Optimal Scheduling of an Integrated Energy System With Hydrogen‐Blended Natural Gas and Refined Hydrogen Energy Utilization

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 CO 2 emissions. These findings demonstrate the model's effectiveness in achieving multienergy coordination and deep decarbonization.