Field-scale impacts of long-term wettability alteration in geological <mml:math xmlns:mml="http://www.w3.org/1998/Math/MathML" altimg="si3.svg"><mml:msub><mml:mtext>CO</mml:mtext><mml:mn>2</mml:mn></mml:msub></mml:math> storage

Kassa, Abay Molla; Gasda, Sarah E.; Landa-Marbán, David; Sandve, Tor Harald; Kumar, Kundan

doi:10.1016/j.ijggc.2021.103556

Cited by 13 publications

(7 citation statements)

References 41 publications

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“…Accordingly, the specific pore surface area increases with decreasing pore radius and narrower pores can adsorb more CO 2 per unit pore volume. As adsorbed CO 2 molecules are more densely packed in narrow pores, the utilization efficiency of the reservoirs and CO 2 storage capacity would increase, although the effect of decreased capillary pressure on trapping CO 2 in the reservoirs needs to be carefully assessed. − …”

Section: Resultsmentioning

confidence: 99%

Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂

Wang,

Samara,

et al. 2023

Energy Fuels

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Wettability change of rocks under high-pressure CO 2 is analyzed for CO 2 storage assessment. Increased water contact angle (measured by the sessile drop method) with CO 2 pressure on three different rocks is related to CO 2 adsorption on the rocks using complementary experimental results of CO 2 adsorption (by gravimetric measurement) and interfacial tension between water and CO 2 (by the pendant drop method). An analysis of free energy change accompanying CO 2 adsorption on the rock surface shows that adsorbed CO 2 could result in moving the CO 2 /water/rock contact line and change the rocks from water-wet to non-water-wet, increasing the potential for CO 2 to spread and displace water. The free energy change has not been studied previously, and the results suggest that CO 2 adsorption on rocks could decrease the capillary force in geological reservoirs and enable injected CO 2 to enter a greater portion of pore space. This would significantly increase the reservoir utilization efficiency and CO 2 storage capacity.

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Section: Resultsmentioning

confidence: 99%

Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂

Wang,

Samara,

et al. 2023

Energy Fuels

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“…The plume migration process involves various complex physical and chemical interactions, including buoyancy, capillary forces, and mineral reactions [108,109]. Over time, the injected CO 2 can migrate both vertically and laterally within the aquifer [110]. While some vertical migration is expected due to buoyancy, lateral migration can be influenced by the geologic properties of the formation, such as permeability and porosity [111].…”

Section: Co 2 Plume Migrationmentioning

confidence: 99%

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Hawez,

Asim

2024

Energies

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Carbon capture and storage (CCS) is a critical technology for mitigating greenhouse gas emissions and combating climate change. CCS involves capturing CO2 emissions from industrial processes and power plants and injecting them deep underground for long-term storage. The success of CCS projects is influenced by various factors, including the regional pressure dissipation effects in subsurface geological formations. The safe and efficient operation of CCS projects depends on maintaining the pressure in the storage formation. Regional pressure dissipation, often resulting from the permeability and geomechanical properties of the storage site, can have significant effects on project integrity. This paper provides a state-of-art of the impact of regional pressure dissipation on CCS projects, highlights its effects, and discusses ongoing investigations in this area based on different case studies. The results corroborate the idea that the Sleipner project has considerable lateral hydraulic connectivity, which is evidenced by pressure increase ranging from <0.1 MPa in case of an uncompartmentalized reservoir to >1 MPa in case of substantial flow barriers. After five years of injection, pore pressures in the water leg of a gas reservoir have increased from 18 MPa to 30 MPa at Salah project, resulting in a 2 cm surface uplift. Furthermore, artificial CO2 injection was simulated numerically for 30 years timespan in the depleted oil reservoir of Jurong, located near the Huangqiao CO2-oil reservoir. The maximum amount of CO2 injected into a single well could reach 5.43 × 106 tons, potentially increasing the formation pressure by up to 9.5 MPa. In conclusion, regional pressure dissipation is a critical factor in the implementation of CCS projects. Its impact can affect project safety, efficiency, and environmental sustainability. Ongoing research and investigations are essential to improve our understanding of this phenomenon and develop strategies to mitigate its effects, ultimately advancing the success of CCS as a climate change mitigation solution.

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“…7 Thus, the economic and technical feasibility of storing CO 2 in deep saline aquifers is anticipated to be more favorable in comparison to other GCS alternatives. 8 T h i s c o n t e n t i s In an aquifer, the density of injected CO 2 is lower than that of the brine present in the aquifer. 7 Consequently, this density difference causes the CO 2 to migrate upward toward the caprock.…”

Section: ■ Introductionmentioning

confidence: 99%

“…Nevertheless, deep saline aquifers have been recommended as a highly attractive option for GCS because of their global accessibility, significant CO 2 storage capacity, and reduced difficulties linked to multiphase flow . Thus, the economic and technical feasibility of storing CO 2 in deep saline aquifers is anticipated to be more favorable in comparison to other GCS alternatives …”

Section: Introductionmentioning

confidence: 99%

Molecular Dynamics Perspective of Illite Wettability in Induced Acidic Conditions during Supercritical and Subcritical Carbon Dioxide Sequestration in Deep Saline Aquifers

Ali,

Negash,

Ridha

et al. 2024

Energy Fuels

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Wettability plays a vital role in evaluating the structural integrity of caprock, typically shale, during the implementation of geological carbon storage (GCS). There have been limited investigations of the wettability of clay minerals, which is common in shale formations, especially concerning carbon dioxide (CO 2 ) injection into saline aquifers. Furthermore, the consequence of CO 2 dissolution in aquifer brine, resulting in acidic conditions, on the wettability of clay−CO 2 −brine systems has not been thoroughly investigated. This study utilizes molecular dynamic modeling to investigate the wettability of the illite−CO 2 −brine system under conditions corresponding to a typical deep saline aquifer. The wettability has been studied through the measurement of the water contact angle, adopting the microscopic wetting technique. In addition, the wettability has been further examined qualitatively by the analysis of relative concentration and radial distribution function. A comparative analysis was also carried out to assess the findings of this study in relation to applicable literature data. The results of this study suggested that illite's wettability shifts from hydrophilic to hydrophobic under induced acidic conditions, irrespective of the brine's salinity and the type of CO 2 injection (either supercritical or subcritical). The water contact angle increased considerably from 44°in nonacidic conditions at 5 MPa and 333 K to 80°in acidic conditions at 10 MPa and 333 K. Furthermore, the competitive microscopic distribution revealed that acidic conditions facilitate the adsorption of CO 2 onto illite. The results also showed that acidic conditions have a greater impact on the wettability alteration under supercritical conditions as opposed to subcritical conditions. In addition to the acidic conditions, the water wettability of the illite−CO 2 −brine system is significantly reduced by elevated pressure, increased brine salinity, and a higher level of organic content in the rock. This work is expected to contribute to a better understanding of the wettability characteristics of caprocks in various geo-storage scenarios.

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Field-scale impacts of long-term wettability alteration in geological CO2 storage

Cited by 13 publications

References 41 publications

Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂

Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Molecular Dynamics Perspective of Illite Wettability in Induced Acidic Conditions during Supercritical and Subcritical Carbon Dioxide Sequestration in Deep Saline Aquifers

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Field-scale impacts of long-term wettability alteration in geological CO2 storage

Cited by 13 publications

References 41 publications

Analysis of the Impact of CO2 Adsorption on Rock Wettability for Geological Storage of CO2

Analysis of the Impact of CO2 Adsorption on Rock Wettability for Geological Storage of CO2

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Molecular Dynamics Perspective of Illite Wettability in Induced Acidic Conditions during Supercritical and Subcritical Carbon Dioxide Sequestration in Deep Saline Aquifers

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Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂

Analysis of the Impact of CO₂ Adsorption on Rock Wettability for Geological Storage of CO₂