Geological controls on the methane storage capacity in organic-rich shales

Gašparík, Matúš; Bertier, Pieter; Gensterblum, Yves; Ghanizadeh, Amin; Krooß, Bernhard M.; Littke, Ralf

doi:10.1016/j.coal.2013.06.010

Cited by 670 publications

(644 citation statements)

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“…Gasparik et al reported no correlation for methane sorption capacity and TOC (0.8-10.5%) for dry shales 16 , 5 but found a correlation for another suite of dry shales with TOC (0.4-14.1%). 13 These results illustrate the complex nature of the problem when relating composition and structure of shales to methane sorption capacity. Water may also be present under subsurface conditions and methane adsorption studies of moisture-equilibrated shale samples show that competitive adsorption has a detrimental effect on methane sorption capacity.…”

Section: Introductionmentioning

confidence: 96%

“…Within the phyllosilicates group, illiterich mixed layer illite-smectite is the most prominent component, followed by kaolinite, illite, muscovite and chlorite. In addition, there is a moderate content of quartz (8)(9)(10)(11)(12)(13)(14)(15)(16) wt.%) and minor contents of pyrite (4-9 wt.%), feldspars (1-5 wt.%) and dolomite (0.3-6.4 wt.%).…”

Section: Mineralogymentioning

confidence: 99%

“…Also, under geological conditions, moisture may be present leading to reduced methane capacity compared with dry shales. 12,13,14 Ross et al have reported positive correlations between maturity and sorption capacity in organic-rich shales, which they attributed to an increased micropore volume (pore width 0.3 -2 nm). 14 However, they were not able to fully explain variations in sorption capacity by micropore volume and Total Organic Carbon (TOC) content alone.…”

Section: Introductionmentioning

confidence: 99%

“…Water may also be present under subsurface conditions and methane adsorption studies of moisture-equilibrated shale samples show that competitive adsorption has a detrimental effect on methane sorption capacity. 13 The differences between surface excess and absolute amounts adsorbed become significant in high pressure isotherms. The surface excess adsorbed represents the amount of gas exceeding bulk gas phase density in the system.…”

Section: Introductionmentioning

confidence: 99%

“…11 Although sorption data on shales are available, the absolute sorption capacity in shale remains poorly constrained. [11][12][13][14][15][16][18][19][20] Shales are complex heterogeneous materials with amorphous kerogen and inorganic phases. The amounts of methane adsorbed on shales are also very low and this is complicated by the fact that the minor kerogen component has a much larger adsorption capacity than the inorganic phase in the shale.…”

Section: Introductionmentioning

confidence: 99%

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High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

et al. 2014

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. (2014) 'High-pressure methane adsorption and characterization of pores in Posidonia shales and isolated kerogens.', Energy fuels., 28 (5). pp. 2886-2901. Further information on publisher's website:http://dx.doi.org/10.1021/ef402466mPublisher's copyright statement:This document is the Accepted Manuscript version of a Published Work that appeared in nal form in Energy Fuels, copyright c American Chemical Society after peer review and technical editing by the publisher. To access the nal edited and published work see http://dx.doi.org/10.1021/ef402466m. Additional information:Use policyThe full-text may be used and/or reproduced, and given to third parties in any format or medium, without prior permission or charge, for personal research or study, educational, or not-for-pro t purposes provided that:• a full bibliographic reference is made to the original source • a link is made to the metadata record in DRO • the full-text is not changed in any way The full-text must not be sold in any format or medium without the formal permission of the copyright holders.Please consult the full DRO policy for further details. AbstractSorption capacities and pore characteristics of bulk shales and isolated kerogens have been determined for immature, oil-window and gas-window mature samples from the Lower Toarcian Posidonia Shale formation. Dubinin-Radushkevich (DR) micropore volumes, sorption pore volumes and surface areas of shales and kerogens were determined from CO 2 adsorption isotherms at -78°C and 0°C, and N 2 adsorption isotherms at -196°C. Mercury injection capillary pressure porosimetry, grain density measurements and helium pycnometry were used to determine shale and kerogen densities and total pore volumes.Total porosities decrease through the oil-window and then increase into the gas-window.High-pressure methane isotherms up to 14 MPa were determined at 45, 65 and 85°C on dry shale and at 45 and 65°C on kerogen. Methane excess uptakes at 65°C and 11.5 MPa were in the range 0.056-0.110 mmol g -1 (40-78 scf t -1 ) for dry Posidonia shales and 0.36-0.70 mmol g -1 (253-499 scf t -1 ) for the corresponding dry kerogens. Absolute methane isotherms were calculated by correcting for the gas at bulk gas phase density in the sorption pore volume. The enthalpies of CH 4 adsorption for shales and kerogens at zero surface coverage showed no significant variation with maturity, indicating that the sorption pore volume is the primary control on sorption uptake. The sum of pore volumes measured by a) CO 2 sorption at -78°C and b) mercury injection, are similar to the total porosity for shales. Since mercury in our experiments occupies pores with constrictions larger than ca. 6 nm, we infer that porosity measured by CO 2 adsorption at -78°C in the samples used in this study is largely within pores with effective diameters smaller than 6 nm. The linear correlation between maximum CH 4 surface excess sorption and CO 2 sorption pore volume at -78°C is very strong for both shales and kerogens, and goes through the origin, suggestin...

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Section: Introductionmentioning

confidence: 96%

Section: Mineralogymentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

et al. 2014

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Molecular simulation of CH₄ adsorption behavior in slit nanopores: Verification of simulation methods and models

et al. 2019

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The aim of this study is to select an appropriate method for CH 4 adsorption in organic nanopores for shale-gas development. Molecular dynamics (MD) and grand canonical Monte Carlo (GCMC) simulations were performed. Three comparison studies were included: (i) comparison of the adsorption behavior in kerogen nanopores using different schemes for dispersion correction, (ii) comparison of the adsorption behavior in graphite nanopores using MD and GCMC simulations, and (iii) comparison of the adsorption behavior in kerogen and graphite nanopores using MD simulations. The result was reliable when using a particle-mesh Ewald scheme or a cutoff ≥1.5 nm without dispersion correction. The simulation results were essentially identical for the MD and GCMC simulations. The free-gas CH 4 density inside the nanopores started to deviate from the bulk density at~2 nm for the graphite model and at~7-10 nm for the kerogen model, whereas the total CH 4 density deviates from the bulk density at~20 nm.

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Prediction of methane adsorption capacity in different rank coal at low temperature by the Polanyi‐based isotherm model

Zhao

Wang

et al. 2022

Energy Science & Engineering

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To investigate the adsorption properties of methane in coal under low temperatures, the isothermal adsorption tests of the three coal samples with different metamorphic degrees were conducted at the ambient temperatures of 253.15−293.15 K, and the low‐temperature nitrogen adsorption (LNA) tests of coal were also performed. Then a relational expression of equilibrium pressure, temperature, and methane adsorption capacity (T−P model) was deduced to predict the adsorption isotherm at any other temperature based on the Polanyi adsorption theory. The results show that the gas adsorption capacity of coal can be significantly increased at low temperatures (below 273.15 K), and the adsorbed methane in anthracite is obviously more than that in lean coal and coking coal by the virtue of possessing a larger micropore/transition pore volume and specific surface area. The relations between adsorption potential (ε) and adsorption volume (ω) at different temperatures can be drawn on one single logarithmic curve, and a suitable pseudo‐saturation pressure can be obtained by the improved Amankwah's method. The predicted adsorbed capacities via the T−P model are in line with the measured results at other equilibrium conditions, indicating that the model can contribute to the deep coalbed methane resources estimation and the gas disaster prevention and control in coal mines.

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Geological controls on the methane storage capacity in organic-rich shales

Cited by 670 publications

References 62 publications

High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

Molecular simulation of CH₄ adsorption behavior in slit nanopores: Verification of simulation methods and models

Prediction of methane adsorption capacity in different rank coal at low temperature by the Polanyi‐based isotherm model

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Geological controls on the methane storage capacity in organic-rich shales

Cited by 670 publications

References 62 publications

High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

High-Pressure Methane Adsorption and Characterization of Pores in Posidonia Shales and Isolated Kerogens

Molecular simulation of CH4 adsorption behavior in slit nanopores: Verification of simulation methods and models

Prediction of methane adsorption capacity in different rank coal at low temperature by the Polanyi‐based isotherm model

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Molecular simulation of CH₄ adsorption behavior in slit nanopores: Verification of simulation methods and models