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The formation pressure characteristics in the Penglai gas area of Southwest oilfield are complex, and there are problems in cementing operations such as narrow annular gaps, safety density windows, difficulties in leak prevention and pressure stability, low efficiency of cement slurry replacement, and high risk of gas channeling. Therefore, optimizing cement slurry and cementing technology based on geological characteristics and wellbore structural parameters is crucial for ensuring construction safety and cementing quality. Taking a typical risk exploration well as an example, the fifth section design of Peng-X well is cementing with a 206.38 mm liner at the 241.3 mm hole. The drilling fluid is the potassium polysulfonate system that heavily thickens in contact with cement slurry, making construction difficult. The design of cement slurry and cementing process is optimized to achieve safe and efficient cementing. High density lead slurry is used to seal overlapping sections, anti channeling self-healing tail slurry is used to seal high-pressure gas layers in open holes, and anti-organic salt pollution spacer fluid is used to isolate the lead slurry and drilling mud and ensure the quality of plugging. After construction, segmented annular pressure suppression measures are taken to stabilize high-pressure gas in the setting period of cement slurry. The experimental results and field application showed that the friction coefficient of the cement slurry is low (K < 1.0 Pa sn). The cement slurry exhibited good settlement stability with density difference less than 0.02 g cm−3. The thickening time can be adjustable. The anti-channeling performance is also excellent with the SPN value less than 3. The strength time at the top of the slurry is 10.5 h, and the compress strength is greater than 14 MPa after 48 h. There is no gas channeling or annular pressure phenomenon after cementing. The successful application of this technology can provide guidance and reference for liner cementing of high pressure natural gas wells in the Southwest oilfield.

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Study and Application of a High Density Self-Healing Cement Slurry for Peng-X Well

  • 会议论文

  • 发表日期：

    2025年

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  • Wei-ji Shi,
  • Ming-yue Zhao,
  • Xiao-jie Sun,
  • Zhi-gang Huang,
  • Kun-peng Yang,
  • Jiang-Long Li,
  • Guang-hui Shao

摘要

The formation pressure characteristics in the Penglai gas area of Southwest oilfield are complex, and there are problems in cementing operations such as narrow annular gaps, safety density windows, difficulties in leak prevention and pressure stability, low efficiency of cement slurry replacement, and high risk of gas channeling. Therefore, optimizing cement slurry and cementing technology based on geological characteristics and wellbore structural parameters is crucial for ensuring construction safety and cementing quality. Taking a typical risk exploration well as an example, the fifth section design of Peng-X well is cementing with a 206.38 mm liner at the 241.3 mm hole. The drilling fluid is the potassium polysulfonate system that heavily thickens in contact with cement slurry, making construction difficult. The design of cement slurry and cementing process is optimized to achieve safe and efficient cementing. High density lead slurry is used to seal overlapping sections, anti channeling self-healing tail slurry is used to seal high-pressure gas layers in open holes, and anti-organic salt pollution spacer fluid is used to isolate the lead slurry and drilling mud and ensure the quality of plugging. After construction, segmented annular pressure suppression measures are taken to stabilize high-pressure gas in the setting period of cement slurry. The experimental results and field application showed that the friction coefficient of the cement slurry is low (K < 1.0 Pa sn). The cement slurry exhibited good settlement stability with density difference less than 0.02 g cm−3. The thickening time can be adjustable. The anti-channeling performance is also excellent with the SPN value less than 3. The strength time at the top of the slurry is 10.5 h, and the compress strength is greater than 14 MPa after 48 h. There is no gas channeling or annular pressure phenomenon after cementing. The successful application of this technology can provide guidance and reference for liner cementing of high pressure natural gas wells in the Southwest oilfield.