This web map service provides visualisations of the datasets used as inputs into the analysis of potential for tholeiitic intrusion-hosted Ni-Cu-PGE sulfide deposits in Australia, and the resulting outputs. The datasets included in this service cover the four mineral system components incorporated in the conceptual model for the formation of tholeiitic intrusion-hosted Ni-Cu-PGE sulfide deposits : (1) energy sources or drivers of the ore-forming system; (2) crustal and mantle lithospheric architecture; (3) sources of ore constituents (i.e., Ni, PGE, Cu, S in magmatic systems); and (4) gradients in ore depositional physico-chemical parameters. The results of the analysis are published in the report "Potential for intrusion-hosted Ni-Cu-PGE sulfide deposits in Australia: A continental-scale analysis of mineral system prospectivity. http://dx.doi.org/10.11636/Record.2016.001".

Geoscience Australia is the nation’s trusted provider of independent groundwater science and advice. We support the fair sharing of Australia’s water resources for a strong economy, resilient communities and cultures, and to protect environmental assets. We aspire to identify the location, quantity and quality of Australia’s groundwater resources to support responsible water management.

<p>A geochemical study was conducted to establish oil-oil correlations and evaluate potential source rocks within the latest Devonian–earliest Carboniferous succession of the onshore Canning Basin, Western Australia. Aromatic hydrocarbons, together with the routinely used saturated biomarker ratios and stable carbon isotopes, demonstrate that the recently discovered Ungani oilfield located on the southern margin of the Fitzroy Trough are similar, but not identical, to the early Carboniferous Larapintine 4 (L4) oil family present to the north of the Fitzroy Trough on the Lennard Shelf. The L4 oil family has been correlated to a lower Carboniferous (Tournaisian) source rock core sample from the Laurel Formation at Blackstone-1 although its bulk geochemical properties signify that it could generate substantially more gas than liquid hydrocarbons. <p>The Ungani oils can be distinguished from the L4 oils by their higher concentrations of paleorenieratane and isorenieratane, coupled with more depleted δ13C values for n-alkanes, pristane and phytane compared with other components. Hopane isomerisation ratios show distinct grouping of the two oil families that reflect both source and maturity variations. The oil from Wattle-1 ST1 on the Lennard Shelf also has an unusual composition, exhibiting some molecular and isotopic features similar to both the L4 and Ungani oils. Source rocks for the Ungani and Wattle-1 ST1 oils are unknown since their geochemical signature does not match that of the Tournaisian Laurel Formation or the Middle−Upper (Givetian–Frasnian) Devonian Gogo Formation which sourced the Devonian-reservoired Larapintine 3 oils at Blina and Janpam North-1. It is postulated that such potential oil-prone source rocks could occur within the Famennian–Tournaisian succession.

<p>The Exploring for the Future program is an initiative by the Australian Government dedicated to boosting investment in resource exploration in Australia. The four-year program led by Geoscience Australia focusses on northern Australia and parts of South Australia to gather new data and information about the potential mineral, energy and groundwater resources concealed beneath the surface. As part of the Exploring for the Future program, this study aims to improve our understanding of the petroleum resource potential of northern Australia. As a component of this project, collaboration between the Onshore Energy Systems Branch, Geoscience Australia and the Northern Territory Geological Survey (NTGS) is designed to produce pre-competitive information to assist with the evaluation of the petroleum prospectivity of onshore Northern Territory basins. <p>Proterozoic basins of northern Australia including the McArthur Basin, the Isa Superbasin and the Isa Superbasin have the potential to host conventional oil and gas, in addition to unconventional shale gas and oil plays (Muir et al., 1980; Munson, 2014; Revie, 2016; Revie, 2017; Gorton & Troup, 2018). To date, work on the prospective petroleum systems in the McArthur Basin has focused principally on source rocks within the McArthur and Roper groups in the southern parts of the basin. However due to limited data availability, the spatial variability in source rock quality, type and thermal maturity remains poorly constrained across the region. In the South Nicholson region of Queensland and the Northern Territory, data from the Paleoproterozoic Isa Superbasin and the Mesoproterozoic South Nicholson Basin is extremely limited and a large proportion of the available data is old and of poor quality. To more comprehensively characterise these organic rich source rocks, higher resolution coverages of pre-competitive geochemical data is required (Gorton & Troup, 2018; Jarrett et al. 2018). <p>This data release contains the total organic carbon (TOC) content and Rock-Eval pyrolysis data of 314 samples selected from nine drill cores from the McArthur Basin, South Nicholson Basin and Isa Superbasin that are housed in the Northern Territory Geological Survey’s Darwin core repository. The wells include Glyde 1, Lamont Pass 3 (McArthur Basin), Brunette Downs 1, CRDD001, NTGS 00/1, NTGS 01/1, NTGS 02/1 (South Nicholson Basin), in addition to ND1 and ND2 (Isa Superbasin). This data was generated at the Isotope and Organic Geochemistry Laboratory at Geoscience Australia as part of the Exploring for the Future program. The results show that the McArthur Basin samples analysed contain source rocks with poor to fair oil and gas generative potential with variable thermal maturity from immature to early oil mature. The Isa Superbasin samples analysed have poor to good gas generative potential and the South Nicholson samples analysed have poor to excellent gas generative potential. Samples from the Walford Dolostone and the Mullera Formation are overmature and petroleum potential cannot be assessed from the results of this study. This data release provides additional information that can be used to characterise the organic richness, kerogen type and thermal maturity of source rocks in the Teena Dolostone, Barney Creek Formation and Lynott Formation of the McArthur Basin, the Walford Dolostone and Mount Les Siltstone of the Isa Superbasin, in addition to the Constance Sandstone and Mullera Formation of the South Nicholson Basin. This data is provided in preparation for future work to generate statistics quantifying the spatial distribution, quantity and quality of source rocks, providing important insights into the hydrocarbon prospectivity of northern Australian basins

<b>BACKGROUND</b> <p> <p>The United States Geological Survey's (USGS) Landsat satellite program has been capturing images of the Australian continent for more than 30 years. This data is highly useful for land and coastal mapping studies. <p>In particular, the light reflected from the Earth’s surface (surface reflectance) is important for monitoring environmental resources – such as agricultural production and mining activities – over time. <p>We need to make accurate comparisons of imagery acquired at different times, seasons and geographic locations. However, inconsistencies can arise due to variations in atmospheric conditions, sun position, sensor view angle, surface slope and surface aspect. These need to be reduced or removed to ensure the data is consistent and can be compared over time. <p>&nbsp</p> <b>WHAT THIS PRODUCT OFFERS</b> <p> <p>GA Landsat 7 ETM+ Analysis Ready Data Collection 3 takes Landsat 7 Enhanced Thematic Mapper (ETM+) imagery captured over the Australian continent and corrects for inconsistencies across land and coastal fringes. The result is accurate and standardised surface reflectance data, which is instrumental in identifying and quantifying environmental change. <p> <p>The ETM+ instrument is a fixed ‘whisk broom’, eight-band, multispectral scanning radiometer capable of providing high-resolution imaging information of the Earth’s surface. It is an enhanced version of the Thematic Mapper (TM) sensor. <p> <p>This product is a single, cohesive Analysis Ready Data (ARD) package, which allows you to analyse surface reflectance data as is, without the need to apply additional corrections. <p> <p>It contains three sub-products that provide corrections or attribution information: <p> <p>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;1) GA Landsat 7 ETM+ NBAR Collection 3 <p>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;2) GA Landsat 7 ETM+ NBART Collection 3 <p>&nbsp;&nbsp;&nbsp;&nbsp;&nbsp;3) GA Landsat 7 ETM+ OA Collection 3 <p> <p>The resolution is a 30 m grid based on the USGS Landsat Collection 1 archive.

<p>A regional mapping program conducted by Geoscience Australia addressed stratigraphic and structural aspects of exploration risk within the Triassic succession of the Roebuck Basin and parts of the adjacent sub-basins (central North West Shelf, Figure 1). <p>Seismic horizons of regional significance were mapped using 2D and 3D seismic surveys. Seismic survey coverage is shown in Figure 1. 2D surveys include regional deep surveys such as AGSO s110, AGSO s120, and PGS New Dawn. 3D surveys include Admiral, Beagle, CNOOC, Curt, Lord, Naranco, Polly, Whitetail, and a 5 x 5 km extract (used with permission) from the TGS Capreolus MC3D. Synthetic seismograms (Nguyen et al., 2019) were used to tie seismic horizons to wells. <p>The mapped horizons are placed within a regional tectonostratigraphic framework by Abbott et al. (2019, their Figure 2). This data pack comprises seismic horizon grids and isochron grids generated from the TR10.0_SB (base Triassic), TR17.0_SB (Mid–Triassic), and J10.0_SB (top Triassic) seismic horizons (Figure 2). Fault maps compiled at the TR10.0 _SB and J10.0_SB are also included.

Promotional flyer comprising map showing petroleum exploration permits, pipelines and basins in Australia

The Larsemann Hills region is dominated by two major lithological associations, a Mesoproterozoic to Neoproterozoic felsic dominated orthogneiss complex (Søstrene Orthogneiss) which occurs as basement to a sequence of pelitic, psammitic and felsic paragneisses (Brattstrand Paragneiss) and felsic intrusives. Recent unpublished data suggest a late Neoproterozoic depositional age for the Brattstrand Paragneiss. Current geochronology indicates that the region experienced medium to low pressure granulite-facies metamorphism during the Early Palaeozoic (~515-530 Ma). Although the paragneiss sequences record no evidence of earlier metamorphism, relics of a previous metamorphic event at ~1000-950 Ma are preserved in the Søstrene Orthogneiss. Within the Larsemann Hills region, the Early Palaeozoic event is characterised by peak metamorphism of ~7 kbar at ~800-850°C, with the post-peak evolution characterised by decompression, with some cooling, to 4 kbars at 750°C, then to 2-3 kbar at 600-650°C during final stages of orogenesis, with exhumation largely driven by crustal extension. Tectonic models generally argue for a continental-continental collisional scenario, with thermal input derived from a thinned mantle lithosphere.

<p>The Roebuck Basin is considered a new and relatively untested hydrocarbon province in the central North West Shelf of Australia. Inconsistent results from drilling for hydrocarbons highlights the need to better understand the deep structures along this rifted margin that initially formed as an intra-continental, failed rift during Late Permian. Recent wells penetrated the previously unknown Lower-Middle Triassic fluvio-deltaic sedimentary package in the Bedout Sub-basin (inboard part of the Roebuck Basin), including intervals with major oil and gas discoveries. Another two wells, Anhalt 1 and Hannover South 1, only penetrated the top of this succession and they encountered volcanics in the Rowley Sub-basin (outboard part of the Roebuck Basin). Steeply dipping clinoforms observed in the seismic data in the Rowley Sub-basin have been interpreted either as a lava delta complex associated with a failed triple junction; or as a series of back-stepping, Late Permian carbonate ramps and banks, interpreted to have developed on a thermally subsiding rift flank. The implication for prospectivity between the two scenarios is significant. Geoscience Australia undertook a Triassic regional basin analyses, including potential field modelling to validate whether the two proposed models are a plausible solution. A combination of magnetic and gravity 2.5D modelling along nine key regional seismic lines, considered the distribution of potential intrabasinal volcanic rocks and the crustal structure, including Moho depth and depth to top crystalline basement. <p>New seismic interpretation correlated to recent wells, including 2D and 3D seismic reflection surveys was integrated with deep seismic reflection and refraction data resulting in an improved geometry and lithology model that was input into the potential field analyses. The results show that the combined Jurassic and Triassic successions reach up to 16 km deep in the central North West Shelf. The Lower-Middle Triassic sediment package in the Rowley Sub-basin correlates with up to 10 km of dense material (about 2.7 g/cm3 density) and contains magnetic features partially sourced from basalts at the top of the section, as intersected in Anhalt 1 and Hannover South 1. Combined with other causative sources within basement, the basalts correlate with a spatially large positive magnetic anomaly that extends north onto the Scott Plateau and into the Barcoo Sub-basin; in the offshore southwest part of the Browse Basin, where Warrabkook 1 intersected Late Jurassic volcanoclastics at its total depth. The presence of high density and high positive magnetic anomalies in the Lower-Middle Triassic and basement supports the presence of a large igneous province in this area. This interpretation in the outer Rowley Sub-basin downgrades the petroleum prospectivity in this area for this Lower-Middle Triassic interval. Petroleum prospectivity remains in the area due to the overlying sediments containing good source rocks which have been identified to have good to excellent generative potential. <p>The Lower-Middle Triassic sediment package in the adjacent northern Carnarvon Basin has been intersected only on the Lambert Shelf; encountering fluvio-deltaic sediments. In the offshore part of the northern Carnarvon Basin, the nature of this sediment package still remains enigmatic. It correlates with low density sediments (about 2.5 g/cm3 density) that include magnetic bodies on the outboard Exmouth Plateau. The basement and crust show crustal thinning with the presence of a thick layer of interpreted hyper-extended continental crust or exhumed lithospheric mantle. This crustal domain is overlain by thick onlapping Lower-Middle Triassic sediments which form a triangular shape depocentre in the inboard northern Carnarvon Basin, wrapping around the edge of the Pilbara Craton. The location of this initial thick sediment package suggests that it was controlled by the inherited thermal structure of the Late Permian-early Triassic rift architecture that is associated with some volcanics related to a large igneous province extending across the central North West Shelf. As described in the Rowley Sub-basin, the petroleum prospectivity of the northern Carnarvon Basin remains in the overlying sediments showing similar characteristics and indicating good to excellent hydrocarbon generative potential.