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11.

The Leading Edge 2007;26:420-426.
The Backus number
Chris Liner and Tong Fei
[Abstract] [Full Text] [PDF]

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Figure 4. Synthetic shot record for the original isotropic layered model (left), and the VTI layered model after 15.5 m (51 ft) Backus averaging (right). This corresponds to about half of the minimum dominant wavelength.

12.

The Leading Edge 2008;27:382-384.
The flaw of averages and the pitfalls of ignoring variablity in attribute interpretations
Tapan Mukerji and Gary Mavko
[Abstract] [Full Text] [PDF]

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Figure 2. Relation between normal-incidence reflectivity and sand/shale ratio in very thin-bedded sand-shale layers. The back line is obtained using Backus average for thin layers, with blocked average values of sand and shale properties from well log. Curves show the result of computations using Monte Carlo simulation to incorporate the variability of sand and shale velocity, density, and impedance. The blue curve is the mean of the distributions obtained from the simulations, and the red and green dotted curves are the 10 percentile and 90 percentile curves, respectively. We see clearly the pitfalls of ignoring variability.

13.

The Leading Edge 2006;25:637-642.
The challenge of scale in seismic mapping of hydrate and solutions
Jack Dvorkin and Richard Uden
[Abstract] [Full Text] [PDF]

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Figure 3. Earth model with three methane hydrate layers. From left to right: clay content, porosity, hydrate saturation, and acoustic impedance. The red curve is the Backus average of the log-scale impedance using a running 5-m window. The plot on the right shows a model impedance versus hydrate saturation curve (blue) and the seismic-scale impedance and inferred hydrate saturation (red). Black represents the log-scale impedance.

14.

The Leading Edge 2001;20:1056-1059.
Predrill pore-pressure prediction using 4-C seismic data
Colin M. Sayers, Marta J. Woodward, and Robert C. Bartman
[Full Text] [PDF]

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Figure 9. Comparison of the P-wave velocity obtained by tomography at the vertical well with the interval velocity obtained by upscaling the sonic log using Backus averaging (left). The tomographic S-wave velocity at the well compared to the prediction of the mudrock line using the tomographic P-wave velocities (right).

15.

The Leading Edge 2002;21:188-192.
Seismic pore-pressure prediction using reflection tomography and 4-C seismic data
Colin M. Sayers, Marta J. Woodward, and Robert C. Bartman
[Full Text] [PDF]

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Figure 10. Comparison (left) of the P-wave velocity obtained by isotropic tomography at the vertical well with the interval velocity obtained by upscaling the sonic log using Backus averaging. The isotropic tomographic S-wave velocity (right) at the well compared with prediction of the mudrock line using the tomographic P-wave velocities.

16.

The Leading Edge 2002;21:380-387.
Estimation of net-to-gross from P and S impedance in deepwater turbidites
L. Vernik, D. Fisher, and S. Bahret
[Full Text] [PDF]

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Figure 2. Petrofacies average laminar V_sh, V_P (a) and fast V_S (b) for subsets of straight (red) and deviated (green) wells superposed by the best-fit Backus models.

17.

The Leading Edge 2001;20:1056-1059.
Predrill pore-pressure prediction using 4-C seismic data
Colin M. Sayers, Marta J. Woodward, and Robert C. Bartman
[Full Text] [PDF]

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Figure 10. Comparison of the P-wave velocity obtained by tomography at the deviated well with the interval velocity obtained by inverting the check shot and by upscaling the sonic log using Backus averaging (left). The tomographic S-wave velocity at the well compared to the prediction of the mudrock line using the tomographic P-wave velocities.

18.

The Leading Edge 2002;21:188-192.
Seismic pore-pressure prediction using reflection tomography and 4-C seismic data
Colin M. Sayers, Marta J. Woodward, and Robert C. Bartman
[Full Text] [PDF]

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Figure 9. Comparison (left) of the P-wave velocity obtained using isotropic tomography at the deviated well with the interval velocity obtained by inverting the check shot and by upscaling the sonic log using Backus averaging. The isotropic tomographic S-wave velocity (right) at the well compared with prediction of the mudrock line using tomographic P-wave velocities.

19.

The Leading Edge 2001;20:996-1007.
Borehole-integrated anisotropic processing of converted modes
Scott Leaney, Richard Bale, Mark Wheeler, and Sergei Tcherkashnev
[Full Text] [PDF]

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Figure 5. The piecewise gradient anisotropy model used for VTI traveltime calibration. Anisotropy parameters are assumed to increase (or decrease) linearly with depth subject to a shaliness threshold so that reservoir sands may be made isotropic (or weakly anisotropic through Backus averaging if log data are available).

20.

The Leading Edge 2003;22:842-847.
Rock physics of a gas hydrate reservoir
Jack Dvorkin, Amos Nur, Richard Uden, and Turhan Taner
[Full Text] [PDF]

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Figure 9. Pseudowell with methane hydrate. From left to right: clay content; total porosity; hydrate and gas saturation; P-wave impedance; and Poisson's ratio. The impedance and PR. are calculated from porosity, clay content, and saturation according to the gas hydrate model. In the last two frames the blue curves are for the original log data and red curves represent Backus average upscaling.

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