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Abstract Global hydrogen production contributes significantly to carbon dioxide emissions due to reliance on fossil fuels. This study aims to integrate and model various upstream and downstream processes to facilitate concurrent hydrogen production, underground storage, CO2 utilization, and electricity generation. The first part of this paper focuses on modeling gasification and CO2 capture processes, supplemented by an economic analysis to estimate critical capital and operating costs for design, scale-up, and integration considerations. The second part of this work shows how CO2-plume geothermal systems and power generation plants can complement gasification and CO2 capture processes to create a sustainable energy system. Key findings reveal a H2/VR ratio is 0. 24 % wt/wt with a CO2 intensity is 3 % wt/wt. The CO-2 capture process achieves a capture rate of 97%, with an initial CO2 flow rate of 582. 0 kg/s and a captured CO2 flow rate of 565. 8 kg/s. Additionally, the levelized costs of H2, with and without carbon capture, are determined as 1. 795 /kg and 1. 684 /kg, respectively. The CO2-plume geothermal model demonstrates varied outcomes, with the 1000 md scenario exhibiting the lowest CO2 sequestration due to its high average CO2 flow rate, while the 25 md scenario produces the most water owing to low permeability values. Notably, the 250 md and 1000 md scenarios achieve the highest and second-highest average power output, attributed to high CO2 flow rate, low water cut, and prolonged maintenance of CO2 in a supercritical state. This research provides valuable economic and technical insights that support the transition towards a low-carbon hydrogen future. The findings pave the way for more sustainable and efficient energy solutions.
Altowilib et al. (Mon,) studied this question.