Techno-Economic Co-Planning of Hybrid Battery and Hydrogen Energy Storage for Renewable-Rich Distribution Networks Under Severe Contingencies

초록

Hybrid battery–hydrogen energy storage (HBHES) systems are emerging as a promising solution for renewable-rich distribution networks, as they combine the fast-response capability of batteries with the long-duration backup capability of hydrogen storage. However, single-shot optimization rarely produces designs that are simultaneously cost-effective, resilient, and electrically feasible under severe contingencies. This paper proposes a techno-economic co-planning framework that jointly determines the siting, sizing, and operating roles of battery and hydrogen subsystems, and iteratively refines candidate designs through feedback-assisted replanning. A mixed-integer linear programing (MILP) planning problem is coupled with nonlinear AC power flow validation, so that electrically weak designs identified after validation are converted into updated capacity requirements for subsequent iterations. A multistate HBHES model is developed to represent the differentiated roles of battery and hydrogen subsystems under both normal and screened N − 1/N − 2 contingency conditions, while composite severity-based contingency screening preserves computational tractability. The framework is demonstrated on the IEEE 123-bus feeder with renewable generation and load profiles representing a renewable-rich operating environment. Among six candidate architectures, the selected B1H2 configuration reduces the screened-state unserved energy from 201.4 to 98.3 MWh (−51.2%), improves the average served ratio under screened N − 1 contingencies from 53.8% to 57.5%, and raises the minimum post-contingency voltage from 0.921 to 0.952 p.u. while eliminating overload and nonconvergence events after three feedback iterations. The comparative analysis reveals that the preferred architecture is not the largest-capacity option (B3H2, 62.1 MWh screened-state unserved energy at 1.93 B KRW/yr) but a moderately expanded hybrid layout (B1H2, 1.39 B KRW/yr) offering the highest compromise score (0.711) and the lowest resilience premium (0.15 B KRW/yr per pp). These results indicate that coordinated battery–hydrogen storage planning, when combined with closed-loop AC validation, provides physically credible and economically interpretable design insight for hybrid energy storage deployment in renewable-rich distribution networks.

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