A New Approach to 3D Reservoir Simulation: Effect of Interfacial Tension on Improving Oil Recovery

Abstract

Abstract The importance of this simulation work was the incorporation of the experimental interfacial tension (IFT) and oil spreading coefficient parameters measured in our laboratories. The effect of IFT was incorporated into the simulator through relative permeability curves measured under positive and negative spreading coefficient for the three-phase reservoir system: oil, water and gas. The oil spreading phenomena was tested on a black-oil reservoir located in Australia. The reservoir descriptions used in the model were validated by comparing the simulated results with the actual reservoir performance and its production parameters. A more severe test is to have the simulator compute the past performance of each individual wells, as well as historical pressures and fluid saturation distribution. The models incorporating permeability distributions has shown a far superior history match of primary and waterflood performance at a pressure below the original reservoir pressure (positive spreading coefficient) matching and confirming the core flooding results. Good history match was also obtained on individual well basis. The work has shown that a substantial increased in the oil recovery can be achieved by operating the black-oil reservoir below its bubble point to ensure a positive spreading coefficient system. This allowed a balance between viscous force and gravity force for the oil to form a thin continuous oil film. Thus, ensuring continuity of the oil flow as it is being produced. The scheme has demonstrated that the oil recovery could be improved by as much as 15%.