Hydrogen and carbon dioxide kinetic adsorption and diffusion behavior into organic-rich shale: Implications of mineralogy and organic content

Authors

Amer Alanazi
Hussein Abid, Edith Cowan UniversityFollow
Saleh A. Bawazeer
Norah Aljeban
Israa S. Abu-Mahfouz
Alireza Keshavarz, Edith Cowan UniversityFollow
Stefan Iglauer, Edith Cowan UniversityFollow
Hussein Hoteit

Author Identifier

Hussein Abid: https://orcid.org/0000-0003-3368-371X

Alireza Keshavarz: https://orcid.org/0000-0002-8091-961X

Stefan Iglauer: https://orcid.org/0000-0002-8080-1590

Document Type

Journal Article

Publication Title

Energy and Fuels

Volume

38

Issue

23

First Page

23009

Last Page

23024

Publisher

ACS

School

School of Engineering

RAS ID

77377

Comments

Alanazi, A., Abid, H., Bawazeer, S. A., Aljeban, N., Abu-Mahfouz, I. S., Keshavarz, A., ... & Hoteit, H. (2024). Hydrogen and carbon dioxide kinetic adsorption and diffusion behavior into organic-rich shale: Implications of mineralogy and organic content. Energy & Fuels, 38(23), 23009-23024. https://doi.org/10.1021/acs.energyfuels.4c04405

Abstract

Geological storage of hydrogen (GSH) is a pivotal technology for advancing an industrial-scale hydrogen economy. Shale formations, known for their impermeable sealing and abundance, offer promising potential for secure GSH applications. However, the complex mineralogy and organic content of shale necessitate a detailed investigation. This study examines the potential of organic-rich shale samples from Jordanian oil source rocks for hydrogen (H2) storage and carbon dioxide (CO2) sequestration. Adsorption kinetics were measured at two different temperatures (303 and 333 K) and pressures (15 and 45 bar) using a volumetric experimental approach. Common mathematical models were applied to evaluate the adsorption data and calculate the diffusion coefficients. The results indicate that H2 adsorption on shale surfaces occurs at significantly lower rates than CO2, with H2 being adsorbed approximately 2-7 times less as pressure increases from 0.1 to 68 bar. Both gases show increased adsorption with rising pressure and decreased adsorption at higher temperatures. The superior adsorption capacity of CO2 highlights its potential as a cushion gas, facilitating the preferential in situ separation of H2 during extraction processes. This study also uses two distinct shale samples to explore the impact of varying total organic carbon (TOC) and calcite contents on gas adsorption capacity. The diffusion coefficients for H2 were found to be approximately 10 times higher than those for CO2, offering critical insights into the dynamics of H2 storage and retrieval in geological formations. The findings provide insights into H2 storage and retrieval in geological formations and enhance the feasibility of utilizing shale formations as reliable seals or storage media for H2

DOI

10.1021/acs.energyfuels.4c04405

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This work is licensed under a Creative Commons Attribution 4.0 License.