DEPOSITIONAL SEQUENCE OF THE WITHNELL FORMATION, DAMPIER SUB-BASIN

1995 ◽  
Vol 35 (1) ◽  
pp. 296
Author(s):  
J. S. Rasidi
Keyword(s):  
Late Cretaceous ◽  
Seismic Data ◽  
Depositional Environment ◽  
Thickness Distribution ◽  
Well Logs ◽  
Hydrocarbon Potential ◽  
Depositional Sequence ◽  
Well Data ◽  
Water Depths ◽  
Reservoir Facies

The Late Cretaceous Withnell Formation has attracted very little exploration attention because of the perception that it has poor hydrocarbon potential. This unfavourable perception has arisen from the fact that very little is known about its depositional environment and lithofacies and therefore, its petroleum prospectivity.A sudden fall of relative sea level occurred at the end of the Santonian, and was followed by the deposition of the siliciclastic Withnell Formation. The occurrence of a number of channels and canyons at the base of the formation, over the old shelf and slope on the southern margin of the sub-basin, supports the hypothesis that the Withnell Formation began as a lowstand systems tract. The thickness distribution of the formation and the progradation direction of seismic packages suggest a southeasterly provenance. Correlation of seismic data and well logs, and rock descriptions demonstrate the presence of units deposited during increasing water depths and subsequent highstand systems tract.Much more information, both seismic and well data, is required to establish the facies distribution within the Withnell Formation which may contain sand-prone lowstand facies such as basinfloor or slope fans. The presence of such reservoir facies would enhance the petroleum prospectivity of the Withnell Formation.

DEPOSITIONAL SEQUENCE MODEL FOR THE POST-BARROW GROUP NEOCOMIAN SUCCESSION, BARROW AND EXMOUTH SUB-BASINS, WESTERN AUSTRALIA

1993 ◽  
Vol 33 (1) ◽  
pp. 151
Author(s):  
Peter A. Arditto
Keyword(s):  
Seismic Data ◽  
Sensu Stricto ◽  
Well Log ◽  
Depositional Sequence ◽  
Sequence Stratigraphic ◽  
Exmouth Plateau ◽  
Stratigraphic Analysis ◽  
Cast Doubt ◽  
Well Data ◽  
Stratigraphic Nomenclature

Structural traps at the top 'Barrow Group' are the most successful oil exploration targets in the Barrow/Exmouth Sub-basins. However, a reinterpretation of recent exploration activities undertaken by BHP Petroleum Pty Ltd, combined with regional investigations on the Exmouth Plateau, has cast doubt on the validity of accepted stratigraphic nomenclature for the Neocomian succession. A more geologically rational subdivision of the upper part of the Neocomian succession into two discrete sequence stratigraphic units is proposed.Key seismic data from the Exmouth Plateau, tied into wells with good age control, have enabled precise recognition of the Intra-Valanginian Unconformity within the currently-defined Barrow Group. The Barrow Group (sensu stricto) is redefined in this paper as the Barrow Megasequence (restricted to a Berriasian age succession), comprising a rapid progradational phase, which was abruptly terminated by the Intra-Valanginian event.Local erosion of the Barrow Megasequence along the Novara Arch through an Early Valanginian uplift, during the ensuing Valanginian regional transgression, contributed to the development of a parasitic clastic wedge, previously referred to as the Upper Barrow Delta on the Exmouth Plateau and here named the Zeepaard Sequence, with a nominated section in Zeepaard-1. The Zeepaard sequence is terminated by a Top Valanginian unconformity, upon which a final deltaic clastic pulse was deposited as the Birdrong Sequence. Each successive clastic wedge had a more limited development, with the basinward progradation terminating well short of the underlying stratigraphic unit. The Birdrong Sequence was terminated by an Intra-Hauterivian unconformity upon which the highly glauconitic, thin, Mardie Greensand Member of the Muderong Sequence was developed.The Zeepaard Sequence and overlying Birdrong Sequence can be characterised using both seismic and well log character. Well data in particular has enabled detailed stratigraphic mapping of the Birdrong Sequence which is thin and generally not seismically resolvable across the Barrow Sub-basin. This paper presents a detailed sequence stratigraphic analysis of the Birdrong Sequence using well log data.

Integrating Wireline Logs and Seismic Data to Analyse The Facies snd Paleogeography of Tanjung Formation, Barito Basin, South Kalimantan

2020 ◽  
Author(s):  
E. A. Rosa
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Depositional Environment ◽  
Well Logs ◽  
Facies Distribution ◽  
Sequence Stratigraphic ◽  
Core Data ◽  
Wireline Logs ◽  
Depositional Models

The study area is physiographically part of the Barito Basin, South Kalimantan (Van Bemmelen, 1949). 2D seismic data along with well logs from three wells, biostratigraphy data from two wells, and core data are utilized to do an integrated sequence stratigraphy. Petrography data from the equivalent formation at well-X from the study area is also used to support the evaluation. This study was to determine lithology facies and depositional environment based on several key maps: Sand Shale Ratio (SSR), Isopach, and Paleogeographic Maps. After that, seismically-supported sequence stratigraphy was applied to vertically and laterally subdivide the facies distribution and paleogeography into two depositional models based on the following key sequence-stratigraphic markers: (1) Sequence Boundary (SB)-1 to SB-2 that show regressive succession, and (2) SB-2 to Top Tanjung Formation that reflects transgressive phase.

THE CEDUNA SUB-BASIN—A SNAPSHOT OF PROSPECTIVITY

2001 ◽  
Vol 41 (1) ◽  
pp. 321 ◽  
Author(s):  
R. Somerville
Keyword(s):  
Late Cretaceous ◽  
Seismic Data ◽  
Charge System ◽  
The North ◽  
Exploration Risk ◽  
Exploration Drilling ◽  
Marine Seismic ◽  
Hydrocarbon Charge ◽  
Great Australian Bight ◽  
Water Depths

The Ceduna Sub-basin comprises one of the major untested potential petroleum provinces in Australia. It is located in the Great Australian Bight, forming part of the Bight Basin. Water depths range from 100 m in the north to over 4,000 m in the south. Although over 100,000 line km of 2D marine seismic data have been acquired in the Great Australian Bight, only 20,600 line km of 2D marine seismic data of variable vintage and quality have been acquired in the Ceduna Sub-basin. Only one exploration well, Potoroo–1, has been drilled within the Ceduna Sub-basin. The Potoroo–1 well is located on the extreme landward edge of the depocentre which is dominated by the Late Cretaceous Ceduna Delta. Consequently, the hydrocarbon potential of the basin is effectively untested.The most promising play types within the Ceduna Subbasin are dip and fault-dip closures associated with listric faults within the Late Cretaceous (Santonian- Maastrichtian) deltaic sequence and accentuated by slight Late Cretaceous/Tertiary compression. Fault-dip closures are also recognised within the Santonian section. A channel sub-crop play within the Santonian is also potentially viable.Hydrocarbon charge is perceived to be the most significant exploration risk. Although asphaltite strandings have been reported, the hydrocarbon charge system is unproven. Future exploration in the Great Australian Bight will need to address:harsh climatic/meteorological and oceanographic conditions in the Southern Ocean and short seasonal windows;extreme sea floor relief and viability of safe exploration drilling in water depths over 1,500 m; andoperating in a responsible and environmentally sensitive way in proximity to the Benthic Protection Zone.

THE GEOLOGY AND HYDROCARBON POTENTIAL OF THE NORTH-WESTERN OFFICER BASIN

1985 ◽  
Vol 25 (1) ◽  
pp. 52
Author(s):  
Bruce J. Phillips ◽  
Alan W. James ◽  
Graeme M. Philip
Keyword(s):  
Seismic Data ◽  
Source Rocks ◽  
Petroleum Exploration ◽  
Hydrocarbon Potential ◽  
Aeromagnetic Data ◽  
The North ◽  
Carbonate Sequence ◽  
Well Data ◽  
Regional Gravity ◽  
North Western

Recent petroleum exploration in EP 186 and EP 187 in the north-western Officer Basin has greatly increased knowledge of the regional stratigraphy, structure and petroleum prospectivity of the region. This exploration programme has involved the drilling of two deep stratigraphic wells (Dragoon 1 and Hussar 1) and the acquisition of 1438 km of seismic data. Integration of regional gravity and aeromagnetic data with regional seismic and well data reveals that the Gibson Sub-basin primarily contains a Proterozoic evaporitic sequence. In contrast, the Herbert Sub-basin contains a Late Proterozoic to Cambrian clastic and carbonate sequence above the evaporites. This sequence, which was intersected in Hussar 1, is identified as the primary exploration target in the Western Officer Basin. The sequence contains excellent reservoir and seal rocks in association with mature source rocks. Major structuring of the basin has also been caused by compressive movements associated with the Alice Springs Orogeny. The northwestern Officer Basin thus has all of the ingredients for the discovery of commercial hydrocarbons.

scholarly journals Seismic Sequence Stratigraphic Sub-Division Using Well Logs and Seismic Data of Taranaki Basin, New Zealand

2021 ◽  
Vol 11 (3) ◽  
pp. 1226
Author(s):  
Abd Al-Salam Al-Masgari ◽  
Mohamed Elsaadany ◽  
Abdul Halim Abdul Latiff ◽  
Maman Hermana ◽  
Umar Bin Hamzah ◽  
...  
Keyword(s):  
Sequence Stratigraphy ◽  
Seismic Data ◽  
Depositional Environment ◽  
Seismic Facies ◽  
Well Logs ◽  
Seismic Section ◽  
Sequence Stratigraphic ◽  
New Perspective ◽  
Potential Traps ◽  
Bottom To Top

This study focuses on the sequence stratigraphy and the dominated seismic facies in the Central Taranaki basin. Four regional seismic sequences namely SEQ4 to SEQ1 from bottom to top and four boundaries representing unconformities namely H4 to H1 from bottom to top have been traced based on the reflection terminations. This was validated using well logs information. An onlapping feature on the seismic section indicates a new perspective surface separated between the upper and lower Giant formation, which indicates a period of seawater encroachment. This study focused extensively on deposition units from SEQ4 to SEQ1. The seismic facies, isochron map, and depositional environment were determined, and the system tract was established. This study was also able to propose a new perspective sequence stratigraphy framework of the basin and probable hydrocarbon accumulations and from the general geological aspect, SA-Middle Giant Formation (SEQ3) could act as potential traps.

Role of Well Logs and Seismic Data Conditioning in Improving the Imaging of Complex Reservoirs from Abu Dhabi

2021 ◽  
Author(s):  
Khalid Obaid ◽  
Muhammad Aamir ◽  
Tarek Yehia Nafie ◽  
Omar Aly ◽  
Widad Krissat ◽  
...  
Keyword(s):  
Seismic Data ◽  
Drilling Fluid ◽  
Rock Physics ◽  
Seismic Inversion ◽  
Well Logs ◽  
Abu Dhabi ◽  
Residual Noise ◽  
Data Conditioning ◽  
Well Data

Abstract Rock physics/seismic inversion is a powerful tool that deliver information about intra-wells rocks elastic attributes and reservoir properties such as porosity, saturation and rock lithology classification. In principle, inversion is like an engine that should be fueled by proper input quality of both seismic and well data. As for the well data, sonic and density logs measure the rock properties a few inches from the borehole. Reliability of sonic transit-time and bulk density logs can be affected by large and rapid variation in the diameter and shape of the borehole cross-section, as well as the process of drilling fluid invasion. The basic assumption for acoustic well logs editing and conditioning is to use other recorded logs (not affected by bad-hole conditions) in a Multivariate-Regression Algorithm. In addition, Fluid Substitution was implemented to correct for the mud invasion that affects the acoustic and elastic properties based on the PVT data for fluid properties computation. The logs were then quality checked by multiple cross-plotting comparisons to the standard Rock-physics trends templates. As for seismic data, there are several factors affecting the quality of surface seismic data including the presence of residual noise and multiples contamination that caused improper amplitude balancing. Optimizing the seismic data processing for the inversion studies require reviewing and conditioning the seismic gathers and pre-stack volumes, guided by a deterministic seismic-to-well tie analysis after every major stage of the processing sequence. The applied processes are mainly consisting of Curvelet domain noise attenuation to attenuate residual noise. This was followed by high resolution Radon anti-multiple to attenuate residual surface multiples and Extended interbed multiple prediction to attenuate interbed multiples. In addition, Offset dependent amplitude and spectral balancing were applied to maintain the seismic amplitudes fidelity. This paper will illustrate a case from Abu Dhabi where data conditioning results improved the Hydrocarbon saturated carbonates vs brine saturated carbonate and the lithology predictions, leading to optimizing field development plans and drilling operations.

Bight Basin acreage release—new exploration opportunities in a deep water frontier

2009 ◽  
Vol 49 (1) ◽  
pp. 491
Author(s):  
Jennifer Totterdell ◽  
Heike Struckmeyer ◽  
Andrew Stacey
Keyword(s):  
Late Cretaceous ◽  
Seismic Data ◽  
Source Rocks ◽  
High Quality ◽  
Reservoir Rocks ◽  
Potential Source ◽  
Exploration Risk ◽  
Commonwealth Government ◽  
Exploration Drilling ◽  
Water Depths

In 2009, the Commonwealth Government is releasing six large exploration areas in the frontier Bight Basin. The areas lie in the Ceduna Sub-basin, in water depths ranging from 130 to 4,600 m. At present, no permits are held in this part of the basin. Most exploration drilling in the Bight Basin has focussed on the margins of the Ceduna Sub-basin and on the adjacent Duntroon Sub-basin. Gnarlyknots 1A, drilled by Woodside Energy and partners in 2003, is the only well to have attempted to test the thick, prospective Ceduna Sub-basin succession away from the margins of the sub-basin, but did not reach all its target horizons due to weather and ocean conditions. The key to the petroleum prospectivity of the Ceduna Sub-basin is the distribution of the Late Cretaceous marine and deltaic facies. Recent dredging of Late Cenomanian–Turonian organic-rich marine rocks has confirmed the presence of high quality source rocks in the Bight Basin and has significantly reduced exploration risk. These potential source rocks are mature in the central part of the Ceduna Sub-basin and are likely to have generated and expelled hydrocarbons since the Campanian. Excellent reservoir rocks and potential intraformational seals are present in the Late Cretaceous deltaic successions and regional seals could be provided by Late Cretaceous marine shales. Interpretation of seismic data has identified numerous play types in the basin and some structures show amplitude anomalies, providing many exploration targets for explorers.

scholarly journals Main favorable factorscreatee oligocene formation become a petroleum prospect in south-east area, Cuu Long basin

2017 ◽  
Vol 19 (1) ◽  
pp. 169-179
Author(s):  
Huy Nhu Tran ◽  
Xuan Van Tran ◽  
Kha Xuan Nguyen ◽  
Ngoc Ba Thai ◽  
Thanh Quoc Truong ◽  
...  
Keyword(s):  
Seismic Data ◽  
Depositional Environment ◽  
Research Area ◽  
Well Log ◽  
Well Test ◽  
Depositional Facies ◽  
Seismic Line ◽  
Study Results ◽  
Porosity And Permeability ◽  
Well Data

The previous researchs almost demonstrated the reservoir in Lower Oligocene sandstone has complicated distribution, probably low porosity and permeability, no nature flow are seen by wells. Based on recent study results of depositional environment of E Oligocene sedimentary in Cuu Long basin and E sand distribution in blocks 01/10 & 02/10, block 09-2/09, block 09-2/10 and block 16-2 area, the paper determines depositional facies according to petrophysic and geophysic data. From Chrono-stratigraphy priciple, as well as interpretation and intergration of seismic data, well data, well log data, core & sample analysis results, petrophysic data, well test data, the paper forcuses on create correlation lines between wells and seismic line for confirming Oligocene E distribution in Cuu Long basin, buildup the gross mapping for depositional environment in sub-sequence Oligocene E upper and E lower and mapping of seismic attributes for sub-sequence Oligocene E upper and E lower.At last successfully predict the sand distribution in Oligocene E upper and E lower sub-sequence in research area and hence determine the stratigraphic traps in Oligocene formation of South-East area Cuulong basin.

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