Volume 43 Issue 4
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Tian Ganghua, Xia Qi, Wang Haizhu, et al.Fracture propagation patterns of pre-CO2 fracturing in shale oil reservoirs[J]. Drilling Fluid & Completion Fluid，2026, 43（4）：549-561 doi: 10.12358/j.issn.1001-5620.2026.04.014
Citation: Tian Ganghua, Xia Qi, Wang Haizhu, et al.Fracture propagation patterns of pre-CO2 fracturing in shale oil reservoirs[J]. Drilling Fluid & Completion Fluid，2026, 43（4）：549-561 doi: 10.12358/j.issn.1001-5620.2026.04.014
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Fracture Propagation Patterns of Pre-CO2 Fracturing in Shale Oil Reservoirs

doi: 10.12358/j.issn.1001-5620.2026.04.014

  • State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum (Beijing), Beijing 102249

  • Received Date: 2026-05-19
  • Accepted Date: 2026-06-18
  • Rev Recd Date: 2026-05-30
  • Publish Date: 2026-07-30
    Abstract
  • Using CO2 as a fracturing fluid can enhance reservoir stimulation effect and achieve carbon sequestration. The CO2 pre-pad fracturing technology combines the advantages of both CO2 fracturing and water-based fracturing, serving as an important approach to improving fracturing performance in shale reservoirs. In this study, a thermal-hydro-mechanical-damage (THMD) coupled fracture propagation model was established for CO2 pre-pad fracturing. Through numerical simulations, the evolution patterns of stress, temperature, fluid pressure, and damage during the CO2 pre-pad fracturing process were analyzed, and the effects of CO2 injection mode, injection volume, and injection rate on fracture propagation were investigated. The results indicated that fracture propagation was jointly driven by thermal stress and fluid pressure. The influence of thermal stress was primarily confined to a range of approximately 5 m near the wellbore, but its effect could not be ignored. The injection mode of injecting CO2 first followed by slickwater proved more conducive to promoting fracture propagation. A non-monotonic relationship was observed between the CO2 injection volume and the reservoir stimulation effect, and excessive CO2 injection might inhibit damage evolution. When the CO2 injection volume was 500 m3, the stimulation effect was optimal with a damage area of 629.91 m2, which was 41.82 m2 larger than that of conventional hydraulic fracturing. Furthermore, as the CO2 injection rate increased, both the damage area and fracturing efficiency increased. These findings provided a theoretical basis for optimizing CO2 pre-pad fracturing parameters in shale reservoirs and the efficient utilization and geological sequestration of CO2.

     

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