Influence of stearic acid and alumina nanofluid on CO2 wettability of calcite substrates: Implications for CO2 geological storage in carbonate reservoirs

Arain, Zain-UL-Abedin; Aftab, Adnan; Ali, Muhammad; M.M., Altaf,; Sarmadivaleh, Mohammad

doi:10.1016/j.jcis.2023.05.066

Cited by 20 publications

(2 citation statements)

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“…They found that nanoparticles could be denser with increasing exposure time and concentration, while, beyond a certain value, the effect of exposure time and concentration would be negligible. Likewise, Arain et al found that the wettability alteration efficiency and NF concentration are greatly linked and the optimum concentration for changing the wettability was 0.25 wt %. Their results also indicated that wettability alteration efficiency may be impaired for the NF with concentrations greater than 0.25 wt %.…”

Section: Resultsmentioning

confidence: 96%

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

et al. 2023

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The surface wettability and morphology of shale may both be modified by SiO 2 nanofluid (SNF), directly influencing the capillary force and CO 2 geo-storage. However, the literature requires more information and studies with respect to nanoparticles' effect on shale surface at reservoir conditions of high pressure and temperature. Here, we investigate the stability of nanoparticle layers formed by SNF on Longmaxi (marine) and Yanchang (continental) shale in ScCO 2 and nanoparticles' efficiency of wettability reversal at different nanofluid aging times and concentrations. Besides, low-pressure nitrogen gas adsorption (LP-NA) was performed to evaluate the effect of nanoparticles on shale pore structures after ScCO 2 exposure. Results indicate that the nanoparticle structure could be stable in ScCO 2 and render the wettability of shale samples to be more hydrophilic, while the quartz-rich Longmaxi shale surface shows a denser nanostructure than the clay-rich Yanchang shale surface does and presents a stronger water wettability. More micropores are transformed into mesopores or macropores for ScCO 2and SNF-treated Longmaxi samples than solely ScCO 2 samples, but the pore structure parameters show trivial alteration in Yanchang samples after SNF treatment. The difference in the capillary force recovery between Longmaxi (recovered by 660.5%) and Yanchang (recovered by 500.6%) shale implies that silica nanofluid may be more suitable for Longmaxi formation in the CGS application.

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Section: Resultsmentioning

confidence: 96%

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

et al. 2023

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“…Prior investigations have utilized porous and permeable rock samples to examine the impact of cleaning on wettability. While others experimented on rock/gas//brine systems (see refs ,,− ), employing techniques such as the contact angle and the Amott index. Table presents a summary of rock surface preparation and cleaning methods prior to contact angle measurements.…”

Section: Introductionmentioning

confidence: 99%

Influence of Surface Cleaning on the Wettability of Quartz/Oil/Brine Systems

et al. 2023

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Wettability is the measure of a liquid’s ability to adhere to or spread on a solid surface. The contact angle is a quantitative measure of wettability but can be affected by surface cleaning processes. The systematic investigation of wettability modification caused by surface cleaning is lacking. This study employs pure quartz substrates to examine the effect of rock surface cleaning on the wettability of rock/oil/brine systems. The nonporous substrates were polished and aged in solvents and formation fluids before being cleaned with different agents. Wettability was assessed using the contact angle technique at elevated pressures (0.1–50 MPa) and temperatures (353 K). The study also examined adsorption, surface morphology, roughness, and changes in rock strength using scanning electron microscopy (SEM), scanning probe microscopy (SPM), and nanoindentation. Fourier transform infrared spectroscopy (FTIR) and X-ray fluorescence (XRF) analyses were also performed before and after exposure to fluids. The results showed that interactions between quartz–brine, quartz–oil, and quartz–solvents significantly influence the wetting behavior. Our findings suggest that cleaning agents may not completely remove all adsorbed salts and crude oil components from the rock surfaces and may also adsorb onto the surfaces themselves, altering wettability. The presence of oxygen-containing groups, such as hydroxyl groups (O–H), increased the surface energy and promoted hydrophilic behavior, making the surface more water-wet. While the presence of nonpolar functional groups, like alkyl groups (−CH3), aromatic C–H, and methylene (CH2) groups, makes the surface more oil-wet. Interestingly, an increase in pressure has little or no effect on the contact angle of the n-decane/brine/rock system, but exposure to fluids did modify rock surface roughness and strength. Overall, this study provides valuable insights into rock surface cleaning and its influence on the wettability of rock/oil/brine systems. Understanding these interactions is crucial for various applications in the oil and gas industry.

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Comprehensive review of experimental studies, numerical modeling, leakage risk assessment, monitoring, and control in geological storage of carbon dioxide: Implications for effective CO₂ deployment strategies

Sori,

Moghaddas,

Abedpour

2024

Greenhouse Gases

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The geological storage of carbon dioxide (CO2) represents a promising strategy for mitigating climate change by securely sequestering CO2 emissions. This review article aims to provide a comprehensive overview of the current state of research and development in the field of geological carbon dioxide (CO2) sequestration. We systematically examined a wide range of recent literature, focusing on advancements in numerical simulations, experimental studies, risk assessments, and monitoring techniques related to CO2 sequestration. Literature was selected based on relevance, recency, and contribution to the understanding of key challenges and solutions in CO2 storage, with sources spanning peer‐reviewed journals, conference proceedings, and significant technical reports. Our review highlights several key themes: the integration of machine learning and advanced numerical models in predicting CO2 behavior in subsurface formations; innovative experimental approaches to understanding the physicochemical interactions between CO2, brine, and geological substrates; and the development of robust risk assessment frameworks to address potential leakage and induced seismicity. We also explore recent advancements in monitoring technologies, emphasizing their critical role in ensuring the long‐term integrity and effectiveness of CO2 storage sites. Overall, this review synthesizes the latest findings and identifies gaps in current knowledge, providing a roadmap for future research directions. Our aim is to enhance the understanding of CO2 sequestration processes, support the development of safer and more efficient storage methods, and contribute to the global effort in mitigating climate change through effective carbon management strategies. © 2024 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Influence of stearic acid and alumina nanofluid on CO2 wettability of calcite substrates: Implications for CO2 geological storage in carbonate reservoirs

Cited by 20 publications

References 88 publications

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

Influence of Surface Cleaning on the Wettability of Quartz/Oil/Brine Systems

Comprehensive review of experimental studies, numerical modeling, leakage risk assessment, monitoring, and control in geological storage of carbon dioxide: Implications for effective CO₂ deployment strategies

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Influence of stearic acid and alumina nanofluid on CO2 wettability of calcite substrates: Implications for CO2 geological storage in carbonate reservoirs

Cited by 20 publications

References 88 publications

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO2 Exposure: Implications for CO2 Sequestration

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO2 Exposure: Implications for CO2 Sequestration

Influence of Surface Cleaning on the Wettability of Quartz/Oil/Brine Systems

Comprehensive review of experimental studies, numerical modeling, leakage risk assessment, monitoring, and control in geological storage of carbon dioxide: Implications for effective CO2 deployment strategies

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Product

Resources

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Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

Investigation on Capillary Force Recovery of Nanoparticle-Coated Shale after Supercritical CO₂ Exposure: Implications for CO₂ Sequestration

Comprehensive review of experimental studies, numerical modeling, leakage risk assessment, monitoring, and control in geological storage of carbon dioxide: Implications for effective CO₂ deployment strategies