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Numerical Simulation Study on Temporary Well Shut-In Methods in the Development of Shale Oil Reservoirs

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  • Qitao Zhang

    (School of Civil and Resource Engineering, University of Science and Technology Beijing, Beijing 100083, China
    John and Willie Leone Family Department of Energy and Mineral Engineering, The Pennsylvania State University, State College, PA 16801, USA)

  • Wenchao Liu

    (School of Civil and Resource Engineering, University of Science and Technology Beijing, Beijing 100083, China)

  • Jiaxin Wei

    (Geology Institute, No. 2 Oil Production Plant, Changqing Oilfield Company, Qingcheng, Qingyang 745100, China)

  • Arash Dahi Taleghani

    (John and Willie Leone Family Department of Energy and Mineral Engineering, The Pennsylvania State University, State College, PA 16801, USA)

  • Hai Sun

    (School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China)

  • Daobing Wang

    (School of Mechanical Engineering, Beijing Institute of Petrochemical Technology, Beijing 102617, China)

Abstract

Field tests indicate that temporary well shut-ins may enhance oil recovery from a shale reservoir; however, there is currently no systematic research to specifically guide such detailed operations in the field, especially for the design of the shut-in scheme and multiple rounds of shut-ins. In this study, the applicability of well shut-in operations for shale oil reservoirs is studied, and a numerical model is built using the finite element method. In order to simulate the production in a shale oil reservoir, two separate modules (i.e., Darcy’s law and phase transport) were two-way coupled together. The established model was validated by comparing its results with the analytical Buckley–Leverett equation. In this paper, the geological background and parameters of a shale oil reservoir in Chang-7 Member (Chenghao, China) were used for the analyses. The simulation results show that temporary well shut-in during production can significantly affect well performance. Implementing well shut-in could decrease the initial oil rate while decreasing the oil decline rate, which is conducive to long-term production. After continuous production for 1000 days, the oil rate with 120 days shut-in was 9.85% larger than the case with no shut-in. Besides, an optimal shut-in time has been identified as 60 days under our modeling conditions. In addition, the potential of several rounds of well shut-in operations was also tested in this study; it is recommended that one or two rounds of shut-ins be performed during development. When two rounds of shut-ins are implemented, it is recommended that the second round shut-in be performed after 300 days of production. In summary, this study reveals the feasibility of temporary well shut-in operations in the development of a shale oil reservoir and provides quantitative guidance to optimize these development scenarios.

Suggested Citation

  • Qitao Zhang & Wenchao Liu & Jiaxin Wei & Arash Dahi Taleghani & Hai Sun & Daobing Wang, 2022. "Numerical Simulation Study on Temporary Well Shut-In Methods in the Development of Shale Oil Reservoirs," Energies, MDPI, vol. 15(23), pages 1-24, December.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:23:p:9161-:d:991923
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    References listed on IDEAS

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    1. Yuping Sun & Qiaojing Li & Cheng Chang & Xuewu Wang & Xuefeng Yang, 2022. "NMR-Based Shale Core Imbibition Performance Study," Energies, MDPI, vol. 15(17), pages 1-10, August.
    2. Lutz Kilian, 2016. "The Impact of the Shale Oil Revolution on U.S. Oil and Gasoline Prices," Review of Environmental Economics and Policy, Association of Environmental and Resource Economists, vol. 10(2), pages 185-205.
    3. Zhou Zhou & Shiming Wei & Rong Lu & Xiaopeng Li, 2020. "Numerical Study on the Effects of Imbibition on Gas Production and Shut-In Time Optimization in Woodford Shale Formation," Energies, MDPI, vol. 13(12), pages 1-18, June.
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