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Numerical Investigation on Wellbore Temperature Prediction during the CO 2 Fracturing in Horizontal Wells

Author

Listed:
  • Xinrun Lyu

    (State Key Laboratory of Petroleum Resources and Engineering, China University of Petroleum, Beijing 102249, China
    National Computer Network Emergency Response Technical Team/Coordination Center of China, Beijing 100029, China)

  • Shicheng Zhang

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

  • Yueying He

    (National Computer Network Emergency Response Technical Team/Coordination Center of China, Beijing 100029, China)

  • Zihan Zhuo

    (National Computer Network Emergency Response Technical Team/Coordination Center of China, Beijing 100029, China)

  • Chong Zhang

    (National Computer Network Emergency Response Technical Team/Coordination Center of China, Beijing 100029, China)

  • Zhan Meng

    (State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation, Southwest Petroleum University, Chengdu 610500, China)

Abstract

A novel model is established to predict the temperature field in the horizontal wellbore during CO 2 fracturing. The pressure work and viscous dissipation are considered, and the transient energy, mass and momentum equations as well as the CO 2 physical properties are solved fully coupled. The model passes the convergence test and is verified through a comparison using the COMSOL software. Then, a sensitivity analysis is performed to study the effects of the treating parameters. Results illustrate that the relationship between the injection rate and the stable bottom-hole temperature (hereinafter referred to as BHT) is non-monotonic, which is different from the hydraulic fracturing. The existence of the horizontal section will increase the BHT at 2 m 3 /min condition but reduce the BHT at 10 m 3 /min condition. The problem of high wellbore friction can be alleviated through tube size enhancement, and the ultimate injection rate allowed increased from 2.7 m 3 /min to 29.6 m 3 /min when the tube diameter increased from 50.3 mm to 100.3 mm. Additionally, the open-hole completion method of the horizontal section can increase the BHT to 2.7 °C but reduce the near formation temperature to 24.5 °C compared with the casing completion method.

Suggested Citation

  • Xinrun Lyu & Shicheng Zhang & Yueying He & Zihan Zhuo & Chong Zhang & Zhan Meng, 2021. "Numerical Investigation on Wellbore Temperature Prediction during the CO 2 Fracturing in Horizontal Wells," Sustainability, MDPI, vol. 13(10), pages 1-33, May.
    • Handle: RePEc:gam:jsusta:v:13:y:2021:i:10:p:5672-:d:557353
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    References listed on IDEAS

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    1. Lyu, Xinrun & Zhang, Shicheng & Ma, Xinfang & Wang, Fei & Mou, Jianye, 2018. "Numerical study of non-isothermal flow and wellbore heat transfer characteristics in CO2 fracturing," Energy, Elsevier, vol. 156(C), pages 555-568.
    2. Gu, Hao & Cheng, Linsong & Huang, Shijun & Du, Baojian & Hu, Changhao, 2014. "Prediction of thermophysical properties of saturated steam and wellbore heat losses in concentric dual-tubing steam injection wells," Energy, Elsevier, vol. 75(C), pages 419-429.
    3. Yuan, Jiehui & Luo, Dongkun & Feng, Lianyong, 2015. "A review of the technical and economic evaluation techniques for shale gas development," Applied Energy, Elsevier, vol. 148(C), pages 49-65.
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