Objective In the context of the “dual carbon” goals, energy conservation and carbon reduction are essential for national energy security and green transformation. As major energy consumers in oil and gas gathering, transportation, and processing, oilfield joint stations using the traditional “power grid + gas-fired boiler” supply model face significant challenges, including high costs, large emissions, and limited resilience. Therefore, it is urgent to develop a multi-energy complementary system capable of integrating a high share of renewables and providing robust seasonal regulation.
Methods To address the issues of high energy consumption, emission, and resilience risks in oilfield joint stations, a collaborative “wind-solar-hydrogen-storage-load” multi-energy system architecture was proposed. Wind and solar generation replaced purchased electricity, while an “electricity-hydrogen-electricity” closed loop was established through electrolytic hydrogen production, hydrogen storage, and fuel cells. Multi-source heat supply was achieved via combined heat and power units, heat pumps, and heat storage. The system innovatively incorporated stepped carbon trading and dual demand response (price/incentive) into a unified optimization model, which was evaluated across economic, low-carbon, and resilience objectives.
Results Based on mixed-integer linear programming (MILP), four scenarios were analyzed using a joint station in Daqing Oilfield as a case study. The findings were as follows: (1) Compared to the traditional supply mode, the multi-energy complementary system with hydrogen cycling increased energy utilization efficiency by over 30％, reduced annual operating costs by 41.2％, and lowered carbon emission intensity to 2.1 kg/(kW·h). (2) Leveraging stepped carbon trading, total system costs decreased by 16.05％, carbon emissions dropped by 6.74％, and renewable energy consumption exceeded 90％. (3) With superimposed demand response, peak load was reduced by 5.8％, carbon emissions decreased by an additional 1.3％, and carbon trading costs fell by 12.7％, achieving both emission and cost reductions. (4) The hydrogen subsystem acted as a spatio-temporal regulator, storing surplus green electricity during wind and solar generation and supplying power and heat during peak loads or extreme weather. The annual wind and solar curtailment rate was kept below 1％, significantly improving energy supply resilience. Economic analysis indicated that, at current carbon prices and electrolyzer investment levels, the payback period for incremental investment was 5–8 years; if the carbon price dropped below RMB 80/t and electrolyzer costs fell below RMB 2 500/kW, the payback period could be shortened to 4 years.
Conclusion The research establishes a replicable low-carbon transformation pathway for energy supply in oilfield joint stations, supporting quality and efficiency improvements in existing stations with abundant associated gas and stable electric and thermal loads. It also provides an “electricity-heat-hydrogen” collaborative model for microgrid planning in new blocks with high renewable energy penetration.
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