3D Seismic Attribute Analysis in Browse Basin, Australia

3D SEISMIC ATTRIBUTE ANALYSIS IN
BROWSE BASIN, AUSTRALIA
A graduation project submitted to the Department of
geophysics a partial fulfillment of the requirements for
the award of B.Sc. in Applied geophysics
BY
Seham Atia
Mohammed Abdel-Aal
Alaa Hussien
Supervised by
Dr. Azza Mahmoud Abd El-Latif El-Rawy
Lecturer at Geophysics Department- Faculty of Science- Ain Shams
University
Cairo - 2018

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ACKNOWLEDGMENT
Our appreciations and gratitude to our supervisor Dr.Azza EL-Rawy for her
help to complete this project by guidance ,continuous support, efforts and correct
the mistakes . The words fail to thanks her.
We are also thankful to Dr. Mohamed Ali from Ganoub El Wadi Petroleum
Holding Co for his help and advices and to Mr. Mohamed ibrahim shihata for his
self-training online
Also, to Geophysics department who gave us a help to complete this
project.
Finally, to our dear parents and our colleagues who are supporting and
tolerating us by show their love and gave words of encouragement that pushed us
to do the best.

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Abstract
The project area is (Poseidon 3D, Browse Basin) Marine Surface Seismic
Survey is located approximately 350 km offshore north of Broome in Western
Australia.
As determination of lithology and fluid content distribution is desirable
objective for reservoir characterization.
We used in our project the help of 3D seismic attributes to enhance our
interpretation especially spectral decomposition (SD) attribute which Separate the
seismic signal into its constituent frequencies. This allows the user to see phase
and amplitude tuned to specific wavelengths, so after applying it we know the
dominant frequency range of our pre-stack data is (30 HZ and 40 HZ) which give
high resolution and showed the reservoir channel.
Also, we used Cross plot which showed relationships between seismic data
and well data. Applying Cross plot (seismic attribute Vs. Seismic attribute), By
plotting Cross-plots between Spectral Decomposition (SD) 30 Hz on X-axis and 40
Hz on Y-axis - in the 3cubes, which showed variation in thickness or saturation
between reservoir and surrounding rocks.
________________________________________________
Key Words: Browse Basin, 3D seismic interpretation, Seismic Attributes and
Cross-plots

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List of Contents Page
.No
Acknowledgment………………………………………………………………………. I
Abstract………………………………………………………………………………… II
List of Contents ……………………………………………………………….............. III
List of Figures…………………………………………………………………............. V
List of Tables…………………………………………………………………………... VIII
CHAPTER (1) INTRODUCTION……………………………………………............ 1
1.1 Location of the study Area………………………………………………………... 1
1.2 Objective………………………………………………………………….............. 1
1.3 Available Data……………………………………………………………………. 2
1.4 Methodology of techniques………………………………………………………. 2
1.4.1 Conventional Interpretation…………………………………………………… 2
1.4.2 Un conventional Interpretation………………………………………………... 2
1.5 Exploration History……………………………………………………….............. 2
CHAPTER (2) GEOLOGICAL SETTING…………………………………....…….. 4
2.1) Introduction……………………………………………………………………… 4
Chapter (3) DATA DESCRIPTION and 3D SEISMIC
INTERPRETATION………………………………………………………………….. 13
3.1 Introduction……………………………………………………………………….. 13
3.2 Data Acquisition………………………………………………………………….. 13
3.2.1 Data Acquisition Parameters…………………………………………………. 13
3.3 Data Processing…………………………………………………………………… 14
3.3.1 Processing Parameters………………………………………………………... 14
3.4 Software…………………………………………………………………………... 18
3.5 workflow………………………………………………………………………….. 18
3.6 picking……………………………………………………………………………. 20

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CHAPTER (4) SEISMIC ATTRIBUTE……………………………………………... 24
4.1 Why do we generate Seismic Attributes?………………………………………… 24
4.2 Classifications of Seismic Attributes……………………………………………... 24
4.3 Attribute workflow……………………………………………………………….. 26
4.4 Instantaneous Attribute…………………………………………………………… 26
4.4.1 Instantaneous amplitude……………………………………………………… 27
4.4.2 Instantaneous Phase…………………………………………………………... 28
4.5 Volume attribute …………………………………………………………………. 29
4.5.1 Amplitude Attribute…………………………………………………………... 29
4.5.1.1 RMS Attribute……………………………………………………………. 29
4.5.1.2 Energy attribute…………………………………………………………… 30
4.5.2 Similarity attribute……………………………………………………………. 31
4.5.3 Absorption Quality Factor……………………………………………………. 32
4.5.4 Spectral Decomposition………………………………………………………. 33
CHAPTER 5 Cross-plot………………………………………………………………. 41
5.1 SEDIMENTARY ENVIRONMENTS…………………………………………… 41
5.1.1 Meandering streams…………………………………………………………... 41
5.2 Cross-Plot………………………………………………………………………… 42
5.2.1 Seismic attributes vs. seismic attributes……………………………………… 43
Summary Conclusion…………………………………………………………………. 48
References……………………………………………………………………………… 49

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List of Figures Page
.No
Figure (1) the Poseidon 3D Seismic Survey Regional Location…………………….. 1
Figure (2) Figure (2) Regional Structural Elements Map……………………………. 5
Figure (3) Figure (3) Stratigraphic Column of browse basin………………………... 6
Figure (4) Figure (4) Major structural elements of the Timor Sea…………………... 10
Figure (5) Figure (5) Structural elements of the Vulcan Graben……………………. 10
Figure (6) Figure (6) tectonic of Timor Sea…………………………………………. 11
Figure (7) Survey parameters………………………………………………………... 19
Figure (8) Import the Seismic Data………………………………………………….. 19
Figure (9) Wavelet extraction parameters…………………………………………… 19
Figure (10) synthetic seismogram…………………………………………………… 20
Figure (11) Picking of jamieson Fm cross line (near-stack)………………………… 20
Figure (12) Picking of jamieson Fm in line (near-stack)……………………………. 20
Figure (13) Picking of jamieson Fm cross line (mid-stack)…………………………. 20
figure (14) Picking of jamieson Fm in line (mid-stack)……………………………... 20
Figure (15) Picking of jamieson Fm cross line(far-stack)…………………………… 21
figure (16) Picking of jamieson Fm in line (far-stack)………………………………. 21
Figure (17) well marker……………………………………………………………… 21
Figure (18) plover Fm……………………………………………………………….. 21
Figure (19) TWT map for top plover Fm……………………………………………. 22
Figure (20) surface map for top plover Fm, with Amplitude Variance attribute……. 22
Figure (21) surface map for top plover Fm, with Energy attribute………………….. 22
Figure (22) Amplitude Spectrum of the Data………………………………………... 23
Figure (23) complex seismic trace…………………………………………………... 26
Figure (24) Instantaneous amplitude attribute………………………………………. 27

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Figure (25) Instantaneous amplitude attribute………………………………………. 27
Figure (26) Instantaneous phase attribute…………………………………………… 28
Figure (27) Instantaneous phase attribute…………………………………………… 28
Figure (28) RMS attribute at 3300…………………………………………………... 30
Figure (29) RMS attribute at 3400…………………………………………………... 30
Figure (30) Energy attribute at 3300………………………………………………… 31
Figure (31) Energy attribute at 3400………………………………………………… 31
Figure (32) Coherence time Slice at 3400…………………………………………… 32
Figure (33) Application of absorption quality factor………………………………... 33
Figure (34) Spectral Decomposition 20 attribute at slice 3300……………………… 35
Figure (45) Spectral Decomposition 30 attribute at slice 3300 (mid stack)…………. 38
Figure (49) Spectral Decomposition 30 attribute at slice 3300 (far stack)………….. 39

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Figure (53) show the degree of meandering that controlled by the energy of
sediments………….………….………….………….………….………….…………
41
Figure (54) shows meander and oxbow………….………….………….…………… 42
Figure (55) polygons drawn to indicate meander and oxbow………….……………. 42
Figure (56) polygon drawn at slice 3300………….………….………….………….. 43
Figure (57) cross-plot between SD 20 & SD 30 (near stack)………….………….…. 43
Figure (58) cross-plot between SD 20 & SD 30 with high selection………….…….. 44
Figure (59) display high selection at the polygon………….………….………….…. 44
Figure (60) cross-plot between SD 20 & SD 30 with low selection………….……... 44
Figure (61) Display low selection at the polygon………….………………………... 45
Figure (62) display the two selections at the polygon.………….…………………… 45
Figure (63) cross-plot between SD 20 & SD 30 (mid stack)………….………….…. 45
Figure (64) cross-plot between SD 20 & SD 30 (mid stack) high selection………… 46
Figure (65) cross-plot between SD 20 & SD 30 (mid stack) low selection…………. 46
Figure (66) display the two selections at the polygon………….……………………. 46
Figure (67) cross-plot between SD 20 & SD 30 (far stack)………….……………… 46
Figure (68) cross-plot between SD 20 & SD 30 (far stack), with high selection……. 47
Figure (69) cross-plot between SD 20 & SD 30 (far stack), with low selection…….. 47
Figure (70) display the two selections at the polygon.………….………….………... 47

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List of Tables Page.No
Table (1) Summary of 2D Seismic Data………….………….………… 3
Table (2) Summary of the major tectonic events in Browse Basin…….. 12
Table (3) the parameters used in the acquisition of the Poseidon 3D...... 13
Table (4) the parameters used in the processing of Poseidon 3D……… 14

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CHAPTER 1
INTRODUCTION
1.1 Location of the study Area
The Poseidon block (Poseidon 3D) area is located in Browse Basin
approximately 350 km offshore north of Broome in Western Australia (Figure 1).
Figure (1) the Poseidon 3D Seismic Survey Regional Location
1.2 Objective
The principle objective of 3-D seismic interpretation is an extraction of geologic
information from seismic data. Based on what you need to know. 3-D seismic data
have become the key tool used in the oil and gas industry to understand the subsurface.
In addition to providing excellent structural images, the dense sampling of a 3-D survey
can sometimes make it possible to map reservoir quality and the distribution of oil and
gas. Seismic data should not be interpreted in a stand-alone fashion.

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Interpreting seismic data requires an understanding of the subsurface formations
and how they may affect wave reception. Both geological and geophysical expertise
and data need to be included in a “complete” interpretation (Bacon, et al 2003).
1.3 Available Data
Seismic interpretation in this study is utilized pre-stack seismic Data; near, mid
and far Cubes with CBVS format. As well as, wells data (Density and Delta T
Compressional sonic) logs and VSP segy Data.
1.4 Methodology of techniques
1.4.1 Conventional Interpretation
• Data loading
• Wells (import & display)
• Well tops
• VSP data
• Wavelet extraction
• Seismic to well tie
• Horizon Interpretation
• Tie loop
• Export Seismic Horizon
• Mapping (time map)
1.4.2 Un conventional Interpretation
• Seismic Attributes
• Channel Interpretation
• Cross plot
1.5 Exploration History
In the Poseidon 3D area, 2D seismic data was the primary data set used in the
interpretation. 2D data in the area was used to tie into nearby wells and for regional

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mapping purposes. The 2D sets available to incorporate into the interpretation are given
in Table 1.
Table (1) Summary of 2D Seismic Data in WA-315-P and WA-398-P
The existing BKG05a 3D seismic survey was also used in the regional
evaluation. The BKG06b survey was superseded by the Poseidon survey, the Poseidon
3D data has been processed to a polarity of SEG reverse (an increase in acoustic
impedance across a boundary is a negative number and a trough). The 2D data has been
balanced to match the Poseidon 3D polarity. The Poseidon 3D shows improved data
quality over the existing 2D and 3D datasets. The Poseidon 3D data is considered of
high quality.

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CHAPTER 2
GEOLOGICAL SETTING
2.1 Introduction
The study area; Browse Basin is a northeast-southwest trending, Palaeozoic to
Cenozoic depocentre located entirely in the offshore Timor Sea region off the coast of
Western Australia. It extends over an area of approximately 140,000 km2
and contains
in excess of 15 km of sediments. The basin sits between the Scott Plateau and Argo
Abyssal Plain to the northwest and the Kimberley Block to the southeast. It is also
flanked by the Yampi - Leveque shelves to the southeast and is contiguous with the
Rowley Sub-basin of the Roebuck Basin to the southwest and the Vulcan Sub-basin of
the Bonaparte Basin to the northeast Figure (2).
The basin has been divided into a number of structurally defined features Figure
(2). The Browse Basin is composed by the Leveque Shelf, Yampi Shelf, Barcoo Sub-
basin, Caswell Sub-basin, Scott Plateau, Seringapatam Sub-basin.
Browse Basin commenced formation during the Late Carboniferous through to
the Early Permian as a result of an extensional phase associated with the separation of
Sibumasu from northwestern Australia. This resulted in the formation of a series of
extensional intracratonic half grabens. Initial basin fill was dominated by
fluviodeltaics in the Carboniferous, grading to marine shales and limestones in the
Lower Permian. The basin then underwent a phase of thermal subsidence in the Late
Permian continuing through to the Triassic.
A period of increased tectonism commenced in the Late Triassic, with the
initiation of the break-up of Australia from Argoland. Associated block faulting
generated the dominant southwest-northeast trending structural grain and many of the
present-day basin elements, including the arcuate Buffon trend and the Scott Reef –
Brecknock anticlinal trends Figure (2).

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Figure (2) Regional Structural Elements Map (WA-314-P, WA-315-P and WA-398-P
highlighted in yellow)
2.2 stratigraphy
The Browse Basin is considered to contain over 11000 m of Carboniferous to
Recent sediment (Allen et al., 1978; Elliott, 1990) as summarized on the stratigraphic
column in Figure (3). The Permian to Middle Triassic post rift sag phase resulted in
deposition of shales, sands and carbonates of the Hyland Bay Formation and marine
shales of the Mt Goodwin Formation. Regression in Middle to Late Triassic times
saw shallow marine sands and carbonates deposited as part of the Osprey, Pollard,
Challis and Nome Formations. A Stratigraphic Column of the Browse Basin is
provided in Figure (3).
Although pre-Triassic sedimentary rocks have only been drilled along the
eastern flank of the basin, it is commonly assumed that Permo-Carboniferous and

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perhaps older Palaeozoic rocks extend throughout the area (Allen et al., 1978;
Passmore, 1980; Elliott, 1990; Cadman et al., 1991; Wilmot et al., 1993).
Figure (3) Stratigraphic Column of browse basin

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A detail about stratigraphy of each formation is discussed from the importance
for hydrocarbon point of view i.e. Source rock, Reservoir and Seal rock
2.2.1 Source rocks
Comprehensive assessment of the source rock potential of the Browse Basin
was unertaken by Boreham et al (1997), and the results summarised by Blevin et al
(1998a, 1998b). These studies recognised organic-rich rocks with fair to moderate oil
potential at numerous stratigraphic levels within the Permian to Lower Cretaceous
succession.
Local, thin, high-quality coals and pro-delta shales with high source potential
occur within the thick succession of Lower– Middle Jurassic Plover Formation
sediments that extend throughout the Caswell Sub-basin and reach a maximum
penetrated thickness within the Barcoo Sub-basin (920 m in Barcoo 1). This section is
dominated by fluvio-deltaic sediments, including pro-delta shales and coastal plain
shaly coals that have significant source potential (Blevin et al, 1998b). Hydrocarbons
generated from this succession are likely to be dominated by gas rather than oil.
Thick claystones within the Lower Cretaceous Echuca Shoals and Jamieson
formations occur within both the Caswell and Barcoo sub-basins and contain mixed
marine and terrestrial organic matter with moderate to good source potential. However,
available pyrolysis data suggests that these sediments have better liquid hydrocarbon
potential in the Caswell Sub-basin than in the Barcoo Sub-basin (Kennard et al, 2004).
2.2.2 Reservoir Rocks
The main reservoir in the area is Plover Formation. Its age: Early to Mid Jurassic
(Hettangian – Callovian), in interval ranges from 4585.0 m to 5075.0 m. Its thickness
is about 490.0 m. The Plover Formation can be divided into two distinctive lithological
units.
2.2.2.1 Formation: Plover Formation (Top Volcanics)
This section of the Plover Formation consists of interbedded volcanics and
siltstone, with trace sandstone. The volcanics have been subdivided into three types –

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volcanics, ferruginous volcanics and argillaceous volcanics. Volcanics are light
greenish grey to greenish grey, yellowish grey, white to very light grey, mottled,
occasional fine granular texture, predominantly soft, occasionally firm, subblocky,
non-calcareous, common chlorite grains where aggregated. Ferruginous volcanics are
predominantly pale reddish brown, occasionally greyish red and pale brown, soft to
firm, amorphous, trace sub-blocky. Siltstone is light olive grey to olive grey, olive
black, predominantly firm, occasionally hard, sub-blocky, slightly calcareous, mottled,
trace black lithic laminae, trace quartz silt, trace micromicaceous, common chlorite
staining and fine grains. Sandstone is translucent to transparent, unconsolidated, very
fine, sub-rounded to rounded, well sorted. Calcimetry data range is 10-14 / 4-6 % for
calcium and magnesium content respectively
2.2.2. Formation: Plover Formation (Top Reservoir)
This section of the Plover Formation consists of interbedded sandstone, siltstone
and volcanics, with minor calcilutite and trace claystone. Sandstone is moderate light
brown to pale yellowish brown, light olive grey to yellowish grey, white, translucent,
abundant clean loose grains, friable to very hard, very fine to medium, moderately to
well sorted, sub-angular to sub-rounded, commonly silty, siliceous cement, weak
calcareous cement. Siltstone is olive grey to olive black, medium to dark grey, and soft
to moderately hard. Interval ranges from 4776.0m to 5075.0m. Its thickness is about
299.0 m
2.2.3 Seals Rocks
Caswell Sub-basin
Exploration activity has focused on the Caswell Sub-basin, where the Upper
Jurassic–Lower Cretaceous upper Vulcan and Lower Cretaceous Echuca Shoals and
Jamieson Formations form the regional seal. The thick (500–600 m) Callovian–
Turonian claystone seal exceeds the throw of the faults within the underlying
reservoirs, ensuring an adequate lateral seal across much of the basin. Sections within
the lower Vulcan Formation also form adequate seals for Plover Formation reservoirs.
Potential intraformational sealing shales occur within the Plover Formation (Blevin et

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al, 1998b), while marls and mudstones provide potential seals for Campanian–
Maastrichtian ponded turbidites and unconfined fan sandstones in the Puffin Formation
(Benson et al, 2004). The influence of basement controlled drainage patterns on the
Kimberly Block has had a profound effect on the distribution of shelf sedimentation of
both reservoirs and seals (Tucker, 2009).
2.3 Structure Setting
The Vulcan Graben is located within the Timor Sea on the far northwestern
Australian margin and lies approximately half-way between the Kimberley Block and
Timor (Figure b). It is presently one of Australia's most active petroleum exploration
areas, with a number of Significant oil discoveries, including the Jabiru, Challisj
Cassini, and Skua fields. It is flanked by two major elevated blocks, the Ashmore
Platform to the northwest and the Londonderry High to the southeast Figures (4) & (5).
The Vulcan Graben itself is sub-divided into a series of NE- and ENE-trending sub-
grabens Figure (5) which are separated by intra-graben terraces (Patillo and Nicholls,
1990).
The Early to Middle Jurassic extensional event resulted in widespread, small
scale faulting and the collapse of Triassic anticlines. Extensional faulting was
concentrated in the northeastern portion of the Caswell Sub-basin and along the outer
margin of the Prudhoe Terrace (Struckmeyer et al, 1998). This event was also largely
instrumental in defining the elements of the potential Jurassic and Triassic petroleum
systems in the Caswell Sub-basin (Blevin et al, 1998). During this cycle of basin
development up to 1.5 km of section was deposited in the central Caswell Sub-basin.
The rifting event in the Middle to Late Jurassic has caused multiple three ways
fault dependent structures in the area of the Poseidon 3D. The Poseidon 1 well proved
that this play type works within the Poseidon 3D area. The area has undergone complex
multi-staged faulting which has influenced the presence of structures and also the facies
distribution. Play types within this interval are the pre-rift fluvial deltaics, synrift
shallow marine sandstones and post rift marine deep water and barrier fringing
sandstones. Trap styles are predominantly structural but potential does exist for

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stratigraphic traps on the flanks of existing structures and alluvial/submarine fan
deposition on the hanging wall of major horsts.
The rifting was associated with volcanism which may degrade the reservoir
quality and occupy accommodation space preventing the deposition of sandstones.
Figure (4) Major structural elements of the Timor Sea.. (after Pattillo and Nicholls. 1990).
Figure (5) Structural elements of the Vulcan Graben (after Pattillo and Nicholls. 1990). Structurally
high areas are shaded.

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2.4 Tectonic Evolution
The Browse Basin developed during six major tectonic phases:
Struckmeyer et al (1998) divided the basin development into six main phases.
These phases represent a pattern of extension, thermal subsidence and inversion which
have been repeated twice during the evolution of the basin (Blevin et al, 1998).
• Late Carboniferous to Early Permian extension (Figure f)
• Late Permian to Triassic thermal subsidence
• Late Triassic to Early Jurassic inversion
• Early to Middle Jurassic extension
• Late Jurassic to Cenozoic thermal subsidence
• Middle to late Miocene inversion
Figure (6) tectonic of Timor Sea

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Summary of the major tectonic events and the related structure feature of the
Browse Basin is represented in Table (1)
`

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Chapter 3
DATA DESCRIPTION and 3D SEISMIC
INTERPRETATION
3.1 Introduction
The Poseidon 3D Marine Surface Seismic Survey (Poseidon 3D) was acquired
during the period October 2009 to March 2010 within Browse Basin exploration
permits WA-315-P and WA-398-P, operated by ConocoPhillips (Browse Basin) Pty
Ltd (ConocoPhillips). The survey area is located approximately 350 km offshore north
of Broome in Western Australia.
In our interpretation we use pre-stack Data 3Cubes - near, mid & far stack – with
CBVS format, wells Data such (Density & Delta T Compressional) logs & VSP segy
Data.
3.2 Data Acquisition
3.2.1 Data Acquisition Parameters
The following table (Table 3) lists the parameters used in the acquisition of the
Poseidon 3D survey:
Country of Survey Australia
Area of Survey Browse Basin
Block/Tenement WA-315-P and WA-398-P
Survey Name Poseidon 3D Marine
Data Type Marine 3D
Volume 370 Sailed Lines covering 2829km 2
(Sequence 001 – 370, see section 7.1 for
full list of lines processed)
Acquisition Contractor CGGVeritas
Acquisition Vessel Geowave Voyager
Acquisition record length 7000ms
Acquisition Sample Interval 2ms
Acquisition Direction 130°/310°

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Acquisition Filter Applied 3Hz, 6dB/Oct – 200Hz, 370 dB/Oct
Source Separation 37.5m
Shot Interval 18.75m(flip –to- flop)
Source Depth 6m
Streamer Separation 75m
Streamer Length 6000m
No. Streamers 10
Channel Interval 12.5m
No. Channels 480
Streamer Depth 7m
2D Inline Near Offset 160m
Crossline Interval 12.5m
Inline Interval 18.75m
3.3 Data Processing
3.3.1 Processing Parameters
The following table (Table 4) lists the parameters used in the processing of Poseidon
3D:
Processing Record Length 7000ms
Processing Sample Interval 4ms
Datum WGS84
Grid Size 6.25 x 18.75m to 12.5 x 18.75m after
trace drop
The Poseidon 3D data was processed by CGG Veritas Pty Ltd in Perth, WA,
between March 2010 and September 2010. The processing sequence is summarized
below. A more detailed account of the processing can be found in the “Seismic Data

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Processing Report, Poseidon and BKG06b Marine 3D”, prepared by CGG Veritas Pty
Ltd, a copy of which was previously submitted to the DMP.
1. Navigation reformat
2. Seismic data reformat to internal CGG Veritas format a. 50ms SEG-D Delay b. High
Cut Anti-Alias (AA) filter prior to Resampling: 100Hz, 110dB/Oct c. Resample from
2ms to 4ms d. Cut Record Length to 7000ms e. De-bias and 3Hz, 18dB/Octave
Butterworth low cut filter f. Navigation and Seismic Data merge g. Flag observer’s
reports edits
3. Gun and Cable Static correction using real depths
4. Apply deterministic Zero phasing filter on 0.5 m cable depth increments
5. Apply Tidal Statics Correction
6. Reverse polarity to make trough an increase in impedance
7. Cascaded Swell Noise Attenuation (SNA)
a. Sort to back-to-back Shot Points (SP)
b. Two passes of SNA, splitting into separate frequency bands
8. Apply Shot point and Channel Edits
9. Linear Noise Attenuation
a. K-notch anti-alias filter with NMO wrap-around
b. Extrapolation of SPs in f x-y domain
c. Extend record length to 12000ms
d. Forward Tau-P transform (1200 P traces)
e. Tau-P mute for linear noise attenuation
f. Reverse Tau-P transform
10. Apply Tidal Statics Correction (Poseidon Only)
11. Linear Radon transform for residual linear noise attenuation

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12. Trace drop to go from 6.25m Common Mid-Point (CMP) spacing to 12.5m spacing
(BKG06B-3D Only)
13. 3D Surface Related Multiple Elimination (SRME)
a. modelling
b. Subtraction in the Shot point domain
14. Second order deconvolution in Tau-P domain
a. Target window: 3800 – 5800ms
15. Shot-to-shot amplitude correction
a. Filter Length: 5 shot points
16. Trace drop to go from 6.25m Common Mid-Point (CMP) spacing to 12.5m shot
amplitude correction
spacing (Poseidon Only)
17. Normal Moveout (NMO) correction using manually picked stacking velocity field
(1 x 1km) (Poseidon Only)
18. High Resolution Radon De-multiple on NMO corrected gathers:
a. High Resolution Parabolic Radon in 2D CMP domain (DTMIN–2000ms,
DTMAX 1200ms, DTCUT 300ms, DDT 20ms, start time 1.7* water-bottom with
300ms taper)
19. SEGY Output of 2D CMP Gathers
a. Removal of NMO correction
b. Removal of initial amplitude recovery
20. Sort to Offset Volumes
a. Output of 80 75m offset volumes (160-234m….6085-6159m)
b. First 3 offset volumes purposefully over-populated (1-422m, 235-434m, 310-
446m)
21. Automatic Bi-spectral Pre-Stack Time Migration (PSTM) velocity analysis on a 25
x 250m interval
a. PSTM of target velocity in lines
b. Automatic bi-spectral velocity picking

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c. Smoothing of raw picks for PSTM algorithm
d. Output of PSTM VRMS and ETA fields on a 500 x 500m grid
22. 3D Data regularization
a. Regularization of the dataset along two directions using Fourier Reconstruction
23. Diffracted multiple attenuation
a. Start time 4000ms and 1000ms taper
24. Frequency Dependent Offset Noise Attenuation
a. Removal of initial amplitude recovery
b. Spherical Divergence correction (V2/T) using PSTM VRMS field
c. Phase Only Q Compensation with Q=135
25. Full Kirchhoff PSTM a. Dip Limit: 60˚ b. 4km Half Aperture
26. Residual velocity analysis parameters on a 12.5 x 18.75m grid
a. Offline Residual Radon de-multiple, with DTCUT 240 ms
b. Automatic Bi-spectral velocity picking
c. Removal of any erroneous picks and a small smoothing operator
d. Output of final RMO VRMS and ETA fields on a 12.5 x 18.75m grid
27. Application of 12.5 x 18.75m RMO VRMS and ETA fields
28. SEGY output of Raw PSTM Bin Gathers
a. Removal of final RNMO velocity and ETA fields
29. Residual Hi-Resolution RADON de-multiple
a. Time Variant High Resolution Parabolic Radon in the CMP domain
i. DTMIN-1000ms, DTMAX2000, DTCUT160ms, DDT 20ms, start time
1.9 * water-bottom with 300ms taper
ii. DTMIN-1000ms, DTMAX2000ms, DTCUT100ms, DDT 20ms, start time
2.6 seconds with a 400 ms taper.
30. SEGY output of Final PSTM Bin Gathers

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31. Final Angle Stacks
a. Full Stack = 6 - 42˚
b. Near Stack = 6 - 18˚
c. Mid Stack = 18 - 30˚ d. Far Stack = 30 - 42˚
32. SEGY output of Raw AVA Stacks
33. Post Stack processing
a. Amplitude only Q Compensation
b. Time Variant Scaling
c. Diffracted Multiple Attenuation
d. Random Noise Attenuation
34. SEGY output of Final AVA Stacks
35. AVO Product generation
a. Gradient Stack
b. Product Stack
c. Lambda-Rho Stack
d. Fluid Factor Stack e. Intercept Stack
36. SEGY output of AVO Attribute Products.
3.4 Software
seismic data is used in this study with CBVS format. So, opendtect software is
used in the interpretation. Due to its ability to import this type of format.
3.5 Workflow
At first, we start a new project in the software by adding the survey parameters,
as shown below Figure (7).

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Figure (7) Survey parameters
3.5.1 Loading the Data: we import our cubes in the software as shown below in
figure (8)
Figure (8) Import the Seismic Data
Then we import wells & VSP Data to create seismic to well tie, by using the
Density log & Delta T Compressional log to Create a synthetic seismic trace using
Wavelet Extraction option in the software with following parameters figure (9).
Figure (9) Wavelet extraction parameters

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Then we tie the seismic and well data figure (10)
Figure (10) synthetic seismogram
3.6 picking
Figure (11) Picking of jamieson Fm cross line
3000 (near-stack)
Figure (12) Picking of jamieson Fm in line
2400 (near-stack)
3000 (mid-stack)
figure (14) Picking of jamieson Fm in line 2400
(mid-stack)

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3000 (far-stack)
Figure (16) Picking of jamieson Fm in line
2400 (far-stack)
Due to the similarity of Picking at the three cubes and high S/N ratio in the
near stack cube, we pick the reservoir formation -plover Fm- only at near stack cube,
by using the markers at wells.
Figure (17) well marker
Figure (18) plover Fm
Many Attribute helped us in Picking our formation, such as in chapter (4), after
picking we have (TWT map and surface map) for top Plover Fm.

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Figure (19) TWT map for top plover Fm
Figure (20) surface map for top plover Fm,
with Amplitude Variance attribute
Figure (21) surface map for top plover Fm,
with Energy attribute

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After that we try to know the frequency range of the Data, by Display the
Amplitude Spectrum of the Data.
Figure (22) Amplitude Spectrum of the Data
So, the frequency value is between (20:60) HZ.

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CHAPTER 4
SEISMIC ATTRIBUTE
4.1 Introduction
Seismic attribute is any measure of seismic data that helps us better visualize
or quantify features of interpretation interest.
The Oxford Dictionary defines an attribute as, "A quality ascribed to any person
or thing " We have extended this definition to:" seismic Attributes are all the information
obtained from seismic data, either by direct measurements or by logical or Experience
based reasoning "Thus, the computation and the use of attributes actually goes back to
the origins of seismic exploration methods.
Why do we generate Seismic Attributes?
- To Enhance structural and stratigraphic features
- for the interpreter on seismic sections.
- Locate mis-interpretation.
- Get information on lithology, facies or fluid content.
- Reservoir characterization
4.2 Classifications of Seismic Attributes
Taner et al (1994) divide attributes into two general categories, 'geometrical' and
'physical'. The objective of geometrical attributes is to enhance the visibility of the
geometrical characteristics of seismic data: they include dip, azimuth, and continuity.
Physical attributes have to do with the physical parameters of the subsurface and so relate
to lithology. These include amplitude, phase, and frequency. The classification may be
further divided into post-stack and pre-stack attributes.
Brown (1996, 2004) classified attributes using a tree structure comprising time,
amplitude, frequency and attenuation as the main branches, which further branch out
into post-stack and pre-stack categories. Time attributes provide information on structure
while amplitude attributes provide information on stratigraphy and reservoir.

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Classificationofattributetypes.Attributescanbepoint-basedalongagiventimesliceorhorizon,ortheycanbebasedonawindow
thatisconstantintime,timeassociatedwithagivenhorizon,ortimesassociatedwithtwohorizons(afterBrown).

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4.3 Attribute workflow
The seismic attributes that have been generated and analyzed, as well as their
implications, have been provided below. Each attribute has been utilized in the creation
of time-slices/section through an area interest.
4.4 Instantaneous Attribute (Trace Envelope)
Instantaneous attributes are computed sample by sample and represent
instantaneous variations of various parameters. Instantaneous values of attributes such
as trace envelope, its derivatives, frequency and phase may be determined from complex
traces.
It can be used as an effective discriminator for the following characteristics:
• Mainly represents the acoustic impedance contrast, hence reflectivity,
• Bright spots, possible gas accumulation,
• Sequence boundaries,
• Thin-bed tuning effects,
• Major changes in depositional environment,
• Spatial correlation to porosity and other lithologic variations,
• Indicates the group, rather than phase component of the seismic wave propagation.
Figure (23) complex seismic trace

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complex seismic trace consisting of a real part x(t), which is the actual seismic
trace, and an imaginary part y(t), which is a mathematical function calculated from the
real part by a Hilbert transform. When the real and imaginary parts are added in a vector
sense, the result is a helical spiral centered on the seismic time axis (t). This helical trace
is the complex seismic trace.
4.4.1 Instantaneous amplitude
a(t) = [x2
(t) + y2
(t)]1/2
➢ Amplitude 1st derivative: Time derivative of the instantaneous amplitude i.e time rate
of change of the envelope. It shows the variation of the energy of the reflected events. It
is used to detect sharp interfaces and discontinuities.
➢ Amplitude 2nd derivative: Second derivative of the envelope. It provides a measure of
the sharpness of amplitude peak. It can be used to identify all reflecting interfaces within
the seismic bandwidth.
Figure (24) Instantaneous amplitude attribute at 3300 that shows the channel
Figure (25) Instantaneous amplitude attribute at 3400 that shows the channel

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4.4.2 Instantaneous Phase
Calculates the instantaneous phase at the sample location, it emphasizes spatial
continuity/discontinuity of reflections by providing a way for weak and strong events to
appear with equal strength, it relates to the phase component of wave-propagation, it is
also used to compute the phase velocity.
This attribute is of central importance since it describes the location of events in the
seismic trace and leads to the computation of other instantaneous quantities, the
instantaneous phase makes strong events clearer and is effective at highlighting
discontinuities of reflectors, faults, pinch-outs, angularities and bed interfaces.
➢ Cosine phase: Cosine of the instantaneous phase, also called normalized amplitude. It
has the same uses as instantaneous phase with one additional benefit: It is continually
smooth. By providing the +/-180-degree discontinuity that occurs with instantaneous
phase, the cosine of instantaneous phase can be further processed (e.g, filtered and
stacked) using conventional seismic processing tools. Amplitude peaks and troughs
retain their position, but with strong and weak events now exhibiting equal strength.
➢ Envelope weighted phase: Instantaneous phase, weighted by the envelope over the
given time window.
➢ Rotate Phase: Phase output is rotated through a user-specified angle.
Figure (26) Instantaneous phase attribute
helping at tracking the reflector crossline
2490
Figure (27) Instantaneous phase attribute
helping at tracking the reflector crossline 2400

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4.5 Volume Attribute
4.5.1 Amplitude Attribute
The theoretical background for seismic amplitude interpretation was already
established at the beginning of last century. In Knott (1899) and Zoeppritz (1919)
researches, the seismic amplitude dependence on seismic velocity and density in the two
layers medium were analyzed. Based on these works, the equations were developed
describing amplitude changes as functions of P and S wave velocities, density and angle
of incidence of seismic arrival on the reflector.
Reflection coefficients of seismic amplitudes are calculated from these properties.
Accordingly, seismic amplitude analysis should provide more useful subsurface data,
particularly in already discovered oil and gas accumulations. The change of attribute
values is primarily functionally connected with geology and geological changes.
In this project we focus on some amplitude attributes applied on our data as follows:
4.5.1.1 RMS Attribute
The Root Mean Square (RMS), or quadratic mean, is a popular statistical measure
of the magnitude of variation over a dataset. RMS amplitude provides a scaled estimate
of the trace envelope. It is computed in a sliding tapered window of N samples as the
square root of the sum of all the trace values x squared where w and n are the window
values as presented in the following Equation
The RMS proves particularly useful when values run through the positive and
negative domain like in sinusoids or seismic traces.

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The RMS attribute thus emphasizes the variations in acoustic impedance over a
selected sample interval. Generally, the higher the acoustic impedance variation of
stacked lithologies (with bed thicknesses above the seismic resolution) the higher the
RMS values will be.
For example, a high RMS in a channel results from either a high acoustic
impedance contrast of channel fill with the surrounding lithology or acoustic impedance
contrasts within the infill. (Petroleum Geology Forums).
Figure (28) RMS attribute at 3300 that shows the channel
Figure (29) RMS attribute at 3400 that shows the channel
4.5.1.2 Energy attribute
Energy Response attribute that returns the energy of a trace segment. This attribute
calculates the squared sum of the sample values in the specified time-gate divided by the

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number of samples in the gate. The Energy is a measure of reflectivity in the
specified time-gate. The higher the Energy, the higher the Amplitude.
This attribute enhances, among others, lateral variations within seismic events and
is, therefore, useful for seismic object detection (e.g. chimney detection). The response
energy also characterizes acoustic rock properties and bed thickness, the output of this
attribute is Energy, Sqrt (Energy) and Ln(Energy).
Figure (30) Energy attribute at 3300 that shows the channel
Figure (31) Energy attribute at 3400 that shows the channel
4.5.2 Similarity attribute
Similarity is a form of "coherency" that expresses how much two or more
trace segments look alike. A similarity of 1 means the trace segments are completely

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identical in waveform and amplitude. A similarity of 0 means they are completely dis-
similar, Coherency attribute is a measure of lateral changes in acoustic impedance
caused by variations in structure -faults as shown in figure (27)-, stratigraphy, lithology,
porosity, and fluid content. (Opendetect manual). Areas of traces that change with a fault
or other geological phenomena have lower coherency in contrast with the adjacent traces
(Gazar and Javaherian, 2009).
Figure (32) Coherence time Slice at 3400 that shows the channel
4.5.3 Absorption Quality Factor
In the gas hydrate stability zone, the velocity is increased slightly by the presence
of gas hydrate in pore space of sediments, which in the pure state has twice the velocity
of typical deep-sea sediments (Max et al. 2006). This effect can be because of that gas
hydrate is a solid as opposed to brine or gas. By filling the pore space, gas hydrate acts
to reduce the porosity available to the pore fluid and increase the elastic moduli of the
solid frame. Despite to increasing the velocity, more recent observations show that the
attenuation of elastic waves grows with increasing gas hydrate concentration (Dvorkin
and Uden, 2004). We use absorption quality factor for analyzing the attenuation effect
of gas hydrate in host sediments. High attenuation occurs where gas hydrate is present

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Figure (23). The BSR is an indicator of the phase boundary between hydrate bearing and
free gas-bearing sediments. Free gases commonly are trapped and accumulated just
beneath the BSR.
Figure (33) Application of absorption quality factor for identification of high
attenuation in gas hydrate bearing zone. This figure is the result of applying absorption
quality factor attribute to cross line 2400
4.5.4 Spectral Decomposition
Spectral Decomposition Frequency attribute that returns the amplitude spectrum
(FFT) or wavelet coefficients (CWT), Spectral Decomposition unravels the seismic
signal into its constituent frequencies, which allows the user to see phase and amplitude
tuned to specific wavelengths. The amplitude component excels at quantifying thickness
variability and detecting lateral discontinuities while the phase component detects lateral
discontinuities.
By transforming the seismic data into the frequency domain via the DFT, the
amplitude spectra delineate temporal bed thickness variability while the phase spectra
indicate lateral geologic discontinuities. This signal analysis technology has been used
successfully in 3-D seismic data to delineate stratigraphic settings such as channel sands
and structural settings involving complex fault systems (Brown, 2011).

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It is a useful tool for "below resolution" seismic interpretation, sand thickness
estimation, and enhancing channel structures.
Spectral decomposition (SD) is a technique that breaks down seismic signal into
narrow frequency sub-bands. When these sub-bands are examined in a spatial context
(i.e., plan view of a 3-D survey) they reveal interference that is occurring across the
available bandwidth of signal so that it makes use of much lower seismic frequencies to
image the reflective nature of the subsurface rock mass.
Such decomposition provides greater resolution and detection of the layer stacking
heterogeneity, boundaries, and thickness variability than are possible with traditional
broad band seismic attributes. The interference observed in seismic data is controlled by
the interaction of a band-limited signal with local distribution of impedance contrasts.
This interaction causes geologic features to tune in at some frequencies and tune-out at
other frequencies.
Finding frequencies at which the geologic features standout (i.e., either tune-in or
tune-out) from the background amplitude is the key to the successful application of
spectral decomposition (Brown, 2011).
Input Parameters
We can choose between two types of transform:
➢ FFT the Fast Fourier Transform. The FFT requires a short window (time-gate) and a
step-size between the analyzed frequencies. This step can be interpreted as the frequency
resolution.
➢ CWT the Continuous Wavelet Transform. The CWT requires a wavelet type and
When choosing the CWT, you can set the wavelet type:
• Morlet
• Gaussian
• Mexican Hat
AS we hint that the frequency range of this Data is (20:60) HZ, we use that range at slice
3300 to attend our Dominant frequency.

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Figure (34) Spectral Decomposition 20
attribute at slice 3300
Figure (38) Spectral Decomposition 60 attribute at slice 3300

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After compare between different SD at slice 3300 we conclude that the dominant
frequencies are (30 & 40) which show best details. So, we apply this frequency range at
different slices to follow our feature, as shown below

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By following the feature, we note that the feature appears clearly at slices 3300&
3400, So we apply the Dominant frequencies at that slices at the other two cubes – mid
& far -.
Figure (45) Spectral Decomposition 30 attribute at slice 3300 (mid stack)

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Figure (49) Spectral Decomposition 30 attribute at slice 3300 (far stack)

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CHAPTER 5
SEDIMENTARY ENVIRONMENT AND
ATTRIBUTE CROSS-PLOT
5.1 Sedimentary Environments
A sedimentary environment is an area of the earth's surface where sediment is
deposited. It can be distinguished from other areas on the basis of its physical,
chemical, and biological characteristics.
5.1.1 Meandering Streams
Have a single channel with a sinuous pattern and a broad floodplain. It’s the
most common pattern on floodplains. A meander is produced by a stream or river as
it erodes the sediments comprising an outer, concave bank (cut bank) and deposits this
and other sediment downstream on an inner, convex bank which is typically a point
bar which is composed of cross-bedded sand.
As the channel migrates, parts of it may become abandoned and left behind as
oxbow lakes which made up of fine-grained sand to silt (lake sediments). The degree
of meandering of the channel of a river, stream, or other watercourse is measured by
its sinuosity. The sinuosity of a watercourse is the ratio of the length of the channel to
the straight line down-valley distance. Streams or rivers with a single channel and
sensuosities of 1.5 or more are defined as meandering streams or rivers.
Figur (53) show the degree of meandering that controlled by the energy of sediments

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This basic elements is considered the key which aid in a successful seismic
interpretation. Attributes analysis clarify the meander and oxbow of the channel as
follows
Fig (54) shows meander and oxbow
Fig (55) polygons drawn to indicate meander and oxbow
Therfore, we focus on the main or major channel to make another interpretation
in try to make a lot of information about that intersted zone .
5.2 CROSS-PLOT
The cross-plot tool creates 2D cross-plots for analyzing relationships between
seismic data. Two types of cross-plots are typically analyzed:
• Seismic attributes vs. seismic attributes
• Seismic attributes vs. well logs.

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The data points are extracted in a given volume or in a region of interest e.g. by
drawing a polygon. The extracted data is displayed in a spread sheet. The spread sheet
is then used to manipulate and plot the data (opendtect manual).
5.2.1 Seismic Attributes vs. Seismic Attributes
As we hint that the Dominant frequencies are (30&40) HZ & found
the highest resolution feature -channel- at time slices 3300 & 3400 msec.
Figure (56) polygon drawn at slice 3300
By plotting Cross-plots between Spectral Decomposition (SD) 30 on– X-axis
and 40 on Y-axis - in the 3cubes, then show the result at polygon.
• At near stack cube
Figure (57) cross-plot between SD 20 & SD 30 (near stack)

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We take a high selection
Figure (58) cross-plot between SD 20 & SD 30 with high selection
And showing that selection on the polygon
Figure (59) display high selection at the polygon.
We take a low selection
Figure (60) cross-plot between SD 20 & SD 30 with low selection

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And showing that selection on the polygon
Figure (61) Display low selection at the polygon.
We showing the two selections together on the polygon
Figure (62) display the two selections at the polygon.
We Interpretation the Different in amplitude is as a result of Different
in thickness or different in saturation.
• A Mid Stack Cube
Figure (63) cross-plot between SD 20 & SD 30 (mid stack)

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Figure (64) cross-plot between SD 20 & SD
30 (mid stack) high selection
30 (mid stack) low selection
• A Far Stack Cube
Figure (67) cross-plot between SD 20 & SD 30 (far stack)

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30 (far stack), with high selection
30 (far stack), with low selection

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Summary and Conclusion
The project is held in The Poseidon block (Poseidon 3D) area is located in
Browse Basin approximately 350 km offshore north of Broome in Western Australia.
The Poseidon 3D Marine Surface Seismic Survey (Poseidon 3D) was acquired during
the period October 2009 to March 2010 within Browse Basin exploration, operated by
ConocoPhillips. The Poseidon 3D covers an area of 2,828km2
sail lines and 21
orthogonal lines in the area adjacent to the Seringapatam reef. The survey was acquired
with sail lines oriented 130° / 310° and consists of 172 primes.
The target of this study is to image gas reservoir channel at late Jurassic to early
cretaceous. Imaging of the Tertiary and Cretaceous sequences has allowed an
improvement understanding of the geology of this area and identified new play types
as showen in Chapter (1, 2).
Chapter 1 describes the available data; that is pre-stack Data 3 Cubes - near, mid
and far stack – with CBVS format, Survey with inline range (983-4419) and cross line
range (504-5556) lines.
In Pre-stack data Cubes there were three drilled Wells in the area in the logs that
measured are: Kronos 1, Poseidon 1, Poseidon 2, Well logs such as: (Density and
Compressional sonic) logs with VSP.
OpendTect Version 6 software is used for interpretation and attribute extraction
to define variables types of seismic attributes in (Chapter 4) and Cross plots in
(Chapter5) to confirm the presence of Gas in this area. We used in our project different
types of attributes which helped us to reinforce our interpretation of this area which
contained Gas. The important one is: spectral decomposition which showed the channel
of gas with dominant frequency 30 Hz and 40 Hz which high resolution. Attributes
Cross-Plot is also useful for discrimination between saturation and lithology.

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