Review of experimental sorption studies of CO2 and CH4 in shales

Klewiah, Isaac; Berawala, Dhruvit Satishchandra; Walker, Hans Christian Alexander; Andersen, Pål Østebø; Nadeau, Paul

doi:10.1016/j.jngse.2019.103045

Cited by 176 publications

(139 citation statements)

References 143 publications

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“… 18 − 23 Furthermore, the strong positive correlation between the clay level and methane adsorption in shale with low TOC content has been reported. 13 , 24 − 27 However, no definite relationship between the clay content and methane adsorption was observed in TOC-rich shale. 28 − 31 Although the TOC content is the dominant controlling factor in shale adsorption, kerogen type and thermal maturity also significantly influence the adsorption capability of shale.…”

Section: Introductionmentioning

confidence: 97%

“…Abundant micropores are developed in organic-rich shale, providing a large proportion of adsorption sites for methane. 13 Therefore, it is commonly accepted that the adsorption capability of shale is positively related to its TOC level. 14 − 17 As the most critical inorganic component in shale, clay minerals are considered to have a considerable contribution to methane adsorption due to their microstructure.…”

Section: Introductionmentioning

confidence: 99%

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Synergetic Effect of Water, Temperature, and Pressure on Methane Adsorption in Shale Gas Reservoirs

Han

Memon

et al. 2021

ACS Omega

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Adsorption is one of the most important forms of storage of gas in shale reservoirs. Shale gas adsorption in the actual reservoir is not only affected by individual factors such as water content, temperature, and pressure but also by the synergetic effect of these factors. In this study, we conducted laboratory experiments on methane adsorption in dry and wet shale at different pressures and temperatures. The synergetic effect of water content, temperature, and pressure on shale gas adsorption is explored. The results show that increasing temperature weakens the interaction between methane and shale and reduces adsorption capacity due to the exothermic nature of adsorption. Water reduces methane adsorption capacity by occupying adsorption sites and blocking pores in the shale system. Although temperature and water reduce methane adsorption individually, the effect of these two factors weakens each other. Temperature has a more significant effect on methane adsorption in shales with low water content, while water has a more remarkable impact on methane adsorption at a low temperature. Furthermore, the increase in pressure reduces the negative influence of water and temperature on methane adsorption. By quantitatively analyzing the relationship between methane adsorption in dry and wet shales, a predictive adsorption model for wet shale considering the influence of in situ conditions is proposed and validated. Validation shows that the proposed model has high accuracy and broad applicability to shales with different properties.

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Section: Introductionmentioning

confidence: 97%

Section: Introductionmentioning

confidence: 99%

Synergetic Effect of Water, Temperature, and Pressure on Methane Adsorption in Shale Gas Reservoirs

Han

Memon

et al. 2021

ACS Omega

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“…For a specific gas shale, the free gas content is mainly related to its porosity, gas saturation, and geological temperature and pressure (Bustin et al, 2008;Gasparik et al, 2012;Pan and Connell, 2015;Ye et al, 2016;, but the controlling mechanism of the adsorbed gas is more complex. Except for the factors mentioned above, the adsorbed gas content is also correlated with its pore type, property and structure, which are comprehensively controlled by the organic matter content and type, mineral composition, and thermal maturity (Yang and Aplin, 1998;Dewhurst et al, 1999;Bustin, 2007, 2008; Ross and Bustin, 2007;Curtis et al, 2010Curtis et al, , 2011Song et al, 2013;Zhang et al, 2013;Shan et al, 2017;Chen et al, 2018;Hou et al, 2018;Li et al, 2018;Bhowrnik and Dutta, 2019;Klewiah et al, 2019;Wang and Guo, 2019;Gou et al, 2020;Zhang Y. F. et al, 2020). High-pressure adsorption experiments based on dry samples are generally carried out to evaluate the adsorption capacity of the targeted shales.…”

Section: Introductionmentioning

confidence: 99%

Occurrence of Irreducible Water and Its Influences on Gas-Bearing Property of Gas Shales From Shallow Longmaxi Formation in the Xishui Area, Guizhou, Southern China

et al. 2021

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Systematic studies are quite rare on the gas-bearing property and its controlling factors of the shallow Longmaxi shale outside the Sichuan Basin. In a previous study, the gas in place contents of a suit of Longmaxi shale samples with a depth range of 362–394 m from the well XK2, which was drilled in the Xishui area, Guizhou, southern China, were reported. In the present study, the pore structure parameters and irreducible water occurrence characteristics of those samples, and their influences on the gas-bearing property were further investigated. The results show that, compared to the dry sample, the non-micropore specific surface areas and micropore volumes of the moist sample are significantly reduced by an average value of 61 and 30%, respectively, and that the water averagely occupies 82 and 41% of the inorganic and organic non-micropore specific surface areas, respectively, and 44 and 18% of the inorganic and organic micropore volumes, respectively. The shallow shale reservoir is dominated by adsorbed gas. It accounts for 66–93% of the total gas. The water significantly decreases the adsorption capacity of the inorganic matte (mainly clay minerals) pores, but has a limited influence on that of the organic matter pores. The adsorbed gas occurs mostly in the organic matter nanopores, and even if the shales were highly saturated with the water, they can still store a certain amount of the adsorbed gas. These results are to provide some guides for the evaluation and exploration of the shallow Longmaxi shale located in the strongly tectonic transformation areas of southern China.

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“…There are limited experimental studies on the effects of dry scCO2 on matrix permeability of shale rocks [10,22,23]. After interaction with scCO2, shale rocks exhibit a sorption-induced strain resulting in a reduction in permeability [20,22,24], with a more substantial permeability reduction for vertical samples compared to horizontal samples [22]. The emphasis of these studies, however, were centered around pore space characterization before and after interaction with scCO2.…”

Section: Introductionmentioning

confidence: 99%

Effects of Supercritical CO2 on Matrix Permeability of Unconventional Formations

2021

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We studied the effects of supercritical carbon dioxide (scCO2) on the matrix permeability of reservoir rocks from the Eagle Ford, Utica, and Wolfcamp formations. We measured permeability using argon before exposure of the samples to scCO2 over time periods ranging from days to weeks. We measured permeability (and the change of permeability with confining pressure) when both argon and scCO2 were the pore fluids. In all three formations, we generally observe a negative correlation between initial permeability and carbonate content – the higher the carbonate content, the lower the initial permeability. In clay- and organic-rich samples, swelling of the matrix resulting from adsorption decreased the permeability by about 50% when the pore fluid was scCO2 although this permeability change is largely reversible. In carbonate-rich samples, dissolution of carbonate minerals by carbonic acid irreversibly increased matrix permeability, in some cases by more than one order of magnitude. This dissolution also increases the pressure dependence of permeability apparently due to enhanced mechanical compaction. Despite these trends, we observed no general correlation between mineralogy and the magnitude of the change in permeability with argon before and after exposure to scCO2. Flow of scCO2 through mm-scale cracks appears to play an important role in determining matrix permeability and the pressure dependence of permeability. Extended permeability measurements show that while adsorption is nearly instantaneous and reversible, dissolution is time-dependent, probably owing to reaction kinetics. Our results indicate that the composition and microstructure of matrix flow pathways control both the initial permeability and how permeability changes after interaction with scCO2. Electron microscopy images with Back-Scattered Electron (BSE) and Energy Dispersive Spectroscopy (EDS) revealed dissolution and etching of calcite minerals and precipitation of calcium sulfide resulting from exposure to scCO2.

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Review of experimental sorption studies of CO2 and CH4 in shales

Cited by 176 publications

References 143 publications

Synergetic Effect of Water, Temperature, and Pressure on Methane Adsorption in Shale Gas Reservoirs

Synergetic Effect of Water, Temperature, and Pressure on Methane Adsorption in Shale Gas Reservoirs

Occurrence of Irreducible Water and Its Influences on Gas-Bearing Property of Gas Shales From Shallow Longmaxi Formation in the Xishui Area, Guizhou, Southern China

Effects of Supercritical CO2 on Matrix Permeability of Unconventional Formations

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