Predicting oil recovery through CO2 flooding simulation using methods of continuous and water alternating gas

Abstract

In this study, CO2 Flooding simulation models were used to predict oil recovery. The models were previously validated by laboratory experiments of continuous injection and water Alternating Gas (CO2) injection for miscible condition. Sensitivity test was performed to attain the effect of injection rate parameters. The simulation experiments indicated that the optimal performance for both methods obtained at injection rate of 0.09 cuft/day. The scenarios of continuous CO2 injection showed that the maximum recovery factor was 21.1%. While the maximum recovery factor of the scenarios of water alternating gas was 37.9%. Based on the results of the whole scenarios used, Walter Alternating Gas flooding resulted in more effective recovery factor than Continuous CO2 Flooding, within the range of injection rate studied.