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Shale Porosity - What Can We Learn from Different Methods?Normal access

Authors: A. Busch, K. Schweinar, N. Kampman, A. Coorn, V. Pipich, A. Feoktystov, L. Leu, A. Amann-Hildenbrand and P. Bertier
Event name: Fifth EAGE Shale Workshop
Session: Shale Characterization I
Publication date: 02 May 2016
DOI: 10.3997/2214-4609.201600391
Organisations: EAGE
Language: English
Info: Extended abstract, PDF ( 485.16Kb )
Price: € 20

While the determination of porosity on sandstones is well established, porosities determined on shales are much less straightforward due to limited coring or inadequate pore preservation. Porosity in shale has an important control on many petrophysical, geomechanical and geochemical parameters of shales. Most of the porosity in shales is associated with small pore throat sizes, ranging in diameter from few up to about 100 nm. Pore throat sizes in carbonate or sandstone reservoir rocks are typically determined using mercury injection porosimetry (MIP). It is however well understood that MIP on shales underestimates porosity due to its limited accessibility. It is well known that using different methods for determining shale porosity results in different porosity values which is due to the different accessibility. Nonetheless, porosity is generally used as an absolute, intrinsic parameter without considering the method for determination. To address this issue we compare porosity, specific surface areas and pore volume distributions from fluid invasion and radiation methods on a total of 14 different Opalinus Clay samples recovered from the shaly facies at the Mont Terri underground laboratory in St. Ursanne, Switzerland.

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