Abstract
This paper proposes a multi-objective, multi-period distribution network reconfiguration (DNR) model applied to a real large-scale distribution system. This model aims to minimize the overall operation cost of the system, including power losses and costs associated with overloading lines, transformers, and bus voltage violations. Furthermore, to align the model with practical implementations, we have incorporated considerations for switching costs and the identification of switchable and non-switchable lines. Two case studies are conducted to validate the effectiveness and advantages of the proposed model. A 15-bus case study assesses the feasibility of the model and conducts an in-depth analysis of the impact of DNR on the objective function components under different demand sensitivities. Additionally, an 821-bus case study illustrates how DNR could be implemented in a real-world network. Building on the outcomes of this work, challenges and potential future research directions are discussed, focusing on three key aspects, DNR modeling for real-world large-scale systems, the potential interactions of DNR with other flexibility resources, and the importance of DNR integration within the regulatory framework and electricity market design. Specifically, the interaction between DNR and local flexibility markets is further analyzed by examining its impact on distribution system operator (DSO) regulated revenues and market power mitigation in flexibility markets.
Multi-objective distribution network reconfiguration: application to a real large-scale distribution system
