Quantifying porosity, compressibility and permeability in Shale

Ernest Ncha Mbia, Ida Lykke Fabricius, Peter Frykman, Anette Krogsbøll, F. Dalhoff

Research output: Contribution to conferenceConference abstract for conferenceResearchpeer-review

Abstract

The Fjerritslev Formation in the Norwegian-Danish Basin forms the main seal to Upper Triassic-Lower Jurassic sandstone reservoirs. In order to estimate rock properties Jurassic shale samples from deep onshore wells in Danish basin were studied. Mineralogical analysis based on X-ray diffractometry (XRD) of shale samples show about 50% silt and high content of kaolinite in the clay fraction when compared with offshore samples from the Central Graben. Porosity measurements from helium porosimetry-mercury immersion (HPMI), mercury injection capillary pressure (MICP) and nuclear magnetic resonance (NMR) show that, the MICP porosity is 9-10% points lower than HPMI and NMR porosity. Compressibility result shows that deep shale is stiffer in situ than normally assumed in geotechnical modelling and that static compressibility corresponds with dynamic one only at the begining of unloading stress strain data. We found that Kozeny's modelled permeability fall in the same order of magnitude with measured permeability for shale rich in kaolinite but overestimates permeability by two to three orders of magnitudes for shale with high content of smectite. The empirical Yang and Aplin model gives good permeability estimate comparable to the measured one for shale rich in smectite. This is probably because Yang and Aplin model was calibrated in London clay which is rich in smectite.
Original languageEnglish
Publication date2014
Number of pages1
DOIs
Publication statusPublished - 2014
EventFourth EAGE Shale Workshop - Porto, Portugal
Duration: 6 Apr 20149 Apr 2014

Conference

ConferenceFourth EAGE Shale Workshop
CountryPortugal
CityPorto
Period06/04/201409/04/2014

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