Optimization of CO2 Flooding Parameters in Ultra-Low Permeability Oil Reservoirs with High Water Cut
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Abstract
A numerical simulation of CO2 flooding was conducted to determine the impact of production parameters on enhanced oil recovery. Optimizing the CO2 flooding parameters revealed that increasing the CO2 injection rate enhances the oil production rate but also intensifies gas channelling, reduces the oil exchange rate, and poses a risk of fracturing the formation. While an increase in bottomhole pressure may temporarily limit the oil production rate, it is beneficial in the long term as it helps to elevate formation pressure, facilitating CO2 miscibility with reservoir oil to improve stage recovery and oil exchange rate. Bottomhole pressure should be increased as much as possible, ensuring an injection-production balance. An increase in water cut in the block diminishes CO2 flooding effectiveness, leading to lower recovery and oil exchange rate. During CO2 flooding development, oil exchange rate will decline with rising production gas-oil ratio. Therefore, injection wells should be shut in timely to ensure reasonable CO2 injection amounts. Based on these findings, optimal parameters were determined: a CO2 injection rate of 15, 000 m3/d, a production bottomhole pressure of 25 MPa, CO2 injection timing at a block water cut of 60%, and shut-in timing when the production gas-oil ratio reaches 1 000 m3/m3, with a reasonable CO2 injection amount of 92 000 tons. Simulation results using these optimized parameters indicated that after 9 years of CO2 injection, crude oil production from the block increased by 213 000 tons, with a corresponding oil recovery improvement of 27.4%. The cumulative oil exchange rate reached 0.58, while the cumulative storage rate reached 0.67.
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