The combined effects of the minimum miscibility pressure and injection rate variations on recovery of co2 flooding in sandstone reservoir

Abstract One of the most effective enhanced oil recovery techniques is carbon dioxide (CO 2 ) flooding. It because its high rate and associated advantage on environment. CO flooding has been broadly used commercially proven. Depending reservoir operational conditions, it can be implemented either in immiscible or miscible modes. Determining injection mode depends minimum miscibility pressure (MMP). The conventional ways determining MMP (slim-tube experiments, supercritical extractor, etc.) are costly time-consuming. A simulation approach deployed to determine a synthetic model using one-dimension compositional slim-tube ECLIPSE300. was also determined group method data handling (GMDH) other existing correlations. by ~ 4176 psia. Comparing MMPs correlations simulation, correlation Maklavani et al. (Braz J Pet, 2010) accurate with mean absolute percentage error (MAPE) 0.79%. GDMH Firoozabadi Khalid had MAPEs 4.96% 6.06%, respectively. GMDH introduced this study not as . could improved, machine learning models improved training prediction estimate more accurately. based literature investigate effect impact investigated scenarios. varied each scenario optimum rate. However, scenarios rates for both were compared waterflood scenario. 2800 2200 Mscf/day, efficiencies 48% 46%, In study, proved recovery. considering difference difficulty achieving miscibility, proves feasible option improving