Pore-scale phenomena in carbon geological storage (Saline aquifers—Mineralization—Depleted oil reservoirs)

• Published in: Frontiers in Energy Research
• Main Authors: Liu, Qi, Benitez, Marcelo D., Xia, Zhao, Santamarina, J. Carlos
• Format: Article in Journal/Newspaper
• Language: unknown
• Published: Frontiers Media SA 2022
• Subjects: Carbonic acid
• Online Access: http://dx.doi.org/10.3389/fenrg.2022.979573; https://www.frontiersin.org/articles/10.3389/fenrg.2022.979573/full

The injection of CO 2 into geological formations triggers inherently coupled thermo-hydro-chemo-mechanical processes. The reservoir pressure and temperature determine the CO 2 density, the CO 2 -water interfacial tension, and the solubility of CO 2 in water (hindered by salts and competing gases). The CO 2 -water interface experiences marked pinning onto mineral surfaces, and contact angles can range from the asymptotic advancing to receding values, in contrast to the single contact angle predicted by Young’s equation. CO 2 dissolves in water to form carbonic acid and the acidified water dissolves minerals; mineral dissolution enhances porosity and permeability, triggers settlement, may couple with advection to form “wormholes”, produces stress changes and may cause block sliding and shear bands. Convective currents can emerge beneath the CO 2 plume and sustain CO 2 and mineral dissolution processes. On the other hand, mineralization is a self-homogenizing process in advective regimes. The crystallization pressure can exceed the tensile capacity of the host rock and create new surfaces or form grain-displacive lenses. Within the rock matrix, coupled reactive-diffusion-precipitation results in periodic precipitation bands. Adequate seal rocks for CO 2 geological storage must be able to sustain the excess capillary pressure in the buoyant CO 2 plume without experiencing open-mode discontinuities or weakening physico-chemical interactions. CO 2 injection into depleted oil reservoirs benefits from time-proven seals; in addition, CO 2 can mobilize residual oil to simultaneously recover additional oil through oil swelling, ganglia destabilization, the reduction in oil viscosity and even miscible displacement. Rapid CO 2 depressurization near the injection well causes cooling under most anticipated reservoir conditions; cooling can trigger hydrate and ice formation, and reduce permeability. In some cases, effective stress changes associated with the injection pressure and cooling thermoelasticity can reactivate ...