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The Numerical Simulation Study of the Oil–Water Seepage Behavior Dependent on the Polymer Concentration in Polymer Flooding

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  • Qiong Wang

    (State Key Laboratory of Offshore Oil Exploitation, Beijing 100028, China
    School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China)

  • Xiuwei Liu

    (School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China)

  • Lixin Meng

    (Dagang Oilfield Company, PetroChina, Tianjin 300280, China)

  • Ruizhong Jiang

    (School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China)

  • Haijun Fan

    (School of Petroleum Engineering, China University of Petroleum (East China), Qingdao 266580, China)

Abstract

It is well acknowledged that due to the polymer component, the oil–water relative permeability curve in polymer flooding is different from the curve in waterflooding. As the viscoelastic properties and the trapping number are presented for modifying the oil–water relative permeability curve, the integration of these two factors for the convenience of simulation processes has become a key issue. In this paper, an interpolation factor Ω that depends on the normalized polymer concentration is firstly proposed for simplification. Then, the numerical calculations in the self-developed simulator are performed to discuss the effects of the interpolation factor on the well performances and the applications in field history matching. The results indicate that compared with the results of the commercial simulator, the simulation with the interpolation factor Ω could more accurately describe the effect of the injected polymer solution in controlling water production, and more efficiently simplify the combination of factors on relative permeability curves in polymer flooding. Additionally, for polymer flooding history matching, the interpolation factor Ω is set as an adjustment parameter based on core flooding results to dynamically consider the change of the relative permeability curves, and has been successfully applied in the water cut matching of the two wells in Y oilfield. This investigation provides an efficient method to evaluate the seepage behavior variation of polymer flooding.

Suggested Citation

  • Qiong Wang & Xiuwei Liu & Lixin Meng & Ruizhong Jiang & Haijun Fan, 2020. "The Numerical Simulation Study of the Oil–Water Seepage Behavior Dependent on the Polymer Concentration in Polymer Flooding," Energies, MDPI, vol. 13(19), pages 1-19, October.
    • Handle: RePEc:gam:jeners:v:13:y:2020:i:19:p:5125-:d:422841
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    References listed on IDEAS

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    1. Yaohao Guo & Lei Zhang & Guangpu Zhu & Jun Yao & Hai Sun & Wenhui Song & Yongfei Yang & Jianlin Zhao, 2019. "A Pore-Scale Investigation of Residual Oil Distributions and Enhanced Oil Recovery Methods," Energies, MDPI, vol. 12(19), pages 1-16, September.
    2. Huiying Zhong & Weidong Zhang & Jing Fu & Jun Lu & Hongjun Yin, 2017. "The Performance of Polymer Flooding in Heterogeneous Type II Reservoirs—An Experimental and Field Investigation," Energies, MDPI, vol. 10(4), pages 1-19, April.
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    Cited by:

    1. Maaike Berger & Francesco Picchioni & Pablo Druetta, 2022. "Simulation of Polymer Chemical Enhanced Oil Recovery in Ghawar Field," Energies, MDPI, vol. 15(19), pages 1-31, October.
    2. Changlin Liao & Xinwei Liao & Ruifeng Wang & Jing Chen & Jiaqi Wu & Min Feng, 2022. "A Method for Evaluating the Dominant Seepage Channel of Water Flooding in Layered Sandstone Reservoir," Energies, MDPI, vol. 15(23), pages 1-12, November.

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