Abstract
Conventional protection schemes in the distribution system are liable to suffer from high penetration of renewable energy source-based distributed generation (RES-DG). The characteristics of RES-DG, such as wind turbine generators (WTGs), are stochastic due to the intermittent behavior of wind dynamics (WD). It can fluctuate the fault current level, which in turn creates the overcurrent relay coordination (ORC) problem. In this paper, the effects of WD such as wind speed and direction on the short-circuit current contribution from a WTG is investigated, and a robust adaptive overcurrent relay coordination scheme is proposed by forecasting the WD. The seasonal autoregression integrated moving average (SARIMA) and artificial neuro-fuzzy inference system (ANFIS) are implemented for forecasting periodic and nonperiodic WD, respectively, and the fault current level is calculated in advance. Furthermore, the ORC problem is optimized using hybrid Harris hawks optimization and linear programming (HHO–LP) to minimize the operating times of relays. The proposed algorithm is tested on the modified IEEE-8 bus system with wind farms, and the overcurrent relay (OCR) miscoordination caused by WD is eliminated. To further prove the effectiveness of the algorithm, it is also tested in a typical wind-farm-integrated substation. Compared to conventional protection schemes, the results of the proposed scheme were found to be promising in fault isolation with a remarkable reduction in the total operation time of relays and zero miscoordination.
Highlights
The integration of renewable energy source-based distributed generation (RES-DG), such as wind turbine generators (WTGs), in power systems is continuously increasing due to extensive technical developments, as well as clean and low-cost energy production [1,2]
Where ∆TF is the time taken by artificial neuro-fuzzy inference system (ANFIS)–seasonal autoregression integrated moving average (SARIMA) to calculate the predicted wind power and fault current, ∆THHO–linear programming (LP) is the time consumed by Harris hawks optimization and linear programming (HHO–LP) to compute the optimum values of relay variables, and ∆T is the time required to transfer the values of Ip and time multiplier setting (TMS) to the relay
If the difference between the predicted and actual fault current due to wind-speed variation was greater than 2%, the actual values were updated, and the HHO–LP algorithm was implemented during the current interval to optimize the relay settings on the basis of the actual fault current level (FCL)
Summary
Mian Rizwan 1,2 , Lucheng Hong 1, *, Muhammad Waseem 3,4 , Shafiq Ahmad 5 , Mohamed Sharaf 5 and Muhammad Shafiq 6, *. Received: 17 August 2020; Accepted: 8 September 2020; Published: 10 September 2020
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