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CT coreflood study of foam flow for enhanced oil recovery: The effect of oil type and saturation

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  • Tang, Jinyu
  • Vincent-Bonnieu, Sebastien
  • Rossen, William R.

Abstract

We present a CT coreflood study of foam, both pre-generated and generated in-situ, displacing oil, as a function of oil type and saturation. Foam generation and propagation are reflected through sectional pressure measurements. Dual-energy CT imaging monitors in-time phase saturations. With an oil less harmful to foam (hexadecane), injection with and without pre-generation of foam exhibits similarities: propagation of a foam bank through a core and later refinement of foam texture. In contrast, with an oil destabilizing to foam (with 20 wt% oleic acid in the hexadecane), pre-generation of foam behaves very differently from co-injection, suggesting very-different effects on foam generation and propagation. Without pre-generation, strong-foam generation is very difficult even at residual oil saturation (about 0.1); generation finally starts from the outlet (likely a result of the capillary-end effect). This strong-foam state propagates upstream very slowly. Pre-generated foam shows two stages of propagation, both from the inlet to outlet. First, weak foam displaces most of the oil, followed by a propagation of stronger foam at lower oil saturation. This dependence on injection method with harmful oil is not represented in currently applied foam models, which need further improvements for reliable prediction of foam for enhanced oil recovery.

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  • Tang, Jinyu & Vincent-Bonnieu, Sebastien & Rossen, William R., 2019. "CT coreflood study of foam flow for enhanced oil recovery: The effect of oil type and saturation," Energy, Elsevier, vol. 188(C).
    • Handle: RePEc:eee:energy:v:188:y:2019:i:c:s0360544219317165
    DOI: 10.1016/j.energy.2019.116022
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    References listed on IDEAS

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    1. Zuloaga, Pavel & Yu, Wei & Miao, Jijun & Sepehrnoori, Kamy, 2017. "Performance evaluation of CO2 Huff-n-Puff and continuous CO2 injection in tight oil reservoirs," Energy, Elsevier, vol. 134(C), pages 181-192.
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    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.
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    Cited by:

    1. Wu, Qianhui & Ding, Lei & Zhang, Lei & Ge, Jijiang & Rahman, Mohammad Azizur & Economou, Ioannis G. & Guérillot, Dominique, 2023. "Polymer enhanced foam for improving oil recovery in oil-wet carbonate reservoirs: A proof of concept and insights into the polymer-surfactant interactions," Energy, Elsevier, vol. 264(C).
    2. Ping Yue & Feng Liu & Kai Yang & Chunshuo Han & Chao Ren & Jiangtang Zhou & Xiukun Wang & Quantang Fang & Xinxin Li & Liangbin Dou, 2022. "Micro-Displacement and Storage Mechanism of CO 2 in Tight Sandstone Reservoirs Based on CT Scanning," Energies, MDPI, vol. 15(17), pages 1-16, August.
    3. Ayomikun Bello & Anastasia Ivanova & Alexey Cheremisin, 2023. "Foam EOR as an Optimization Technique for Gas EOR: A Comprehensive Review of Laboratory and Field Implementations," Energies, MDPI, vol. 16(2), pages 1-52, January.
    4. Hanamertani, Alvinda Sri & Ahmed, Shehzad, 2021. "Probing the role of associative polymer on scCO2-Foam strength and rheology enhancement in bulk and porous media for improving oil displacement efficiency," Energy, Elsevier, vol. 228(C).

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