Pore-scale to core-scale aspects of capillary desaturation curves using CT-scan imaging

Surfactant flooding is one of the effective technologies to enhance oil recovery of water flooded petroleum reservoirs. Several previous studies have demonstrated that the release of oil from a rock submitted to waterflood depends on the competition between displacing forces (viscous and buoyancy) and capillary forces. This competition is expressed by two dimensionless numbers, the Capillary number, defined as the ratio of viscous to capillary forces and the Bond number, defined as the ratio of gravity to capillary forces. At the core scale the evolution of the oil residual saturation as function of the capillary number is better known as the Capillary Desaturation Curve (CDC), which constitutes an important input parameter in EOR processes reservoir simulation. In this work we present a new experimental workflow to investigate the effect of rock structure on the CDC. This workflow combines core flood experiments and CT-scan imaging to accurately measure the mean residual oil saturation at different capillary number values as well as the local saturation distribution along the core plug. The CDC was measured on a set of water-wet sandstone with different permeability and degree of heterogeneity. The capillary number was varied by injecting a surfactant solution at different flow rates. Using this methodology, we first study the effect of core flood orientation (Horizontal injection and vertical downflow injection). The resulting local saturation curves show that in a horizontal configuration the oil migrates upwards in the sample inducing an oriented front strongly deviating from the piston like displacement, and very different from the one observed in the vertically placed sample. This behaviour is manly attributed to buoyancy forces that are no more negligible compared to capillary forces when surfactant is injected. This experiment shows that when measuring a CDC the capillary number needs to be corrected to take into account the buoyancy forces. In a second step we have investigated the effect of local heterogeneity of core plugs on the CDC with Clashach and Fontainebleau sandstones. Two samples of Clashash sandstone with equivalent mean properties were studied (mean permeability of 380 and 426 md and mean porosity of 13.4 % and 14.1% respectively). The resulting CDC curve exhibits almost two decades difference in the critical capillary number. This discrepancy is explained in terms of the local variation of the porosity that induces important differences in the local saturation profile.