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Experimental Study on Surfactant–Polymer Flooding After Viscosity Reduction for Heavy Oil in Matured Reservoir

Author

Listed:
  • Xiaoran Chen

    (School of Engineering Science, University of Chinese Academy of Sciences, Beijing 100049, China
    Institute of Porous Flow and Fluid Mechanics, Chinese Academy of Sciences, Langfang 065007, China
    PetroChina Research Institute of Petroleum Exploration and Development (RIPED), Beijing 100083, China)

  • Qingfeng Hou

    (PetroChina Research Institute of Petroleum Exploration and Development (RIPED), Beijing 100083, China)

  • Yifeng Liu

    (PetroChina Research Institute of Petroleum Exploration and Development (RIPED), Beijing 100083, China)

  • Gaohua Liu

    (PetroChina Liaohe Oilfield Company, Panjin 124010, China)

  • Hao Zhang

    (College of Safety and Ocean Engineering, China University of Petroleum, Beijing 102249, China)

  • Haojie Sun

    (College of Safety and Ocean Engineering, China University of Petroleum, Beijing 102249, China)

  • Zhuoyan Zhu

    (PetroChina Research Institute of Petroleum Exploration and Development (RIPED), Beijing 100083, China)

  • Weidong Liu

    (Institute of Porous Flow and Fluid Mechanics, Chinese Academy of Sciences, Langfang 065007, China
    PetroChina Research Institute of Petroleum Exploration and Development (RIPED), Beijing 100083, China)

Abstract

An advanced enhanced oil recovery (EOR) method was investigated, employing a surfactant–polymer (SP) system in combination with a viscosity reducer for application in a heavy oil reservoir within the Haiwaihe Block, Liaohe Oilfield, in China. Significant advantages were observed through the combination of LPS-3 (an anionic surfactant) and OAB (a betaine surfactant) in reducing interfacial tension and enhancing emulsion stability, with the optimal results achieved at the ratio of 9:1. The BRH-325 polymer was found to exhibit superior viscosity enhancement, temperature resistance, and long-term stability. Graphene nanowedges were utilized as a viscosity reducer, leading to a viscosity reduction in heavy oil of 97.43%, while stability was maintained over a two-hour period. The efficacy of the combined system was validated through core flooding experiments, resulting in a recovery efficiency improvement of up to 32.7%. It is suggested that the integration of viscosity reduction and SP flooding could serve as a promising approach for improving recovery in mature heavy oil reservoirs, supporting a transition toward environmentally sustainable, non-thermal recovery methods.

Suggested Citation

  • Xiaoran Chen & Qingfeng Hou & Yifeng Liu & Gaohua Liu & Hao Zhang & Haojie Sun & Zhuoyan Zhu & Weidong Liu, 2025. "Experimental Study on Surfactant–Polymer Flooding After Viscosity Reduction for Heavy Oil in Matured Reservoir," Energies, MDPI, vol. 18(3), pages 1-19, February.
    • Handle: RePEc:gam:jeners:v:18:y:2025:i:3:p:756-:d:1585328
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    Cited by:

    1. Yongheng Zhao & Jianlong Xiu & Lixin Huang & Lina Yi & Yuandong Ma, 2025. "Two-Dimensional Physical Simulation of the Seepage Law of Microbial Flooding," Energies, MDPI, vol. 18(5), pages 1-16, March.

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