Pore-scale simulation of gas displacement after water flooding using three-phase lattice Boltzmann method
KAUST DepartmentPhysical Science and Engineering (PSE) Division
Permanent link to this recordhttp://hdl.handle.net/10754/689980
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AbstractWater flooding is a commonly used technique to improve oil recovery, although the amount of oil left in reservoirs after the procedure is still significant. Gas displacement after water flooding is an effective way to recover residual oil, but the occurrence state and flow principles of multiphase fluid after gas injection are still ambiguous. Therefore, the gas displacement process after water flooding should be studied on the pore scale to provide a basis for formulating a reasonable gas injection program. Most of the current pore-scale studies focus on two-phase flow, while simulations that account for the influence of oil-gas miscibility and injected water are seldom reported. In this work, the multi-component multi-phase Shan-Chen lattice Boltzmann model is used to simulate the gas displacement after water flooding in a porous medium, and the effects of injected water, viscosity ratio, pore structure, and miscibility are analyzed. It is established that the injected water will cause gas flow path variations and lead to premature gas channeling. Under the impact of capillary pressure, the water retained in the porous medium during the water flooding stage further imbibes into the tiny pores during gas injection and displaces the remaining oil. When miscibility is considered, the oil-gas interface disappears, eliminating the influence of the capillary effect on the fluid flow and enabling the recovery of remaining oil at the corner. This study sheds light on the gas displacement mechanisms after water flooding from the pore-scale perspective and provides a potential avenue for improving oil recovery.
CitationWang, S., Chen, L., Feng, Q., Chen, L., Fang, C., & Cui, R. (2023). Pore-scale simulation of gas displacement after water flooding using three-phase lattice Boltzmann method. Capillarity, 6(2), 19–30. https://doi.org/10.46690/capi.2023.02.01
SponsorsThis work was supported partly by the Major Scientific and Technological Projects of CNPC (No. ZD2019-183-007), the National Natural Science Foundation of China (Nos. 52274055, U1762213 and 51974340), and the Shandong Provincial Natural Science Foundation (No. ZR2022YQ50).
PublisherYandy Scientific Press
Except where otherwise noted, this item's license is described as Archived with thanks to Capillarity under a Creative Commons license, details at: https://creativecommons.org/licenses/by-nc-nd/4.0/