Common direct current (DC) bus integration of DC fast chargers, grid‐scale energy storage, and solar photovoltaic: New York City case study

• Published in: IET smart grid 2024-06, Vol.7 (3), p.351-365
• Main Authors: Kamaludeen, Mohamed K., Zafar, Kirn, Esa, Yusef, Mohamed, Ahmed Ali A., Nyemah, Elihu, Salmeron, Lizzette, Odie, Simon
• Format: Article
• Language: English
• Subjects: distribution networks; energy demand, storage, and EVs
• ISSN: 2515-2947; 2515-2947
• DOI: 10.1049/stg2.12154

The mass deployment of distributed energy resources (DERs) to achieve clean energy objectives has become a major goal across several states in the U.S. However, the viability and reality of achieving these goals in dense urban areas, such as New York City, are challenged by several ‘Techno‐Economic’ barriers associated with available land space and the number of AC/direct current (DC) conversion stages that requires multiple electrical balance of plant (BOP) equipment for pairing/interconnecting these resources to the grid. The fundamental issue of interconnection is addressed by assessing the use of a common DC bus in a one‐of‐a‐kind configuration (to pair grid‐connected energy storage, photovoltaic, and electric vehicle chargers (EVC) systems) and reduce the number of BOP equipment needed for deployment. Building on similar work that has touched on distribution‐level DC interconnection, this paper will also address the intricacies of interconnecting third‐party and Utility DERs to a DC‐based point of common coupling. It will examine the requisite site controller configuration (control architecture) and requirements to coordinate the energy storage system's use between managing Utility and Third‐Party EVC demand while prioritising dispatch. The result shows that the DC‐coupled system is technologically feasible and hierarchical control architecture is recommended to maintain stability during various use cases proposed. This will inform a lab demonstration of this system that aims to test DC integration of the DERs with recommendations for the microgrid (MG) controllers and reduction in the BOP equipment. These learnings will then be applied to practical grid‐scale deployment of the systems at Con Edison's Cedar Street Substation. This system, if proven successful, has the potential to change the way community distributed generation and MGs are interconnected to the Utility System. The fundamental issue of interconnection is addressed by reassessing the use of a common direct current bus in a one‐of‐a‐kind configuration pairing grid‐connected energy storage, photovoltaic, and electric vehicle chargers systems.