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• W3106548023 endingPage "108198" @default.
• W3106548023 startingPage "108198" @default.
• W3106548023 abstract "Accurate quantitative determination of hydrocarbon saturation is important for informing decisions on hydrocarbon reservoir development and management. Petrophysical saturation models, like Archie, Waxman-Smits and other electrical conductivity models, are used to calculate the hydrocarbon saturation from resistivity logs. As these models contain empirical parameters, their accuracy typically depends on calibration against laboratory measurements using core samples. Alternatively, X-ray computer microtomography (Micro-CT) based Digital Rock technology promises a cheaper and faster method for calibrating these empirical parameters, but only if known limitations are addressed. Micron-scale X-ray computer tomography images generated by current imaging technology are limited in resolution; thus, a significant portion of rock pore volume can remain unresolved. This missing pore volume is not accessible to numerical solvers/simulators that simulate multiphase flow and electrical conductivity, which reduces the accuracy of the simulated results and limits applicability of Digital Rock technology. To get meaningful results from direct simulations, at minimum, image-derived exponents inferred from micron-scale images must be corrected for the missing pore volume. To derive the corrected Archie exponents, we develop novel transforms that compensate for the limited image resolution. The exponents predicted by our method agree with those obtained experimentally for reservoir rocks within ± 0.1." @default.
• W3106548023 created "2020-12-07" @default.
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• W3106548023 date "2021-03-01" @default.
• W3106548023 modified "2023-09-27" @default.
• W3106548023 title "Estimating electrical cementation and saturation exponents using digital rock physics" @default.
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• W3106548023 doi "https://doi.org/10.1016/j.petrol.2020.108198" @default.
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