Perpustakaan Digital ITB

This research examines the efficacy of surfactant flooding in improving oil recovery from a high-permeability reservoir containing light, waxy crude oil. A core sample was chosen for laboratory coreflood experiments to assess the efficacy of surfactant injection under controlled conditions. The data obtained were utilized to construct a core-scale simulation model in a commercial reservoir simulator, which was then calibrated via history matching. The validated core model was subsequently upscaled to a megacore and ultimately to a full-field dynamic model to evaluate large-scale implementation. Surfactant flooding scenarios were assessed utilizing a seven-spot injection pattern with three distinct pore volume (PV) injection sizes: 0.1 PV, 0.3 PV, and 0.5 PV. Waterflooding was initially simulated over a 20-year period to determine a baseline recovery, which stabilized at 10.48% after 10 years. Surfactant injection was administered over a period of six months. The final recovery factors were 16.50% for 0.1 PV, 16.66% for 0.3 PV, and 16.66% for 0.5 PV. The findings indicate that augmenting slug size beyond 0.3 PV does not lead to a significant enhancement in recovery. This study highlights the significance of optimizing injection volume in the development of surfactant-based enhanced oil recovery strategies.