A Study on Frequency Stability and Primary Frequency Response of the Korean Electric Power System Considering the High Penetration of Wind Power ^†

Abstract

The high penetration of wind power decreases the system inertia and primary frequency reserve while replacing the conventional synchronous generators (SGs). Therefore, if the system operator does not take appropriate action on the remaining generation units (GUs) operation, high penetration of wind power will aggravate the frequency stability. To solve this problem, wind power plants (WPPs) may provide the inertial response and primary frequency response (PFR) to support the frequency stability. However, due to the variability of renewable energy, WPPs may not provide adequate frequency response whenever it is required. This paper proposes an algorithm to determine the operation of GUs to provide appropriate PFR for a power system with high penetration of wind power. Through the proposed algorithm, it calculates the required PFR to restore the decreased frequency stability caused by the high penetration of wind power. Then, while considering the available PFR from WPPs, it redetermines the droop coefficient of SGs governor to provide the sufficient PFR to recover the frequency stability. Finally, the effectiveness of the proposed algorithm is verified on the practical Korean electric power system.

1. Introduction

Following the global trend of increasing the hosting capacity of the wind power plants (WPPs) to solve environmental and economic issues, the government of Korea is planning to increase the capacity of WPPs to 17.7 GW by 2030 [1,2]. However, various stability problems are being reported due to the uncertainty and variability of renewable energy generation [3]. In particular, the high penetration of wind power decreases the system inertia and the amount of primary frequency reserve, adversely impacting frequency stability. Moreover, when analyzing the frequency stability, frequency nadir (f_nadir) and settling frequency (f_set) are considered for the dynamic and steady state, respectively [4,5,6]. In order to maintain the frequency stability in the Korean electric power system, these two indices need to be above 59 Hz and 59.8 Hz to prevent under-frequency load shedding relay and activate automatic generation control (AGC), respectively. Therefore, the operation of generation units (Gus), including both conventional synchronous generators (SGs) and newly installed distributed generators (DGs), must be appropriately determined to maintain frequency stability [7].

In a steady-state condition, WPPs are normally operated by the maximum power point tracking (MPPT) control method [8]. However, WPPs operating in this method do not provide any frequency responses when a large disturbance such as a generation trip occurs. Therefore, as WPPs replace conventional SGs, which provide an inertial response (IR) and primary frequency response (PFR), frequency stability is severely impacted [9,10]. To solve this problem, many studies have developed effective control methods to provide ancillary services and support power system stability [11,12,13,14]. In particular, inertial control methods are developed for WPPs to provide IR by the stored kinetic energy in the rotating masses supporting the dynamic frequency stability [15,16,17,18]. On the other hand, power reserve control methods are developed for WPPs to provide PFR, supporting both dynamic and steady-state frequency stabilities [19,20,21,22]. However, unlike IR, PFR is provided by WPPs that are curtailed in a steady state. In other words, the available PFR from WPPs depends on the amount of curtailed power, which is determined based on system conditions such as load demand and wind speed, etc. Therefore, WPPs may not be able to provide the proper PFR whenever it is required.

To solve these problems, studies have improved WPPs operation by using energy storage systems (ESSs). These system elements provide ancillary services to enhance the power quality and the power system stability [23,24,25]. The operation of ESS is composed of charging and discharging features. The charged ESS provides additional power when disturbance such as generation loss occurs in the power system. Therefore, DGs with ESSs are able to provide frequency response to support the frequency stability. On the other hand, the discharged ESS is able to store the excessive output power from the DGs. This operation solves the mismatch between the power generation and load demand caused by renewable energy source variations. Thus, the power system stability and flexibility may be improved by installing DGs with ESSs. However, there are many technical and operational limits for ESSs. For example, there have been problems with modeling batteries used in ESSs, which causes over-charging and over-voltage problems, and this may result in causing severe explosion and fire [26,27]. Therefore, since ESSs may not provide PFR whenever required, PFR is still mainly provided by GUs, especially SGs.

As the penetration of renewable energy increases, PFR must be analyzed carefully to maintain frequency stability [28,29]. In particular, the amount of available PFR from GUs is defined with the composite system frequency response characteristic, which is called β [30]. This index is typically measured in MW/0.1 Hz, and it describes the relationship between the output power from GUs and steady-state frequency stability. As mentioned previously, as WPPs operating in the MPPT control method cannot provide PFR, the penetration of these WPPs reduces the overall β in the power system as well as f_set. This problem could be relieved to a certain degree by WPPs that are able to provide PFR. However, as mentioned previously, due to the variability of renewable energy and power system conditions, WPPs may not provide adequate PFR whenever it is required.

To solve this problem, this paper proposes an algorithm to determine the operation of GUs to provide appropriate PFR. To do so, it first analyzes the impact on β of the power system caused by the high penetration of WPPs. Then, it calculates the required PFR in terms of β to restore the decreased f_set. Thereafter, while considering the available PFR from WPPs, the insufficient PFR is handled by redetermining the droop coefficients of SGs governor. The major contributions of this paper are summarized as follows:

• The impact of high penetration of wind power is analyzed in terms of IR, PFR, and frequency stability.
• The algorithm for recovering the decreased f_set caused by high penetration of wind power to the required boundary is proposed based on mathematical and theoretical analysis.
• The frequency stability impact of installing the planned wind power plants according to the national energy plan is analyzed on the Korean electric power system.
• The proposed method is applied to the Korean electric power system to determine the droop coefficients of SGs governor, thereby verifying its performance for improving the frequency stability.

This paper is organized as follows. Section 2 describes the operation of WPPs and the effect of penetration of wind power on frequency stability. Then, in Section 3, the details of the implementation procedure on determining the droop coefficients of SGs governor to recover the frequency stability are given with its theoretical analysis. Thereafter, Section 4 describes the characteristics of a practical Korean electric power system, and case studies are carried out to verify the effectiveness of the proposed method using the DIgSILENT PowerFactory^®. Finally, conclusions and future work are presented in Section 5.

2. Effect of High Penetration of Wind Power on Frequency Stability

2.1. Operation of Wind Power Plants

The mechanical power of WPPs, P_m, for a wind speed of V_w is represented as

$$P_m\hspace{0.17em}\hspace{0.17em}=\hspace{0.17em}\hspace{0.17em}\frac{1}{2}\rho \pi R^2{V}_w{}^3{c}_P(\lambda ,\theta )$$

(1)

where ρ, R, c_P, λ, and θ are the air density, rotor radius, power coefficient, tip speed ratio, and pitch angle, respectively. Note that ρ and R are set to 1.225 kg/m³ and 46 m, respectively, in this paper. Generally, WPPs are normally operated in the MPPT control method [8]. This is because this control method allows WPPs to provide maximum output power in a steady-state condition. Moreover, it is observed in Figure 1 that the MPPT curve intersects with the maximum value in the mechanical power curve for each V_w. Moreover, when WPPs are operated in this method, θ in (1) is maintained to 0˚, and the corresponding maximum output power, P_MPPT, is determined as

$$P_{MPPT}=\frac{\pi \rho R^5{c}_{P,max}}{2{\lambda }_{opt}^3}\cdot {\omega }_r{}^3=k_{opt}\cdot {\omega }_r{}^3$$

(2)

where c_P,max and λ_opt are the optimally selected value of c_P and λ, respectively, by the MPPT control method, ω_r is the rotor speed, and k_opt is the coefficient of the MPPT curve shown in Figure 1. In this paper, c_P,max, λ_opt, and k_opt are set to 0.447, 0.501, and 7.2, respectively.

The MPPT control method is very effective since it provides maximum output power in a steady-state condition. However, when a large disturbance such as a generation trip occurs in the power system, WPPs operating in this control method cannot provide any additional power. In other words, unlike conventional SGs, they do not provide any frequency responses to compensate for the loss. Therefore, frequency stability is severely impacted as penetration of these WPPs increases.

Many studies have developed inertial control methods and power reserve control methods for WPPs to provide proper frequency responses to solve this frequency stability problem. In particular, the former provides IR, which supports dynamic frequency stability, and the latter provides a power reserve, which supports both dynamic and steady-state frequency stabilities. As shown in Figure 2, WPP operating in the inertial control method increases the power by ΔP_IC from the MPPT curve. After providing dynamic frequency stability support, it decreases the output power to recover its rotor speed. Thus, WPPs operating in this method provide IR during a dynamic state. Additionally, this IR is provided from releasable kinetic energy stored in the rotating mass [31], KE_WPP, which is calculated as

$$K{E}_{WPP}\hspace{0.17em}=\hspace{0.17em}H\left({\omega }_0^2-{\omega }_{min}^2\right)$$

(3)

where H is the inertia constant for WPP, ω₀ is the initial rotor speed, and ω_min is the minimum speed limit.

With this releasable kinetic energy, WPPs provide IR by inertial control method [18] as

$$\Delta P_{\hspace{0.17em}IC}\hspace{0.17em}=\hspace{0.17em}\left[P_{T-lim}({\omega }_0)\hspace{0.17em}-\hspace{0.17em}{P}_0\right]\hspace{0.17em}\cdot \left({\omega }_0^n-{\omega }_{min}^n\right)\hspace{0.17em}$$

(4)

where P_T-lim(ω₀) is the power refers to the torque limit at ω₀, P₀ is the initial output power from the WPPs before providing the IR, and n is the parameter to prevent excessive power increment. On the other hand, WPPs operating on the power reserve control method may increase the output power by increasing the output power from curtailed power, as shown in Figure 2. Therefore, unlike the inertial control method, this method maintains the increased power, ΔP_PFR. Thus, WPPs operating in this method provide PFR and support both dynamic and steady-state frequency stabilities.

2.2. Frequency Stability Analysis Based on Penetration of Wind Power

When a large disturbance such as a generation trip occurs in the power system, SGs provide frequency responses to secure the frequency stability. In particular, the relationship between f_set and PFR provided from SGs can be analyzed by composite system frequency response characteristic [30], β, which is calculated as

$$\beta ={\displaystyle \sum _i\frac{100}{R_i}\frac{S_i\cdot \mathrm{P}{\mathrm{F}}_i}{f_{norm}}\frac{1}{10}}$$

(5)

where R_i, S_i, and PF_i are the droop coefficient, power capacity, and power factor of i-th SG, respectively, and f_norm is the nominal value of frequency. By using β, f_set can be calculated as

$$f_{set}\hspace{0.17em}=\hspace{0.17em}{f}_{norm}-\frac{P_{loss}}{\beta }-\mathrm{D}\mathrm{B}$$

(6)

where P_loss is the size of generation loss, and DB is the dead-band of the governor. Therefore, this indicates that even for the same size of generation loss, f_set decreases further in the power system with smaller β.

As shown in Figure 3, the decrease in system inertia and power reserve due to penetration of wind power causes adverse impacts on both dynamic and steady-state frequency stabilities. In addition, as mentioned previously, the former is improved by both IR and PFR, and the latter is improved by PFR. Moreover, while IR is provided from the releasable kinetic energy stored in the rotating mass of WPP, PFR is provided from WPPs that were previously curtailed. In other words, in order to provide PFR by WPPs, they need to be curtailed first. Therefore, the amount of PFR may not be sufficient depending on power system conditions such as wind speed and load demand. Thus, PFR must be determined appropriately for other GUs to provide sufficient frequency support. Of note, lack of PFR may decrease the f_set below the frequency deviation limit (f_limit), which may prevent AGC operation that restores the f_set to f_norm. Thus, it is important for system operators to store proper power reserve to provide sufficient PFR.

3. Proposed Droop Coefficients Determination Method

As mentioned above, the high penetration of wind power causes a severe impact on the frequency stability, which may prevent the operation of AGC and cause under-frequency load shedding relay. Therefore, the system operator must take appropriate action on the GUs to maintain frequency stability. Unfortunately, in the authors’ opinion, there is only a standard on the overall amount of power reserve [32,33], but no decision-making scheme or other standards on determining the operation of GUs to store sufficient PFR after high penetration of renewable energy.

In order to raise the f_set, which is decreased by high penetration of wind power, to f_limit, the proposed algorithm redetermines the droop coefficient of SGs governor while considering the allowable PFR from WPPs. To do so, the proposed method calculates the required PFR to restore the frequency stability. Then, the available PFR stored in both SGs and DGs are calculated to determine whether the power system has sufficient or insufficient PFR to satisfy its required value. Thereafter, if the power system has insufficient PFR to stabilize the frequency within the required boundary, the droop coefficients of SGs governor are newly determined to increase PFR to that of the required value. The overall procedure to implement the proposed droop coefficients determination method is shown in Figure 4. Moreover, the detailed operations in four stages to implement the proposed algorithm are explained below.

• Stage I—PFR analysis for conventional SGs

In the early stage of the proposed algorithm, the available PFR from the remaining conventional SGs is analyzed. As SGs provide PFR through the governor, only the SGs equipped with the governor are considered. However, as shown in Figure 5, even though the SG is able to increase the power according to its governor droop coefficient setting, it may not provide PFR fully due to its power limit. Therefore, the overall available PFR from conventional SGs in a power system, β_sys, is calculated as

$${\beta }_{sys}\hspace{0.17em}=\hspace{0.17em}{\displaystyle \sum _{i=1}^n{\beta }_{SG,i}}$$

(7)

$${\beta }_{SG,i}\hspace{0.17em}=\hspace{0.17em}\left\{\begin{array}{l}\frac{0.1\cdot \left(P_{limit,i}-P_{0,i}\right)}{f_{norm}-f_{set}-\mathrm{D}\mathrm{B}},if\hspace{0.17em}\hspace{0.17em}\left(P_{limit,i}\le P_{up,i}\right)\hspace{0.17em}\hspace{0.17em}\hspace{0.17em}\hspace{0.17em}\hspace{0.17em}\\ {\beta }_i,\hspace{0.17em}\hspace{0.17em}\hspace{0.17em}\hspace{0.17em}otherwise\end{array}\right.\hspace{0.17em}$$

(8)

where P_up,i and P_limit,i are the increased power by PFR and maximum power limit of i-th SG, respectively. Unlike IR, PFR from SG is only provided when the frequency is beyond the DB. In particular, the DB in the Korean electric power system is 0.036 Hz. Therefore, in this stage, β_{sys_bef}, which is β calculated before redetermining droop coefficients, is calculated by (7).

2.

Stage II—PFR analysis for WPPs

In this stage, available PFR from WPPs is calculated. Unlike SGs, since WPPs are normally operated by the MPPT control method, they do not store power reserve. Therefore, these WPPs cannot provide PFR when a disturbance occurs in a power system. However, as mentioned previously, due to the increasing penetration of wind power, they are forced by the system operator to curtail a certain amount of power. Then, these WPPs store power reserve, which can provide PFR when a disturbance occurs in a power system. Moreover, the available PFR from overall WPPs, PFR_WPP, is calculated as

$$PF{R}_{WPP}={\displaystyle \sum _{j=1}\Delta P_{PFR,j}}$$

(9)

3.

Stage III—Analysis on required β

In this stage, the power system condition is analyzed based on β to ensure that the system has sufficient PFR to raise the f_set to f_limit. Therefore, the required β to stabilize the frequency within the frequency deviation limit band (f_SSband) caused by disturbance with a power loss of P_loss is calculated as

$${\beta }_{req}\hspace{0.17em}=\hspace{0.17em}\frac{0.1\cdot (P_{loss}-PF{R}_{WPP})}{f_{SSband}-DB}$$

(10)

where β_req is the required β for the system frequency to be stabilized within f_SSband considering the available PFR from WPPs. Then, β_{sys_bef} is compared with β_req before tuning the droop coefficient of SGs governor. If β_{sys_bef} is higher than β_req, this indicates that the power system has enough power reserve, and the PFR can stabilize the frequency within f_SSband. On the other hand, if β_{sys_bef} is smaller than β_req, this indicates that the frequency cannot converge within f_SSband. Therefore, the system operator must increase the available PFR for the power system.

However, unless WPPs are equipped with an energy storage system, they cannot provide additional PFR other than the previously curtailed power. Therefore, the system operator must increase the available PFR by tuning the droop coefficients of SGs governor.

4.

Stage IV—Tuning droop coefficients of SGs governor

In the last stage, droop coefficients of SGs governor are redetermined to increase the β_{sys_bef} to β_req. To do so, β for SG with high headroom is preferentially increased. This iteration is repeated until the β_{sys_aft}, which is β calculated from the redetermined droop coefficients, is higher than β_req. As the result, the frequency can be stabilized within the f_SSband. Note that the available ranges for droop coefficients vary according to the type of the turbine governors [34].

4. Simulation Results

4.1. Characteristics of Korean Electric Power System

To evaluate the performance of the proposed method, case studies were carried out on the practical Korean electric power system. In this power system, there are more than 400 SGs with a total power capacity of 145 GW. Moreover, as shown in Figure 6, there are six regions in the Korean electric power system according to provinces. Note that simulations were carried out based on one day during winter in 2020. On this particular day, the characteristics of each region, including power generation of SGs, load demand, H, β, and S, are given in

Table 1. Conventional SGs characteristics in Korean electric power system.

Region	Power Generation (GW)	Load Demand (GW)	H (s)	β (MW/0.1 Hz)	S (GW)
Region 1	14.68	25.65	4.91	372	17.61
Region 2	10.07	6.93	4.97	91	11.85
Region 3	4.04	2.55	3.71	144	5.59
Region 4	19.22	13.82	4.34	239	25.52
Region 5	10.69	8.43	4.86	95	13.13
Region 6	25.35	23.64	4.85	314	31.29
Overall system	84.05	81.02	4.69	1255	104.99

. It is observed that Region 1 has a large load demand compared to its power generation. This is because Region 1 is the metropolitan region, including the capital Seoul. Therefore, insufficient power is transmitted from other regions through high voltage transmission lines and high-voltage direct-current (HVDC) system.

Moreover, the Korean government has announced the “Renewable Energy 3020 Action Plan” to increase the hosting capacity of renewable energies, which includes installing WPPs with a total capacity of 17.7 GW until 2030 [1,2]. Therefore, in this paper, among planned WPPs based on the national energy plan, 20 WPPs given in

Table 2. WPPs characteristics in Korean electric power system.

Region	WPP	Location	Capacity (MW)	Wind Speed (m/s)	Power Generation (MW)
Region 1	WPP1	Ansan	200.1	6.8	51
Region 2	WPP2	Deokjeok	299	8	123
	WPP3	Muuido	299	7.2	90
Region 3	WPP4	Yangyang	220.8	6.8	56
	WPP5	Yeongwol	167.9	6.3	34
	WPP6	Jeongseon	218.5	6.4	46
	WPP7	Taebaek	170.2	8.7	90
	WPP8	Pyeongchang	637.1	7.5	216
Region 4	WPP9	Danyang	46	7.5	16
	WPP10	Dangjin	400.2	6.7	97
Region 5	WPP11	Gunsan	1499.6	6.9	396
	WPP12	Suncheon	119.6	8.6	61
	WPP13	Shinan	1499.6	8.2	664
	WPP14	Yeonggwang	878.6	7.9	348
	WPP15	Yeongam	154.1	8.2	68
Region 6	WPP16	Namhae	1000.5	7.1	288
	WPP17	Yeongdeok	1000.5	9.1	605
	WPP18	Yeongyang	278.3	6.7	67
	WPP19	Ulsan	1499.6	8.4	714
	WPP20	Pohang	41.4	7.4	13

with a total capacity of 11 GW are applied in the current Korean electric power system, as shown in Figure 6.

4.2. Simulation Results Based on Proposed Droop Coefficients Determination Method—Case Study 1: WPPs with Power Reserve

To analyze the frequency stability, the Shinkori nuclear power plant with a capacity of 1600 MW in Area 6, which is one of the largest SG in the Korean electric power system, was suddenly disconnected at 10 s. As many WPPs (total of 11 GW) penetrated the Korean electric power system, the conventional SGs were correspondingly replaced. As the result, β_{sys_bef} decreased from 1255 MW/0.1 Hz to 621 MW/0.1 Hz. Then, with the P_loss of 1500, the f_set reduced from 59.834 Hz to 59.705 Hz by (6), which is beyond the f_SSband (see Figure 7). Note that since there are about 2000 buses in the power system, the frequency cannot be analyzed for every bus. Therefore, system frequency is calculated based on the center of inertia [35]. Moreover, WPPs from WPP1 to WPP11 curtailed to a total of 371 MW to balance the power supply and load demand. WPPs from WPP1 to WPP10 curtailed by 10%, and WPP11 curtailed by 7%. Therefore, these WPPs are able to provide a power reserve total of 371 MW. On the other hand, WPPs from WPP12 to WPP20 are operated in MPPT operation point.

In order to recover the f_set within the f_SSband, the proposed method of Figure 4 was applied. In Stage I, the value of β_{sys_bef} was calculated as 621 MW/0.1 Hz for remaining conventional SGs by (7). Next, in Stage II, considering the current wind speed and the curtailed power, the available PFR from 20 WPPs were calculated by (9). In this case, the curtailed WPPs from WPP1 to WPP11 were available to provide a PFR total of 371 MW. Thereafter, in Stage III, β_req was calculated for the current condition in the power system. Note that the f_SSband is 0.2 Hz for the Korean electric power system, and for the case when the Shinkori nuclear power plant was tripped out, the value of P_loss was 1500 MW. However, as WPPs were available to provide PFR of 371 MW, the size of P_loss decreased to 1129 MW. As the result, β_req was calculated as 688 MW/0.1 Hz by (10). Since β_{sys_bef}, which is 621 MW/0.1 Hz, is lower than the β_req, the f_set cannot be stabilized within f_SSband. Therefore, in Stage IV, the R_i was tuned for SG_i to increase the β_{sys_aft} to that of β_req.

As Shinkori nuclear power plant was suddenly disconnected at 10 s, the curtailed WPPs (from WPP1 to WPP11) provided PFR, and the other WPPs (from WPP12 to WPP20) provided IR, as shown in Figure 8. On the other hand, as shown in Figure 9, it is observed that the PFR of the SGs has become different since the SGs governor droop coefficient was redetermined to raise the β_{sys_aft} to β_req. In particular, after tuning the droop coefficient of SGs governor, the PFR in Regions 3 and 4 increased while the PFR in other regions decreased. This indicates that SGs in Regions 3 and 4 had a higher headroom compared to other regions. However, the total amount of PFR provided is the same for both cases. This is because the value of P_loss is the same for these cases.

Moreover, the system frequency for the two cases is shown in Figure 10. It is observed that f_nadir and f_set of both cases are increased more than the case with high penetration of wind power (indicated by the magenta dash-dotted line in Figure 7). This is because WPPs (from WPP1 to WPP11) provide IR to support the dynamic frequency stability, and the other WPPs (from WPP12 to WPP20) provide PFR to support both dynamic and steady-state frequency stabilities. However, it is also observed that f_set is not stabilized within f_SSband (indicated by the blue dash-dotted line in Figure 10) for the case before tuning the droop coefficients. This indicates that WPPs cannot provide sufficient PFR from current wind conditions, and the SGs cannot also provide sufficient PFR with current droop coefficients. On the other hand, increasing the β_{sys_aft} to β_req for the case after tuning the droop coefficients shows that the f_set is successfully raised within the f_SSband (indicated by the solid red line in Figure 10). In particular, compared to the case before tuning the droop coefficients, f_nadir and f_set are raised by 0.028 Hz and 0.039 Hz, respectively.

4.3. Simulation Results Based on Proposed Droop Coefficients Determination Method—Case Study 2: WPPs without Power Reserve

Even though various power reserve control methods have been developed for WPPs in recent studies, due to the technical and operational limits, WPPs may not provide power reserve or inertial response whenever it is required. Therefore, case study 2 assumes that WPPs do not provide any frequency responses. Thus, different from case study 1, WPPs maintain the output power when a disturbance occurs at 10 s. To analyze and solve the insufficient PFR for this case, the proposed method of Figure 4 was applied. In Stages I and III, while β_{sys_bef} is the same as that in case study 1, β_req was increased from 688 MW/0.1 Hz to 915 MW/0.1 Hz compared to case study 1. This is because WPPs do not provide PFR to compensate for the loss in (10). Thus, the difference between β_req and β_{sys_bef} was increased for this case study. In other words, the PFR is much more insufficient for the power system.

The results of PFR and frequency stability for this case study are shown in Figure 11 and Figure 12. It is observed that the overall PFR provided from SGs is increased compared to case study 1. This is because while WPPs provided PFR in the previous case study, WPPs are assumed that they cannot provide PFR due to technical and operational limits for this case study. Therefore, SGs must provide more PFR to compensate for the loss. As WPPs are not providing any fast frequency responses (IR and PFR) for this case, it is observed that before tuning the droop coefficients, f_nadir and f_set are decreased by 0.123 Hz and 0.062 Hz, respectively, compared to those of case study 1. However, after tuning the SGs governor droop coefficients by the proposed method, it is observed that both f_nadir and f_set have been increased by 0.086 Hz and 0.101 Hz, respectively. Moreover, the proposed method has also successfully stabilized the system frequency within the required boundary for this case study.

Table 3. Summary of results for all case studies.

	Low Penetration of Wind Power	High Penetration of Wind Power
	Base case	Case study 1		Case study 2
		Before tuning droop coefficients	After tuning droop coefficients	Before tuning droop coefficients	After tuning droop coefficients
fnadir (Hz)	59.732	59.728	59.756	59.605	59.691
fset (Hz)	59.834	59.767	59.806	59.705	59.806
fSSband satisfaction	Yes	No	Yes	No	Yes

summarizes the numerical values of frequency stability indices for all cases.

5. Conclusions and Future Work

This paper proposed the method to determine the operation of generation units (GUs) to provide proper primary frequency response (PFR) and recover the severely impacted frequency stability caused by the high penetration of wind power. To do so, the proposed method redetermined the droop coefficient of synchronous generators (SGs) governor while considering the available PFR from wind power plants (WPPs). The validation of the proposed method was verified in the Korean electric power system, including the planned WPPs based on the national energy plan. After analyzing the frequency stability problem caused by this high penetration of WPPs, the proposed method was applied to solve this problem. The simulation results showed that the proposed method successfully recovered the settling frequency within the frequency deviation limit band by the redetermined droop coefficients of SGs governor, which provided proper PFR. In practice, this study is expected to provide useful information in decision-making guidance for a system operator to maintain the frequency stability when the penetration of wind power is increasing.

Moreover, inertial response and PFR were considered in this paper while recovering the frequency stability. However, many control methods are being developed for the newly installed WPPs with the energy storage systems (ESSs) to participate more in the frequency response. Therefore, in the future, the system operator must determine the operation of GUs to maintain the settling and dynamic frequency stability considering PFR and other various responses provided from WPPs and ESSs.