A new depositional model for the Tuaheni Landslide Complex, Hikurangi Margin, New Zealand

AbstractThe Tuaheni Landslide Complex (TLC) is characterized by areas of compression upslope and extension downslope. It has been thought to consist of a stack of two genetically linked landslide units identified from seismic data. We used 3D seismic reflection, bathymetry data and International Ocean Discovery Program Core U1517C (Expedition 372) to understand the internal structures, deformation mechanisms and depositional processes of the TLC deposits. Units II and III of U1517C correspond to the two chaotic units in 3D seismic data. In the core, Unit II shows deformation, whereas Unit III appears more like an in situ sequence. Variance attribute analysis showed that Unit II is split into lobes around a coherent stratified central ridge and is bounded by scarps. By contrast, we found that Unit III is continuous beneath the central ridge and has an upslope geometry, which we interpreted as a channel–levee system. Both units show evidence of lateral spreading due to the presence of the Tuaheni Canyon removing support from the toe. Our results suggest that Units II and III are not genetically linked, are separated substantially in time and had different emplacement mechanisms, but they fail under similar circumstances.

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THE APPLICATION OF 3D SEISMIC INTERPRETATION TECHNIQUES FOR OPTIMISING WELL PLACEMENT: FORTESCUE FIELD RE DEVELOPMENT, GIPPSLAND BASIN

The APPEA Journal ◽

10.1071/aj96002 ◽

1997 ◽

Vol 37 (1) ◽

pp. 31

Author(s):

P.J. Ryan ◽

T.E. Vinson

Keyword(s):

High Precision ◽

Seismic Data ◽

Development Program ◽

Seismic Interpretation ◽

3D Seismic ◽

Well Placement ◽

Seismic Waveform ◽

Attribute Analysis ◽

Definition Of ◽

Gippsland Basin

In order to achieve successful drilling results on mature fields, geophysical analysis has become increasingly focussed on the application of high precision 3D seismic interpretation and analysis techniques. These techniques were critical to the success of the re-development program recently completed on the Fortescue Field* Gippsland Basin. Fortescue, initially developed in 1983, contains an estimated oil reserve of 300 million barrels. The field is currently over 80 percent depleted. To offset declining production and develop remaining reserves, an 18 well additional drilling program together with upgrades to platform topsides and production facilities was conducted on the field from October 1994 to October 1996.Many of the proposed additional drilling opportunities relied on oil being trapped structurally updip from existing completions. Given the size (approx. 1 MSTB) and subtle, low relief nature of the targets being pursued, the precision of conventional 3D seismic interpretation techniques was inadequate to optimise the location of wells. This necessitated the development of a series of specific tools that could provide high resolution definition of both the trap and lithology as well as optimising well placement.These high precision interpretation techniques include: reservoir subcrop edge prediction through qualitative calibration of geological models to seismic data: the assessment of overburden velocity distortions of the seismic time field by utilising isochron mapping and interval attribute analysis; and prediction of trap geometries and lateral stratigraphic variations by the application of seismic waveform attributes.The application of these advanced 3D seismic interpretation techniques and their integration with related geoscience and engineering technologies resulted in the completion of a successful 18 well re-development program for the Fortescue field.

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Recursive inversion and attribute analysis of 3D seismic data over a four-way dip structure, Gulf of Thailand

10.29118/ipa.196.77.97 ◽

2018 ◽

Author(s):

S. Thanatit

Keyword(s):

Seismic Data ◽

Gulf Of Thailand ◽

3D Seismic ◽

Attribute Analysis ◽

3D Seismic Data

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Study of Geological Setting of Naftalan-Northern Naftalan Area by Use of Attribute Analysis of 3D Seismic Data

Lecture Notes in Civil Engineering - Innovations and Technologies in Construction ◽

10.1007/978-3-030-72910-3_2 ◽

2021 ◽

pp. 7-14

Author(s):

M. A. Aghayeva

Keyword(s):

Seismic Data ◽

3D Seismic ◽

Geological Setting ◽

Attribute Analysis ◽

3D Seismic Data

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Identification of polygonal faulting from legacy 3D seismic data in vintage Gulf of Mexico data using seismic attributes

Interpretation ◽

10.1190/int-2019-0255.1 ◽

2021 ◽

pp. 1-17

Author(s):

Karen M. Leopoldino Oliveira ◽

Heather Bedle ◽

Karelia La Marca Molina

Keyword(s):

Seismic Data ◽

Seismic Attributes ◽

Fault System ◽

3D Seismic ◽

Seismic Attribute ◽

Variable Amplitude ◽

Attribute Analysis ◽

Amplitude Data ◽

3D Seismic Data ◽

Polygonal Fault

We analyzed a 1991 3D seismic data located offshore Florida and applied seismic attribute analysis to identify geological structures. Initially, the seismic data appears to have a high signal-to-noise-ratio, being of an older vintage of quality, and appears to reveal variable amplitude subparallel horizons. Additional geophysical analysis, including seismic attribute analysis, reveals that the data has excessive denoising, and that the continuous features are actually a network of polygonal faults. The polygonal faults were identified in two tiers using variance, curvature, dip magnitude, and dip azimuth seismic attributes. Inline and crossline sections show continuous reflectors with a noisy appearance, where the polygonal faults are suppressed. In the variance time slices, the polygonal fault system forms a complex network that is not clearly imaged in the seismic amplitude data. The patterns of polygonal fault systems in this legacy dataset are compared to more recently acquired 3D seismic data from Australia and New Zealand. It is relevant to emphasize the importance of seismic attribute analysis to improve accuracy of interpretations, and also to not dismiss older seismic data that has low accurate imaging, as the variable amplitude subparallel horizons might have a geologic origin.

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Quantitative application of post-stack inversion of organic-rich shale based on rock physics linear relationship and 3D seismic data, Perth Basin, Western Australia

The APPEA Journal ◽

10.1071/aj13105 ◽

2014 ◽

Vol 54 (2) ◽

pp. 532

Author(s):

Yazeed Altowairqi ◽

Reza Rezaee ◽

Milovan Urosevic

Keyword(s):

Shale Gas ◽

Seismic Data ◽

Rock Physics ◽

Seismic Inversion ◽

3D Seismic ◽

Physical Relationship ◽

Seismic Properties ◽

Attribute Analysis ◽

Exploration And Production ◽

Compressional Velocity

Unconventional resources such as shale gas have been an extremely important exploration and production target. To understand the seismic responses of the shale gas plays, the use of rock physical relationship is important, which is constrained with geology and formation-evaluation analysis. Since organic-rich shale seismic properties remains poorly understood, seismic inversion can be used to identify the organic-rich shale from barren shale. This approach helps identify and map spatial distributions and of the organic rich shales. This study shows the acoustic impedance (AI), which is the product of compressional velocity and density, decreases nonlinearly with increasing total organic carbon (TOC) content. TOC is obtained using Roc-Eval pyrolysis for more than 120 core shale samples for the Perth Basin. By converting the AI data to TOC precent on the seismic data, we therefore can map lateral distribution, thickness, and variation in TOC profile. This extended abstract presents a case study of the northern Perth Basin 3D seismic with application of different approaches of seismic inversion and multi-attribute analysis with the rock physical relationships.

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