A quantitative analysis of flow properties and heterogeneity in shale rocks using computed tomography imaging and finite-element based simulation

Adeleye, James O.; Akanji, Lateef

doi:10.1016/j.jngse.2022.104742

Cited by 9 publications

(3 citation statements)

References 44 publications

(9 reference statements)

Supporting

Mentioning

Contrasting

Order By: Relevance

“…123 Adeleye et al examined pore morphology and its impact on the intrinsic permeability through direct flow simulation within the 3D micro-CT images of shale. 124 In the second group, different gas transport mechanisms are described directly by solving Boltzmann equation at arbitrary Kn, for example the direct simulation Monte Carlo (DSMC) method, the discrete velocity method (DVM) 125 etc. Based on the DSMC method, Li et al computed the gas permeabilities of representative pore geometries by the direct simulation Bhatnager−Gross−Krook (DSBGK) simulations over a wide range of Kn.…”

Section: Diffusion and Flowmentioning

confidence: 99%

“…In order to determine the intrinsic permeability, Navier–Stokes equations are solved using finite element method (FEM) or finite volume method (FVM) . Adeleye et al examined pore morphology and its impact on the intrinsic permeability through direct flow simulation within the 3D micro-CT images of shale . In the second group, different gas transport mechanisms are described directly by solving Boltzmann equation at arbitrary Kn, for example the direct simulation Monte Carlo (DSMC) method, the discrete velocity method (DVM) etc.…”

Section: Multiscale Flow Simulationmentioning

confidence: 99%

See 1 more Smart Citation

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Yang

Zhang

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

The complex and multiscale nature of shale gas transport imposes new challenges to the already well-developed techniques for conventional reservoirs, especially digital core analysis. Multiscale complicated pore systems and distinctive properties limit most reconstruction methods not applicable. High-precision imaging experiments play a key role in the characterization of pore structures and mineral components. While the exhilarating breakthroughs in physical experimental methods and hybrid superposition methods have made significant achievements in shale digital rock reconstruction, rapidly evolving deep learning methods also present a promising option. Benefiting from the digital rock techniques, the pore-scale flow of shale gas can be directly simulated based on digital rock or indirectly modeled using the pore network model. It is precise and realistic to investigate the shale gas flow at the pore scale considering the desorption, surface diffusion, and slippage in nanopores. In this paper, we reviewed the recent advances in off-mentioned methods and processes and presented a hand for the research in this field.

show abstract

Section: Diffusion and Flowmentioning

confidence: 99%

Section: Multiscale Flow Simulationmentioning

confidence: 99%

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Yang

Zhang

et al. 2023

Energy Fuels

View full text Add to dashboard Cite

show abstract

“…One noninvasive method is computed X-ray tomography (CT), which enables the 3D analysis of pores and fractures (Arns et al 2005, Cnudde & Boone 2013, Backeberg et al 2017. CT images can be used for qualitative and quantitative characterization of the pores and rock filtration abilities (Soulaine et al 2016, Lu et al 2018, as well as for the generation of 3D geometrical models for simulation purposes, e.g., thermal or fluid flow (Krakowska & Madejski 2019, Adeleye & Akanji 2022, Al Balushi & Taleghani 2022. CT images bring new insights in the evaluation of pore size and shape.…”

Section: Introductionmentioning

confidence: 99%

New filtration parameters from X-ray computed tomography for tight rock images

Krakowska-Madejska

2022

geol

View full text Add to dashboard Cite

New parameters are proposed to evaluate the filtration properties of rocks obtained on the basis of 3D interpretation of images from X-ray computed tomography. The analyzed parameters are: global average pore connectivity, average blind pore connectivity, blind pore coefficient per object and blind pore coefficient per branch. The 3D pore space from computed X-ray tomography must be subjected to a process of pore space transformation into a skeleton. Then, the presented parameters can be evaluated, taking into consideration the pore channels (branches), pore channel connection points (junctions) and blind pores (pore without connection to the other pore). The calculations were made for low porosity sandstones, mudstones, limestones, and dolomites which differ in terms of age and depth of present deposition. The global average pore connectivity reflects the degree of development of the pore space in which the formation fluid can flow. The higher the global average pore connectivity, the most complex the pore structure can be expected. The higher the parameter of the average blind pore connectivity, the worse are the filtration properties of the rock. The higher the concentration of blind pore coefficient per object or branch, the worse the filtration properties of the rock. Moreover, new parameters were compared with the Euler characteristic and coordination number, revealing a high consistency.

show abstract

Tortuosity of pore channels in tight rocks as a key parameter in fluid flow ability

Krakowska-Madejska

2024

Acta Geophys.

View full text Add to dashboard Cite

Tortuosity is a significant parameter in porous materials analysis. Not only, when it comes to rocks or soils but also cellular materials, alloys or cells, the multiple definitions exist for tortuosity and several purposes. Geometrical tortuosity describes the pore network paths; on the other hand thermal, diffusional, electrical and hydraulic tortuosity refers to the transport processes in the pore network. Computed X-ray tomography (CT) is the best solution in tortuosity estimation, thanks to the 3D images. In particular, computed X-ray tomography, together with mercury porosimetry (MICP), pulse- and pressure-decay permeability methods (PDP), as well as electrical parameter measurements (EPM), links and expands the information about the tortuosity into the greater meaning. The geological material was composed of tight, low-porosity and low-permeability gas-saturated rocks cored from the present depth of deposition below 3000 m, containing different lithologies, as sandstones, mudstones, limestones, and dolomites. The research presents the novel approach in the identification and analysis of the main pore channels based on 3D CT images. Algorithm of the central axis identifies and analyzes the whole main flow path and calculates tortuosity. High correlation was observed between the tortuosity and Swanson parameter from mercury porosimetry data. Moreover, the high correlation was detected between the tortuosity and saturation exponent from electrical parameter measurement in analyzed tight low-porosity and low-permeability deposits. Multilinear regression (MLR) allows estimating absolute permeability taking CT, MICP and EPM parameters into consideration. Combination of these parameters in one equation with high determination coefficient gives credence in estimating preliminary absolute permeability (PDP) based on the data which is executed as standard core analysis (MICP and EPM) and data from the non-invasive method (CT).

show abstract

A quantitative analysis of flow properties and heterogeneity in shale rocks using computed tomography imaging and finite-element based simulation

Cited by 9 publications

References 44 publications

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

Recent Advances in Multiscale Digital Rock Reconstruction, Flow Simulation, and Experiments during Shale Gas Production

New filtration parameters from X-ray computed tomography for tight rock images

Tortuosity of pore channels in tight rocks as a key parameter in fluid flow ability

Contact Info

Product

Resources

About