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Добірка наукової літератури з теми "Eromanga Basin"

Автор: Grafiati

Опубліковано: 4 червня 2021

Оновлено: 29 січня 2023

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Статті в журналах з теми "Eromanga Basin"

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, Geinitzea tetragonaCantrill & Douglas, is made the type of a new genus,Otwayia, with two species,O. tetragona and O. cudgeloides,both occurring in the Eromanga Basin. No unequivocalCupressaceae/Taxodiaceae were recognised.

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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 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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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 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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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 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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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 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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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. 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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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 different petroleum wells.Accumulation of the Eromanga Basin sequence was initiated in the early Jurassic by major epeirogenic downwarping; in the investigation area the pre-Eromanga Basin surface consists mainly of rocks comprising the Thargomindah Shelf and the Cooper Basin. The lower Eromanga Basin sequence in the area onlaps the Thargomindah Shelf and thickens relatively uniformly to the north-west. The sequence comprises mainly Jurassic/Cretaceous terrestrial units in which vertical and lateral distribution is predominantly facies-controlled. These are uniformly overlain by the mainly paralic Cadna-owie Formation, signalling the initiation of a major Cretaceous transgression over the basin.The terrestrial sequence over most of the area comprises alternating coarser and finer-grained sedimentary rocks, reflecting major cyclical changes in the energy of the depositional environment. The Hutton Sandstone, Adori Sandstone and 'Namur Sandstone Member' of the Hooray Sandstone comprise mainly sandstone, and reflect high energy fluvial depositional environments. Lower energy fluvial and lacustrine conditions are reflected by the finer-grained sandstone, siltstone and mudstone of the Birkhead and Westbourne Formations, and 'Murta Member' of the Hooray Sandstone. Similar minor cycles are represented in the 'basal Jurassic' unit. The Algebuckina Sandstone, recognised only in the far south-west of the investigation area, comprises mainly fluvial sandstones.

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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 seismic recording instrument, an off-end spread with 15m source and receiver station spacing and 1800 m maximum offset presented the best compromise between optimal achievement of exploration objectives and available resources.For comparison an 8 km portion of a nearby 1988 centre spread line was overshot using the off-end technique, and was processed by the same contractor with a similar processing sequence. The improvements in data quality obtained demonstrate that off-end data acquisition is a viable technique which can be optimally suited to meet lateral sampling and noise suppression requirements.

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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 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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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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Дисертації з теми "Eromanga Basin"

1

Kagya, Meshack L. N. "The source rock and petroleum geochemistry of the Early Jurassic Poolowanna Formation, Eromanga Basin /." Title page, contents and abstract only, 1997. http://web4.library.adelaide.edu.au/theses/09PH/09phk118.pdf.

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2

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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3

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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4

Root, Robert Sinclair. "The application of high-resolution sequence stratigraphy to reservoir characterisation and development : Wyandra Sandstone Member, Cadna-Owie Formation, Eromanga Basin, Southwest Queensland / y Robert Sinclair Root." Thesis, Queensland University of Technology, 2001. https://eprints.qut.edu.au/37092/1/37092_Root_2001.pdf.

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Early sequence stratigraphic models emphasised the use of sequence stratigraphic surfaces for identifying and constraining the stratigraphic position of reservoir intervals at large scales (100s-1 000s of metres) using mostly seismic reflection data. In contrast, reservoir development focuses on resolving smallscale, largely lateral changes in reservoir quality and distribution where the stratigraphic position of the reservoir interval is generally already well defined. Also, due to the scale of analysis, the database for reservoir development studies commonly consists exclusively of well data (i.e. fullhole cores, wireline logs and image logs); fluid flow properties can be measured directly using the same data types that are employed to identify and map key surfaces. Despite well documented successes of the sequence stratigraphic approach at exploration scales, little information exists regarding the utility of sequence stratigraphic approach for reservoir development. This study investigates the utility of the sequence stratigraphic approach for aiding reservoir development of the Wyandra Sandstone Member at Tarbat-lpundu Field, Southwest Queensland. A sequence stratigraphic framework was constructed for the Wyandra Sandstone Member using a database of core, wireline suites, image logs, palynological data and modern analogues. The utility of the sequence stratigraphic framework for reservoir development was then evaluated using petrography and measurements of fluid flow properties from conventional core analysis and wireline logs. The Wyandra Sandstone Member is a -20m thick, volcaniclastic sandstone sheet that forms a fining-upward succession. Despite relative lithologic homogeneity, the sandstone sheet is characterised by severe variations in fluid flow properties stemming from complex patterns of diagenetic porosity/permeability occlusion and enhancement. A grain size control on the occurrence and intensity of secondary dissolution suggests that an understanding of grain size distribution within the_ Wyandra Sandstone Member is central to resolving reservoir heterogeneity. Sequence stratigraphic divisions of the Wyandra Sandstone Member indicate that it formed in response to a high-order regressive - transgressive cycle driven by glacio-eustatic fluctuation coupled with variation in the rate of basin subsidence from the Barremian to the Aptian. Seventy-three percent of reservoir rock within the Cadna-owie Formation is confined to the lower, fluvially dominated portion of the Wyandra Sandstone Member that is interpreted to represent a lowstand systems tract. However, the identification of the lowstand systems tract, in itself, is of limited value for reservoir development. Several uneconomic development wells have intersected low permeability sandstone within the lowstand systems tract. The largely lateral variations in reservoir properties within the lowstand systems tract of the Wyandra Sandstone Member stem from the partitioning of medium- to very coarse-grained sandstone to channelised fluvial distributary deposits. Although sandstone of fluvial distributary deposits show a range of fluid flow properties (0.01->1000mD), secondary dissolution of chemically unstable framework grains, authigenic clay and carbonate cement occurs preferentially in areas of intense channel amalgamation. These areas are interpreted as major fluvial axes similar to those that occur at the 'fan apex' of modern depositional systems of the Great Artesian Basin and modern transverse depositional systems occurring along strike-slip faults. The position of the major fluvial axes are interpreted to be controlled by localised changes in the style of basement faulting and related patterns of differential compaction in the overlying cover units. Mapping sequence stratigraphic surfaces, as distinct from lithologic surfaces, in the Cadna-owie Formation defines linkages of contemporaneous depositional systems. Consequently, the sequence stratigraphic divisions are compatible with studies of modern depositional systems, whereas lithologic divisions of the Cadnaowie Formation generally are not. As a result, a variety of analyses conducted with respect to sequence stratigraphic divisions, and particularly the utilisation of modern analogues, improves our understanding of the sedimentological processes operative during deposition of the Wyandra Sandstone Member. It is hoped that the conclusions stemming from this study provide a basis for more accurately accessing the development risk at Tarbat-lpundu Field.

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5

Musakti, Oki Trinanda. "Regional sequence stratigraphy of a non-marine intracratonic succession : the Hooray sandstone and Cadna-Owie formation, Eromanga Basin, Queensland." Thesis, Queensland University of Technology, 1997. https://eprints.qut.edu.au/36968/1/36968_Musakti_1997.pdf.

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The general objectives of the study are to assess the applicability of sequence stratigraphic concepts to non-marine deposition in a large intracratonic basin and to determine fundamental controls that affect the stratal architectures of this basin. During the last two decades, sequence stratigraphy has been emerging as a powerful tool to analyze marine sedimentary successions and has been successfully applied in many petroleum exploration programs. However, at present, there is still some debate as to the applicability of sequence stratigraphic concepts to non-marine successions. The early works in sequence stratigraphy (i.e. Vail et. al. 1977; Posamentier and Vail, 1988; Galloway, 1989) focused on passive continental margin settings. In these settings, eustatic change of sea level (such as published by Haq et. al., 1988) is the major factor in determining the facies architecture and stacking patterns of sedimentary rock strata. The model derived from these studies has often been used (or abused!) as a template for exploration works in marginal marine basins (Posamentier and James, 1993). Later it was realized that the concepts of sequence stratigraphy could also be applied to the study of sedimentary strata of non marine basins (e.g. Shanley and McCabe, 1993; Legaretta et al., 1993; Blum, 1993, among others) where global sea level change has little, if any, effect on the processes of sedimentation. Although the basic concepts of sequence stratigraphy, the control of sediment supply and accommodation, are valid in all basin settings, the specific models and schematic sections for marginal marine basins certainly need to be modified before being applied to basins that are isolated from the sea (Weimer, 1992; Posamentier and James, 1993).

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6

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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7

Hill, Leon V. "Environmental analysis of the Hutton sandstone to Birkhead formation transition within the south-western Eromanga Basin, Queensland /." Title page, table of contents and abstract only, 1985. http://web4.library.adelaide.edu.au/theses/09SB/09sbh646.pdf.

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8

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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9

Zhou, Shaohua. "Geophysical investigations on the formation mechanism of the Eromanga Basin, Australia /." Title page, contents and abstract only, 1991. http://web4.library.adelaide.edu.au/theses/09PH/09phz634.pdf.

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10

Anderson, Alan. "A geoseismic investigation of carbonate cementation of the Namur Sandstone in the Gidgealpa Field, Eromanga Basin /." Title page, contents and abstract only, 1985. http://web4.library.adelaide.edu.au/theses/09S.B/09s.ba545.pdf.

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Книги з теми "Eromanga Basin"

1

Almond, C. S. Organic geochemistry: Rock-eval pyrolisis data summary, southern Eromanga Basin, Queensland \. [Brisbane: Geological Survey of Queensland, 1987.

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2

M, Finlayson D., ed. Geophysical abstracts and seismic profiles from the central Eromanga Basin region, eastern Australia. Canberra: Australian Govt. Pub. Service, 1987.

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3

Burger, D. Stratigraphy, palynology, and palaeoenvironments of the Hooray Sandstone, eastern Eromanga Basin, Queensland and New South Wales. [Brisbane]: Queensland Dept. of Mines, 1989.

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Contributions to the geology and hydrocarbon potential of the Eromanga Basin. Sydney, N.S.W., Australia: Geological Society of Australia, 1986.

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5

The Eromanga-Brisbane Geoscience Transect: A guide to basin development across Phanerozoic Australia in southern Queensland. Canberra: Australian Govt. Pub. Service, 1990.

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Частини книг з теми "Eromanga Basin"

1

Boult, P. J., P. N. Theologou, and J. Foden. "Capillary Seals Within the Eromanga Basin, AustraliaImplications for Exploration and Production." In Seals, Traps, and the Petroleum System. American Association of Petroleum Geologists, 1997. http://dx.doi.org/10.1306/m67611c10.

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Тези доповідей конференцій з теми "Eromanga Basin"

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Adams, S. J. "New Insight Into Eromanga Basin Oil Saturations." In SPE Asia Pacific Oil and Gas Conference and Exhibition. Society of Petroleum Engineers, 2002. http://dx.doi.org/10.2118/77886-ms.

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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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3

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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4

Goode, P. A., A. M. Sibbit, and S. Y. Looi. "Reservoir Saturation Determination in the Eromanga Basin Using Carbon/Oxygen Logging." In SPE Asia Pacific Oil and Gas Conference. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/28798-ms.

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5

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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6

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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7

Williams, N. V., P. J. Boult, Maris Zwigulis, and R. P. Schlichting. "Unusual Lacustrine Reservoirs and Seals of the Murteree Horst Area, Eromanga Basin, Australia." In SPE Asia Pacific Oil and Gas Conference. Society of Petroleum Engineers, 1994. http://dx.doi.org/10.2118/28751-ms.

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8

Troup, Alison Jane. "THE TINTABURRA STRUCTURE, EROMANGA BASIN, QUEENSLAND – A POSSIBLE CRETACEOUS IMPACT CRATER IN CENTRAL AUSTRALIA." In GSA 2020 Connects Online. Geological Society of America, 2020. http://dx.doi.org/10.1130/abs/2020am-356980.

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9

Röth, J., C. Boreham, L. Hall, and R. Littke. "Organic Geochemistry and Organic Petrography of the Birkhead and Murta Formations, Eromanga Basin, Central Australia." In 29th International Meeting on Organic Geochemistry. European Association of Geoscientists & Engineers, 2019. http://dx.doi.org/10.3997/2214-4609.201902812.

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10

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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Звіти організацій з теми "Eromanga Basin"

1

Tan, K. P., N. Rollet, J. Vizy, and P. Kilgour. Great Artesian Basin eastern recharge area assessment – Eastern Eromanga Basin airborne electromagnetic data interpretation report. Geoscience Australia, 2022. http://dx.doi.org/10.11636/record.2022.033.

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2

Norton, C. J., and N. Rollet. Regional stratigraphic correlation transects across the Great Artesian Basin: Eromanga and Surat basins focus study. Geoscience Australia, 2022. http://dx.doi.org/10.11636/record.2022.002.

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3

McCubbine, J. C., Z. Du, C. Ojha, M. C. Garthwaite, and N. J. Brown. InSAR processing over the Great Artesian Basin and analysis over the western Eromanga Basin and northern Surat Basin. Geoscience Australia, 2022. http://dx.doi.org/10.11636/record.2022.029.

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