Image-based micro-continuum model for gas flow in organic-rich shale rock

• Published in: Advances in water resources Vol. 122; pp. 70 - 84
• Main Authors: Guo, Bo, Ma, Lin, Tchelepi, Hamdi A.
• Format: Journal Article
• Language: English
• Published: Oxford Elsevier Ltd 01.12.2018; Elsevier Science Ltd
• Subjects: Computational fluid dynamics; Computer applications; Computer simulation; Continuum modeling; Darcy–Brinkman–Stokes; Diffusion; Diffusion effects; Digital imaging; Dye dispersion; Dynamics; Fluid dynamics; Frameworks; Gas flow; Heterogeneity; High resolution; Image resolution; Instruments; Mathematical models; Micro-continuum; Nanoporous media; Organic chemistry; Organic matter; Permeability; Physics; Pores; Porosity; Regions; Resolution; Rocks; Sediment samples; Sedimentary rocks; Shale; Shale gas; Spatial distribution; Stokes flow; Surface diffusion; Three dimensional flow; Micro-continuum; Darcy–Brinkman–Stokes; Nanoporous media; Shale gas
• ISSN: 0309-1708; 1872-9657
• DOI: 10.1016/j.advwatres.2018.10.004

The physical mechanisms that control the flow dynamics in organic-rich shale are not well understood. The challenges include nanometer-scale pores and multiscale heterogeneity in the spatial distribution of the constituents. Recently, digital rock physics (DRP), which uses high-resolution images of rock samples as input for flow simulations, has been used for shale. One important issue with images of shale rock is sub-resolution porosity (nanometer pores below the instrument resolution), which poses serious challenges for instruments and computational models. Here, we present a micro-continuum model based on the Darcy–Brinkman–Stokes framework. The method couples resolved pores and unresolved nano-porous regions using physics-based parameters that can be measured independently. The Stokes equation is used for resolved pores. The unresolved nano-porous regions are treated as a continuum, and a permeability model that accounts for slip-flow and Knudsen diffusion is employed. Adsorption/desorption and surface diffusion in organic matter are also accounted for. We apply our model to simulate gas flow in a high-resolution 3D segmented image of shale. The results indicate that the overall permeability of the sample (at fixed pressure) depends on the time scale. Early-time permeability is controlled by Stokes flow, while the late-time permeability is controlled by non-Darcy effects and surface-diffusion.