Passive distribution networks tend to become active, due to the high penetration of photovoltaic units, battery energy storage utilization and their combined active participation to distribution network operation. In this paper, a framework for the assessment of the impact of photovoltaic and battery energy storage systems on voltage profiles, power losses and reverse power flow phenomena of active distribution networks is proposed. Also, the utilization of photovoltaic and battery energy storage systems is evaluated. The proposed methodology is applied to statistically analyse results obtained from annual timeseries power flow calculations in a real 18-bus low-voltage network over a range of operating conditions; the obtained results are quantified using a set of probabilistic indices. The proposed framework can be a useful tool for distribution system operators to identify operational challenges and ensure the optimal exploitation of end-user and network assets.
The evolution of distribution networks to active systems as a consequence of the increased penetration of distributed energy resources and the electrification of traditionally fuel-based activities have changed drastically the landscape of power systems operation promoting the necessity of benchmarking tools for planning studies. Nevertheless, there is a scarcity of such tools that enable the holistic analysis of modern power systems according to the new grid standards. In this paper, a multi-purpose benchmarking testbed for low-voltage active distribution networks is introduced. The testbed comprises a granular residential appliancelevel dataset, a benchmarking framework based on quasi-static simulations, a set of technical indices and a non-intrusive load monitoring tool. A suite of benchmark case studies including overvoltage, undervoltage and line congestion is presented, supported by ancillary trouble-shooting services, such as voltage control and demand response. The proposed testbed can be a useful tool for distribution system operators to evaluate the operating conditions of the grid without violating technical limitations, test new technologies, identify operational challenges, and foresee grid investments.
Net-metering has been introduced as an alternative to the feed-in tariff scheme to encourage consumers to act as prosumers by installing photovoltaics. Originally, net-metering referred mainly to household photovoltaic systems, however, larger prosumers connected to medium-voltage networks are also considered. Scope of this paper is to present a techno-economic assessment methodology to evaluate the viability of net-metering policy in medium-voltage prosumers. Unlike most relevant methods, the proposed methodology combines techno-economic analysis with a quasi-static simulation model incorporating the real-world operational properties of the distribution network, where the medium-voltage prosumers are connected. The analysis focuses on nine university campuses operating under net-metering policy. The impact of several important parameters on the viability of the investment as well as on the optimal size of the system is investigated; among them special emphasis is given on the applicability of the decentralized voltage regulation techniques applied to the prosumer's photovoltaic system.
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