This paper describes the use of a graphical pre-processing software to generate the grid block array input data for the large scale Kuparuk Full Field Model. Geological and reservoir property maps generated with various mapping packages were imported along with the 77 by 88 simulation packages were imported along with the 77 by 88 simulation grid. Computing time for calculating the entire grid block array data was approximately 45 minutes on a VAXStation 3200. The pre-processor greatly expedited the task of initializing and updating the model. An estimated two man-months of engineering time were saved. The compatibility of the pre-processor with the simulator helped to ensure data pre-processor with the simulator helped to ensure data consistency. Juxtaposition of sands due to faulting and truncation were handled automatically using non-standard grid block connections. An inactive middle layer was extracted while preserving the proper depths of the lower sands, resulting in significant savings in CRAY run times and memory requirements. Introduction The Kuparuk River Field is located in the Arctic Coastal Plain region, 20 miles west of the Prudhoe Bay Field Plain region, 20 miles west of the Prudhoe Bay Field (Figure 1). The productive area covers 250 square miles; current field development encompasses 40 drillsites with 16 to 22 wells each. Over 600 wells on nominal 160-acre well spacing have been drilled in Kuparuk. Currently, the field oil production rate averages 300,000 STB/D (1,000 STB/D/well) with water cut of 42%, and gas-oil ratio of 1,100 scf/STB. Cumulative oil production at the end of 1990 was 723 MMSTB. The Kuparuk River Field is the second largest oil producer in the United States. Field production started in December 1981. The reservoir oil was initially undersaturated with a solution gas-oil ratio of about 450 scf/STB. During primary depletion, the main reservoir mechanisms were fluid expansion above bubble point pressure, followed by solution gas drive. Aquifer point pressure, followed by solution gas drive. Aquifer support in Kuparuk River Field is negligible. Waterflooding was initiated early in field life for pressure maintenance. Full field waterflood, mainly on direct line drive patter, was completed by 1985. Excess formation gas is re-injected into the reservoir via water-alternating-gas injection and gas storage wells. Two enhanced oil recovery pilots of enriched gas alternating with water injection was implemented in mid-1988 with favorable oil production response. Fluid production and injection in Kuparuk is handled by three central processing facilities and an associated seawater treatment plant. Gas lift gas requirements are increasing steadily as the waterflood matures. Future development strategies include peripheral drilling, 80-acre infill drilling, and enhanced oil recovery expansions. Facility expansions with long equipment lead times and large capital expenditures are likely to be needed to support current and future field development. P. 217
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