Perpustakaan Digital ITB

The global oil demand is increasing due to economic integration, encouraging petroleum engineers to focus on recovering hydrocarbons and expanding production. A strategic plan for recovering oil is needed, including primary, secondary, and tertiary recovery methods, with chemical EOR being the most promising method. The study focuses on sulfate concentrations, salinity, and flow rate changes, assessing oil recovery factors on surfactant performance. The author developed a comprehensive methodology for investigating surfactant flooding, focusing on sulfate ions impact on brine composition and optimal injection production rate. The methodology includes a literature review, laboratory study, and reservoir simulation using CMG STARS 2021. The recovery factor in Field X increases with injection/production rate ratios, with optimal ratios between 1.0 and 1.5. Low-salinity surfactant alters rock wettability, resulting in water saturation shifts from 44% to 62%. Surfactant injection leads to greater oil recovery than waterflooding. The calculation shows that a 100 bbl/day injection rate at waterflood can achieve a maximum cumulative oil volume of 551,237 bbl in Field X. A modification of the valence charge of the anion does not affect the interfacial tension (IFT) in the case of Na?SO?. Surfactant injection reduces water cut and oil saturation, increasing cumulative oil volume. The maximum recovery factor achieved through surfactant injection was 35.04% of OOIP and following water flooding.