IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v17y2024i23p6024-d1533426.html
   My bibliography  Save this article

Experimental Study on Enhanced Oil Recovery of Shallow Super-Heavy Oil in the Late Stage of the Multi-Cycle Huff and Puff Process

Author

Listed:
  • Chunyu Hu

    (Xinjiang Xinchun Petroleum Development Co., Ltd., Sinopec, Dongying 257000, China)

  • Jianqiang Tao

    (Xinjiang Xinchun Petroleum Development Co., Ltd., Sinopec, Dongying 257000, China)

  • Meng Feng

    (Oil Test Company, Karamay 834000, China
    CNPC Xibu Drilling Engineering Co., Ltd., Karamay 834000, China)

  • Qian Wang

    (Research Institute of Petroleum Exploration and Development, Xinjiang Oilfield Company, PetroChina, Karamay 834000, China)

  • Hui Cao

    (Exploration and Development Research Institute of Qinghai Oilfield Branch, China National Petroleum Corporation, Dunhuang 736202, China)

  • Hongmei Su

    (Xinjiang Uygur Autonomous Region Coalfield Geology Bureau 156 Coalfield Geological Exploration Team, Urumqi 830009, China)

  • Junke Sun

    (1st Oil Plant of PetroChina Qinghai Oil Field Branch Company 816499, Dunhuang 736202, China)

  • Wenfeng Wang

    (School of Geology and Mining Engineering, Xinjiang University, Urumqi 830017, China
    School of Resources and Geosciences, China University of Mining and Technology, Xuzhou 221116, China)

Abstract

The shallow, thin super-heavy oil reservoir demonstrates certain characteristics, such as shallow reservoir depths, low-formation temperature, and high crude oil viscosity at reservoir temperatures. In the current production process, the central area of P601 is undergoing high-frequency huff and puff operations, facing certain problems such as decreasing production, low recovery rates, and rapid depletion of formation pressure. Through physical simulation experiments, the various elements of HDNS-enhanced oil recovery technology were analyzed. Nitrogen plus an oil-soluble viscosity reducer can improve the thermal recovery and development effect of super-heavy oil. With the addition of the viscosity-reducing slug, the recovery rate of steam flooding was 58.61%, which was 23.32% higher than that of pure steam flooding; after adding the 0.8 PV nitrogen slug, the recovery rate increased to 76.48%. With the increased nitrogen injection dosage, the water breakthrough time was extended, the water cut decreased, and the recovery rate increased. Nitrogen also plays a role in profile control and plugging within the reservoir; this function can effectively increase the heating range, increase steam sweep efficiency, and reduce water cut. So, the synergistic effects of steam, nitrogen, and viscosity-reducing agents are good. This technology enhances the development of shallow-layer heavy oil reservoirs, and subsequent development technologies are being compared and studied to ensure the sustainable development of super-heavy oil reservoirs.

Suggested Citation

  • Chunyu Hu & Jianqiang Tao & Meng Feng & Qian Wang & Hui Cao & Hongmei Su & Junke Sun & Wenfeng Wang, 2024. "Experimental Study on Enhanced Oil Recovery of Shallow Super-Heavy Oil in the Late Stage of the Multi-Cycle Huff and Puff Process," Energies, MDPI, vol. 17(23), pages 1-13, November.
  • Handle: RePEc:gam:jeners:v:17:y:2024:i:23:p:6024-:d:1533426
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/17/23/6024/pdf
    Download Restriction: no

    File URL: https://www.mdpi.com/1996-1073/17/23/6024/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Zhang, Kaiqiang & Jia, Na & Li, Songyan & Liu, Lirong, 2019. "Static and dynamic behavior of CO2 enhanced oil recovery in shale reservoirs: Experimental nanofluidics and theoretical models with dual-scale nanopores," Applied Energy, Elsevier, vol. 255(C).
    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. Zhang, Xiaoying & Ma, Funing & Yin, Shangxian & Wallace, Corey D & Soltanian, Mohamad Reza & Dai, Zhenxue & Ritzi, Robert W. & Ma, Ziqi & Zhan, Chuanjun & Lü, Xiaoshu, 2021. "Application of upscaling methods for fluid flow and mass transport in multi-scale heterogeneous media: A critical review," Applied Energy, Elsevier, vol. 303(C).
    2. Wang, Tianyu & Tian, Shouceng & Li, Gensheng & Zhang, Liyuan & Sheng, Mao & Ren, Wenxi, 2021. "Molecular simulation of gas adsorption in shale nanopores: A critical review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 149(C).
    3. Guo Wang & Rui Shen & Shengchun Xiong & Yuhao Mei & Qinghao Dong & Shasha Chu & Heying Su & Xuewei Liu, 2025. "Research Progress on Nano-Confinement Effects in Unconventional Oil and Gas Energy—With a Major Focus on Shale Reservoirs," Energies, MDPI, vol. 18(1), pages 1-41, January.
    4. Wang, Hui & Chen, Li & Qu, Zhiguo & Yin, Ying & Kang, Qinjun & Yu, Bo & Tao, Wen-Quan, 2020. "Modeling of multi-scale transport phenomena in shale gas production — A critical review," Applied Energy, Elsevier, vol. 262(C).
    5. Wang, Chao & Liu, Bo & Mohammadi, Mohammad-Reza & Fu, Li & Fattahi, Elham & Motra, Hem Bahadur & Hazra, Bodhisatwa & Hemmati-Sarapardeh, Abdolhossein & Ostadhassan, Mehdi, 2024. "Integrating experimental study and intelligent modeling of pore evolution in the Bakken during simulated thermal progression for CO2 storage goals," Applied Energy, Elsevier, vol. 359(C).
    6. Guo, Yaohao & Liu, Fen & Qiu, Junjie & Xu, Zhi & Bao, Bo, 2022. "Microscopic transport and phase behaviors of CO2 injection in heterogeneous formations using microfluidics," Energy, Elsevier, vol. 256(C).
    7. Song, Yilei & Song, Zhaojie & Chen, Zhangxin & Zhang, Lichao & Zhang, Yunfei & Feng, Dong & Wu, Zhengbin & Wu, Jiapeng, 2024. "Fluid phase behavior in multi-scale shale reservoirs with nano-confinement effect," Energy, Elsevier, vol. 289(C).
    8. Zhang, Xue & Su, Yuliang & Li, Lei & Da, Qi'an & Hao, Yongmao & Wang, Wendong & Liu, Jiahui & Gao, Xiaogang & Zhao, An & Wang, Kaiyu, 2022. "Microscopic remaining oil initiation mechanism and formation damage of CO2 injection after waterflooding in deep reservoirs," Energy, Elsevier, vol. 248(C).

    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:17:y:2024:i:23:p:6024-:d:1533426. 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.