Inverter-interfaced distributed generation (DG) can provide voltage support in unbalanced distribution feeders; however, sequential, phase-selective siting and sizing under local interconnection constraints have received limited attention. This study proposes a constructive Volt/VAR planning method that allocates DG according to the apparent demand and voltage-deficient phases at each candidate bus. A descending reactive power feasibility test rejects solutions that cause non-convergence, overvoltage, or deterioration of the minimum system voltage. The method was implemented through automated unbalanced three-phase power-flow simulations and tested on the IEEE 13-node feeder and the real 3849-bus CHIRIPA medium-voltage network in Honduras, using active power allocation factors of 0.7 and 0.9. The selected configurations were evaluated over 24 h profiles for representative sunny and rainy days, annualized, and assessed economically over a 25-year horizon. Annual energy losses decreased by 25.8% and 26.4% in the IEEE feeder, although local capacity constraints prevented all phase voltages from reaching the 0.95–1.05 p.u. range. In CHIRIPA, all medium-voltage bus-phase voltages satisfied this range at maximum demand, although this improvement persisted only during solar hours; annual losses fell by 15.1% and 18.7%. The economic feasibility threshold in CHIRIPA depended primarily on installed capacity (approximately 6.5–6.6 MW), rather than unit count. These results provide a reproducible framework for prioritizing phase-specific DG investments under technical and economic constraints.

This study evaluates the impact of integrating Electric Buses (EBs) charging infrastructure into the Tegucigalpa distribution network under the PROMOVEHR project, aiming to decarbonize the transport sector. Integration was analyzed through simulations of the modeled circuits in DIgSILENT PowerFactory, using real historical data from months of peak demand. A primary focus was ensuring grid stability, as unplanned EB deployment could stress the system due to current conditions. Consequently, this research proposes a strategic approach by scheduling charging operations during off-peak intervals. The simulation results show that the system can safely handle the 160 kW per-circuit demand, with the proper planning, this demand is managed without compromising stability, establishing a scalable baseline for future expansion. The Results indicate that the integration only increased total demand without adversely affecting the network parameters, as the voltage profiles and loading levels remained stable. These findings confirm the technical feasibility of the EBs infrastructure through strategic planning based on real system parameters.