Perpustakaan Digital ITB

After primary and secondary recovery, significant oil remains trapped in the reservoir, necessitating enhanced oil recovery (EOR) techniques. This study evaluates multiple chemical flooding scenarios-ASP flooding, slug-stage ASP, SP flooding, and Polymer Preflush followed by Alkaline–Surfactant Drive in Field "X" using reservoir simulation and probabilistic analysis. Sensitivity analysis identified interfacial tension, residual oil saturation, and polymer viscosity as the most influential parameters affecting oil production and recovery factor. Monte Carlo simulation in CMG-CMOST assessed production uncertainty. Results show SP flooding with SC8 formulation achieved the best performance: 17.161% incremental recovery factor and 0.347 MMSTB incremental production. Probabilistic estimates yielded 2.336 MMSTB (P90), 2.41 MMSTB (P50), and 2.46 MMSTB (P10), corresponding to an incremental recovery ranging from 13.77% (P90) to 19.90% (P10), indicating relatively low uncertainty. These findings demonstrate that chemical flooding can effectively enhance oil recovery in Field "X".