Optimized planning framework of solar photovoltaic based generation with EV charging station in a rural distribution network considering uncertainties

To minimize global warming effect and carbon emission impacts, plug-in hybrid electric vehicles (PHEVs) are becoming popular now-a-days as an alternative to conventional vehicles. As PHEVs are charged from existing grid, so planning and analysis should be done properly for integration. In this paper, the impact of assimilating PHEV in the distribution network in terms of all the technical factors such as voltage profile, line loss, voltage unbalance is analysed. Taking into account the uncertainty of PHEV load, the 24 hour power demand curve of PHEVs is developed which is probabilistic in nature. Then PHEVs are incorporated with residential load in the IEEE-13 bus system. Here the hourly load flow for unbalanced distribution system is performed in OpenDSS (version 9.4.0.1) software interfaced with MATLAB (version 2018a) software. It was observed that increase in penetration level of PHEVs leads to violation of security constraints in terms of voltage profile and voltage unbalance. The performance parameters are studied for different penetration levels of PHEVs. In order to increase the penetration level of PHEV in the distribution system, FACTS devices such as DSTATCOMs are incorporated in the existing system and the results were compared and analyzed.

This study aims to provide an efficient framework for the coordinated integration of AC and DC chargers, intermittent solar Photovoltaic (PV) Distributed Generation (DG) units, and a Distribution Static Compensator (DSTATCOM) across residential, commercial, and industrial zones of a Radial Distribution Network (RDN) considering the benefits of various stakeholders: Electric Vehicle (EV) charging station owners, EV owners, and distribution network operators. The model uses a multi-zone planning method and healthy-bus strategy to allocate Electric Vehicle Charging Stations (EVCSs), Photovoltaic Distributed Generation (PVDG) units, and DSTATCOMs. The proposed framework optimally determines the numbers of EVCSs, PVDG units, and DSTATCOMs using Harris Hawk Optimization, considering the maximization of techno-economic benefits while satisfying all the security constraints. Further, to showcase the benefits from the perspective of EV owners, an EV waiting-time evaluation is performed. The simulation results show that integrating EVCSs (with both AC and DC chargers) with solar PVDG units and DSTATCOMs in the existing RDN improves the voltage profile, reduces power losses, and enhances cost-effectiveness compared to the system with only EVCSs. Furthermore, the zonal division ensures that charging infrastructure is distributed across the network increasing accessibility to the EV users. It is also observed that combining AC and DC chargers across the network provides overall benefits in terms of voltage profile, line loss, and waiting time as compared to a system with only AC or DC chargers. The proposed framework improves EV owners’ access and reduces waiting time, while supporting distribution network operators through enhanced grid stability and efficient integration of EV loads, PV generation, and DSTATCOM.