The increase in the number of consumers who produce part of their own electricity through photovoltaic distributed generation (PVDG) led to the need for studies on how the power system is affected. As the distribution systems were not designed to integrate PVDG, it is important for regulatory agencies and utilities to identify technical problems in the grid associated with the levels of photovoltaic penetration. In this regard, this study presents a method with indicators that quantify the technical impacts that PVDG growth causes to an actual utility that contains hundreds of feeders with different topologies, load types, and densities. Real solar irradiance and temperature values over a year, and photovoltaic system locations varying based on the Monte Carlo method were also considered in the computational simulations. This study helps the utilities to plan preventive measures to strengthen the grid, and regulatory agencies to enhance policies to support PVDG. We analyzed the impacts on voltage magnitudes, technical losses and peak demand arising from the PVDG integration. The results show that, even at low penetration levels (2%), one-third of feeders required modification in the distribution system to allow photovoltaic integration. For over 60% of feeders, penetration levels of up to 20% reduced technical losses and voltage problems, with practically no effect on peak demand. Feeders in residential and commercial/industrial areas presented increases in technical losses and voltage levels for high penetration levels. Rural areas presented reductions in these parameters for all levels of PVDG integration.

This study assesses the technical and financial impacts on voltage levels, peak demand, and technical losses of distribution systems due to the integration of battery energy storage systems (BESSs) associated with photovoltaic distributed generation (PVDG). It assumes that the BESS features (location and storage capacity) are chosen by consumers individually, aiming to directly benefit themselves according to self-consumption and price arbitrage uncoordinated control strategies. Computational simulations of several PVDG/BESS penetration levels in residential feeders of a Brazilian utility were performed via OpenDSS, employing real data of the load (consumption and load profiles) and photovoltaic generation (irradiance and temperature). We address the PVDG/BESS locations and the selection of solar irradiance, temperature, and load profile based on the Monte Carlo method. As the impacts on voltage levels, peak demand, and technical losses are expressed in different units, they were stochastically converted into monetary amounts to identify the control strategy that enhances the technical benefits in the distribution system. The results show that BESS installation with location, size, and control strategy defined by consumers creates technical benefits for the distribution system. The risk analysis allows us to conclude that price arbitrage should be prioritized in deciding incentives for penetration levels of up to 60%. Above these levels, self-consumption should be prioritized as an incentive. However, it is worth mentioning that the two strategies could be encouraged regardless of the penetration levels, as both create technical benefits for the distribution networks. The proposed method can support policy proposals to encourage BESS integration in distribution systems.

This paper presents a stochastic methodology to determine a premium designed to compensate prosumers for the technical benefits arising from the integration of battery energy storage systems (BESS) with photovoltaic distributed generation (PVDG). The motivation stems from the existing asymmetry among stakeholders: distribution utilities benefit technically and economically from BESS deployment, through peak demand reduction, lower technical losses, and mitigation of voltage violations, without bearing the investment burden. The proposed approach employs stochastic simulations to (i) quantify both the technical and financial impacts from the utility’s perspective, based on the integration of these technologies into real distribution feeders, and (ii) assess the economic feasibility of BESS adoption from the prosumer’s perspective. A univariate sensitivity analysis is conducted to identify the minimum financial incentive required to make such installations viable. The study explicitly considers regulatory and tariff structures that influence prosumer decision-making, focusing on two uncoordinated control strategies: self-consumption and price arbitrage. Results derived from 23 real low-voltage feeders demonstrate that, when the proposed premium is applied, BESS adoption becomes economically viable for prosumers while simultaneously enhancing grid performance. The findings highlight that compensating prosumers according to the monetized technical benefits of BESS integration effectively aligns private incentives with public grid improvements, thereby fostering sustainable energy transition policies without reliance on traditional subsidies.