Abstract
ABSTRACT Fractal distributions of porosity and permeability in two-dimensional vertical cross sections can be used to represent reservoir heterogeneity. We compare a hybrid finite-difference/streamtube method and pseudo-relative permeabilities as two methods of using these distributions in reservoir simulations. We simulate waterflood displacements in a field case study and some additional sensitivity cases. In all the cases studied, predicted cumulative oil production values agree within 5 percent between the two methods.
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