Effect of CO2 Flooding on the Wettability Evolution of Sand-Stone

Abstract

Wettability is one of the main parameters controlling CO2 injectivity and the movement of CO2 plume during geological CO2 sequestration. Despite significant research efforts, there is still a high uncertainty associated with the wettability of CO2/brine/rock systems and how they evolve with CO2 exposure. This study, therefore, aims to measure the contact angle of sandstone samples with varying clay content before and after laboratory core flooding at different reservoir pressures, of 10 MPa and 15 MPa, and a temperature of 323 K. The samples’ microstructural changes are also assessed to investigate any potential alteration in the samples’ structure due to carbonated water exposure. The results show that the advancing and receding contact angles increased with the increasing pressure for both the Berea and Bandera Gray samples. Moreover, the results indicate that Bandera Gray sandstone has a higher contact angle. The sandstones also turn slightly more hydrophobic after core flooding, indicating that the sandstones become more CO2-wet after CO2 injection. These results suggest that CO2 flooding leads to an increase in the CO2-wettability of sandstone, and thus an increase in vertical CO2 plume migration and solubility trapping, and a reduction in the residual trapping capacity, especially when extrapolated to more prolonged field-scale injection and exposure times.

A Review of Mineral and Rock Wettability Changes Induced by Reaction: Implications for CO2 Storage in Saline Reservoirs

“…However, the mineral content did not change much before and after the reaction. Other mineral-related reactions were not verified in this report, as shown in Table 5 [65].…”

“…Brine 2 was composed of 5 wt% NaCl and 1 wt% KCl. In contrast, after the sandstone flooded by brine 1 at (10 MPa, 15 MPa) and 50 • C for 7 days, it was found that the advancing/receding angle (θ A , θ R ) in the system of CO 2 -brine 2-sandstone was greater and the sandstone even became CO 2 -wet at a higher pressure (15 MPa) at 50 • C [65], as shown in Table 5.…”

“…In principle, chemical reactions promoted sandstone dissolution and precipitation. Kaolinite precipitation was observed by SEM [65]. Sandstone wettability was altered.…”

Simulation study of chemo‐mechanical impacts of CO2injection in morrow b sandstone reservoir

“…Sole reliance on structural trapping could be risky as even a meticulous assessment of caprock integrity can miss some structural flaw. However, by virtue of the non‐wetting nature of CO 2 in the reservoir pore surfaces, capillary pressure among phases of formation fluids instigates saturation hysteresis that traps CO 2 as residual gas 17–20 . The effects of hysteresis are very prominent in processes that involve strong flow reversals, for instance, in a WAG operation 21 .…”

“…However, by virtue of the non-wetting nature of CO 2 in the reservoir pore surfaces, capillary pressure among phases of formation fluids instigates saturation hysteresis that traps CO 2 as residual gas. [17][18][19][20] The effects of hysteresis are very prominent in processes that involve strong flow reversals, for instance, in a WAG operation. 21 Literature has provided several residual gas trapping models that predict the hysteresis effect of CO 2 .…”