Abstract
Abstract Streamline methods as a reservoir simulation tool have generated a great deal of interest in petroleum engineering because of the capability to calculate fluid flow in multi-million cell geological models with reasonable CPU times. Recently, streamline simulation has been applied to fractured reservoirs at the geo-scale. However, these simulations have been limited to two-phase incompressible systems. Commercial application of streamline methods to fractured reservoirs often requires the modeling of at least three compressible fluid phases. Flow simulation of fractured reservoirs is commonly performed using a dual porosity model. The dual porosity system is modeled by using two coupled grids: one for matrix and one for fracture. The interaction between the two continua is modeled using matrix-fracture transfer functions. Until now, there were no mathematical models of dual porosity three-phase compressible flow for streamline simulators. To realize this model it was necessary to reformulate the matrix and fracture pressure equations. Conventional transfer function has been incorporated as a source/sink term, not only in the streamline saturation equations (as it was in incompressible case), but also in the pressure equation. The dual porosity model has been implemented into a streamline simulator. This tool has its main application in the high resolution reservoir modeling domain for analyzing geological uncertainty, model ranking and screening, and dynamic model calibration using production data. This paper describes the mathematical model for three-phase compressible dual porosity model for a streamline simulator and compares the results and run times of the streamline-based approach with a conventional dual porosity grid-based commercial simulator. The results from the streamline simulator for dual porosity show good agreement with those produced by a commercial finite difference simulator with order of magnitude improvement in simulation time.
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