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ABSTRACT
The IZYP field, located in the Niger Delta region, is an oil rim reservoir characterized by a combined drive mechanism involving both an aquifer and solution gas. The field has undergone primary recovery and conventional water injection, achieving a recovery factor of 19% and 28.5%, respectively. However, the late initiation of water injection led to substantial pressure depletion and solution gas liberation, compromising the reservoir's natural energy drive and hindering efficient hydrocarbon recovery. This study aimed to optimize the water injection strategy for the IZYP field to maximize oil recovery and resource utilization. A representative reservoir simulation model was developed through history matching, replicating the field's past production performance. Subsequent simulations evaluated the impact of modifying water injection timings and operational parameters on overall recovery factors. The optimized water injection strategy involved initiating water injection at an earlier stage (3,015 days or 1997), effectively maintaining reservoir pressure above the bubble point. This proactive approach minimized solution gas production and preserved the reservoir's energy potential. The optimized strategy yielded a substantial improvement in the ultimate recovery factor, increasing from 28.5% to 32.6% after 34 years of production. Comparative analyses of average reservoir pressure, gas-oil ratio (GOR), and recovery factor graphs illustrated the significant benefits of the optimized approach. Early water injection effectively mitigated GOR spikes, indicating reduced solution gas liberation and improved pressure maintenance. The optimization process identified the most favorable combination of water injection well locations and injection rates, tailored to the specific characteristics of the IZYP field. The findings underscore the importance of timely and strategic reservoir management practices, particularly in fields with combined drive mechanisms.
