Hierarchical integration of porosity in shalesCitation formats

  • External authors:
  • Thomas J.A. Slater
  • Patrick Dowey
  • Sheng Yue
  • Peter Lee

Standard

Hierarchical integration of porosity in shales. / Ma, Lin; Slater, Thomas J.A.; Dowey, Patrick; Yue, Sheng; Rutter, Ernest; Taylor, Kevin; Lee, Peter.

In: Scientific Reports, Vol. 8, No. 1, 11683, 03.08.2018.

Research output: Contribution to journalArticlepeer-review

Harvard

Ma, L, Slater, TJA, Dowey, P, Yue, S, Rutter, E, Taylor, K & Lee, P 2018, 'Hierarchical integration of porosity in shales', Scientific Reports, vol. 8, no. 1, 11683. https://doi.org/10.1038/s41598-018-30153-x

APA

Ma, L., Slater, T. J. A., Dowey, P., Yue, S., Rutter, E., Taylor, K., & Lee, P. (2018). Hierarchical integration of porosity in shales. Scientific Reports, 8(1), [11683]. https://doi.org/10.1038/s41598-018-30153-x

Vancouver

Ma L, Slater TJA, Dowey P, Yue S, Rutter E, Taylor K et al. Hierarchical integration of porosity in shales. Scientific Reports. 2018 Aug 3;8(1). 11683. https://doi.org/10.1038/s41598-018-30153-x

Author

Ma, Lin ; Slater, Thomas J.A. ; Dowey, Patrick ; Yue, Sheng ; Rutter, Ernest ; Taylor, Kevin ; Lee, Peter. / Hierarchical integration of porosity in shales. In: Scientific Reports. 2018 ; Vol. 8, No. 1.

Bibtex

@article{30989f5e902b4de093b493773c754b3e,
title = "Hierarchical integration of porosity in shales",
abstract = "Pore characterization in shales is challenging owing to the wide range of pore sizes and types present. Haynesville-Bossier shale (USA) was sampled as a typical clay-bearing siliceous, organic-rich, gas-mature shale and characterized over pore diameters ranging 2 nm to 3000 nm. Three advanced imaging techniques were utilized correlatively, including the application of Xe+ plasma focused ion beam scanning electron microscopy (plasma FIB or PFIB), complemented by the Ga+ FIB method which is now frequently used to characterise porosity and organic/inorganic phases, together with transmission electron microscope tomography of the nano-scale pores (voxel size 0.6 nm; resolution 1–2 nm). The three pore-size scales each contribute differently to the pore network. Those <10 nm (greatest number), 10 nm to 100 nm (best-connected hence controls transport properties), and >100 nm (greatest total volume hence determines fluid storativity). Four distinct pore types were found: intra-organic, organic-mineral interface, inter-mineral and intra-mineral pores were recognized, with characteristic geometries. The whole pore network comprises a globally-connected system between phyllosilicate mineral grains (diameter: 6–50 nm), and locally-clustered connected pores within porous organic matter (diameter: 200–800 nm). Integrated predictions of pore geometry, connectivity, and roles in controlling petrophysical properties were verified through experimental permeability measurements.",
author = "Lin Ma and Slater, {Thomas J.A.} and Patrick Dowey and Sheng Yue and Ernest Rutter and Kevin Taylor and Peter Lee",
note = "Funding Information: This project was funded in part by the UK-NERC (NE/M001458/1 and NE/R013527/1), the European Union{\textquoteright}s Horizon 2020 716 Research and Innovation Programme under the ShaleXenvironmenT project, (grant no. 640979), and an industry consortium constituted by Shell (formerly BG Group, who provided the specimen used), Chevron, and Schlumberger. The authors also would like to acknowledge HEFCE funding through the UK Research Partnership Investment Funding (UKRPIF) Manchester RPIF Round 2 for the Multiscale Characterisation Facility, and facilities at the Research Complex at Harwell supported in part by the UK-EPSRC (EP/I02249X/1). John Waters and Stephen May (University of Manchester) respectively carried out the XRD analyses and maintained the permeametry equipment. Publisher Copyright: {\textcopyright} 2018, The Author(s). Copyright: Copyright 2018 Elsevier B.V., All rights reserved.",
year = "2018",
month = aug,
day = "3",
doi = "10.1038/s41598-018-30153-x",
language = "English",
volume = "8",
journal = "Scientific Reports",
issn = "2045-2322",
publisher = "Springer Nature",
number = "1",

}

RIS

TY - JOUR

T1 - Hierarchical integration of porosity in shales

AU - Ma, Lin

AU - Slater, Thomas J.A.

AU - Dowey, Patrick

AU - Yue, Sheng

AU - Rutter, Ernest

AU - Taylor, Kevin

AU - Lee, Peter

N1 - Funding Information: This project was funded in part by the UK-NERC (NE/M001458/1 and NE/R013527/1), the European Union’s Horizon 2020 716 Research and Innovation Programme under the ShaleXenvironmenT project, (grant no. 640979), and an industry consortium constituted by Shell (formerly BG Group, who provided the specimen used), Chevron, and Schlumberger. The authors also would like to acknowledge HEFCE funding through the UK Research Partnership Investment Funding (UKRPIF) Manchester RPIF Round 2 for the Multiscale Characterisation Facility, and facilities at the Research Complex at Harwell supported in part by the UK-EPSRC (EP/I02249X/1). John Waters and Stephen May (University of Manchester) respectively carried out the XRD analyses and maintained the permeametry equipment. Publisher Copyright: © 2018, The Author(s). Copyright: Copyright 2018 Elsevier B.V., All rights reserved.

PY - 2018/8/3

Y1 - 2018/8/3

N2 - Pore characterization in shales is challenging owing to the wide range of pore sizes and types present. Haynesville-Bossier shale (USA) was sampled as a typical clay-bearing siliceous, organic-rich, gas-mature shale and characterized over pore diameters ranging 2 nm to 3000 nm. Three advanced imaging techniques were utilized correlatively, including the application of Xe+ plasma focused ion beam scanning electron microscopy (plasma FIB or PFIB), complemented by the Ga+ FIB method which is now frequently used to characterise porosity and organic/inorganic phases, together with transmission electron microscope tomography of the nano-scale pores (voxel size 0.6 nm; resolution 1–2 nm). The three pore-size scales each contribute differently to the pore network. Those <10 nm (greatest number), 10 nm to 100 nm (best-connected hence controls transport properties), and >100 nm (greatest total volume hence determines fluid storativity). Four distinct pore types were found: intra-organic, organic-mineral interface, inter-mineral and intra-mineral pores were recognized, with characteristic geometries. The whole pore network comprises a globally-connected system between phyllosilicate mineral grains (diameter: 6–50 nm), and locally-clustered connected pores within porous organic matter (diameter: 200–800 nm). Integrated predictions of pore geometry, connectivity, and roles in controlling petrophysical properties were verified through experimental permeability measurements.

AB - Pore characterization in shales is challenging owing to the wide range of pore sizes and types present. Haynesville-Bossier shale (USA) was sampled as a typical clay-bearing siliceous, organic-rich, gas-mature shale and characterized over pore diameters ranging 2 nm to 3000 nm. Three advanced imaging techniques were utilized correlatively, including the application of Xe+ plasma focused ion beam scanning electron microscopy (plasma FIB or PFIB), complemented by the Ga+ FIB method which is now frequently used to characterise porosity and organic/inorganic phases, together with transmission electron microscope tomography of the nano-scale pores (voxel size 0.6 nm; resolution 1–2 nm). The three pore-size scales each contribute differently to the pore network. Those <10 nm (greatest number), 10 nm to 100 nm (best-connected hence controls transport properties), and >100 nm (greatest total volume hence determines fluid storativity). Four distinct pore types were found: intra-organic, organic-mineral interface, inter-mineral and intra-mineral pores were recognized, with characteristic geometries. The whole pore network comprises a globally-connected system between phyllosilicate mineral grains (diameter: 6–50 nm), and locally-clustered connected pores within porous organic matter (diameter: 200–800 nm). Integrated predictions of pore geometry, connectivity, and roles in controlling petrophysical properties were verified through experimental permeability measurements.

U2 - 10.1038/s41598-018-30153-x

DO - 10.1038/s41598-018-30153-x

M3 - Article

C2 - 30076389

VL - 8

JO - Scientific Reports

JF - Scientific Reports

SN - 2045-2322

IS - 1

M1 - 11683

ER -