Abstract
A rapid increase in electric-vehicle (EV) adoption is imposing new stresses on distribution feeders, yet quantitative evidence on how coordinated renewable generation and vehicle-to-grid (V2G) operation can mitigate these impacts remains limited, especially for radial networks with long laterals and evening-peaking demand. In this study, high-resolution (15-min) time-series power-flow simulations were performed on canonical 69-bus radial system to evaluate uncontrolled EV charging, managed charging with V2G triggers, and combined scenarios with feeder-embedded photovoltaics (PV) and wind turbine generation (WTG). A stochastic EV arrival model, battery state-of-charge tracking, and a simple charger model (2.3 kW per phase, pf≈0.95) were adopted; V2G discharging was activated when local voltage fell below 0.95 pu (V_on) and deactivated when voltage recovered above 0.97 pu (V_off) or when SoC reached the lower bound, to avoid chattering. PV/WTG outputs followed realistic diurnal profiles with lagging power factors representative of inverter limits. Backward/forward-sweep load flow yielded node voltages, branch currents, and total feeder losses across a 24-h horizon, and results were synthesized via heat maps, box plots, and daily power balance curves. It was found that coordinated V2G with feeder-level PV/WTG materially reduces peak source current, alleviates trunk and mid-feeder overloading, and lowers total active power losses, while lifting minimum voltages toward acceptable limits during critical evening windows. Benefits were strongest when renewable production temporally overlapped charging demand and where DERs were electrically proximate to stressed branches; residual constraints persisted during late-night peaks with weak renewable support. Overall, the results indicate that pragmatic V2G thresholds, modest feeder-sited renewables, and basic charging management can substantially improve hosting capacity without immediate network reinforcement.