The history match of the 3-D fluid flow model constructed on the Ekofisk Field is the focus of this study. The Ekofisk reservoir is a high porosity, low matrix permeability naturally fractured chalk. Fluid flow is largely governed by the distribution, orientation and interconnectivity of the natural fracture system associated with complex structure and reservoir distribution. Because of the impact heterogeneity has on preferential fluid flow direction, significant attention was given to capturing as much of the intrinsic heterogeneity as possible, both laterally and vertically, in the new 3-D geological model. A fairly high-resolution simulation mesh was defined for the fluid flow model, and a flow-based upscaling technique was then applied to preserve the heterogeneity from the geological to the fluid flow model. Because of the complexity of the Ekofisk Field, with its numerous faults and fracture networks, anisotropy was one of the primary attributes manipulated to achieve an individual well and field history match. However, faults and fault sealing factors, vertical permeability, pseudo relative permeability curves, bubble point pressure correlations, local permeability, and rock compressibility were also key parameters in the history match, and are presented in this paper. A brief discussion on the preliminary implementation of water-induced compaction is included.

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