Journal articles: 'Geological Survey of Queensland'

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Edwards, Sally. "Geological Survey of Queensland: Camooweal 2D seismic survey." Preview 2020, no. 205 (March 3, 2020): 22. http://dx.doi.org/10.1080/14432471.2020.1751783.

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Greenwood, Matthew, Janelle Simpson, and Roger Cant. "Geological Survey of Queensland: Strategic Resources Exploration Program." Preview 2019, no. 201 (July 4, 2019): 16. http://dx.doi.org/10.1080/14432471.2019.1646695.

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Greenwood, Matthew. "Geological survey of Queensland: New geophysical data released for Queensland’s north west mineral province." Preview 2019, no. 199 (March 4, 2019): 22–23. http://dx.doi.org/10.1080/14432471.2019.1597670.

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Troup, Alison, Melanie Fitzell, Sally Edwards, Owen Dixon, and Gopalakrishnan Suraj. "Unconventional petroleum resource evaluation in Queensland." APPEA Journal 53, no. 2 (2013): 471. http://dx.doi.org/10.1071/aj12082.

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The search for unconventional petroleum resources requires a shift in the way the petroleum potential of sedimentary basins is assessed. Gas in source rocks and tight reservoirs has largely been ignored in preference for traditional conventional gas plays. Recent developments in technology now allow for the extraction of gas trapped in low-permeability reservoirs. Assessments of the unconventional petroleum potential of basins, including estimates of the potential resource are required to guide future exploration. The Geological Survey of Queensland is collaborating with Geoscience Australia (GA) and other state agencies to undertake regional assessments of several basins with potential for unconventional petroleum resources in Queensland. The United States Geological Survey methodology for assessment of continuous petroleum resources is being adopted to estimate total undiscovered oil and gas resources. Assessments are being undertaken to evaluate the potential of key formations as shale oil and gas and tight-gas plays. The assessments focus on mapping key attributes including depth, thickness, maturity, total organic carbon (TOC), porosity, gas content, reservoir pressure, mineralogy and regional facies patterns using data from stratigraphic bores and petroleum wells to determine play fairways or areas of greatest potential. More detailed formation evaluation is being undertaken for a regional framework of wells using conventional log suites and mudlogs to calculate porosity, TOC, maturity, oil and gas saturations, and gas composition. HyLoggerTM data is being used to determine its validity to estimate bulk mineralogy (clay-carbonate-quartz) compared with traditional x-ray diffraction methods. These methods are being applied to key formations with unconventional potential in the Georgina and Eromanga basins in Queensland.

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Fensham, R. J., R. J. Fairfax, and P. R. Sharpe. "Spring wetlands in seasonally arid Queensland: floristics, environmental relations, classification and conservation values." Australian Journal of Botany 52, no. 5 (2004): 583. http://dx.doi.org/10.1071/bt03171.

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The vegetation and environmental setting of permanent spring wetlands are described from a survey of 269 spring complexes throughout seasonally arid Queensland. Wetlands associated with springs in the western and southern discharge areas of the Great Artesian Basin are floristically distinct from other spring wetlands. Ordination analysis suggests that the biogeographic regions and the broad geological substrates that support spring wetlands provide a meaningful representation of floristic range. An existing classificatory system that defines ‘regional ecosystems’ on the basis of the biogeographic region and broad geological substrate is adopted to define 15 spring-wetland types in seasonally arid Queensland. The conservation value of the springs is assessed by a scheme that weights plant species populations on the basis of their endemicity and isolation from other populations, demonstrating that both Great Artesian Basin and non-Great Artesian Basin springs have similar conservation values.

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Cant, Roger, Janelle Simpson, and Matthew Greenwood. "Geological Survey of Queensland: New Economy Resources Initiative geophysics programmes and Cloncurry extension MT results released." Preview 2021, no. 211 (March 4, 2021): 21–22. http://dx.doi.org/10.1080/14432471.2021.1905966.

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Rix, Alan. "The Triassic insects of Denmark Hill, Ipswich, Southeast Queensland: the creation, use and dispersal of a collection." Memoirs of the Queensland Museum - Nature 62 (March 18, 2021): 217–42. http://dx.doi.org/10.17082/j.2204-1478.62.2021.2020-11.

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Type and additional fossil insects from the Late Triassic Denmark Hill locality in Southeast Queensland, Australia, are held in the collections of the Queensland Museum (Brisbane), the Australian Museum (Sydney) and the Natural History Museum of the United Kingdom (London). The history of these collections shows that they were the product of a concerted effort in the first two decades of the twentieth century to extract the fossils by Benjamin Dunstan, Queensland’s Chief Government Geologist, and to describe the fossils by Dunstan and Robin Tillyard, the foremost Australian entomologist of the time. They collaborated closely to document the late Triassic insects of Australia, at the same time as Dunstan carefully curated and organised both the official government collection of these insects for the Geological Survey of Queensland, and his own private collection. The death of the two men in the 1930s led to the sale by his widow of Dunstan’s private fossil collection (including type and type counterpart specimens) to the British Museum, and the donation of Tillyard’s by his widow to the same institution, in addition to some material that went to the Australian Museum. This paper documents the locations of all of the published specimens. The history of the Denmark Hill fossils (a site no longer accessible for collection) highlights the problems for researchers of the dispersal of holdings such as these, and in particular the separation of the part and counterpart of the same insect fossils. It also raises ethical questions arising from the ownership and disposal of private holdings of important fossil material collected in an official capacity.

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Knight, Tony. "Approaches to data-driven exploration in Queensland." APPEA Journal 59, no. 2 (2019): 896. http://dx.doi.org/10.1071/aj18077.

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Queensland has a very significant petroleum resource endowment within 27 hydrocarbon basins spread across the state. Three of those basins already host Australia’s largest onshore gas supply industry, leaving significant opportunity to develop additional gas resources. To optimise the development of new resources, the Geological Survey of Queensland (GSQ) is implementing an integrated approach to exploration and appraisal called ‘data driven exploration’. Working in collaboration with industry, the research sector and relevant government agencies, GSQ is promoting data-driven exploration in four ways: by (1) optimising the type and quality of geoscience data collected and reported by industry; (2) improving data curation practices in government data repositories; (3) creating value-added opportunities for the use of geoscience data; and (4) improving industry capability and capacity through skills enhancement, collaborative mechanisms, and access to an expert capability network. The overarching objective of ‘data-driven exploration’ is to enable industry exploration and appraisal success by making best use of geoscience data coupled with supporting mechanisms to improve competency and capability to derive, interpret and employ geoscience information. The expression of success will vary depending on individual circumstances, but is intended to encompass a range of outcomes including improvements in the rate, cost and efficiency of discovery and appraisal.

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Green, Peter. "Australian States and Northern Territory acreage update at APPEA 2010." APPEA Journal 50, no. 1 (2010): 35. http://dx.doi.org/10.1071/aj09003.

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Peter Green is the Geoscience Manager: Energy Geoscience in the Geological Survey Queensland and has extensive experience in basin studies, geoscience and the development of petroleum regulation in Queensland. This paper provides a summary of the land releases for petroleum exploration for onshore areas and coastal waters of Australia for 2010. The summaries include upstream petroleum acreage opportunities for the states and the Northern Territory, and geothermal energy exploration opportunities. The rise in interest in export liquefied natural gas projects has ensured petroleum exploration and production has remained strong. Interest in acquiring petroleum acreage to explore for both conventional and non-conventional plays remains high. Australian state and the Northern Territory governments continue to provide access to land and promotional opportunities for companies to undertake exploration and development of our petroleum resources. Acreage on offer provides a mix of exploration opportunities from conventional oil and gas through to the unconventional plays such as shale gas and tight gas. This change in acreage on offer reflects the changing nature of the onshore petroleum industry in Australia.

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Rowland, Mike, and Malcolm Connolly. "Towards GIS Mapping and Spatial Modelling of Archaeological Sites in the Southeast Queensland Bioregion." Queensland Archaeological Research 13 (December 1, 2002): 39. http://dx.doi.org/10.25120/qar.13.2002.67.

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<p>In the early 1980s a strategic approach to the description, assessment and management of cultural heritage places using biogeographical boundaries was developed in Queensland. A recent refinement correlates sites on the Environmental Protection Agency's Indigenous Sites Database with environmental variables for the Moreton Basin Province of the Southeast Queensland Bioregion. Archaeological sites in the province are correlated with distance to water, elevation and particular geological and vegetation types. These correlations may reflect either real relationships or biases in the data. Preliminary correlative models developed are not considered substitutes for further inventory surveys and ongoing model refinement. The development of such models is considered useful in providing initial understanding of site distribution patterns.</p>

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Cant, Roger, Janelle Simpson, and Matthew Greenwood. "Geological Survey of Queensland: Strategic Resources Exploration Program concludes, New Economy Minerals Initiative and geophysical programmes commence, and MT results released." Preview 2021, no. 213 (July 4, 2021): 22–23. http://dx.doi.org/10.1080/14432471.2021.1958526.

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Johnson, PM, BJ Nolan, and DN Schaper. "Introduction of the Proserpine rock-wallaby Petrogale persephone from the Queensland mainland to nearby Hayman Island." Australian Mammalogy 25, no. 1 (2003): 61. http://dx.doi.org/10.1071/am03061.

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Between 1998 and 2002, 27 ‘endangered’ Proserpine rock-wallabies Petrogale persephone were introduced from the Queensland mainland to Hayman Island. Site release selection was based on faunal, botanical, geological and ecological surveys carried out before the release. The eradication of a feral herbivorous competitor, the feral goat (Capra hircus), allowed the introduction to proceed. Eagle predation in the early part of the introduction necessitated all further introductions be carried out by soft release. Between 1999 and 2000, monitoring and non-invasive video surveillance has shown that this introduced population is breeding.

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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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Talebi, Behnam. "1D depth burial history and thermal maturity modelling of the Toolebuc Formation, Queensland." APPEA Journal 56, no. 2 (2016): 590. http://dx.doi.org/10.1071/aj15096.

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The Toolebuc Formation in the Eromanga and Carpentaria basins in western Queensland shares many characteristics with successful tight oil plays in the US. A study by the Geological Survey of Queensland has examined key parameters for this formation, including depth, thickness, lithology, mineralogy, maturity (both vitrinite reflectance and Tmax), total organic carbon and mud gas compositions and identified a possible play fairway in the central Eromanga Basin. Mudgas wetness ratios indicate that in areas modelled to be more mature, oil may be present in the Toolebuc Formation. These areas are typically in the central Eromanga Basin where the Toolebuc Formation is deepest, though oil responses have been calculated for wells that are shallower. This is contradicted by the apparent maturity of the formation based on vitrinite reflectance and Tmax measurements. Initial burial history modelling of the six petroleum wells indicates that DIO Hammond–1, SSL Clinton–1, DIO Tanbar North–1 and DIO Marengo–1 are in main oil window (0.7–1.0 %Ro) while DIO Denley–1 and DIO Ingella–1 are in the early oil window (0.55–0.7 %Ro). A single erosional event of 550 m of the Winton Formation has been assumed for this modelling. These wells are the deepest intersections of the Toolebuc Formation where it has been modelled to have higher maturity, and mudgas wetness ratios indicate oil may be present. Further refinement of these models and examination of additional wells is needed to better understand the potential for the Toolebuc Formation to have generated petroleum.

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Heath, Philip. "Update on geophysical survey progress from Geoscience Australia and the Geological Surveys of Western Australia, South Australia, Northern Territory, Queensland, New South Wales, Victoria and Tasmania (information current on 23 January 2019). Yvette Poudjom Djomani, Geological Survey of South Australia: Geophysical plans for 2019." Preview 2019, no. 198 (January 2, 2019): 15–17. http://dx.doi.org/10.1080/14432471.2019.1570802.

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Hutton, Laurie, Melanie Fitzell, Kinta Hoffmann, Ian Withnall, Bernie Stockill, Ben Jupp, and Paul Donchak. "The Millungera Basin—new geoscience supporting exploration." APPEA Journal 50, no. 2 (2010): 727. http://dx.doi.org/10.1071/aj09091.

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An unknown sedimentary sequence was first recorded during a Geoscience Australia/ Geological Survey of Queensland/ pmd*CRC deep seismic reflection survey in the Mount Isa Inlier and adjacent undercover terrains, during 2006/07. The sequence occurs unconformably underneath the Carpentaria Basin succession in the Julia Creek area, east of Cloncurry in north Queensland, and is named the Millungera Basin. A section through the basin is recorded along seismic line 07GA–IG1, recorded between north of Cloncurry to east of Croydon. In this section three internal sequences are noted—with two strongly reflective units separated by a poorly reflective unit. As well as deep crustal seismic reflection profiles, magnetotelluric profiles were collected along the same traverse. These data show a moderately conductive Millungera Basin underlying the strongly conductive Carpentaria Basin. Zones of limited reflectors beneath the basin in the seismic sections have been interpreted as granites, raising the possibility of raised geothermal gradients. The Millungera Basin may comprise a potential geothermal target. The Millungera Basin sequence is interpreted to overlie granites. Adjacent Proterozoic granites of the Williams Batholith are known to be high heat producing granites, containing high levels of potassium thorium and uranium. The hydrocarbon potential of the basin is similarly uncertain. Strong reflectors in the seismic sections may be coal beds. Although the depth of the basin in the seismic section is insufficient to have reached the oil window, interpretation of gravity profiles by Geoscience Australia suggest the basin deepens to the south, possibly reaching 4,000 m. If fertile beds have reached the oil window, the structurally more complex eastern side of the basin may contain petroleum traps. The age of the rocks in the Millungera Basin is not known. Constraints from the seismic suggest between the early Mesoproterozoic and the Middle Jurassic. Investigations into the nature of the basin are continuing. A more detailed magnetotellurc survey is being undertaken to better define the shape of the basin. In order to reliably describe the basins components, a deep drilling program is required.

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Djoman, Yvette Poudjom. "Update on geophysical survey progress from Geoscience Australia and the Geological Surveys of Western Australia, South Australia, Northern Territory, Queensland, New South Wales, Victoria and Tasmania (information current on 26 March 2019)." Preview 2019, no. 199 (March 4, 2019): 20–21. http://dx.doi.org/10.1080/14432471.2019.1597668.

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Barlow, Mike. "Update on geophysical survey progress from Geoscience Australia and the Geological Surveys of Western Australia, South Australia, Northern Territory, Queensland, New South Wales, Victoria and Tasmania (information current on 10 July 2019)." Preview 2019, no. 201 (July 4, 2019): 11–13. http://dx.doi.org/10.1080/14432471.2019.1647607.

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Barlow, Mike. "Update on geophysical survey progress from Geoscience Australia and the Geological Surveys of Western Australia, South Australia, Northern Territory, Queensland, New South Wales, Victoria and Tasmania (information current on 17 September 2019)." Preview 2019, no. 202 (September 3, 2019): 15–17. http://dx.doi.org/10.1080/14432471.2019.1672260.

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Barlow, Mike. "Update on geophysical survey progress from Geoscience Australia and the Geological Surveys of Western Australia, South Australia, Northern Territory, Queensland, New South Wales, Victoria and Tasmania (information current on 12 November 2019)." Preview 2019, no. 203 (November 2, 2019): 25–27. http://dx.doi.org/10.1080/14432471.2019.1694472.

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Bailey, Adam H. E., Liuqi Wang, Lisa Hall, and Paul Henson. "Rock properties and in-situ stress state of the Egilabria Prospect, Lawn Hill Platform, Queensland." APPEA Journal 59, no. 1 (2019): 383. http://dx.doi.org/10.1071/aj18260.

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The Energy component of Geoscience Australia’s Exploring for the Future (EFTF) program is aimed at improving our understanding of the petroleum resource potential of northern Australia, in partnership with the state and territory geological surveys. The sediments of the Mesoproterozoic South Nicholson Basin and the underlying Paleoproterozoic Isa Superbasin in the Northern Territory and Queensland are amongst the primary targets of the EFTF Energy program, as they are known to contain organic-rich sedimentary units with the potential to host unconventional gas plays, although their subsurface extent under the cover of the Georgina Basin is presently unknown. In order to economically produce from unconventional reservoirs, the petrophysical rock properties and in-situ stresses must be conducive to the creation of secondary permeability networks that connect a wellbore to as large a reservoir volume as possible. This study utilises data from the recently drilled Armour Energy wells Egilabria 2, Egilabria 2-DW1, and Egilabria 4 to constrain rock properties and in-situ stresses for the Isa Superbasin sequence where intersected on the Lawn Hill Platform of north-west Queensland. These results have implications for petroleum prospectivity in an area with proven gas potential, which are discussed here in the context of the rock properties and in-situ stresses desired for a viable shale gas play. In addition, these results are relevant to potential future exploration across the broader Isa Superbasin sequence.

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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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Codd, A. L., and L. Gross. "Three-dimensional inversion for sparse potential data using first-order system least squares with application to gravity anomalies in Western Queensland." Geophysical Journal International 227, no. 3 (August 13, 2021): 2095–120. http://dx.doi.org/10.1093/gji/ggab323.

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SUMMARY We present an inversion algorithm tailored for point gravity data. As the data are from multiple surveys, it is inconsistent with regards to spacing and accuracy. An algorithm design objective is the exact placement of gravity observations to ensure no interpolation of the data is needed prior to any inversion. This is accommodated by discretization using an unstructured tetrahedral finite-element mesh for both gravity and density with mesh nodes located at all observation points and a first-order system least-squares (FOSLS) formulation for the gravity modelling equations. Regularization follows the Bayesian framework where we use a differential operator approximation of an exponential covariance kernel, avoiding the usual requirement of inverting large dense covariance matrices. Rather than using higher order basis functions with continuous derivatives across element faces, regularization is also implemented with a FOSLS formulation using vector-valued property function (density and its gradient). Minimization of the cost function, comprised of data misfit and regularization, is achieved via a Lagrange multiplier method with the minimum of the gravity FOSLS functional as a constraint. The Lagrange variations are combined into a single equation for the property function and solved using an integral form of the pre-conditioned conjugate gradient method (I-PCG). The diagonal entries of the regularization operator are used as the pre-conditioner to minimize computational costs and memory requirements. Discretization of the differential operators with the finite-element method (FEM) results in matrix systems that are solved with smoothed aggregation algebraic multigrid pre-conditioned conjugate gradient (AMG-PCG). After their initial setup, the AMG-PCG operators and coarse grid solvers are reused in each iteration step, further reducing computation time. The algorithm is tested on data from 23 surveys with a total of 6519 observation points in the Mt Isa–Cloncurry region in north–west Queensland, Australia. The mesh had about 2.5 million vertices and 16.5 million cells. A synthetic case was also tested using the same mesh and error measures for localized concentrations of high and low densities. The inversion results for different parameters are compared to each other as well as to lower order smoothing. Final inversion results are shown with and without depth weighting and compared to previous geological studies for the Mt Isa–Cloncurry region.

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Dunlop, Erik C., David S. Warner, Prue E. R. Warner, and Louis R. Coleshill. "Ultra-deep Permian coal gas reservoirs of the Cooper Basin: insights from new studies." APPEA Journal 57, no. 1 (2017): 218. http://dx.doi.org/10.1071/aj16015.

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There is a vast, untapped gas resource in deep coal seams of the Cooper Basin, where extensive legacy gas infrastructure facilitates efficient access to markets. Proof-of-concept for the 5 million acre (20 000km2) Cooper Basin Deep Coal Gas (CBDCG) Play was demonstrated by Santos Limited in 2007 during the rise of shale gas. Commercial viability on a full-cycle, standalone basis is yet to be proven. If commercial reservoirs in nanoDarcy matrix permeability shale can be manufactured by engineers, why not in deep, dry, low-vitrinite, poorly cleated coal seams having comparable matrix permeability but higher gas content? Apart from gas being stored in a source rock reservoir format, there is little similarity to other unconventional plays. Without an analogue, development of an optimal reservoir stimulation technology must be undertaken from first principles, using deep coal-specific geotechnical and engineering assumptions. Results to date suggest that stimulation techniques for other unconventional reservoirs are unlikely to be transferable. A paradigm shift in extraction technology may be required, comparable to that devised for shale reservoirs. Recent collaborative studies between the South Australian Department of State Development, Geological Survey of Queensland and Geoscience Australia provide new insight into the hydrocarbon generative capacity of Cooper Basin coal seams. Sophisticated regional modelling relies upon a limited coal-specific raw dataset involving ~90 (5%) of the total 1900 wells penetrating Permian coal. Complex environmental overprints affecting resource concentration and gas flow capacity are not considered. Detailed resource estimation and the detection of anomalies such as sweet spots requires the incorporation of direct measurement. To increase granularity, the authors are conducting an independent, basin-wide review of underutilised open file data, not yet used for unconventional reservoir purposes. Reservoir parameters are quantified for seams thicker than 10feet (3m), primarily using mudlogs and electric logs. To date, ~3750 reservoir intersections are characterised in ~1000 wells. Some parameters relate to resource, others to extraction. A gas storage proxy is generated, not compromised by desorption lost gas corrections. A 2016 United States Geological Survey resource assessment, based on Geoscience Australia studies, suggests that the Play remains a world-class opportunity, despite being technology-stranded for the past 10years. Progress has been made in achieving small but incrementally economic flow rates from add-on hydraulic fracture stimulation treatments inside conventional gas fields. Nevertheless, a geology/technology impasse precludes full-cycle, standalone commercial production. A review of open file data and cross-industry literature suggests that the root cause is the inability of current techniques to generate the massive fracture network surface area essential for high gas flow. Coal ductility and high initial reservoir confining stress are interpreted to be responsible. Ultra-deep coal reservoirs, like shale reservoirs, must be artificially created by a large-scale stimulation event. Although coal seams fail the reservoir ‘brittleness test’ for shale reservoir stimulation practices, the authors conclude from recent studies that pervasive, mostly cemented or closed coal fabric planes of weakness may instead be reactivated on a large scale, to create a shale reservoir-like stimulated reservoir volume (SRV), by mechanisms which harness the reservoir stress reduction capacity of desorption-induced coal matrix shrinkage.

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Southgate, Peter, Keith Sircombe, and Christopher Lewis. "New insights into reservoir sand provenance in the Exmouth Plateau and Browse Basin." APPEA Journal 51, no. 2 (2011): 715. http://dx.doi.org/10.1071/aj10095.

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A pilot study to determine if zircons present in reservoir facies of the North West Shelf can be used to identify provenance and sediment transport pathways has analysed samples from three wells: Guardian–1 and Hijinx–1 (Carnarvon Basin), and Burnside–1 (Browse Basin). Operating companies Chevron, Santos and Hess collected 3–5 kg of cuttings from sandstone bodies intersected in the three wells. Samples were sent to Geoscience Australia for zircon separation and analysis at the Geochronology Laboratory on a sensitive high-resolution ion microprobe (SHRIMP). To provide a statistically meaningful representation of ages in each sample, 70–80 grains were randomly selected for analysis. During the past 20 years, Geoscience Australia and the state geological surveys of WA, NT, Queensland and SA, together with the ANU, UWA and Curtin University, have analysed zircons found in igneous and sedimentary rocks that outcrop in WA and central Australia. This analysis has been done to determine the ages of emplacement, extrusion or maximum depositional ages. This dataset permits the ages of potential onshore provenance areas to be differentiated; hence, correlations can be made between zircons contained within the transported sands and their potential source regions from onshore Australia. In this extended abstract, the spectrum of ages in each sample will be shown, and potential provenance and sediment transport pathways will be discussed. The abstract concludes with the outline of a 2–3 year project to obtain a dataset that will provide a regional stratigraphic and spatial coverage of the North West Shelf for provenance studies.

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Donovan, D. T. "Geological Survey." Nature 362, no. 6421 (April 1993): 583. http://dx.doi.org/10.1038/362583d0.

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Kavanagh, Etta. "U.S. Geological Survey." Eos, Transactions American Geophysical Union 75, no. 7 (1994): 75. http://dx.doi.org/10.1029/94eo00780.

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HAO, Ziguo, Hongcai FEI, Lian LIU, Qingqing HAO, and Susan TURNER. "2015-2020 Geological Survey Program of China Geological Survey Bureau." Acta Geologica Sinica - English Edition 88, no. 6 (December 2014): 1917–19. http://dx.doi.org/10.1111/1755-6724.12357.

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Lü, Qing-tian, Jia-yong Yan, Xuan-hua Chen, He-sheng Hou, Wen-shi Wang, and Yu-le Hu. "Progress of Deep Geological Survey Project under the China Geological Survey." China Geology 3, no. 1 (2020): 153–72. http://dx.doi.org/10.31035/cg2020001.

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30

Bush, S. "Minnesota geological survey funded." Eos, Transactions American Geophysical Union 73, no. 10 (1992): 107. http://dx.doi.org/10.1029/91eo00083.

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31

Kato, Susumu. "Geological survey of oil fields in Japan by Geological Survey of Japan." Journal of the Japanese Association for Petroleum Technology 83, no. 4 (October 22, 2018): 267–73. http://dx.doi.org/10.3720/japt.83.267.

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32

Kato, Susumu. "Geological survey of oil fields in Japan by Geological Survey of Japan." Journal of the Japanese Association for Petroleum Technology 83, no. 4 (October 22, 2018): 267–73. http://dx.doi.org/10.3720/japt.83.267.

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33

Clifford, H. T., and Alex Cook. "A presumed Leichhardt geological specimen in the Queensland Museum." Memoirs of the Queensland Museum - Nature 59 (2015): 186. http://dx.doi.org/10.17082/j.2204-1478.59.2015.2015-05.

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34

Bradshaw, Barry E., Lynton K. Spencer, Anna-Liisa Lahtinen, Kamal Khider, Damien J. Ryan, Jim B. Colwell, Alfredo Chirinos, et al. "An assessment of Queensland’s CO2 geological storage prospectivity — The Queensland CO2 Geological Storage Atlas." Energy Procedia 4 (2011): 4583–90. http://dx.doi.org/10.1016/j.egypro.2011.02.417.

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Murdie, Ruth. "Geological Survey of Western Australia: Geological Survey of Western Australia’s Accelerated Geoscience Program." Preview 2021, no. 213 (July 4, 2021): 24–25. http://dx.doi.org/10.1080/14432471.2021.1958521.

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Haydon, Suzanne. "Geological Survey of Victoria: News." Preview 2019, no. 201 (July 4, 2019): 20–21. http://dx.doi.org/10.1080/14432471.2019.1647598.

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LUMSDEN, G. I., and R. T. HAWORTH. "The British Geological Survey Database." Journal of the Geological Society 143, no. 3 (May 1986): 379–80. http://dx.doi.org/10.1144/gsjgs.143.3.0379.

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38

Draper, J. J., and C. J. Boreham. "GEOLOGICAL CONTROLS ON EXPLOITABLE COAL SEAM GAS DISTRIBUTION IN QUEENSLAND." APPEA Journal 46, no. 1 (2006): 343. http://dx.doi.org/10.1071/aj05019.

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Methane is present in all coals, but a number of geological factors influence the potential economic concentration of gas. The key factors are (1) depositional environment, (2) tectonic and structural setting, (3) rank and gas generation, (4) gas content, (5) permeability, and (6) hydrogeology. Commercial coal seam gas production in Queensland has been entirely from the Permian coals of the Bowen Basin, but the Jurassic coals of the Surat and Clarence-Moreton basins are poised to deliver commercial gas volumes.Depositional environments range from fluvial to delta plain to paralic and marginal marine—coals in the Bowen Basin are laterally more continuous than those in the Surat and Clarence-Moreton basins. The tectonic and structural settings are important as they control the coal characteristics both in terms of deposition and burial history. The important coal seam gas seams were deposited in a foreland setting in the Bowen Basin and an intracratonic setting in the Surat and Clarence-Moreton basins. Both of these settings resulted in widespread coal deposition. The complex burial history of the Bowen Basin has resulted in a wide range of coal ranks and properties. Rank in the Bowen Basin coal seam gas fields varies from vitrinite reflectance of 0.55% to >1.1% Rv and from Rv 0.35-0.6% in the Surat and Clarence-Moreton basins in Queensland. High vitrinite coals provide optimal gas generation and cleat formation. The commercial gas fields and the prospective ones contain coals with >60% vitrinite.Gas generation in the Queensland basins is complex with isotopic studies indicating that biogenic gas, thermogenic gas and mixed gases are present. Biogenic processes occur at depths of up to a kilometre. Gas content is important, but lower gas contents can be economic if deliverability is good. Free gas is also present. Drilling and production techniques play an important role in making lower gas content coals viable. Since the Bowen and Surat basins are in a compressive regime, permeability becomes a defining parameter. Areas where the compression is offset by tensional forces provide the best chances for commercial coal seam gas production. Tensional setting such as anticline or structural hinges are important plays. Hydrodynamics control the production rate though water quality varies between the fields.

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HAO, Ziguo, Hongcai FEI, Qingqing HAO, and Susan TURNER. "Status of China's Geological Survey and Geological Environments in 2013." Acta Geologica Sinica - English Edition 88, no. 3 (June 2014): 1020–21. http://dx.doi.org/10.1111/1755-6724.12256.

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Rutherford, Shannon, Judith A. K. Owen, and Rod W. Simpson. "Survey of airspora in Brisbane, Queensland, Australia." Grana 36, no. 2 (January 1997): 114–21. http://dx.doi.org/10.1080/00173139709362597.

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Richardson, Joanna, Therese Nolan-Brown, Pat Loria, and Stephanie Bradbury. "Library Research Support in Queensland: A Survey." Australian Academic & Research Libraries 43, no. 4 (December 2012): 258–77. http://dx.doi.org/10.1080/00048623.2012.10722287.

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Garton, BJ, and PJ Ford. "Root caries: a survey of Queensland dentists." International Journal of Dental Hygiene 11, no. 3 (February 21, 2013): 216–25. http://dx.doi.org/10.1111/idh.12018.

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Hodgkinson, J. H., S. McLoughlin, and M. E. Cox. "Drainage patterns in southeast Queensland: the key to concealed geological structures?" Australian Journal of Earth Sciences 54, no. 8 (December 2007): 1137–50. http://dx.doi.org/10.1080/08120090701615766.

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HORI, Yoshinao. "Geological survey and visualization of underground." JOURNAL OF THE FLOW VISUALIZATION SOCIETY OF JAPAN 7, no. 27 (1987): 405–10. http://dx.doi.org/10.3154/jvs1981.7.405.

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Zhaojun Xu, Jiqiu Deng, Huangling Gu, and Na Li. "Hunan Geological Disaster Emergency Survey System." International Journal of Digital Content Technology and its Applications 7, no. 6 (March 31, 2013): 852–60. http://dx.doi.org/10.4156/jdcta.vol7.issue6.96.

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KANZAKI, Yutaka, and Yukiyasu FUJII. "Using Digital Gadgets in Geological Survey :." Journal of the Japan Society of Engineering Geology 59, no. 4 (October 10, 2018): 213–18. http://dx.doi.org/10.5110/jjseg.59.213.

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McNeely, Roger. "Geological Survey of Canada Soil Database." Radiocarbon 38, no. 2 (1996): 271–75. http://dx.doi.org/10.1017/s0033822200017641.

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The Geological Survey of Canada (GSC) has developed, over the past decade, a user-oriented database, Date Locator File, of Canadian samples dated by the 14C technique. This database presently contains >3500 soil and soil-related dates. The primary category in this suite of dates is peat, as a large portion of the Canadian landscape is covered with this type of organic soil. The data is available gratis to all researchers in a large variety of formats from simple lists to complex tables for inclusion in publications. The site localities can also be plotted on base maps suitable for publication. The database is actively augmented on an ongoing basis, but to continue to be relevant, it depends largely on the altruism of the scientific community.

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Stark, Peter. "The United States geological survey website." Government Information Quarterly 14, no. 4 (January 1997): 414–15. http://dx.doi.org/10.1016/s0740-624x(97)90042-3.

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Brenchley, P. J. "Publications from the British Geological Survey." Geological Journal 39, no. 2 (April 2004): 227–28. http://dx.doi.org/10.1002/gj.971.

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"Geological Survey of Queensland: Newly released airborne data and MT survey in the North West Mineral Province." Preview 2020, no. 209 (November 1, 2020): 23–24. http://dx.doi.org/10.1080/14432471.2020.1855774.

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Journal articles on the topic 'Geological Survey of Queensland'

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