This paper presents the applicability/validity and rate sensitivity of several conventional up-scaling techniques in fractured reservoir simulation. Three different models have been developed and simulated using Kyte and Berry, Pore Volume Weighted, Weighted Relative Permeability, and Stone type pseudos at different rates and with different oil-to-water viscosity ratio.

From the results it can be concluded that these techniques may be used in fractured reservoir simulation in order to reduce number of simulation grids as well as to synthesize details of small-scale fluid mechanics and reservoir heterogeneity. They may or may not be rate sensitive depending on the model type.

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