IDEAS home Printed from https://ideas.repec.org/a/gam/jsusta/v13y2021i10p5672-d557353.html
   My bibliography  Save this article

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
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/2071-1050/13/10/5672/pdf
    Download Restriction: no
    File URL: https://www.mdpi.com/2071-1050/13/10/5672/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    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.
    Full references (including those not matched with items on IDEAS)

    Most related items

    These are the items that most often cite the same works as this one and are cited by the same works as this one.
    1. Sun, Fengrui & Yao, Yuedong & Chen, Mingqiang & Li, Xiangfang & Zhao, Lin & Meng, Ye & Sun, Zheng & Zhang, Tao & Feng, Dong, 2017. "Performance analysis of superheated steam injection for heavy oil recovery and modeling of wellbore heat efficiency," Energy, Elsevier, vol. 125(C), pages 795-804.
    2. Huang, Liang & Ning, Zhengfu & Wang, Qing & Zhang, Wentong & Cheng, Zhilin & Wu, Xiaojun & Qin, Huibo, 2018. "Effect of organic type and moisture on CO2/CH4 competitive adsorption in kerogen with implications for CO2 sequestration and enhanced CH4 recovery," Applied Energy, Elsevier, vol. 210(C), pages 28-43.
    3. Sun, Fengrui & Yao, Yuedong & Li, Guozhen & Li, Xiangfang, 2018. "Geothermal energy extraction in CO2 rich basin using abandoned horizontal wells," Energy, Elsevier, vol. 158(C), pages 760-773.
    4. Zhou, Junping & Tian, Shifeng & Zhou, Lei & Xian, Xuefu & Yang, Kang & Jiang, Yongdong & Zhang, Chengpeng & Guo, Yaowen, 2020. "Experimental investigation on the influence of sub- and super-critical CO2 saturation time on the permeability of fractured shale," Energy, Elsevier, vol. 191(C).
    5. Xiaoqian Guo & Qiang Yan & Anjian Wang, 2017. "Assessment of Methods for Forecasting Shale Gas Supply in China Based on Economic Considerations," Energies, MDPI, vol. 10(11), pages 1-14, October.
    6. Xuhua Gao & Junhong Yu & Xinchun Shang & Weiyao Zhu, 2023. "Investigation on Nonlinear Behaviors of Seepage in Deep Shale Gas Reservoir with Viscoelasticity," Energies, MDPI, vol. 16(17), pages 1-23, August.
    7. Gao, Xinyuan & Yang, Shenglai & Tian, Lerao & Shen, Bin & Bi, Lufei & Zhang, Yiqi & Wang, Mengyu & Rui, Zhenhua, 2024. "System and multi-physics coupling model of liquid-CO2 injection on CO2 storage with enhanced gas recovery (CSEGR) framework," Energy, Elsevier, vol. 294(C).
    8. Jin, Xu & Wang, Xiaoqi & Yan, Weipeng & Meng, Siwei & Liu, Xiaodan & Jiao, Hang & Su, Ling & Zhu, Rukai & Liu, He & Li, Jianming, 2019. "Exploration and casting of large scale microscopic pathways for shale using electrodeposition," Applied Energy, Elsevier, vol. 247(C), pages 32-39.
    9. Kim, Tae Hong & Cho, Jinhyung & Lee, Kun Sang, 2017. "Evaluation of CO2 injection in shale gas reservoirs with multi-component transport and geomechanical effects," Applied Energy, Elsevier, vol. 190(C), pages 1195-1206.
    10. Wang, Sen & Qin, Chaoxu & Feng, Qihong & Javadpour, Farzam & Rui, Zhenhua, 2021. "A framework for predicting the production performance of unconventional resources using deep learning," Applied Energy, Elsevier, vol. 295(C).
    11. Lin Tan & Lingzhi Xie & Bo He & Yao Zhang, 2024. "Multi-Fracture Propagation Considering Perforation Erosion with Respect to Multi-Stage Fracturing in Shale Reservoirs," Energies, MDPI, vol. 17(4), pages 1-21, February.
    12. Zou, Youqin & Yang, Changbing & Wu, Daishe & Yan, Chun & Zeng, Masun & Lan, Yingying & Dai, Zhenxue, 2016. "Probabilistic assessment of shale gas production and water demand at Xiuwu Basin in China," Applied Energy, Elsevier, vol. 180(C), pages 185-195.
    13. Prinisha Manda & Diakanua Bavon Nkazi, 2020. "The Evaluation and Sensitivity of Decline Curve Modelling," Energies, MDPI, vol. 13(11), pages 1-16, June.
    14. Niu, Wente & Lu, Jialiang & Sun, Yuping & Zhang, Xiaowei & Li, Qiaojing & Cao, Xu & Liang, Pingping & Zhan, Hongming, 2024. "Techno-economic integration evaluation in shale gas development based on ensemble learning," Applied Energy, Elsevier, vol. 357(C).
    15. Taha Yehia & Ahmed Naguib & Mostafa M. Abdelhafiz & Gehad M. Hegazy & Omar Mahmoud, 2023. "Probabilistic Decline Curve Analysis: State-of-the-Art Review," Energies, MDPI, vol. 16(10), pages 1-20, May.
    16. Li, Yanbin & Li, Yun & Wang, Bingqian & Chen, Zhuoer & Nie, Dan, 2016. "The status quo review and suggested policies for shale gas development in China," Renewable and Sustainable Energy Reviews, Elsevier, vol. 59(C), pages 420-428.
    17. Yang, Yan & Wang, Limao & Fang, Yebing & Mou, Chufu, 2017. "Integrated value of shale gas development: A comparative analysis in the United States and China," Renewable and Sustainable Energy Reviews, Elsevier, vol. 76(C), pages 1465-1478.
    18. Nie, Bin, 2023. "Study on thermal decomposition of oil shale: Two-phase fluid simulation in wellbore," Energy, Elsevier, vol. 272(C).
    19. Gong, Jianming & Qiu, Zhen & Zou, Caineng & Wang, Hongyan & Shi, Zhensheng, 2020. "An integrated assessment system for shale gas resources associated with graptolites and its application," Applied Energy, Elsevier, vol. 262(C).
    20. Zhengbin Wu & Hanzhao Chen & Xidong Cai & Qiyang Gou & Liangliang Jiang & Kai Chen & Zhangxin Chen & Shu Jiang, 2023. "Current Status and Future Trends of In Situ Catalytic Upgrading of Extra Heavy Oil," Energies, MDPI, vol. 16(12), pages 1-29, June.

    Corrections

    All material on this site has been provided by the respective publishers and authors. You can help correct errors and omissions. When requesting a correction, please mention this item's handle: RePEc:gam:jsusta:v:13:y:2021:i:10:p:5672-:d:557353. See general information about how to correct material in RePEc.

    If you have authored this item and are not yet registered with RePEc, we encourage you to do it here. This allows to link your profile to this item. It also allows you to accept potential citations to this item that we are uncertain about.

    If CitEc recognized a bibliographic reference but did not link an item in RePEc to it, you can help with this form .

    If you know of missing items citing this one, you can help us creating those links by adding the relevant references in the same way as above, for each refering item. If you are a registered author of this item, you may also want to check the "citations" tab in your RePEc Author Service profile, as there may be some citations waiting for confirmation.

    For technical questions regarding this item, or to correct its authors, title, abstract, bibliographic or download information, contact: MDPI Indexing Manager (email available below). General contact details of provider: https://www.mdpi.com .

    Please note that corrections may take a couple of weeks to filter through the various RePEc services.

    IDEAS is a RePEc service. RePEc uses bibliographic data supplied by the respective publishers.