Abstract
Summary An analytical model describing the transient pressure behavior of a well completed in a composite naturally fractured reservoir is presented. This model was derived by extending the naturally fractured reservoir model with unrestricted interporosity flow to a composite reservoir. The composite reservoir has a circular inner region with fluid and rock properties different from those of the outer region. It is a concentric composite model with a finite-radius well located in the center. Two new solutions for analyzing the pressure response at the producing (or injection) well in infinitely large composite and bounded composite naturally fractured reservoirs are given. The results were obtained with the Stehfest algorithm for Laplace-transform inversion. Depending on the reservoir and fluid properties, various semilog straight lines may be observed in a particular pressure/time curve. The pseudo-steady-state approach can be used to determine the swept volume. On the basis of model results for different parameter values, guidelines are provided for conducting and interpreting a pressure test to determine the characteristics of a composite naturally fractured system, provided that wellbore-storage effects do not mask early-time data.
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