A slip-flow model for multi-component shale gas transport in organic nanopores

Sun, Fengrui; Yao, Yuedong; Li, Guozhen; Li, Xiangfang

doi:10.1007/s12517-019-4303-6

Cited by 30 publications

(9 citation statements)

References 49 publications

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“…Generally, the Knudsen number is used to determine whether the fluid is suitable for the continuum hypothesis. The Knudsen number formula for mudstone gas migration is [49]…”

Section: The Controlling Effect Of Pore Structure On Gasmentioning

confidence: 99%

Pore Structure Characteristics, Genesis, and Its Controlling Effect on Gas Migration of Quaternary Mudstone Reservoir in Qaidam Basin

Tang

Shao

et al. 2022

Geofluids

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The Sanhu Depression in Qaidam Basin is the largest Quaternary biogenic gas exploration area with the shallowest burial depth in the world. The shallow high abundance of gas reservoirs and high-quality pure methane have become the main production areas. The development characteristics of loose mudstone reservoirs are restricted by extreme heterogeneity. Therefore, the Quaternary Qigequan Formation mudstone in Qaidam Basin is selected as the research object. Based on the study of the sedimentary background, petrological characteristics, and pore structure characteristics, by comparing the characteristics of different mudstone reservoirs, the controlling factors of the development of different mudstone reservoirs and the control of gas migration are clarified. Research shows the following: (1) The mudstone reservoirs of the Qigequan Formation mainly develop intergranular pores, clay mineral pores, and intragranular pores. The pore size distribution varies from nanometers to micrometers, and mesopores mainly contribute to the specific surface area. (2) Rigid minerals and clay minerals are the main controlling factors for the pore structure of mudstone reservoirs. The increase in the content of rigid minerals is conducive to the development of macropores or larger micropores, while the increase in the content of clay minerals is conducive to the development of mesopores and provides an important specific surface area for gas adsorption. (3) The gas migration form of pure mudstone is mainly dominated by Fick diffusion and slippage flow, which has the characteristics of self-sealing accumulation. The gas migration form of silty mudstone is the coexistence of Fick diffusion, slippage flow, and Darcy flow, which has the features of self-sealing and Darcy flow accumulation. The gas migration form of sandy mudstone is mainly Darcy flow, only with Darcy flow accumulation characteristics. The flow form of gas creates different accumulation modes of mudstone biogas. The Quaternary mudstone reservoir shows different particularity under different material components, and the exploration targets should be treated differently according to specific mudstone types.

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“…Generally, the Knudsen number is used to determine whether the fluid is suitable for the continuum hypothesis. The Knudsen number formula for mudstone gas migration is [49]…”

Section: The Controlling Effect Of Pore Structure On Gasmentioning

confidence: 99%

Pore Structure Characteristics, Genesis, and Its Controlling Effect on Gas Migration of Quaternary Mudstone Reservoir in Qaidam Basin

Tang

Shao

et al. 2022

Geofluids

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“…The macroscopic-scale mathematical model of shale gas flow can be obtained by substituting Eqs. (5) and (6) into Eq. (8) as: (9) Literature survey shows that there are several main upscaling methods of flow models from microscopic to macroscopic scale, i.e.…”

Section: Variations Of Viscous Flow and Diffusion With Kn (Dimensionlmentioning

confidence: 99%

“…Method (6): the pore network model including pore size distribution, anisotropy, and low connectivity of the pore structure, etc. in shale [54,55].…”

Section: Variations Of Viscous Flow and Diffusion With Kn (Dimensionlmentioning

confidence: 99%

“…After reviewing the upscaling methods in Table 3, it is obvious that the method used in this work is not a bad compromise when compared to method (1) which is too simple and coarse, methods (2) and (3) where it is impractical and daunting to count the size/shape of every single pore with huge computational efforts, method (5) where complex processing for the model establishment and solution is needed, and methods (4) and (6) where redundant parameters/information about pore structure need to be assumed or obtained from multiple ways. Therefore, on the one hand, only the pore size distribution experiment is needed for the determination of the upscaling parameters in this chapter to make the consideration of various pore sizes happen.…”

Section: Variations Of Viscous Flow and Diffusion With Kn (Dimensionlmentioning

confidence: 99%

See 1 more Smart Citation

Mechanism, Model, and Upscaling of the Gas Flow in Shale Matrix: Revisit

Hu¹,

Ya-Xiong²,

Li³

2022

Emerging Technologies in Hydraulic Fracturing and Gas Flow Modelling

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Shale gas accounts for an increasing proportion in the world's oil and gas supply, with the properties of low carbon, clean production, and huge potential for the compensation for the gradually depleted conventional resources. Due to the ubiquitous nanopores in shale matrix, the nanoscale gas flow becomes one of the most vital themes that are directly related to the formulation of shale gas development schemes, including the optimization of hydraulic fracturing, horizontal well spacing, etc. With regard to the gas flow in shale matrix, no commonly accepted consensus has been reached about the flow mechanisms to be considered, the coupled flow model in nanopores, and the upscaling method for its macroscopic form. In this chapter, the propositions of wall-associated diffusion, a physically sound flow mechanism scheme, a new coupled flow model in nanopores, the upscaling form of the proposed model, and the translation of lab-scale results into field-scale ones aim to solve the aforementioned issues. It is expected that this work will contribute to a deeper understanding of the intrinsic relationship among various flow mechanisms and the extension of the flow model to full flow regimes and to upscaling shale matrix, thus establishing a unified model for better guiding shale gas development.

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“…Geng et al [3], under the assumption of ignoring adsorption and desorption, established a flow model that can describe the continuous flow state, slip flow state, transition state, and molecular state of the gas in shale nanopore throats. Sun et al [10], considering the effects of multicomponent slip flow and Knudsen diffusion, proposed a new model for simulating the transport of multicomponent shale gas through nanopores in shale formations. Li et al [11] used multiple relaxation time lattice Boltzmann method (LBM) simulations to study the flow characteristics of shale gas in sudden and gradual contraction channels and explored the influence of Knudsen number and cross-sectional contraction coefficient on shale gas transportation.…”

Section: Introductionmentioning

confidence: 99%

Study on Flow Model and Flow Equation of Shale Gas Based on Microflow Mechanism

et al. 2022

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Shale gas storage and permeability space is between nanometers and micrometers and has strong multiscale characteristics, resulting in highly complicated shale gas flow. Therefore, the development of shale gas needs to clarify the seepage mechanism of shale gas and establish a flow model and flow equation that can analyze shale gas flow. In this paper, based on the single nanotube model, combined with the Weiyuan-Changning shale gas demonstration zone of the target layer of the Longmaxi formation shale core high-pressure mercury pore throat test results, the contribution of seepage, diffusion, transition flow, and free molecular flow to shale gas flow was calculated. The contribution of seepage and diffusion is over 95%, and seepage and diffusion are the main flow pattern. Then, a shale gas seepage and diffusion coupled flow model and coupled flow equation were established. A method for calculating shale permeability and diffusion was proposed using the relationship between flow pressure and shale gas velocity. Finally, shale gas flow experiment analysis was carried out to verify that the established shale gas flow model and flow equation can describe the shale gas flow well. The result shows that the flow rate of shale gas is composed of seepage flow rate and diffusion flow rate. The seepage flow rate is proportional to the pseudopressure difference and proportionate to the low-pressure squared difference. The diffusion velocity is proportional to the difference in shale gas density, and the pressure difference in low pressure is proportional. As the pressure of a shale gas reservoir decreases, the proportion of diffusion flow increases. The research results enrich the understanding of shale gas flow; it also has particular reference significance to the development of shale gas reservoirs.

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A slip-flow model for multi-component shale gas transport in organic nanopores

Cited by 30 publications

References 49 publications

Pore Structure Characteristics, Genesis, and Its Controlling Effect on Gas Migration of Quaternary Mudstone Reservoir in Qaidam Basin

Pore Structure Characteristics, Genesis, and Its Controlling Effect on Gas Migration of Quaternary Mudstone Reservoir in Qaidam Basin

Mechanism, Model, and Upscaling of the Gas Flow in Shale Matrix: Revisit

Study on Flow Model and Flow Equation of Shale Gas Based on Microflow Mechanism

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