Solar PV penetration on utility grid brings both benefits and technical challenges, particularly in radial feeders with long line lengths and distributed loads. This study investigates the impact of grid-connected solar photovoltaic (PV) integration on active power losses and voltage profiles in a radial distribution network in Kume, Myanmar, by using DigSILENT PowerFactory. Using realistic network and load data, load flow analysis is performed for a base case without PV and many PV integration scenarios. PV units are represented as distributed generation sources that inject active power at selected buses along the feeder. Simulation results indicate that buses located far from the substation experience significant voltage drops and higher technical losses. Voltage profiles approach 1.0 pu and overall feeder losses drop from approximately 0.5 MW to approximately 0.2 MW with solar PV integration at two and three buses. These results show that appropriate PV placement can significantly enhance distribution system performance without causing reverse power flow or overvoltage issues.

Myanmar’s renewable resources could support green-hydrogen production, but evidence on how location, hourly variability, and system configuration influence performance remains limited. This study compares PV-only, wind-only, and hybrid PV–wind systems at five Myanmar locations. Hourly ERA5 data for 2015–2025 were converted into renewable-electricity profiles and supplied to a 10 MW proton-exchange-membrane electrolyser model. For each location, weather year, and cost scenario, 48 discrete renewable-capacity designs were evaluated through hourly dispatch, hydrogen production, electrolyser utilisation, curtailment, and plant-gate levelised cost of hydrogen (LCOH). PV capacity factors varied little among locations, while wind capacity factors exhibited greater spatial and interannual variability. Under the central cost case, Minbu consistently selected 15 MW PV, whereas Ngapudaw, Seikphyu, and Wundwin consistently selected 15 MW PV plus 10 MW wind. Wundwin achieved the lowest mean LCOH (10.30 USD/kg) and highest mean annual hydrogen production (725.30 tonnes/year). Mean LCOH across all locations ranged from 6.53 to 13.94 USD/kg under the low and high cost cases. Fixed-design analysis showed robust performance at four locations; Sittwe incurred a mean penalty of 0.06 USD/kg. Hydrogen cost therefore depends jointly on resource complementarity, electrolyser utilisation, curtailment, and renewable-capacity cost.