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Optimal Scheduling of an Integrated Energy System With Hydrogen-Blended Natural Gas and Refined Hydrogen Energy Utilization
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DOI：10.1002/ente.202502381.png)
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Abstract
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Driven by the low-carbon transition, hydrogen is vital; however, most existing studies on hydrogen-blended combustion rely on deterministic models with fixed blending ratios, overlooking the benefits of diversified hydrogen allocation. Furthermore, the traditional power-to-gas (P2G) process suffers from excessive energy conversion losses. To address these limitations, this article proposes a low-carbon economic dispatch model for a virtual power plant (VPP). The primary innovation lies in decoupling the traditional P2G process into a bi-level architecture-comprising an upper layer for hydrogen production and a lower layer for diversified utilization. Additionally, liquid-based carbon capture and storage (CCS) and hydrogen storage units are introduced. On this basis, a dynamic hydrogen allocation model based on a multipriority strategy is established. Combined with an reward-penalty tiered carbon trading mechanism, the model coordinately optimizes hydrogen pathways including hydrogen fuel cell (HFC) power generation, hydrogen-blended combustion, methanation, and hydrogen storage. Simulation results show that the P2G–CCS decoupling reduces system costs by 9.73% (337,660 CNY) and carbon emissions by 17.76%. Furthermore, transitioning to variable blending ratios with HFC integration yields an additional 158,000 CNY in savings and a 402.8 tons reduction in CO2 emissions. These findings demonstrate the model's effectiveness in achieving multienergy coordination and deep decarbonization.
Keywords:
hydrogen-blended combustion
hydrogen blending ratio
integrated energy system
power-to-hydrogen
refined hydrogen utilization
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