind generator in Case 01 is DFIG = 28 MW and SCIG = 72 MW (total: 100 MW), and, in Case 02, DFIG = 27 MW and SCIG = 73 MW (total: 100 MW). Figure 24a,b show the responses of reactive powers, which indicate that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage quickly recovers to the rated value in Case 01, as shown in Figure 25a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition, and thus, the connection point voltage cannot be back to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 26.    Therefore, the lowest power rating of the DFIG with the conventional rotor-side controller is 59 MW in order to stabilize the 41 MW SCIG. The DFIG can also stabilize the SGs.

Analysis Using the Proposed Rotor-Side Controller
Two cases are considered using the proposed rotor-side controller shown in Figure 6. The power rating of each wind generator in Case 01 is DFIG = 28 MW and SCIG = 72 MW (total: 100 MW), and, in Case 02, DFIG = 27 MW and SCIG = 73 MW (total: 100 MW). Figure 24a,b show the responses of reactive powers, which indicate that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage quickly recovers to the rated value in Case 01, as shown in Figure 25a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition, and thus, the connection point voltage cannot be back to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 26.    Figure 24a,b show the responses of reactive powers, which indicate that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage quickly recovers to the rated value in Case 01, as shown in Figure 25a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition, and thus, the connection point voltage cannot be back to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 26.  Therefore, the lowest power rating of the DFIG with the conventional rotor-side controller is 59 MW in order to stabilize the 41 MW SCIG. The DFIG can also stabilize the SGs.

Analysis Using the Proposed Rotor-Side Controller
Two cases are considered using the proposed rotor-side controller shown in Figure 6. The power rating of each wind generator in Case 01 is DFIG = 28 MW and SCIG = 72 MW (total: 100 MW), and, in Case 02, DFIG = 27 MW and SCIG = 73 MW (total: 100 MW). Figure 24a,b show the responses of reactive powers, which indicate that the DFIG can provide the necessary reactive power during the severe symmetrical 3LG fault in Case 01. As a result, the connection point voltage quickly recovers to the rated value in Case 01, as shown in Figure 25a. However, in Case 02, the DFIG does not provide the necessary reactive power during the fault condition, and thus, the connection point voltage cannot be back to the rated value. Since the connection point voltage does not satisfy the standard grid code of Figure 16 in Case 02, the WF is disconnected from the power system by opening CBs near bus 12 at 2 s. The rotor speed responses of both wind generators are stable in Case 01, but unstable in Case 02, as shown in Figure 26.  Figure 27 shows the active power output of DFIG and SCIG, respectively. The active power can recover to the nominal value in Case 01 for both wind generators, but failed to recover to the nominal value in Case 02. Moreover, the DC-link voltage of the DFIG becomes more stable in Case 01, as compared to Case 02, as shown in Figure 28a. Figure 29a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 30, where the system frequency collapses in Case 02 after the WF has been disconnected.     Figure 27 shows the active power output of DFIG and SCIG, respectively. The active power can recover to the nominal value in Case 01 for both wind generators, but failed to recover to the nominal value in Case 02. Moreover, the DC-link voltage of the DFIG becomes more stable in Case 01, as compared to Case 02, as shown in Figure 28a. Figure 29a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 30, where the system frequency collapses in Case 02 after the WF has been disconnected.     Figure 27 shows the active power output of DFIG and SCIG, respectively. The active power can recover to the nominal value in Case 01 for both wind generators, but failed to recover to the nominal value in Case 02. Moreover, the DC-link voltage of the DFIG becomes more stable in Case 01, as compared to Case 02, as shown in Figure 28a. Figure 29a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 30, where the system frequency collapses in Case 02 after the WF has been disconnected.  Figure 27 shows the active power output of DFIG and SCIG, respectively. The active power can recover to the nominal value in Case 01 for both wind generators, but failed to recover to the nominal value in Case 02. Moreover, the DC-link voltage of the DFIG becomes more stable in Case 01, as compared to Case 02, as shown in Figure 28a. Figure 29a,b show the active power output and rotor speed responses, respectively, of the conventional power plants (SGs). The active power and rotational speed of the SGs can return to the initial condition in Case 01. However, the active power of the SGs in Case 02 increases significantly after the WF has been disconnected, resulting in a rotor speed drop of the SGs. It is clear that the system becomes unstable in Case 02, which can also be seen from Figure 30, where the system frequency collapses in Case 02 after the WF has been disconnected.      Therefore, the lowest power rating of the DFIG with the proposed rotor-side controller is 28 MW in order to stabilize the 72 MW SCIG. The DFIG can also stabilize the SGs. Finally, the reactive power output of DFIG (capacity is 28 MW) for both proposed and conventional rotor-side controllers is depicted in Figure 31. The reactive power output for the proposed FLC-controlled DFIG is larger and more efficient than the conventional PI-controlled DFIG.    Therefore, the lowest power rating of the DFIG with the proposed rotor-side controller is 28 MW in order to stabilize the 72 MW SCIG. The DFIG can also stabilize the SGs. Finally, the reactive power output of DFIG (capacity is 28 MW) for both proposed and conventional rotor-side controllers is depicted in Figure 31. The reactive power output for the proposed FLC-controlled DFIG is larger and more efficient than the conventional PI-controlled DFIG.   Therefore, the lowest power rating of the DFIG with the proposed rotor-side controller is 28 MW in order to stabilize the 72 MW SCIG. The DFIG can also stabilize the SGs. Finally, the reactive power output of DFIG (capacity is 28 MW) for both proposed and conventional rotor-side controllers is depicted in Figure 31. The reactive power output for the proposed FLC-controlled DFIG is larger and more efficient than the conventional PI-controlled DFIG.  Therefore, the lowest power rating of the DFIG with the proposed rotor-side controller is 28 MW in order to stabilize the 72 MW SCIG. The DFIG can also stabilize the SGs. Finally, the reactive power output of DFIG (capacity is 28 MW) for both proposed and conventional rotor-side controllers is depicted in Figure 31. The reactive power output for the proposed FLC-controlled DFIG is larger and more efficient than the conventional PI-controlled DFIG.

Dynamic Performance Analysis Using the Proposed Rotor-Side Controller
In order to evaluate the dynamic performance of the proposed system, the real wind speed data measured at Rishiri Island, Hokkaido, Japan, shown in Figure 32, is used in the simulation. The power system model shown in Figure 11 is considered in this dynamic analysis. The capacities of the DFIG and the SCIG are 28 MW and 72 MW (The total capacity of the WF is 100 MW), respectively. Because this power ratings of the wind generators are stable case for the proposed system as presented in Section 7.1.2.   Figure 37 shows the responses of the blade pitch angle. The increase in the blade pitch angle will help to reduce the mechanical power extraction from the wind turbines. The total active and reactive power output of the wind generators at bus 12 is shown in Figure 38.

Dynamic Performance Analysis Using the Proposed Rotor-Side Controller
In order to evaluate the dynamic performance of the proposed system, the real wind speed data measured at Rishiri Island, Hokkaido, Japan, shown in Figure 32, is used in the simulation. The power system model shown in Figure 11 is considered in this dynamic analysis. The capacities of the DFIG and the SCIG are 28 MW and 72 MW (The total capacity of the WF is 100 MW), respectively. Because this power ratings of the wind generators are stable case for the proposed system as presented in Section 7.1.2.

Dynamic Performance Analysis Using the Proposed Rotor-Side Controller
In order to evaluate the dynamic performance of the proposed system, the real wind speed data measured at Rishiri Island, Hokkaido, Japan, shown in Figure 32, is used in the simulation. The power system model shown in Figure 11 is considered in this dynamic analysis. The capacities of the DFIG and the SCIG are 28 MW and 72 MW (The total capacity of the WF is 100 MW), respectively. Because this power ratings of the wind generators are stable case for the proposed system as presented in Section 7.1.2.  Figure 33 shows the reactive power output of wind generators. The DFIG provides the necessary reactive power to the SCIG for voltage regulation. Thus, the connection point voltage at bus 12 is approximately constant, as shown in Figure 34. Figure 35 shows the active power outputs of the VSWT-DFIG and the FSWT-SCIG. The DC-link voltage of the DFIG is maintained constant, as shown in Figure 36. The variation of the DC-link voltage is very small, even though there are wide fluctuations in the wind speed. Figure 37 shows the responses of the blade pitch angle. The increase in the blade pitch angle will help to reduce the mechanical power extraction from the wind turbines. The total active and reactive power output of the wind generators at bus 12 is shown in Figure 38.  Figure 33 shows the reactive power output of wind generators. The DFIG provides the necessary reactive power to the SCIG for voltage regulation. Thus, the connection point voltage at bus 12 is approximately constant, as shown in Figure 34. Figure 35 shows the active power outputs of the VSWT-DFIG and the FSWT-SCIG. The DC-link voltage of the DFIG is maintained constant, as shown in Figure 36. The variation of the DC-link voltage is very small, even though there are wide fluctuations in the wind speed. Figure 37 shows the responses of the blade pitch angle. The increase in the blade pitch angle will help to reduce the mechanical power extraction from the wind turbines. The total active and reactive power output of the wind generators at bus 12 is shown in Figure 38.          The active power output of conventional power plants (SGs) and the power system frequency response are shown in Figures 39 and 40. The conventional SGs adjust their active power output according to the fluctuating power injected from the WF. Moreover, the frequency variation lies within the permissible limit in Japan (±0.2 Hz).   The active power output of conventional power plants (SGs) and the power system frequency response are shown in Figures 39 and 40. The conventional SGs adjust their active power output according to the fluctuating power injected from the WF. Moreover, the frequency variation lies within the permissible limit in Japan (±0.2 Hz).   The active power output of conventional power plants (SGs) and the power system frequency response are shown in Figures 39 and 40. The conventional SGs adjust their active power output according to the fluctuating power injected from the WF. Moreover, the frequency variation lies within the permissible limit in Japan (±0.2 Hz).  The active power output of conventional power plants (SGs) and the power system frequency response are shown in Figures 39 and 40. The conventional SGs adjust their active power output according to the fluctuating power injected from the WF. Moreover, the frequency variation lies within the permissible limit in Japan (±0.2 Hz).

Discussion
The transient simulation analyses in Sections 7.1.1 and 7.1.2 reveal that the necessary power rating of the DFIG to stabilize the SCIG in the WF, as well as to prevent conventional SGs from becoming out of step during a 3LG fault, is much lower in the case of the proposed rotor-side controller than in the case of the conventional rotor-side controller, where the total capacity of the DFIG and the SCIG is 100 MW. Table 6 summarizes the results, which reveal that, for stable operation of the WF and SGs, the lowest power rating of the DFIG is 28 MW for the proposed method and 59 MW for the conventional method. The dynamic simulation analysis confirmed that the proposed FLC-controlled DFIG can effectively inject reactive power and thus maintain the terminal voltage constant under a randomly varying wind speed.

Conclusions
In order to enhance the LVRT performance of the SCIG-based WF, partial installation of the DFIG with the new rotor-side controller based on the FLC is proposed in the present study. Moreover,

Discussion
The transient simulation analyses in Sections 7.1.1 and 7.1.2 reveal that the necessary power rating of the DFIG to stabilize the SCIG in the WF, as well as to prevent conventional SGs from becoming out of step during a 3LG fault, is much lower in the case of the proposed rotor-side controller than in the case of the conventional rotor-side controller, where the total capacity of the DFIG and the SCIG is 100 MW. Table 6 summarizes the results, which reveal that, for stable operation of the WF and SGs, the lowest power rating of the DFIG is 28 MW for the proposed method and 59 MW for the conventional method. The dynamic simulation analysis confirmed that the proposed FLC-controlled DFIG can effectively inject reactive power and thus maintain the terminal voltage constant under a randomly varying wind speed.

Conclusions
In order to enhance the LVRT performance of the SCIG-based WF, partial installation of the DFIG with the new rotor-side controller based on the FLC is proposed in the present study. Moreover,

Discussion
The transient simulation analyses in Sections 7.1.1 and 7.1.2 reveal that the necessary power rating of the DFIG to stabilize the SCIG in the WF, as well as to prevent conventional SGs from becoming out of step during a 3LG fault, is much lower in the case of the proposed rotor-side controller than in the case of the conventional rotor-side controller, where the total capacity of the DFIG and the SCIG is 100 MW. Table 6 summarizes the results, which reveal that, for stable operation of the WF and SGs, the lowest power rating of the DFIG is 28 MW for the proposed method and 59 MW for the conventional method. The dynamic simulation analysis confirmed that the proposed FLC-controlled DFIG can effectively inject reactive power and thus maintain the terminal voltage constant under a randomly varying wind speed.

Conclusions
In order to enhance the LVRT performance of the SCIG-based WF, partial installation of the DFIG with the new rotor-side controller based on the FLC is proposed in the present study. Moreover, a comparative study of the proposed and conventional rotor-side controllers is carried out. Based on the simulation results and performance analyses, the following points are of notable significance regarding the proposed method: 1.
The proposed FLC-controlled DFIG of a lower power rating can stabilize the larger power rating of SCIG as well as conventional SGs during fault conditions. 2.
The installation cost can be decreased by incorporating a small number of VSWT-DFIGs with the proposed controller and a large number of FSWT-SCIGs into a WF. 3.
The proposed FLC controlled DFIG system can maintain its terminal voltage at constant under normal operating conditions by effectively injecting reactive power into the grid.
Therefore, if the proposed DFIG with a relatively small power rating is installed at a WF composed mainly of SCIGs, its LVRT capability, as well as the stability of a connected power system, can be enhanced.