IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v15y2022i11p3868-d822992.html
   My bibliography  Save this article

A New Relative Permeability Characterization Method Considering High Waterflooding Pore Volume

Author

Listed:
  • Guangfeng Qi

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Jingang Zhao

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Hu He

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Encheng Sun

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Xin Yuan

    (Sinopec Shengli Oilfield Technology Testing Center, Dongying 257062, China)

  • Shuoliang Wang

    (Faculty of Engineering, School of Energy, China University of Geosciences, Beijing 100083, China)

Abstract

In the process of waterflooding development, high waterflooding PVs will make the fluid percolation in the reservoir more complicated, resulting in lower efficiency of waterflooding. High waterflooding PVs will affect the relative permeability and change the seepage law of oil–water two-phase flow in a high water-cut period. In this study, we performed high waterflooding PVs relative permeability experiments using nine natural cores. The unsteady measurement method is used to test the relative permeability curve. The results show that: (1) the relative permeability is affected by the waterflooding PVs, the recovery efficiency of 2000 waterflooding PVs is 10.72% higher than that of 50 waterflooding PVs on the core scale; (2) it makes water mobility increase sharply, while oil phase flow capacity remains low and decreases at high water cut stage. A new relative permeability characterization method considering high waterflooding PVs is established, which is applied to the numerical simulator. It shows that the remaining oil saturation of the high-permeability belt is higher than the calculation results of the traditional numerical simulator. It means that the injected water does not diffuse much into the low-permeability zone of the formation. The modified simulator is validated with the actual China offshore oilfield model. The numerical saturation of the key section of the passing well is in good agreement with the actual logging interpretation results, and the water cut curve fits better in the whole area. The modified simulator could predict oil production accurately after high waterflooding PVs treatment.

Suggested Citation

  • Guangfeng Qi & Jingang Zhao & Hu He & Encheng Sun & Xin Yuan & Shuoliang Wang, 2022. "A New Relative Permeability Characterization Method Considering High Waterflooding Pore Volume," Energies, MDPI, vol. 15(11), pages 1-16, May.
  • Handle: RePEc:gam:jeners:v:15:y:2022:i:11:p:3868-:d:822992
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/15/11/3868/pdf
    Download Restriction: no

    File URL: https://www.mdpi.com/1996-1073/15/11/3868/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Baoyang Cheng & Junjian Li & Shuai Jiang & Chunhua Lu & Hang Su & Fuwei Yu & Hanqiao Jiang, 2021. "Pore-Scale Investigation of Microscopic Remaining Oil Variation Characteristic in Different Flow Rates Using Micro-CT," Energies, MDPI, vol. 14(11), pages 1-16, May.
    2. Congcong Li & Shuoliang Wang & Qing You & Chunlei Yu, 2021. "A New Measurement of Anisotropic Relative Permeability and Its Application in Numerical Simulation," Energies, MDPI, vol. 14(16), pages 1-18, August.
    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. Zhenghuai Guo & Klaus Regenauer-Lieb & Phung Nhu Hao Vu & Zhenliang Guan, 2022. "Characteristics of Elastoplastic Consolidation by Compaction and Its Effects on Coal Permeability," Energies, MDPI, vol. 15(20), pages 1-35, October.
    2. Vladimir Valerievych Poplygin & Irina Sergeevna Poplygina & Viktor Antonovich Mordvinov, 2022. "Influence of Reservoir Properties on the Velocity of Water Movement from Injection to Production Well," Energies, MDPI, vol. 15(20), pages 1-14, October.

    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:jeners:v:15:y:2022:i:11:p:3868-:d:822992. 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.