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The Leading Edge 2006;25:839-845.
Tectonostratigraphy and depositional patterns in Krishna Offshore Basin, Bay of Bengal
Ravi Bastia and Prasanta K. Nayak
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Figure 12. Isopach map between basement and top Maastrichtian indicating sedimentation pattern controlled by rift architecture. Red indicates maximum thickness. Gray indicates very-thin-to-zero thickness as evident on Krishna Ridge. The contour interval is 750 m.

The Leading Edge 2007;26:966-968.
Integration—the watchword for pore-pressure studies
Dan Ebrom, Martin Albertin, Dave Greeley, and Phil Heppard
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Figure 2. The pore pressure distribution in a basin is the accumulated effect of sedimentation rate, sediment type, and architecture. Note how pore pressure (easily seen in ppg terms) increases due to fluid transfer updip. (Figure courtesy of Tim Matava.)

The Leading Edge 2006;25:830-837.
Basin architecture and petroleum system of Krishna Godavari Basin, east coast of India
S. K. Gupta
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Figure 8. Tertiary depositional model showing influence of growth tectonics over the sedimentation during Late Drift Stage IV.

The Leading Edge 2009;28:332-338.
Joint poststack P- and PS-wave impedance inversion and an example from northern China
Chen Maoshan, Zhan Shifan, Wan Zhonghong, and Liu Lanfeng
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Figure 4. P-wave velocity from inversion (near well S16). P-wave velocity units are m/s. Green and yellow represent sand sedimentation.

The Leading Edge 2006;25:478-482.
A petroleum systems study of the northern Gulf of Mexico
Tim Matava
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Figure 3. A schematic diagram illustrating the principle used to deform autochthonous salt. Differential stress on the top of salt (yellow layer) results from laterally varying rates of sedimentation. Differential stress on the salt is expressed as a stress perturbation from the mean or average stress. Salt deforms such that the stress within the salt on a datum is a constant value. The implication is that salt is an isotropic material that does not support shear. In fluids, such an assumption is called the hydrostatic assumption and is a standard scaling method applied to a momentum balance.

The Leading Edge 2002;21:1103-1111.
Comparison of depositional sequences and tectonic styles among the West African deepwater frontiers of western Ivory Coast, southern Equatorial Guinea, and northern Namibia
Katrina Coterill, Gabor C. Tari, Jim Molnar, and Paul R. Ashton
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Figure 11. Seismic section across the northern portion of the Equatorial Guinea study area. Senonian age ponded turbidites are formed behind the salt-cored toe-thrust. Tertiary and late Cretaceous sedimentation consists of cyclical, aggradational slope fan deposits. Vertical axis is two-way traveltime in seconds.

The Leading Edge 2002;21:826-836.
Frequency-enhanced imaging of stratigraphically complex, thin-bed reservoirs: A case study from South Marsh Island Block 128 Field
Marcus L. Countiss
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Figure 9. Revised subsurface cross-section based on standard bandwidth 3D seismic. Note increased complexity of correlations compared to Figure 5. This stratigraphy seems more likely given the depositional environment and lobe shifting sedimentation style.

The Leading Edge 2006;25:620-628.
Seafloor reflectivity—An important seismic property for interpreting fluid/gas expulsion geology and the presence of gas hydrate
Harry H. Roberts, Bob A. Hardage, William W. Shedd, and Jesse Hunt, Jr.
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Figure 3. This figure summarizes the response at the seafloor of venting-to-seepage rates of hydrocarbons, formation fluids, and fluidized sediment (modified from Roberts, 2001). Rapid-flux systems are generally accompanied by fluidized sediment resulting in mudflows and mud volcanoes of various dimensions. Sedimentation rates are typically too high to support complex communities of benthic organisms. Bacterial mats (Beggiatoa) and lucinid-vesycomyid clams occur on the surfaces of recently deposited sediments laced with hydrocarbons. Slow-flux systems are characterized by hardgrounds and mound-like buildups of authigenic carbonates. Intermediate-flux areas support large and densely populated communities of chemosynthetic mussels and tube worms. Localized authigenic carbonate hardgrounds and bacterial mats are also common to this setting. Each picture has a field of view of 2–4 m across.

The Leading Edge 2004;23:760-765.
Hydrocarbon generation, migration, and venting in a portion of the offshore Louisiana Gulf of Mexico basin
L. M. Cathles
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Figure 4. The geologic evolution of the stretched McBride section shown in Figure 3 was determined by backstripping, decompacting, and moving salt from areas of higher- to less-than-average top of salt depression. In the inferred evolution, the Louann salt migrates to form a salt sill at 10.5 Ma. Sedimentation then produces a salt-withdrawal minibasin in the north (5.8 Ma) and then in the south (1.4 and 0 Ma). Hydrocarbon maturation in the Jurassic and Eocene source strata is significant in the last $~$ 15 Ma (Figure 8).

10.

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Figure 2. Although all three study areas have undergone similar passive margin development, their stratigraphic signatures show considerable variations. The Ivory Coast section shows middle to upper Cretaceous interbedded sands and shales overlain by Tertiary shales. Equato-Guinean stratigraphy includes salt deposition in the Aptian and some carbonate deposition during the Albian, with clastic sediments later in the Senonian. Namibia stratigraphy lacks cyclicity in sedimentation and appears to be dominated by a major hiatal event that spans the late Cretaceous through the early Tertiary. No salt is identified in Namibia; however carbonates are documented in the Albo-Aptian section to the south.

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