Linear amplitude patterns in Corpus Christi Bay Frio Subbasin, south Texas: Interpretive pitfalls or depositional features?

Geophysics ◽  
2008 ◽  
Vol 73 (5) ◽  
pp. A27-A31 ◽  
Author(s):  
Hongliu Zeng ◽  
Robert G. Loucks ◽  
Ursula Hammes
Keyword(s):  
Seismic Data ◽  
South Texas ◽  
Dispersal Patterns ◽  
Reservoir Prediction ◽  
Sediment Dispersal ◽  
Corpus Christi ◽  
Bay Area ◽  
Corpus Christi Bay ◽  
3D Seismic Data ◽  
Geomorphological Features

Linear amplitude patterns on stratal slices in the Corpus Christi Bay area of Texas are important seismic geomorphological features that reflect sediment dispersal patterns. These amplitude patterns are oriented in both strike and dip directions. Some of the linear amplitude patterns are related to faults; however, most are related to orientation of sandstone bodies. Faulting may make the depositionally related linear amplitude patterns more fragmented, but faults do not destroy the overall orientation or geomorphologic significance of these patterns. Amplitude patterns on stratal slices should be interpreted as unbiased, general, sediment-dispersal patterns unless the patterns can be tied directly to a structural feature. In-depth understanding of structural and depositionally related amplitude patterns leads to more accurate stratal slicing interpretation in facies/reservoir prediction using poststack 3D seismic data.

Diapiric shale and coast-perpendicular, fault-related subbasins, south Texas Gulf Coast

2015 ◽  
Vol 3 (2) ◽  
pp. T43-T56 ◽  
Author(s):  
Osareni C. Ogiesoba ◽  
Rodolfo Hernandez
Keyword(s):  
Seismic Data ◽  
Gulf Coast ◽  
Structural Features ◽  
South Texas ◽  
3D Seismic ◽  
Texas Gulf Coast ◽  
Vertical Loading ◽  
The North ◽  
Visualization Tools ◽  
3D Seismic Data

Coast-perpendicular shale ridges are rare structural features worldwide, and their origin remains a subject of debate. We studied some coast-perpendicular shale ridges and faults within a minibasin located onshore in Refugio County in the Texas Gulf Coast. We used 3D seismic data, visualization tools, and seismic attributes to examine the geometry of coast-perpendicular diapiric structures associated subbasins (SBs) and faults, and coast-parallel listric faults. Our results indicated that the minibasin is subdivided into four SBs by five diapiric shale ridges that intrude through the fault heaves of down-to-the-basin (synthetic) and coast-perpendicular faults. Three of the SBs are oriented perpendicular to the coast, whereas the fourth has a curvilinear form trending northeast–southwest–southeast. Of the five diapiric shale ridges, three are coast-perpendicular. The other two are curvilinear to the coast. All five diapiric shale ridges are associated with coast-perpendicular faults that bound the flanks of the ridges. On the basis of our mapping results, we deduced that the origin of the coast-perpendicular faults in the study area are related to the coalescing of en echelon synthetic faults, as well as the coalition of synthetic and antithetic fault planes. We inferred that the origin of the shale diapirs is related to vertical loading and, possibly, local southwest–northeast lateral compression of interbedded, overpressured, shale-prone intervals. The coast-perpendicular faults within the Frio formed as a result of reactivation of the Eocene-Vicksburg coast-perpendicular faults. Synthetic faults dominate the pattern within the SB in the north where shale ridges are broad, whereas antithetic faults dominate the pattern in the south where shale ridges are narrow.

Tectonostratigraphic framework of the Lower Keraudren Formation, Bedout Sub-basin: interplay of tectonics and sedimentary systems

2018 ◽  
Vol 58 (2) ◽  
pp. 839 ◽  
Author(s):  
Jon Minken ◽  
Melissa Thompson ◽  
Jack Woodward ◽  
Fred Fernandes ◽  
Rylan Fabrici
Keyword(s):  
Seismic Data ◽  
Middle Triassic ◽  
Sediment Supply ◽  
Sediment Provenance ◽  
Reservoir Quality ◽  
Dispersal Patterns ◽  
North West ◽  
Sediment Dispersal ◽  
Stratigraphic Architecture ◽  
Basin Geometry

Recent drilling activity and new seismic data have contributed to the understanding of the Lower Keraudren Formation in the Bedout Sub-Basin. The Lower Keraudren Formation is a thick (>5 km) succession of strata that was deposited rapidly during the Anisian of the Middle Triassic. Distinctive characteristics related to sediment provenance, sediment supply and accommodation have facilitated subdivision of the Formation into eight informal units: the Milne, Crespin, Baxter, Caley, Hove, Barret, Palma, and Huxley members. Tectonic elements of the East Gondwana Interior Rift and the Bedout High influenced the Sub-basin geometry during deposition of the Lower Keraudren. Extensional tectonics of the East Gondwana Interior Rift generated a series of Palaeozoic tilted fault blocks and grabens, which influenced the stratigraphic architecture, sediment dispersal patterns and distribution of reservoir and source rock facies. The structurally proud Bedout High, a roughly circular (~60 km wide) igneous feature, created a northern boundary to deposition. Seismic stratigraphic interpretation has characterised the interval as a series of north west prograding wedges. Well based data indicates the section is dominated by fluvio-deltaic deposits. Separating the Caley and Hove Members is a significant unconformity that is associated with renewed uplift of the Bedout High and a change in sediment provenance. Chemostratigraphy and petrology indicates the Caley and older strata were derived from a more mature sediment source, whereas the Hove and younger a more immature metamorphic source. Distinct changes in reservoir quality are observed above and below the Caley–Hove unconformity. Below the unconformity, the older, more mature sandstones exhibit superior reservoir quality compared with the younger, more immature sandstones.

Extreme curvature and extreme flexure analysis for fracture characterization from 3D seismic data: New analytical algorithms and geologic implications

Geophysics ◽  
2015 ◽  
Vol 80 (2) ◽  
pp. IM11-IM20 ◽  
Author(s):  
Dengliang Gao ◽  
Haibin Di
Keyword(s):  
Seismic Data ◽  
Seismic Analysis ◽  
Fractured Reservoirs ◽  
Absolute Maximum ◽  
3D Seismic ◽  
Curve Shape ◽  
Reservoir Prediction ◽  
Fracture Characterization ◽  
3D Seismic Data ◽  
New Algorithms

Fracture characterization is fundamental to the reliable prediction of fractured reservoirs; however, it is difficult and expensive to obtain detailed fracture information required for reservoir prediction due to the lack of direct observational data in the subsurface. Here we develop seismic analysis methods to characterize fractured reservoirs based on reflection geometry related to bending and shearing of reservoir formations. Among various geometric attributes, we focus on extreme curvature and extreme flexure that are considered effective at detecting fractures. Extreme curvature refers to the signed absolute maximum curvature at a specific azimuth where the curve shape is the tightest, whereas extreme flexure refers to the signed absolute maximum gradient of curvature at a specific azimuth where the curve shape changes the most. We implement new algorithms based on analytical equations to calculate extreme curvature and extreme flexure along with the corresponding azimuth from 3D seismic data. Results from 3D seismic surveys demonstrate that the new algorithms help resolve structural details that are otherwise not easily discernible from regular amplitude and conventional attributes. Most importantly, the algorithms hold the potential to volumetrically detect and visualize fractures in an automatic and quantitative manner. We conclude that extreme curvature and extreme flexure attributes have important geologic implications for predicting fundamental fracture properties that are critical to fractured reservoir characterization in the subsurface.

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