A History of Abnormal Pressure Determinations From Seismic Data

1976 ◽  
Author(s):  
Billy W. Aud
Keyword(s):  
Seismic Data ◽  
Abnormal Pressure ◽  
History Of

NEW IDEAS ON THE RIFTING HISTORY AND STRUCTURAL ARCHITECTURE OF THE WESTERN OTWAY BASIN: EVIDENCE FROM THE INTEGRATION OF AEROMAGNETIC, GRAVITY AND SEISMIC DATA

1994 ◽  
Vol 34 (1) ◽  
pp. 529 ◽  
Author(s):  
G.W. O'Brien ◽  
C.V. Reeves ◽  
P.R. Milligan ◽  
M.P. Morse ◽  
E.M. Alexander ◽  
...  
Keyword(s):  
Seismic Data ◽  
Normal Fault ◽  
Magnetic Data ◽  
Data Sets ◽  
Stress Regime ◽  
Petroleum Potential ◽  
History Of ◽  
New Ideas ◽  
Structural Architecture ◽  
Great Australian Bight

The integration of high resolution, image-processed aeromagnetic data with regional geological, magnetic, gravity and seismic data-sets has provided new insights into the structural architecture, rifting history, and petroleum potential of the western onshore and offshore Otway Basin, south-eastern Australia.Three principal structural directions are evident from the magnetic data: NS, NE-ENE and NW-WNW. The structural fabric and regional geological data suggest that the rifting history of the basin may have taken place in two distinct stages, rather than within a simple rift-to-drift framework. The initial stage, from 150 to ~120 Ma, took place within a stress regime dominated by NW-SE extensional transport, similar to that of the basins within the Great Australian Bight to the west. ENE-striking extensional rift segments, such as the Crayfish Platform-Robe Trough and the Torquay Sub-Basin, developed during this period, contemporaneous with the deposition of thick sediments of the Early Cretaceous (Tithonian-Hauterivian) Crayfish Subgroup. In other parts of the basin, NW-striking rift segments, such as the Penola, and perhaps Ardonachie, Troughs onshore, developed within a strongly trans-tensional (left-lateral strike-slip) environment. At ~120 Ma, the regional stress field changed, and the Crayfish Subgroup-aged rift segments were reactivated, with uplift and block faulting extending through to perhaps 117 Ma. Rifting then recommenced at about 117 Ma (contemporaneous with the deposition of the Barremian-Albian Eumeralla Formation), though the extensional transport direction was now oriented NNE-SSW, almost perpendicular to that of the earlier Crayfish Subgroup rift stage. This later rift episode ultimately led to continental breakup at ~96 Ma and produced the 'traditional' normal fault orientations (NW-SE to WNW-ESE) throughout the Otway Basin.

THE HYDROCARBON POTENTIAL OF THE PENOLA TROUGH, OTWAY BASIN

1995 ◽  
Vol 35 (1) ◽  
pp. 358 ◽  
Author(s):  
R. Lovibond ◽  
R.J. Suttill ◽  
J.E. Skinner ◽  
A.N. Aburas
Keyword(s):  
Early Cretaceous ◽  
Seismic Data ◽  
Oil And Gas ◽  
Direct Detection ◽  
Source Rocks ◽  
Well Control ◽  
Potential Reservoir ◽  
Half Graben ◽  
History Of

The Penola Trough is an elongate, Late Jurassic to Early Cretaceous, NW-SE trending half graben filled mainly with synrift sediments of the Crayfish Group. Katnook-1 discovered gas in the basal Eumeralla Formation, but all commercial discoveries have been within the Crayfish Group, particularly the Pretty Hill Formation. Recent improvements in seismic data quality, in conjunction with additional well control, have greatly improved the understanding of the stratigraphy, structure and hydrocarbon prospectivity of the trough. Strati-graphic units within the Pretty Hill Formation are now mappable seismically. The maturity of potential source rocks within these deeper units has been modelled, and the distribution and quality of potential reservoir sands at several levels within the Crayfish Group have been studied using both well and seismic data. Evaluation of the structural history of the trough, the risk of a late carbon dioxide charge to traps, the direct detection of gas using seismic AVO analysis, and the petrophysical ambiguities recorded in wells has resulted in new insights. An important new play has been recognised on the northern flank of the Penola Trough: a gas and oil charge from mature source rocks directly overlying basement into a quartzose sand sequence referred to informally as the Sawpit Sandstone. This play was successfully tested in early 1994 by Wynn-1 which flowed both oil and gas during testing from the Sawpit Sandstone. In mid 1994, Haselgrove-1 discovered commercial quantities of gas in a tilted Pretty Hill Formation fault block adjacent to the Katnook Field. These recent discoveries enhance the prospectivity of the Penola Trough and of the Early Cretaceous sequence in the wider Otway Basin where these sediments are within reach of the drill.

scholarly journals The Study of Seafloor Tin Placer Resources of Quaternary Sediment at Toboali Waters, South Bangka

2017 ◽  
Vol 31 (2) ◽  
Author(s):  
Muhammad Zulfikar ◽  
Noor CD Aryanto
Keyword(s):  
Source Rock ◽  
Seismic Data ◽  
Data Interpretation ◽  
Placer Deposit ◽  
Rock Weathering ◽  
Sediment Thickness ◽  
Quaternary Sediment ◽  
History Of ◽  
Sediment Cover ◽  
Tin Deposit

Bangka Island has primary and secondary tin deposit. However, along the history of tin mining has been done the primary tin deposit domination is less than secondary tin deposit. Secondary tin deposit is formed from Granitic S-type source rock weathering and then transported by gravity. After that, Cassiterite mineral (SnO2) accumulates and forms a placer deposit in the study area. The thickness of sediment cover at Toboali Waters is quite diverse, with a range between 5-20 milliseconds, by knowing the quarter sediment thickness using seismic data interpretation results, is expected to give an idea about tin placer deposit potential in Toboali waters. Based on the Isochron map shows patterns of quaternary sediment thickening to the southwest, south and southeast of Bangka Island.Keywords: Quaternary sediment, placer deposit, isochron map, Toboali WatersPulau Bangka memiliki endapan timah primer dan endapan timah sekunder. Namun, sepanjang sejarah penambangan timah yang telah dilakukan endapan timah primer tidak mendominasi jika dibandingkan dengan endapan timah sekunder. Pembentukan endapan timah sekunder berawal dari pelapukan batuan Granit tipe-S yang kemudian mengalami transportasi akibat adanya gravitasi. Setelah itu, mineral kasiterit (SnO2) terakumulasi dan membentuk endapan plaser di daerah penelitian. Ketebalan sedimen penutup di Perairan Toboali berkisar antara 5-20 milidetik, dengan mengetahui ketebalan sedimen kuarter berdasarkan interpretasi data hasil rekaman seismik diharapkan dapat memberikan gambaran tentang potensi endapan timah placer di Perairan Toboali. Berdasarkan atas peta isokron, memperlihatkan bahwa pola penebalan sedimen kuater ke arah baratdaya, selatan dan tenggara Pulau Bangka.Kata kunci : Sedimen kuarter, endapan placer, peta isokron, Perairan Toboali

scholarly journals Cenozoic post-breakup compressional deformation and exhumation of the southern Australian margin

2011 ◽  
Vol 51 (1) ◽  
pp. 613 ◽  
Author(s):  
Simon Holford ◽  
Richard Hillis ◽  
Ian Duddy ◽  
Paul Green ◽  
Martyn Stoker ◽  
...  
Keyword(s):  
Seismic Data ◽  
Sedimentary Basin ◽  
Stress Fields ◽  
Basin Inversion ◽  
Southern Margin ◽  
Australian Plate ◽  
Southeastern Margin ◽  
Hydrocarbon Fields ◽  
History Of ◽  
Compressional Deformation

We present results from a margin-wide analysis of the history of post-breakup Cenozoic compressional deformation and related exhumation along the passive southern margin of Australia, based on a regional synthesis of seismic, stratigraphic and thermochronological data. The Cenozoic sedimentary record of the southern margin contains regional unconformities of intra-Lutetian and late Miocene–Pliocene age, which coincide with reconfigurations of the boundaries of the Indo-Australian Plate. Seismic data show that post-breakup compressional deformation and sedimentary basin inversion—characterised by reactivation of syn-rift faults and folding of post-rift sediments—is pervasive from the Gulf St Vincent to Gippsland basins, and occurred almost continually since the early- to mid-Eocene. Inversion structures are absent from the Bight Basin, which we interpret to be the result of both the unsuitable orientation of faults for reactivation with respect to post-breakup stress fields, and the colder, stronger lithosphere that underlies that part of the margin. Compressional deformation along the southeastern margin has mainly been accommodated by reactivation of syn-rift faults, resulting in folds with varying ages and amplitudes in the post-rift Cenozoic succession. Many hydrocarbon fields in the Otway and Gippsland basins are located in these folds, the largest of which are often associated with substantial localised exhumation. Our results emphasise the importance of constraining the timing of Cenozoic compression and exhumation in defining hydrocarbon prospectivity of the southern margin.

scholarly journals Depositional History of Paleocene Sediments in the Offshore Canterbury Basin, New Zealand

2021 ◽  
Author(s):  
◽  
Sanjay Paul Samuel
Keyword(s):  
Seismic Data ◽  
The South ◽  
Depositional History ◽  
Reservoir Rocks ◽  
The North ◽  
Late Paleocene ◽  
Shelf Slope ◽  
History Of ◽  
Well Correlation ◽  
First Time

<p>The Paleocene interval within the Canterbury Basin has been relatively understudied with respect to the Neogene and Cretaceous intervals. Within the Paleocene interval is the Tartan Formation and the Charteris Bay Sandstone, which are potential source and reservoir rocks respectively. These two formations have not been previously mapped in the offshore Canterbury Basin and their limits have not been defined. This study utilises a database of nearly 12,000km of 2D seismic data together with data from four open–file wells and sidewall core samples from three wells and newly availiable biostratigraphic information to better constrain the chronostratigraphical interpretation of seismic data. Seismic mapping together with corroboration from well correlation and core lithofacies analysis revealed new insights into the development of the offshore Canterbury Basin through the Paleocene. These include the delineation of the lateral extents and thicknesses of the Tartan Formation and Charteris Bay Sandstone and location of the palaeo shelf–slope break and also the development of a new well correlation panel that incorporates the Tartan Formation for the first time.  This study presents four new paleogeographic maps for the offshore Canterbury Basin that significantly improves our understanding of the development of the basin during the Paleocene. These maps show that during the Earliest Paleocene, the mudstones of the Katiki Formation were being deposited in the south of the study area, with the siltier sediments of the Conway Formation being deposited in the north. The coarser grained Charteris Bay Sandstone was deposited from Early to possibly Middle Paleocene in the northeast. The mudstones of the Moeraki Formation were being deposited in the south at this time. From Middle to Late Paleocene, the mudstones of the Moeraki Formation were deposited in the south and these mudstones onlapped against the Charteris Bay Sandstone which remained as a high in the north. The Tartan Formation was deposited during the Late Paleocene in the central and southern areas of the offshore Canterbury Basin, during a relative fall in sea–level. Deposition had ceased in the north of the study area or erosion possibly removed Late Paleocene sediments from there. During the Latest Paleocene, the mudstones of the Moeraki Formation were deposited over the Tartan Formation in the central and southern parts of the offshore Canterbury Basin with the northern area undergoing erosion, sediment bypass or both.</p>

scholarly journals Depositional History of Paleocene Sediments in the Offshore Canterbury Basin, New Zealand

2021 ◽  
Author(s):  
◽  
Sanjay Paul Samuel
Keyword(s):  
Seismic Data ◽  
The South ◽  
Depositional History ◽  
Reservoir Rocks ◽  
The North ◽  
Late Paleocene ◽  
Shelf Slope ◽  
History Of ◽  
Well Correlation ◽  
First Time

<p>The Paleocene interval within the Canterbury Basin has been relatively understudied with respect to the Neogene and Cretaceous intervals. Within the Paleocene interval is the Tartan Formation and the Charteris Bay Sandstone, which are potential source and reservoir rocks respectively. These two formations have not been previously mapped in the offshore Canterbury Basin and their limits have not been defined. This study utilises a database of nearly 12,000km of 2D seismic data together with data from four open–file wells and sidewall core samples from three wells and newly availiable biostratigraphic information to better constrain the chronostratigraphical interpretation of seismic data. Seismic mapping together with corroboration from well correlation and core lithofacies analysis revealed new insights into the development of the offshore Canterbury Basin through the Paleocene. These include the delineation of the lateral extents and thicknesses of the Tartan Formation and Charteris Bay Sandstone and location of the palaeo shelf–slope break and also the development of a new well correlation panel that incorporates the Tartan Formation for the first time.  This study presents four new paleogeographic maps for the offshore Canterbury Basin that significantly improves our understanding of the development of the basin during the Paleocene. These maps show that during the Earliest Paleocene, the mudstones of the Katiki Formation were being deposited in the south of the study area, with the siltier sediments of the Conway Formation being deposited in the north. The coarser grained Charteris Bay Sandstone was deposited from Early to possibly Middle Paleocene in the northeast. The mudstones of the Moeraki Formation were being deposited in the south at this time. From Middle to Late Paleocene, the mudstones of the Moeraki Formation were deposited in the south and these mudstones onlapped against the Charteris Bay Sandstone which remained as a high in the north. The Tartan Formation was deposited during the Late Paleocene in the central and southern areas of the offshore Canterbury Basin, during a relative fall in sea–level. Deposition had ceased in the north of the study area or erosion possibly removed Late Paleocene sediments from there. During the Latest Paleocene, the mudstones of the Moeraki Formation were deposited over the Tartan Formation in the central and southern parts of the offshore Canterbury Basin with the northern area undergoing erosion, sediment bypass or both.</p>

THE EXPLORATION AND APPRAISAL HISTORY OF THE SKUA FIELD, AC /P2 - TIMOR SEA.

1990 ◽  
Vol 30 (1) ◽  
pp. 197
Author(s):  
M. Osborne
Keyword(s):  
Data Quality ◽  
Seismic Data ◽  
Joint Venture ◽  
Complex Field ◽  
Quality Improvements ◽  
Associated Gas ◽  
Seismic Acquisition ◽  
History Of ◽  
Timor Sea ◽  
Field Geology

The discovery of the Skua Field resulted from an extended and aggressive exploration program with major emphasis placed on gaining continual improvements in seismic data quality. Improved seismic data was principally responsible for the accurate delineation of the Swift and Skua structures which resulted in the drilling of the Skua-2 discovery well in 1985.A positive analysis of the results of Skua-2 (which clipped the fault bounded edge of the field) coupled with extensive new seismic acquisition and further seismic data quality improvements encouraged the AC/P2 Joint Venture to drill the field confirmation well Skua-3, in 1987.The appraisal stage of the Skua field included three further wells and was designed to investigate several specific problem areas: the modest structural size, the volume of a small associated gas cap, the presence of steeply dipping reservoir strata of interbedded sands and shales, and the effect of discrete zones of intense velocity anomaly.A major consideration has been to achieve a balance between exploration expenditure and the need to attain a thorough understanding of the complex field geology to reduce the uncertainties associated with the problem areas.The only potentially viable development option for Skua is to use subsea completions and a floating production facility (FPF). BHP Petroleum's engineering expertise and history of FPF developments at Jabiru and Challis is of great importance to successfully developing this smaller, more complex field.

THE EASTERN OTWAY BASIN WANGERRIP GROUP REVISITED USING AN INTEGRATED SEQUENCE STRATIGRAPHIC METHODOLOGY

1995 ◽  
Vol 35 (1) ◽  
pp. 372 ◽  
Author(s):  
P. A. Arditto
Keyword(s):  
Seismic Data ◽  
Well Log ◽  
Third Order ◽  
Traditional Methods ◽  
Depositional History ◽  
Sequence Stratigraphic ◽  
Reflection Seismic ◽  
Stratigraphic Subdivision ◽  
History Of ◽  
Definition Of

Recent exploration by BHP Petroleum in VIC/ P30 and VIC/P31, within the eastern Otway Basin, has contributed significantly to our understanding of the depositional history of the Paleocene to Eocene siliciclastic Wangerrip Group. The original lithostratigraphic definition of this group was based on outcrop description and subsequently applied to onshore and, more recently, offshore wells significantly basinward of the type sections. This resulted in confusing individual well lithostratigraphies which hampered traditional methods of subsurface correlation.A re-evaluation of the Wangerrip Group stratigraphy is presented based on the integration of outcrop, wireline well log, palynological and reflection seismic data. The Wangerrip Group can be divided into two distinct units based on seismic and well log character. A lower Paleocene succession rests conformably on the underlying Maastrichtian and older Sherbrook Group, and is separated from an overlying Late Paleocene to Eocene succession by a significant regional unconformity. This upper unit displays a highly progradational seismic character and is named here as the Wangerrip Megasequence.Regional seismic and well log correlation diagrams are used to illustrate a subdivision of the Wangerrip Megasequence into eight third-order sequences. This sequence stratigraphic subdivision of the Wangerrip Group is then used to construct a chronostratigraphic chart for the succession within this part of the Otway Basin.

From exploration to production—key trends and differences in the exploration and development of hydrocarbons from Australia's established offshore petroleum provinces

2015 ◽  
Vol 55 (2) ◽  
pp. 492
Author(s):  
Howard Ewan ◽  
Frances Cullen
Keyword(s):  
Seismic Data ◽  
3D Seismic ◽  
Considerable Success ◽  
Early Success ◽  
Offshore Oil Production ◽  
Exploration And Production ◽  
History Of ◽  
Offshore Oil ◽  
3D Seismic Data ◽  
Opening Up

Since peaking at more than 200 MMbbl in 2000, offshore oil production in Australia has declined steadily by falling to below 100 MMbbl in 2011. Various initiatives and policies have been introduced by the Australian Government to encourage exploration of frontier basins to find a new oil province that may stop this production decline. By analysing the exploration and production profiles of established petroleum provinces in offshore Australia, the reasons behind similarities, differences and trends can be understood. This knowledge can be applied to future exploration efforts and provides a variety of possible outcomes should success come in immature and frontier provinces. Analysis of data mainly from the Bonaparte, Browse, Gippsland, North Carnarvon and, to a lesser extent, the Otway and Perth basins, shows that early success typifies these petroleum provinces. The degree of early success is, however, not always a good indication of later exploration results. While the creaming curves of some basins conform to the hypothetical basin creaming curve, characterised by large initial reserves increases and falling discovery size across time, it is evident that this cannot be universally applied. Considerable success much later in the exploration history of a basin is demonstrated, by success driven policy implementation, exploration incentivisation and increases in data acquisition. In this extended abstract, the importance of using advances in technology is demonstrated by reserves additions following the opening up of deepwater areas and the increased use of high-density 2D seismic and 3D seismic data. This information supports the notion that frontier areas may hold the key to alleviating dependence on foreign supply, success in immature basins is still possible and should not be overlooked.

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