In this study, the authors use measured CO2/brine relative permeability data available in the literature to study the behavior of the data obtained for various rocks. These measured CO2 relative permeabilities show large variations in the values of relative permeability and also in the trend of the relative permeability curves. The results of this study will allow identification of rocks that would be more suitable for CO2 injection on the basis of the pore structure and the distribution of the pores inside the rock.
Introduction
In much of the literature, the relative permeability of CO2 has been studied for each formation separately and the main factors considered to affect CO2 relative permeability include fluid saturation, hysteresis, and interfacial tension (IFT). As for a group of formations with different rock types, the difference in CO2 relative permeability curves is mainly attributed to rock-type parameters. However, it has been found that even in a set of samples extracted from different formations in the same rock type or from a single formation, there is diversity in CO2 relative permeability curves.
