2016
DOI: 10.1093/gji/ggw302
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An energy-based approach to estimate seismic attenuation due to wave-induced fluid flow in heterogeneous poroelastic media

Abstract: Whenever a seismic wave propagates through a fluid-saturated porous rock that contains heterogeneities in the mesoscopic scale range, that is, heterogeneities that are much larger than the typical pore size but much smaller than the predominant wavelengths, local

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Cited by 26 publications
(42 citation statements)
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“…5, we observe excellent agreement between the results based on the energy-based approach and those obtained based on the viscoelastic assumption, which validates the use of the viscoelastic approach to upscale attenuation and dispersion characteristics from our heterogeneous medium described by the coupled LNS equations. For consistency, we do the same for the numerical scheme based on Biot's equations using the equations derived by Solazzi et al (2016) and, as these authors point out, the agreement is nearly perfect (Fig. 5).…”
Section: Interconnected Rectangular Cracksmentioning
confidence: 84%
“…5, we observe excellent agreement between the results based on the energy-based approach and those obtained based on the viscoelastic assumption, which validates the use of the viscoelastic approach to upscale attenuation and dispersion characteristics from our heterogeneous medium described by the coupled LNS equations. For consistency, we do the same for the numerical scheme based on Biot's equations using the equations derived by Solazzi et al (2016) and, as these authors point out, the agreement is nearly perfect (Fig. 5).…”
Section: Interconnected Rectangular Cracksmentioning
confidence: 84%
“…The same reasoning can be applied to the P wave attenuation at low fracture densities, although it does not explain the behavior at high fracture densities. Local contribution to the overall seismic attenuation per unit area (Solazzi et al, 2016) at the frequency of the second attenuation peak for (a, b) P waves and (c, d) S waves for a fracture network with a fracture density of 1.5% (Figures 10a and 10c) and a fracture density of 3.25% (Figures10b and 10d). A close inspection of the fluid pressure fields reveals certain areas with lower induced fluid pressures within the fractures than on average (orange ellipse in Figure 8i).…”
Section: Fracture-to-fracture Fpdmentioning
confidence: 99%
“…To compute the inverse quality factor density for the relaxation tests, we follow the energy-based approach described in Solazzi et al (2016). By doing so, the local contribution to the inverse quality factor per unit area can be written as…”
Section: Appendix A: Inverse Quality Factor Densitymentioning
confidence: 99%