Prediction of methane adsorption content in continental coal-bearing shale reservoir using SLD model

Li, Xianqing; Tang, Yuan; Chen, Daye

doi:10.1080/10916466.2019.1610773

Cited by 8 publications

(3 citation statements)

References 15 publications

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“…The effect of TOC content, thermal maturity, clay content, and temperature on the adsorption capacity of shale have been reported in various literature. It is generally accepted that the higher TOC and clay content results in a higher adsorption capacity since the adsorption sites for gas are predominantly provided by the organic matter and clay minerals in shale (Yuan et al, 2014;Wang et al, 2015Xiong et al, 2017;Jiao et al, 2019;Zhang et al, 2019). A positive correlation of methane adsorption capacity with shale thermal maturity was also observed from experimental studies (Lu et al, 1995;Bustin, 2007a, 2007b;Zhang et al, 2012;Rexer et al, 2014;Huang et al, 2018a).…”

Section: Introductionmentioning

confidence: 83%

Experimental investigation of methane adsorption and desorption in water-bearing shale

Han

Fang

et al. 2020

Capillarity

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Methane adsorption and desorption in shale can significantly be affected by water due to the water-bearing depositional environment of shale and the application of hydraulic fracturing technology in shale gas production. The characteristics of shale gas adsorption and desorption are comprehensively affected by the temperature, pressure, and especially, the water content in the reservoir. To further explore the impact of water on shale gas adsorption and desorption, the adsorption-desorption experiments of methane in waterbearing shale at different temperatures and different pressures are performed. Afterward, the adsorption behavior and desorption hysteresis are characterized by employing the Langmuir model and Langmuir+λ model. Finally, the ways of the pressure, temperature, and water combinedly affect shale gas adsorption behavior and desorption hysteresis are analyzed. The results show that adsorption and desorption of methane in the water-bearing shale are irreversible, which are consistent with the Langmuir model and the Langmuir+λ model, respectively. An increase in temperature will reduce adsorption and promote desorption, as an increase in temperature essentially enhances the thermal movement of methane molecules. Water lowers the adsorption and desorption of methane in shale, as the water molecules occupy the adsorption sites in organic pores and clay mineral pores in different ways. However, the effect of temperature and water content on adsorption is closely related to the pressure. The lower the pressure, the more significant the effect of temperature and water content. The combined effect analysis demonstrates that the impact of water on methane adsorption in shale is much more significant than that of the temperature. Still, desorption is simultaneously affected by both temperature and water content. As the pressure decreases in the desorption process, the desorption rate is dominantly affected by water when the pressure is lower than 8 MPa, and the desorption rate is aggressively affected by temperature when the pressure is at above 8 MPa.

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Section: Introductionmentioning

confidence: 83%

Experimental investigation of methane adsorption and desorption in water-bearing shale

Han

Fang

et al. 2020

Capillarity

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“…The simplified local density (SLD) model is based on the local density approximation (LCA) to calculate the configurational energy of adsorbates according to fluid–surface interaction and EOS . The SLD model which considers both fluid–fluid interactions and fluid–surface interactions has been widely used in interpreting hydrocarbon adsorption in shale and coal. ,− The currently used SLD model often describes adsorbates in slit pores as shown in Figure .…”

Section: Methane Excess Adsorption and Absolute Adsorption: Measureme...mentioning

confidence: 99%

Comprehensive Review about Methane Adsorption in Shale Nanoporous Media

2021

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Shale/tight gas plays an increasingly important role to meet the growing global energy demand and reduce carbon emissions. Unlike conventional reservoirs, shale formations are subject to rock heterogeneity and have pore size distributions ranging from sub-1 nm to a few micrometers. Thanks to the large number of nanosized pores, adsorbed methane capacity plays a dominant role in total shale gas-in-place. Methane adsorption behaviors can vary drastically in micropores and mesopores, and rock surface type may also greatly affect its adsorption. In this review, we provide a systematic discussion on measurements of shale rock properties including rock compositions and pore structures such as specific surface area (SSA) and pore size distribution (PSD), which are important parameters for methane adsorption in shale nanoporous media. We also provide in-depth discussions on experimental measurements on methane (excess) adsorption in shale nanoporous media, methane adsorption behavior characterization based on molecular simulations, and various excess-adsorption-to-absolute-adsorption conversion methods. We pay particular attention to the assumptions and working mechanisms proposed in various interpretation methods which are embedded in pore structures (SSA and PSD) and absolute adsorption characterizations. In the end, we summarize the key challenges in the methane adsorption characterization in shale media.

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“…Rocks due to their mineralogy are pervasive and the modeling of such a system is difficult as a result of the ionic, hydrodynamic, and electrochemical interactions (Joekar-Niasar et al, 2019). Furthermore, different from the popular flow assurance adsorption is the surface storage capacity of gases in shale reservoirs which is natural and can be quantified using the simplified and isothermal local density method (Zhang et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

A review on polymer, gas, surfactant and nanoparticle adsorption modeling in porous media

Mohammed

Afagwu

Adjei

et al. 2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Adsorption is a rock surface phenomenon and has increasingly become popular, especially in particle-transport applications across many fields. This has drawn a remarkable number of publications from the industry and academia in the last decade, with many review articles focused on adsorption of polymers, surfactants, gas, and nanoparticles in porous media with main applications in Enhanced Oil Recovery (EOR). The discussions involved both experimental and modeling approaches to understanding and efficiently mimicking the particle transport in a bid to solve pertinent problems associated with particle retention on surfaces. The governing mechanisms of adsorption and desorption constitute an area under active research as many models have been proposed but the physics has not been fully honored. Thus, there is a need for continuous research effort in this field. Although adsorption/desorption process is a physical phenomenon and a reversible process resulting from inter-molecular and the intramolecular association between molecules and surfaces, modeling these phenomena requires molecular level understanding. For this reason, there is a wide acceptance of molecular simulation as a viable modeling tool among scientists in this area. This review focuses on existing knowledge of adsorption modeling as it relates to the petroleum industry cutting across flow through porous media and EOR mostly involving polymer and surfactant retention on reservoir rocks with the associated problems. The review also analyzes existing models to identify gaps in research and suggest some research directions to readers.

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Prediction of methane adsorption content in continental coal-bearing shale reservoir using SLD model

Cited by 8 publications

References 15 publications

Experimental investigation of methane adsorption and desorption in water-bearing shale

Experimental investigation of methane adsorption and desorption in water-bearing shale

Comprehensive Review about Methane Adsorption in Shale Nanoporous Media

A review on polymer, gas, surfactant and nanoparticle adsorption modeling in porous media

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