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TitleA comparison of shale permeability coefficients derived using multiple non-steady-state measurement techniques: examples from the Duvernay Formation, Alberta (Canada)
AuthorGhanizadeh, A; Bhowmik, S; Haeri Ardakani, O; Sanei, H; Clarkson, C R
SourceFuel vol. 140, 2015 p. 371-387,
Alt SeriesEarth Sciences Sector, Contribution Series 20140482
Mediapaper; on-line; digital
File formatpdf
NTS83F; 83G; 83J; 83K
AreaDuvernay Formation
Lat/Long WENS-118.0000 -114.0000 55.0000 53.0000
Subjectseconomic geology; fossil fuels; geochemistry; regional geology; permeability; porosity; petroleum occurrence; reservoirs; reservoir fluid analyses; fluid migration; shales; oil; gas; hydrocarbons; petroleum; petroleum exploration; petroleum resources; petroleum occurrence; Duvernay Formation; Unconventional gas reservoirs; Devonian
Illustrationstables; schematic diagrams; graphs; equations
ProgramShale Reservoir Characterization, Geoscience for New Energy Supply (GNES)
AbstractMatrix permeability, while an important control on fluid flow in unconventional reservoirs, is difficult to measure in the laboratory. There are now multiple methods for laboratory determination of permeability for shales, but little consensus on the appropriate method for permeability measurement. Each technique is based on different physical principles and utilizes reservoir samples at different scales. The combination of sample size and preparation and measurement conditions can lead to a wide range in permeability estimates, creating confusion for recipients of the data. In this work, we compare different non-steady state methods for determination of gas permeability in low-permeability Canadian shales and provide insight into the causes of permeability variation. Further, we analyze and discuss the effects of different controlling factors including porosity, pore-fluid content, mineralogy and effective stress on permeability. Gas permeability measurements were conducted on low-permeability (shale) samples from the Duvernay Formation (Alberta, Canada) using three different methods: profile (probe), pulse-decay and crushed-rock permeability techniques. The analyzed samples differ in total organic carbon (TOC) content, pore network characteristics (porosity, pore size distribution), pore-fluid content (''as-received'' and cleaned/dried) and mineralogy. Profile (probe) and crushed-rock permeability measurements were performed on samples in the ''as-received'' and cleaned/dried conditions. Pulse-decay measurements were conducted on samples in the cleaned/dried state. Helium pycnometry/expansion measurements were performed using ''as-received'' and cleaned/dried samples under unconfined and controlled ''in situ'' effective stress conditions.
Summary(Plain Language Summary, not published)
We have presented the results from a laboratory study on the fluid storage and transport properties of the Duvernay Shale, an emerging shale oil/gas play in Alberta. The study compares different techniques for determination of gas permeability in low-permeability shales. Furthermore, to date, this study is the most comprehensive study for laboratory characterization of porosity/permeability in the Duvernay Shale in Alberta.