Waterflooding as an incremental oil recovery technique remains the most commonly used method. Although the injected brine type is mainly dependent on its availability, few of its characteristics can be controlled during project design.
Laboratory experiments show that the adjustment of injected brine composition can cause an increase on oil production by wettability alteration. This work objective is to simulate accurately incremental oil recovery and pressure drop in
carbonate cores using a numerical simulator. We use a physically based model that predicts contact angles to predict wettability alteration in a Pre-salt Brazilian Carbonate rock. Our work can be applied to increase reservoir production
lifetime and ultimate oil recovery.
