The Australian Government formally releases new offshore exploration areas at the annual APPEA conference. The previous two releases were characterised by several large gazetted areas in underexplored regions, a trend that is maintained this year with several frontier areas in excess of 100 graticular blocks on offer. The uptake of new exploration permits in the Bight Basin, the offshore North Perth Basin and the Roebuck Basin indicates a continuing strong industry interest in offshore frontier exploration.

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

These data include potentially petroleum relevant shot point and navigation line records of seismic data that has been acquired offshore Australia in the vicinity of the Brremer sub-basin in Western Australia waters.

The upper Permian to Lower Triassic sedimentary succession in the southern Bonaparte Basin represents an extensive marginal marine depositional system that hosts several gas accumulations, including the Blacktip gas field that has been in production since 2009. Development of additional identified gas resources has been hampered by reservoir heterogeneity, as highlighted by preliminary results from a post drill analyses of wells in the study area that identify reservoir effectiveness as a key exploration risk. The sedimentary succession that extends across the Permian–Triassic stratigraphic boundary was deposited during a prolonged marine transgression and shows a transition in lithofacies from the carbonate dominated Dombey Formation to the siliciclastic dominated Tern and Penguin formations. Recent improvements in chronostratigraphic calibration of Australian biostratigraphic schemes, spanning the late Permian and Early Triassic, inform our review of available palynological data and re-interpretation and infill sampling of well data. The results provide a better resolved, consistent and up-to-date stratigraphic scheme, allowing an improved understanding of the timing, duration, and distribution of depositional environments of the upper Permian to Lower Triassic sediments across the Petrel Sub-basin and Londonderry High. <b>Citation:</b> Owens R., Kelman A., Khider K., Iwanec J., Bernecker T. (2022) Addressing exploration uncertainties in the southern Bonaparte Basin: enhanced stratigraphic control and post drill analysis for upper Permian plays. <i>The APPEA Journal</i> 62, S474-S479

The folloing metadata covers the datasets within the 'SEEBASE' directory on the CD-ROM and is a sub-set of an external product delivered to Geoscience Australia. This product was created by FrOG Tech (Formerly SRK Consulting Energy Services). It is not an official Geoscience Australia (GA) product. It has not been through the production validation regimen, nor has it been tested by GA for its data completeness, correct spatial representation, attribute accuracy, logical consistency, metadata completeness and correctness. What is SEEBASE? 3D Image of Southern Margins SEEBASE (Structurally Enhanced View of Economic Basement) SEEBASE is a depth-to-basement model that represents the culmination of a number of calibration and integration steps: Integrated structural/kinematic interpretation Geophysical modeling Seismic & well calibration Integration of tectonic events & responses SEEBASE defines basin architecture, and forms the basis for the systematic evaluation of exploration strategies. SEEBASE provides a foundation for petroleum systems evaluation, including play element distribution (source/reservoir/seal), migration pathways, zones of structural complexity, trap distribution, trap type & integrity, Palaeogeography, oil vs. gas distribution, etc.

Promotional flyer comprising map showing petroleum exploration permits and current and proposed gazettal areas for acreage release. map is supplemented by short information (text) about geological aspects of release areas and summeries of Austrlaia's oil and gas production levels.

Regular release of offshore acreage, part of the Australian Governmen's strategy to encourage investment in petroleum exploration. Provides information to intending investors in the Australian petroleum (oil and gas) sector, and to general public on the Australian investment framework for petroleum. It has been produced in the Australian Government Department of Industry, Science and Resources by the Petroleum and Electricity Division, in consultation with the Mines Departments in the six States and the Northern Territory. 2001 offshore petroleum acreage release package is available on CD-ROM or at internet address: www.isr.gov.au/resources/petroleum.html.

AVO compliant reprocessing of 3 lines from the Remus 2D seismic survey covering the 2007 Acreage Release Areas W07-19 and W07-21

The Cooper Basin is a late Carboniferous-Middle Triassic intracratonic basin in northeastern South Australia and southwestern Queensland. The basin is one of Australia's premier onshore hydrocarbon producing provinces and, by providing domestic gas for the East Coast Gas Market, is nationally significant. This study reviews the distribution, quality and maturity of source rocks across the Cooper Basin and forms part of Geoscience Australia's source rock program. All publicly-available total organic carbon (TOC) content and Rock-Eval pyrolysis data for the Cooper Basin were compiled into a single database, quality checked and compiled by well and formation to highlight the multiple viable source rock units throughout the Permian. The Toolachee and Patchawarra formations represent the principal source rocks in the basin. These comprise coals and carbonaceous shales deposited in fluvial deltaic and peat swamp environments and show good to very good oil and gas source potential. Additional source intervals include the gas prone lacustrine Roseneath and Murteree shales, as well as coals and carbonaceous shales of the Daralingie and Epsilon formations. Permian source rock distribution was investigated using lithofacies mapping combined with geochemistry data. Lithofacies maps published for South Australia were integrated with electrofacies data from Queensland to produce new, internally consistent, net source thickness maps for key intervals, including coals and carbonaceous shales of the Toolachee and Patchawarra formations, and the Roseneath and Murteree shales. Pyrolysis data that indicate the presence of an in-situ source rock with remaining hydrocarbon generation potential (i.e. TOC > 2% and S1+S2 > 3 mg hydrocarbons/g rock) were mapped by formation, demonstrating the broad extent of Permian source rocks across the basin. Toolachee and Patchawarra source rocks are present in most major depocentres, including the Windorah Trough and Ullenbury Depression in the northern part of the basin, where maximum coal thicknesses still reach more than 10 m. Source rocks within the Roseneath and Murteree shale are generally restricted to the southern Cooper Basin.

No abstract available