Perpustakaan Digital ITB

Natural gas, particularly gas condensate, has a significant role for global energy sources. However, the issue of condensate banking, which hinders gas production, may develop when these reservoirs become depleted. This study investigates the application of CO2 injection to enhance gas recovery and mitigate condensate banking in a depleted gas condensate reservoir. The study simulates various CO2 injection scenarios using the tNavigatorTM to determine the optimum method that achieves highest hydrocarbon recovery and maximizes CO2 sequestration. A reservoir model based on the PUNQ-S3 framework is developed as part of the technique, and several injection scenarios are simulated and their effects on gas production, condensate removal, and CO2 storage are examined. The location of the injection well, the injection rate, and the start time of the CO2 injection are important factors that were examined. The findings show that, in comparison with distant injection wells, CO2 injection close to production wells greatly improves gas recovery and increases CO2 storage capacity. According to the simulation results, there is a significant increase in cumulative gas output and efficient condensate removal; overall gas production and CO2 storage are optimized with nearby injector wells. This study demonstrates that CO2 injection addresses environmental concerns and enhances gas recovery from depleted gas reservoirs while providing a feasible means of sequestering carbon. According to the research, gas condensate reservoirs should incorporate CO2 injection techniques to maximize hydrocarbon recovery and reduce greenhouse gas emissions.