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<p>The Mishrif Formation in Southern Iraq is a significant carbonate reservoir with considerable hydrocarbon potential. However, its complex heterogeneity presents major challenges for efficient oil recovery. This study aims to improve oil recovery and economic outcomes by integrating dynamic reservoir modeling with well-spacing optimization. Geological characterization revealed that the southern section of the MB21 unit has a larger bulk volume of 35,118&#xa0;million cubic meters (MM³), while the northern section has 11,773 MM³. The average Net-to-Gross (NTG) ratio is approximately 0.96 in the south and 0.66 in the north. The estimated Oil Initially in Place (OOIP) for the entire formation is about 4138.7&#xa0;million barrels. The Oil-Water Contact (OWC) is located at depths of − 3877&#xa0;m in the southern zone and − 3885&#xa0;m in the northern zone. Four development scenarios were examined through dynamic simulation: a Do-Nothing case and three well-spacing strategies of 1500&#xa0;m, 1000&#xa0;m, and 500&#xa0;m. The results indicated that vertical infill wells with a spacing of 1500&#xa0;m were the most effective in the southern part of the field, achieving a plateau period of 11 years, cumulative oil production of 398.188&#xa0;million stock tank barrels (MMSTB), a reservoir pressure of 2915.18 psi, a water cut of 7.6%, and a recovery factor (RF) of 14.1%. In contrast, a spacing of 1000&#xa0;m proved to be optimal in the north for 4 years, yielding 167.56 MMSTB, a water cut of 46.368%, and an RF of 9.197%. Sensitivity analysis revealed that South-2a remains the best overall Net Present Value (NPV) performer for the southern region, offering a good plateau and a moderate drilling count. North-2b continues to be the economic winner in the north, providing the highest incremental RF per well. However, cases 2-c (in both regions) appear the least attractive when realistic capital expenditures (CAPEX) are considered, despite their aggressive plateau rates. Overall, the dynamic modeling integrated with appropriate well-spacing strategies can enhance reservoir management, boost hydrocarbon production, and improve economic performance.</p>

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Maximizing oil recovery and economic returns through strategic well spacing in the Mishrif Formation, Southern Iraq

  • 期刊论文

  • 发表日期：

    2025年9月8日

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  • Mohammed A. Khashman,
  • Hamed Shirazi,
  • Ahmed N. AL-Dujaili,
  • Nada M. Sulaiman

摘要

The Mishrif Formation in Southern Iraq is a significant carbonate reservoir with considerable hydrocarbon potential. However, its complex heterogeneity presents major challenges for efficient oil recovery. This study aims to improve oil recovery and economic outcomes by integrating dynamic reservoir modeling with well-spacing optimization. Geological characterization revealed that the southern section of the MB21 unit has a larger bulk volume of 35,118 million cubic meters (MM³), while the northern section has 11,773 MM³. The average Net-to-Gross (NTG) ratio is approximately 0.96 in the south and 0.66 in the north. The estimated Oil Initially in Place (OOIP) for the entire formation is about 4138.7 million barrels. The Oil-Water Contact (OWC) is located at depths of − 3877 m in the southern zone and − 3885 m in the northern zone. Four development scenarios were examined through dynamic simulation: a Do-Nothing case and three well-spacing strategies of 1500 m, 1000 m, and 500 m. The results indicated that vertical infill wells with a spacing of 1500 m were the most effective in the southern part of the field, achieving a plateau period of 11 years, cumulative oil production of 398.188 million stock tank barrels (MMSTB), a reservoir pressure of 2915.18 psi, a water cut of 7.6%, and a recovery factor (RF) of 14.1%. In contrast, a spacing of 1000 m proved to be optimal in the north for 4 years, yielding 167.56 MMSTB, a water cut of 46.368%, and an RF of 9.197%. Sensitivity analysis revealed that South-2a remains the best overall Net Present Value (NPV) performer for the southern region, offering a good plateau and a moderate drilling count. North-2b continues to be the economic winner in the north, providing the highest incremental RF per well. However, cases 2-c (in both regions) appear the least attractive when realistic capital expenditures (CAPEX) are considered, despite their aggressive plateau rates. Overall, the dynamic modeling integrated with appropriate well-spacing strategies can enhance reservoir management, boost hydrocarbon production, and improve economic performance.