The spontaneous imbibition of fracturing fluid in the shale matrix is one of the main reasons for the low hydraulic fracturing flowback rate. The distribution characteristics of fracturing fluid in the shale spontaneous imbibition process are studied by the low field nuclear magnetic resonance (NMR) method. An improved pseudo-potential lattice Boltzmann model is proposed to simulate the spontaneous imbibition behavior in a three-dimensional porous shale structure. The results show that the viscosity, sample length, and permeability of the imbibition solution have an important influence on the imbibition characteristics of the samples. In the imbibition process based on the SC-LBM model, due to the capillary force effect, the imbibition liquid preferentially enters the larger pores of the wetting phase and then gradually distributes in the adjacent pores.
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The study has been performed with the financial support of the National Key R & D Program of China (2016YFC0600705), National Major Project for Science and Technology of China (2017ZX05003-006), National Natural Science Foundation of China (Grant No. U1562217, 51679251, 51727807), China Postdoctoral Science Foundation (Grant No. 2017M610877), and National Science and Technology Major Project on Oil and Gas (No.2017ZX05013001).
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Translated from Khimiya i Tekhnologiya Topliv i Masel, No. 2, pp. 100 — 105, March — April, 2021.
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Cheng, H., Zhang, J., Leng, R. et al. Mechanism of Imbibition in Shale Pores Based on Imbibition Nuclear Magnetic Experiment and LBM Method. Chem Technol Fuels Oils 57, 387–395 (2021). https://doi.org/10.1007/s10553-021-01257-4
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DOI: https://doi.org/10.1007/s10553-021-01257-4