An integrated full-field reservoir simulation study has been performed to\r\ndetermine the reservoir management and production strategies in a mature sandstone\r\nreservoir. The reservoir is a candidate for an enhanced oil recovery process or otherwise\r\nsubject to abandonment. Based on its charateristics, the reservoir was found to be most\r\nsuited for a surfactant/polymer (SP) flood. The study started with a large data gathering\r\nand the building of a full-field three-dimensional geological model. Subsequently, a full\r\nfield simulation model was built and used to history match the water flood. The history\r\nmatch of the water flood emphasizes the areas with remaining high oil saturations,\r\nestablishes the initial condition of the reservoir for an SP flood, and generates a forecast of\r\nreserves for continued water flood operations. A sector model was constructed from the\r\nfull field model and then used to study different design parameters to maximize the project\r\nprofitability from the SP flood. An economic model, based on the estimated recovery,\r\nresidual oil in-place, oil price, and operating costs, has been implemented in order to\r\noptimize the project profitability. The study resulted in the selection of surfactant and\r\npolymer concentrations and slug size that yielded the best economic returns when applied\r\nin this reservoir. The study shows that, in today�s oil prices, surfactant/polymer flood when\r\napplied in this reservoir has increased the ultimate oil recovery and provide a significant\r\nfinancial returns.
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