A Comparative Study on the Impact of Grid Code Regulations on Stability of Wind Integrated Power Systems

Karbouj, Hazem; Rather, Zakir Hussain

doi:10.1109/gpecom.2019.8778495

Cited by 8 publications

(7 citation statements)

References 10 publications

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“…If required, the reactive output current must be capable of reaching at least 100% of the rated current. All of the above is true outside the dead band of 10% around the nominal voltage [23,24]. According to the North American grid code, utilities frequently allow IIRES with a unity power factor (active current generator) to ride through faults [25,26].…”

Section: Impact Of Iires On Distance Protectionmentioning

confidence: 99%

Transmission line protection using local information in the presence of inverter‐interfaced renewable energy sources

Yaseen

Seydi

Abapour

2023

IET Generation Trans & Dist

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Although inverter-interfaced renewable energy sources (IIRESs) have great economic and environmental benefits, their fault current characteristics differ from those of synchronous generators. IIRESs also comply with modern grid code (GC) requirements for injecting reactive current to compensate for voltage drop during fault conditions. Moreover, the limits of renewable energy-side fault current contribution and the phase angle difference between the local and infeed fault current from conventional sources lead to incorrect reactance estimation by the traditional distance relay at the IIRES substation and negatively affect relay dependability. As a result, the IIRES-side distance protection is prone to incorrect operation. Furthermore, an improved relaying scheme is proposed to alleviate the adverse effects of IIRES on the reactance calculation. This research aims to improve the performance of the ground distance protection scheme in the case of a singlephase to ground fault in zone one. The proposed method, with more than 99% accuracy, is solely dependent on the local information and, therefore, no communication link is required to implement the algorithm. Moreover, the algorithm is compatible with the existing pilot protection methods used in the industry. The simulation studies are modeled in the Digsilent Power Factory environment.

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Section: Impact Of Iires On Distance Protectionmentioning

confidence: 99%

Transmission line protection using local information in the presence of inverter‐interfaced renewable energy sources

Yaseen

Seydi

Abapour

2023

IET Generation Trans & Dist

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“…On the other hand, the post‐fault delayed active power recovery of WTG is currently a critical issue in high wind penetrated power systems [5, 19, 20]. A severe fault‐induced voltage dip in the vicinity of a large‐scale wind power plant can cause an instantaneous active power imbalance between generation and load in the system, thus resulting in a frequency excursion.…”

Section: Lvrt Requirements For Wtgmentioning

confidence: 99%

Enhanced wind turbine generator fault ride‐through capability by using hybrid on‐load tap changer

Karbouj

Rather

2020

IET Generation, Transmission & Distribution

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“…EirGrid, the Irish transmission system operator, has identified voltage dip induced frequency dips (VDIFDs) as a future technical challenge [3], which has received limited attention in the literature [4]- [7]. Based on a modified IEEE 39-bus system, the impact on frequency nadirs, of different wind shares (up to 60%) and demand levels were studied in [4], with the post-fault active power recovery rates of wind turbine generators under different grid codes and load types studied in [5]. In [6], based on a future Ireland and Northern Ireland power system, studies were performed considering two retained wind power values and two post-fault recovery durations, with and without constant reactive current injection during faults, and with different reactive current rise times.…”

Section: Introductionmentioning

confidence: 99%

Voltage Dip Induced Frequency Dips for Power Systems with High Shares of Wind Energy

Zhao

Flynn

2022

2022 IEEE 13th International Symposium on Power Electronics for Distributed Generation Systems (PEDG)

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In order to limit drivetrain mechanical stress, wind turbine generators typically implement a delayed active power recovery following a voltage dip, which may result in a substantial reduction in system frequency, if many wind farms adopt a similar strategy, due to the resulting generationdemand imbalance. Therefore, based on a modified IEEE 39bus system, the impact of active and reactive current priority strategies, and various reactive current loop controls for wind turbine generators on voltage dip induced frequency dips (VDIFDs) are examined. The effectiveness of local voltage control with reactive current priority is validated. In addition, if synchronous-based generation is displaced by grid-forming converters (GFMs), the frequency dips are less severe and the post-fault frequency recovers more quickly. However, due to reduced overcurrent capability, the GFM virtual angle control must be carefully designed to avoid transient instability, by, for example, reducing the droop gain. Finally, if DC-link voltage control and maximum power point tracking control for the grid-side and machine-side converters are switched (to simplify fault ride through implementation) care is needed to avoid large post-fault over-frequency transients for VDIFD events.

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A Comparative Study on the Impact of Grid Code Regulations on Stability of Wind Integrated Power Systems

Cited by 8 publications

References 10 publications

Transmission line protection using local information in the presence of inverter‐interfaced renewable energy sources

Transmission line protection using local information in the presence of inverter‐interfaced renewable energy sources

Enhanced wind turbine generator fault ride‐through capability by using hybrid on‐load tap changer

Voltage Dip Induced Frequency Dips for Power Systems with High Shares of Wind Energy

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