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<p>Carbon dioxide effectively prevents clay mineral hydration and mitigates formation damage, while exhibiting higher mobility compared to water-based fluids, making it an ideal fracturing flooding medium for low-permeability reservoirs. However, systematic studies on CO₂ fracturing flooding technology remain limited. A new model for CO₂ fracturing flooding was developed using the Displacement Discontinuity Method and the point-source seepage equation, linking fracture flow and matrix seepage through mass conservation. Validation was performed through analytical solutions and commercial software. The results show that compared with instantaneous injection, continuous injection increased the maximum seepage distance of water by 22.2% and that of CO₂ by 28.9%. Moreover, continuous injection is more favorable for CO₂ to penetrate deeper into the formation than water. CO₂ fracturing flooding increases fracture length by 40.0% and expands the seepage area to 2.4 times that of water injection. Natural fracture systems are more easily activated during CO₂ fracturing flooding, enhancing fracture complexity and further extending the swept area.</p>

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The Numerical Modeling and Simulation of CO2 Fracturing Flooding in Low-Permeability Reservoirs

  • 期刊论文

  • 发表日期：

    2026年4月16日

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  • Ziyuan Cong,
  • Jia Liu,
  • Yuwei Li,
  • P. G. Ranjith,
  • Xiaorong Li

摘要

Carbon dioxide effectively prevents clay mineral hydration and mitigates formation damage, while exhibiting higher mobility compared to water-based fluids, making it an ideal fracturing flooding medium for low-permeability reservoirs. However, systematic studies on CO₂ fracturing flooding technology remain limited. A new model for CO₂ fracturing flooding was developed using the Displacement Discontinuity Method and the point-source seepage equation, linking fracture flow and matrix seepage through mass conservation. Validation was performed through analytical solutions and commercial software. The results show that compared with instantaneous injection, continuous injection increased the maximum seepage distance of water by 22.2% and that of CO₂ by 28.9%. Moreover, continuous injection is more favorable for CO₂ to penetrate deeper into the formation than water. CO₂ fracturing flooding increases fracture length by 40.0% and expands the seepage area to 2.4 times that of water injection. Natural fracture systems are more easily activated during CO₂ fracturing flooding, enhancing fracture complexity and further extending the swept area.