Speaker
Description
To investigate the fluid imbibition behavior in the micro-nanopores of shale reservoirs, a comprehensive dynamic model is established based on the capillary tube approach, incorporating the effects of capillary force, displacement pressure, oil phase buoyancy, viscous resistance, and gravity. By introducing tortuosity to characterize pore path complexity and employing the Lambert W function, an explicit analytical solution for the time dependent imbibition distance is derived. Model validation demonstrates that the proposed solution reduces to and agrees well with the classical Lucas–Washburn equation under simplified single phase conditions. Sensitivity analysis indicates that increasing the displacement pressure significantly enhances the ultimate imbibition distance and shortens the time to reach steady state. Larger pore radii and lower tortuosity both promote faster imbibition rates. In addition, greater inclination angles impede the imbibition process, particularly under hydrophilic conditions. The study further highlights the critical role of wettability in regulating imbibition dynamics by altering the direction of capillary forces. This model provides a theoretical framework for the quantitative characterization of imbibition behavior and fracture optimization in shale reservoirs, offering valuable insights for improving shale oil recovery.
| Country | China |
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