Relative permeability provides important information for understanding the dynamic behavior of two-phase flow. EOR technology featured by polymer flooding, surfactant flooding and ASP compositional flooding requires relative permeability data to characterize the flow behavior in reservoir engineering calculation and numerical simulation. A dynamic pore scale network model and its application in simulating the impact of IFT and oil/water viscosity on relative permeability are presented in this paper. The parameters of both viscous force and capillary force, instead of the only one parameter the capillary pressure as in conventional or invasion percolation algorithm, control the displacement configuration in this model, and so the model can better reflect the impact of chemical flooding on flow behavior.

The study presented that both water and oil relative permeability curves shift with variation of IFT and oil/water viscosity ratio. It was found that both water and oil relative permeability curves shift upward as IFT is reduced. They tend to become linear with saturation as IFT reach ultra low value. The effect of viscosity ratio is very small when the interfacial tension is high. But when the interfacial is low, the water relative permeability decreases with the increase of the water viscosity. The oil relative permeability also decreases but not as much as water, especially at high water saturation, the decrease can be neglected. The breakthrough saturation tends to decrease with reduction of IFT, however within a certain range of IFT value, this simple correlation between breakthrough saturation and IFT might be changed with oil/water viscosity ratio.

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