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dc.contributor.authorAl-Yaseri, Ahmed
dc.contributor.authorYekeen, Nurudeen
dc.contributor.authorAli, Muhammad
dc.contributor.authorPal, Nilanjan
dc.contributor.authorVerma, Amit
dc.contributor.authorAbdulelah, Hesham
dc.contributor.authorHoteit, Hussein
dc.contributor.authorSarmadivaleh, Mohammad
dc.identifier.citationAl-Yaseri, A., Yekeen, N., Ali, M., Pal, N., Verma, A., Abdulelah, H., Hoteit, H., & Sarmadivaleh, M. (2022). Effect of organic acids on CO2-Rock and water-rock interfacial tension: Implications for CO2 geo-storage. Journal of Petroleum Science and Engineering, 110480.
dc.description.abstractA small concentration of organic acid in carbon dioxide (CO2) storage formations and caprocks could significantly alter the wettability of such formations into less water-wet conditions, decreasing the CO2-storage potential and containment security. Recent studies have attempted to infer the influence of the organic acid concentration on the wettability of rock–CO2–brine systems by measuring advancing and receding contact angles. However, no studies have investigated the influence of organic acid contamination on CO2-storage capacities from rock-fluid interfacial tension (IFT) data because solid-brine and solid-CO2 IFT values cannot be experimentally measured. Equilibrium contact angles and rock-fluid IFT datasets were used to evaluate the viability of CO2 storage in storage rocks and caprocks. First, the contact angles of rock in brine-CO2 systems were measured to compute Young's equilibrium contact angles. Subsequently, rock-brine and rock-gas IFT values at CO2 geo-storage conditions were computed via a modified form of Neumann's equation of state. For two storage-rock minerals (quartz and calcite) and one caprock mineral (mica), the results demonstrated high CO2-brine equilibrium contact angles at high pressure (0.1–25 MPa) and increasing concentrations of stearic acid (10−5 to 10−2 mol/L). Rock-brine IFT increased with the increased stearic acid concentration but remained constant with increased pressure. In all conditions, the order of increasing hydrophobicity of the mineral surfaces is calcite > mica > quartz. At 323 K, 25 MPa, and a stearic acid concentration of 10−2 mol/L, quartz became intermediate-wet with a CO2-brine equilibrium contact angle of 89.8°, whereas mica and calcite became CO2-wet with CO2-brine equilibrium contact angles of 117.5° and 136.5°, respectively. This work provides insight into the effects of organic acids inherent in CO2 geo-storage formations and caprocks on rock wettability and rock-fluid interfacial interactions.
dc.publisherElsevier BV
dc.rights© 2022 The Authors. Published by Elsevier B.V. This is an open access article under the CC BY license (
dc.subjectContact angle
dc.subjectOrganic acids
dc.subjectCarbon dioxide geological storage
dc.subjectRock/fluid IFT
dc.titleEffect of organic acids on CO2-rock and water-rock interfacial tension: Implications for CO2 geo-storage
dc.contributor.departmentAli I. Al-Naimi Petroleum Engineering Research Center (ANPERC)
dc.contributor.departmentPhysical Science and Engineering (PSE) Division
dc.contributor.departmentEnergy Resources and Petroleum Engineering Program
dc.identifier.journalJournal of Petroleum Science and Engineering
dc.eprint.versionPublisher's Version/PDF
dc.contributor.institutionCenter of Integrative Petroleum Research (CIPR), College of petroleum Engineering and Geoscience, King Fahd University of Petroleum and Minerals, 31261, Saudi Arabia
dc.contributor.institutionDepartment of Chemical & Petroleum Engineering, Faculty of Engineering, Technology and Built Environment, UCSI University, 56000, Kuala Lumpur, Malaysia
dc.contributor.institutionWestern Australia School of Mines, Minerals, Energy and Chemical Engineering, Curtin University, Kensington 6151, Western Australia, Australia
dc.contributor.institutionSchool of Petroleum Technology (SPT), Pandit Deendayal Petroleum University, Gandhinagar, Gujarat 382426, India
dc.contributor.institutionSchool of Engineering, Edith Cowan University, Joondalup 6027, WA, Australia
dc.contributor.institutionInstitute of Hydrocarbon Recovery, Department of Petroleum Engineering, Universiti Teknologi PETRONAS, Seri Iskandar 32610, Perak, Malaysia
kaust.personAli, Muhammad
kaust.personPal, Nilanjan
kaust.personHoteit, Hussein

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© 2022 The Authors. Published by Elsevier B.V. This is an open access article under the CC BY license (
Except where otherwise noted, this item's license is described as © 2022 The Authors. Published by Elsevier B.V. This is an open access article under the CC BY license (