Abstract

ABSTRACT EOR processes that feature a near miscible process, CO2 injected below the minimum miscibility pressure or micellar fluids, require relative permeability data to calculate the flow behavior of the low interfacial tension (low IFT) fluids. The flow behavior of low IFT fluids differs from that of conventional gas and oil or water and oil; it depends upon IFT, viscosity, and flow rate as well as the rock properties of pore size distribution and wettability. The results of laboratory core tests using an alcohol, brine, and oil fluid system in outcrop and reservoir rock samples are presented. Both water and oil relative permeability curves were found to shift upward, indicating the two phases interfere less with each other as IFT is reduced. For a given reservoir rock type, the flow behavior is adequately characterized by a capillary number defined by combined (total) fluid velocity, average viscosity, and interfacial tension. It was also found that flow tests on representative reservoir rock samples are necessary to describe low interfacial tension relative permeability for field process performance calculations.

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