Data

Cooper Basin Petroleum Systems Modelling: Regional Hydrocarbon Prospectivity of the Cooper Basin Data Pack 3

Geoscience Australia
Hall, L.S. ; Palu, T.J. ; Boreham, C.J. ; Edwards, D.S. ; Hill, A.J. ; Troup, A ; Lawson, C.
Viewed: [[ro.stat.viewed]] Cited: [[ro.stat.cited]] Accessed: [[ro.stat.accessed]]
ctx_ver=Z39.88-2004&rft_val_fmt=info%3Aofi%2Ffmt%3Akev%3Amtx%3Adc&rfr_id=info%3Asid%2FANDS&rft_id=https://pid.geoscience.gov.au/dataset/ga/90684&rft.title=Cooper Basin Petroleum Systems Modelling: Regional Hydrocarbon Prospectivity of the Cooper Basin Data Pack 3&rft.identifier=https://pid.geoscience.gov.au/dataset/ga/90684&rft.description=The Cooper Basin is an upper Carboniferous to Middle Triassic intracratonic basin in northeastern South Australia and southwestern Queensland (Gravestock et al., 1998; Draper, 2002; Carr et al., 2016). The basin is Australia's premier onshore hydrocarbon producing province and is nationally significant in providing gas to the eastern Australian gas market. The basin also hosts a range of unconventional gas play types within the Permian Gidgealpa Group, including basin-centred gas and tight gas accumulations, deep dry coal gas associated with the Patchawarra and Toolachee formations, the Murteree and Roseneath shale gas plays and deep coal seam gas in the Weena Trough (e.g. Goldstein et al., 2012; Menpes et al., 2013; Greenstreet, 2015). The principal source rocks for these plays are the Permian coals and coaly shales of the Gidgealpa Group (Boreham & Hill, 1998; Deighton & Hill, 1998; Deighton et al., 2003). Hall et al. (2016a) reviews the maturity and generation potential of the Cooper Basin source rocks and is the third part of a series of reports reviewing various aspects of the hydrocarbon prospectivity of the Cooper Basin (see also Hall et al., 2015a; Hall et al., 2016a). This data pack contains the supplementary material accompanying this report. Over ninety 1D thermal and burial history models were integrated with the 3D basin model and source rock property characteristics to create a regional multi-1D petroleum systems model for the basin. The burial and thermal history of the model was calibrated using present day corrected temperatures and maturity indicators (Ro, Tmax). In addition lithologies for key wells were calibrated using velocity, density and thermal conductivity data. Thermal boundary conditions were modelled as transient heat-flow from base lithosphere. Crustal thickness and radiogenic heat production properties were used from published studies (e.g. Beardsmore, 2004; Meixner et al., 2012; Hall et al. 2015a). The 1D models are integrated with a 3D regional basin model (Hall et al., 2015a) to create a multi-1D petroleum systems model of the Cooper Basin. Parameters for source rock distribution, amount and quality were added from analysis of log data and source rock geochemical data (Hall et al., 2016a) and new Cooper Basin kinetics (Mahlstedt et al., 2015). This data pack includes the following grids for each source rock: temperature (°C), maturity (%Ro), transformation ratio (%), total hydrocarbon generation (mmboe/km2), oil expelled (mmbbl/km2), gas expelled (mmboe/km2; bcf/km2), oil retained (mmbbl/km2) and gas retailed (mmboe/km2; bcf/km2). The results quantify both the maturity and total maximum hydrocarbon yield of each source rock, providing important insights into the hydrocarbon prospectivity of the basin (Hall et al., 2015b; Kuske et al., 2015).Maintenance and Update Frequency: notPlannedStatement: The input datasets and technical work flow used to generate these produces are described in Hall, L.S., Palu, T.J., Boreham, C.J., Edwards, D.S., Hill, A.J. & Troup, A. 2016. Cooper Basin Petroleum Systems Modelling: Regional Hydrocarbon Prospectivity of the Cooper Basin, Part 3. Record 2016. Geoscience Australia, Canberra.&rft.creator=Hall, L.S. &rft.creator=Palu, T.J. &rft.creator=Boreham, C.J. &rft.creator=Edwards, D.S. &rft.creator=Hill, A.J. &rft.creator=Troup, A &rft.creator=Lawson, C. &rft.date=2016&rft.coverage=westlimit=139; southlimit=-29.5; eastlimit=144.5; northlimit=-24.5; projection=GDA94 / MGA zone 54 (EPSG:28354)&rft.coverage=westlimit=139; southlimit=-29.5; eastlimit=144.5; northlimit=-24.5; projection=GDA94 / MGA zone 54 (EPSG:28354)&rft_rights=&rft_rights=Creative Commons Attribution 4.0 International Licence&rft_rights=CC-BY&rft_rights=4.0&rft_rights=http://creativecommons.org/licenses/&rft_rights=WWW:LINK-1.0-http--link&rft_rights=Australian Government Security ClassificationSystem&rft_rights=https://www.protectivesecurity.gov.au/Pages/default.aspx&rft_rights=WWW:LINK-1.0-http--link&rft_rights=Creative Commons Attribution 4.0 International Licence http://creativecommons.org/licenses/by/4.0&rft_subject=geoscientificInformation&rft_subject=Data Package&rft_subject=QLD&rft_subject=SA&rft_subject=EARTH SCIENCES&rft_subject=Cooper Basin&rft_subject=Petroleum prospectivity&rft_subject=Petroleum systems modelling&rft_subject=Toolachee Formation&rft_subject=Patchawarra Formation&rft_subject=Epsilon Formation&rft_subject=Daralingie Formation&rft_subject=Roseneath Shale&rft_subject=Murteree Shale&rft_subject=Published_External&rft.type=dataset&rft.language=English Access the data

Licence & Rights:

Open Licence view details
CC-BY

Creative Commons Attribution 4.0 International Licence
http://creativecommons.org/licenses/by/4.0

Creative Commons Attribution 4.0 International Licence

CC-BY

4.0

http://creativecommons.org/licenses/

WWW:LINK-1.0-http--link

Australian Government Security ClassificationSystem

https://www.protectivesecurity.gov.au/Pages/default.aspx

WWW:LINK-1.0-http--link

Access:

Open

Brief description

The Cooper Basin is an upper Carboniferous to Middle Triassic intracratonic basin in northeastern South Australia and southwestern Queensland (Gravestock et al., 1998; Draper, 2002; Carr et al., 2016). The basin is Australia's premier onshore hydrocarbon producing province and is nationally significant in providing gas to the eastern Australian gas market. The basin also hosts a range of unconventional gas play types within the Permian Gidgealpa Group, including basin-centred gas and tight gas accumulations, deep dry coal gas associated with the Patchawarra and Toolachee formations, the Murteree and Roseneath shale gas plays and deep coal seam gas in the Weena Trough (e.g. Goldstein et al., 2012; Menpes et al., 2013; Greenstreet, 2015). The principal source rocks for these plays are the Permian coals and coaly shales of the Gidgealpa Group (Boreham & Hill, 1998; Deighton & Hill, 1998; Deighton et al., 2003). Hall et al. (2016a) reviews the maturity and generation potential of the Cooper Basin source rocks and is the third part of a series of reports reviewing various aspects of the hydrocarbon prospectivity of the Cooper Basin (see also Hall et al., 2015a; Hall et al., 2016a). This data pack contains the supplementary material accompanying this report. Over ninety 1D thermal and burial history models were integrated with the 3D basin model and source rock property characteristics to create a regional multi-1D petroleum systems model for the basin. The burial and thermal history of the model was calibrated using present day corrected temperatures and maturity indicators (Ro, Tmax). In addition lithologies for key wells were calibrated using velocity, density and thermal conductivity data. Thermal boundary conditions were modelled as transient heat-flow from base lithosphere. Crustal thickness and radiogenic heat production properties were used from published studies (e.g. Beardsmore, 2004; Meixner et al., 2012; Hall et al. 2015a). The 1D models are integrated with a 3D regional basin model (Hall et al., 2015a) to create a multi-1D petroleum systems model of the Cooper Basin. Parameters for source rock distribution, amount and quality were added from analysis of log data and source rock geochemical data (Hall et al., 2016a) and new Cooper Basin kinetics (Mahlstedt et al., 2015). This data pack includes the following grids for each source rock: temperature (°C), maturity (%Ro), transformation ratio (%), total hydrocarbon generation (mmboe/km2), oil expelled (mmbbl/km2), gas expelled (mmboe/km2; bcf/km2), oil retained (mmbbl/km2) and gas retailed (mmboe/km2; bcf/km2). The results quantify both the maturity and total maximum hydrocarbon yield of each source rock, providing important insights into the hydrocarbon prospectivity of the basin (Hall et al., 2015b; Kuske et al., 2015).

Lineage

Maintenance and Update Frequency: notPlanned
Statement: The input datasets and technical work flow used to generate these produces are described in Hall, L.S., Palu, T.J., Boreham, C.J., Edwards, D.S., Hill, A.J. & Troup, A. 2016. Cooper Basin Petroleum Systems Modelling: Regional Hydrocarbon Prospectivity of the Cooper Basin, Part 3. Record 2016. Geoscience Australia, Canberra.

Created: 2016

Issued: 31 05 2016

This dataset is part of a larger collection

Click to explore relationships graph

144.5,-24.5 144.5,-29.5 139,-29.5 139,-24.5 144.5,-24.5

141.75,-27

text: westlimit=139; southlimit=-29.5; eastlimit=144.5; northlimit=-24.5; projection=GDA94 / MGA zone 54 (EPSG:28354)

Other Information
Identifiers