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1
Somerville, R. "THE CEDUNA SUB-BASIN—A SNAPSHOT OF PROSPECTIVITY." APPEA Journal 41, no. 1 (2001): 321. http://dx.doi.org/10.1071/aj00015.
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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.
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Totterdell, Jennifer, Heike Struckmeyer, and Andrew Stacey. "Bight Basin acreage release—new exploration opportunities in a deep water frontier." APPEA Journal 49, no. 1 (2009): 491. http://dx.doi.org/10.1071/aj08032.
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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.
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Norvick, M. S., and M. A. Smith. "MAPPING THE PLATE TECTONIC RECONSTRUCTION OF SOUTHERN AND SOUTHEASTERN AUSTRALIA AND IMPLICATIONS FOR PETROLEUM SYSTEMS." APPEA Journal 41, no. 1 (2001): 15. http://dx.doi.org/10.1071/aj00001.
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Southern Australian breakup history is divisible into three phases. The first phase began with Callovian (c.159–165 Ma) rifting in the western Bight Basin. During the Tithonian (c.142–146 Ma), rifting extended eastwards into the Duntroon, Otway and Gippsland Basins. By the Valanginian (c.130–135 Ma), ocean crust formed between India and western Australia. Structural style in the western Bight changed to thermal subsidence. However, fluvio-lacustrine rift sedimentation continued in Duntroon, Otway and Gippsland until the Barremian (c.115–123 Ma) when these basins also changed to thermal subsidence. The diachronous progression of basin fill types produces a progressive shift in ages of potential source, seal and reservoir intervals along the margin.The second phase began during the Cenomanian (c.92–97.5 Ma) with uplift in eastern Australia, stress reorganisation and divergence of basin development. The Otway, Sorell and Great South Basins formed in a transtensional regime. These tectonics resulted in trap generation through faulting, inversion and wrenching. During the Santonian, oceanic spreading began in the southern Tasman Sea (c.85 Ma). Slow extension caused thinning of continental crust in the Bight and Otway Basins and subsidence into deeper water. Ocean crust formed south of the Bight Basin in the Early Campanian (c.83 Ma) and also started extending up the eastern Australian coast.The third stage in development was caused by Eocene changes to fast spreading in the Southern Ocean (c.44 Ma), final separation of Australia and Antarctica, and cessation of Tasman Sea spreading. These events caused collapse of continental margins and widespread marine transgression. The resultant loading, maturation and marine seal deposition are critical to petroleum prospectivity in the Gippsland Basin.
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Gülzow, W., G. Rehder, J. Schneider v. Deimling, T. Seifert, and Zs Tóth. "One year of continuous measurements constraining methane emissions from the Baltic Sea to the atmosphere using a ship of opportunity." Biogeosciences Discussions 9, no. 8 (August 1, 2012): 9897–944. http://dx.doi.org/10.5194/bgd-9-9897-2012.
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Abstract. Methane and carbon dioxide were measured with an autonomous and continuous running system on a ferry line crossing the Baltic Sea on a 2–3 day interval from the Mecklenburg Bight to the Gulf of Finland in 2010. Surface methane saturations show great seasonal differences in shallow regions like the Mecklenburg Bight (103–507%) compared to deeper regions like the Gotland Basin (96–161%). The influence of controlling parameters like temperature, wind, mixing depth and processes like upwelling, mixing of the water column and sedimentary methane emissions on methane oversaturation and emission to the atmosphere are investigated. Upwelling was found to influence methane surface concentrations in the area of Gotland significantly during the summer period. In February 2010, an event of elevated methane concentrations in the surface water and water column of the Arkona Basin was observed, which could be linked to a wind-derived water level change as a potential triggering mechanism. The Baltic Sea is a source of methane to the atmosphere throughout the year, with highest fluxes during the winter season. Stratification was found to intensify the formation of a methane reservoir in deeper regions like Gulf of Finland or Bornholm Basin, which leads to long lasting elevated methane concentrations and enhanced methane fluxes, when mixed to the surface during mixed layer deepening in autumn and winter. Methane concentrations and fluxes from shallow regions like the Mecklenburg Bight are rather controlled by sedimentary production and consumption of methane, wind events and the change in temperature-dependent solubility of methane in the surface water. Methane fluxes vary significantly in shallow regions (e.g. Mecklenburg Bight) and regions with a temporal stratification (e.g. Bornholm Basin, Gulf of Finland). On the contrary, areas with a permanent stratification like the Gotland Basin show only small seasonal fluctuations in methane fluxes.
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Gülzow, W., G. Rehder, J. Schneider v. Deimling, T. Seifert, and Z. Tóth. "One year of continuous measurements constraining methane emissions from the Baltic Sea to the atmosphere using a ship of opportunity." Biogeosciences 10, no. 1 (January 8, 2013): 81–99. http://dx.doi.org/10.5194/bg-10-81-2013.
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Abstract. Methane and carbon dioxide were measured with an autonomous and continuous running system on a ferry line crossing the Baltic Sea on a 2–3 day interval from the Mecklenburg Bight to the Gulf of Finland in 2010. Surface methane saturations show great seasonal differences in shallow regions like the Mecklenburg Bight (103–507%) compared to deeper regions like the Gotland Basin (96–161%). The influence of controlling parameters like temperature, wind, mixing depth and processes like upwelling, mixing of the water column and sedimentary methane emissions on methane oversaturation and emission to the atmosphere are investigated. Upwelling was found to influence methane surface concentrations in the area of Gotland significantly during the summer period. In February 2010, an event of elevated methane concentrations in the surface water and water column of the Arkona Basin was observed, which could be linked to a wind-derived water level change as a potential triggering mechanism. The Baltic Sea is a source of methane to the atmosphere throughout the year, with highest fluxes occurring during the winter season. Stratification was found to promote the formation of a methane reservoir in deeper regions like Gulf of Finland or Bornholm Basin, which leads to long lasting elevated methane concentrations and enhanced methane fluxes, when mixed to the surface during mixed layer deepening in autumn and winter. Methane concentrations and fluxes from shallow regions like the Mecklenburg Bight are predominantly controlled by sedimentary production and consumption of methane, wind events and the change in temperature-dependent solubility of methane in the surface water. Methane fluxes vary significantly in shallow regions (e.g. Mecklenburg Bight) and regions with a temporal stratification (e.g. Bornholm Basin, Gulf of Finland). On the contrary, areas with a permanent stratification like the Gotland Basin show only small seasonal fluctuations in methane fluxes.
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Kempton, Richard H., Julien Bourdet, Se Gong, and Andrew S. Ross. "Revealing oil migration in the frontier Bight Basin, Australia." Marine and Petroleum Geology 113 (March 2020): 104124. http://dx.doi.org/10.1016/j.marpetgeo.2019.104124.
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Farrington, Rebecca, Kevin C. Hill, Jane Cunneen, Romain Beucher, and Louis Moresi. "The Bight Basin, Evolution & Prospectivity III; FE modelling." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–4. http://dx.doi.org/10.1080/22020586.2019.12073226.
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Strømsøyen, Ingine, Edwin Schomacker, Bo Søderstrøm, and Bärbel M. T. Waagan. "The Bight Basin: a tale of three deltaic megasequences." APPEA Journal 59, no. 2 (2019): 952. http://dx.doi.org/10.1071/aj18213.
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The Bight Basin developed during the Jurassic and Cretaceous in response to repeated periods of extension and thermal cooling leading up to, and following, the onset of seafloor spreading between present-day Australia and Antarctica. The bulk of the resulting sedimentary basin fill includes up to 15 km of Middle Jurassic–recent sediments comprising three deltaic megasequences: White Pointer, Tiger and Hammerhead. High quality seismic 3D data have enabled detailed mapping of the megasequences, evaluation of the nature of infill and assessment of implications for hydrocarbon prospectivity. The Cenomanian White Pointer Megasequence succeeds a period of widespread mudstone deposition in the basin. Growth fault and complex styles of deposition are a function of the high accumulation rates. The growth faulting gradually ceased towards the top of the megasequence allowing for the delta to advance into the basin. Renewed tectonic activity during accumulation of the Turonian–Santonian Tiger Megasequence led to formation of the Outer High trend in the basin. Basal transgressive mudstones during early Tiger deposition are succeeded by a set of progradational–retrogradational units. The base of the Santonian–Maastrichtian Hammerhead Megasequence records widespread subaerial erosion and formation of incised valleys depicting a distinct drop in relative sea level most likely in response to the start of the Australian and Antarctic breakup. This event is followed by a widespread regional flooding event, before the Hammerhead delta built out, first in a highly progradational and subsequently in a more aggradational style. At the end of the sequence, the delta steps back due to decreasing sediment input. Detailed seismic stratigraphic mapping has improved the understanding of the gross depositional environment developed throughout the three megasequences, and importantly also helped identification of the main reservoir fairways and their distribution through time.
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Macdonald, J., G. Backé, R. King, S. Holford, and R. Hillis. "Geomechanical modelling of fault reactivation in the Ceduna Sub-basin, Bight Basin, Australia." Geological Society, London, Special Publications 367, no. 1 (2012): 71–89. http://dx.doi.org/10.1144/sp367.6.
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Cunneen, Jane, Chanel DePledge, Sharon Lowe, Kevin Hill, Candice Godfrey, Amanda Buckingham, and Rebecca Farrington. "The Bight Basin, Evolution & Prospectivity I: gravity, deep seismic & basin morphology." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–4. http://dx.doi.org/10.1080/22020586.2019.12073121.
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Struckmeyer, H. I. M., A. K. Williams, R. Cowley, J. M. Totterdell, G. Lawrence, and G. W. O’Brien. "EVALUATION OF HYDROCARBON SEEPAGE IN THE GREAT AUSTRALIAN BIGHT." APPEA Journal 42, no. 1 (2002): 371. http://dx.doi.org/10.1071/aj01020.
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The regional assessment of hydrocarbon seepage is built around a combination of Radarsat and ERS Synthetic Aperture Radar (SAR) data, acquired during 1998 and 1999, as part of a collaborative project between Geoscience Australia, Nigel Press Associates, Radarsat International and AUSLIG (specifically the Australian Centre for Remote Sensing). In total, 55 Radarsat Wide 1 Beam Mode scenes and one ERS scene from the Great Australian Bight (GAB) region were analysed. The data were integrated with regional geological information, and other hydrocarbon migration and seepage indicators such as reprocessed and reinterpreted legacy Airborne Laser Fluorosensor (ALF) data, to provide an assessment of the possible charge characteristics of the region.The results of the study suggest that active, though areally restricted, liquid hydrocarbon seepage is occurring within the Bight Basin. The majority of seepage slicks occur along the outer margin of the major depocentre, the Ceduna Sub-basin, in areas where significant Late Tertiary to Recent faulting extends to the seafloor. Very little evidence of seepage was observed on the SAR data above the main depocentre, which is an area of minimal Late Tertiary to Recent faulting. Reprocessed ALF data reveal three main areas with relatively dense fluors. Although they are not directly coincident with locations of seepage interpreted from SAR data, their distribution support the pattern of preferred leakage along the basin margins.Integration of regional geological models with the results of this study suggests that structural features related to active tectonism have focused laterally migrating hydrocarbons to produce active seepage at specific locations in the basin. Where these features are absent, seepage may be passive and/or be governed by long distance migration to points of seal failure. Together with oil and gas shows in exploration wells, observations from this study provide further evidence that liquid hydrocarbons have been generated in the Great Australian Bight.
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Buijsman, M. C., Y. Uchiyama, J. C. McWilliams, and C. R. Hill-Lindsay. "Modeling Semidiurnal Internal Tide Variability in the Southern California Bight." Journal of Physical Oceanography 42, no. 1 (January 1, 2012): 62–77. http://dx.doi.org/10.1175/2011jpo4597.1.
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Abstract The Regional Oceanic Modeling System (ROMS) is applied in a nested configuration with realistic forcing to the Southern California Bight (SCB) to analyze the variability in semidiurnal internal wave generation and propagation. The SCB has a complex topography with supercritical slopes that generate linear internal waves at the forcing frequency. The model predicts the observed barotropic and baroclinic tides reasonably well, although the observed baroclinic tides feature slightly larger amplitudes. The strongest semidiurnal barotropic to baroclinic energy conversion occurs on a steep sill slope of the 1900-m-deep Santa Cruz Basin. This causes a forced, near-resonant, semidiurnal Poincaré wave that rotates clockwise in the basin and is of the first mode along the radial, azimuthal, and vertical directions. The associated tidal-mean, depth-integrated energy fluxes and isotherm oscillation amplitudes in the basin reach maximum values of about 5 kW m−1 and 100 m and are strongly modulated by the spring–neap cycle. Most energy is locally dissipated, and only 10% escapes the basin. The baroclinic energy in the remaining basins is orders of magnitudes smaller. High-resolution coastal models are important in locating overlooked mixing hotspots such as the Santa Cruz Basin. These mixing hotspots may be important for ocean mixing and the overturning circulation.
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Venkatesan, M. I., E. Ruth, and I. R. Kaplan. "Triterpenols from sediments of Santa Monica Basin, Southern California Bight, U.S.A." Organic Geochemistry 16, no. 4-6 (January 1990): 1015–24. http://dx.doi.org/10.1016/0146-6380(90)90138-p.
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Frery, E., M. Ducros, L. Langhi, J. Strand, and A. Ross. "Integrated 3D basin and petroleum systems modelling of the Great Australian Bight." APPEA Journal 57, no. 2 (2017): 733. http://dx.doi.org/10.1071/aj16133.
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3D stratigraphic, structural, thermal and migration modelling has become an essential part of petroleum systems analysis for passive margins, especially if complex 3D facies patterns and extensive volcanic activity are observed. A better understanding of such underexplored offshore areas requires a refined 3D basin modelling approach, with the implementation of realistically sized volcanic intrusions, source rocks and reservoir intervals. In this study, an integrated modelling workflow based on a Great Australian Bight case study has been applied. The 244800-km2 3D model integrates well data, marine surveys, 3D stratigraphic forward modelling and 3D basin modelling to better predict the effects of 3D facies variations and heat flow anomalies on the determination of the source rock-enriched intervals, the source rock maturity history and the hydrocarbon migration pathways. Plausible sedimentary sequences have been estimated using a stratigraphic forward model constrained by the limited available well data, seismic interpretation and published tectonic basin history. We also took into account other datasets to produce a thermal history model, such as the location of known volcanic intrusion, volcanic seamounts, bottom hole temperature and surface heat flow measurements. Such basin modelling integrates multiple datatypes acquired in the same basin and provides an ideal platform for testing hypotheses on source rock richness or kinetics, as well as on hydrocarbon migration timing and pathways evolution. The model is flexible, can be easily refined around specific zones of interest and can be updated as new datasets, such as new seismic interpretations and data from new sampling campaigns and wells, are acquired.
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Cunneen, Jane, Candice Grigg, and Eoin Keating. "Evolution of the outer basin high, Ceduna Sub-basin, southern Australia." APPEA Journal 57, no. 2 (2017): 722. http://dx.doi.org/10.1071/aj16196.
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Recent exploration in the Bight Basin has identified an uplifted area on the outer margin of the Ceduna Shelf, known as the outer basin high. The Tiger Supersequence, a potential source rock, thins onto the uplifted area, so the timing and extent of uplift has implications for petroleum system maturity. The outer basin high is 15–40 km wide and extends along the south-western flank of the Ceduna Sub-basin, beneath the outer flank of the Ceduna Terrace. Relative uplift of greater than 2000 m occurs within the area. The outer basin underlies a transitional zone of deformation between the extensional faulting and outer fold and thrust regions of the overlying White Pointer and Hammerhead delta systems. Detailed mapping using the recently released Ceduna 3D seismic dataset reveals two main episodes of relative uplift, in the Santonian and again in the Maastrichtian to Eocene. The first phase of relative uplift is associated with thinning of the Tiger Supersequence onto the high. The second phase is identified as a decrease in thickness of the Hammerhead Supersequence overlying the high. The exact timing of this uplift is difficult to constrain due to truncation of the Hammerhead Supersequence by the basin-wide Eocene unconformity, however, estimates of the amount of uplift are based on seismic mapping.
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Totterdell, J. M., J. E. Blevin, H. I. M. Struckmeyer, B. E. Bradshaw, J. B. Colwell, and J. M. Kennard. "A NEW SEQUENCE FRAMEWORK FORTHE GREAT AUSTRALIAN BIGHT: STARTING WITH A CLEAN SLATE." APPEA Journal 40, no. 1 (2000): 95. http://dx.doi.org/10.1071/aj99007.
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The 1999 release of offshore petroleum exploration acreage in the Great Australian Bight and the acquisition of high quality seismic datasets covering the Bight and Duntroon Basins, have provided a timely opportunity to reassess the stratigraphic and tectonic evolution of the area. A sequence stratigraphic framework for the Great Australian Bight region has been developed based on the interpretation of exploration wells in the Bight and Duntroon basins and a grid of new and reprocessed seismic data in the Bight Basin. Previous formation-based nomenclature has emphasised lithostratigraphic correlations rather than the chronostratigraphic relationships. The new sequence framework underpins an analysis of play elements and petroleum systems and is helping to identify new exploration opportunities.Deposition in the Bight and Duntroon Basins commenced in the Late Jurassic during a period of lithospheric extension. Extensive half graben systems were filled with fluvial and lacustrine clastic sediments (Sea Lion and Minke supersequences). Potential source rocks within these supersequences are immature at Jerboa-1 in the Eyre Sub-basin, however higher maturities are expected within adjacent half graben and in the Ceduna and Recherche Sub-basins. The syn-rift successions are overlain by widespread Berriasian to Albian fluvio-lacustrine to marine sediments of the Southern Right and Bronze Whaler supersequences. The onlapping sag-fill geometry of these Early Cretaceous packages in the Eyre, Ceduna and inner Recherche Sub-basins suggests that they were deposited during a period of thermal subsidence.Accelerated subsidence commencing in the late Albian led to the deposition of the marine shales of the Blue Whale supersequence, followed by a period of gravity-controlled faulting and deformation in the Cenomanian. The White Pointer supersequence is characterised by growth strata associated with a series of listric faults that sole out in underlying ductile shales of the Blue Whale supersequence. Open marine conditions during the Turonian-Santonian (Tiger supersequence) were followed by the development of massive shelf margin delta complexes in the late Santonian-Maastrichtian (Hammerhead supersequence). The progradational to aggradational stratal geometries within the Hammerhead supersequence suggest initial high rates of sediment input that subsequently waned during this period. An overall transgressive phase of sedimentation in the Early Tertiary (Wobbegong supersequence) was followed by the establishment of open marine carbonate shelf conditions from the Early Eocene onward (Dugong supersequence). Organic geochemical studies show that the Bronze Whaler to White Pointer supersequences have good source rock potential in the relatively proximal facies intersected by existing petroleum exploration wells. Our sequence stratigraphic model predicts the likelihood of widespread late Aptian, Albian, Cenomanian-Santonian, and Campanian marine shales, which underpin four potential marine petroleum systems.
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Petit, Tillys, Virginie Thierry, and Herlé Mercier. "Deep through-flow in the Bight Fracture Zone." Ocean Science 18, no. 4 (July 15, 2022): 1055–71. http://dx.doi.org/10.5194/os-18-1055-2022.
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Abstract. Iceland–Scotland Overflow Water (ISOW) is exported from the Nordic Seas into the Iceland Basin to feed the lower limb of the Meridional Overturning Circulation. The Bight Fracture Zone (BFZ) is known to be a major route for ISOW toward the Irminger Sea, but the role of this gateway in the evolution of ISOW properties over the subpolar gyre is unclear. A combination of ship-based and Deep-Argo data gathered between 2015 and 2018 allows us to investigate the pathways and hydrographic evolution of ISOW as it flows through the BFZ, as well as its influence on the North Atlantic Deep Water (NADW) properties in the Irminger Sea. The ISOW flow through the BFZ amounts to 0.8 ± 0.2 Sv and is mainly fed by the lighter part of the ISOW layer flowing west of 29–30∘ W as part of the East Reykjanes Ridge Current in the Iceland Basin. In the rift valley of the BFZ, between an eastern and a western sill, the bathymetry of the BFZ shapes a cyclonic circulation along which the ISOW layer is homogenized. The largest changes in ISOW properties are however observed downstream of the western sill, at the exit of the BFZ. There, ISOW is mixed isopycnally with comparatively fresher NADW circulating in the Irminger Sea. Hence, our analysis reveals the key role of the BFZ through-flow in the salinification of the NADW in the Irminger Current.
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Bernecker, Tom. "The 2010 Australian offshore release for petroleum exploration." APPEA Journal 50, no. 1 (2010): 5. http://dx.doi.org/10.1071/aj09002.
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The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. In 2010, thirty-one areas in five offshore basins are being released for work program bidding. Closing dates for bid submissions are either six or twelve months after the release date—i.e. 11 November 2010 and 12 May 2011—depending on the exploration status in these areas and on data availability. The 2010 release areas are located in Commonwealth waters offshore Northern Territory, Western Australia and South Australia, comprising intensively explored areas close to existing production as well as new frontiers. The Westralian Superbasin along the North West Shelf continues to feature prominently, and is complimented by a new frontier area in offshore SW Australia (Mentelle Basin), as well as two areas in the Ceduna/Duntroon sub-basins in the eastern part of the Bight Basin. The Bonaparte Basin is represented by three areas in the Petrel Sub-basin and two areas in the Vulcan Sub-basin. Further southwest, four large areas are being released in the outer Roebuck Basin—a significantly under-explored region. This year, the Carnarvon Basin provides 16 release areas of which three are located in the Beagle Sub-basin, five in the Dampier Sub-basin, five in the Barrow Sub-basin, three on the Exmouth Plateau and three in the Exmouth Sub-basin. The largest singular release area covers much of the Mentelle Basin in offshore SW Australia, and two areas are available in the Ceduna and Duntroon sub-basins as part of South Australia’s easternmost section of the Bight Basin. The 2010 Offshore Acreage Release offers a wide variety of block sizes in shallow as well as deep water environments. Area selection has been undertaken in consultation with industry, the States and the Northern Territory. As part of Geoscience Australia’s Offshore Energy Security Program, new data has been acquired in offshore frontier regions parts of which are being published on the Mentelle Basin (Borissova et al, this volume).
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Bourdet, Julien, Richard H. Kempton, Vanessa Dyja-Person, Jacques Pironon, Se Gong, and Andrew S. Ross. "Constraining the timing and evolution of hydrocarbon migration in the Bight Basin." Marine and Petroleum Geology 114 (April 2020): 104193. http://dx.doi.org/10.1016/j.marpetgeo.2019.104193.
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Hill, Kevin C., Jane Cunneen, and Rebecca Farrington. "The Bight Basin, evolution and prospectivity II; seismic, structure and balanced sections." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–5. http://dx.doi.org/10.1080/22020586.2019.12073098.
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Dean, Christopher D., Daniel S. Collins, Marijn van Cappelle, Alexandros Avdis, and Gary J. Hampson. "Regional-scale paleobathymetry controlled location, but not magnitude, of tidal dynamics in the Late Cretaceous Western Interior Seaway, USA." Geology 47, no. 11 (September 25, 2019): 1083–87. http://dx.doi.org/10.1130/g46624.1.
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Abstract Despite extensive outcrop and previous sedimentologic study, the role of tidal processes along sandy, wave- and river-dominated shorelines of the North American Cretaceous Western Interior Seaway remains uncertain, particularly for the extensive mid-Campanian (ca. 75–77.5 Ma) tidal deposits of Utah and Colorado, USA. Herein, paleotidal modeling, paleogeographic reconstructions, and interpretations of depositional process regimes are combined to evaluate the regional-scale (hundreds to thousands of kilometers) basin physiographic controls on tidal range and currents along these regressive shorelines in the “Utah Bight”, southwestern Western Interior Seaway. Paleotidal modeling using a global and astronomically forced tidal model, combined with paleobathymetric sensitivity tests, indicates the location of stratigraphic units preserving pronounced tidal influence only when the seaway had a deep center (∼400 m) and southern entrance (>100 m). Maximum tidal velocity vectors under these conditions suggest a dominant southeasterly ebb tide within the Utah Bight, consistent with the location and orientation of paleocurrent measurements in regressive, tide-influenced deltaic units. The modeled deep paleobathymetry increased tidal inflow into the basin and enhanced local-scale (tens to hundreds of kilometers) resonance effects in the Utah Bight, where an amphidromic cell was located. However, the preservation of bidirectional, mudstone-draped cross-stratification in fine- to medium-grained sandstones requires tides in combination with fluvial currents and/or local tidal amplification below the maximum resolution of model meshes (∼10 km). These findings suggest that while regional-scale controls govern tidal potential within basins, localized physiography exerts an important control on the preservation of tidal signatures in the geologic record.
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Kempton, Richard, Julien Bourdet, Se Gong, Andrew Ross, and Jacques Pironon. "Petroleum migration in the Bight Basin: a fluid inclusion approach to constraining source, composition and timing." APPEA Journal 57, no. 2 (2017): 762. http://dx.doi.org/10.1071/aj16222.
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The Bight Basin in southern Australia is a vast under-explored offshore area with promise of, but as of yet, limited proof for hydrocarbons. Fluid inclusions (FIs) offer a unique method to test for petroleum migration, composition and timing, which would otherwise remain hidden in the rocks, and more direct evidence to calibrate basin models. A reconnaissance-scale FI study, using CSIRO’s Grain with Oil Inclusion (GOI™) technique, was undertaken to detect liquid hydrocarbons in Jurassic to Cretaceous sandstones. Oil-bearing, and in some cases gas-rich, inclusions were detected at low abundance, and their presence provides proof of oil generation and migration in the Ceduna Sub-basin. Geochemical fingerprinting of FI oil was undertaken using the Molecular Composition of oil Inclusions (MCI) technique on an intra-Coniacian interval in Gnarlyknots-1A and a Cenomanian interval in Greenly-1. The results show differences in the type of organic matter input, with algal co-sourcing significant for the central Ceduna Sub-basin. The timing of oil migration from pressure-temperature (PT) reconstructions was interpreted in Gnarlyknots-1A, Greenly-1, Duntroon-1 and Potoroo-1. The results indicate oil charge during the Late Cretaceous in the basin depocentres, explained by sediment loading of the Upper Cretaceous succession by the Hammerhead Supersequence and oil, gas-condensate and gas charge to the depocentres and basin margins during the Miocene. The Great Australian Bight Research Program is a collaboration between BP, CSIRO, the South Australian Research and Development Institute (SARDI), the University of Adelaide and Flinders University. The Program aims to provide a whole-of-system understanding of the environmental, economic and social values of the region, providing an information source for all to use.
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Thunell, Robert C., Cynthia H. Pilskaln, Eric Tappa, and Leslie Reynolds Sautter. "Temporal variability in sediment fluxes in the San Pedro Basin, southern California bight." Continental Shelf Research 14, no. 4 (April 1994): 333–52. http://dx.doi.org/10.1016/0278-4343(94)90022-1.
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Ross, Andrew, Alan Williams, Asrar Talukder, Joanna Parr, Christine Trefry, Richard Kempton, Charlotte Stalvies, et al. "Insights into the Great Australian Bight gained through marine geology and benthic ecology studies." APPEA Journal 58, no. 2 (2018): 845. http://dx.doi.org/10.1071/aj17240.
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While the Great Australian Bight (GAB) represents one of the most prospective deep water basins in Australia, its vast geographic extent and deep sedimentary sequences remain poorly characterised. Recently, multidisciplinary research has been conducted to better characterise the continental and abyssal slope of the Ceduna Sub-basin. The Great Australian Bight Deepwater Marine Program (GABDMP) aimed to build a regional understanding of the deep water GAB marine geology and benthic ecology. This three-year research program encompassed four research voyages that aimed to sample and characterise deep water outcropping facies, volcanic seamounts, potential seeps and their associated biological communities. These voyages used a variety of equipment to achieve the research goals and included the deployment of autonomous underwater and remotely operated vehicles and a seafloor coring system. Numerous sites across the Ceduna Sub-basin from 700 to 5501 m water depth were studied. Sampling operations collected over 2.8 tons of rocks, 148 m of core, 55 698 biological specimens and 48 097 km2 of mapping data. Nearly 4000 geological samples have been analysed to date. This paper will summarise the key findings from the GABDMP and the geological and biological insights that have been revealed through this multidisciplinary research program.
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Klauser-Baumgärtner, Detlef, Thomas Reichel, and John-Are Hansen. "Regional paleodepositional environment of the Cretaceous in the Great Australian Bight – a support for frontier exploration." APPEA Journal 59, no. 2 (2019): 891. http://dx.doi.org/10.1071/aj18055.
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To reveal the development of the depositional environment in the Great Australian Bight, regional and high-resolution 3D-seismic interpretation and palynological evidence from well data was integrated with tectonic plate- and paleo topographical-reconstructions. Results from that work explain the drainage patterns and changes in the sedimentary evolution. A maximum transgression at the Cenomanian–Turonian boundary causes the deposition of the expected main source rock interval at the base of the Tiger mega-sequence. This is supported by Integrated Ocean Drilling Program wells (2017), asphalite strandings and dredge samples from the basin. A relative sea-level drop in the mid-Turonian initiates a forced regression and sand deposition in more distal parts of the basin. As a third mega-sequence the Hammerhead Formation progrades into the basin, depositing several thousand metres of deltaic sandstones and lagoonal shales. Our source to sink model based on our gross depositional environment maps could explain the presence of source rocks and reservoir intervals within this frontier exploration basin.
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Koh, Weidi. "Getting it right the first time in the Ceduna Sub-basin: regional and target depth imaging in a frontier setting." APPEA Journal 57, no. 2 (2017): 767. http://dx.doi.org/10.1071/aj16180.
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The acquisition and depth imaging of almost 20400 km2 of broadband seismic data in the Great Australian Bight has created an excellent dataset fit for quantitative interpretation. This new dataset was derived from a merge of 12400 km2 of 2011 vintage conventional streamer data in an almost seamless manner with 8000 km2 of 2014 vintage dual-sensor streamer data. The Ceduna Sub-basin is the main depocentre of the Bight Basin. It lies adjacent to the continental shelf and slope and is covered by two broad bathymetric terraces in water depths ranging from <200 to >4000 m. A potentially prospective Late Jurassic syn-rift to Late Cretaceous post-rift sedimentary succession (fluvial to paralic sediments) >15 km thick is imaged with remarkable quality and resolution. Features of particular interest include large stacked fan and channel systems, as well as simple, structurally closed formations. Careful survey design and execution optimised efficiency, enabling each survey to be acquired in less than one season. Particular attention was given to amplitude versus offset and phase compliance, including customised flows to overcome a paucity of well control in this frontier area. Optimised preprocessing, velocity model building and survey merging were applied to ensure structural and depth integrity in the final images. Regional and targeted mapping and quantitative interpretation results testify to the value of the multifaceted geophysical and geological disciplines used in the overall project execution.
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MacDonald, Justin, Rosalind King, Richard Hillis, and Guillaume Backé. "Structural style of the White Pointer and Hammerhead Delta—deepwater fold-thrust belts, Bight Basin, Australia." APPEA Journal 50, no. 1 (2010): 487. http://dx.doi.org/10.1071/aj09029.
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GeoScience Victoria and partners have undertaken the first detailed basin-wide study of the regional top seal in the Gippsland Basin. The Gippsland Basin is an attractive site for geological carbon storage (GCS) because of the close proximity to emission sources and the potential for large-scale storage projects. This top seal assessment involved the analysis of seal attributes (geometry, capacity and mineralogy) and empirical evidence for seal failure (soil gas geochemical anomalies, gas chimneys, hydrocarbon seepage and oil slicks). These datasets have been integrated to produce a qualitative evaluation of the containment potential for GCS, and also hydrocarbons, across the basin. Mineralogical analysis of the top seal has revealed that the Lakes Entrance Formation is principally a smectite-rich claystone. The geometry of the top seal is consistent with deposition in an early post-rift setting where marine sediments filled palaeo-topographic lows. The seal thickness and depth to seal base are greatest in the Central Deep and decrease toward the margins. There is a strong positive relationship between seal capacity column heights, seal thickness, depth to seal base and smectite content. At greater burial depths (below 700 m) and where smectite content is greater than 70%, seal capacity is increased (supportable column heights above 150 m). Natural hydrocarbon leakage and seepage onshore and offshore is correlated with fault distribution and areas of poor seal capacity. This study provides a framework for qualitatively evaluating seal potential at a basin scale. It has shown that the potential of the regional top seal over the Central Deep, Southern Terrace, central eastern Lake Wellington Depression and the southern to central near shore areas in the Seaspray Depression are most suitable for the containment of supercritical CO2. Further toward the margin of the regional seal in both onshore and offshore areas, containment of supercritical CO2 is less likely.
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Schwebel, D. "EXPLORATION REVIEW." APPEA Journal 43, no. 2 (2003): 93. http://dx.doi.org/10.1071/aj02066.
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Both exploration expenditure and drilling were significantly down in 2002 in comparison to 2001. This quiet phase is primarily due to the evaluation of the 2001 drilling and seismic results which should lead, in the long term, to the next cycle of prospect drilling and re-evaluation.The amount of onshore 2D seismic acquisition data gathered was similar to 2001 with most data acquired primarily in the producing basins.Offshore seismic acquisition was down markedly due the completion of a number of major 3D surveys. These data are now in the processing and interpretation phase and when completed will identify the next drilling candidates.The continued success story of the offshore Otway Basin has re-invigorated exploration interest in Australia’s southern margins with exploration continuing to ramp up in the Bight Basin. In the west, the further evaluation of the offshore Perth Basin indicates renewed interest as a result of the Cliff Head discovery.
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Wainman, Carmine, Peter McCabe, and Simon Holford. "New insights on Upper Cretaceous stratigraphy and sedimentology of the Bight Basin, Australia from IODP Site U1512." APPEA Journal 59, no. 2 (2019): 968. http://dx.doi.org/10.1071/aj18136.
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The Bight Basin, on Australia’s southern margin, is one of the world's most prospective deepwater frontier basins. The 10 offshore wells drilled in the basin had limited success or yielded disappointing results. There has been a strong dependence on seismic data to interpret stratal ages and the regional depositional history because of the limited number of wells, which are all in the more proximal region. In October 2017, the International Ocean Discovery Program Expedition 369 drilled a hole at Site U1512 that straddled the Australian Geological Survey Organisation Survey s065 line 06 on the continental slope, ~67 km south-east of the Jerboa 1 well. The recovered core is the most extensive lithological dataset acquired from the basin and consists of a 10 m thick Pleistocene ooze overlying a 690 m succession of Turonian–Santonian strata. The Cretaceous strata consist of silty claystone with a few thin beds of glauconitic and sideritic sandstone (<32 cm thick). The Tiger Supersequence is substantially thicker than had been anticipated. Preliminary palynofacies analysis indicates a prevailing dysoxic marine environment, with the assemblage dominated by phytoclasts (40–90% of the assemblage). This may have been a consequence of high rates of freshwater runoff into the restricted basin. Rapid sedimentation rates (up to 260 m/Myr), the silt content (2–25%) and the palynofacies suggest the strata were deposited primarily by hyperpycnal and hypopycnal flows. These new datasets will provide a means to re-evaluate the palaeogeography of the basin and its resource potential.
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Reynolds, Scott D., Richard R. Hillis, and Evelina Paraschivoiu. "In Situ Stress Field, Fault Reactivation and Seal Integrity in the Bight Basin, South Australia." ASEG Extended Abstracts 2003, no. 2 (August 2003): 1–5. http://dx.doi.org/10.1071/aseg2003ab141.
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Reynolds, Scott, Richard Hillis, and Evelina Paraschivoiu. "In situ stress field, fault reactivation and seal integrity in the Bight Basin, South Australia." Exploration Geophysics 34, no. 3 (June 2003): 174–81. http://dx.doi.org/10.1071/eg03174.
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Gong, Se, Richard H. Kempton, Andrew S. Ross, and Julien Bourdet. "Geochemical characterisation of migrated hydrocarbons reveals insights into the source rocks of the Bight Basin." Marine and Petroleum Geology 119 (September 2020): 104467. http://dx.doi.org/10.1016/j.marpetgeo.2020.104467.
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MacDonald, Justin, Guillaume Backé, Rosalind King, and Richard Hillis. "The Hammerhead Delta—deepwater fold-thrust belt, Bight Basin, Australia: 2D kinematic and geomechanical reconstructions." APPEA Journal 51, no. 2 (2011): 739. http://dx.doi.org/10.1071/aj10119.
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The Hammerhead Delta—deepwater fold-thrust belt is located in the Ceduna Sub-basin of the Bight Basin, offshore southern Australia. It is a short lived gravity gliding system, Late Santonian-Maastrichtian in age. It exhibits a distinctive spoon shape in cross-section and detaches on a master horizon above Santonian marine shales of the Tiger Supersequence. Here, we have interpreted a large seismic dataset—including the recently acquired regional two-dimensional seismic dataset provided by Ion Geophysical—to constrain the regional structural geometry of the Hammerhead Delta—deepwater fold-thrust belt. Two structural restorations were completed to quantify the amount of extension and shortening in the system. These restorations were: a two-dimensional kinematic restoration, using 2D MOVE; and a two-dimensional geomechanical restoration, using Dynel 2D. By comparing results from the two techniques we demonstrate that the amount of observed extension in the delta top is nearly balanced by the shortening in the delta toe. The near balance (< 2 % excess extension) of the system is a unique result. Other passive margin systems demonstrate larger amounts of extension compared to shortening, due to the regional-scale pro-gradational nature of the systems. These results suggest that the balanced geometry of the Hammerhead Delta—deepwater fold-thrust belt is consistent with either a sudden decrease in sediment supply during the upper Maastrichtian, resulting in a cessation of prograding fault activity, or a loss of extension to the underlying Cenomanian growth faults or some combination thereof. Thus, the system failed to develop into an extensive passive margin delta—deepwater fold-thrust belt.
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Diechmann, R., and H. W. Partenscky. "A NEW EQUILIBRIUM ANALYSIS FOR NEARSHORE TIDAL BASINS." Coastal Engineering Proceedings 1, no. 20 (January 29, 1986): 80. http://dx.doi.org/10.9753/icce.v20.80.
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A large tidal flat area of about 40 tidal basins with catchment areas of between 10 and 790 km2 exists along the coast of the German Bight. Not all of these tidal basins are morphologically stable. The main parameter necessary for determining the state of equilibrium is the volumetric capacity of the concave portions of the tidal basin. In order to examine the equilibrium state it is necessary to compare the volumetric capacity of the tidal basin determined from hydrographic charts (measured volume) with a theoretical volume given by newly developed stability criteria representing averaged conditions (volume balances). Significant deviations between the theoretical and the measured volumes indicate a state of non-equilibrium. Using stability criteria it is possible to desribe the state of equilibrium of a tidal basin in a stepwise manner either from the bottom of the tidal basin to the datum plane MHW in order to obtain a cross-sectional stability profile, or from the shore to the seaward boundary of the basin in order to obtain a longitudinal stability profile. The applicability of the new method for analyzing the equilibrium of a tidal basin will be demonstrated by the example of the Suderau tidal basin in the north of Germany.
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Snyder, Morgan E., and John W. F. Waldron. "Deformation of soft sediments and evaporites in a tectonically active basin: Bay St. George sub-basin, Newfoundland, Canada." Atlantic Geology 57 (November 11, 2021): 275–304. http://dx.doi.org/10.4138/atlgeol.2021.013.
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The Bay St. George sub-basin of SW Newfoundland, part of the larger late Paleozoic Maritimes basin, formed under the influence of strike-slip faulting and the movement of evaporites. New stratigraphic correlations between Newfoundland and other late Paleozoic sub-basins illustrate the effects of both basement and salt movement. Coastal outcrops show complex combinations of synsedimentary, salt-related, and tectonic structures. Map relationships and dramatic thickness contrasts in the Tournaisian Anguille Group indicate that a large, concealed, NE–striking normal growth fault (Ship Cove fault) controlled sedimentation; the exposed Snakes Bight fault originated as a hanging-wall splay. Structures formed during, or soon after deposition include soft-sediment folds, boudins, clastic dykes, and millimetre-scale diapiric bulb structures, formed by overpressuring and liquidization of sediment. These suggest that the sub-basin was tectonically active throughout deposition. Evaporite-related deformation is recorded in the Visean Codroy Group and overlying strata. Comparisons between outcrop and subsurface suggests that significant amounts of evaporite were removed from exposed sections by halokinesis and solution. Complex outcrop relationships indicate salt welds, and suggest that units of the upper Codroy and overlying Barachois groups represent fills of minibasins that subsided into thick evaporites. Field relationships suggest tectonic inversion deposition related to E-W dextral strike slip motion that affected the entire Maritimes basin in the Serpukhovian, producing reverse-sense offsets and contractional folds. Many of the structures in the Bay St. George sub-basin, previously interpreted as post-depositional and purely tectonic, were formed by deformation of unlithified sediment and ductile evaporites during basin development.
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Garrison, Ervan G., Gary S. Morgan, Krista McGrath, Camilla Speller, and Alexander Cherkinsky. "Recent dating of extinct Atlantic gray whale fossils, (Eschrichtius robustus), Georgia Bight and Florida, western Atlantic Ocean." PeerJ 7 (February 4, 2019): e6381. http://dx.doi.org/10.7717/peerj.6381.
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The Atlantic gray whale (Eschrichtius robustus) presents an interesting case study of climate related dispersal and extinction. While (limited) fossil records confirm its presence in the Atlantic up until the 18th Century, its abundance and distribution within the Eastern and Western basins are still not well understood. The discovery of presumed gray whale fossil remains from the Georgia Bight and the Atlantic coast of Florida, from the mid-1980s to late-2000s, provides a new opportunity to recover additional data regarding their chronology within the Western basin. Here, we apply accelerator mass spectrometry radiocarbon techniques to six fossil whale finds, identifying dates within marine isotope stage 3 (59–24 ka) and the late Holocene, ∼2,000 yr BP. We additionally confirm the taxonomic identification of two fossil bone samples as E. robustus using collagen peptide mass fingerprinting (ZooMS). The obtained dates, when combined with a larger corpus of previously published Atlantic gray whale fossil dates, support the hypothesis for the decline of the Atlantic gray whale in the late Pleistocene and the late Holocene. These new data augment the findings of the Eastern Atlantic Basin and better incorporate the Western Atlantic Basin into a pan-ocean understanding for the species.
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Sidjabat, Mulia M. "THE NUMERICAL MODELLING OF TIDES IN A SHALLOW SEMI-ENCLOSED BASIN BY A MODIFIED ELLIPTIC METHOD." Marine Research in Indonesia 21 (May 10, 2018): 1–47. http://dx.doi.org/10.14203/mri.v21i0.389.
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A numerical model which renders possible the numerical solution of the nonlinear tidal equations by obtaining a solution for each individual tidal component is developed. For this purpose, a set of time independent non-linear equations for each tidal constituent is constructed. Each of these sets of equations is interrelated through the non-linear frictional terms, the approximation of which is accomplished by an iterative scheme. The method is tested for several models before it is applied to the real basin (Bight of Abaco). In order to evaluate the model and to construct the boundary conditions along the opening, a series of tidal observations were undertaken. The viability of the method is indicated by the fact that the results of computations using a coefficient of friction r = 0.0034 give good agreement with observations for all components and over all stations.
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King, R. C., and G. Backé. "A balanced 2D structural model of the Hammerhead Delta–Deepwater Fold-Thrust Belt, Bight Basin, Australia." Australian Journal of Earth Sciences 57, no. 7 (October 2010): 1005–12. http://dx.doi.org/10.1080/08120099.2010.509409.
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McDermott, Kenneth, Paul Bellingham, Rod Graham, James Pindell, Lynn Pryer, Donna Cathro, and Brian Horn. "Continental extension and break-up—using the Australian margins as a case study." APPEA Journal 55, no. 2 (2015): 399. http://dx.doi.org/10.1071/aj14034.
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The continental margins of Australia provide an excellent natural laboratory for investigations of continental extension and break-up, with examples of failed rifts, multi-phase extensional systems, and volcanic and non-volcanic margins. The thick sedimentary cover across large parts, however, has hindered understanding of the deep crustal and lithospheric structure due to poor imaging. ION Geophysical has acquired deep, long offset seismic data across Australia’s North West Shelf, as well as the Bight Basin on Australia’s southern margin. These programs provide unique imaging of the deep basement structures and the complete overlying sedimentary section, and across all of the terrains from continental crust to oceanic crust. The authors’ interpretation of these data will be discussed in the context of existing models for continental extension and break-up and the resulting implications for the petroleum system: Models of hyper-extension and possible mantle exhumation will be discussed with regards to the Bonaparte, Browse and Bight basins. Multi-phase extension and the development of intra-sedimentary detachment horizons will be reviewed across many areas. Development of volcanic margins, including the effects of dynamic uplift and magmatic intrusions, will be investigated in the Exmouth Plateau. Creation of enough accommodation space to allow the deposition of the observed (~20 km) sedimentary sections in the Carnarvon and Bonaparte basins.
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Walter, S., U. Breitenbach, H. W. Bange, G. Nausch, and D. W. R. Wallace. "Nitrous oxide water column distribution during the transition from anoxic to oxic conditions in the Baltic Sea." Biogeosciences Discussions 3, no. 3 (June 26, 2006): 729–64. http://dx.doi.org/10.5194/bgd-3-729-2006.
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Abstract. In January 2003, a major inflow of cold and oxygen-rich North Sea Water in the Baltic Sea terminated an ongoing stagnation period in parts of the central Baltic Sea. In order to investigate the role of North Sea Water inflow to the Baltic Sea with regard to the production of nitrous oxide (N2O), we measured dissolved and atmospheric N2O at 26 stations in the southern and central Baltic Sea in October 2003. At the time of our cruise, water renewal had proceeded to the eastern Gotland Basin, whereas the western Gotland Basin was still unaffected by the inflow. The deep water renewal was detectable in the distributions of temperature, salinity, and oxygen concentrations as well as in the distribution of the N2O concentrations: Shallow stations in the Kiel Bight and Pomeranian Bight were well-ventilated with uniform N2O concentrations near equilibrium throughout the water column. In contrast, stations in the deep basins, such as the Bornholm and the Gotland Deep, showed a clear stratification with deep water affected by North Sea Water. Inflowing North Sea Water led to changed environmental conditions, especially enhanced oxygen (O2) or declining hydrogen sulfide (H2S) concentrations, thus, affecting the conditions for the production of N2O. Pattern of N2O profiles and correlations with parameters like oxygen and nitrate differed between the basins. The dominant production pathway seems to be nitrification rather than denitrification. No indications for advection of N2O by North Sea Water were found. A rough budget revealed a significant surplus of in situ produced N2O after the inflow. However, due to the permanent halocline, it can be assumed that the formed N2O does not reach the atmosphere. Hydrographic aspects therefore are decisive factors determining the final release of produced N2O to the atmosphere.
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Kovacevic, Matthew, Jane Cunneen, and Chris Elders. "Evolution of detached listric fault systems in the Ceduna Delta, Bight Basin: Insights from 3D seismic data." ASEG Extended Abstracts 2015, no. 1 (December 2015): 1–4. http://dx.doi.org/10.1071/aseg2015ab012.
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Strand, Julian, Laurent Langhi, Andrew Stuart Ross, and Christopher Dyt. "Coupled stratigraphic and fault seal modelling used to describe trap integrity in the frontier Bight Basin, Australia." Marine and Petroleum Geology 86 (September 2017): 474–85. http://dx.doi.org/10.1016/j.marpetgeo.2017.06.011.
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Bernecker, Thomas, Tehani Kuske, Bridgette Lewis, and Tegan Smith. "The hydrocarbon potential of the 2015 Offshore Acreage Release Areas for petroleum exploration." APPEA Journal 55, no. 1 (2015): 71. http://dx.doi.org/10.1071/aj14007.
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The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. These areas are located across various offshore hydrocarbon provinces ranging from mature basins with ongoing oil and gas production to exploration frontiers. A total of 23 areas are released for work-program bidding and six areas for cash bidding (Fig. 1). The two work-program bidding rounds will remain open until 29 October 2015 and 21 April 2016, respectively, while cash bid submissions will close on 4 February 2016. The 2015 Release Areas are located in 13 distinct geological provinces across eight basins and all were supported by industry nominations. Six areas are located in the Bonaparte Basin, two of which are cash bid areas over the Turtle/Barnett oil accumulations. In the Browse Basin, three areas in the Caswell Sub-basin and one area on the Yampi Shelf are released. In support of recent exploration activities and success, one large area has been gazetted in the central Roebuck Basin. The Northern Carnarvon Basin offering comprises 11 areas on the Exmouth Plateau and in the Dampier Sub-basin, including four for cash bidding. This year, the usual predominance of North West Shelf Release Areas is counterbalanced by seven large areas in the Bight, Otway, Sorell and Gippsland basins. This includes one area in the Ceduna Sub-basin, three areas in the deepwater Otway Basin, one area in the northern Sorell Basin and two areas in the southeastern Gippsland Basin. The nominations received for these areas highlights the industry’s interest in evaluating the hydrocarbon potential of Australia’s underexplored southern margin. Geoscience Australia continues to support industry activities by acquiring, interpreting and integrating pre-competitive datasets that are made freely available as part of the agency’s regional petroleum geological studies.
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Bernecker, Thomas. "Petroleum geological summary of the 2012 offshore acreage release for petroleum exploration." APPEA Journal 52, no. 1 (2012): 7. http://dx.doi.org/10.1071/aj11002.
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The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. In 2012, 27 areas in nine offshore basins are being released for work program bidding. Closing dates for bid submissions are either six or twelve months after the release date, i.e. 8 November 2012 or 9 May 2013, depending on the exploration status in these areas and on data availability. As was the case in 2011, this year’s Release again covers a total offshore area of about 200,000 km2. The Release Areas are located in Commonwealth waters offshore Northern Territory, Western Australia, South Australia, Victoria and Tasmania (Fig. 1). Areas on the North West Shelf feature prominently again and include under-explored shallow water areas in the Arafura and Money Shoal basins and rank frontier deep water areas in the outer Browse and Roebuck basins as well as on the outer Exmouth Plateau. Following the recent uptake of exploration permits in the Bight Basin (Ceduna and Duntroon sub-basins), Australia’s southern margin is well represented in the 2012 Acreage Release. Three new areas in the Ceduna Sub-basin, four areas in the Otway Basin, one large area in the Sorell Basin and two areas in the eastern Gippsland Basin are on offer. Multiple industry nominations for this Acreage Release were received, confirming the healthy status of exploration activity in Australia. The Australian government continues to support these activities by providing free access to a wealth of geological and geophysical data.
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Bernecker, Thomas, Dianne Edwards, Tehani Kuske, Bridgette Lewis, and Tegan Smith. "Prospectivity of the 2014 offshore acreage release areas for petroleum exploration." APPEA Journal 54, no. 1 (2014): 383. http://dx.doi.org/10.1071/aj13040.
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The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. Industry nominations provided guidance for the selection of gazettal areas, and in 2014 all 30 areas are supported by such nominations. The release areas are located across various offshore hydrocarbon provinces ranging from mature basins with ongoing oil and gas production to exploration frontiers. Work program bids are invited for two rounds closing on 2 October 2014 and 2 April 2015, while the closing date for four cash bid areas is 5 February 2015. Twenty-nine of the 2014 Release Areas are located along Australia’s northern margin within the Westralian Superbasin, which encompasses the rift-basins that extend from the Northern Carnarvon Basin to the Bonaparte Basin. Evolution during Gondwana break-up established a series of petroleum systems, many of which have been successfully explored, while others remain untapped. Only one area was nominated and approved for release on Australia’s southern margin. The 220 graticular blocks cover almost the entire Eyre Sub-basin of the Bight Basin. In the context of the recent commencement of large-scale exploration programs in the Ceduna and Duntroon sub-basins, this release area provides additional opportunities to explore an offshore frontier. Geoscience Australia’s new long-term petroleum program supports industry activities by engaging in petroleum geological studies that are aimed at the establishment of margin to basin-scale structural frameworks and comprehensive assessments of Australian source rocks underpinning all hydrocarbon prospectivity studies.
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Juo, A. S. R., and L. P. Wilding. "Soils of the lowland forests of West and Central Africa." Proceedings of the Royal Society of Edinburgh. Section B. Biological Sciences 104 (1996): 15–29. http://dx.doi.org/10.1017/s0269727000006102.
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The forest zone of West and Central Africa comprises the coastal and adjacent inland regions bounded the semi-deciduous forests in the west and the equatorial forests in central Africa and the Congo basin. Sedimentary plains, developed mostly on weathered sandy materials, lie along the coastal stretches and cover vast areas of the Congo basin. Behind the coast the plain rises gradually to hills and plateaus of much lower elevation than those of the highlands of East Africa. Two great rivers, the Niger and the Congo, which discharge huge volumes of fresh water to the Atlantic Ocean, are major contributors to the hydrological cycles of the rain forests ecosystems of the Guinea–Congo Region. The Niger originates from the forested highlands of Guinea and discharges its waters into the Bight of Benin by way of a large delta in southern Nigeria. The Congo basin occupies an immense area of 750 000 km2, surrounded by Pre-Cambrian uplands. The alluvial floor of the saucer-shaped basin is flat, and marshes and swamps comprise a large proportion of the total area. The highlands and plateaus along the rim are low to the west and north and higher to the south. To the east, they merge with the mountains of the Great Rift Valley of East Africa (Gann & Duignan 1972; Hance 1975; Grove 1978; Hamilton 1989).
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Wiegemann, Maja. "Wild cyprids metamorphosing in vitro reveal the presence of Balanus amphitrite Darwin, 1854 in the German Bight basin." Aquatic Invasions 3, no. 2 (June 2008): 235–38. http://dx.doi.org/10.3391/ai.2008.3.2.14.
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Wainman, Carmine C., Gabriel Tagliaro, and Peter J. McCabe. "New insights on the Upper Cretaceous Tiger Supersequence of the Bight Basin from International Ocean Discovery Hole U1512." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–2. http://dx.doi.org/10.1080/22020586.2019.12073023.
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ROOS, P. C., and H. M. SCHUTTELAARS. "Horizontally viscous effects in a tidal basin: extending Taylor's problem." Journal of Fluid Mechanics 640 (October 27, 2009): 421–39. http://dx.doi.org/10.1017/s0022112009991327.
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The classical problem of Taylor (Proc. Lond. Math. Soc., vol. 20, 1921, pp. 148–181) of Kelvin wave reflection in a semi-enclosed rectangular basin of uniform depth is extended to account for horizontally viscous effects. To this end, we add horizontally viscous terms to the hydrodynamic model (linearized depth-averaged shallow-water equations on a rotating plane, including bottom friction) and introduce a no-slip condition at the closed boundaries.In a straight channel of infinite length, we obtain three types of wave solutions (normal modes). The first two wave types are viscous Kelvin and Poincaré modes. Compared to their inviscid counterparts, they display longitudinal boundary layers and a slight decrease in the characteristic length scales (wavelength or along-channel decay distance). For each viscous Poincaré mode, we additionally find a new mode with a nearly similar lateral structure. This third type, entirely due to viscous effects, represents evanescent waves with an along-channel decay distance bounded by the boundary-layer thickness.The solution to the viscous Taylor problem is then written as a superposition of these normal modes: an incoming Kelvin wave and a truncated sum of reflected modes. To satisfy no slip at the lateral boundary, we apply a Galerkin method. The solution displays boundary layers, the lateral one at the basin's closed end being created by the (new) modes of the third type. Amphidromic points, in the inviscid and frictionless case located on the centreline of the basin, are now found on a line making a small angle to the longitudinal direction. Using parameter values representative for the Southern Bight of the North Sea, we finally compare the modelled and observed tide propagation in this basin.
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Edwards, D. S., H. I. M. Struckmeyer, M. T. Bradshaw, and J. E. Skinner. "GEOCHEMICAL CHARACTERISTICS OF AUSTRALIA'S SOUTHERN MARGIN PETROLEUM SYSTEMS." APPEA Journal 39, no. 1 (1999): 297. http://dx.doi.org/10.1071/aj98017.
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The hydrocarbons discovered to date on the southern margin of Australia have been assigned to the Austral Petroleum Supersystem based on the age of their source rocks and common tectonic history. Modelling of the source facies distribution within this supersystem using tectonic, climatic and geographic history of the southern margin basins, suggests the presence of a variety of source rocks deposited in saline playa lakes, fluvial, lacustrine, deltaic and anoxic marine environments.Testing of the palaeogeographic model using geochemical characteristics of liquid hydrocarbons confirms the three-fold subdivision (Al, A2 and A3) of the Austral Petroleum Supersystem.Bass Basin oils are assigned to the Austral 3, Eastern View Petroleum System. The presence of oleanane in the biomarker assemblages of these oils, together with their negatively sloping, heavy, isotopic profiles, indicate derivation from Upper Cretaceous-Tertiary fluvio–deltaic source facies.In the eastern Otway Basin, oils of the Austral 2, Eumeralla Petroleum System are sourced by Lower Cretaceous (Aptian–Albian) coaly facies. Oil shows reservoired in the Wigunda Formation at Greenly-1 in the Duntroon Basin are possibly sourced from the Borda Formation and are assigned to the Austral 2, Borda Petroleum System.In the western Otway, Duntroon and Bight basins, a lack of definitive oil-source rock correlations precludes the identification of individual Austral 1 petroleum systems.