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ABSTRACT
This study investigated the effectiveness of various recovery techniques for a black oil reservoir using CMG IMEX reservoir simulation software. The reservoir initially contained an estimated 88.8 million stock tank barrels (STB) of oil, 132 million STB of water, and 122 billion standard cubic feet (SCF) of gas. The research compared three recovery scenarios simulated over a 20-year period (2016-2036). Natural depletion, relying solely on solution gas drive without aquifer support, resulted in a low ultimate recovery, reaching only 9% of the original oil in place (OOIP) and 20% of the initial gas in place (IGIP). While the presence of an aquifer slightly improved recovery, it also led to a substantial increase in water production. Waterflooding, implemented with 10 producers and 2 injectors, demonstrated improved sweep efficiency. This technique achieved recoveries of approximately 21% OOIP and 45% IGIP without aquifer support. When combined with aquifer support, waterflooding yielded even better results, reaching 27% OOIP and over 50% IGIP. Polymer flooding exhibited the highest recovery potential among the evaluated methods. It achieved around 21% OOIP recovery without aquifer support due to its optimized displacement efficiency. When coupled with aquifer support, polymer flooding further improved recovery, reaching approximately 27% OOIP and over 50% IGIP. These findings highlight the limitations of relying solely on natural flow for hydrocarbon recovery. The study underscores the significant benefits of implementing enhanced oil recovery techniques, particularly polymer flooding, to maximize oil and gas production from the reservoir.
