CO2 Leakage Behaviors in Typical Caprock-Aquifer System during Geological Storage Process

In this study, a 3D reactive flow simulation model is built to simulate the leakage processes though assumed leakage channels. The geochemical reactions are coupled with fluid flow simulation in this model with consideration of reservoir minerals calcite, kaolinite, and anorthite. As an essential trigger for geochemical reactions, changes in pH value are investigated during and after the CO2 injection process. By comparing CO2 migration with/without geochemical reactions, the influence of geochemical processes on CO2 leakage is illustrated. The leakage behaviors through leakage channels with different permeabilities are evaluated. Influence of reservoir temperature on CO2 leakage is also exhibited. Furthermore, the effects of the distance between the injection well and leakage zone on the leakage potential are studied. The results indicate that the geochemical reactions have impact on the leakage processes, which can decrease the leakage level with the presence of geochemical reactions. The region of low pH enlarges with continuous injection of CO2. Hence, monitoring changes in pH can reflect the migration of CO2, which can provide an alert for CO2 leakage. The occurrence of the leakage phenomenon is postponed with increasing the distance between the CO2 injection well and the leakage channel. However, the leakage level tends to be consistent with injecting more CO2. The CO2 leakage risk can be reduced through the leakage channels with lower permeability. With the presence of higher reservoir temperatures, the leakage risk can be improved. These results can provide references for the application of monitoring methods and prediction of CO2 front associated with geochemical processes.