Pseudo relative permeability curves have been used to model heterogeneous (layered) reservoirs in the past. Although the two-phase flow and the nature of heterogeneity are different from the layered systems, the same concept can be applied to the modeling of naturally fractured reservoirs. The proposed relative permeabilities are shown to be not only a function of saturation values but are also dependent on flow velocity, permeability and capillary pressure levels of the matrix.

The EFRP’s (Effective Fracture Relative Permeability) were generated for different rates and matrix properties in oil water systems. Using the EFRP curves, a dual porosity system can be reduced to a fracture network model. This provides a significant reduction and modification in modeling of dual porosity systems.

This type of modeling approach will reduce the time spent for matrix and transfer flow calculations and more emphasis can be devoted to represent the irregularity of the fracture pattern.

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