Wettability of Caprock–H<sub>2</sub>–Water: Insights from Molecular Dynamic Simulations and Sessile-Drop Experiment

Abdel-Azeim, Safwat; Al-Yaseri, Ahmed; Norrman, Kion; Patil, Pramod; Qasim, Abdulaziz; Yousef, Ali

doi:10.1021/acs.energyfuels.3c03198

Cited by 12 publications

(7 citation statements)

References 58 publications

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“…The authors argued that the reported trend in contact angles was caused by the increasing intermolecular quartz-gas interactions with increasing molecular gas density at increased pressure [29]. While this increase in intermolecular interactions would be expected to occur for any mineral, applying the tilted-plate applied to cleaned, pure mica showed no temperature and pressure dependence of the contact angles with a contact angle of zero for all experimental conditions (5-20 MPa, temperature 300-323K, salinity 0-213.000 ppm) [51]. In an approach to explain the contact angle discrepancy in the literature, it was recently postulated that the key determinant for the outcome of any fluid flow study is the type of forces acting under a given experimental condition [34]: When gravitational and capillary forces dominate, as in the case of the tilted plate method, there should be a clear temperature and pressure dependency on the fluid injectivity and recovery, and different gases are expected to show different contact angles and displacement patterns.…”

Section: Relation To Other Work 431 Hydrogenmentioning

confidence: 88%

“…[50] and Abdel-Azeim et al [51] do not. On the other hand, Abdel-Azeim et al [51] suggested that contact angles higher than zero as reported by e.g.…”

Section: Relation To Other Work 431 Hydrogenmentioning

confidence: 96%

“…[50] and Abdel-Azeim et al [51] do not. On the other hand, Abdel-Azeim et al [51] suggested that contact angles higher than zero as reported by e.g. [27][28][29] and apparent contact angle increases with pressure [29] may stem from contamination of organic matter on the rock surfaces.…”

Section: Relation To Other Work 431 Hydrogenmentioning

confidence: 96%

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Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

Thaysen,

Jangda,

Hassanpouryouzband

et al. 2024

Preprint

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To meet global commitments to reach net-zero carbon (C) emissions by 2050, the energy mix must be adjusted to reduce emissions from fossil fuels and transition to low or zero C energy sources. Hydrogen (H2) can support this transition by facilitating increased renewable (zero C) energy use by acting as an energy store to balance supply and demand. Underground H2 storage in porous media is investigated due to its high capacity and economical price. An important unknown in underground porous media H2 storage is the volume of recoverable H2 which is partly controlled by the H2 wettability. We computed receding and advancing contact angles for the H2-brine-Clashach sandstone system at pore fluid pressures of 2-7 MPa and for nitrogen (N2)-brine-Clashach sandstone at 5 MPa, based on X-ray microtomography images of gas displacement and trapping in Clashach sandstone. A centrifuge analysis of the capillary pressure (Pc) at varying water saturations was conducted for N2. The H2 Pc curve was derived from the N2 Pc, the N2 wettability measurements, and existing information on the density differential and the interfacial tensions between brine and H2 and N2, respectively. The results show no change of the H2-brine-Clashach sandstone contact angles within the examined pressure range, with mean receding (drainage) and advancing (imbibition) contact angles of 61°± 24-26° and 58°± 20-22°, respectively, at all pore fluid pressures, indicating a water-wet rock and that increased hydrogen residual trapping at higher pressure was not controlled by wettability. N2-brine-Clashach sandstone receding and advancing contact angles were 66°± 21° and 62°± 24°, respectively. We found H2 Pc of 0.43 MPa at irreducible water saturations of 12.6-14.0%. Our results provide detailed insights into the controls on H2 displacement and capillary trapping as well as crucial input parameters for the modelling and design of H2 storage operations in porous media.

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Section: Relation To Other Work 431 Hydrogenmentioning

confidence: 88%

“…[50] and Abdel-Azeim et al [51] do not. On the other hand, Abdel-Azeim et al [51] suggested that contact angles higher than zero as reported by e.g.…”

Section: Relation To Other Work 431 Hydrogenmentioning

confidence: 96%

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Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

Thaysen,

Jangda,

Hassanpouryouzband

et al. 2024

Preprint

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“…Therefore, it is highly recommended to perform further experimental studies beyond the temperature, pressure, and duration applied in this study. Moreover, employing geochemical modeling techniques such as PHREEQ-C, Molecular Dynamic (MD), and CMG-GEM software could aid in assessing the induced geochemical reactions between injected hydrogen and carbonate minerals over an extended period. ,− These reactions may facilitate the dissolution of sulfate and carbonate minerals, potentially resulting in substantial gas leakage …”

Section: Challenges and Future Prospectsmentioning

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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“…Carbon dioxide subsurface sequestration has been widely studied as a promising solution for reducing greenhouse gas emissions and assisting the energy transition from fossil fuels into clean energy sources . In recent years, studies have been conducted to evaluate various types of CO 2 storage such as geological storage of CO 2 in the forms of hydrates − and underlying depleted oil and gas reservoirs with caprock seals. − Understanding the role of sealing caprocks during carbon capture and storage (CCS) application is crucial to ensure the safe containment of the stored CO 2 . , Due to the low density of CO 2 compared to formation brine, CO 2 tends to migrate upward and penetrate through the sealing layers resulting in CO 2 breakthrough. − Shale caprocks play a major role in a petroleum reservoir system, as they are considered effective sealing layers due to their ultralow permeability and high capillary pressures, which can either prevent CO 2 leakage or significantly reduce CO 2 migration rate. Previous studies reported that CO 2 /brine injection can be beneficial for enhanced oil recovery (EOR) applications, as CO 2 can generate complex fractures with high conductivity, prevent formation damage, reduce the amount of produced wastewater, , and provide better displacement of the natural preadsorbed methane during fracturing. , However, during storage, CO 2 can cause major changes in the petrophysical and chemical properties of rocks and affect the storage capacity. − Considerable accomplishments were achieved in studying the sealing integrity of shales during CO 2 storage. − Seal integrity of shales is mainly affected by the geochemical interactions between CO 2 –brine and shale mineralogy, which can alter the wetting behavior, pore structure, and surface chemistry.…”

Section: Introductionmentioning

confidence: 99%

Surface Chemistry and Chemical Structure of Shale Caprocks Exposed to CO₂: Implication for Sealing Integrity

Fatah,

Norrman,

Al-Yaseri

2024

Energy Fuels

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Subsurface carbon dioxide storage is being widely studied as an effective solution for minimizing greenhouse gas emissions. Shale caprocks are regarded as effective seals during CO 2 storage that provide safe CO 2 conditions and prevent possible CO 2 leakage. However, the geochemical CO 2 /shale reactions remain a key challenge that can affect the sealing integrity. Despite the extensive studies on CO 2 /shale geochemical reactions, the impact of CO 2 on the surface chemistry and chemical structure of shale caprocks has rarely been addressed. In this work, we provide a detailed experimental analysis of the impact of CO 2 exposure on the chemical structure of shale caprocks and the potential implications for seal integrity. A real reservoir subsurface shale sample was treated with CO 2 at 75 °C at 1400 psi for 35 days and examined using chemical characterization techniques X-ray photoelectron spectroscopy and time-of-flight secondary ion mass spectrometry. Based on the XPS results, no detectable reaction between CO 2 and the shale surface was observed, and the composition of the carbon functionalities appeared to be unaffected by the CO 2 exposure. The elemental composition showed insignificant changes, and no major chemical alterations occurred on the surface as a result of CO 2 exposure. TOF-SIMS analysis revealed that the saturated hydrocarbons accumulated on the surface, which consequently reduces the occurrence of inorganic and aromatic components since these get partly covered by the saturated hydrocarbons. This process is presumably a result of the experimental conditions (75 °C, 1400 psi, 35 days) rather than the presence of CO 2 . No direct evidence was found for any reaction involving CO 2 . This suggests a high sealing integrity of shales with low risks of CO 2 leakage. Future work can build on the findings in this work and consider it as a suitable experimental framework to assist in evaluating the reactivity of CO 2 to shale caprocks.

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Wettability of Caprock–H₂–Water: Insights from Molecular Dynamic Simulations and Sessile-Drop Experiment

Cited by 12 publications

References 58 publications

Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

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

Surface Chemistry and Chemical Structure of Shale Caprocks Exposed to CO₂: Implication for Sealing Integrity

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Wettability of Caprock–H2–Water: Insights from Molecular Dynamic Simulations and Sessile-Drop Experiment

Cited by 12 publications

References 58 publications

Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

Hydrogen wettability and capillary pressure in Clashach sandstone for underground hydrogen storage

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

Surface Chemistry and Chemical Structure of Shale Caprocks Exposed to CO2: Implication for Sealing Integrity

Contact Info

Product

Resources

About

Wettability of Caprock–H₂–Water: Insights from Molecular Dynamic Simulations and Sessile-Drop Experiment

Surface Chemistry and Chemical Structure of Shale Caprocks Exposed to CO₂: Implication for Sealing Integrity