Abstract
Quadrant geometry with permeability and wettability contrast occurs in different events, such as faults, wellbore damage, and perforation zones. In these events, understanding the dynamics of immiscible fluid displacement is vital for enhanced oil recovery. Fluid flow studies showed that viscous fingering occurs due to viscous instabilities that depend on the mobility of fluids and capillary forces. Besides, the porous domain heterogeneity is also effective on the formation of fingering. So, the purpose of the current research is to numerically investigate the effect of heterogeneity in wettability and permeability, and flow properties in Saffmann-Taylor instabilities. Numerical simulations with different flow rates in the permeability contrast model illustrated the nodal crossflow, growth of viscous fingering in the nodal part, and bypass flow in the second zone. In the wettability contrast model, a capillary fingering pattern is observed and fluid patches are isolated because of capillary force and the end effects are trapped within the quadrant. Moreover, the consequences of wettability on apparent wettability that alters the fluid-front pattern and displacement efficiency are shown.
Highlights
Understanding the true fluid movement path and displacement pattern is necessary for efficient hydrocarbon reservoir production management (Dawe, 1998)
Shale and sandstone rocks are placed in the quadrant geometry
In addition, heterogeneity are three factors that are important in immiscible fluid flow and fingering formation
Summary
Understanding the true fluid movement path and displacement pattern is necessary for efficient hydrocarbon reservoir production management (Dawe, 1998). The evaluation of the nodal flow near the wellbores is challenging when acids or remedial fluids with an overbalanced pressure are pushed into the formation. These fluids are pushed through the permeable areas, while low permeable areas remain intact. The displacing fluid cannot alter the properties of the low permeable regions for enhanced oil recovery (EOR) (Wei, 2017; Vulin et al, 2018; Alawi et al, 2020). The current research focused on immiscible fluid flow instabilities across the nodal part of a heterogeneous porous medium with heterogeneity in permeability and wettability
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