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Abnormal Phenomena and Mathematical Model of Fluid Imbibition in a Capillary Tube

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  • Wenquan Deng

    (State Key Laboratory of Oil and Gas Resources and Prospecting, China University of Petroleum at Beijing, Beijing 102249, China)

  • Tianbo Liang

    (State Key Laboratory of Oil and Gas Resources and Prospecting, China University of Petroleum at Beijing, Beijing 102249, China)

  • Shuai Yuan

    (State Key Laboratory of Oil and Gas Resources and Prospecting, China University of Petroleum at Beijing, Beijing 102249, China)

  • Fujian Zhou

    (State Key Laboratory of Oil and Gas Resources and Prospecting, China University of Petroleum at Beijing, Beijing 102249, China)

  • Junjian Li

    (State Key Laboratory of Oil and Gas Resources and Prospecting, China University of Petroleum at Beijing, Beijing 102249, China)

Abstract

At present, the imbibition behavior in tight rocks has been attracted increasing attention since spontaneous imbibition plays an important role in unconventional oil and gas development, such as increasing swept area and enhancing recovery rate. However, it is difficult to describe the imbibition behavior through imbibition experiment using tight rock core. To characterize the imbibition behavior, imbibition and drainage experiments were conducted among water, oil, and gas phases in a visible circular capillary tube. The whole imbibition process is monitored using a microfluidic platform equipped with a high frame rate camera. This study conducts two main imbibition experiments, namely liquid-displacing-air and water-displacing-oil experiments. The latter is a spontaneous imbibition that the lower-viscosity liquid displaces the higher-viscosity liquid. For the latter, the tendency of imbibition rate with time does not match with previous model. The experimental results indicate that it is unreasonable to take no account of the effect of accumulated liquid flowing out of the capillary tube on imbibition, especially in the imbibition experiments where the lower-viscosity liquid displaces the higher-viscosity liquid. A mathematical model is established by introducing an additional force to describe the imbibition behavior in capillary tube, and the model shows a good prediction effect on the tendency of imbibition rate with time. This study discovers and analyzes the effect of additional force on imbibition, and the analysis has significances to understand the imbibition behavior in tight rocks.

Suggested Citation

  • Wenquan Deng & Tianbo Liang & Shuai Yuan & Fujian Zhou & Junjian Li, 2022. "Abnormal Phenomena and Mathematical Model of Fluid Imbibition in a Capillary Tube," Energies, MDPI, vol. 15(14), pages 1-15, July.
    • Handle: RePEc:gam:jeners:v:15:y:2022:i:14:p:4994-:d:858417
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    References listed on IDEAS

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    1. Wenxiang Chen & Zubo Zhang & Qingjie Liu & Xu Chen & Prince Opoku Appau & Fuyong Wang, 2018. "Experimental Investigation of Oil Recovery from Tight Sandstone Oil Reservoirs by Pressure Depletion," Energies, MDPI, vol. 11(10), pages 1-17, October.
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    Cited by:

    1. Yuping Sun & Qiaojing Li & Cheng Chang & Xuewu Wang & Xuefeng Yang, 2022. "NMR-Based Shale Core Imbibition Performance Study," Energies, MDPI, vol. 15(17), pages 1-10, August.
    2. Daoyi Zhu, 2023. "New Advances in Oil, Gas, and Geothermal Reservoirs," Energies, MDPI, vol. 16(1), pages 1-4, January.

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