Organic-rich source rock/H2/brine interactions: Implications for underground hydrogen storage and methane production

Al-Yaseri, Ahmed; Abu-Mahfouz, Israa S.; Yekeen, Nurudeen; Wolff-Boenisch, Domenik

doi:10.1016/j.est.2023.106986

Cited by 14 publications

(6 citation statements)

References 51 publications

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“…Additionally, it is presumed that basalt could reveal high contamination security and storage durability during the phase of H 2 injection. 57 In contrast, θ of H 2 remains approximately 62°until 1500 psi at 25 °C. This demonstrates a weak water-wet behavior of the rock in the presence of H 2 under microbial influence (Fig.…”

Section: Wettability Of Basalt Rock With and Without Microorganism Ef...mentioning

confidence: 98%

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Aftab,

Al‐Yaseri,

Nzila

et al. 2024

Greenhouse Gases

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Hydrogen (H2) fuel is assessed to be a major component of sustainable energy systems in the net‐zero world. However, hydrogen storage is challenging and requires safe and environmentally friendly solutions like H2 geo‐sequestration. This study evaluates the effects of sulphate‐reducing bacteria (SRB) on H2 geological storage potential in the basalt rock. Fourier‐transform infrared spectroscopy (FTIR) findings show the presence of significant components, that is, O‐Si‐O and organic functional groups, that is, aromatics, amine salts, alkane, and cyclohexane in the basalt rock immersed in the nutrient solution without SRB. However, we found that C‐H stretching modes of organics with peaks at 1,465 cm−1 were observed. Consequently, amine salt (N‐H) (850–750 cm−1), solvent impurities (C‐H), and alkane spectrums are components of nutrient solutions and can be results of metabolic microbial activity that can influence on the surface of the basalt rock. Hence, these changes indicate the presence of microbial activity which might affect the surface chemistry of the rock leading to wettability alteration. We observed that the contact angle (θ) of brine‐H2 on the rock surface slightly changed from 500 to 4,000 psi pressure after the effect of bacteria at 50 °C. The wettability changed the surface of the rock from strong water‐wet to weak or intermediate water‐wet condition (i.e., θ < 75°) at 4,000 psi and temperatures 25 and 50 °C after the bacteria effect. The affiliation of brine water reduces on the rock surface with increasing temperatures and pressures, even without microbial influence. Additionally, we investigated interfacial tension and capillary pressure on SRB bacteria treated basalt which is not yet reported in the published work. Interfacial tension (IFT) and Pc of H2 were reduced by 19% and 65%, respectively at 50 °C and 4,000 psi after the bacteria effect. Hence, the above findings could help to answer the key factors of the reservoir rock including wettability, capillary pressure, and interfacial tension to plan a field‐scale H2 geo‐sequestration strategy under the influence of biotic life. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Wettability Of Basalt Rock With and Without Microorganism Ef...mentioning

confidence: 98%

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Aftab,

Al‐Yaseri,

Nzila

et al. 2024

Greenhouse Gases

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“…Ion milling parameters were incident angle 15°, accelerating voltage 5 kV, time 15 min, medium sample rotation, and ±5 mm lateral sample movement. 1,21 This was followed by a low-angle ion polishing step with parameters: incident angle 6°, accelerating voltage 6 kV, time 30 min, medium sample rotation, and ±5 mm lateral sample movement. The surface cleaning procedure was followed similar to our previous work.…”

Section: Materials and Samples Preparationmentioning

confidence: 99%

Subsurface Hydrogen Storage in Limestone Rocks: Evaluation of Geochemical Reactions and Gas Generation Potential

Al-Yaseri,

Fatah,

Alsaif

et al. 2024

Energy Fuels

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Underground hydrogen storage (UHS) in carbonate reservoirs is a suitable solution for safe storage and efficient hydrogen recovery during the cycling process. The uncertainties associated with potential geochemical reactions between hydrogen, rock, and brine may impact the long-term containment of produced hydrogen in carbonate formations. Despite the current interest in studying hydrogen-rock reactions, only limited work is available in the literature. In this study, we experimentally evaluate the reactivity of carbonate rocks to hydrogen and address the potential of gas generation induced by geochemical reactions. Limestone samples are treated with hydrogen under 1500 psi and 75 °C temperature for a duration between 6 and 13 months using simple reaction cells. Scanning electron microscopy (SEM) analysis is performed to examine the potential dissolution/precipitation reactions induced by hydrogen. In contrast, gas chromatography (GC analyzer) analysis and inductively coupled plasma optical emission spectroscopy (ICP-OES) are conducted to detect gas generation and ion precipitation. The experimental results indicate no significant impact of hydrogen treatment on surface morphology and pore structure even after 6 months of treatment, suggesting that abiotic reactions in carbonate rocks are unlikely to occur during the first stages of UHS. Furthermore, in the presence of brine, there are no apparent indications of geochemical reactions occurring between hydrogen and calcite, and no traces of any other gases are detected after 13 months of treatment. Besides, the solutions’ pH remains almost unchanged, with a minor increase in calcium (Ca2+) ions in the solution, which is attributed to the presence of water, not hydrogen reactions. The results of this work promisingly support the utilization of carbonate reservoirs for long-term hydrogen storage.

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“…Ion milling parameters were an incident angle of 15°, accelerating voltage of 5 kV, time of 15 min, medium sample rotation, and ±5 mm lateral sample movement. 49,50 This was followed by a low angle ion polishing step with the following parameters: incident angle of 6°, accelerating voltage of 6 kV, time of 30 min, medium sample rotation, and ±5 mm lateral sample movement.…”

Section: Materials and Sample Preparationmentioning

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

Energy Fuels

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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 .

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Organic-rich source rock/H2/brine interactions: Implications for underground hydrogen storage and methane production

Cited by 14 publications

References 51 publications

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Subsurface Hydrogen Storage in Limestone Rocks: Evaluation of Geochemical Reactions and Gas Generation Potential

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

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Organic-rich source rock/H2/brine interactions: Implications for underground hydrogen storage and methane production

Cited by 14 publications

References 51 publications

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Microbial impact on basalt‐water‐hydrogen system: Insights into wettability, capillary pressure, and interfacial tension for subsurface hydrogen storage

Subsurface Hydrogen Storage in Limestone Rocks: Evaluation of Geochemical Reactions and Gas Generation Potential

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

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