Two-phase relative permeability prediction from capillary pressure data for one Iraqi oil field: A comparative study

Abstract

In almost all measurements of the fluid flowing in pores media, relative permeability data is essential. Relative permeability curves have an important role in describing two-phase flow in porous media and estimating of immiscible displacement processes efficiency. Calculations of relative permeability are usually derived from laboratory tests utilizing core samples, or from capillary pressure test data. There are several approaches utilized for estimating the relative permeability utilizing the drainage or imbibition capillary pressure curve. In this study, different approaches utilized to measure the oil-water relative permeability from experimental capillary pressure data. The Corey relative permeability model generally accepted as a method for measuring relative permeability curves utilizing capillary pressure data. In this study, the analytical solution relative permeability model was found to be best appropriate model to the experimental wetting and non-wetting-phase relative permeability data. The variations between experimental relative permeability and analytical solution model were almost insignificant in both wetting and non-wetting phases. Measurement of relative permeabilities utilizing the analytical solution model and Corey model for the nonwetting-phase were very similar to the experimental measurements other than the Rose and Bruce model. This study showed that the relative permeability acceptably determined by selecting a suitable model utilizing capillary pressure. Capillary pressure may also be measured in the reverse procedure once the relative permeability data were accessible.