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Chemo‐Mechanical Coupling in Fractured Shale With Water and Hydrocarbon Flow
Author(s) -
Wenning Quinn C.,
Madonna Claudio,
Kurotori Takeshi,
Petrini Claudio,
Hwang Junyoung,
Zappone Alba,
Wiemer Stefan,
Giardini Domenico,
Pini Ronny
Publication year - 2021
Publication title -
geophysical research letters
Language(s) - English
Resource type - Journals
SCImago Journal Rank - 2.007
H-Index - 273
eISSN - 1944-8007
pISSN - 0094-8276
DOI - 10.1029/2020gl091357
Subject(s) - geology , oil shale , fluid dynamics , permeability (electromagnetism) , creep , geomechanics , shear (geology) , geotechnical engineering , swelling , sorption , digital image correlation , mineralogy , materials science , composite material , mechanics , petrology , adsorption , chemistry , paleontology , biochemistry , physics , organic chemistry , membrane
The transport of chemically reactive fluids through fractured clay‐rich rocks is fundamental to many subsurface engineering technologies. Here, we present results of direct‐shear laboratory experiments with simultaneous imaging by X‐ray Computed Tomography in Opalinus claystone with subsequent fluid injection to unravel the interplay between mechanical fracture deformation, fluid sorption, and flow. Under constant radial stress ( σ c = 1.5 MPa), the average mechanical apertured ¯ C Tincreases with shear displacement. Upon brine injection,d ¯ C Tis reduced by 40% relative to initial conditions (d ¯ C T 0 = 140 − 250 μ m) and fluid‐sorption induces a divergent displacement of the two sample halves (Δ h = ±50 − 170 μ m) quantified by digital image correlation. None of these changes are observed in a control experiment with decane, indicating that creep is subordinate to swelling in sealing the fracture. Swelling‐induced changes in permeability within the fracture are heterogeneous and largely affect the fracture flow field, as computed using numerical simulations.