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Artykuły w czasopismach na temat „Eromanga Basin”

Autor: Grafiati

Data publikacji: 4 czerwca 2021

Data aktualizacji: 29 stycznia 2023

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1

Pole, Mike S. "Mid-cretaceous conifers from the Eromanga Basin, Australia." Australian Systematic Botany 13, no. 2 (2000): 153. http://dx.doi.org/10.1071/sb99001.

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Mid-Cretaceous (latest Albian–earliest Cenomanian) sediment in sevenbore cores from the Eromanga Basin (south-western Queensland) was sampled fororganically preserved plant macrofossils. Among those recovered, 26 taxa ofconifers have been distinguished. Families Araucariaceae, Podocarpaceae, andCheirolepidiaceae were prominent. The Araucariaceae includeAraucaria sp., while the remainder are considered torepresent extinct genera. Podocarpaceae are all species of extinct genera andtwo new genera are described: Eromangia andThargomindia. There are two species ofCheirolepidiaceae. One of these, Ge

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2

Wecker, H. R. B. "THE EROMANGA BASIN." APPEA Journal 29, no. 1 (1989): 379. http://dx.doi.org/10.1071/aj88032.

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The Eromanga Basin, encompassing an area of approximately 1 million km2 in Central Australia, is a broad intracratonic downwarp containing up to 3000 m of Middle Triassic to Late Cretaceous sediments.Syndepositional tectonic activity within the basin was minimal and the main depocentres largely coincide with those of the preceding Permo- Triassic basins. Several Tertiary structuring phases, particularly in the Early Tertiary, have resulted in uplift and erosion of the Eromanga Basin section along its eastern margin, and the development of broad, northwesterly- to northeasterly- trending anticl

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3

Lavering, L. H., V. L. Passmore, and I. M. Paton. "DISCOVERY AND EXPLOITATION OF NEW OILFIELDS IN THE COOPER-EROMANGA BASINS." APPEA Journal 26, no. 1 (1986): 250. http://dx.doi.org/10.1071/aj85024.

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Since 1975 the level of petroleum exploration in the Cooper-Eromanga basins has undergone an unprecedented expansion due to the discovery and development of an increasing number of oil reservoirs, largely in the Eromanga Basin sequence. The commercial incentive provided by the Commonwealth Government's Import Parity Pricing and excise arrangements have been instrumental in the lead up to and continuation of this series of discoveries.Three types of oil discovery in the Eromanga Basin sequence are evident; firstly, shallow pools above Cooper Basin gas fields; secondly, separate single-field dis

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4

Alexander, R., A. V. Larcher, R. I. Kagi, and P. L. Price. "THE USE OF PLANT DERIVED BIOMARKERS FOR CORRELATION OF OILS WITH SOURCE ROCKS IN THE COOPER/EROMANGA BASIN SYSTEM, AUSTRALIA." APPEA Journal 28, no. 1 (1988): 310. http://dx.doi.org/10.1071/aj87024.

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Whether or not the sediments in the Eromanga Basin have generated petroleum is a problem of considerable commercial importance which remains contentious as it has not yet been resolved unequivocally. Sediments of the underlying Cooper Basin were deposited throughout the Permian and much of the Triassic, and deposition in the overlying Eromanga Basin commenced in the Early Jurassic and extended into the Cretaceous. As Araucariaceae (trees of the kauri pine group) assumed prominence for the first time in the Early to Middle Jurassic and were all but absent in older sediments, a promising approac

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5

Boreham, C. J., and R. E. Summons. "NEW INSIGHTS INTO THE ACTIVE PETROLEUM SYSTEMS IN THE COOPER AND EROMANGA BASINS, AUSTRALIA." APPEA Journal 39, no. 1 (1999): 263. http://dx.doi.org/10.1071/aj98016.

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This paper presents geochemical data—gas chromatography, saturated and aromatic biomarkers, carbon isotopes of bulk fractions and individual n-alkanes—for oils and potential source rocks in the Cooper and Eromanga basins, which show clear evidence for different source-reservoir couplets. The main couplets involve Cooper Basin source and reservoir and Cooper Basin source and Eromanga Basin reservoir. A subordinate couplet involving Eromanga Basin source and Eromanga Basin reservoir is also identified, together with minor inputs from pre-Permian source rocks to reservoirs of the Cooper and Eroma

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6

Schulz-Rojahn, J. P. "CALCITE-CEMENTED ZONES IN THE EROMANGA BASIN: CLUES TO PETROLEUM MIGRATION AND ENTRAPMENT?" APPEA Journal 33, no. 1 (1993): 63. http://dx.doi.org/10.1071/aj92006.

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The occurrence of calcite cementation zones in oil- bearing sequences of the Jurassic-Cretaceous Eromanga Basin is of importance to petroleum exploration. The erratic distribution and thickness of these calcite-cemented intervals is problematic for both prediction of subsurface reservoir quality and structural interpretation of seismic data due to velocity anomalies.Carbon isotope signatures suggest the carbonate cements may form by dissipation of carbon dioxide upward from the Cooper Basin into the calcium-bearing J-aquifers of the Great Artesian Basin of which the Eromanga Basin forms a part

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7

John, B. H., and C. S. Almond. "LITHOSTRATIGRAPHY OF THE LOWER EROMANGA BASIN SEQUENCE IN SOUTH WEST QUEENSLAND." APPEA Journal 27, no. 1 (1987): 196. http://dx.doi.org/10.1071/aj86017.

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Five fully-cored and wire-line logged stratigraphic bores have been drilled by the Queensland Department of Mines, relatively close to producing oil fields in the Eromanga Basin, south-west Queensland. Correlations between the stratigraphic bores and petroleum wells have established lithologic control in an area where lithostratigraphy is interpreted mainly from wire-line logs. The Eromanga Basin sequence below the Wallumbilla Formation has been investigated, and a uniform lithostratigraphic nomenclature has been applied; in the past, an inconsistent nomenclature system was applied in differen

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8

Gisolf, A. "OFF-END SEISMIC DATA ACQUISITION IN THE EROMANGA BASIN." APPEA Journal 30, no. 1 (1990): 355. http://dx.doi.org/10.1071/aj89023.

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During late 1988 and early 1989 Shell conducted a land seismic survey in permit ATP 267P in the Eromanga Basin, in fulfilment of farm-in obligations. Against traditional wisdom in the Eromanga Basin Shell decided for an off-end acquisition geometry.An acquisition geometry design rationale is presented which leads to an optimum stack response. Depending on geological and economical constraints on maximum offset and shot and receiver station spacing this may result in either a split spread or an off-end geometry.For Shell's Eromanga seismic campaign it was decided that, given a 120 channel seism

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9

Deighton, I., J. J. Draper, A. J. Hill, and C. J. Boreham. "A HYDROCARBON GENERATION MODEL FOR THE COOPER AND EROMANGA BASINS." APPEA Journal 43, no. 1 (2003): 433. http://dx.doi.org/10.1071/aj02023.

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The aim of the National Geoscience Mapping Accord Cooper-Eromanga Basins Project was to develop a quantitative petroleum generation model for the Cooper and Eromanga Basins by delineating basin fill, thermal history and generation potential of key stratigraphic intervals. Bio- and lithostratigraphic frameworks were developed that were uniform across state boundaries. Similarly cross-border seismic horizon maps were prepared for the C horizon (top Cadna-owie Formation), P horizon (top Patchawarra Formation) and Z horizon (base Eromanga/Cooper Basins). Derivative maps, such as isopach maps, were

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10

Kuang, K. S. "History and style of Cooper?Eromanga Basin structures." Exploration Geophysics 16, no. 2-3 (June 1985): 245–48. http://dx.doi.org/10.1071/eg985245.

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11

Cook, Alex G. "Cretaceous faunas and events, northern Eromanga Basin, Queensland." Episodes 35, no. 1 (March 1, 2012): 153–59. http://dx.doi.org/10.18814/epiiugs/2012/v35i1/014.

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12

McIntyre, Steven. "Analysis of predictive performance in the Eromanga Basin." APPEA Journal 52, no. 2 (2012): 678. http://dx.doi.org/10.1071/aj11092.

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Strategic and operational management in the exploration and production business is characterised by prediction and decision making in a data-rich, high-uncertainty environment. Analysis of predictive performance since the 1970s by multiple researchers indicates that predictions are subject to over-confidence and optimism negatively impacting performance. The situation is the same for other areas of human endeavour also operating within data-rich, high-uncertainty environments. Research in the fields of psychology and neuroscience indicates the way in which the human brain perceives, integrates

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13

Bishop, Ian, and Steve Martucci. "WELL TUBULAR CORROSION IN THE COOPER/EROMANGA BASIN." APPEA Journal 31, no. 1 (1991): 404. http://dx.doi.org/10.1071/aj90034.

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In September 1987 the Della-1 gas well blew out at approximately 19.5m (64ft) abovesea level (42.7m (140 ft) KB) due to corrosion of the production casing and tubing.The production casing failure and other similar corrosion occurrences were considered to be due to sulphate-reducing bacteria which have been identified in a large number of wells in the Cooper Basin. It was considered possible that iron sulphide was being deposited on the casings in the surface-to-production casing annulus at the air/water interface promoting the formation of anodic sites and therefore corrosion.Further investiga

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14

Boult, P. J., E. Lanzilli, B. H. Michaelsen, D. M. McKirdy, and M. J. Ryan. "A NEW MODEL FOR THE HUTTON/BIRKHEAD RESERVOIR/SEAL COUPLET AND THE ASSOCIATED BIRKHEAD-HUTTON(!) PETROLEUM SYSTEM." APPEA Journal 38, no. 1 (1998): 724. http://dx.doi.org/10.1071/aj97048.

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Biomarker analysis of source rocks and oils from the Permian and Jurassic of the central Patchawarra Trough and the Gidgealpa area, reveal that much of the oil in the Eromanga Basin may have a significant lateral migrational component and be of Jurassic (i.e. intra-Eromanga) origin. Differences in hopane signatures can be used to discriminate between palaeo-oil and presently migrating live oil, and to constrain migration pathways. Thus, in some locations the identification of new source kitchens has been made possible by a combination of seal and biomarker analysis taking into account stratigr

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15

Lockhart, D. A., E. Riel, M. Sanders, A. Walsh, G. T. Cooper, and M. Allder. "Play-based exploration in the southern Cooper Basin: a systematic approach to exploration in a mature basin." APPEA Journal 58, no. 2 (2018): 825. http://dx.doi.org/10.1071/aj17138.

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Exploration within a mature basin poses many challenges, not least how to best utilise resources and time to maximise success and reduce cost. Play-based exploration (PBE) provides a team-based approach to combine key aspects of the petroleum system into an integrated and wholistic view of basin prospectivity. While the PBE methodology is well established, it is not often applied to its full extent on a basin scale. After a period of declining exploration success in parts of the South Australia Cooper-Eromanga Basin, this study was undertaken by a dedicated regional geoscience team with the ai

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16

Röth, Joschka, and Ralf Littke. "Down under and under Cover—The Tectonic and Thermal History of the Cooper and Central Eromanga Basins (Central Eastern Australia)." Geosciences 12, no. 3 (March 2, 2022): 117. http://dx.doi.org/10.3390/geosciences12030117.

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The Cooper subregion within the central Eromanga Basin is the Swiss army knife among Australia’s sedimentary basins. In addition to important oil and gas resources, it hosts abundant coal bed methane, important groundwater resources, features suitable conditions for enhanced geothermal systems, and is a potential site for carbon capture and storage. However, after seven decades of exploration, various uncertainties remain concerning its tectonic and thermal evolution. In this study, the public-domain 3D model of the Cooper and Eromanga stacked sedimentary basins was modified by integrating the

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17

Kaushik, Pankaj R., Christopher E. Ndehedehe, Ryan M. Burrows, Mark R. Noll, and Mark J. Kennard. "Assessing Changes in Terrestrial Water Storage Components over the Great Artesian Basin Using Satellite Observations." Remote Sensing 13, no. 21 (November 6, 2021): 4458. http://dx.doi.org/10.3390/rs13214458.

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The influence of climate change and anthropogenic activities (e.g., water withdrawals) on groundwater basins has gained attention recently across the globe. However, the understanding of hydrological stores (e.g., groundwater storage) in one of the largest and deepest artesian basins, the Great Artesian Basin (GAB) is limited due to the poor distribution of groundwater monitoring bores. In this study, Gravity Recovery and Climate Experiment (GRACE) satellite and ancillary data from observations and models (soil moisture, rainfall, and evapotranspiration (ET)) were used to assess changes in ter

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18

Cull, J. P., and J. D. Gray. "Sediment compaction and magnetotelluric data in the Eromanga Basin." Exploration Geophysics 20, no. 2 (1989): 335. http://dx.doi.org/10.1071/eg989335.

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Magnetotelluric data obtained in the Eromanga Basin can be interpreted using one-dimensional models to describe plane layers consistent with geological mapping. Interpretations are based on the results of non-linear inversions generating a minimum least-squares error between the observations and the model. However there is no statistical justification for selecting highly complex starting models. In particular adequate solutions can be generated using models based on 2, 3 or 4 layers over basement; additional layers defining fine structure can only be retained using external geological constra

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19

Lowry, David, and David Evans. "Eromanga (Queensland) exploration–new concepts for an old basin." APPEA Journal 51, no. 1 (2011): 333. http://dx.doi.org/10.1071/aj10021.

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Eromanga Basin exploration surged in Queensland after the discovery of the Jackson field in 1982, but has ebbed over the last 20 years. Perceived exploration risks are: • Oil generation and migration peaked in the mid-Cretaceous before much of the anticlinal structuring, so that modern structure is an uncertain guide to Cretaceous migration paths. • Permian coals are generally credited with sourcing most of the oil and gas in the Cooper-Eromanga Basin. In Queensland, the Permian largely drains to the southern flank and the northern flank is thought to have a high charge risk. This study covers

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20

Khorasani, Ganjavar Khavari. "RECENT ORGANIC GEOCHEMICAL EVALUATION OF THE CENTRAL EROMANGA BASIN." APPEA Journal 27, no. 1 (1987): 106. http://dx.doi.org/10.1071/aj86011.

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Systematic analyses of bulk properties and of molecular composition, by gas chromatography (GC), fluorescence spectroscopy, gas chromatography-mass spectroscopy (GC-MS), reflectance photometry and 'Rock-Eval' pyrolysis of core samples from three stratigraphic bores from the central and northern-central Eromanga Basin, reveal the following:The organic facies variations in the central Eromanga are considerable; however, the biofacies can be grouped into three major types.The sediments do not enter the mature zone of oil generation until a reflectance level of 0.65 per cent Rv max. or higher is r

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21

Rodgers, J., F. L. Wehr, and J. W. Hunt. "Tertiary uplift estimation from velocity data in the Eromanga Basin." Exploration Geophysics 22, no. 2 (June 1991): 321–24. http://dx.doi.org/10.1071/eg991321.

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22

Hardman, Jonathon, Simon Holford, Nick Schofield, Mark Bunch, and Daniel Gibbins. "Nature and origin of Jurassic volcanism in the Eromanga Basin." ASEG Extended Abstracts 2019, no. 1 (November 11, 2019): 1–5. http://dx.doi.org/10.1080/22020586.2019.12072957.

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Gibson, DL. "Post-early cretaceous landform evolution along the western margin of the Bancannia trough, western NSW." Rangeland Journal 22, no. 1 (2000): 32. http://dx.doi.org/10.1071/rj0000032.

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Previously undated post-Devonian sediments outcropping north of Fowlers Gap station near the western margin of the Bancannia Trough are shown by plant macro- and microfossil determinations to be of Early Cretaceous (most likely Neocomian and/or Aptian) age, and thus part of the Eromanga Basin. They are assigned to the previously defined Teleplione Creek Formation. Study of the structural configuration of this unit and the unconformably underlying Devonian rocks suggests that the gross landscape architecture of the area results from post-Early Cretaceous monoclinal folding along blind faults at

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24

Craig, Adam. "Exploration and appraisal year in review 2021." APPEA Journal 62, no. 2 (May 13, 2022): S527—S536. http://dx.doi.org/10.1071/aj21222.

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Petroleum exploration and appraisal activity increased in 2021. Exploration spend increased for the year, continuing a positive trend. Onshore exploration and appraisal activity continues to dominate the petroleum exploration scene in Australia. Positive indications of increased work program bids (wells, seismic and spend) are, however, tempered by the downward trend of total exploration acreage (by area) and new acreage awards. In addition to petroleum exploration acreage, greenhouse gas sequestration acreage was released across Australia in 2021. Twenty-nine exploration wells were drilled in

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25

Tupper, N. P., and D. M. Burckhardt. "USE OF THE METHYLPHENANTHRENE INDEX TO CHARACTERISE EXPULSION OF COOPER AND EROMANGA BASIN OILS." APPEA Journal 30, no. 1 (1990): 373. http://dx.doi.org/10.1071/aj89025.

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The methylphenanthrene index (MPI) molecular maturity parameter is available for over 100 Cooper and Eromanga Basin oils. Oil maturity data define the threshold and range of expulsion maturity for source rocks and can be used to determine oil-source affinity. Mapping of this maturity range for all potential source rocks identifies areas of greatest oil potential.Cooper and Eromanga oils were expelled over a wide maturity range commencing at 0.6 per cent calculated vitrinite reflectance equivalent in some parts of the basin. Oil occurrence and expulsion maturity are controlled by variations in

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26

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 sev

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27

Gallagher, KERRY, and KURT Lambeck. "Subsidence, sedimentation and sea-level changes in the Eromanga Basin, Australia." Basin Research 2, no. 2 (June 1989): 115–31. http://dx.doi.org/10.1111/j.1365-2117.1989.tb00030.x.

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Watts, K. J. "THE HUTTON SANDSTONE-BIRKHEAD FORMATION TRANSITION, ATP 269P(1), EROMANGA BASIN." APPEA Journal 27, no. 1 (1987): 215. http://dx.doi.org/10.1071/aj86018.

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The Hutton Sandstone and Birkhead Formation are the reservoir and seal, respectively, for most ofthe oil discovered in the Eromanga Basin. The traps are generally simple anticlinal closures; however stratigraphic complexities are common. Development well failures in ATP 269P(1) are commonly caused by stratigraphic variations at the Hutton-Birkhead transition.In ATP 269P(1) two distinct sandstone compositions are present over the Hutton-Birkhead transition, and are end-members of a spectrum of compositions. The first end-member consists of porous and permeable quartzose sandstone which is typic

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29

Newton, C. B. "THE TINTABURRA OILFIELD." APPEA Journal 26, no. 1 (1986): 334. http://dx.doi.org/10.1071/aj85029.

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The Tintaburra oilfield, discovered in December 1983 with the drilling of Tintaburra 1, is situated within Petroleum Lease 29 (previously within Authority to Prospect 299P Part 2) on the southeast margin of the Eromanga Basin, Queensland.Tintaburra 1 recorded the first flow of oil from the Cretaceous Wyandra Sandstone Member of the Cadnaowie Formation in the Eromanga Basin and established the presence of oil columns in the Murta Member and Hutton Sandstone. The Hutton Sandstone produced 1750 barrels of 44° API gravity oil per day on drill stem test.The results of six successful appraisal wells

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Keany, Mitchell, Simon Holford, and Mark Bunch. "Constraining Late Cretaceous exhumation in the Eromanga Basin using sonic velocity data." APPEA Journal 56, no. 1 (2016): 101. http://dx.doi.org/10.1071/aj15009.

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Exhumation in sedimentary basins can have significant consequences for their petroleum systems. For example, source rocks may be more mature than their present-day burial depths suggest, increased compaction can result in reduced reservoir quality, and seal integrity problems are commonly encountered. The Eromanga Basin in central Australia experienced an important phase of exhumation during the Late Cretaceous, though the magnitude and spatial distribution of exhumation is poorly constrained. In this study exhumation magnitudes have been determined for 100 petroleum wells based on sonic trans

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31

Mai, P. S. Moore D. K. Hobday H., and Z. C. Sun. "COMPARISON OF SELECTED NON-MARINE PETROLEUM-BEARING BASINS IN AUSTRALIA AND CHINA." APPEA Journal 26, no. 1 (1986): 285. http://dx.doi.org/10.1071/aj85026.

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This paper summarises the geology and hydrocarbon potential of two Chinese and two Australian basins (Ordos, Northern Jiangsu, Eromanga, and Surat basins) in order to compare factors affecting the generation, migration, and entrapment of hydrocarbons. In all four basins, hydrocarbons are generated from nonmarine source rocks of lacustrine and fluvial-overbank origin. While the Chinese and Australian basins contain a similar range of sedimentary facies, from alluvial fan to lacustrine, the arrangement and relative thicknesses of these facies vary considerably as a result of different tectonic a

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32

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

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Chua, Min Lee, Sergey Birdus, Alexey Artyomov, and Joe Miller. "Case study: Successful application of 3D depth processing in Eromanga Basin, Queensland." ASEG Extended Abstracts 2013, no. 1 (December 2013): 1–3. http://dx.doi.org/10.1071/aseg2013ab260.

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Armanios, Carim, Robert Alexander, Imam B. Sosrowidjojo, and Robert I. Kagi. "Identification of bicadinanes in Jurassic organic matter from the Eromanga Basin, Australia." Organic Geochemistry 23, no. 9 (September 1995): 837–43. http://dx.doi.org/10.1016/0146-6380(95)80004-b.

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Bradshaw, Barry E., Nadege Rollet, Jeremy Iwanec, and Tom Bernecker. "A regional chronostratigraphic framework for play-based resource assessments in the Eromanga Basin." APPEA Journal 62, no. 2 (May 13, 2022): S392—S399. http://dx.doi.org/10.1071/aj21097.

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Geoscience Australia is undertaking a series of basin-scale assessments to identify the ‘yet-to-find’ resource potential for hydrocarbons, as well as for groundwater resources and carbon capture and storage (CCS) opportunities in central Australia under the Exploring for the Future (EFTF) Program. A play-based exploration approach is being used to systematically evaluate the key risk elements for each resource type through the analysis of drilling results and spatial data to map ‘sweet spots’ for exploration. These assessments aim to reduce the risks and uncertainties for explorers by providin

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36

Randal, M. A. "PETROLEUM EXPLORATION AND DEVELOPMENTS IN QUEENSLAND DURING 1985." APPEA Journal 26, no. 2 (1986): 46. http://dx.doi.org/10.1071/aj85051.

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Petroleum exploration in Queensland during 1985 remained at the high levels that existed during 1984. Of the 115 wells spudded, 88 were wildcat exploration wells, 24 were appraisal wells, and three were development wells. New field discoveries numbered 23, being 16 oil and 7 of gas, the highest number ever recorded. All but two of the appraisal wells and all three development wells were successful. Seismic surveys totalled 23 158 km of subsurface section, 75 per cent in the western part of the state in the Eromanga/Cooper and Eromanga/Galilee basins and their environs, and the remainder in the

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Shirley, Erin. "Investigating depth structure uncertainty for horizontal well placement, Bauer Field, Cooper-Eromanga Basin." APPEA Journal 58, no. 2 (2018): 865. http://dx.doi.org/10.1071/aj17198.

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The Bauer Field was discovered in August 2011 on the Western Flank of the Cooper-Eromanga Basin. Bauer 1 discovered an 11 m oil column in the Namur Sandstone, directly overlain by a 4 m oil column in the McKinlay Member. The Bauer Field has been developed by vertical wells targeting the high deliverability Namur Sandstone with the McKinlay Member as a secondary target. In 2017 the decision was made to specifically target the McKinlay Member with a horizontal well, requiring a multi-disciplinary approach to combine geological, geophysical and engineering datasets. The McKinlay Member is 3–5 m i

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Gravestock, D. I., and E. M. Alexander. "POROSITY AND PERMEABILITY OF RESERVOIRS AND CAPROCKS IN THE EROMANGA BASIN, SOUTH AUSTRALIA." APPEA Journal 26, no. 1 (1986): 202. http://dx.doi.org/10.1071/aj85020.

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When effective porosity and permeability are measured at simulated overburden pressure, and grain size variation is taken into account, two distinct relationships are evident for Eromanga Basin reservoirs. Reservoirs in the Hutton Sandstone and Namur Sandstone Member behave such that significant porosity reduction can be sustained with retention of high permeability, whereas permeability of reservoirs in the Birkhead Formation and Murta Member is critically dependent on slight porosity variations. Logging tool responses are compared with core-derived data to show in particular the effects of g

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Powell, T. G., C. J. Boreham, D. M. McKirdy, B. H. Michaelsen, and R. E. Summons. "PETROLEUM GEOCHEMISTRY OF THE MURTA MEMBER, MOOGA FORMATION, AND ASSOCIATED OILS, EROMANGA BASIN." APPEA Journal 29, no. 1 (1989): 114. http://dx.doi.org/10.1071/aj88015.

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An investigation has been made of the source potential, degree of maturation and hydrocarbon composition of selected oils and sediments in the Murta Member in ATP 267P and the Moomba and Napacoongee- Murteree Blocks (PEL 5 and 6), Eromanga Basin. Shales in the Murta Member contain low amounts (up to 2.5% TOC) of terrestrial oil- prone organic matter (Types II–III) which consists predominantly of sporinite, lipto- detrinite and inertinite with lower amounts of vitrinite, although some samples contain relatively abundant telalginite. Extractable hydrocarbon yields demonstrate that parts of the M

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Mavromatidis, Angelos, and Richard Hillis. "Quantification of exhumation in the Eromanga Basin and its implications for hydrocarbon exploration." Petroleum Geoscience 11, no. 1 (January 2005): 79–92. http://dx.doi.org/10.1144/1354-079304-621.

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Sajjadi, Freshteh, and Geoffrey Playford. "New epithets for two Upper Jurassic miospore species from the Eromanga Basin, Queensland." Alcheringa: An Australasian Journal of Palaeontology 27, no. 2 (January 2003): 171. http://dx.doi.org/10.1080/03115510308619556.

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Molnar, Ralph E. "New morphological information about Cretaceous sauropod dinosaurs from the Eromanga Basin, Queensland, Australia." Alcheringa: An Australasian Journal of Palaeontology 35, no. 2 (June 2011): 329–39. http://dx.doi.org/10.1080/03115518.2011.533978.

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Borazjani, S., D. Kulikowski, K. Amrouch, and P. Bedrikovetsky. "Composition changes of hydrocarbons during secondary petroleum migration." APPEA Journal 58, no. 2 (2018): 784. http://dx.doi.org/10.1071/aj17127.

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We investigate secondary migration of hydrocarbons with significant composition difference between the source and oil pools in the Cooper-Eromanga Basin, Australia. The secondary migration period is significantly shorter than the time of the hydrocarbon pulse generation, so neither adsorption nor dispersion of components can explain the concentration difference. The filtration coefficients, obtained from oil compositions in source rock (Patchawarra Formation) and in the reservoir (Poolowanna Formation and Hutton Sandstone), monotonically increase as carbon number increases. The monotonicity ta

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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 ret

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Troup, Alison, and Behnam Talebi. "Adavale Basin petroleum plays." APPEA Journal 59, no. 2 (2019): 958. http://dx.doi.org/10.1071/aj18083.

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The Devonian Adavale Basin system is an under-explored, frontier petroleum basin in south-west Queensland. It has a confirmed petroleum system with production from the Gilmore gas field. The age, marine depositional environments and high carbonate content suggest the basin may have unconventional petroleum potential, and there has been renewed interest from industry in evaluating the basin. In support of this, the Queensland Department of Natural Resources, Mines and Energy has examined the source rock properties of the Bury Limestone and Log Creek Formation and has commissioned an update to t

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Sajjadi, Freshteh, and Geoffrey Playford. "Systematic and stratigraphic palynology of Late Jurassic-earliest Cretaceous strata of the Eromanga Basin, Queensland, Australia: Part Two." Palaeontographica Abteilung B 261, no. 4-6 (March 12, 2002): 99–165. http://dx.doi.org/10.1127/palb/261/2002/99.

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Sajjadi, Freshteh, and Geoffrey Playford. "Systematic and stratigraphic palynology of Late Jurassic-earliest Cretaceous strata of the Eromanga Basin, Queensland, Australia: Part One." Palaeontographica Abteilung B 261, no. 1-3 (March 12, 2002): 1–97. http://dx.doi.org/10.1127/palb/261/2002/1.

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Tinapple, Bill. "Australian states and Northern Territory acreage update at APPEA 2011." APPEA Journal 51, no. 1 (2011): 79. http://dx.doi.org/10.1071/aj10004.

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Bill’s presentation is on behalf of the NT, Queensland, NSW, Victoria, SA and WA. Some highlights are: • NT: 24 onshore exploration applications were received in 2010 (an increase of 50 % from 2009). About 479,100 sq km of the NT is now under application, including grassroots areas. • Queensland: In 2011, a variety of exploration opportunities are being offered in basins ranging in age from Precambrian to Cretaceous. Targets include conventional oil and gas as well as shale gas. • NSW: There are now more than 800 unallocated petroleum exploration blocks, including the Darling Basin, the Tamwor

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Edwards, B. "Eromanga Basin seismic stratigraphy and tectonic modelling – keys to exploration success in ATP 299P." Exploration Geophysics 22, no. 1 (March 1991): 117–22. http://dx.doi.org/10.1071/eg991117.

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Taylor, Geoffrey R. "Image analysis techniques for the interpretation of airphoto lineaments ‐ petroleum exploration, Eromanga Basin, Australia." Geocarto International 3, no. 3 (September 1988): 53–60. http://dx.doi.org/10.1080/10106048809354166.

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