Publicado 12 números por año
ISSN Imprimir: 1091-028X
ISSN En Línea: 1934-0508
Indexed in
FLUID FLOW THROUGH A FRACTURED POROUS RESERVOIR USING CFD MODELING
SINOPSIS
When considering fluid flow through subsurface reservoirs, the complex characteristics of natural fractures, along with the surrounding porous domain, significantly influence the fluid dynamics within the reservoir. It is of paramount importance for such features and their influence on fluid flow and transport behavior to be fully understood to allow optimized hydrocarbon production and recovery. Two two-dimensional fracture profiles were generated within a square porous domain to model the fluid flow for different pressure and permeability conditions for both an isotropic and anisotropic reservoir environment. For low-permeability reservoirs, around 10%–11% increase in maximum velocity is obtained, changing the interface condition from wall to porous. However, for high-permeability reservoirs, a reverse trend is noticed, which was explained due to the fracture geometry. By increasing the inlet pressure, it was found that the maximum velocity through the fracture increased for the isotropic reservoir with both wall and porous boundary conditions. For an anisotropic reservoir, it was observed that the permeability in both longitudinal and transverse directions influenced the maximum velocity, although the permeability in the transverse direction must be adequately significant before the permeability in the longitudinal direction has a substantial impact on the maximum velocity of flow through porous media. Furthermore, the effect of variation in longitudinal and transverse permeability over the pressure distribution through the porous media is explained.
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