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Journal of Porous Media
Impact-faktor: 1.49 5-jähriger Impact-Faktor: 1.159 SJR: 0.43 SNIP: 0.671 CiteScore™: 1.58

ISSN Druckformat: 1091-028X
ISSN Online: 1934-0508

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Journal of Porous Media

DOI: 10.1615/JPorMedia.2019029084
pages 611-629

FLUID FLOW THROUGH A FRACTURED POROUS RESERVOIR USING CFD MODELING

Ryan Noble
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom
Sheikh Zahidul Islam
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom
Ghazi Droubi
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom
Mamdud Hossain
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom
Kirsten Stephen
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom
Yatin Suri
School of Engineering, Robert Gordon University, The Sir Ian Wood Building, Garthdee Road, Aberdeen, AB10 7GJ, United Kingdom

ABSTRAKT

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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