%0 Journal Article
%@ 09204105
%A Al-Yaseri, A.
%A Yekeen, N.
%A Ali, M.
%A Pal, N.
%A Verma, A.
%A Abdulelah, H.
%A Hoteit, H.
%A Sarmadivaleh, M.
%D 2022
%F scholars:16619
%I Elsevier B.V.
%J Journal of Petroleum Science and Engineering
%K 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
%R 10.1016/j.petrol.2022.110480
%T Effect of organic acids on CO2-rock and water-rock interfacial tension: Implications for CO2 geo-storage
%U https://khub.utp.edu.my/scholars/16619/
%V 214
%X 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�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. © 2022 The Authors
%Z cited By 21