Field Experiences With History Matching an Offshore Turbiditic Reservoir Using Inverse Modeling
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AbstractReconciling high-resolution geologic models with pressure and multiphase production history is one of the most time-consuming aspects of the workflow for geoscientists and engineers. Although significant advancements have been made in this area over the last decade, current industry practice largely involves iterative trial and error methods and often utilizes arbitrary permeability multipliers that lead to loss of geologic realism and consequently poor performance predictions.In this paper, we demonstrate the application of an efficient inverse modeling scheme for history matching a waterflooded, structurally complex and faulted offshore turbiditic oil reservoir. The field has an estimated 500 MMSTB and is located in a prolific offshore hydrocarbon basin. Permeability and fault transmissibilities are the main uncertainties. More than 10 years of production data from up to 8 producing wells are available for history matching. Our approach combines the efficiency of the streamline-based sensitivity computations with the versatility and accuracy of finite difference models for matching the water cut at the producers.Specifically, a finite-difference model is used for flow simulation and to generate velocity fields based on which we compute streamlines and sensitivities for updating reservoir permeability via fast inverse modeling. These sensitivities relate the reservoir properties to production data and can be obtained using a single flow simulation resulting in an efficient inverse algorithm for history matching. A unique aspect of the field study here is the novel approach used for streamline tracing and sensitivity calculations across faults and non-neighbor connections in the geologic models via local grid refinement.
