A modified supercritical Dubinin–Radushkevich model for the accurate estimation of high pressure methane adsorption on shales

Xu, Shan; Lü, Xiuxiang; Shen, Yunqi; Guo, Shaohui; Guan, Yao

doi:10.1016/j.coal.2018.04.008

Cited by 61 publications

(39 citation statements)

References 40 publications

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“…One famous pressure-based model is the classical Langmuir isotherm adsorption model [7]. The pressurebased models are not suitable to describe the gas adsorption under supercritical conditions [3,9]. The density-based models have been developed and extensively applied to characterize the adsorption that occurs in shale media.…”

Section: Model Equationsmentioning

confidence: 99%

“…Shale gas refers to natural gas composed of primarily methane, which is trapped within the pores of fine-grained sedimentary rocks with rich micropores and relatively low permeability. The shale gas reservoirs differ from conventional natural gas reservoirs that apart from free gas in the pores and fractures, a certain amount of gas is adsorbed onto the solid surfaces, and as a result, it can not only store shale gas but also generate gas [1][2][3][4]. Experimental investigations have indicated that adsorbed gas storage capacity is primarily affected by shale reservoir conditions, such as temperature, pressure, and shale matrix pore structures [2,3,5,6].…”

Section: Introductionmentioning

confidence: 99%

“…The shale gas reservoirs differ from conventional natural gas reservoirs that apart from free gas in the pores and fractures, a certain amount of gas is adsorbed onto the solid surfaces, and as a result, it can not only store shale gas but also generate gas [1][2][3][4]. Experimental investigations have indicated that adsorbed gas storage capacity is primarily affected by shale reservoir conditions, such as temperature, pressure, and shale matrix pore structures [2,3,5,6]. A number of adsorption models have been developed to describe the methane adsorption in shale gas reservoirs.…”

Section: Introductionmentioning

confidence: 99%

“…The Langmuir model [7] and Dubinin-Radushkevich (D-R) model [8] are the most popularly employed models to describe the gas adsorption in micropore-rich materials. Methane under shale formation conditions usually stays at the supercritical state, and consequently, the classical models that require a saturation pressure cannot be applied to describe the gas adsorption under supercritical conditions [3,9]. By the use of gas density rather than gas pressure, modified formulations of the Langmuir and D-R models have been developed for supercritical conditions [3,9].…”

Section: Introductionmentioning

confidence: 99%

“…Methane under shale formation conditions usually stays at the supercritical state, and consequently, the classical models that require a saturation pressure cannot be applied to describe the gas adsorption under supercritical conditions [3,9]. By the use of gas density rather than gas pressure, modified formulations of the Langmuir and D-R models have been developed for supercritical conditions [3,9]. In this paper, it is shown that the use of gas density will also be beneficial for ensuring thermodynamical consistency of the models.…”

Section: Introductionmentioning

confidence: 99%

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Chemical Potential-Based Modeling of Shale Gas Transport

et al. 2021

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Shale gas plays an increasingly important role in the current energy industry. Modeling of gas flow in shale media has become a crucial and useful tool to estimate shale gas production accurately. The second law of thermodynamics provides a theoretical criterion to justify any promising model, but it has been never fully considered in the existing models of shale gas. In this paper, a new mathematical model of gas flow in shale formations is proposed, which uses gas density instead of pressure as the primary variable. A distinctive feature of the model is to employ chemical potential gradient rather than pressure gradient as the primary driving force. This allows to prove that the proposed model obeys an energy dissipation law, and thus, the second law of thermodynamics is satisfied. Moreover, on the basis of energy factorization approach for the Helmholtz free energy density, an efficient, linear, energy stable semi-implicit numerical scheme is proposed for the proposed model. Numerical experiments are also performed to validate the model and numerical method.

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Section: Model Equationsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Chemical Potential-Based Modeling of Shale Gas Transport

et al. 2021

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Evaluation and analysis of methane adsorption capacity in deep‐buried coal seams

et al. 2022

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In this work, the high‐pressure methane adsorption/desorption tests were conducted in four coal samples (from low‐rank bituminous coal to anthracite) under different temperature and pressure conditions to reveal the mechanism of desorption hysteresis effect in the deep‐buried coal seams. The experimental and fitting results show that the presence of free methane molecules in the adsorption phase results in an obvious difference between the measured methane adsorption amount with the actual adsorption capacity. The Langmuir, Langmuir–Freundlich (L–F) and Dubinin–Astakhov (D–A) models have their own advantages and disadvantages in fitting the experimental adsorption/desorption data. As residual adsorption capacity C fitted by the D–A model would be negative at high temperatures and lose the meaning of the constant, the Langmuir model is more suitable to describe methane desorption process. The residual adsorption capacity fitted by Langmuir model tended to decrease as the temperature increased until it is almost completely desorbed at 373 K. Meanwhile, because the adsorption sites with lower energy are gradually occupied by methane molecules in the high‐pressure stage, intermolecular forces increased and methane molecules are more easily desorbed. Therefore, the desorption hysteresis coefficient trends to increase exponentially with the decrease of pressure and temperature, which indicated that the original gas content of the coal seams may decrease with the increase of the burial depth, but the risk of coal and gas outburst accidents may increase. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd.

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High-pressure Iisothermal Adsorption Model for Supercritical Methane in Shale

Dong¹,

Zhao

et al. 2023

Springer Series in Geomechanics and Geoengineering

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A modified supercritical Dubinin–Radushkevich model for the accurate estimation of high pressure methane adsorption on shales

Cited by 61 publications

References 40 publications

Chemical Potential-Based Modeling of Shale Gas Transport

Chemical Potential-Based Modeling of Shale Gas Transport

Evaluation and analysis of methane adsorption capacity in deep‐buried coal seams

High-pressure Iisothermal Adsorption Model for Supercritical Methane in Shale

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