The interest in modeling the operation of large-scale battery energy storage systems (BESS) for analyzing power grid applications is rising. This is due to the increasing storage capacity installed in power systems for providing ancillary services and supporting nonprogrammable renewable energy sources (RES). BESS numerical models suitable for grid-connected applications must offer a trade-off, keeping a high accuracy even with limited computational effort. Moreover, they are asked to be viable in modeling for real-life equipment, and not just accurate in the simulation of the electrochemical section. The aim of this study is to develop a numerical model for the analysis of the grid-connected BESS operation; the main goal of the proposal is to have a test protocol based on standard equipment and just based on charge/discharge tests, i.e., a procedure viable for a BESS owner without theoretical skills in electrochemistry or lab procedures, and not requiring the ability to disassemble the BESS in order to test each individual component. The BESS model developed is characterized by an experimental campaign. The test procedure itself is framed in the context of this study and adopted for the experimental campaign on a commercial large-scale BESS. Once the model is characterized by the experimental parameters, it undergoes the verification and validation process by testing its accuracy in simulating the provision of frequency regulation. A case study is presented for the sake of presenting a potential application of the model. The procedure developed and validated is replicable in any other facility, due to the low complexity of the proposed experimental set. This could help stakeholders to accurately simulate several layouts of network services.

With the Smart Grid revolution and the increasing interest in renewable distributed sources, house energy consumption will play a significant role in the energy system: the whole energy generation and distribution system performance can be improved by optimizing the house energy management. Beside the energy bill reduction for single users, another advantage can be obtained for the overall system by jointly managing the energy consumption of a set of users, thus reducing their peak absorption. In this paper we propose optimization models which allow to manage every day energy load for both single and multi-users cases, taking into account distributed energy sources and batteries. Computational results, obtained applying models on real life data, are provided and discussed.

The features of the new electricity market with the presence of many different operators lead to a new interest in the congestion management. The changes to the market-clearing point schedules required by the presence of bottlenecks in the electric grid can be strongly reduced if flexible ac transmission system (FACTS) devices are suitably installed in the transmission system with the aim of redistributing real and reactive power flows. Their optimal setting and operation mode can be determined by the use of customized security-constrained optimal power flow (SCOPF) programs. This paper deals with the use of FACTS devices as control variables in a compact and reduced SCOPF formulation, focusing on the definition of their control regions and on a new procedure implemented to find a global solution without sticking on local minima. The application of the new SCOPF procedure to a real system is also presented.

Shortages and poor diversification of generating capacity, high environmental impacts, and low qualities of supply and affordability are common characteristics of the electricity sector in most developing countries (DevCs). Recent cost reductions in the telecommunication sector and some generation technologies, especially renewable-based, with improved economic feasibility have paved the way for new electric infrastructures. This is especially true for emerging economies, as locally dispatched hybrid microgrids introduce flexibility and show the promise of technical and economic advantages. The design and integration of microgrids require detailed assessments to ensure the effective deployment of capital to minimize the risk of stranded assets and capital waste. Microgrids can be considered an affordable option for a rapid response to the electrification challenge, recognizing that, in the longer horizon, a sharing of resources with the bulk electrical power system will remain, technically and economically, advantageous. This article presents a comprehensive review of the approaches commonly adopted for microgrid electrification. A ''real-life'' study case is reported to highlight the operational challenges of a stand-alone microgrid versus a grid-connected system. The need for an improved regulatory framework is presented as the cornerstone problem to be solved to allow an effective integration of microgrids in the national grid.