A Feature-Based Stochastic Permeability of Shale: Part 2–Predicting Field-Scale Permeability

Singh, Harpreet; Cai, Jianchao

doi:10.1007/s11242-018-1076-4

Cited by 13 publications

(10 citation statements)

References 32 publications

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“…And the effects of Knudsen diffusion and slip flow on production rate and cumulative production increases with the decrease of pore radius. Although the proposed study shows the importance of matrix as a significant source of gas in the total gas production, there are studies that do not endorse these results in that the importance of matrix relative to fractures in total production is insignificant.…”

Section: Resultsmentioning

confidence: 76%

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Huang

Cao

Yuan

et al. 2019

Energy Science & Engineering

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Multiflow mechanisms coexist in shale gas reservoirs (SGRs) due to the abundant nanopores and the organic matter as a medium of gas souring and storage. The gas transport mechanisms in nanopores including bulk gas transfer and adsorption‐gas surface diffusion were already investigated in pore‐scale models, but their effects on actual gas production of multistage fractured horizontal wells in SGRs are not clearly understood, which are crucial for the economic development of unconventional resources. Therefore, a comprehensive apparent permeability (AP) model which couples the surface diffusion of adsorbed gas, slippage flow considering the additional flux generated by surface diffusion based on Langmuir's theory, and Knudsen diffusion is established. The presented model is validated with the experimental data and lattice Boltzmann method (LBM) simulation results. Then, we propose a numerical model which combines multiflow mechanisms in microscale pores and a multistage fractured horizontal well (MSFHW) in macroscale shale gas reservoirs together. The effects of different transport mechanisms on both AP of nanopores and gas production are analyzed thoroughly. The results show that the effect of surface diffusion on the apparent permeability of nanopores is much greater than that on the actual gas production of MSFHW, and the influence of high‐pressure condition must be considered when calculating the surface diffusion coefficient. The presented numerical model has important implications for accurate numerical simulation and efficient development of shale gas reservoirs.

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Section: Resultsmentioning

confidence: 76%

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Huang

Cao

Yuan

et al. 2019

Energy Science & Engineering

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“…e typical characteristics of a shale reservoir include low porosity, low permeability [185,186], complex network of matrix-fracture systems [187][188][189][190][191], and heterogeneous mineralogy [181,182,[192][193][194][195], and the combination of these characteristics presents a unique challenge in understanding the fluid flow and fluid-rock and fluid-fluid interactions in these reservoirs. Following theoretical considerations, some studies explored the fluid flow in these reservoirs as a function of convection, slip flow, Knudsen diffusion [196][197][198][199][200][201], surface diffusion/sorption [202][203][204][205][206][207][208][209][210], rock-mechanics [189,[211][212][213][214][215], and osmosis [216][217][218].…”

Section: Literature Reviewmentioning

confidence: 99%

Critical Review of Fluid Flow Physics at Micro‐ to Nano‐scale Porous Media Applications in the Energy Sector

Singh

Myong

2018

Advances in Materials Science and Engineering

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While there is a consensus in the literature that embracing nanodevices and nanomaterials helps in improving the efficiency and performance, the reason for the better performance is mostly subscribed to the nanosized material/structure of the system without sufficiently acknowledging the role of fluid flow mechanisms in these systems. This is evident from the literature review of fluid flow modeling in various energy-related applications, which reveals that the fundamental understanding of fluid transport at micro- and nanoscale is not adequately adapted in models. Incomplete or insufficient physics for the fluid flow can lead to untapped potential of these applications that can be used to increase their performance. This paper reviews the current state of research for the physics of gas and liquid flow at micro- and nanoscale and identified critical gaps to improve fluid flow modeling in four different applications related to the energy sector. The review for gas flow focuses on fundamentals of gas flow at rarefied conditions, the velocity slip, and temperature jump conditions. The review for liquid flow provides fundamental flow regimes of liquid flow, and liquid slip models as a function of key modeling parameters. The four porous media applications from energy sector considered in this review are (i) electrokinetic energy conversion devices, (ii) membrane-based water desalination through reverse osmosis, (iii) shale reservoirs, and (iv) hydrogen storage, respectively. Review of fluid flow modeling literature from these applications reveals that further improvements can be made by (i) modeling slip length as a function of key parameters, (ii) coupling the dependency of wettability and slip, (iii) using a reservoir-on-chip approach that can enable capturing the subcontinuum effects contributing to fluid flow in shale reservoirs, and (iv) including Knudsen diffusion and slip in the governing equations of hydrogen gas storage.

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“…However, shale permeability does not adhere to Darcy’s law due to tiny pore sizes and heterogeneity that affect fluid flow in many ways not described by Darcy’s law. In other words, shale permeability is dynamic such that it does not necessarily remain constant and is impacted by different mechanisms of fluid transport besides advective flow. , The vast majority of expressions in the literature focus on predicting the permeability of the matrix. This work reviews gas transport in shale at two spatial scales: in a single nanopore and in a network of nanopores.…”

Section: Introductionmentioning

confidence: 99%

Gas Flow Models of Shale: A Review

et al. 2021

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Conventional flow models based on Darcy's flow physics fail to model shale gas production data accurately. The failure to match field data and laboratory-scale evidence of non-Darcy flow has led researchers to propose various gas-flow models for the shale reservoirs. There is extensive evidence that suggests the size of the pores in shale is microscopic in the range of a few to hundreds of nanometers (also known as nanopores). These small pores are mostly associated with the shale's organic matter portion, resulting in a dual pore system that adds to the gas flow complexity. Unlike Darcy's law, which assumes that a dominant viscous flux determines a rock's permeability, shale's permeability leads to other flow processes besides viscous flow such as gas slippage and Knudsen diffusion. This work reviews the dominant gas-flow processes in a single nanopore on the basis of theoretical models and molecular dynamics simulations, and lattice Boltzmann modeling. We extend the review to pore network models used to study the gas permeability of shale.

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A Feature-Based Stochastic Permeability of Shale: Part 2–Predicting Field-Scale Permeability

Cited by 13 publications

References 32 publications

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

A novel numerical model of gas transport in multiscale shale gas reservoirs with considering surface diffusion and Langmuir slip conditions

Critical Review of Fluid Flow Physics at Micro‐ to Nano‐scale Porous Media Applications in the Energy Sector

Gas Flow Models of Shale: A Review

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