Modeling of CO2 injection scenarios in carbonate reservoir as carbon capture and utilization storage program in the Jatibarang oil field

Abstract

Carbon dioxide (CO₂) gas injection is one of the carbon capture utilization and storage (CCUS) programs implemented in the Jatibarang oil field, not only for reducing the effects of emissions on the environment but also for increasing oil recovery. CO₂ injection scenarios are simulated herein, considering carbonate reservoirs with a high degree of heterogeneity. By modeling the reservoir, the behavior of the reservoir fluid is observed, and the optimal injection scenario that produces the highest oil recovery is determined. CO₂ injection involves several key parameters, including the injection pattern and injection pressure, which are varied to improve the performance and increase oil recovery. Injection pressures are assessed in the range of 500–3000 psi, and five patterns are considered: staggered drive, line drive, direct line, four spot, and five spot. From the simulations, a staggered drive pattern with an injection pressure of 2500 psi is optimal, reaching a recovery factor of 27.24%. The changes in the oil viscosity and oil saturation distribution before and after CO₂ injection are also obtained.