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A Systematic Study to Assess Displacement Performance of a Naturally-Derived Surfactant in Flow Porous Systems

Author

Listed:
  • Aghil Moslemizadeh

    (Department of Petroleum Engineering, Amirkabir University of Technology (Tehran Polytechnic), Tehran 158754413, Iran
    Department of Production Engineering, China National Petroleum Corporation International (CNPCI), Tehran 1549943404, Iran)

  • Hossein Khayati

    (Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz 6318714317, Iran)

  • Mohammad Madani

    (Department of Petroleum Engineering, Amirkabir University of Technology (Tehran Polytechnic), Tehran 158754413, Iran
    Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz 6318714317, Iran)

  • Mehdi Ghasemi

    (Department of Petroleum Engineering, Amirkabir University of Technology (Tehran Polytechnic), Tehran 158754413, Iran)

  • Khalil Shahbazi

    (Department of Petroleum Engineering, Petroleum University of Technology, Ahwaz 6318714317, Iran)

  • Sohrab Zendehboudi

    (Faculty of Engineering and Applied Science, Memorial University, St. John’s, NL A1B 3X7, Canada)

  • Azza Hashim Abbas

    (School of Mining and Geosciences, Nazarbayev University, Nur Sultan 010000, Kazakhstan)

Abstract

For the first time, the present work assesses the feasibility of using Korean red ginseng root extract, a non-ionic surfactant, for the purposes of enhanced oil recovery (EOR). The surfactant is characterized by Fourier-transform infrared spectroscopy (FT-IR) analysis. Pendant drop and sessile drop techniques are employed to study the oil–water interfacial tension (IFT) and wettability nature of the sandstone rock, respectively. In addition, oil recovery enhancement is investigated using micromodel and core floods. In the salt-free system, IFT measurements indicate that the surfactant carries a critical micelle concentration of 5 g/L. In a saline medium (up to 50 g/L), the addition of a surfactant with different concentrations leads to an IFT reduction of 47.28–84.21%. In a constant surfactant concentration, a contact angle reduction is observed in the range of 5.61–9.30°, depending on salinity rate, revealing a wettability alteration toward more water-wet. Surfactant flooding in the glass micromodel provides a more uniform sweeping, which leads to an oil recovery enhancement of 3.02–11.19%, depending on the extent of salinity. An optimal salt concentration equal to 30 g/L can be recognized according to the results of previous tests. Surfactant flooding (10 g/L) in optimal salt concentration achieves an additional oil recovery of 7.52% after conventional water flooding.

Suggested Citation

  • Aghil Moslemizadeh & Hossein Khayati & Mohammad Madani & Mehdi Ghasemi & Khalil Shahbazi & Sohrab Zendehboudi & Azza Hashim Abbas, 2021. "A Systematic Study to Assess Displacement Performance of a Naturally-Derived Surfactant in Flow Porous Systems," Energies, MDPI, vol. 14(24), pages 1-21, December.
    • Handle: RePEc:gam:jeners:v:14:y:2021:i:24:p:8310-:d:698954
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    References listed on IDEAS

    as
    1. Olajire, Abass A., 2014. "Review of ASP EOR (alkaline surfactant polymer enhanced oil recovery) technology in the petroleum industry: Prospects and challenges," Energy, Elsevier, vol. 77(C), pages 963-982.
    2. Rui, Zhenhua & Wang, Xiaoqing & Zhang, Zhien & Lu, Jun & Chen, Gang & Zhou, Xiyu & Patil, Shirish, 2018. "A realistic and integrated model for evaluating oil sands development with Steam Assisted Gravity Drainage technology in Canada," Applied Energy, Elsevier, vol. 213(C), pages 76-91.
    3. Zhang, Zhien & Li, Yifu & Zhang, Wenxiang & Wang, Junlei & Soltanian, Mohamad Reza & Olabi, Abdul Ghani, 2018. "Effectiveness of amino acid salt solutions in capturing CO2: A review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 98(C), pages 179-188.
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