Input Dataset for OPF-Based Network-Constrained Scheduling of a 37-Bus Renewable Energy Community

The network topology, branch impedances and thermal ratings follow the original 37-bus test feeder; the DER and market configuration were modified to construct this scenario: the electric vehicle fleet was capped at ten vehicles per member (219 vehicles in total), two additional wind generation sites were added at buses that previously hosted dispatchable combined-heat-and-power (CHP) units, and all CHP capacity was removed.

The dataset includes hourly (24-hour) load, PV and wind generation profiles, reactive demand, retail/wholesale/peer-to-peer tariffs, battery energy storage system parameters, and per-vehicle EV fleet data (battery capacity, efficiencies, power limits, connection status and trip energy consumption), together with the full network topology and base values. It was used to compare network-constrained (OPF-based, Relaxed Branch Flow Model) and economic-only REC scheduling, quantifying the economic cost of guaranteeing distribution-grid feasibility.