@article{scholars16619,
         journal = {Journal of Petroleum Science and Engineering},
          volume = {214},
            year = {2022},
           title = {Effect of organic acids on CO2-rock and water-rock interfacial tension: Implications for CO2 geo-storage},
            note = {cited By 21},
       publisher = {Elsevier B.V.},
             doi = {10.1016/j.petrol.2022.110480},
        keywords = {Calcite; Contact angle; Digital storage; Equations of state; Mica; Quartz; Rocks; Wetting, Acid concentrations; Cap rock; Carbon dioxide geological storage; Interfacial tension values; Organic acid concentration; Rock/fluid interfacial tension; Small concentration; Storage potential; Water rocks; Wet conditions, Carbon dioxide, cap rock; carbon dioxide; carbon sequestration; organic acid; underground storage; water-rock interaction},
        abstract = {A 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{\^a}??CO2{\^a}??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{\^a}??25 MPa) and increasing concentrations of stearic acid (10{\^a}??5 to 10{\^a}??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{\^a}??2 mol/L, quartz became intermediate-wet with a CO2-brine equilibrium contact angle of 89.8{\^A}o, whereas mica and calcite became CO2-wet with CO2-brine equilibrium contact angles of 117.5{\^A}o and 136.5{\^A}o, 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. {\^A}{\copyright} 2022 The Authors},
            issn = {09204105},
             url = {https://www.scopus.com/inward/record.uri?eid=2-s2.0-85127494103&doi=10.1016\%2fj.petrol.2022.110480&partnerID=40&md5=132d7d52ebea67a3b693821c8762ec08},
          author = {Al-Yaseri, A. and Yekeen, N. and Ali, M. and Pal, N. and Verma, A. and Abdulelah, H. and Hoteit, H. and Sarmadivaleh, M.}
}