petroleum reserves
Type of resources
Keywords
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Restricted on advice from A. Barrett
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Restricted on advice from A. Barrett
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This report contains data on the 68 petroleum accumulations discovered in the Bonaparte Basin to December 2002. It provides summaries of the regional setting, evolution and stratigraphy of the basin and discusses the hydrocarbon habitat and development of the producing accumulations. For the purpose of this report, a discrete, measured recovery of petroleum on test from an exploration well qualifies as a `discovery?. Petroleum accumulations inferred from wireline log interpretations (and where petroleum has not been recovered on test) are referred to as `shows?. Small quantities of gas recovered on test in three wells included in this report may represent `solution gas? - indicating these wells may not have intersected a petroleum pool.
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This publication is the successor to Oil and Gas Resources of Australia 2006 and continues as the definitive reference on exploration, development and production of Australia's petroleum resources. The tables describe: - wells drilled - seismic surveys - petroleum discoveries - petroleum reserves - production and development including a chronological listing of offshore facilities
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Restricted on advice from A. Barrett
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The map and supporting booklet (the key) are based on information held by the State and Territory Departments of Mines and the Commonwealth Department of Industry, Science and Resources. The map is published annually at a scale of 1:5 000 000 and supports the Commonwealth Government's offshore petroleum exploration area release program. The map includes all available information up to May 2003. The key (booklet) accompanying the map lists the relevant title numbers, the title holders, areas of the titles and expiry dates, by State and Territory. Also included is information on petroleum exploration permits, licences, leases and production licences in offshore areas under the jurisdiction of the relevant State and Territory petroleum acts, and offshore areas under the Commonwealth Petroleum (Submerged Lands) Act.
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Producing petreoleum fields and potential petreoleum producers, oil and gas pipelines (current and proposed)
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It appears that the hydrocarbon exploration industry will be able to enjoy today's vibrant times for years to come. In the current climate of high oil prices and ongoing expansion of global energy needs, many companies find themselves in the pursuit of new prospective acreage. It has long been acknowledged that Australia's early Palaeozoic sedimentary basins are largely under-explored. This may be partly due to the lack of infrastructure and partly due to the perceived high risk involved in committing to an expensive exploration program in remote areas. From a regional geological perspective however, several provinces can be earmarked as candidates that may emerge as future hydrocarbon producers. These include the western extension of the prolific Cooper/Eromanga hydrocarbon province (Pedirka and Warburton basins in SA, NT), the Georgina Basin (NT, Qld), the Amadeus Basin (NT, WA), the Officer Basin (SA, WA) and the southern Canning Basin (Kidson-Sub-basin, WA). As part of Geoscience Australia's Onshore Energy Security Program, new radiometric and aeromagnetic data have been acquired with the aim to better image crustal features such as regional tectonic lineaments that control basin evolution. A significant part of the program is devoted to the acquisition of deep seismic surveys over key areas in which petroleum systems are known to exist. Such surveys will target major basin-bounding lineaments and basinal deeps in order to improve the understanding of basin-fill processes. The effects of tectonism on the occurrence and preservation of petroleum systems elements is of particular interest. While source rocks are likely to be available in virtually all target areas, the distribution of permeable reservoir facies needs to be delineated. Moreover, trap configurations are crucially important to assess and the integrity of the sealing facies needs to be ascertained.
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The Mentelle Basin is a large (36 400 m2) frontier basin lying less than 100 km to the west of the oil and gas producing Perth Basin. The basin was formed during Jurassic extension which preceded the breakup between Australia and Greater India in the Valanginian. The breakup was accompanied by significant volcanism with extensive lava flows overlying the Valanginian unconformity. The Mentelle Basin comprises two structurally different depocentres. The eastern depocentre lying in shallow water (less than 500 m) is a large complex half-graben with up to 8 km of sediments, most of which are synrift section. The Western Mentelle depocentre lies between 2000 to 3300 m water depths and contains up to 7 km synrift and 2.5 km postrift section. The Mentelle Basin has never been drilled. Seismo-stratigraphic correlations are made to the DSDP well 258 on the Naturaliste Plateau and to the exploration wells in the Southern Vlaming Sub-basin. However direct correlations are possible only for the Late Cretaceous to recent part of the section. Recent Geoscience Australia studies involving structural restoration of the margin have shown that major tectonic and accommodation cycles are the same for both basins. The ages of the synrift sequences in the Mentelle basin therefore have been interpreted using the new Vlaming Sub-basin tectonostratigraphic framework. Seismic facies analysis was then used to define potential source rock intervals and correlate them to the known source rocks in the Vlaming Sub-basin. To test petroleum potential of this frontier basin 2D burial history analysis has been performed for the three regional lines. For each line three different scenarios with varying source rock characteristics reflecting end member possibilities have been explored. The potential effect of heat flow variations and intrusive volcanics on the maturation history have also been assessed. The modelling results suggest that source rocks in the deepest part of the synrift section are overmature, while uppermost Berriasian source rocks are immature. Source rocks that are currently within the maturation window are Middle Jurassic to Early Cretaceous shaly and coaly intervals, which commenced generation in the Late Jurassic. The erosion of significant sedimentary thickness in the Eastern Mentelle during continental breakup slowed down and in some cases stopped hydrocarbon generation. As this part of the basin has less that 1 km of postrift section only source rocks with sufficient overburden are still generating. In the Western Mentelle the same source rocks are buried much deeper and continued to generate throughout the Tertiary and up to the present. In the Eastern Mentelle oil generation and migration was roughly synchronous with the development of most structures whereas in the western Mentelle more source rock intervals continued generating after the major structuring. The main risk in the Mentelle Basin is the presence of good quality seals at the right stratigraphic level. Existing seismic coverage is insufficient for detailed structural interpretation needed to define potential traps. Provided suitable structures are found in the Mentelle Basin it may have similar petroleum potential to the Vlaming Sub-basin.
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Map depicting major Australian Oil & Gas Fields as at 23 March 2009.