Статті в журналах: "Georgina Basin"

1

Lodwick, W. R., and J. F. Lindsay. "SOUTHERN GEORGINA BASIN: A NEW PERSPECTIVE." APPEA Journal 30, no. 1 (1990): 137. http://dx.doi.org/10.1071/aj89008.

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The Georgina Basin formed as a shallow intracratonic depression on the Australian craton along with a number of other basins in the Proterozoic and early Palaeozoic, probably in response to the break up of the Proterozoic supercontinent. Since all of these basins evolved under similar tectonic and sea-level controls, the basins all have similar sediment successions and, it might thus be assumed, similar petroleum prospectivity. One basin, the Amadeus Basin, currently has petroleum production, suggesting a potential for exploration success in the other intracratonic basins.In the Amadeus Basin the main petroleum prospects lie within or adjacent to major sub-basins that formed along the Basin's northern margin. The Georgina Basin has sub-basins that formed along its southern margin, almost as a mirror image of the Amadeus Basin. The lower Palaeozoic section of the Toko Syncline in the southern Georgina Basin has hydrocarbon shows in Middle Cambrian to Middle Ordovician rocks. Source rocks appear to have developed within the transgressive systems tract and the condensed interval of the highstand systems tract, at times when the basin was starved for clastic sediments and carbonate production was restricted.Seismic data acquired in the 1988 survey are of a higher quality than that previously obtained in the area. Its interpretation portrays the westward thrusting French Fault at the eastern edge of the Toko Syncline with potential hangingwall and footwall traps. Cambro- Ordovician Georgina Basin sediments subcrop the overlying Eromanga Basin with angularity, providing potentially large stratigraphic traps. Fracturing of the Cambrian and Ordovician carbonates within fault zones, and solution porosity at the unconformity, would also enhance reservoir potential in the area. Perhaps most significantly, the new data also shows an earlier, apparently independent basin completely buried beneath the Georgina section. The concealed section may simply be a very thick, early Upper Proterozoic section, or perhaps an equivalent to, or a lateral extension of the McArthur Basin. Recent work in the McArthur Basin has shown considerable source potential in the McArthur and Roper Groups, which may support the possibility of an additional, as yet unrecognised, source beneath the Georgina Basin.

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2

Won, Mun-Zu, and Raimond Below. "Cambrian Radiolaria from the Georgina Basin, Queensland, Australia." Micropaleontology 45, no. 4 (1999): 325. http://dx.doi.org/10.2307/1486119.

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3

Kruse, Peter D. "Cambrian fauna of the Top Springs Limestone, Georgina Basin." Beagle : Records of the Museums and Art Galleries of the Northern Territory 8, no. 1 (September 1991): 169–88. http://dx.doi.org/10.5962/p.262819.

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4

Smith, Tegan, Andrew P. Kelman, Robert Nicoll, Dianne Edwards, Lisa Hall, John Laurie, and Lidena Carr. "An updated stratigraphic framework for the Georgina Basin, NT and Queensland." APPEA Journal 53, no. 2 (2013): 487. http://dx.doi.org/10.1071/aj12098.

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The Georgina Basin is a Neoproterozoic to Lower Devonian sedimentary basin covering 325,000 km2 of western Queensland and the NT. It is a northwest-southeast-trending extensional basin, with prospective conventional and unconventional hydrocarbon targets in Cambrian and Ordovician carbonate and siliciclastic rock units. The unconventional gas and oil potential of the basin has led to recent exploration interest, although the basin has been relatively less explored in the past. At the southern end of the basin, depocentres contain up to 2.2 km of Cambrian to Devonian sedimentary rocks, overlying Neoproterozoic sedimentary rocks more than 1.5 km thick. The basin succession thins toward the north, where Cambrian sediments overlie the McArthur Basin sediments in the Beetaloo Sub-basin. Biostratigraphic interpretations of the prospective southern, central and eastern regions of the basin have been revised to reflect the 2012 Geological Time Scale (Gradstein, Ogg, Schmitz, and Ogg, 2012), resulting in an updated chronostratigraphic framework for the basin. The revised biostratigraphic interpretations have implications for important hydrocarbon source rocks. For example, the limestone unit in the southern parts of the basin, generally regarded as the Thorntonia Limestone, is of a different age to the type section for this unit, located in the Undilla Sub-basin. Additionally, the basal hot shale of the Arthur Creek Formation is diachronous across the Dulcie and Toko synclines, which may have ramifications for hydrocarbon exploration. This revised chronostratigraphic framework (by Geoscience Australia) for the Georgina Basin provides a baseline for the first basin-wide assessment of the unconventional hydrocarbon potential of the basin.

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5

Edwards, Sally, and Behnam Talebi. "New deep crustal seismic data acquisition program for NWQ's frontier petroleum basins." APPEA Journal 59, no. 2 (2019): 869. http://dx.doi.org/10.1071/aj18084.

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The Georgina and South Nicholson basins and the Isa Superbasin of North West Queensland (NWQ), represent frontier basins earmarked for examination of resource potential under the Strategic Resources Exploration Program. Little exploration has occurred for petroleum resources in these basins although a proven petroleum system exists in both the Isa Superbasin and the Georgina Basin with demonstrated flow at sub-commercial rates. To increase knowledge of the petroleum system, define the extent of the South Nicholson Basin and examine basin architecture, Geoscience Australia acquired deep (to 20-s listening time) seismic data across the South Nicholson Basin and northern Isa Superbasin area in 2017. However, this survey focused on broader structural architecture definition across the Proterozoic Isa Superbasin and South Nicholson and McArthur basins. Little is understood of the petroleum system in the southern Isa Superbasin, or even if this structure is part of the Isa Superbasin, where Proterozoic gas is inferred from mineral boreholes and oil stained Cambrian-aged carbonates exist. To increase understanding of this southern region, the Queensland Government acquired a new NWQ SEEBASE® (depth to basement) model in 2018, and will be undertaking a 2D deep seismic survey within the Camooweal region to better understand the structural architecture, sediment thicknesses and seismic characteristic of packages of this southern area. The seismic survey is centred on the Georgina Basin and will tie into the South Nicholson survey – extending knowledge further south across major structures featured in the SEEBASE® model.

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6

Draper, J. "GEORGINA BASIN—AN EARLY PALAEOZOIC CARBONATE PETROLEUM SYSTEM IN QUEENSLAND." APPEA Journal 47, no. 1 (2007): 107. http://dx.doi.org/10.1071/aj06006.

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Queensland contains a number of carbonate-bearing basins which are under-explored for petroleum, but contain the elements of potentially economic petroleum systems. The oldest such basin is the Neoproterozoic to Ordovician Georgina Basin which straddles the Queensland-Northern Territory border and is traversed by the Ballera to Mount Isa gas pipeline.The basin developed across several major crustal blocks resulting in regional variations in deposition and deformation. Thick Neoproterozoic rocks of the Centralian Superbasin form the base of the sequence in apparently fault-bounded, extensional sub-basins. These rocks are generally tight and source rocks are unknown. The Cambrian to Ordovician rocks have the best petroleum potential with the most prospective part of the basin being the Toko Syncline. The Burke River Structural Belt is less prospective, but is worthy of further exploration. Basin fill consists of Cambrian and Early Ordovician rocks which are dominantly carbonates, with both limestones and dolostones present. In the Early to Middle Ordovician, the rocks became predominantly siliciclastic.The main phase of deformation affecting the Georgina Basin occurred in the Devonian as part of the Alice Springs Orogeny. The Toomba Fault, which forms the western boundary of the asymmetric Toko Syncline, is a thrust fault with up to 6.5 km of uplift. The angle of thrusting is between less than 40 degrees and up to 70 degrees. Rich, marine source rocks of Middle Cambrian age in the Toko Syncline are mature for oil except in the deepest part of the syncline where they are mature for dry gas. The deeper part of the Toko Syncline may be gas saturated.Potential hydrocarbon targets include large folds associated with fault rollovers, stratigraphic traps and faultbounded traps. Vugular, secondary porosity in dolostones offers the best chance for commercial reservoirs within the Ninmaroo and Kelly Creek formations and Thorntonia Limestone. There are also oolitic carbonates which may have good primary porosity, as well as interbedded sandstones in the carbonates with preserved porosity. Structurally controlled hydrothermal dolomite facies represent potential reservoirs. The dominantly siliciclastic Ordovician sequence is water flushed. Fracture porosity is another possibility (cf. the Palm Valley gas field in the Amadeus Basin). As the deeper part of the Toko Syncline appears to be gas saturated, there may be potential for basin-centred gas. Fine-grained carbonates and shales provide excellent seals. There has not been a valid structural test; although AOD Ethabuka–1 flowed 7,000 m3/d of dry gas, the well was abandoned short of the target depth.

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7

Ambrose, G. J., P. D. Kruse, and P. E. Putnam. "GEOLOGY AND HYDROCARBON POTENTIAL OF THE SOUTHERN GEORGINA BASIN, AUSTRALIA." APPEA Journal 41, no. 1 (2001): 139. http://dx.doi.org/10.1071/aj00007.

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The Georgina Basin is an intracratonic basin on the central-northern Australian craton. Its southern portion includes a highly prospective Middle Cambrian petroleum system which remains largely unexplored. A plethora of stratigraphic names plagued previous exploration but the lithostratigraphy has now been rationalised using previously unpublished electric-log correlations and seismic and core data.Neoproterozoic and Lower Palaeozoic sedimentary rocks of the southern portion of the basin cover an area of 100,000 km2 and thicken into two main depocentres, the Toko and Dulcie Synclines. In and between these depocentres, a Middle Cambrian carbonate succession comprising Thorntonia Limestone and Arthur Creek Formation provides a prospective reservoir-source/seal couplet extending over 80,000 km2. The lower Arthur Creek Formation includes world class microbial source rocks recording total organic carbon (TOC) values of up to 16% and hydrocarbon yields up to 50 kg/tonne. This blanket source/seal unconformably overlies sheetlike, platform dolostone of the Thorntonia Limestone which provides the prime target reservoir. Intra- Arthur Creek high-permeability grainstone shoals are important secondary targets.In the Toko Syncline, Middle Cambrian source rocks entered the oil window during the Ordovician, corresponding to major sediment loading at this time. The gas window was reached prior to structuring associated with the Middle Devonian-Early Carboniferous Alice Springs Orogeny, and source rocks today lie in the dry gas window. In contrast, high-temperature basement granites have resulted in overmaturity of the Arthur Creek Formation in the Dulcie Syncline area. On platform areas adjacent to both these depocentres source rocks reached peak oil generation shortly after the Alice Springs Orogeny; numerous structural leads have been identified in these areas. In addition, an important stratigraphic play occurs in the Late Cambrian Arrinthrunga Formation (Hagen Member) on the southwestern margin of the basin. Key elements of the play are the pinchout of porous oil-stained, vuggy dolostone onto basement where top seal is provided by massive anhydrite while underlying Arthur Creek Formation shale provides a potential source.

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8

Laurie, John R. "Silicified Late Cambrian brachiopods from the Georgina Basin, western Queensland." Alcheringa: An Australasian Journal of Palaeontology 21, no. 3 (January 1997): 179–89. http://dx.doi.org/10.1080/03115519708619172.

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9

Bailey, A., E. Tenthorey, and B. Ayling. "Characterising the present-day stress regime of the Georgina Basin." Australian Journal of Earth Sciences 64, no. 1 (January 2, 2017): 121–36. http://dx.doi.org/10.1080/08120099.2017.1268206.

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10

Eyre, B. "Early Cambrian alluvial fan‐deltas in the Georgina Basin, Australia." Australian Journal of Earth Sciences 41, no. 1 (February 1994): 27–36. http://dx.doi.org/10.1080/08120099408728110.

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11

Gibson, D. L. "Pyrite-organic matter relationships: Currant Bush Limestone, Georgina Basin, Australia." Geochimica et Cosmochimica Acta 49, no. 4 (April 1985): 989–92. http://dx.doi.org/10.1016/0016-7037(85)90313-8.

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12

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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13

Playford, Geoffrey, and Merrell A. Miller. "Chitinozoa from Lower Ordovician strata of the Georgina Basin, Queensland (Australia)." Geobios 21, no. 1 (January 1988): 17–39. http://dx.doi.org/10.1016/s0016-6995(88)80029-9.

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14

Kruse, Peter D. "Biostratigraphic potential of Middle Cambrian hyoliths from the eastern Georgina Basin." Alcheringa: An Australasian Journal of Palaeontology 26, no. 3 (January 2002): 353–98. http://dx.doi.org/10.1080/03115510208619263.

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15

Pegum, D., and M. Loeliger. "THE LANDER TROUGH—A CENTRAL AUSTRALIAN FRONTIER EXPLORATION AREA." APPEA Journal 30, no. 1 (1990): 128. http://dx.doi.org/10.1071/aj89007.

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The Lander Trough is an almost unexplored area of 30 000 square kilometres in the central western Northern Territory. It has very similar stratigraphy and structural features to the nearby Amadeus, Ngalia and southern Georgina Basins. They all contain fluvio-deltaic to marine sediments of Late Proterozoic to Carboniferous age and were subjected to deformation during several major periods of folding and overthrusting. They are remnants of one depositional basin which covered much of Northern Australia in the Late Proterozoic and Early Palaeozoic Eras. Producing oil and gas fields occur in the Amadeus Basin and there are many oil and gas occurrences in the southern Georgina and Ngalia Basins. The Lander Trough contains up to 3000 metres of largely marine clastic and carbonate sediments which are expected to include mature source rocks and effective reservoirs and seals. Adequate migration paths and trapping mechanisms are believed to be present. The Lander Trough has the potential for commercial petroleum discoveries.

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16

Foster, Clinton B., Reed Wicander, and Geoffrey Playford. "Eomerismopedia maureeniae n.g. n.sp., a chroococcacean cyanobacterium from the lower Ordovician Coolibah Formation, Georgina Basin, Queensland, Australia." Neues Jahrbuch für Geologie und Paläontologie - Monatshefte 2002, no. 2 (January 29, 2002): 65–74. http://dx.doi.org/10.1127/njgpm/2002/2002/65.

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17

Young, G. C., and H. P. Schultze. "New osteichthyans (bony fishes) from the Devonian of Central Australia." Fossil Record 8, no. 1 (January 1, 2005): 13–35. http://dx.doi.org/10.1002/mmng.200410002.

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Abstract. Osteichthyan remains described from two localities in Central Australia (Mount Winter, Amadeus Basin, and southern Toomba Range, Georgina Basin) include the dipnoan Amadeodipterus kencampbelli n. gen., n. sp., the osteolepidid Muranjilepis winterensis n. gen., n. sp., and the onychodontid Luckeus abudda n. gen., n. sp., as well as indeterminate holoptychiid scales, osteolepidid scales of a new type from the Georgina Basin locality, and indeterminate onychodontid remains from both localities. Amadeodipterus n. gen. is a short-headed dipterid dipnoan with bones A and H enclosed into the skull roof; Muranjilepis n. gen. is a small form with short postparietal and parietoethmoidal shields, large orbits, and large pores of the sensory line system. It is closest to Thursius, and some Chinese osteolepidid material. Luckeus n. gen. is based on an onychodontid lower jaw with Meckel’s cartilage separately ossified perichondrally from the dentary and infradentary, and carrying the parasymphysial tooth whorl. Different osteichthyan taxa at the two localities indicate a difference in age and/or palaeoenvironment within the Early-Middle Devonian. Knochenfischreste aus zwei Fundorten Zentralaustraliens (Mount Winter, Amadeus Becken und südlicher Toomba Rücken, Georgina Becken) umfassen den Lungenfisch Amadeodipterus kencampbelli n. gen., n. sp., den osteolepididen Sarcopterygier Muranjilepiswinterensis n. gen., n. sp., und den onychodontiden Sarcopterygier Luckeus abudda n. gen., n. sp., sowie unbestimmte holoptychiide und osteolepidide Schuppen eines neuen Typs aus dem Fundort im Georgina Becken und unbestimmte onychodontide Reste von beiden Fundorten. Amadeodipterus n. gen. ist ein kurz-schädeliger Lungenfisch, bei dem die Knochen A und H in das Schädeldach miteingeschlossen sind. Bei Muranjilepis n. gen. handelt es sich um einen kleinen Osteolepididen mit kurzem Postparietal- und Parietoethmoidal-Schild, großen Augenhöhlen und großen Poren des Sinneskanalsystems; er ist am nächsten mit Thursius und einigen chinesischen Osteolepididen verwandt. Ein unbestimmter onychodontider Unterkiefer zeigt ein wahrscheinlich primitives Merkmal in der perichondralen Verknöcherung des Meckelschen Knorpels getrennt von Dentale und Infradentale, der die Unterlage der parasymphysialen Zahnspirale bildet. Verschiedene Knochenfischtaxa treten an den beiden Lokalitäten auf; das deutet auf unterschiedliches Alter und/oder Palaeoenviroment an der Unter-Mitteldevongrenze zwischen beiden Lokalitäten hin. doi:10.1002/mmng.200410002

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18

Troup, Alison, and Sally Edwards. "Old basins, new seismic data – architecture of Proterozoic basins in Northwest Queensland." APPEA Journal 62, no. 2 (May 13, 2022): S502—S507. http://dx.doi.org/10.1071/aj21167.

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As part of the Strategic Resources Exploration Program and to complement surveys acquired under Geoscience Australia’s Exploring for the Future (EFTF) initiative, the Geological Survey of Queensland acquired the Camooweal 2D seismic survey in 2019. This survey was designed to support exploration for hydrocarbons in the Georgina and South Nicholson Basins and Isa Superbasin in Northwest Queensland (NWQ) by providing precompetitive sub-surface data to enable interpretation of basin and basement architecture and to examine structures interpreted in the 2018 North West Queensland SEEBASE Study. The Camooweal 2D seismic survey extends Geoscience Australia’s L210 South Nicholson Seismic Survey into an underexplored region of NWQ. It also ties into and complements the 1994 and 2004 Mount Isa seismic surveys, and the 2019 L212 Barkly Seismic Survey in the Northern Territory. The South Nicholson survey highlighted a significant thickness of sedimentary strata and identified a new depocenter of probable Proterozoic age, now referred to as the Carrara Sub-basin. The Camooweal and Barkly surveys extended the seismic coverage in this region and possibly increase the Carrara Sub-basin’s extent underneath the Georgina Basin. This work will present an interpretation of the basin architecture of the Camooweal 2D seismic in light of the recent drilling at NDI Cararra 1 and tie into interpretation of the Barkly Seismic Survey to provide a regional interpretation of NWQ’s Proterozoic basins in the region.

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19

Bernecker, Thomas, and Jenny Maher. "What can deep seismic reflection data tell us about hydrocarbon prospectivity in onshore." APPEA Journal 49, no. 2 (2009): 598. http://dx.doi.org/10.1071/aj08071.

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Now in its third year, Geoscience Australia’s Onshore Energy Security Program has acquired several suites of regional geological and geophysical data. The data includes several deep seismic reflection surveys that have been designed to image: basement provinces with high geothermal gradients that may contain uranium enrichments and are potential candidates for geothermal energy; geological terrane boundaries; and, sedimentary basins that are known to host petroleum system elements but are under-explored. Seismic signals are recorded down to 20 seconds two-way-time (TWT) which corresponds to 25–35 km depth depending on dominant lithologies. Basinal sections normally extend down to 6–8 sec TWT and the data is of such high quality that any section of the seismic profile can be enlarged without significant loss of resolution. Deep reflection surveys are able to image the relationship between crystalline basement and overlying basin sequences very clearly and also allow interpretations of structural styles as well as impacts of deformational processes on the basin-fill. A new basinal section was discovered beneath the Eromanga Basin suite of sediments. Named the Mullangera Basin,its structural style and basement relationship seem to indicate some affinity with the Georgina Basin, located further west. The succession is clearly composed of several sequences that contain both fine and coarse-grained sediments. If a geological relationship with the Georgina Basin can be ascertained, a new hydrocarbon prospective area could be delineated. Another new section was discovered beneath the Devonian section of the Darling Basin. Judging by the fast acoustic velocities, the entire basin-fill sequence appears to be very dense and therefore largely non-porous and of low permeability. While low poro-perm characteristics would normally be translated to low prospectivity for oil and gas, the potential for unconventional hydrocarbons such a tight-gas and shale-gas warrants further attention.

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20

Valetich, Matthew, Diana Zivak, Carl Spandler, Helen Degeling, and Micaela Grigorescu. "REE enrichment of phosphorites: An example of the Cambrian Georgina Basin of Australia." Chemical Geology 588 (January 2022): 120654. http://dx.doi.org/10.1016/j.chemgeo.2021.120654.

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21

Turner, Susan, and Gavin C. Young. "Shark teeth from the Early-Middle Devonian Cravens Peak Beds, Georgina Basin, Queensland." Alcheringa: An Australasian Journal of Palaeontology 11, no. 3 (January 1987): 233–44. http://dx.doi.org/10.1080/03115518708618990.

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22

Carr, Lidena, Russell Korsch, Wolfgang Preiss, Sandra Menpes, Josef Holzschuh, and Ross Costelloe. "Structural and stratigraphic architecture of Australia's frontier onshore sedimentary basins: the Arckaringa, Officer, Amadeus, and Georgina basins." APPEA Journal 51, no. 2 (2011): 703. http://dx.doi.org/10.1071/aj10083.

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The Onshore Energy Security Program—funded by the Australian Government and conducted by Geoscience Australia—has acquired deep seismic reflection data in conjunction with state and territory geological surveys, across several frontier sedimentary basins to stimulate petroleum exploration in onshore Australia. Here, we present data from two seismic lines collected in SA and NT. Seismic line 08GA-OM1 crossed the Arckaringa and Officer basins in SA and the southern-most Amadeus Basin in NT. Seismic line 09GA-GA1 crossed the northeastern part of the Amadeus Basin and the complete width of the southern Georgina Basin in NT. Structural and sequence stratigraphic interpretations of the seismic lines will be presented here, followed by an assessment of the petroleum potential of the basins. Seismic line 08GA-OM1 also crosses the Neoproterozoic to Devonian eastern Officer Basin. The basin is structurally complex in this area, being dominated by south-directed thrust faults and fault-related folds—providing potential for underthrust petroleum plays. The northern margin of the basin is overthrust to the south by the Mesoproterozoic Musgrave Province. To the north, the Moorilyanna Trough of the Officer Basin is a major depocentre of up to 7,000 m deep. Both seismic lines cross parts of the eastern Amadeus Basin. Seismic line 08GA-OM1 shows that the southern margin of the basin is overthrust to the north by the Musgrave Province with the main movement during the Petermann Orogeny. In the northeast, seismic line 09GA-GA1 crosses two parts of the basin separated by the Paleoproteroozic to Mesoproterozoic Casey Inlier (part of the Arunta Region). The northern margin of the basin is imaged seismically as a southward-verging, thinned-skinned thrust belt, showing considerable structural thickening of the stratigraphic succession. Seismic line 09GA-GA1 was positioned to cross that part of the southern Georgina Basin that was considered previously to be in the oil window. Here, the basin has a complex southern margin, with Neoproterozoic stratigraphy being thrust interleaved with basement rocks of the Arunta Region. The main part of the basin, containing a Neoproterozoic to Devonian succession, is asymmetric, thinning to the north where it overlies the Paleoproterozoic Davenport Province. The well, Phillip–2, drilled adjacent to the seismic line, intersected basement at a depth of 1,489 m, and has been used to map the stratigraphic sequences across the basin.

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23

Korsch, Russell, Heike Struckmeyer, Alison Kirkby, Laurie Hutton, Lidena Carr, Kinta Hoffmann, Richard Chopping, et al. "Energy potential of the Millungera Basin: a newly discovered basin in north Queensland." APPEA Journal 51, no. 1 (2011): 295. http://dx.doi.org/10.1071/aj10020.

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Deep seismic reflection surveys in north Queensland that were collected in 2006 and 2007 discovered a previously unknown sedimentary basin, now named the Millungera Basin, which is completely covered by a thin succession of sediments of the Jurassic–Cretaceous, Eromanga-Carpentaria Basin. Interpretation of regional aeromagnetic data suggests that the basin could have areal dimensions of up to 280 km by 95 km. Apart from regional geophysical data, virtually no confirmed geological information exists on the basin. To complement the seismic data, new magnetotelluric data have been acquired on several lines across the basin. An angular unconformity between the Eromanga and Millungera basins indicates that the upper part of the Millungera Basin was eroded prior to deposition of the Eromanga-Carpentaria Basin. Both the western and eastern margins of the Millungera Basin are truncated by thrust faults, with well-developed hangingwall anticlines occurring above the thrusts at the eastern margin. The basin thickens slightly to the east, to a maximum preserved subsurface depth of ˜3,370 m. Using sequence stratigraphic principles, three discrete sequences have been mapped. The geometry of the stratigraphic sequences, the post-depositional thrust margins, and the erosional unconformity at the top of the succession all indicate that the original succession across much of the basin was thicker–by up to at least 1,500 m–than preserved today. The age of the Millungera Basin is unknown, but petroleum systems modelling has been carried out using two scenarios, that is, that the sediment fill is equivalent in age to (1) the Neoproterozoic-Devonian Georgina Basin, or (2) the Permian–Triassic Lovelle Depression of the Galilee Basin. Using the Georgina Basin analogue, potential Cambrian source rocks are likely to be mature over most of the Millungera Basin, with significant generation and expulsion of hydrocarbons occurring in two phases, in response to Ordovician and Cretaceous sediment loading. For the Galilee Basin analogue, potential Permian source rocks are likely to be oil mature in the central Millungera Basin, but immature on the basin margins. Significant oil generation and expulsion probably occurred during the Triassic, in response to late Permian to Early Triassic sediment loading. Based on the seismic and potential field data, several granites are interpreted to occur immediately below the Millungera Basin, raising the possibility of hot rock geothermal plays. Depending on its composition, the Millungera Basin could provide a thermal blanket to trap any heat which is generated. 3D inversion of potential field data suggests that the inferred granites range from being magnetic to nonmagnetic, and felsic (less dense) to more mafic. They may be part of the Williams Supersuite, which is enriched in uranium, thorium and potassium, and exposed just to the west, in the Mount Isa Province. 3D gravity modelling suggests that the inferred granites have a possible maximum thickness of up to 5.5 km. Therefore, if granites with the composition of the Williams Supersuite occur beneath the Millungera Basin, in the volumes indicated by gravity inversions, then, based on the forward temperature modelling, there is a good probability that the basin is prospective for geothermal energy.

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DONNELLY, TERRENCE H., JOHN H. SHERGOLD, and PETER N. SOUTHGATE. "Anomalous geochemical signals from phosphatic Middle Cambrian rocks in the southern Georgina Basin, Australia." Sedimentology 35, no. 4 (August 1988): 549–70. http://dx.doi.org/10.1111/j.1365-3091.1988.tb01235.x.

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25

Troup, Alison, and Sally Edwards. "Source rock characterisation of under-explored regions of Queensland." APPEA Journal 56, no. 2 (2016): 580. http://dx.doi.org/10.1071/aj15086.

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Historically, petroleum exploration in Queensland has focused on the Bowen-Surat and Cooper-Eromanga basins, with only cursory examination of other basins across the state. As part of the Queensland Industry Priorities Initiative, two projects (Round 1 and 2) were submitted to the Geological Survey of Queensland (GSQ) to examine the geochemical characteristics of potential petroleum source rocks throughout Queensland. The analysis conducted provides a better understanding of generative potential for petroleum, and predicts the timing, volume, composition, and physical state of hydrocarbons retained in and expelled from source rocks. It is an integral component to petroleum systems analysis used to identify the potential for undiscovered accumulations of petroleum from conventional and unconventional reservoirs. Of particular interest were the Georgina, Drummond, Eromanga, and Maryborough basins. Of these, the Georgina and Maryborough basins have known hydrocarbon shows identified through exploration drilling, though no commercial discoveries have yet been made. The Drummond Basin was targeted to identify a potential source for oil and gas shows encountered in drilling within the Galilee Basin. The Toolebuc Formation in the Eromanga Basin has been noted as having the potential for a shale oil play and this study is supporting further assessment to identify optimal areas for future exploration through predictive modelling. This report details the results from Round 1 of the study for samples taken from the Georgina Limestone and Scartwater, Ducabrook, Mount Hall, Toolebuc, and Maryborough formations, where limited analysis of source rock characteristics has historically been undertaken. Ninety-seven samples were chosen from nine wells and sent to Geos4 in Potsdam, Germany, for source rock analysis. All samples were screened for suitability of further analysis using Rock-Eval and TOC by LECO, with immature and organic-rich samples being preferentially selected for further testing. Screened samples were analysed using pyrolysis gas chromatography (n=27), thermovaporisation (n=23), bulk kinetics (n=5), compositional kinetics (n=4), late gas analysis (n=14), and biomarker and bulk isotope analysis (n=15). These results have been integrated with existing analyses to better understand the prospectivity of the under-explored basins of Queensland.

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26

Willink, Robbert, and Mitch Allison. "Exploring unconventional plays in the Georgina Basin, central Australia: will the real Arthur Creek Formation hot shale please stand up!" APPEA Journal 55, no. 2 (2015): 430. http://dx.doi.org/10.1071/aj14065.

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The search for hydrocarbons in the southern Georgina Basin in central Australia is now focused on assessing the unconventional potential of the Middle Cambrian lower Arthur Creek Formation. Recent regional well correlation studies, supported by a review of nominated type sections and of regional seismic data, and integrating core-based sedimentological, palaeontological, chemostratigraphic, and geochemical information, suggest that the organic rich hot shale at the base of this formation, encountered in wells drilled in the Dulcie Syncline, is not a correlative of the organic rich hot shale encountered in wells drilled in the Toko Syncline. Although similar in lithofacies and mineralogy, the former is significantly older and is more restricted in geographic distribution to an area west of a prominent northwest to southeast trending shear zone in the basement. This interpretation is contrary to correlations presented in recent publications on the geology and resource potential of the southern Georgina Basin by government agencies, various petroleum consultancy firms that have provided estimates of the volumetric potential of the unconventional hydrocarbon resources in the lower Arthur Creek Formation, and several petroleum companies actively exploring in the basin. Any historical inference that simply assumed the lower Arthur Creek Formation hot shale in the Toko domain should be an attractive unconventional target because of the lithological properties of the lower Arthur Creek Formation hot shale observed in the Dulcie domain is not supported by these revised correlations. Pursuit of the basal lower Arthur Creek Formation unconventional play in the Dulcie Syncline and in the Toko Syncline should be done on their respective merits.

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27

Janussen, Dorte, Michael Steiner, and Zhu Maoyan. "New well-preserved scleritomes of Chancelloridae from the early Cambrian Yuanshan Formation (Chengjiang, China) and the middle Cambrian Wheeler Shale (Utah, USA) and paleobiological implications." Journal of Paleontology 76, no. 4 (July 2002): 596–606. http://dx.doi.org/10.1017/s0022336000041895.

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From the early Cambrian of Yunnan, China, new chancellorid scleritomes assigned to Allonnia junyuani new species are described and compared with scleritomes of Chancelloria eros Walcott, 1920 from the Middle Cambrian of Utah, USA and isolated phosphatized chancellorid sclerites from the Georgina Basin of North Australia. Characters of the entirely preserved chancellorids offer new insight into the paleobiology of Chancelloridae. An irregular thickening at the inferred base of the narrow body end of Chancelloria eros from Utah is interpreted as a root bulb that anchored the sessile animal in the soft bottom sediment. Sclerites show gradual increase in size from the narrower towards the broader upper end of the chancellorid body. A central “gastral” lumen was not directly observed in any of the investigated specimens, but the orientation of sclerites towards the outer body surface indicates that the fossils are secondarily flattened due to compaction and were originally hollow. Taphonomy of isolated chancellorid sclerites from the Georgina Basin, Australia, indicates a biomineralization very different from that of sponge spicules, including the spongin spiculoids of demospongid Keratosa. Allonnia junyuani from Chengjiang (Yunnan) exhibits a prominent epidermis, probably with stable epithelian cell-to-cell connections. This feature excludes a sponge affiliation of the Chancelloridae and points towards a systematic position of this group within the epithelian-bearing animals and thus well above the Porifera.

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28

Greene, David C. "Neoproterozoic rifting in the southern Georgina Basin, central Australia: Implications for reconstructing Australia in Rodinia." Tectonics 29, no. 5 (September 17, 2010): n/a. http://dx.doi.org/10.1029/2009tc002543.

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29

Hinz-Schallreuter, Ingelore, and Peter J. Jones. "Gladioscutum lauriei n.gen. n.sp. (Archaeocopida) from the Middle Cambrian of the Georgina Basin, central Australia." Paläontologische Zeitschrift 68, no. 3-4 (September 1994): 361–75. http://dx.doi.org/10.1007/bf02991349.

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30

Young, Gavin C., and Daniel Goujet. "Devonian fish remains from the Dulcie Sandstone and Cravens Peak Beds, Georgina Basin, central Australia." Records of the Western Australian Museum, Supplement 65, no. 1 (2003): 1. http://dx.doi.org/10.18195/issn.0313-122x.65.2003.001-085.

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31

McConachie, B. A., M. G. Barlow, J. N. Dunster, R. A. Meaney, and A. O. Schaap. "THE MOUNT ISA BASIN—DEFINITION, STRUCTURE AND PETROLEUM GEOLOGY." APPEA Journal 33, no. 1 (1993): 237. http://dx.doi.org/10.1071/aj92018.

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The Mount Isa Basin is a new concept to describe the area of Palaeo- to Mesoproterozoic rocks south of the Murphy Inlier (not the Murphy Tectonic Ridge) and inappropriately described as the Mount Isa Inlier. The new basin concept presented in this paper allows the characterisation of basin-wide structural deformation and the recognition of areas with petroleum exploration potential.The northern depositional margin of the Mount Isa Basin is the metamorphic, intrusive and volcanic complex referred to as the Murphy Inlier. The eastern, southern and western boundaries of the basin are obscured by younger basins (Carpentaria, Eromanga and Georgina Basins). The Murphy Inlier rocks comprise the seismic basement to the Mount Isa Basin sequence. Evidence for the continuity of the Mount Isa Basin with the McArthur Basin to the northwest and the Willyama Block (Basin) at Broken Hill to the south is presented. These areas combined with several other areas of similar age are believed to have comprised the Carpentarian Superbasin.The application of seismic exploration within Authority to Prospect (ATP) 423P at the northern margin of the basin was critical to the recognition and definition of the Mount Isa Basin. The northern Mount Isa Basin is structurally analogous to the Palaeozoic Arkoma Basin of Oklahoma and Arkansas in the southern USA but as with all basins it contains unique characteristics, a function of its individual development history. The northern Mount Isa Basin is defined as the basin area northwest of the Mount Gordon Fault.

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32

Moore, J. L., and Susannah M. Porter. "Plywood-like shell microstructures in hyoliths from the middle Cambrian (Drumian) Gowers Formation, Georgina Basin, Australia." Palaeontology 61, no. 3 (March 7, 2018): 441–67. http://dx.doi.org/10.1111/pala.12352.

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33

Donnelly, T. H., J. H. Shergold, and P. N. Southgate. "Pyrite and organic matter in normal marine sediments of Middle Cambrian age, southern Georgina Basin, Australia." Geochimica et Cosmochimica Acta 52, no. 2 (February 1988): 259–63. http://dx.doi.org/10.1016/0016-7037(88)90081-6.

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34

Blach, Tomas, Andrzej P. Radlinski, Dianne S. Edwards, Christopher J. Boreham, Christine Rehm, Liliana de Campo, and Elliot P. Gilbert. "Fingerprint of hydrocarbon generation in the southern Georgina Basin, Australia, revealed by small angle neutron scattering." International Journal of Coal Geology 186 (February 2018): 135–44. http://dx.doi.org/10.1016/j.coal.2017.10.013.

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35

NICOLAIDES, STELIOS. "Origin and modification of Cambrian dolomites (Red Heart Dolomite and Arthur Creek Formation), Georgina Basin, central Australia." Sedimentology 42, no. 2 (April 1995): 249–66. http://dx.doi.org/10.1111/j.1365-3091.1995.tb02101.x.

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36

E. Twigg, Laurie, Laurie E. Twigg, Dennis R. King, and Dennis R. King. "Artificially enhanced tolerance to fluoroacetate and its implications for wildlife conservation." Pacific Conservation Biology 6, no. 1 (2000): 9. http://dx.doi.org/10.1071/pc000009.

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It is with some concern that we have been following a research programme aimed at developing non-specific, genetically modified ruminant bacteria capable of detoxifying fluoroacetate (Compound 1080) to protect domestic livestock from fluoroacetate-poisoning (Gregg et al. 1994; Gregg et al. 1998; Synergy 1998). The main thrust of this research programme is the prevention of cattle losses in the Georgina Basin in the Northern Territory and Queensland where the toxic plant, Gidgee Acacia georginae occurs. Although rarely mentioned in formal reports of this work, 1080 is an important vertebrate pesticide that is widely used throughout Australia and New Zealand. It is the first defence against a number of pest species that impact on agricultural production and conservation efforts in both countries. The main concerns about this work relate to the potential lack of target specificity of these modified microorganisms, and also, if released, their potential impact on conservation biology. We raise these questions now because the Genetic Manipulation Advisory Council has been approached for approval to conduct field trials in Western Australia using the modified bacteria. We believe the perceived advantages and disadvantages of these modified organisms need informed debate before such approval, or any general release of these modified rumen bacteria, could be considered.

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37

Feltrin, Leonardo, and Nicholas H. S. Oliver. "Timing and origin of megabreccia and folds along the Early Middle Cambrian margin of the Georgina Basin, Australia." Carbonates and Evaporites 29, no. 1 (March 13, 2014): 3–31. http://dx.doi.org/10.1007/s13146-014-0193-6.

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38

Pagès, Anais, Susanne Schmid, Dianne Edwards, Stephen Barnes, Nannan He, and Kliti Grice. "A molecular and isotopic study of palaeoenvironmental conditions through the middle Cambrian in the Georgina Basin, central Australia." Earth and Planetary Science Letters 447 (August 2016): 21–32. http://dx.doi.org/10.1016/j.epsl.2016.04.032.

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39

Gorton, Justin, and Alison Troup. "Petroleum systems of the Proterozoic in northwest Queensland and a description of various play types." APPEA Journal 58, no. 1 (2018): 311. http://dx.doi.org/10.1071/aj17115.

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As part of Queensland Government’s Strategic Resources Exploration Program, in conjunction with the Australian Government’s Exploring for the Future program, a study to improve the subsurface knowledge of Proterozoic basins in northwest Queensland (NWQ) is underway. Proterozoic sedimentary basins are prevalent across central and western Australia. Several of these basins have proven petroleum systems, with the best discoveries to date being in the Greater McArthur Basin, Northern Territory. Recent exploration and appraisal in the Beetaloo Sub-basin of the Greater McArthur Basin has identified large volumes of gas resources contained within unconventional shale reservoirs. In NWQ, the Isa Superbasin and overlying South Nicholson Basin are related in both age and likely deposition to the Greater McArthur Basin. The thick, extensive shale units of the Isa Superbasin are excellent source rocks, while the Mullera Formation in the South Nicholson Basin also has potential but has not been investigated in detail. There are several potential reservoirs within the Proterozoic section and younger units of the overlying Georgina and Carpentaria basins, including clastic and carbonate types. Exploration in the Isa Superbasin identified an estimated 22.1 trillion cubic feet of prospective resources (Armour Energy 2015) in unconventional shale reservoirs of the Lawn Hill Formation and Riversleigh Siltstone. This paper will discuss the stratigraphy, depositional and structural history of these Proterozoic basins and characterise their source and reservoir units using existing and recently acquired geophysical, geochemical, petrographic and petrophysical datasets. From this, several plays or play concepts will be identified and described to help understand the region’s potential for both conventional and unconventional petroleum resources.

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40

Willink, Robbert J., Nathan C. Palmer, Mathew Davies, Chris Woodfull, Peter Stuart-Smith, and Charles Verdel. "Introducing the Sylvester Graben, a ?Neoproterozoic depocenter on the eastern flank of the Toko Syncline, southern Georgina Basin, Queensland." APPEA Journal 56, no. 2 (2016): 534. http://dx.doi.org/10.1071/aj15040.

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Regional 2D seismic lines acquired in 2013 along the eastern edge of the Toko Syncline in Queensland have imaged a complexly faulted, northwest–southeast trending graben below subcropping Cambrian carbonates. At its deepest, this depocenter contains some 3,500 m of sediments that are inferred to be of Neoproterozoic age, if not older at depth. Surface outcrops of this succession are mapped as the Sylvester Sandstone. Shallow core holes confirm that the uppermost ~1,000 m of sediments are of fluvioglacial, glacio lacustrine and glacial origin, overlain by a thin carbonate of Lower Cambrian age based on the occurrence of archaeocyathids. Unconformably underlying this succession is an internally reflective sedimentary section that is up to 2,500 m which has not been drilled to date. Although the localised development of Neoproterozoic depocenters below Cambrian carbonates in the Toko Syncline has been inferred previously based on vintage seismic and gravity data, such features were not imaged as clearly as on the newly acquired seismic. Inferred sediments in this faulted graben may be correlatives of the Neoproterozoic succession in the Amadeus Basin and could be prospective for hydrocarbons as well as ore deposits.

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41

Willink, Robbert J., Mike J. Bucknill, and Nathan C. Palmer. "Could a structurally controlled, hydrothermal dolomite play be operative in Cambro-Ordovician carbonates of the southern Georgina Basin, Queensland?" APPEA Journal 56, no. 2 (2016): 535. http://dx.doi.org/10.1071/aj15041.

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Hydrothermal dolomitisation of carbonates can create zones of favourable porosity and permeability in otherwise tight carbonate successions. In North America, a number of fields produce oil and gas from such reservoirs that developed along and adjacent to pre-existing fault zones acting as loci for hydrothermal fluid flow. Seismic data across these North American fields are characterised by linear zones of disturbance evident along fault zones where porosity development has occurred. Similar zones of disturbance have been observed on newly acquired seismic over the Toko Syncline in Queensland. Here, these zones extend through a thick Cambro-Ordovician carbonate succession that includes platform carbonates of the Thorntonia Limestone, overlying deeper water deposits of the Arthur Creek Formation that are organic rich and hydrocarbon generative at their base, and also in younger shallow water carbonates of the Arrinthrunga, Ninmaroo, Kelly Creek and Coolibah formations. If these zones of disturbance on seismic also reflect the development of hydrothermal dolomite reservoirs, they provide a new exploration target in the southern Georgina Basin.

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42

Brock, Glenn A. "Middle Cambrian articulate brachiopods from the Southern New England Fold Belt, Northeastern N.S.W., Australia." Journal of Paleontology 72, no. 4 (July 1998): 604–19. http://dx.doi.org/10.1017/s0022336000040336.

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Calcareous articulate brachiopods are rare components of the high diversity, phosphatic, silicified, and epidote coated shelly fauna derived from Middle Cambrian (Floran-Undillan) allochthonous limestone clasts from the Murrawong Creek Formation, southern New England Fold Belt, northeastern New South Wales, Australia. Three taxa are described, the kutorginids Nisusia metula n. sp., and Yorkia sp. indet., and the protorthid Arctohedra austrina n. sp. Yorkia is documented from Australia for the first time. An unusual valve (possibly a brachial valve) of enigmatic affinity is also reported and illustrated. Generically, the taxa provide broad regional paleobiogeographic links with the “first discovery limestone” Member of the Coonigan Formation, western New South Wales, and the Current Bush Limestone in the Georgina Basin, northern Australia, and globally, with broadly contemporaneous sequences in western North America, Siberia, and South China.

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43

Jorand, C., K. Connors, L. Pryer, and C. Pietrucha. "A new spatially continuous basement heat flow map for NW Queensland." APPEA Journal 59, no. 2 (2019): 879. http://dx.doi.org/10.1071/aj18042.

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A recently released open file study of the depth-to-basement and basement heat flow is presented, which covers the Queensland portion of the South Nicholson Basin and includes basins underlying the Lawn Hill Platform and Georgina Basin. The present-day basement heat flow model is derived from an analysis of basement composition, structure and history, with the crustal radiogenic and mantle heat flow assessed separately. Resulting from an integrated, iterative interpretation and analysis of a wide range of publicly available spatially continuous geophysical and geological datasets, the heat flow model reproduces faithfully sharp and high-amplitude variations of the published heat flow at small distances. Variations are replicated through the integration of interpreted basement composition and a geologically driven determination of heat production within the radiogenic crustal layer. The values of mantle heat flow based on lithosphere thickness derived from seismic tomography models are consistent with published stable mantle heat flow under terranes of similar age. The long-wavelength regional variations can be attributed to the change in the thickness of the lithosphere. Regionally, the highest values of heat flow are found where radiogenic crust is the thickest and the composition is interpreted to comprise radiogenic intrusives.

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44

Southgate, P. N. "A model for the development of phosphatic and calcareous lithofacies in the Middle Cambrian Thorntonia Limestone, northeast Georgina Basin, Australia." Australian Journal of Earth Sciences 35, no. 1 (March 1988): 111–30. http://dx.doi.org/10.1080/08120098808729443.

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45

SMITH, PATRICK M., JOHN R. PATERSON, and GLENN A. BROCK. "Trilobites and agnostids from the Goyder Formation (Cambrian Series 3, Guzhangian; Mindyallan), Amadeus Basin, central Australia." Zootaxa 4396, no. 1 (March 18, 2018): 1. http://dx.doi.org/10.11646/zootaxa.4396.1.1.

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A new assemblage containing twenty-two species of trilobites and agnostids is described from the Goyder Formation (Cambrian Series 3) in the Ross River Syncline and Gardiner Ranges of the Amadeus Basin, Northern Territory, central Australia. New trilobite taxa described include the genus, Trephina gen. nov., and four new species Adelogonus prichardi sp. nov., Hebeia stewarti sp. nov., Liostracina joyceae sp. nov., and Trephina ranfordi sp. nov. Two agnostid taxa previously known only from Antarctica, Ammagnostus antarcticus Bentley, Jago & Cooper, 2009 and Hadragnostus helixensis Jago & Cooper, 2005, are also documented. Of the two agnostid species, the latter is the most age diagnostic, previously reported from the Cambrian Series 3 (Guzhangian; late Mindyallan; Glyptagnostus stolidotus Zone) Spurs Formation in Northern Victoria Land. This age for the Goyder Formation assemblage is supported by the co-occurrence of the trilobites Biaverta reineri Öpik, 1967, Blackwelderia repanda Öpik, 1967, Henadoparia integra Öpik, 1967, Monkaspis cf. travesi (Öpik, 1967), Nomadinis pristinus Öpik, 1967, Paraacidaspis? priscilla (Öpik, 1967), and Polycyrtaspis cf. flexuosa Öpik, 1967, also known from the late Mindyallan (G. stolidotus Zone) successions of the neighbouring Georgina Basin (Northern Territory and Queensland). The generic assemblage of the Goyder Formation is also similar to those from the Guzhangian (Mindyallan) of other parts of Australia (New South Wales, South Australia, and Western Australia), in addition to East Antarctica and North and South China.

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46

Smith, Tegan, John Laurie, Lisa Hall, Robert Nicoll, Andrew Kelman, and James Ogg. "The times they are a-changin': Australian biozones, petroleum basins, and the international geologic time scale (GTS) 2012." APPEA Journal 54, no. 2 (2014): 473. http://dx.doi.org/10.1071/aj13046.

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The international Geologic Time Scale (GTS) continually evolves due to refinements in age dating and the addition of more defined stages. The GTS 2012 has replaced GTS 2004 as the global standard timescale, resulting in changes to the age and duration of most chronological stages. These revisions have implications for interpreted ages and durations of sedimentary rocks in Australian basins, with ramifications for petroleum systems modelling. Accurate stratigraphic ages are required to reliably model the burial history of a basin, hence kerogen maturation and hydrocarbon expulsion and migration. When the resolution of the time scale is increased, models that utilise updated ages will better reflect the true basin history. The international GTS is largely built around northern hemisphere datasets. At APPEA 2009, Laurie et al. announced a program to tie Australian biozones to GTS 2004. Now, with the implementation of GTS 2012, these ties are being updated and refined, requiring a comprehensive review of the correlations between Australian and International biozonation schemes. The use of Geoscience Australia’s Timescales Database and a customised ‘Australian Datapack’ for the visualisation software package TimeScale Creator has greatly facilitated the transition from GTS 2004 to GTS 2012, as anticipated in the design of the program in 2009. Geoscience Australia’s basin biozonation and stratigraphy charts (e.g. Northern Carnarvon and Browse basins) are being reproduced to reflect the GTS 2012 and modified stratigraphic ages. Additionally, new charts are being added to the series, including a set of onshore basin charts, such as the Georgina and Canning basins.

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47

Carr, Lidena, Russell Korsch, Leonie Jones, and Josef Holzschuh. "The role of deep seismic reflection data in understanding the architecture and petroleum potential of Australia's onshore sedimentary basins." APPEA Journal 50, no. 2 (2010): 726. http://dx.doi.org/10.1071/aj09090.

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The onshore energy security program, funded by the Australian Government and conducted by Geoscience Australia, has acquired deep seismic reflection data across several frontier sedimentary basins to stimulate petroleum exploration in onshore Australia. Detailed interpretation of deep seismic reflection profiles from four onshore basins, focussing on overall basin geometry and internal sequence stratigraphy, will be presented here, with the aim of assessing the petroleum potential of the basins. At the southern end of the exposed part of the Mt Isa Province, northwest Queensland, a deep seismic line (06GA–M6) crosses the Burke River structural zone of the Georgina Basin. The basin here is >50 km wide, with a half graben geometry, and bounded in the west by a rift border fault. Given the overall architecture, this basin will be of interest for petroleum exploration. The Millungera Basin in northwest Queensland is completely covered by the thin Eromanga Basin and was unknown prior to being detected on two seismic lines (06GA–M4 and 06GA–M5) acquired in 2006. Following this, seismic line 07GA–IG1 imaged a 65 km wide section of the basin. The geometry of internal stratigraphic sequences and a post-depositional thrust margin indicate that the original succession was much thicker than preserved today and may have potential for a petroleum system. The Yathong Trough, in the southeast part of the Darling Basin in NSW, has been imaged in seismic line 08GA–RS2 and interpreted in detail using sequence stratigraphic principles, with several sequences being mapped. Previous studies indicate that the upper part of this basin consists of Devonian sedimentary rocks, with potential source rocks at depth. In eastern South Australia, seismic line 08GA–A1 crossed the Cambrian Arrowie Basin, which is underlain by a Neoproterozoic succession of the Adelaide Rift System. Stratigraphic sequences have been mapped and can be tied to recent drilling for mineral and geothermal exploration. Shallow drill holes from past petroleum exploration have aided the assessment of the petroleum potential of the Cambrian Hawker Group, which contains bitumen in the core, indicating the presence of source rocks in the basin system.

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Sheng, Jiani, Sarah Kachovich, and Jonathan C. Aitchison. "Skeletal architecture of middle Cambrian spicular radiolarians revealed using micro-CT." Journal of Micropalaeontology 39, no. 1 (May 26, 2020): 61–76. http://dx.doi.org/10.5194/jm-39-61-2020.

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Abstract. X-ray micro-computed tomography (micro-CT) is used to resolve the detailed internal architecture of the siliceous skeletons of two well-preserved middle Cambrian (Miaolingian Series) radiolarians from the Inca Formation of the Georgina Basin, Australia. Digital dissections of specimens of Archeoentactinia incaensis and A. tetractinia reveal for the first time that both are exclusively composed of tetractine spicules. A basal layer consisting of robust spicules together with an interwoven meshwork of smaller spicules is observed in both micro-CT models. Detailed structural analysis with the aid of a digitally inserted artificial sphere shows that the framework spicules are likely to have been added one by one as the radiolarian cell enlarged. The timing of spicule genesis may be an important factor controlling the morphology of different groups of spicular radiolarians. Observation of these fundamental skeletal structures suggests that the type genus of Archeoentactiniidae Archeoentactinia belongs to Echidninidae; thus, Archeoentactiniidae is a junior synonym of Echidninidae.

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Schmid, Susanne, and Wayne R. Taylor. "Significance of carbonaceous shales and vanadium geochemical haloes in the exploration for rock phosphate deposits in the southern Georgina Basin, central Australia." Journal of Geochemical Exploration 101, no. 1 (April 2009): 91–92. http://dx.doi.org/10.1016/j.gexplo.2008.12.033.

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Blach, Tomas, Andrzej P. Radlinski, Dianne S. Edwards, Christopher J. Boreham, and Elliot P. Gilbert. "Pore anisotropy in unconventional hydrocarbon source rocks: A small-angle neutron scattering (SANS) study on the Arthur Creek Formation, Georgina Basin, Australia." International Journal of Coal Geology 225 (May 2020): 103495. http://dx.doi.org/10.1016/j.coal.2020.103495.

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Статті в журналах з теми "Georgina Basin"

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