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Rheological Properties of Crude Oil and Produced Emulsion from CO 2 Flooding

Author

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  • Mingzheng Qiao

    (School of Energy and Power Engineering, Xi’an Jiaotong University, Xi’an 710049, China
    Energy Strategy and Low-Carbon Development Research Center, Sichuan Energy Internet Research Institute, Tsinghua University, Chengdu 610213, China)

  • Fan Zhang

    (Energy Strategy and Low-Carbon Development Research Center, Sichuan Energy Internet Research Institute, Tsinghua University, Chengdu 610213, China
    Department of Energy and Power Engineering, Tsinghua University, Beijing 100084, China)

  • Weiqi Li

    (Energy Strategy and Low-Carbon Development Research Center, Sichuan Energy Internet Research Institute, Tsinghua University, Chengdu 610213, China
    Department of Energy and Power Engineering, Tsinghua University, Beijing 100084, China)

Abstract

Carbon Capture, Utilization and Storage (CCUS) technology is recognized as a pivotal strategy to mitigate global climate change. The CO 2 storage and enhanced oil recovery (CCUS-EOR) technology not only enhances oil recovery rates but also contributes to significant reductions in CO 2 emissions, with significant social and economic benefits. This paper examines the application of CO 2 -EOR technology in both enhancing oil recovery and facilitating geological CO 2 storage, and analyzes its implementation status and differences in the United States and China. Through experimental investigations conducted in a specific oilfield, we analyze the effects of dissolved CO 2 on the viscosity–temperature characteristics, yield value under pressure, stability, and rheological properties of crude oil and produced fluids. Additionally, we assess the demulsification effectiveness of various demulsifiers. Our findings indicate that both dissolved CO 2 in crude oil and emulsions exhibit non-Newtonian fluid behavior characterized by shear thinning, and the viscosity decreases with the increase in temperature and pressure. Furthermore, the presence of dissolved CO 2 exacerbates the oil–water separation phenomenon in produced fluids, thereby diminishing emulsion stability. The increase in emulsion concentration and the increase in emulsification temperature are both conducive to improving the emulsification rate. These research results provide critical insights for pipeline design and pump selection in oilfield production processes.

Suggested Citation

  • Mingzheng Qiao & Fan Zhang & Weiqi Li, 2025. "Rheological Properties of Crude Oil and Produced Emulsion from CO 2 Flooding," Energies, MDPI, vol. 18(3), pages 1-16, February.
    • Handle: RePEc:gam:jeners:v:18:y:2025:i:3:p:739-:d:1584655
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    References listed on IDEAS

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    1. Anna Samnioti & Vassilis Gaganis, 2023. "Applications of Machine Learning in Subsurface Reservoir Simulation—A Review—Part I," Energies, MDPI, vol. 16(16), pages 1-43, August.
    2. Anna Samnioti & Vassilis Gaganis, 2023. "Applications of Machine Learning in Subsurface Reservoir Simulation—A Review—Part II," Energies, MDPI, vol. 16(18), pages 1-53, September.
    3. Ren, Bo & Duncan, Ian J., 2019. "Reservoir simulation of carbon storage associated with CO2 EOR in residual oil zones, San Andres formation of West Texas, Permian Basin, USA," Energy, Elsevier, vol. 167(C), pages 391-401.
    4. Min Thura Mon & Roengchai Tansuchat & Woraphon Yamaka, 2024. "CCUS Technology and Carbon Emissions: Evidence from the United States," Energies, MDPI, vol. 17(7), pages 1-18, April.
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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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