Hydrogen, carbon dioxide, and methane adsorption potential on Jordanian organic-rich source rocks: Implications for underground H2 storage and retrieval

Underground hydrogen storage (UHS) is a promising solution to meet the increase in energy supply and demand while supporting the energy transition to net-zero carbon. The successful implementation of UHS requires careful assessment of several scientific aspects, among them evaluating the cement stability and wellbore integrity to ensure safe storage and production of hydrogen. Few studies have evaluated the geochemical reactivity of cement to hydrogen; however, more studies are needed to explore the role of hydrogen adsorption and diffusivity behavior with cement and address the associated wellbore integrity issues. This minireview presents the state-of-the-art advancement in evaluating the impact of hydrogen on cement wellbore stability from various aspects, including hydrogen/ cement interactions, hydrogen adsorption and diffusivity, current methodologies, experimental setups, and the role of cement additives and cushion gases. This minireview provides a general comparison between UHS and other gas storage applications and mainly aims to bridge the knowledge gap by providing insights for practical implementations, challenges, and future directions relevant to wellbore integrity. Although most of the reviewed studies reported a low impact of hydrogen injection on cement stability, the successful implementation of UHS requires further assessment as various technical and non-technical factors and mechanisms are involved. Systematic scientific studies should be performed in the future, which will assist in overcoming the existing challenges and reducing the uncertainty associated with wellbore integrity during UHS.

Section: Hydrogen Diffusivity and Adsorptionmentioning

confidence: 99%

Section: Hydrogen Diffusivity and Adsorptionmentioning

confidence: 99%

Section: Cement Reactivity With Hydrogen Injectionmentioning

confidence: 99%

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Hydrogen Impact on Cement Integrity during Underground Hydrogen Storage: A Minireview and Future Outlook

Fatah,

Al Ramadan,

Al-Yaseri

2024

“…Similarly, researchers were only able to measure H 2 /brine interfacial tension (IFT) in the laboratory; rock/gas and rock/water interfacial tensions were evaluated through empirical correlations. ,− Results generally showed that the interfacial tension between the rock and gases (CO 2 , CH 4 , and H 2 ) reduced, whereas contact angles increased with pressure and the presence of organic acid, but IFT increased whereas contact angles reduced with increasing nanofluid (nanosilica and nanoalumina) concentration and temperature. − , …”

Section: Introductionmentioning

confidence: 99%

Snap-Off Effects and High Hydrogen Residual Trapping: Implications for Underground Hydrogen Storage in Sandstone Aquifer

Al-Yaseri,

Yekeen,

Al-Mukainah

et al. 2024

Hydrogen (H 2 ) is a promising clean fuel that could replace fossil fuels for the actualization of the net zero carbon energy transition. Underground hydrogen storage (UHS) in sandstone formations is an essential component of the hydrogen economy value chain for achieving large-scale H 2 storage. In this study, snap-off effects and impacts of high hydrogen residual trapping on the viability of UHS in a Gosford sandstone formation were assessed from initial and residual H 2 saturations in the miniature core plugs. The flooded cores were imaged with X-ray microcomputed tomography (μCT) to identify the fluid (brine and H 2 ) distributions in the pore spaces. Results showed the presence of large interconnected stable H 2 clusters after the drainage process, with an initial H 2 saturation of almost 53%, suggesting that hydrogen will occupy more than half of the pore volume during storage. However, several disconnected H 2 ganglia and the snapped-off of H 2 droplets from the pore throats were noticed after the imbibition stage with almost 44% residual H 2 saturations. Such highly residually trapped H 2 in the strongly water-wet Gosford sandstone will be difficult to mobilize, resulting in the possible withdrawal of just 9% stored H 2 . The study suggests that the water-wet system could produce high H 2 residual saturations, which is unfavorable for hydrogen withdrawal and extraction at the peak energy demand period due to disconnection and trapping of the nonwetting phase.

“…Few studies reported that the presence of clay and carbonate minerals caused increases of the pore volume after CO 2 treatment in organic-rich shales. − However, the role of the TOC content on shale/CO 2 interactions requires further research, and there is a lack of understanding in terms of how shale TOC impacts shale/CO 2 interactions. A recent study reported adsorption measurements for H 2 , CO 2 , and CH 4 gases on organic-rich carbonate-rich Jordanian source rock samples (TOC = 13–18%), indicating high adsorption for CO 2 for high-TOC samples. Moreover, the high calcite contents with hydroxyl groups in the samples significantly improved the CO 2 adsorption.…”

Section: Introductionmentioning

confidence: 99%

Geochemical Reactions of High Total Organic Carbon Oil Shale during CO₂ Treatment Relevant to Subsurface Carbon Storage

Fatah,

Amao,

Abu-Mahfouz

et al. 2023

Subsurface carbon dioxide (CO 2 ) storage is being widely studied as a suitable solution for reducing greenhouse emissions. Shales are regarded as effective storage rocks and caprock seals of stored CO 2 ; however, the induced CO 2 /shale interactions remain a key challenge that can affect storage and sealing behaviors. Despite the current devotion directed toward understanding the CO 2 /shale geochemical interactions, only limited work is available on the reactivity of CO 2 to shale rocks with high total organic carbon (TOC) contents. In this work, we experimentally investigate the CO 2 /rock geochemical reactions for high-TOC shales and address the impact on the surface morphology and storage potential. A high-TOC shale sample (14.6 wt %) was treated with CO 2 at 75 °C and 1400 psi for 60 days, and various analytical methods, including X-ray diffraction, TOC analysis, scanning electron microscopy, and energy-dispersive X-ray analysis, were performed. The results indicate a minor alteration in mineral composition after CO 2 treatment, suggesting that mineral dissolution/precipitation induced by CO 2 was very low. The dissolution behavior of calcite indicates that carbonate solubility in shales in the presence of CO 2 is likely to occur, which in the long term can provide an efficient trapping mechanism through mineralization. The contents and distribution of organic matter on the shale surface did not exhibit a significant change after CO 2 treatment, suggesting that decomposition/oxidation of organic matter was not sufficient during the treatment duration. We observed only minor changes in the pore distribution of the volume after CO 2 treatment, indicating that neither pore expansion nor shrinkage occurred. The obtained results confirm the stability and suitability of high-TOC shales for CO 2 subsurface storage applications under the experimental conditions. Future works can build on the obtained results of this experimental work to assist in the understanding of the nature of shale reactivity to CO 2 .