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Jmicrovision download1/1/2023 ![]() Weger, 2008, Effects of microporosity on sonic velocity in carbonate rocks: The Leading Edge, 27, 1012–1018, doi: 10.1190/1.2967554. Mavko, 2005, Quantitative seismic interpretation: Applying rock physics tools to reduce interpretation risk: Cambridge University Press. GPPRAR 0016-8025 Crossref Web of Science Google Scholar Sothcott, 2003, Velocities of compressional and shear waves in limestones: Geophysical Prospecting, 51, 1–13, doi: 10.1046/j. GPYSA7 0016-8033 Abstract Web of Science Google Scholar Best, 2008, Effects of fluids and dual-pore systems on pressure-dependent velocities and attenuations in carbonates: Geophysics, 73, no. 5, N35–N47, doi: 10.1190/1.2969774. TCTOAM 0040-1951 Crossref Web of Science Google Scholar Guéguen, 2011, Dispersion of elastic moduli in a porous-cracked rock: Theoretical predictions for squirt-flow: Tectonophysics, 503, 173–181, doi: 10.1016/j.tecto.2010.10.012. Hamon, 2019, Effective medium modeling of the diagenesis impact on the petroacoustic properties of carbonate rocks: Geophysics, 84, this issue, doi: 10.1190/geo2018-0559.1. Brevik, 2006, Gassmann’s fluid substitution and shear modulus variability in carbonates at laboratory seismic and ultrasonic frequencies: Geophysics, 71, no. 6, F173–F183, doi: 10.1190/1.2358494. Batzle, 2008, Elastic properties of carbonates from laboratory measurements at seismic and ultrasonic frequencies: The Leading Edge, 27, 1026–1032, doi: 10.1190/1.2967556. The obtained results demonstrate the applicability of Biot-Gassmann’s equation for the two studied carbonate families and indicate the link between their petroacoustic signature and diagenetic history. This approach is implemented on samples representative of two different carbonate formations deposited in lacustrine and marine environments, respectively. It allows the identification of the whole set of parameters required by Biot-Gassmann’s equation including the bulk modulus of the solid matrix. The defined approach is based on the phase-velocity measurements performed in liquid-saturated conditions using polar and nonpolar fluids. We have developed an integrated experimental workflow that allows a consistent checking of the applicability of Biot-Gassmann’s equation and provides key geologic and microstructural information to understand the petroacoustic signature of carbonate rocks. The still-discussed applicability of Biot-Gassmann’s equation for fluid substitution in carbonate rocks remains another key issue. The velocity disparities between carbonates of similar mineralogy and porosity result from different microstructures derived from their sedimentary facies and subsequent diagenetic transformations. ![]() At the laboratory scale, carbonate rocks do not indicate a strong correlation between P- and S-wave velocities and porosity. Carbonate formations are characterized by multiscale heterogeneities that control their acoustic response and flow properties. ![]()
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