TY - JOUR
T1 - Coupling Between Poromechanical Behavior and Fluid Flow in Tight Rock
AU - Kim, Kiseok
AU - Makhnenko, Roman Y.
N1 - Funding Information:
The experimental data is available upon request. K. Kim’s research was supported by Technip FMC Educational Fund Fellowship. R.Y. Makhnenko acknowledges the support from US DOE through CarbonSAFE Macon County Project DE-FE0029381. Swisstopo is acknowledged for providing Opalinus clay cores. A. Tarokh helped with setting up the experimental equipment.
Publisher Copyright:
© 2020, Springer Nature B.V.
PY - 2020/11/1
Y1 - 2020/11/1
N2 - Proper characterization of the mechanical and flow properties of participating rock formations is crucial for subsurface geo-energy projects, including hydrocarbon extraction, geologic carbon storage, and enhanced geothermal systems. Application of mechanical and hydraulic pressures changes the porosity of rock and modifies flow paths. For low-permeable or “tight” rock that mainly contains nanoscale pores and serves as the confining layer for underground storage operations, a significant change in permeability may occur due to a small change in porosity. The pore volume changes in nanoporous geomaterials are extremely difficult to measure directly, but can be assessed from the knowledge of the hydro-mechanical response. Experimental methods to measure the stress-dependent permeability and poroelastic parameters of fluid-saturated tight rock are introduced. Eau Claire shale, Opalinus clay (claystone), and Charcoal granite are selected as representative materials for tight rock and their pore structure and material properties are carefully investigated. The porosity–permeability relationship for tight rock is established by adopting a power-law dependence with the exponent value in the range of 15–17, thus being significantly larger than that for a porous reservoir rock. Consequently, even small perturbations of porosity can cause orders of magnitude changes in permeability possessing a risk on the sealing capacity of the tight formations.
AB - Proper characterization of the mechanical and flow properties of participating rock formations is crucial for subsurface geo-energy projects, including hydrocarbon extraction, geologic carbon storage, and enhanced geothermal systems. Application of mechanical and hydraulic pressures changes the porosity of rock and modifies flow paths. For low-permeable or “tight” rock that mainly contains nanoscale pores and serves as the confining layer for underground storage operations, a significant change in permeability may occur due to a small change in porosity. The pore volume changes in nanoporous geomaterials are extremely difficult to measure directly, but can be assessed from the knowledge of the hydro-mechanical response. Experimental methods to measure the stress-dependent permeability and poroelastic parameters of fluid-saturated tight rock are introduced. Eau Claire shale, Opalinus clay (claystone), and Charcoal granite are selected as representative materials for tight rock and their pore structure and material properties are carefully investigated. The porosity–permeability relationship for tight rock is established by adopting a power-law dependence with the exponent value in the range of 15–17, thus being significantly larger than that for a porous reservoir rock. Consequently, even small perturbations of porosity can cause orders of magnitude changes in permeability possessing a risk on the sealing capacity of the tight formations.
KW - Opalinus clay
KW - Permeability
KW - Porosity
KW - Saturation
KW - Shale
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U2 - 10.1007/s11242-020-01484-z
DO - 10.1007/s11242-020-01484-z
M3 - Article
AN - SCOPUS:85092200510
VL - 135
SP - 487
EP - 512
JO - Transport in Porous Media
JF - Transport in Porous Media
SN - 0169-3913
IS - 2
ER -