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Academic literature on the topic 'Cooper-Eromanga Basin'

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Published: 10 December 2022
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Journal articles on the topic "Cooper-Eromanga Basin"

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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 discoveries in areas of limited exploration; and thirdly, as multifield discoveries along major structural trends. Exploitation of the Eromanga Basin oil discoveries has been made possible by a combination of rapid appraisal and development drilling and early commencement of production.The initial Eromanga Basin oil discoveries overlie major Cooper Basin gas fields and were located during appraisal and development drilling of deeper Cooper Basin gas reservoirs. Wildcat and appraisal drilling on Eromanga Basin prospects, such as Wancoocha and Narcoonowie, has upgraded the prospectivity of the Eromanga Basin sequence in the southern Cooper Basin—an area where earlier exploration for Cooper Basin gas was unsuccessful. Significant oil discoveries in Bodalla South 1 and Tintaburra 1, in the Queensland sector of the Eromanga Basin, have extended the range of exploration success and generated considerable interest in lesser known parts of the Eromanga Basin.Three successive phases of Cooper-Eromanga exploration have led to the present high level of success. Early exploration, before 1969, led to the initial discovery and development of Cooper Basin gas fields and was largely supported by the Petroleum Search Subsidy Acts (19571974). The results of the second phase, between 1970 and 1975, provided little encouragement to operators to extend exploration beyond the limits of the then known gas accumulations. In the decade since 1975, the oil potential of the Eromanga and parts of the Cooper Basin sequences has become a major factor in the exploration and development activity of the region. Since 1975, the favourable commercial conditions prevailing under the Import Parity Pricing scheme and the concessional crude oil excise arrangments for production from 'newly discovered' oilfields provided a significant incentive for development and exploitation of the post-1975 oil discoveries.
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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 approach would seem to be using the presence or absence of specific araucariacean chemical marker signatures as a means of distinguishing oils formed from source rocks in the Eromanga Basin from those derived from the underlying Cooper Basin sediments.The saturated and aromatic hydrocarbon compositions of the sediment extracts from the Cooper and Eromanga Basins have been examined to identify the distinctive fossil hydrocarbon markers derived from such resins. Sediments from the Eromanga Basin, which contain abundant micro-fossil remains of the araucariacean plants, contain diterpane hydrocarbons and aromatic hydrocarbons which bear a strong relationship to natural products in modern members of the Araucariaceae. Sediments from the Permo-Triassic Cooper Basin, which predate the Jurassic araucariacean flora, have different distributions of diterpane biomarkers and aromatic hydrocarbons.Many oils found in the Cooper/Eromanga region do not have the biological marker signatures of the Jurassic sediments and appear to be derived from the underlying Permian sediments; however, several oils contained in Jurassic to Cretaceous reservoirs show the araucariacean signature of the associated Jurassic to Early Cretaceous source rock sediments. It is likely, therefore, that these oils were sourced and reservoired within the Eromanga Basin and have not migrated from the Cooper Basin sequences below. Accordingly, exploration strategies in the Cooper Eromanga system should include prospects that could have been charged with oil from mature Jurassic/Early Cretaceous sediments of the Eromanga Basin.
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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 Eromanga basins.The source–reservoir relationships are well expressed in the carbon isotopic composition of individual n-alkanes. These data reflect primary controls of source and maturity and are relatively insensitive to secondary alteration through migration fractionation and water washing, processes that have affected the molecular geochemistry of the majority of oils. Accordingly, the principal Gondwanan Petroleum Supersystem originating from a Permian source of the Cooper Basin has been further subdivided into two petroleum systems associated with Lower Permian Patchawarra Formation and Upper Permian Toolachee Formation sources respectively. Both sources are characterised by n-alkane isotope profiles that become progressively lighter with increasing carbon number—negative n-alkane isotope gradient. The Patchawarra source is isotopically lighter than the Toolachee source. Reservoir placement of oil in either the Toolachee or Patchawarra formations is, in general, a good guide to its source and perhaps an indirect measure of seal effectiveness. The subordinate Murta Petroleum Supersystem of the Eromanga Basin is subdivided into the Birkhead Petroleum System and Murta Petroleum System to reflect individual contributions from Birkhead Formation and Murta Formation sources respectively. Both systems are characterised by n-alkane carbon isotope profiles with low to no gradient. The minor Larapintine Petroleum Supersystem has been tentatively identified as involving pre-Permian source rocks in the far eastern YVarburton Basin and western margin of the Warrabin Trough in Queensland.Eromanga source inputs to oil accumulations in the Eromanga Basin can be readily recognised from saturated and aromatic biomarker assemblages. However, biomarkers appear to over-emphasise local Eromanga sources. Hence, we have preferred the semi-quantitative assessment of relative Cooper and Eromanga inputs that can be made using n-alkane isotope data and this appears to be robust provided that Eromanga source input is greater than 25% in oils of mixed origin. Enhanced contributions from Birkhead sources are concentrated in areas of thick and mature Birkhead source rocks in the northeastern Patchawarra Trough. Pre-Permian inputs are readily recognised by n-alkanes more depleted in I3C compared with late Palaeozoic and Mesozoic sources.Long range migration (>50 km) from Permian sources has been established for oil accumulations in the Eromanga Basin. This, together with contributions from local Eromanga sources, highlights petroleum pro- spectivity beyond the Permian edge of the Cooper Basin. Deeper, pre-Permian sources must also be considered in any petroleum system evaluation of the Cooper and Eromanga basins.
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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 latest structural and stratigraphic data, then used to perform numerical basin modelling and subsidence history analysis for a better comprehension of their complex geologic history. Calibrated 1D/3D numerical models provide the grounds for heat flow, temperature, thermal maturity, and sediment thickness maps. According to calibrated vitrinite reflectance profiles, a major hydrothermal/magmatic event at about 100 Ma with associated basal heat flow up to 150 mW/m2 caused source rock maturation and petroleum generation and probably overprinted most of the previous hydrothermal events in the study area. This event correlates with sedimentation rates up to 200 m/Ma and was apparently accompanied by extensive crustal shear. Structural style and depocentre migration analysis suggest that the Carboniferous–Triassic Cooper Basin initially has been a lazy-s shaped triplex pull-apart basin controlled by the Cooper Basin Master Fault before being inverted into a piggy-back basin and then blanketed by the Jurassic–Cretaceous Eromanga Basin. The interpreted Central Eromanga Shear Zone governed the tectonic evolution from the Triassic until today. It repeatedly induced NNW-SSE directed deformation along the western edge of the Thomson Orogen and is characterized by present-day seismicity and distinct neotectonic features. We hypothesize that throughout the basin evolution, alternating tectonic stress caused frequent thermal weakening of the crust and facilitated the establishment of the Cooper Hot Spot, which recently increased again its activity below the Nappamerri Trough.
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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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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 investigations of the evidence indicates that sulphate-reducing bacteria are not the major contributors to the corrosion as was initially believed. Field studies, laboratory analysis and ongoing well programs show that the process of differential aeration is the prime cause of the casing corrosion. Corrosion has been found to occur predominantly at a depth of between 18.3m (60 ft) and 36.6m (120 ft) above sea level and occurs over a band of 6.1 m (20 ft) to 9.1m (SO ft) in each well in conjunction with the external water table.As a result of this corrosion failure SANTOS has initiated a regular program of well maintenance, annulus inhibitor top-ups and pressure testing. A total of 315 wells have been tested to date, production casing corrosion problems have been identified in 35 wells, 31 wells have been repaired and four wells abandoned.
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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 prepared from the seismic horizon maps.Burial geohistory plots were constructed using standard decompaction techniques, a fluctuating sea level and palaeo-waterdepths. Using terrestrial compaction and a palaeo-elevation for the Winton Formation, tectonic subsidence during the Winton Formation deposition and erosion is the same as the background Eromanga Basin trend—this differs significantly from previous studies which attributed apparently rapid deposition of the Winton Formation to basement subsidence. A dynamic topography model explains many of the features of basin history during the Cretaceous. Palaeo-temperature modelling showed a high heatflow peak from 90–85 Ma. The origin of this peak is unknown. There is also a peak over the last two–five million years.Expulsion maps were prepared for the source rock units studied. In preparing these maps the following assumptions were made:expulsion is proportional to maturity and source rock richness;maturity is proportional to peak temperature; andpeak temperature is proportional to palaeo-heatflow and palaeo-burial.The geohistory modelling involved 111 control points. The major expulsion is in the mid-Cretaceous with minor amounts in the late Tertiary. Maturity maps were prepared by draping seismic structure over maturity values at control points. Draping of maturity maps over expulsion values at the control points was used to produce expulsion maps. Hydrocarbon generation was calculated using a composite kerogen kinetic model. Volumes generated are theoretically large, up to 120 BBL m2 of kitchen area at Tirrawarra North. Maps were prepared for the Patchawarra and Toolachee Formations in the Cooper Basin and the Birkhead and Poolowanna Formations in the Eromanga Basins. In addition, maps were prepared for Tertiary expulsion. The Permian units represent the dominant source as Jurassic source rocks have only generated in the deepest parts of the Eromanga Basin.
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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. The model is feasible if the pH of the Eromanga Basin aquifer waters is buffered externally, by generation of organic acid anions during kerogen maturation or aluminosilicate reactions.Hydrocarbons are likely to have migrated up-dip along the same conduits as the carbon dioxide. Consequently, delineation of massive calcite-cemented zones in the Eromanga Basin reservoirs using well log and seismic data may aid in the identification of petroleum migration pathways, and sites of hydrocarbon entrapment.
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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 aim of rebuilding an understanding of the basin, based on first principles and stripping away exploration paradigms. The study area comprises an acreage position in the South Australian and Queensland Cooper-Eromanga Basins covering 70 000 km2 in which Senex Energy has 14 oil fields, has drilled more than 80 exploration wells and has acquired 2D and 3D seismic material. A plethora of proven and emerging plays exist within the acreage ranging from high productivity light sweet oil (Birkhead and Namur Reservoirs) to tight oil (Murta Formation), conventional gas (Toolachee/Epsilon and Patchawarra Formation), tight gas (Patchawarra Formation) and the emerging deep coal play (Toolachee and Patchawarra Coals). Play-based exploration methodologies incorporating the integration of seismic data, log and palynological data, structural analysis, geochemistry, 3D basin modelling, consistent well failure analysis and gross depositional environment maps have allowed the systematic creation of common risk segment maps at all play levels. This information is now actively utilised for permit management, business development, work program creation and portfolio management. This paper will present an example of the work focussing on the southern section of the South Australian Cooper-Eromanga Basin.
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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 anticlines within the basin. In some instances, high angle faults are associated with these features. This structural deformation occurred in an extensional regime and was strongly influenced by the underlying Palaeozoic structural grain.The Eromanga Basin section is composed of a basal, dominantly non- marine, fluvial and lacustrine sequence overlain by shallow marine deposits which are in turn overlain by another fluvial, lacustrine and coal- swamp sequence. The basal sequence is the principal zone of interest to petroleum exploration. It contains the main reservoirs and potential source rocks and hosts all commercial hydrocarbon accumulations found to date. While the bulk of discovered reserves are in structural traps, a significant stratigraphic influence has been noted in a number of commercially significant hydrocarbon accumulations.All major discoveries have been in the central Eromanga Basin region overlying and adjacent to the hydrocarbon- productive, Permo- Triassic Cooper Basin. The mature Permian section is believed to have contributed a significant proportion of the Eromanga- reservoired hydrocarbons. Accordingly, structural timing and migration pathways within the Permian and Middle Triassic- Jurassic sections are important factors for exploration in the central Eromanga Basin region. Elsewhere, in less thermally- mature areas, hydrocarbon generation post- dates Tertiary structuring and thus exploration success will relate primarily to source- rock quality, maturity and drainage factors.Although exploration in the basin has proceeded spasmodically for over 50 years, it has only been in the last decade that significant exploration activity has occurred. Over this recent period, some 450 exploration wells and 140 000 km of seismic acquisition have been completed in the pursuit of Eromanga Basin oil accumulations. This has resulted in the discovery of 227 oil and gas pools totalling an original in- place proved and probable (OOIP) resource of 360 MMSTB oil and 140 BCF gas.Though pool sizes are generally small, up to 5 MMSTB OOIP, the attractiveness of Eromanga exploration lies in the propensity for stacked pools at relatively shallow depths, moderate to high reservoir productivity, and established infrastructure with pipelines to coastal centres. Coupled with improved exploration techniques and increasing knowledge of the basinal geology, these attributes will undoubtedly ensure the Eromanga Basin continues to be a prime onshore area for future petroleum exploration in Australia.
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Dissertations / Theses on the topic "Cooper-Eromanga Basin"

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Scott, Jennifer Suzanne. "Heat flow in the Cooper-Eromanga Basin /." Title page, contents and abstract only, 1998. http://web4.library.adelaide.edu.au/theses/09SB/09sbs4271.pdf.

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Macklin, Troy A. "Regional depth conversion in the Cooper - Eromanga Basin /." Title page, table of contents and abstract only, 1994. http://web4.library.adelaide.edu.au/theses/09S.B/09s.bm158.pdf.

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Mavromatidis, Angelos. "Quantification of exhumation in the Cooper-Eromanga Basins, Australia /." Title page, contents and abstract only, 1997. http://web4.library.adelaide.edu.au/theses/09PH/09phl7935.pdf.

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Hochwald, Cathy. "Statistical application of seismic attributes Cooper/Eromanga Basin, South Australia /." Title page, contents and abstract only, 1995. http://web4.library.adelaide.edu.au/theses/09SB/09sbh685.pdf.

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Wythe, Scott R. "A comparative study of petrological and geochemical maturity indicators in Mesozoic and Palaeozoic sediments from Dullingari-1, Eromanga/Cooper Basin /." Title page, abstract and contents only, 1989. http://web4.library.adelaide.edu.au/theses/09SB/09sbw996.pdf.

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Jøraandstad, Susann. "Use of stacking velocity for depth prediction and lithological indication in the Challum field of the Cooper/Eromanga basin, Queensland /." Title page, abstract and contents only, 1999. http://web4.library.adelaide.edu.au/theses/09SB/09sbj818.pdf.

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Thesis (B.Sc.(Hons.))--University of Adelaide, National Centre of Petroleum Geology and Geophyiscs, 1999.
Two folded enclosures in pocket inside backcover. Includes bibliographical references (2 leaves).
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Jenkins, C. C. "The organic geochemical correlation of crude oils from early Jurassic to late Cretaceous Age reservoirs of the Eromanga Basin and late Triassic Age reservoirs of the underlying Cooper Basin /." Title page, contents and abstract only, 1987. http://web4.library.adelaide.edu.au/theses/09SM/09smj521.pdf.

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Ryan, Melanie J. "The use of biomarkers and molecular maturity indicators to determine the provenance of residual and produced oils in the Gidgealpa Field in the Cooper-Eromanga Basin, Australia /." Title page, contents and abstract only, 1996. http://web4.library.adelaide.edu.au/theses/09S.B/09s.br9891.pdf.

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Krawczynski, Lukasz. "Sequence stratigraphic interpretation integrated with 3-D seismic attribute analysis in an intracratonic setting : Toolachee Formation, Cooper Basin, Australia." Thesis, Queensland University of Technology, 2004. https://eprints.qut.edu.au/16087/1/Lukasz_Krawcynski_Thesis.pdf.

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This study integrates sequence stratigraphy of the Late Permian Toolachee Formation in the non-marine intracratonic Permian-Triassic Cooper Basin, Australia with 3-D seismic attribute analysis to predict the extent of depositional environments identified on wireline and well core data. The low resolution seismic data (tuning thickness 23 - 31 m) comprised of six seismic horizons allowed the successful testing of sequence stratigraphic interpretations of the productive Toolachee Formation that were based on wireline data. The analysis of 29 well logs and three 20 m core intervals resulted in the identification of eleven parasequences that comprise the building blocks of an overall transitional systems tract, characterised by a gradual increase in accommodation. The parasequences reflect cyclic transitions between braided and meandering fluvial systems as a result of fluctuations in sediment flux, possibly driven by Milankovitch climatic-forcing. The seismic horizon attribute maps image mostly the meandering fluvial bodies within the upper parts of the parasequences, but some maps image the lower amalgamated sand sheets and show no channel structures. Categorisation of the fluvial bodies in the overbank successions reflects a gradual decrease in sinuosity, channel width, and channel belt width up-section, supporting the overall increase in accommodation up-section. Similar acoustic impedance values for shales and sands do not suggest successful seismic forward modelling between the two lithologies. Geological interpretations suggest most imaged channel fill to be made up predominantly of fine sediments, as channel avulsion and abandonment is common and increases with time. Seismic forward modelling resulted in the interpretation of carbonaceous shale as a possible channel fill, supporting the geological interpretations. The three major identified fluvial styles; braided, meanders, and distributaries are potential targets for future exploration. Extensive sand sheets deposited from braided fluvial systems require structural traps for closure. Meandering and anastomosing channel systems represent excellent stratigraphic traps, such as the basal sands/gravels of laterally accreted point bars.
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Krawczynski, Lukasz. "Sequence Stratigraphic Interpretation integrated with 3-D Seismic Attribute Analysis in an Intracratonic Setting: Toolachee Formation, Cooper Basin, Australia." Queensland University of Technology, 2004. http://eprints.qut.edu.au/16087/.

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This study integrates sequence stratigraphy of the Late Permian Toolachee Formation in the non-marine intracratonic Permian-Triassic Cooper Basin, Australia with 3-D seismic attribute analysis to predict the extent of depositional environments identified on wireline and well core data. The low resolution seismic data (tuning thickness 23 - 31 m) comprised of six seismic horizons allowed the successful testing of sequence stratigraphic interpretations of the productive Toolachee Formation that were based on wireline data. The analysis of 29 well logs and three 20 m core intervals resulted in the identification of eleven parasequences that comprise the building blocks of an overall transitional systems tract, characterised by a gradual increase in accommodation. The parasequences reflect cyclic transitions between braided and meandering fluvial systems as a result of fluctuations in sediment flux, possibly driven by Milankovitch climatic-forcing. The seismic horizon attribute maps image mostly the meandering fluvial bodies within the upper parts of the parasequences, but some maps image the lower amalgamated sand sheets and show no channel structures. Categorisation of the fluvial bodies in the overbank successions reflects a gradual decrease in sinuosity, channel width, and channel belt width up-section, supporting the overall increase in accommodation up-section. Similar acoustic impedance values for shales and sands do not suggest successful seismic forward modelling between the two lithologies. Geological interpretations suggest most imaged channel fill to be made up predominantly of fine sediments, as channel avulsion and abandonment is common and increases with time. Seismic forward modelling resulted in the interpretation of carbonaceous shale as a possible channel fill, supporting the geological interpretations. The three major identified fluvial styles; braided, meanders, and distributaries are potential targets for future exploration. Extensive sand sheets deposited from braided fluvial systems require structural traps for closure. Meandering and anastomosing channel systems represent excellent stratigraphic traps, such as the basal sands/gravels of laterally accreted point bars.
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Conference papers on the topic "Cooper-Eromanga Basin"

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Taylor, Neale F. "Managing Remote Field Operations In The Cooper-Eromanga Basin, Australia." In International Meeting on Petroleum Engineering. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/29914-ms.

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Aung, Tun H. "High Temperature Drilling Fluids In The Cooper-Eromanga Basin, Australia." In Offshore South East Asia Show. Society of Petroleum Engineers, 1986. http://dx.doi.org/10.2118/14616-ms.

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Taylor, Neale F. "Managing Remote Field Operations In The Cooper-Eromanga Basin, Australia (Chinese)." In International Meeting on Petroleum Engineering. Society of Petroleum Engineers, 1995. http://dx.doi.org/10.2118/29914-ch.

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Squire, Shane G. "Reservoir and Pool Parameter Distributions From the Cooper/Eromanga Basin, Australia." In SPE Asia Pacific Oil and Gas Conference. Society of Petroleum Engineers, 1996. http://dx.doi.org/10.2118/37365-ms.

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Elliott*, Lindsay G. "Using Biodegradation to Date Hydrocarbon Entry Into Reservoirs: Examples From the Cooper/Eromanga Basin, Australia." In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2210537.

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Kokkoni, Panayiotis Peter, and Alizera Salmachi. "Analysis of South Australian Onshore Oil & Gas Well Decommissioning and Potential Impact on Regulatory Compliance, Environmental and Corporate Risk — Unified Risk Code." In SPE/IATMI Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2021. http://dx.doi.org/10.2118/205762-ms.

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The Cooper/Eromanga Basin is in central Australia and has been the focal point for oil and gas exploration and development in South Australia since the first commercial hydrocarbon discovery in 1963. In the years and decades following, thousands of subsequent wells have been drilled. The CE Basin spans across four states and territories covering an area ~35,000km2. The concentration of South Australian wells is situated in the Northeast of the state and sparsely concentrated in a 300km × 500km area (Figure 1) with the wells in this area being the focus of this research study. Well decommissioning commonly referred to as Plug and Abandonment (P&A) aims to restore the natural integrity of geological formations that existed prior to drilling. It is a mandatory requirement for all wells and must account for the effects of any foreseeable chemical and geological processes from an eternal standpoint. The minimum requirement for abandonment of the South Australian wells is governed by Objective 6 Cooper Basin State Environmental Objectives (SEO): Drilling, Completions and Well Operations, November 2015 guidelines, which provides the compliance criteria for appropriate barrier installation and verification. Well complexity is determined by the difficulty in achieving this minimum compliance requirement based on available data of well conditions, simplified in the form of a risk code.
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Alchin, Liam, Andre Lymn, Thomas Russell, Alexander Badalyan, Pavel Bedrikovetsky, and Abbas Zeinijahromi. "Near-Wellbore Damage Associated with Formation Dry-Out and Fines Migration During CO2 Injection." In SPE Asia Pacific Oil & Gas Conference and Exhibition. SPE, 2022. http://dx.doi.org/10.2118/210763-ms.

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Abstract:
Abstract One of the key parameters for subsurface CO2 storage in well injectivity. There are multiple factors that can affect injection rate including formation dry-out, fines migration, and salt precipitation that can increase or decrease the injectivity. In this study, we experimentally investigated the cumulative effect of rock drying-out and fines migration on well injectivity for a formation in the Cooper – Eromanga Basin, South Australia. Four core plugs with a range of clay content and permeability were chosen from the formation. Each core was fully saturated with artificially made formation water to measure initial permeability. The core samples were then subjected to a constant flow of gas (air or CO2) at reservoir pressure for up to 185,000 PVI. The effluent fluid was sampled continuously to measure the concentration of solid particles produced from the core during gas injection. The tests were followed by injection of formation water to eliminate the salt precipitation effect and then DI water to identify the maximum possible formation damage in each core sample. Overall injectivity increased significantly during continuous injection of CO2or air into fully saturated core samples despite permeability damage due to fines migration. Fines migration was observed during gas injection, resulting in a pressure drop increase across the cores and fine release at the core outlet. 30-60% reduction of core permeabilities were observed during connate water evaporation. The damaging effect of fines migration on injection rate was negligible compared to 4-30 times pressure drop decrease due to reduction in liquid saturation.
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8

Mackie, Steve. "History of Petroleum Exploration and Development in the Cooper and Eromanga Basins." In International Conference and Exhibition, Melbourne, Australia 13-16 September 2015. Society of Exploration Geophysicists and American Association of Petroleum Geologists, 2015. http://dx.doi.org/10.1190/ice2015-2194999.

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9

Pap, I., and I. Virshylo. "Quantitative modelling of Earth satellite gravity data for Cooper-Eromanga basins (Australia)." In 15th EAGE International Conference on Geoinformatics - Theoretical and Applied Aspects. Netherlands: EAGE Publications BV, 2016. http://dx.doi.org/10.3997/2214-4609.201600534.

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10

Webster, M. A., and A. G. Grimison. "Hydrodynamics in the Queensland Sector of the Cooper/Eromanga Basins: Identifying Non-Conventional Exploration Plays Using Water Pressure and Chemistry Data." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2000. http://dx.doi.org/10.2118/64281-ms.

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