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Published: 10 December 2022

Last updated: 29 January 2023

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1

Carr, Lidena, Russell Korsch, and Tehani Palu. "Australia's onshore basin inventory: volume I." APPEA Journal 56, no. 2 (2016): 591. http://dx.doi.org/10.1071/aj15097.

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Following the publication of Geoscience Australia Record 2014/09: Petroleum geology inventory of Australia’s offshore frontier basins by Totterdell et al (2014), the onshore petroleum section of Geoscience Australia embarked on a similar project for the onshore Australian basins. Volume I of this publication series contains inventories of the McArthur, South Nicholson, Georgina, Amadeus, Warburton, Wiso, Galilee, and Cooper basins. A comprehensive review of the geology, petroleum systems, exploration status, and data coverage for these eight Australian onshore basins was conducted, based on the results of Geoscience Australia’s precompetitive data programs, industry exploration results, and the geoscience literature. A petroleum prospectivity ranking was assigned to each basin, based on evidence for the existence of an active petroleum system. The availability of data and level of knowledge in each area was reflected in a confidence rating for that ranking. This extended abstract summarises the rankings assigned to each of these eight basins, and describes the type of information available for each of these basins in the publically available report by Carr et al (2016), available on the Geoscience Australia website. The record allocated a high prospectivity rating for the Amadeus and Cooper basins, a moderate rating for the Galilee, McArthur and Georgina basins, and a low rating for the South Nicholson, Warburton and Wiso basins. The record lists how best to access data for each basin, provides an assessment of issues and unanswered questions, and recommends future work directions to lessen the risk of these basins in terms of their petroleum prospectivity. Work is in progress to compile inventories on the next series of onshore basins.

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Falvey, D. A., P. A. Symonds, J. B. Colwell, J. B. Willcox, J. F. Marshall, P. E. Williamson, and H. M. J. Stagg. "AUSTRALIA'S DEEPWATER FRONTIER PETROLEUM BASINS AND PLAY TYPES." APPEA Journal 30, no. 1 (1990): 239. http://dx.doi.org/10.1071/aj89015.

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Vast areas of Australia's continental margin sedimentary basins lying seawards of the 200 m water depth line, or shelf edge, are under-explored for petroleum. Indeed, most are essentially unexplored. However, recent advances in drilling and production technology, as well as recent reconnaissance seismic, geochemical, geothermal and seabed sampling data collected by the Bureau of Mineral Resources' (BMR) Marine Division, may reduce the perceived economic risk of many of these deepwater basins relative to their shelf counterparts. Triassic reefs have been identified off the northern Exmouth Plateau and possibly in the deepwater Canning Basin, locally within a predicted oil window. In the deepwater North Perth Basin, major wrench structures have been identified. The deepwater areas of the Great Australian Bight and Otway Basin are actually the main depocentres of a major basin complex lying along the almost totally unexplored southern Australian continental margin. The Latrobe Group in the outer Gippsland Basin is likely to have similar geology to the well explored and productive shelf basin, but remains untested. The Queensland and Townsville troughs, in deepwater off northeast Australia, contain many significant structures typical of unbreached rift systems.All these areas have been risked relative to each other and their prospectivity assessed. The most attractive frontier areas in terms of relative risk may be the Otway and North Perth basins. The highest potential may occur in the deepwater rift troughs off northeast Australia, although the relative risk is very high. Triassic reefs of the Northwest Shelf may have the best prospectivity in the shorter term, given that they are known from drilling in a region with proven source potential and a substantial exploration infrastructure.

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Salmachi, Alireza, Mojtaba Rajabi, Carmine Wainman, Steven Mackie, Peter McCabe, Bronwyn Camac, and Christopher Clarkson. "History, Geology, In Situ Stress Pattern, Gas Content and Permeability of Coal Seam Gas Basins in Australia: A Review." Energies 14, no. 9 (May 5, 2021): 2651. http://dx.doi.org/10.3390/en14092651.

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Coal seam gas (CSG), also known as coalbed methane (CBM), is an important source of gas supply to the liquefied natural gas (LNG) exporting facilities in eastern Australia and to the Australian domestic market. In late 2018, Australia became the largest exporter of LNG in the world. 29% of the country’s LNG nameplate capacity is in three east coast facilities that are supplied primarily by coal seam gas. Six geological basins including Bowen, Sydney, Gunnedah, Surat, Cooper and Gloucester host the majority of CSG resources in Australia. The Bowen and Surat basins contain an estimated 40Tcf of CSG whereas other basins contain relatively minor accumulations. In the Cooper Basin of South Australia, thick and laterally extensive Permian deep coal seams (>2 km) are currently underdeveloped resources. Since 2013, gas production exclusively from deep coal seams has been tested as a single add-on fracture stimulation in vertical well completions across the Cooper Basin. The rates and reserves achieved since 2013 demonstrate a robust statistical distribution (>130 hydraulic fracture stages), the mean of which, is economically viable. The geological characteristics including coal rank, thickness and hydrogeology as well as the present-day stress pattern create favourable conditions for CSG production. Detailed analyses of high-resolution borehole image log data reveal that there are major perturbations in maximum horizontal stress (SHmax) orientation, both spatially and with depth in Australian CSG basins, which is critical in hydraulic fracture stimulation and geomechanical modelling. Within a basin, significant variability in gas content and permeability may be observed with depth. The major reasons for such variabilities are coal rank, sealing capacity of overlying formations, measurement methods, thermal effects of magmatic intrusions, geological structures and stress regime. Field studies in Australia show permeability may enhance throughout depletion in CSG fields and the functional form of permeability versus reservoir pressure is exponential, consistent with observations in North American CSG fields.

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Hashimoto, Takehiko, Karen Higgins, Nadege Rollet, Vaughan Stagpoole, Peter Petkovic, Jim Colwell, Ron Hackney, Graham Logan, R. Funnell, and George Bernardel. "Geology and prospectivity of the Capel and Faust basins in the deepwater Tasman Sea region." APPEA Journal 51, no. 2 (2011): 702. http://dx.doi.org/10.1071/aj10082.

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Geoscience Australia recently completed a petroleum prospectivity assessment of the Capel and Faust basins as part of the Australian government's energy security program. This pre-competitive study was carried out in collaboration with GNS Science and the government of New Caledonian, and was based on seismic, potential field, multibeam bathymetry and sample data acquired during marine surveys in 2006–7. The Capel and Faust basins are located in the Tasman Sea region, which contains a number of deepwater basins. There is little information about their geology. The Geoscience Australia study confirmed the existence of large compartmentalised depocentres containing sediments up to 6 km thick. The basins formed during two Cretaceous extensional episodes related to the final breakup of eastern Gondwana. Syn-rift deposition appears to have been initially dominated by volcanics and volcaniclastics, then dominated by non-marine to shallow marine clastics. The post-rift succession comprises upward-fining clastic to calcareous bathyal sediments. A pre-rift (?Mesozoic) sedimentary succession appears to underlie some depocentres. Mesozoic successions in nearby eastern Australian and New Zealand basins suggest that fluvio-deltaic potential source rocks (Triassic/Jurassic to Upper Cretaceous coals) may occur in the pre-rift and syn-rift successions of the Capel and Faust basins. Multi-1D basin modelling suggests that the deeper depocentres are presently within the oil or gas generation window and that expulsion occurred from the Early Cretaceous. Fluvio-deltaic, shoreline and turbiditic sandstones may provide potential reservoirs. Likely play types include large anticlines, fault blocks, unconformities, and stratigraphic pinchouts. The results will guide future exploration and reduce risk in this vast frontier region.

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Krapez, B., and M. E. Barley. "Archaean strike-slip faulting and related ensialic basins: evidence from the Pilbara Block, Australia." Geological Magazine 124, no. 6 (November 1987): 555–67. http://dx.doi.org/10.1017/s0016756800017386.

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AbstractArchaean sedimentary and volcanic successions in the Lalla Rookh Basin andc. 2950 Ma old Whim Creek Belt in the Pilbara Block, Western Australia, were deposited in basins with roughly the same configuration as their present outcrop. Basins were fault-bounded and developed in an ensialic setting, overlying older (3500 to 3300 Ma old); deformed and metamorphosed supracrustal rocks and granitoids. The basin margin faults are now part of a pattern of strike–slip faults which were active during the later stages of regional batholith emplacement. In both cases, structural patterns and style of basin filling are similar to younger basins related to strike–slip faulting. The Lalla Rookh Basin was dominated by coarse clastic sedimentation, comprising alluvial–fan, braided–stream, fan–delta and lacustrine facies. The Whim Creek Belt contains bimodal volcanics and clastic sediments, which comprise alluvial, subaqueous fanglomerate, submarine-fan and basinal facies. Regional strike–slip faulting and the development of the Lalla Rookh Basin and Whim Creek Belt, in response to externally imposed deformation, records an important step in the cratonization of the Pilbara Block. Late Archaean sedimentary basins, dominated by coarse clastic facies and situated adjacent to major strike–slip faults, in other cratons may have a similar origin.

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Stacey, Andrew, Cameron Mitchell, Goutam Nayak, Heike Struckmeyer, Michael Morse, Jennie Totterdell, and George Gibson. "Geology and petroleum prospectivity of the deepwater Otway and Sorell basins: new insights from an integrated regional study." APPEA Journal 51, no. 2 (2011): 692. http://dx.doi.org/10.1071/aj10072.

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The frontier deepwater Otway and Sorell basins lie offshore of southwestern Victoria and western Tasmania at the eastern end of Australia’s Southern Rift System. The basins developed during rifting and continental separation between Australia and Antarctica from the Cretaceous to Cenozoic. The complex structural and depositional history of the basins reflects their location in the transition from an orthogonal–obliquely rifted continental margin (western–central Otway Basin) to a transform continental margin (southern Sorell Basin). Despite good 2D seismic data coverage, these basins remain relatively untested and their prospectivity poorly understood. The deepwater (> 500 m) section of the Otway Basin has been tested by two wells, of which Somerset–1 recorded minor gas shows. Three wells have been drilled in the Sorell Basin, where minor oil shows were recorded near the base of Cape Sorell–1. As part of the federal government-funded Offshore Energy Security Program, Geoscience Australia has acquired new aeromagnetic data and used open file seismic datasets to carry out an integrated regional study of the deepwater Otway and Sorell basins. Structural interpretation of the new aeromagnetic data and potential field modelling provide new insights into the basement architecture and tectonic history, and highlights the role of pre-existing structural fabric in controlling the evolution of the basins. Regional scale mapping of key sequence stratigraphic surfaces across the basins, integration of the regional structural analysis, and petroleum systems modelling have resulted in a clearer understanding of the tectonostratigraphic evolution and petroleum prospectivity of this complex basin system.

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Townson, W. G. "THE SUBSURFACE GEOLOGY OF THE WESTERN OFFICER BASIN — RESULTS OF SHELL'S 1980-1984 PETROLEUM EXPLORATION CAMPAIGN." APPEA Journal 25, no. 1 (1985): 34. http://dx.doi.org/10.1071/aj84003.

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The Officer Basin described in this paper includes four Proterozoic to Lower Palaeozoic sub-basins (Gibson, Yowalga, Lennis, Waigen) which extend in a northwest to southeast belt across 200 000 sq. km of central Western Australia. These sub-basins are bounded by Archaean to Proterozoic basement blocks and are almost entirely concealed by a veneer of Permian and Cretaceous sediments. Depth to magnetic basement locally exceeds eight kilometres.Until recently, information on the sub-surface geology was limited to shallow levels, based on the results of a petroleum exploration campaign in the 1960s and the work of State and Federal Geological Surveys. In 1980, the Shell Company of Australia was awarded three permits (46 200 sq. km) covering the Yowalga and Lennis Sub-basins. The results of 4700 km of seismic data and three deep wildcat wells, combined with gravity, aeromagnetic, Landsat, outcrop and corehole information, has led to a better understanding of the regional subsurface geology.The Lennis Sub-basin appears to contain Lower to Middle Proterozoic sediments, whereas the Yowalga Sub- basin is primarily an Upper Proterozoic to Lower Cambrian sequence which comprises a basal clastic section, a middle carbonate and evaporite sequence and an upper clastic section. Widespread Middle Cambrian basalts cap the Upper Proterozoic to Lower Cambrian prospective sequence. Late Proterozoic uplift resulted in salt- assisted gravity tectonics leading to complex structural styles, especially in the basin axis.Despite oil shows, organic matter in the oil and gas generation windows and reservoir-quality sandstones with interbedded shales, no convincing source rocks or hydrocarbon accumulations have yet been located. The area remains, however, one of the least explored basins in Australia.

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Mcnamara, Kenneth, and Frances Dodds. "The Early History of Palaeontology in Western Australia: 1791-1899." Earth Sciences History 5, no. 1 (January 1, 1986): 24–38. http://dx.doi.org/10.17704/eshi.5.1.t85384660311h176.

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The exploration of the coast of Western Australia by English and French explorers in the late eighteenth and early nineteenth centuries led to the first recorded discoveries of fossiliferous rocks in Western Australia. The first forty years of exploration and discovery of fossil sites in the State was restricted entirely to the coast of the Continent. Following the establishment of permanent settlements in the 1820s the first of the inland fossil localities were located in the 1830s, north of Albany, and north of Perth. As new land was surveyed; particularly north of Perth, principally by the Gregory brothers in the 1840s and 1850s, Palaeozoic rocks were discovered in the Perth and Carnarvon Basins. F.T. Gregory in particular developed a keen interest in the geology of the State to such an extent that he was able, at a meeting of the Geological Society of London in 1861, to present not only a geological map of part of the State, but also a suite of fossils which showed the existence of Permian and Hesozoic strata. The entire history of nineteenth century palaeontology in Western Australia was one of discovery and collection of specimens. These were studied initially by overseas naturalists, but latterly, in the 1890s by Etheridge at The Australian Museum in Sydney. Sufficient specimens had been collected and described by the turn of the century that the basic outline of the Phanerozoic geology of the sedimentary basins was reasonably well known.

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Nicholson, Chris, Edward Bowen, George Bernardel, Barry Bradshaw, Irina Borissova, and Diane Jorgensen. "New geophysical and geological results in frontier basins along the southwest Australian continental margin." APPEA Journal 49, no. 2 (2009): 587. http://dx.doi.org/10.1071/aj08060.

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Under the Australian Government’s Energy Security Program, Geoscience Australia is conducting a seismic survey and a marine reconnaissance survey to acquire new geophysical data and obtain geological samples in frontier basins along the southwest Australian continental margin. Specific areas of interest include the Mentelle Basin, northern Perth Basin, Wallaby Plateau and the southern Carnarvon Basin. The regional seismic survey will acquire 8,000–10,000 km of industry-standard 2D reflection seismic data using an 8 km solid streamer and a 12 second record length, together with gravity and magnetic data. These new geophysical datasets, together with over 7,000 km of reprocessed open-file seismic, will facilitate more detailed mapping of the regional geology, determination of total sediment thickness, interpretation of the nature and thickness of crust beneath the major depocentres, modelling of the tectonic evolution and an assessment of the petroleum prospectivity of frontier basins along the southwest margin. The overall scientific aim of the marine survey is to collect swath bathymetry, potential field data, geological samples and biophysical data. Together with the new seismic data, samples recovered from frontier basins will assist in understanding the geological setting and petroleum prospectivity of these little known areas. Preliminary results from both surveys will be presented for the first time at this conference.

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de Vries, Sjoukje T., Lynn L. Pryer, and Nicola Fry. "Evolution of Neoarchaean and Proterozoic basins of Australia." Precambrian Research 166, no. 1-4 (October 2008): 39–53. http://dx.doi.org/10.1016/j.precamres.2008.01.005.

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Mai, P. S. Moore D. K. Hobday H., and Z. C. Sun. "COMPARISON OF SELECTED NON-MARINE PETROLEUM-BEARING BASINS IN AUSTRALIA AND CHINA." APPEA Journal 26, no. 1 (1986): 285. http://dx.doi.org/10.1071/aj85026.

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This paper summarises the geology and hydrocarbon potential of two Chinese and two Australian basins (Ordos, Northern Jiangsu, Eromanga, and Surat basins) in order to compare factors affecting the generation, migration, and entrapment of hydrocarbons. In all four basins, hydrocarbons are generated from nonmarine source rocks of lacustrine and fluvial-overbank origin. While the Chinese and Australian basins contain a similar range of sedimentary facies, from alluvial fan to lacustrine, the arrangement and relative thicknesses of these facies vary considerably as a result of different tectonic and palaeoclimatic settings.During the Triassic, the Ordos Basin was dominated by retroarc foredeep subsidence and the development of deep, fresh-water lakes with anoxic bottom waters. This non-bioturbated substrate, with Type I and II kerogen precursors, provided an excellent oil source for adjacent fan-delta, deltaic, and fluvial reservoirs, and for the unconformably overlying Jurassic fluvial valley-fill sandstone reservoirs.The Northern Jiangsu Basin was initiated by back-arc extension and underwent very rapid half-graben subsidence in the Eocene. Alluvial fan, shoreline, and fluvial facies aggraded in a relatively narrow zone along the active, faulted margin, and merged laterally into organic-rich shales which provided a local source for oil.By comparison, the Eromanga/Surat basins developed in response to gentle downwarp and reactivation of older structural trends. Reservoirs are largely restricted to craton-derived quartzose facies such as in the Hutton, Precipice, and Namur sandstones. There is probably a dual source for oil, from the underlying Permian (which may be the dominant source in the Surat Basin), and from shales deposited in shallow, partly oxygenated lakes and overbank facies of Jurassic age (important in the Eromanga, and possibly subordinate in the Surat Basin). Deep lacustrine facies, typical of the Chinese basins, did not develop. The greater abundance of oil in the Chinese nonmarine basins is explained in terms of tectonic and palaeoclimatic factors which yielded thicker and better quality source rocks, more rapid maturation, and a better juxtaposition of source rocks and good-quality reservoirs, thus providing short, highly efficient migration routes.

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Sun, Xiaowen. "Structural Style of the Warburton Basin and Control in the Cooper and Eromanga Basins, South Australia." Exploration Geophysics 28, no. 3 (June 1997): 333–39. http://dx.doi.org/10.1071/eg997333.

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Cook, R. A., E. M. Crouch, J. I. Raine, C. P. Strong, C. I. Uruski, and G. J. Wilson. "INITIAL REVIEW OF THE BIOSTRATIGRAPHY AND PETROLEUM SYSTEMS AROUND THE TASMAN SEA HYDROCARBON-PRODUCING BASINS." APPEA Journal 46, no. 1 (2006): 201. http://dx.doi.org/10.1071/aj05012.

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Understanding the genesis and habitat of hydrocarbons in a sedimentary basin takes knowledge of that basin at many levels, from basic infill geology to petroleum systems, plays, prospects and detailed sequence stratigraphy. While geophysics can define the basins and their internal structures, biostratigraphy and paleogeography provide greater understanding of basin geology. Micropaleontology and palynology are the chief tools that we need to define both the environment and dimension of time.As an example, the reconstruction of the Tasman Sea region to the mid-Cretaceous (ca 120 Ma) shows that the hydrocarbon-producing Gippsland and Taranaki petroleum basins developed at similar latitudes and in similar geological contexts. Other basins within the region have been lightly explored and need evaluation as to the value of further exploration.As paleontology has developed separately in Australia and New Zealand, comparison of biostratigraphic zones and their chronostratigraphy is critical to understand the similarity or otherwise of the sedimentary record of the two regions. Recent refinement of the NZ timescale and comparative studies on Gippsland Basin wells by NZ paleontologists have provided some key insights that enable us to compare the geological history of both regions more closely, and to recognise similarities in petroleum systems that may enhance petroleum prospects on both sides of the Tasman Sea.

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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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Pirajno, F., J. A. Jones, R. M. Hocking, and J. Halilovic. "Geology and tectonic evolution of Palaeoproterozoic basins of the eastern Capricorn Orogen, Western Australia." Precambrian Research 128, no. 3-4 (January 2004): 315–42. http://dx.doi.org/10.1016/j.precamres.2003.09.006.

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Lindsay, John F. "Supersequences, superbasins, supercontinents - evidence from the Neoproterozoic-Early Palaeozoic basins of central Australia." Basin Research 14, no. 2 (June 2002): 207–23. http://dx.doi.org/10.1046/j.1365-2117.2002.00170.x.

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Bernecker, Thomas, George Bernardel, Claire Orlov, and Nadège Rollet. "Petroleum geology of the 2018 offshore acreage release areas." APPEA Journal 58, no. 2 (2018): 437. http://dx.doi.org/10.1071/aj17056.

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A total of 21 areas were released in 2018 for offshore petroleum exploration. They are located in the Bonaparte, Browse, Northern Carnarvon, Bight, Otway and Gippsland basins. All release areas were supported by industry nominations, indicating that interest in exploring Australia’s offshore basins remains strong, despite the significant decrease in the number of exploration wells drilled in recent years. Sixteen areas are being released under the work program bidding system with two rounds, one closing on 18 October 2018 and the other on 21 March 2019. Five areas are being released for cash bidding and include the producible La Bella gas accumulation in the Otway Basin. Prequalification for participation in the cash-bid auction closes on 4 October 2018 with the auction scheduled for 7 February 2019. 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. The regional evaluation of the petroleum systems in the Browse Basin has been completed and work continues on assessing the distribution of Early Triassic source rocks and related petroleum occurrences across the North West Shelf. A wealth of seismic and well data, submitted under the Offshore Petroleum and Greenhouse Gas Storage Act 2006, are made available through the National Offshore Petroleum Information Management System. Additional datasets are accessible through Geoscience Australia’s data repository.

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Yang, Ang, Geoff Podger, Shane Seaton, and Robert Power. "A river system modelling platform for Murray-Darling Basin, Australia." Journal of Hydroinformatics 15, no. 4 (March 29, 2012): 1109–20. http://dx.doi.org/10.2166/hydro.2012.153.

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Global climate change and local development make water supply one of the most vulnerable sectors in Australia. The Australian government has therefore commissioned a series of projects to evaluate water availability and the sustainable use of water resources in Australia. This paper discusses a river system modelling platform that has been used in some of these nationally significant projects. The platform consists of three components: provenance, modelling engine and reporting database. The core component is the modelling engine, an agent-based hydrological simulation system called the Integrated River System Modelling Framework (IRSMF). All configuration information and inputs to IRSMF are recorded in the provenance component so that modelling processes can be reproduced and results audited. The reporting database is used to store key statistics and raw output time series data for selected key parameters. This river system modelling platform has for the first time modelled a river system at the basin level in Australia. It provides practitioners with a unique understanding of the characteristics and emergent behaviours of river systems at the basin level. Although the platform is purpose-built for the Murray-Darling Basin, it would be easy to apply it to other basins by using different river models to model agent behaviours.

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Phythian, Paul, Steve Hearn, and Natasha Hendrick. "Spectral characterisation of reflectivity sequences in the Amadeus, Surat and Bowen Basins, Australia." Exploration Geophysics 26, no. 2-3 (June 1, 1995): 497–505. http://dx.doi.org/10.1071/eg995497.

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Whiteway, Tanya, Andrew Heap, Tara Anderson, and Rachel Przeslawski. "Marine mapping survey reveals broad-scale seabed environments of remote offshore basins in Western Australia." APPEA Journal 50, no. 2 (2010): 730. http://dx.doi.org/10.1071/aj09094.

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Between October 2008 and January 2009, Geoscience Australia conducted a marine mapping survey to document the seabed environments and subsurface geology of the Zeewyck, Houtman, Exmouth sub-basins and the deep-water Wallaby (Cuvier) Plateau, Western Australia. The seabed mapping survey, the second and largest mapping survey of the Federal Government’s Offshore Energy Security Program, documented seabed environments and biota from multibeam sonar and sub-bottom profiler data, towed video footage and physical samples. Preliminary analysis of the data indicates that for all of the sub-basins the seabed is comprised of carbonate mud that supports relatively sparse infaunal populations. Rocky substrates, principally in the numerous submarine canyons, supported sparse communities of sessile organisms. Interestingly, some of these hard-grounds were associated with volcanic (basaltic) peaks on the upper slope that attain 200 metres above the surrounding seabed. Data collected from the survey are being analysed in conjunction with existing environmental data to establish a series of environmental summaries that describe the key seabed habitats and biota for the offshore basins. The environmental summaries are being made available to support future acreage release in the sub-basins. The marine mapping survey was run in combination with a regional 2D seismic survey of the same offshore basins, also completed as part of the Offshore Energy Security Program.

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Mavromatidis, Angelos. "Burial/exhumation histories for the Cooper-Eromanga Basins and implications for hydrocarbon exploration, Eastern Australia." Basin Research 18, no. 3 (August 15, 2006): 351–73. http://dx.doi.org/10.1111/j.1365-2117.2006.00294.x.

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Shaanan, Uri, and Gideon Rosenbaum. "Detrital zircons as palaeodrainage indicators: insights into southeastern Gondwana from Permian basins in eastern Australia." Basin Research 30 (June 2, 2016): 36–47. http://dx.doi.org/10.1111/bre.12204.

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Haworth, Jeffrey, and Richard Bruce. "Australian states and Northern Territory acreage update." APPEA Journal 54, no. 1 (2014): 421. http://dx.doi.org/10.1071/aj13042.

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It is encouraging to note that a number of international oil companies (IOCs) have taken an interest in Australian onshore exploration, including the following: Bowen-Surat Basin—BG, ConocoPhillips, CNOOC, PetroChina, Sinopec, KOGAS, Mitsui, Petronas, Shell, and Total.Canning Basin—Mitsubishi, ConocoPhillips, Hess, PetroChina, and Apache.Cooper-Eromanga Basin—BG, and Chevron.Galilee Basin—CNOOC.Georgina Basin—Statoil, and Total. There is now greater interest in Australian onshore exploration, including in a number of sedimentary basins that have previously largely been overlooked. New views on geology and the development of a commercial shale and tight gas sector in the US have prompted a reassessment of onshore petroleum potential, especially in SA, the NT and WA. Access to onshore acreage in Australia for petroleum exploration is, in most jurisdictions, by means of a formal release process with a work program bidding system. Acreage that is being made available for exploration will generally be accompanied by information regarding its geological setting and petroleum prospectivity. Previous exploration activity may be summarised (including information in relation to the amount of pre-existing data available to applicants for acreage), and relevant maps and figures may be included. The following is a compilation of material supplied by the states and NT in relation to onshore acreage being made available for petroleum exploration.

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Watson, Douglas, Simon Holford, Nick Schofield, and Niall Mark. "Failure to predict igneous rocks encountered during exploration of sedimentary basins: A case study of the Bass Basin, Southeastern Australia." Marine and Petroleum Geology 99 (January 2019): 526–47. http://dx.doi.org/10.1016/j.marpetgeo.2018.10.034.

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Lambourne, A. N., B. J. Evans, and P. J. Hatherly. "The application of the 3D seismic surveying technique to coal seam imaging: case histories from the Arckaringa and Sydney basins." Exploration Geophysics 20, no. 2 (1989): 137. http://dx.doi.org/10.1071/eg989137.

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Two dimensional seismic surveying is commonly used in the coal mining industry to assist the mining and development of coal deposits by seismically imaging coal seams. A specialised three dimensional seismic surveying technique has recently been performed over coal mining leases in South Australia and New South Wales, to trial its applicability to coal mine planning and extraction operations.The first two case histories of its trial in Australia are presented, and the conclusion drawn that the specialised three dimensional technique developed to date offers the ability to image coal seams in three dimensions and thereby improve mine planning in regions of complex faulting.

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Glen, R. A. "Formation and inversion of transtensional basins in the western part of the Lachlan Fold Belt, Australia, with emphasis on the Cobar Basin." Journal of Structural Geology 12, no. 5-6 (January 1990): 601–20. http://dx.doi.org/10.1016/0191-8141(90)90077-c.

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27

McLaren, Sandra, Mike Sandiford, and Roger Powell. "Contrasting styles of Proterozoic crustal evolution: A hot-plate tectonic model for Australian terranes." Geology 33, no. 8 (August 1, 2005): 673–76. http://dx.doi.org/10.1130/g21544ar.1.

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Abstract Proterozoic terranes in Australia record complex tectonic histories in the interval 1900– 1400 Ma that have previously been interpreted by means of simple intracratonic or plate-tectonic models. However, these models do not fully account for (1) repeated tectonic reactivation (both orogenesis and rifting), (2) mainly high-temperature–low-pressure metamorphism, (3) rifting and sag creating thick sedimentary basins, (4) the nature and timing of voluminous felsic magmatism, (5) relatively large aspect ratio orogenic belts, and (6) a general paucity of diagnostic plate-boundary features. A key to understanding these histories is the observation that Australian Proterozoic terranes are characterized by an extraordinary, but heterogeneous, enrichment of the heat-producing elements. This enrichment must contribute to long-term lithospheric weakening, and thus we advocate a hybrid lithospheric evolution model with two tectonic switches: plate-boundary–derived stresses and heat-producing-element–related lithospheric weakening. The Australian Proterozoic crustal growth record is therefore a function of the magnitude of these stresses, the way in which the heat-producing elements are distributed, and how both of these change with time.

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Krapež, Bryan, Mark E. Barley, and Stuart J. A. Brown. "Late Archaean synorogenic basins of the Eastern Goldfields Superterrane, Yilgarn Craton, Western Australia." Precambrian Research 161, no. 1-2 (February 2008): 135–53. http://dx.doi.org/10.1016/j.precamres.2007.06.016.

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Krapež, Bryan, Jon G. Standing, Stuart J. A. Brown, and Mark E. Barley. "Late Archaean synorogenic basins of the Eastern Goldfields Superterrane, Yilgarn Craton, Western Australia." Precambrian Research 161, no. 1-2 (February 2008): 154–82. http://dx.doi.org/10.1016/j.precamres.2007.06.017.

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30

Krapež, Bryan, and Mark E. Barley. "Late Archaean synorogenic basins of the Eastern Goldfields Superterrane, Yilgarn Craton, Western Australia." Precambrian Research 161, no. 1-2 (February 2008): 183–99. http://dx.doi.org/10.1016/j.precamres.2007.06.020.

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31

Uysal, I. Tonguç, Claudio Delle Piane, Andrew James Todd, and Horst Zwingmann. "Precambrian faulting episodes and insights into the tectonothermal history of north Australia: microstructural evidence and K–Ar, <sup>40</sup>Ar–<sup>39</sup>Ar, and Rb–Sr dating of syntectonic illite from the intracratonic Millungera Basin." Solid Earth 11, no. 5 (September 4, 2020): 1653–79. http://dx.doi.org/10.5194/se-11-1653-2020.

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Abstract. Australian terranes concealed beneath Mesozoic cover record complex Precambrian tectonic histories involving a successive development of several Proterozoic to Palaeozoic orogenic systems. This study presents an integrated approach combining K–Ar, 40Ar–39Ar, and Rb–Sr geochronologies of Precambrian authigenic illites from the recently discovered Millungera Basin in north-central Australia. Brittle deformation and repeated fault activity are evident from the sampled cores and their microstructures, probably associated with the large-scale faults inferred from interpretations of seismic surveys. Rb–Sr isochron, 40Ar–39Ar total gas, and K–Ar ages are largely consistent in indicating late Mesoproterozoic and early Proterozoic episodes (∼1115±26, ∼ 1070±25, ∼1040±24, ∼1000±23, and ∼905±21 Ma) of active tectonics in north-central Australia. K–Ar results show that illites from fault gouges and authigenic matrix illites in undeformed adjacent sandstones precipitated contemporaneously, indicating that advection of tectonically mobilized fluids extended into the undeformed wall rocks above or below the fracture and shear (fault gouge) zones. Isotopic age data clearly indicate a Mesoproterozoic minimum age for the Millungera Basin and thus previously unrecorded late Mesoproterozoic–early Neoproterozoic tectonic events in north-central Australia. This study provides insight into the enigmatic time–space distribution of Precambrian tectonic zones in central Australia, which are responsible for the formation of a number of sedimentary basins with significant energy and mineral resources.

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Foley, Elliot K., Eric M. Roberts, and Espen M. Knutsen. "Deciphering Late Cretaceous palaeo‐river catchments in eastern Australia: Recognition of distinct northern and southern drainage basins." Basin Research 34, no. 2 (November 17, 2021): 590–617. http://dx.doi.org/10.1111/bre.12632.

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33

Mazumder, Rajat. "A tale of two basins? Stratigraphy and detrital zircon provenance of the Paleoproterozoic Turee Creek and Horseshoe basins of Western Australia: Discussion." Precambrian Research 298 (September 2017): 462–71. http://dx.doi.org/10.1016/j.precamres.2017.06.026.

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34

NEUMANN, N., P. SOUTHGATE, and G. GIBSON. "Defining unconformities in Proterozoic sedimentary basins using detrital geochronology and basin analysis—An example from the Mount Isa Inlier, Australia." Precambrian Research 168, no. 3-4 (February 2009): 149–66. http://dx.doi.org/10.1016/j.precamres.2008.09.012.

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35

Thomas, B. M. "IN FOR THE LONG HAUL - 50 YEARS OF SHELL EXPLORATION IN AUSTRALIA." APPEA Journal 30, no. 1 (1990): 437. http://dx.doi.org/10.1071/aj89032.

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On 27th November, 1939 Shell was awarded its first exploration concession in Australia. The initial holdings covered much of southern Queensland, including parts of the Eromanga, Surat and Bowen Basins. An exploration programme involving field geology, aerial photography, a gravity survey and shallow structural drilling preceded a 'deep test' in 1950, Morella-1, located in the Denison Trough near Springsure. In the course of the venture, Shell was responsible for the first effective application of several modern techniques to petroleum exploration in Australia, including geophysics, organic geochemistry and wireline logging. Although disappointing results led to relinquishment of this first area, Shell has continued to explore in Australia, initially through participation in the WAPET and North West Shelf consortia, and from 1962 in a series of other ventures throughout the country. The rewards, in terms of Shell equity reserves, total some 1.7 billion barrels of oil equivalent at an exploration cost since 1964 of 1.1 billion dollars (1988 equivalent value).

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McAlpine, Sarlae R. B., Meredith L. Orr, Darren Ferdinando, and Stephen Hostetler. "Trusted environmental and geological information to support Australian energy resource development in a changing world." APPEA Journal 62, no. 2 (May 13, 2022): S321—S326. http://dx.doi.org/10.1071/aj21140.

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The Australian Government’s Trusted Environmental and Geological Information (TEGI) program is a scientific program led by Geoscience Australia. The program is part of the Government’s Strategic Basin Initiative under its Gas-fired Recovery agenda, implemented as a post-COVID19 response to stimulate the economy. This program will deliver regional geological and environmental assessments underpinned by transparent, trusted baseline geological and environmental data, commencing in the north Bowen and Galilee and the Cooper and Adavale Basins. This repository of information is to be used in support of bringing forward energy and mineral developments in basins identified by the Government as strategic. This paper discusses how coupling resource assessments with baseline information such as groundwater, geology, energy and mineral resources, surface water and protected environmental matters, can be used to support exploration and development decisions by industry, regulators and other stakeholders. For example, by establishing a regional baseline resource assessment, through prospectivity play mapping, environmental assessments can be prioritised to match resource prospectivity. In anticipating future development scenarios, potential impacts on environmental assets, including groundwater, can be assessed in advance and with key knowledge gaps identified for redress. This approach aims to optimise the regulatory pathway to resource development and increase regulatory efficiency as future development opportunities arise across the scope of petroleum, minerals, carbon capture and storage, and hydrogen storage and production. An example of Geoscience Australia’s work on the Adavale Basin is presented in this paper describing the first steps in linking energy resources and environmental assessments in a changing world.

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37

Twidale, C. Rowland. "Paul S. Hossfeld and His Contribution to Geomorphology." Historical Records of Australian Science 23, no. 2 (2012): 132. http://dx.doi.org/10.1071/hr12006.

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The received wisdom was and is that landscapes cannot be more than a few millions of years old. Nevertheless, consideration of local geology and age of sediments in adjacent basins convinced Paul S. Hossfeld that the summit surface of low relief preserved on the northern Mount Lofty Ranges of South Australia resulted from long-continued planation and that it is of Cretaceous age; that is, some 70 million years old. Hossfeld's apparently intuitive suggestion that very old landscapes exist, recorded in his graduate thesis but not further pursued by him, is the earliest known statement of this idea.

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38

Yang, Jianwen. "Full 3-D numerical simulation of hydrothermal fluid flow in faulted sedimentary basins: Example of the McArthur Basin, Northern Australia." Journal of Geochemical Exploration 89, no. 1-3 (April 2006): 440–44. http://dx.doi.org/10.1016/j.gexplo.2005.11.080.

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39

Tysoe, Simon, Stuart Barrymore, and David Clinch. "East African gas-impacts for Australian LNG." APPEA Journal 53, no. 2 (2013): 432. http://dx.doi.org/10.1071/aj12043.

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Until recently, East Africa, with its complex geology and seemingly limited prospects, was the poor relation of the hydrocarbon provinces of West Africa. Since 2010, however, a string of successful exploration has resulted in offshore Kenya, Tanzania, and Mozambique, culminating in significant mergers and acquisitions and farming activities. Peter Coleman of Woodside described it as a potential game changer and a significant threat to the Australian LNG market. This extended abstract provides an overview of the basins and the discoveries, concentrating on the two most promising countries: Mozambique and Tanzania. The deals to date and the proposed LNG developments are also discussed. Also discussed is the petroleum regimes in each of these jurisdictions, the deals, the underlying title systems, the absence of regulation, and the key risks for parties transacting in that sector. An overview of applicable taxation regimes is supplied. This extended abstract then considers potential development scenarios and the relative advantages and disadvantages that East Africa has compared with Australia and the degree to which East Africa presents a threat to planned Australian projects. It is self-evident that the absence of infrastructure and modern petroleum systems of regulation challenge investment decisions.

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40

Glen, R. A. "Basement control on the deformation of cover basins: An example from the Cobar district in the Lachlan Fold Belt, Australia." Journal of Structural Geology 7, no. 3-4 (January 1985): 301–15. http://dx.doi.org/10.1016/0191-8141(85)90037-9.

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41

Krapež, Bryan, and April L. Pickard. "Detrital-zircon age-spectra for Late Archaean synorogenic basins of the Eastern Goldfields Superterrane, Western Australia." Precambrian Research 178, no. 1-4 (April 2010): 91–118. http://dx.doi.org/10.1016/j.precamres.2010.01.014.

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42

Uruski, Chris. "Exploring New Zealand's marine territory." APPEA Journal 51, no. 1 (2011): 549. http://dx.doi.org/10.1071/aj10039.

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Around the end of the twentieth century, awareness grew that, in addition to the Taranaki Basin, other unexplored basins in New Zealand’s large exclusive economic zone (EEZ) and extended continental shelf (ECS) may contain petroleum. GNS Science initiated a program to assess the prospectivity of more than 1 million square kilometres of sedimentary basins in New Zealand’s marine territories. The first project in 2001 acquired, with TGS-NOPEC, a 6,200 km reconnaissance 2D seismic survey in deep-water Taranaki. This showed a large Late Cretaceous delta built out into a northwest-trending basin above a thick succession of older rocks. Many deltas around the world are petroleum provinces and the new data showed that the deep-water part of Taranaki Basin may also be prospective. Since the 2001 survey a further 9,000 km of infill 2D seismic data has been acquired and exploration continues. The New Zealand government recognised the potential of its frontier basins and, in 2005 Crown Minerals acquired a 2D survey in the East Coast Basin, North Island. This was followed by surveys in the Great South, Raukumara and Reinga basins. Petroleum Exploration Permits were awarded in most of these and licence rounds in the Northland/Reinga Basin closed recently. New data have since been acquired from the Pegasus, Great South and Canterbury basins. The New Zealand government, through Crown Minerals, funds all or part of a survey. GNS Science interprets the new data set and the data along with reports are packaged for free dissemination prior to a licensing round. The strategy has worked well, as indicated by the entry of ExxonMobil, OMV and Petrobras into New Zealand. Anadarko, another new entry, farmed into the previously licensed Canterbury and deep-water Taranaki basins. One of the main results of the surveys has been to show that geology and prospectivity of New Zealand’s frontier basins may be similar to eastern Australia, as older apparently unmetamophosed successions are preserved. By extrapolating from the results in the Taranaki Basin, ultimate prospectivity is likely to be a resource of some tens of billions of barrels of oil equivalent. New Zealand’s largely submerged continent may yield continent-sized resources.

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43

Flood, P. G., and S. A. Brady. "Origin of large-scale crossbeds in the late permian coal measures of the Sydney and Bowen basins, eastern Australia." International Journal of Coal Geology 5, no. 3 (October 1985): 231–45. http://dx.doi.org/10.1016/0166-5162(85)90026-6.

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44

Griffis, Neil Patrick, Isabel Patricia Montañez, Roland Mundil, Jon Richey, John Isbell, Nick Fedorchuk, Bastien Linol, et al. "Coupled stratigraphic and U-Pb zircon age constraints on the late Paleozoic icehouse-to-greenhouse turnover in south-central Gondwana." Geology 47, no. 12 (October 2, 2019): 1146–50. http://dx.doi.org/10.1130/g46740.1.

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Abstract The demise of the Late Paleozoic Ice Age has been hypothesized as diachronous, occurring first in western South America and progressing eastward across Africa and culminating in Australia over an ∼60 m.y. period, suggesting tectonic forcing mechanisms that operate on time scales of 106 yr or longer. We test this diachronous deglaciation hypothesis for southwestern and south-central Gondwana with new single crystal U-Pb zircon chemical abrasion thermal ionizing mass spectrometry (CA-TIMS) ages from volcaniclastic deposits in the Paraná (Brazil) and Karoo (South Africa) Basins that span the terminal deglaciation through the early postglacial period. Intrabasinal stratigraphic correlations permitted by the new high-resolution radioisotope ages indicate that deglaciation across the S to SE Paraná Basin was synchronous, with glaciation constrained to the Carboniferous. Cross-basin correlation reveals two additional glacial-deglacial cycles in the Karoo Basin after the terminal deglaciation in the Paraná Basin. South African glaciations were penecontemporaneous (within U-Pb age uncertainties) with third-order sequence boundaries (i.e., inferred base-level falls) in the Paraná Basin. Synchroneity between early Permian glacial-deglacial events in southwestern to south-central Gondwana and pCO2 fluctuations suggest a primary CO2 control on ice thresholds. The occurrence of renewed glaciation in the Karoo Basin, after terminal deglaciation in the Paraná Basin, reflects the secondary influences of regional paleogeography, topography, and moisture sources.

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45

Pryer, L. L., K. K. Romine, T. S. Loutit, and R. G. Barnes. "CARNARVON BASIN ARCHITECTURE AND STRUCTURE DEFINED BY THE INTEGRATION OF MINERAL AND PETROLEUM EXPLORATION TOOLS AND TECHNIQUES." APPEA Journal 42, no. 1 (2002): 287. http://dx.doi.org/10.1071/aj01016.

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The Barrow and Dampier Sub-basins of the Northern Carnarvon Basin developed by repeated reactivation of long-lived basement structures during Palaeozoic and Mesozoic tectonism. Inherited basement fabric specific to the terranes and mobile belts in the region comprise northwest, northeast, and north–south-trending Archaean and Proterozoic structures. Reactivation of these structures controlled the shape of the sub-basin depocentres and basement topography, and determined the orientation and style of structures in the sediments.The Lewis Trough is localised over a reactivated NEtrending former strike-slip zone, the North West Shelf (NWS) Megashear. The inboard Dampier Sub-basin reflects the influence of the fabric of the underlying Pilbara Craton. Proterozoic mobile belts underlie the Barrow Sub-basin where basement fabric is dominated by two structural trends, NE-trending Megashear structures offset sinistrally by NS-trending Pinjarra structures.The present-day geometry and basement topography of the basins is the result of accumulated deformation produced by three main tectonic phases. Regional NESW extension in the Devonian produced sinistral strikeslip on NE-trending Megashear structures. Large Devonian-Carboniferous pull-apart basins were introduced in the Barrow Sub-basin where Megashear structures stepped to the left and are responsible for the major structural differences between the Barrow and Dampier Sub-basins. Northwest extension in the Late Carboniferous to Early Permian marks the main extensional phase with extreme crustal attenuation. The majority of the Northern Carnarvon basin sediments were deposited during this extensional basin phase and the subsequent Triassic sag phase. Jurassic extension reactivated Permian faults during renewed NW extension. A change in extension direction occurred prior to Cretaceous sea floor spreading, manifest in basement block rotation concentrated in the Tithonian. This event changed the shape and size of basin compartments and altered fluid migration pathways.The currently mapped structural trends, compartment size and shape of the Barrow and Dampier Sub-basins of the Northern Carnarvon Basin reflect the “character” of the basement beneath and surrounding each of the subbasins.Basement character is defined by the composition, lithology, structure, grain, fabric, rheology and regolith of each basement terrane beneath or surrounding the target basins. Basement character can be discriminated and mapped with mineral exploration methods that use non-seismic data such as gravity, magnetics and bathymetry, and then calibrated with available seismic and well datasets. A range of remote sensing and geophysical datasets were systematically calibrated, integrated and interpreted starting at a scale of about 1:1.5 million (covering much of Western Australia) and progressing to scales of about 1:250,000 in the sub-basins. The interpretation produced a new view of the basement geology of the region and its influence on basin architecture and fill history. The bottom-up or basement-first interpretation process complements the more traditional top-down seismic and well-driven exploration methods, providing a consistent map-based regional structural model that constrains structural interpretation of seismic data.The combination of non-seismic and seismic data provides a powerful tool for mapping basement architecture (SEEBASE™: Structurally Enhanced view of Economic Basement); basement-involved faults (trap type and size); intra-sedimentary geology (igneous bodies, basement-detached faults, basin floor fans); primary fluid focussing and migration pathways and paleo-river drainage patterns, sediment composition and lithology.

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46

Lindsay, J. F., and M. D. Brasier. "A carbon isotope reference curve for ca. 1700–1575 Ma, McArthur and Mount Isa Basins, Northern Australia." Precambrian Research 99, no. 3-4 (February 2000): 271–308. http://dx.doi.org/10.1016/s0301-9268(99)00062-5.

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47

Lambeck, Alexis, Karin Barovich, George Gibson, David Huston, and Sergei Pisarevsky. "An abrupt change in Nd isotopic composition in Australian basins at 1655Ma: Implications for the tectonic evolution of Australia and its place in NUNA." Precambrian Research 208-211 (July 2012): 213–21. http://dx.doi.org/10.1016/j.precamres.2012.01.009.

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48

Howard, Peter F. "The distribution of phosphatic facies in the Georgina, Wiso and Daly River Basins, Northern Australia." Geological Society, London, Special Publications 52, no. 1 (1990): 261–72. http://dx.doi.org/10.1144/gsl.sp.1990.052.01.19.

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49

Hill, Kevin C., and Gareth T. Cooper. "A strategy for palinspastic restoration of inverted basins: thermal and structural analyses in SE Australia." Geological Society, London, Special Publications 99, no. 1 (1996): 99–115. http://dx.doi.org/10.1144/gsl.sp.1996.099.01.09.

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50

Veevers, J. J., A. Clare, and H. Wopfner. "Neocratonic magmatic-sedimentary basins of post-Variscan Europe and post-Kanimblan eastern Australia generated by right-lateral transtension of Permo-Carboniferous Pangaea." Basin Research 6, no. 2-3 (June 1994): 141–57. http://dx.doi.org/10.1111/j.1365-2117.1994.tb00081.x.

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