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    Determination of Archie's cementation exponent for shale reservoirs; an experimental approach

    Access Status
    Fulltext not available
    Authors
    Zhong, Zhiqi
    Rezaee, Reza
    Esteban, L.
    Josh, M.
    Feng, Runhua
    Date
    2021
    Type
    Journal Article
    
    Metadata
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    Citation
    Zhong, Z. and Rezaee, R. and Esteban, L. and Josh, M. and Feng, R. 2021. Determination of Archie's cementation exponent for shale reservoirs; an experimental approach. Journal of Petroleum Science and Engineering. 201: ARTN 108527.
    Source Title
    Journal of Petroleum Science and Engineering
    DOI
    10.1016/j.petrol.2021.108527
    ISSN
    0920-4105
    Faculty
    Faculty of Science and Engineering
    School
    WASM: Minerals, Energy and Chemical Engineering
    URI
    http://hdl.handle.net/20.500.11937/89539
    Collection
    • Curtin Research Publications
    Abstract

    Archie's equation has been widely used in well-log interpretations for the fluid saturation calculation from electrical resistivity measurements. Though constrained standard Archie parameters are accepted in sandstone and carbonate reservoirs, the same parameters are more complex to define in Shales. Indeed, the use of standard Archie parameters on shale reservoirs proved to be inaccurate due to the heterogeneities and ultra-tight nature of those formations, and also the excessive conductivity exerted by the strong Cation Exchange Capacity (CEC) property of clays particle surfaces. This study aims to determine Archie's cementation exponent (m) from two Australian shales (oil-shale and gas shale with a maximum of 60% clay content) with the minimization of the CEC effect using high saline pore fluid. The shales were first fully saturated under hydrostatic pressure for about two weeks before conducting electrical resistivity and Nuclear Magnetic Resonance (NMR) laboratory measurements. The resistivity measurements were conducted under ambient conditions, though a small 50 psi axial pressure was added to improve sample-electrode surface contact, and under 2800 psi confining pressure to simulate the reservoir condition. NMR was measured in ambient conditions only to compute the effective porosity (excluding clay bound water volume), and to detect potential residual oil after oil removal treatment. The oil cleaning process enhances the development of micro-fractures but their effects are negligible on the NMR effective porosity (<5%). The results indicated that Archie m is stress-dependent averaging around 2.48 in ambient conditions and increasing to 2.70 in reservoir conditions, an 11% increase that is similar in both oil- and gas-shales. However, Archie m is systematically higher in oil shales despite oil cleaning (m > 3) and lower in gas shales (m < 2.55).

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      Applying the realistic cementation exponent (m) in Archie’s equation is critical for reliable fluid-saturation calculation from well logs in shale formations. In this study, the cementation exponent was determined under ...
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      Determination of water saturation in gas shale reservoirs is a very challenging issue due to the incomplete understanding of the non-Archie components. Kerogen and clay content are the two main factors controlling the ...
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