Study of Slip Flow in Unconventional Shale Rocks Using Lattice Boltzmann Method: Effects of Boundary Conditions and TMAC

Moghaddam, Rasoul Nazari; Jamiolahmady, Mahmoud

doi:10.1007/s11242-017-0912-2

Cited by 21 publications

(7 citation statements)

References 57 publications

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“…Moghaddam et al 78 The capillary-based apparent permeability calculation model would overestimate the apparent permeability for gas flow in nanoporous media. Zhao et al 79 and Jia et al 37 The end effect caused by the complex pore structures makes the capillary-based apparent permeability calculation model less accurate.…”

Section: And Nazarimentioning

confidence: 99%

Minireview on Lattice Boltzmann Modeling of Gas Flow and Adsorption in Shale Porous Media: Progress and Future Direction

Zhao

Wang²,

Zhang

et al. 2023

Energy Fuels

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As an important unconventional resource, shale gas reservoirs have unique characteristics different from conventional oil and gas reservoirs. The ultrasmall pore sizes in shale induce the nanopore confinement effect on shale gas flow. In addition, shale rocks are rich in organic matter, which has strong interactions with gas molecules and results in gas adsorption. The lattice Boltzmann method (LBM) for micro-and nanoscale gas flow, which is originally designed for micro-electro-mechanical systems (MEMS), has been modified to simulate gas flow and adsorption in shale rocks. This work reviews four types of lattice Boltzmann models developed recently for shale gas flow/adsorption: (1) the slip-velocity-based LBM, (2) high-order LBM, (3) diffusion-based LBM, and (4) REV-scale LBM. Among these models, the slip-velocity-based LBM is widely used for shale gas modeling, which incorporates the slip boundary condition and Knudsen number (Kn)-determined relaxation time to simulate the nanopore confinement effect. To model the gas adsorption, the fluid−solid interaction force is introduced into the model, and the magnitude of this interaction force is usually obtained from the molecular level simulations. LBMs have been regarded as an efficient numerical tool to estimate the shale gas apparent permeability, to describe the pore-scale flow behaviors, and to address the influence of gas adsorption on shale gas storage and transport. Nevertheless, some challenges exist in current applications of LBMs for shale gas flow and adsorption simulations that are discussed in this minireview as well.

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Section: And Nazarimentioning

confidence: 99%

Minireview on Lattice Boltzmann Modeling of Gas Flow and Adsorption in Shale Porous Media: Progress and Future Direction

Zhao

Wang²,

Zhang

et al. 2023

Energy Fuels

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“…Moghaddam and Jamiolahmady. 23 studied the slip flow in a single channel. The effects of boundary conditions were discussed.…”

Section: Introductionmentioning

confidence: 99%

“…Wang et al proposed a gas flow under high Knudsen number for simulating shale gas reservoirs. Moghaddam and Jamiolahmady . studied the slip flow in a single channel.…”

Section: Introductionmentioning

confidence: 99%

Effects of Cracks and Geometric Parameters on the Flow in Shale

Zhang

2021

ACS Omega

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In recent years, shale oil/gas has become increasingly important in global energy. The natural pores of shale are mainly of micro–nano sizes and have the cross-scale characteristics, which makes the traditional method difficult and impractical in studying the seepage of shale. In order to obtain the characteristics of seepage of the crack-pore-throat system, the lattice Boltzmann method and dimensional analysis were used to study the seepage in an idealized crack-pore network. The influences of the geometric factors, including crack location, crack opening, and interval between two vertical neighbor throats and boundary conditions on the seepage were studied. The results show that the slip boundary conditions enhance the seepage rate. The enhancement with slip coefficients is nonuniform. The total flux is nearly equal when the crack is near either the inlet or outlet, but larger than that when the crack is located in the middle of the model. The flux ratio between the main throats when the crack is located near the outlet is the greatest. When the crack is near the outlet, the water channel is the largest possible while it is not easy to form when the crack is in the middle. With increase in the opening ratio of the crack-to-throat, the total flow of the system increases. The increase degree decreases with the increasing opening ratio. When the opening ratio is greater than 9, the increase in flux becomes very small. If the crack-pore-throat system is very uniform or even symmetric, the flow rate in the vertical throat/crack is very small. Hence, it is not beneficial to the gas/oil production and gas/oil displacement.

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“…However, predicting gas permeability through these rocks remains challenging because of the need to balance numeral accuracy and computational cost (Apostolopoulou et al 2019, Bonnaud et al 2012, Bui et al 2017, Fan et al 2002, Phan et al 2016, Qomi et al 2014. Among alternative approaches, lattice Boltzmann (LB) simulations are effective in studying fluid transport at intermediate length and time scales (i.e., the mesoscale) at a modest computational cost (Fathi et al 2012, Krüger et al 2017, Landry et al 2016, Moghaddam and Jamiolahmady 2017, Ren et al 2015, Succi and Succi 2018, Wang et al 2016. In this work, we consider the LB approach, as described in what follows.…”

Section: Introductionmentioning

confidence: 99%

Accurate permeability prediction in tight gas rocks via lattice Boltzmann simulations with an improved boundary condition

Fan

Phan

Striolo

2020

Journal of Natural Gas Science and Engineering

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Accurately predicting gas transport in rocks is required for enhancing the accuracy of field production models. The mesoscale lattice Boltzmann (LB) method can be implemented to predict gas permeability in porous rocks. However, the published LB results for the Klinkenberg effect are often inconsistent with the widely used Beskok-Karniadakis-Civan's (BKC) correlation. The culprit of the unphysical effect has been identified in the typically implemented boundary conditions (BCs). An improved BC is proposed herein to reliably predict gas permeability. Non-equilibrium molecular dynamics simulations are conducted to benchmark the proposed approach. The results show that the presented LB predictions for the Klinkenberg effect are quantitatively consistent with experimental data and the BKC correlation, indicating that the unphysical effects have been minimized. More importantly, a numerical consistency is achieved for describing the Klinkenberg effect at molecular through macroscopic scales. These observations are relevant for improving our ability to predict gas production from tight formations.

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Study of Slip Flow in Unconventional Shale Rocks Using Lattice Boltzmann Method: Effects of Boundary Conditions and TMAC

Cited by 21 publications

References 57 publications

Minireview on Lattice Boltzmann Modeling of Gas Flow and Adsorption in Shale Porous Media: Progress and Future Direction

Minireview on Lattice Boltzmann Modeling of Gas Flow and Adsorption in Shale Porous Media: Progress and Future Direction

Effects of Cracks and Geometric Parameters on the Flow in Shale

Accurate permeability prediction in tight gas rocks via lattice Boltzmann simulations with an improved boundary condition

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