Perpustakaan Digital ITB

Surfactant flooding has emerged as a promising Chemical Enhanced Oil Recovery (CEOR) method, particularly in challenging low-permeability reservoirs where conventional waterflooding yields limited recovery. This study presents an integrated core-to-field simulation framework to evaluate the technical feasibility of surfactant injection in a low permeability with light waxy oil. A core flooding experiment was first conducted using a 2 wt% surfactant solution to quantify incremental oil recovery in controlled laboratory conditions. The results were history matched in commercial reservoir simulator through a vertical core model, with calibration on relative permeability and surfactant parameters. The validated model was then upscaled to a megacore and field-scale configuration, maintaining consistency in flow behavior and recovery trends across scales. A sensitivity analysis was performed on surfactant slug size using pore volume injection (PVI) scenarios of 0.1, 0.3, 0.5, and 0.7 PV under a five-spot injection pattern. Results indicate that oil recovery improves with larger slug sizes, but incremental gains diminish significantly beyond 0.5 PV. The findings suggest that 0.5 PV provides an optimal balance between recovery efficiency and chemical usage. This study demonstrates the importance of integrating core flooding, numerical simulation, and pore volume optimization for effective CEOR design in low-permeability reservoirs.