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An increase in inverter-based resources (IBRs) can lower the inertia of a power system, which may adversely affect the power system by causing changes such as a frequency nadir reduction or an increased initial rate of change of frequency (RoCoF). To prevent this, an ancillary service called fast frequency response (FFR) helps the inertia response by using IBRs. The main resources used in FFR are variable-speed wind turbine generators (VSWTGs) or energy storage systems (ESSs), which can respond quickly through converter control. The control is applied to the frequency regulation service faster than the primary frequency response, so the second frequency nadir may fall below the first frequency nadir. This study proposed a novel coordinated control strategy to efficiently utilize energy to improve the frequency nadir through coordinated control of wind turbines based on permanent magnetic synchronous generators (PMSGs) and battery energy storage systems (BESSs). The simulation results confirmed that the two-bus test system was composed of PSCAD/EMTDC, and the frequency nadir increased by utilizing the same amount of energy as in traditional control systems.
HyunWook Kim; Junghun Lee; Jaehyeong Lee; Gilsoo Jang. Novel Coordinated Control Strategy of BESS and PMSG-WTG for Fast Frequency Response. Applied Sciences 2021, 11, 3874 .
AMA StyleHyunWook Kim, Junghun Lee, Jaehyeong Lee, Gilsoo Jang. Novel Coordinated Control Strategy of BESS and PMSG-WTG for Fast Frequency Response. Applied Sciences. 2021; 11 (9):3874.
Chicago/Turabian StyleHyunWook Kim; Junghun Lee; Jaehyeong Lee; Gilsoo Jang. 2021. "Novel Coordinated Control Strategy of BESS and PMSG-WTG for Fast Frequency Response." Applied Sciences 11, no. 9: 3874.
With the continuous development of power electronics technology, variable-speed offshore wind turbines that penetrated the grid system caused the problem of inertia reduction. This study investigates the frequency stability of synchronous, offshore wind-farm integration through a modular-multilevel-converter high-voltage direct-current (MMC–HVDC) transmission system. When full-scale converter wind turbines (type 4) penetrate the AC grid, the AC system debilitates, and it becomes difficult to maintain the AC system frequency stability. In this paper, we present an improved inertial-response-control method to solve this problem. The mathematical model of the synchronous generator is based on the swing equation and is theoretically derived by establishing a MMC–HVDC. Based on the above model, the inertia constant is analyzed using a model that integrates the MMC–HVDC and offshore synchronous generator. With the new improved control method, a more sensitive and accurate inertia index can be obtained using the formula related to the effective short-circuit ratio of the AC system. Moreover, it is advantageous to provide a more accurate inertial control evaluation for AC systems under various conditions. Furthermore, the impact of the MMC–HVDC on system safety is assessed based on the capacitor time constant. This simulation was implemented using the PSCAD/EMTDC platform.
Zicong Zhang; Junghun Lee; Gilsoo Jang. Improved Control Strategy of MMC–HVDC to Improve Frequency Support of AC System. Applied Sciences 2020, 10, 7282 .
AMA StyleZicong Zhang, Junghun Lee, Gilsoo Jang. Improved Control Strategy of MMC–HVDC to Improve Frequency Support of AC System. Applied Sciences. 2020; 10 (20):7282.
Chicago/Turabian StyleZicong Zhang; Junghun Lee; Gilsoo Jang. 2020. "Improved Control Strategy of MMC–HVDC to Improve Frequency Support of AC System." Applied Sciences 10, no. 20: 7282.
As the penetration of renewable energy sources (RESs) increases, the rate of conventional generators and the power system inertia are reduced accordingly, resulting in frequency-stability concerns. As one of the solutions, the battery-type energy storage system (ESS), which can rapidly charge and discharge energy, is utilized for frequency regulation. Typically, it is based on response-driven frequency control (RDFC), which adjusts its output according to the measured frequency. In contrast, event-driven frequency control (EDFC) involves a determined frequency support scheme corresponding to a particular event. EDFC has the advantage that control action is promptly performed compared to RDFC. This study proposes an ESS EDFC strategy that involves estimating the required operating point of the ESS according to a specific disturbance through neural-network training. When a disturbance occurs, the neural networks can estimate the proper magnitude and duration of the ESS output to comply with the frequency grid code. A simulation to validate the proposed control method was performed for an IEEE 39 bus system. The simulation results indicate that a neural-network estimation offers sufficient accuracy for practical use, and frequency response can be adjusted as intended by the system operator.
Soseul Jeong; Junghun Lee; MinHan Yoon; Gilsoo Jang. Energy Storage System Event-Driven Frequency Control Using Neural Networks to Comply with Frequency Grid Code. Energies 2020, 13, 1657 .
AMA StyleSoseul Jeong, Junghun Lee, MinHan Yoon, Gilsoo Jang. Energy Storage System Event-Driven Frequency Control Using Neural Networks to Comply with Frequency Grid Code. Energies. 2020; 13 (7):1657.
Chicago/Turabian StyleSoseul Jeong; Junghun Lee; MinHan Yoon; Gilsoo Jang. 2020. "Energy Storage System Event-Driven Frequency Control Using Neural Networks to Comply with Frequency Grid Code." Energies 13, no. 7: 1657.
In order to solve the problems brought upon by off-shore wind-power plants, it is important to improve fault ride-through capability when an on-shore fault occurs in order to prevent DC overvoltage. In this paper, a coordinated control strategy is implemented for a doubly-fed induction generator (DFIG)-based off-shore wind farm, which connects to on-shore land by a modular multilevel converter (MMC)-based high voltage direct current (HVDC) transmission system during an on-shore fault. The proposed control strategy adjusts the DC voltage of the off-shore converter to ride through fault condition, simultaneously varying off-shore AC frequency. The grid-side converter detects the frequency difference, and the rotor-side converter curtails the output power of the DFIG. The surplus energy will be accumulated at the rotor by accelerating the rotor speed and DC link by rising DC voltage. By the time the fault ends, energy stored in the rotor and energy stored in the DC capacitor will be released to the on-shore side to restore the normal transmission state. Based on the control strategy, the off-shore wind farm will ride through an on-shore fault with minimum rotor stress. To verify the validity of the proposed control strategy, a DFIG-based wind farm connecting to the on-shore side by an MMC HVDC system is simulated by PSCAD with an on-shore Point of Common Coupling side fault scenario.
Junghun Lee; Yeuntae Yoo; MinHan Yoon; Gilsoo Jang; Lee; Yoo; Yoon; Jang. Advanced Fault Ride-through Strategy by an MMC HVDC Transmission for Off-Shore Wind Farm Interconnection. Applied Sciences 2019, 9, 2522 .
AMA StyleJunghun Lee, Yeuntae Yoo, MinHan Yoon, Gilsoo Jang, Lee, Yoo, Yoon, Jang. Advanced Fault Ride-through Strategy by an MMC HVDC Transmission for Off-Shore Wind Farm Interconnection. Applied Sciences. 2019; 9 (12):2522.
Chicago/Turabian StyleJunghun Lee; Yeuntae Yoo; MinHan Yoon; Gilsoo Jang; Lee; Yoo; Yoon; Jang. 2019. "Advanced Fault Ride-through Strategy by an MMC HVDC Transmission for Off-Shore Wind Farm Interconnection." Applied Sciences 9, no. 12: 2522.
In the Korean power system, growing power loads have recently created the problems of voltage instability and fault current in the Seoul Capital Area (SCA). Accordingly, the back-to-back (BTB) voltage source converter (VSC) high-voltage direct-current (HVDC) system is emerging to resolve such problems with grid segmentation. However, non-convergence problems occur in this metropolitan area, due to the large change of power flow in some contingencies. Therefore, this paper proposes two kinds of AC transmission emulation control (ATEC) strategies to improve the metropolitan transient stability, and to resolve the non-convergence problem. The proposed ATEC strategies are able to mitigate possible overloading of adjacent AC transmission, and maintain power balance between metropolitan regions. The first ATEC strategy uses a monitoring system that permits the reverse power flow of AC transmission, and thus effectively improves the grid stability based on the power transfer equation. The second ATEC strategy emulates AC transmission with DC link capacitors in a permissible DC-link voltage range according to angle difference, and securely improves the gird stability, without requiring grid operator schedule decisions. This paper compares two kinds of ATEC schemes: it demonstrates the first ATEC strategy with specific fault scenario with PSS/E (Power Transmission System Planning Software), and evaluates the second ATEC strategy with internal controller performance with PSCAD/EMTDC (Power System Electromagnetic Transients Simulation Software).
Sungyoon Song; Jongin Kim; Junghun Lee; Gilsoo Jang. AC Transmission Emulation Control Strategies for the BTB VSC HVDC System in the Metropolitan Area of Seoul. Energies 2017, 10, 1143 .
AMA StyleSungyoon Song, Jongin Kim, Junghun Lee, Gilsoo Jang. AC Transmission Emulation Control Strategies for the BTB VSC HVDC System in the Metropolitan Area of Seoul. Energies. 2017; 10 (8):1143.
Chicago/Turabian StyleSungyoon Song; Jongin Kim; Junghun Lee; Gilsoo Jang. 2017. "AC Transmission Emulation Control Strategies for the BTB VSC HVDC System in the Metropolitan Area of Seoul." Energies 10, no. 8: 1143.