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Processes
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Hydrogen–Carbon Storage Technology and Optimization
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Hydrogen–Carbon Storage Technology and Optimization

A special issue of Processes (ISSN 2227-9717). This special issue belongs to the section "Energy Systems".

Deadline for manuscript submissions: 31 July 2026 | Viewed by 2396

Special Issue Editors

Dr. Abubakar Isah

E-Mail Website
Guest Editor
Harold Vance Department of Petroleum Engineerinng, Texas A&M University, College Station, TX 77843, USA
Interests: fluid-rock interaction; CO2 and hydrogen; CO2 mineralization; petrophysics; sustainable energy
Dr. Arshad Raza

E-Mail Website
Guest Editor
Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals (KFUPM), Dhahran 31261, Saudi Arabia
Interests: fluid-rock interaction; CO2 and hydrogen storage

Special Issue Information

Dear Colleagues,

This Special Issue aims to highlight recent advances, innovations, and interdisciplinary research at the intersection of hydrogen (H2) and carbon dioxide (CO2) storage technologies, with a particular emphasis on their optimization for energy transition, climate mitigation, and subsurface sustainability. As global energy systems shift toward low-carbon alternatives, the convergence of H2 energy storage and carbon capture and storage (CCS) presents promising opportunities to enable deep decarbonization, enhance grid resilience, and improve energy security.

This Special Issue will highlight recent developments spanning experimental innovations, simulation modeling, and techno-economic frameworks that advance the safe, efficient, and sustainable storage of H2 and CO2 across a range of geological formations, including saline aquifers, depleted oil and gas reservoirs, and engineered porous media.

We invite original research articles, reviews, and technical notes that explore the scientific, engineering, and economic dimensions of H₂ and CO2 storage in geological, chemical, and engineered systems.

Topics of interest include, but are not limited to, the following:

  • Subsurface hydrogen storage (UHS) mechanisms, materials, and site-specific studies;
  • CO2 storage optimization, including injectivity, containment, and plume monitoring;
  • Reactive transport modeling and geochemical interactions in H2 and CO2 systems;
  • Rock–fluid interactions under H2 and CO2 exposure (e.g., wettability, capillary trapping, mineral alteration);
  • Advanced reservoir simulation techniques for coupled H2–CO2 storage scenarios;
  • Thermal, mechanical, and microbial impacts on long-term storage performance;
  • Geomechanical integrity and risk assessment under cyclic or hybrid storage regimes;
  • Hybrid energy systems, such as H2–CCS integration, or power-to-gas-to-storage;
  • Optimization of injection and withdrawal strategies for seasonal H2 storage;
  • Monitoring technologies and data analytics for subsurface storage surveillance;
  • Techno-economic assessments, life-cycle analysis, and policy considerations for dual storage solutions.

Dr. Abubakar Isah
Dr. Arshad Raza
Guest Editors

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 250 words) can be sent to the Editorial Office for assessment.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Processes is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2400 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • hydrogen storage
  • carbon storage
  • energy transition
  • decarbonization
  • rock–fluid interactions for H2 and CO2
  • injectivity and withdrawal
  • sustainability
  • power-to-gas-to-storage

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Further information on MDPI's Special Issue policies can be found here.

Published Papers (2 papers)

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Research

17 pages, 858 KB  
Article
Integrated PSA Hydrogen Purification, Amine CO2 Capture, and Underground Storage: Mass–Energy Balance and Cost Analysis
by Ersin Üresin
Processes 2026, 14(2), 319; https://doi.org/10.3390/pr14020319 - 16 Jan 2026
Viewed by 1290
Abstract
Although technologies used in non-fossil methane and fossil resources to produce blue hydrogen are relatively mature, a system-integrated approach to reference system (RS)-based purification of H2, CO2 capture and storage, and UHS is relatively unexplored and requires research to fill [...] Read more.
Although technologies used in non-fossil methane and fossil resources to produce blue hydrogen are relatively mature, a system-integrated approach to reference system (RS)-based purification of H2, CO2 capture and storage, and UHS is relatively unexplored and requires research to fill gaps in the literature regarding balanced permutations and geological viability for net-zero requirements. This research proposes a system-integrated process for H2 production through a PSA-based purification technique coupled with amine-based CO2 capture and underground hydrogen storage (UHS). The intellectual novelty of the research is its first quantitative treatment of synergistic effects such as heat recovery and pressure-matching across units. Additionally, a site separation technique is applied, where H2 and CO2 reservoirs are selected based on the permeability of rock formations and fluids. On a research methodology front, a base case of a steam methane reforming process with the production of 99.99% pure H2 at a production rate of 5932 kg/h is modeled and simulated using Aspen Plus™ to create a balanced permutation of mass and energy across units. As per the CO2 capture requirements of this research, a capture of 90% of CO2 is accomplished from the production of 755 t/d CO2 within the model. The compressed CO2 is permanently stored at specifically identified rock strata separated from storage reservoirs of H2 to avoid empirically identified hazards of rock–fluid interaction at high temperatures and pressures. The lean amine cooling of CO2 to 60 °C and elimination of tail-gas recompression simultaneously provides 5.4 MWth of recovered heat. The integrated design achieves a net primary energy penalty of 18% of hydrogen’s LHV, down from ~25% in a standalone configuration. This corresponds to an energy saving of 8–12 MW, or approximately 15–18% of the primary energy demand. The research computes a production cost of H2 of 0.98 USD per kg of H2 within a production atmosphere of a commercialized WGS and non-fossil methane-based production of H2. Additionally, a sensitivity analysis of ±23% of the energy requirements of the reference system shows no marked sensitivity within a production atmosphere of a commercially available WGS process. Full article
(This article belongs to the Special Issue Hydrogen–Carbon Storage Technology and Optimization)
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18 pages, 16402 KB  
Article
Pore-Scale Numerical Simulation of CO2 Miscible Displacement Behavior in Low-Permeability Oil Reservoirs
by Tingting Li, Suling Wang, Jinbo Li, Daobing Wang, Zhiheng Tao and Yue Wu
Processes 2025, 13(12), 4073; https://doi.org/10.3390/pr13124073 - 17 Dec 2025
Cited by 2 | Viewed by 708
Abstract
CO2 miscible flooding provides dual advantages in enhancing oil recovery and facilitating geological sequestration, and has become a key technical approach for developing low-permeability oil reservoirs and carbon emission reduction. The pore-scale flow mechanisms governing CO2 behavior during miscible flooding are [...] Read more.
CO2 miscible flooding provides dual advantages in enhancing oil recovery and facilitating geological sequestration, and has become a key technical approach for developing low-permeability oil reservoirs and carbon emission reduction. The pore-scale flow mechanisms governing CO2 behavior during miscible flooding are crucial for achieving efficient oil recovery and secure geological storage of CO2. In this study, pore-scale two-phase flow simulations of CO2 miscible flooding in porous media are performed using a coupled laminar-flow and diluted-species-transport framework. The model captures the effects of diffusion, concentration distribution, and pore structure on the behavior of CO2 miscible displacement. The results indicate that: (1) during miscible flooding, CO2 preferentially displaces oil in larger pore throats and subsequently invades smaller throats, significantly improving the mobilization of oil trapped in small pores; (2) increasing the injection velocity accelerates the displacement front and improves oil utilization in dead-end and trailing regions, but a “velocity saturation effect” is observed—when the inject velocity exceeds 0.02 m/s, the displacement pattern stabilizes and further gains in ultimate recovery become limited; (3) higher injected CO2 concentration accelerates CO2 accumulation within the pores, enlarges the miscible sweep area, promotes a more uniform concentration field, leads to a smoother displacement front, and reduces high-gradient regions, thereby suppressing local instabilities, and improves displacement efficiency, although its effect on overall recovery remains modest; (4) CO2 dynamic viscosity strongly influences flow stability: low-viscosity conditions promote viscous fingering and severe local bypassing, whereas higher viscosity stabilizes flow but increases injection pressure drop and energy consumption, indicating a necessary trade-off between flow stability and operational efficiency. Full article
(This article belongs to the Special Issue Hydrogen–Carbon Storage Technology and Optimization)
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