Beyond dual-porosity modeling for the simulation of complex flow mechanisms in shale reservoirs

DOI10.1007/s10596-015-9548-xzbMath1392.86028OpenAlexW3160245480MaRDI QIDQ722783

Yuhe Wang, Bicheng Yan, John E. Killough

Publication date: 27 July 2018

Published in: Computational Geosciences (Search for Journal in Brave)

Full work available at URL: https://doi.org/10.1007/s10596-015-9548-x

zbMATH Keywords

upscalingrandom distributionapparent permeabilitymicro- and nano-pore systemsmultiple porosity modelshale reservoirs

Mathematics Subject Classification ID

Sensitivity, stability, parametric optimization (90C31) Flows in porous media; filtration; seepage (76S05) Computational methods for problems pertaining to geophysics (86-08)

Related Items (9)

A locally conservative multiscale finite element method for multiphase flow simulation through heterogeneous and fractured porous media ⋮ Numerical simulation for shale gas flow in complex fracture system of fractured horizontal well ⋮ Beyond multiple-continuum modeling for the simulation of complex flow mechanisms in multiscale shale porous media ⋮ Multiphase flow modeling in multiscale porous media: an open-source micro-continuum approach ⋮ Multiscale model reduction for shale gas transport in poroelastic fractured media ⋮ Analytical analysis of gas diffusion into non-circular pores of shale organic matter ⋮ Coupling of multiscale and multi-continuum approaches ⋮ Bridging between macroscopic behavior of shale gas reservoirs and confined fluids in nanopores ⋮ Generalized multiscale multicontinuum model for fractured vuggy carbonate reservoirs

Uses Software

• GMINC

Cites Work

• A quasi steady state method for solving transient Darcy flow in complex 3D fractured networks accounting for matrix to fracture flow

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