Petroleum Systems Modelling for Petroleum Prospectivity Analysis in the Cooper Basin, Australia
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1 Petroleum Systems Modelling for Petroleum Prospectivity Analysis in the Cooper Basin, Australia Lisa Hall 1, Tony Hill 2, Tehani Palu 1, Chris Boreham 1, Dianne Edwards 1, Alison Troup 3, Liuqi Wang 1, 1 Geoscience Australia, ACT 2 Department of State Development, SA 3 Geological Survey Queensland, QLD Acknowledgements: 3D Geo, Andrew Murray, Andrew Stacey, Bianca Reece, Bruce Radke, Jim Preston, Russell Korsch, Steve le Poidevin and many more
2 Cooper Basin Australia s largest onshore conventional gas and oil producer Unconventional exploration targets: shale gas, basin centred gas, deep coal seam gas plays Principal source rocks: Permian coals and coaly shales of the Gidgealpa Group Mapping the petroleum generation potential of these source rocks, together with describing the resulting fluid composition, is critical for understanding the hydrocarbon prospectivity of the basin SOUTH AUSTRALIA Cooper Basin QUEENSLAND NEW SOUTH WALES Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
3 Project Aims To use basin and petroleum systems modelling as a tool to investigate the petroleum prospectively of Permian source rocks in the Cooper Basin. Workflow: Basin architecture and evolution: 3D regional basin model (structure surfaces, isopachs, lithofacies) Source rock geochemistry: Source distribution, thickness, type, quality, kinetics Integrated basin and petroleum systems modelling: Maturity maps, source rock yield, oil and gas generation potential Improve understanding of basin scale hydrocabon prospectivity Underpin future resource assessment studies Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
4 Structural Elements & Tectono-stratigraphy Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
5 Gidgealpa Gp Cooper Basin Source Rocks Conventional Source Res. Seal Continuous Gas Plays BCG Shale gas Deep dry CG key Permian source rocks: Toolachee Fm coal Toolachee Fm coaly shale Daralingie Fm coal Daralingie Fm coaly shale Roseneath Shale Epsilon Fm coal Epsilon Fm coaly shale Murteree Shale Patchawarra Fm coal Patchawarra Fm coaly shale Toolachee Roseneath Daralingie Epsilon Murteree Patch. Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
6 Depth (m) Regional 3D Basin Model B Cooper Basin structure surfaces and isopachs: Better integration of datasets across the state border Incorporation of new open file well picks and seismic interpretation Eromanga and Lake Eyre Basin surfaces: A Modeled from existing seismic interpretation and well picks Unconformities (with uplift and erosion) Based on existing studies; consistent with regional tectonic evolution A SW NE B Stratigraphic ages: Updated to GTS, inclusion of revised spore pollen zone ages Distance(km) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
7 Source Rock Distribution Toolachee Fm ~20m max thick Daralingie Fm ~1m max thick Roseneath Shale ~m max thick Source rock extent and gross formation thickness from 3D model. Toolachee/ Patchawarra Fms thickest and most extensive units. Daralinige, Roseneath, Epislon and Murteree restricted to the southern part of the basin Epsilon Fm ~195m max thick Murteree Shale ~ 90m max thick Patchawarra Fm ~60m max thick Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
8 Source Rock Net Thickness Toolachee Fm Daralingie Fm Toolachee, Daralingie, Epsilon and Patchawarra Formations mixed lithology SA: Sun and Camac (0) electrofacies mapping, with updated coal thicknesses QLD: new electrofacies maps consistent SA methodology coal coaly shale coal coaly shale Epsilon Fm Patchawarra Fm >0 m 0 m coal coaly shale coal coaly shale Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
9 Source Richness Toolachee Fm Daralingie Fm Roseneath Shale Present day TOC maps by lithology: Coal: average TOC ~ 70% Shales and coaly shales: TOC maps formation. Good excellent source potential across all formations (TOC> 2%) Highest TOCs associated with the Toolachee and Patchawarra coaly shales Epsilon Fm Murteree Shale Patchawarra Fm Original HI and TOC maps also generated for input into the petroleum systems modelling Present day TOC (%) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
10 Source Characterisation Toolachee Fm Daralingie Fm Epsilon Fm Patchawarra Fm Roseneath Shale Murteree Shale Oil Oil+gas Gas Coals/ coaly shales. TOCs: 2 0%; (coals > 50%) HI > 250 mg/gc (little variation by lithology highest HI values found in coals) Kerogen type II/III (non-marine) - Good gas to oil + gas source potential. Toolachee, Daralingie, Epsilon and Patchawarra formations show similar source characteristics Shales. TOC: 2 - %; HI s < 0 mg/gc Kerogen type III/IV (non-marine) - Gas prone No sweet lacustrine shales observed Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
11 Transformation Ratio (TR) Residual HI (mg HC/ g TOC) Depth (m) Source Rock Kinetics Down well geochemical and maturity profile: new sampling in Allunga Trough -1, SA Cooper basin kinetics (Malhstedt et al., 15). Consistent with Pepper and Corvi DE F (Type II/III IV; non-marine) Potential for late primary gas generation Calibration with natural maturity sequence from new sampling Bulk kinetics Natural maturity sequence (HI vs Ro) Malhstedt et al. (15) GA Record Download from Temp ( o C) Ro (%) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
12 Transformation Ratio (TR) Cumulative HC6+ Expelled (mmstb/km2) Cumulative HC6+ Expelled (mmstb/km2) Cumulative HC6+ Expelled (mmstb/km2) Hydrocarbons Expelled/ Retrained Expulsion/ Retention & Oil/ Gas Windows Petroleum retained: free + adsorbed Arco model (includes saturation of organic and inorganic porosity) Calibration with observed data (BI vs Ro) Need to better understand adsorption in coals Cooper specific maturity windows Cumulative HC6+ HC6+ Expelled (mmstb/km2) Cumulative HC1-5 HC1-5 Expelled (bcf/km2) Oil Retained Oil Retained Total Total (mmstb/km2) Gas Retained Gas Retained Total Total (bcf/km2) Cumulative HC6+ Expelled (mmstb/km2) Cumulative HC1-5 Expelled (bcf/km2) Oil Retained Total (mmstb/km2) Gas Retained Total (bcf/km2) TSI: TSI: Vitrinite-ARCO (%Ro) (%Ro) 0 Ro (%) Cooper Basin Ro (%) Tmax ( o C) Early oil Peak oil Late oil Wet gas Dry gas Over-mature > 3.5 > TSI: Vitrinite-ARCO (%Ro) Ro (%) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
13 Burial and Thermal History Modelling Set Up 1D models for > 90 wells Model setup: Thermal boundary conditions: transient heatflow from base lithosphere. Crustal thickness and radiogenic heat production properties from published studies Model calibration: Present day corrected temp. and maturity indicators (Ro, Tmax) (all wells). Lithology calibration: velocity, density, thermal conductivity (key wells) Integration with 3D basin model to generate maturity maps Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
14 Maturity Modelling Results Major variation in thermal history between depocentres. Key influences: Big Lake Suite Granodiorites, Late Cretaceous uplift and erosion, thermal blanketing effect of thick Permian coals. Toolachee Fm Roseneath Shale Murteree Shale Patchawarra Fm Windorah Trough (Marengo-1) Nappamerri Trough (Burley-2) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
15 Hydrocarbon Generation HCs Generated (Mmboe/km 2 ) Integration with source rock properties and 2-component kinetics => hydrocarbons generated Toolachee Fm Daralingie Fm Roseneath Shale Epsilon Fm Murteree Shale Patchawarra Fm HCs Generated (Mmboe/km 2 ) >50 0 Total hydrocarbons generated from the Permian Gidgealpa Group Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
16 Hydrocarbons Generated by Source Rock Total Hydrocarbons generated from the Permian Gidgealpa Group > 2x 6 MMboe No distinction is made for HCs adsorbed vs expelled. Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
17 Instantaneous GLR Expelled (scf/stb) Mid Patch source Oil Expelled (mmbbl/km2) 0 Ma Mid Patch source Oil retained Total (mmstb/km2) 0 Ma Mid Patch source Gas Expelled (bcf/km2) 0 Ma Mid Patch source Gas retained Total (bcf/km2) 0 Ma Fluids Expelled/ Retained & GOR 00 Test case: Patchawarra Formation coals GOR: instantaneous/ in situ fluid vs cumulative expelled Need to calibrate with observed data Mid Patch source GOR of Expelled Petroleum (scf/bbl) 0 Ma km Draft u2995 Sep Expelled GOR 1e+007 1e Instantaneous GLR Expelled (scf/stb) Cumulative GLR Expelled (scf/stb) TSI: Vitrinite-ARCO (%Ro) Outputs modified depending on the play type being assessed km 0 km u2995 Sep u2995 Sep Oil expelled km 0 km u2995 Sep u2995 Sep Oil retained Work in progress Patchawarra coal Gas expelled Gas retained Unconventional Gas Prospectivity Cooper Basin APPEA 15
18 Conclusions Map of cumulative hydrocarbons generated from all Gidgealpa Gp source rocks highlights the broad extent of the source kitchen Largest contribution from Toolachee and Patchawarra coals and coaly shales. Results show the importance of BPSM as a predictive tool for understanding the regional petroleum resource potential. Work in progress: improve expulsion models to map hydrocarbons expelled and retained, along with fluid composition application of Monte Carlo simulations to capture model uncertainty HCs Generated (MMboe/km 2 ) Petroleum Systems Modelling for Play Analysis in the Cooper Basin AAPG ICE 15
19 Please visit us at the following locations: Basin Modeling Poster Session, Wed am - # P Australian Government Petroleum Booth - # 529 This paper is published with the permission of the CEO, Geoscience Australia Phone: Web: lisa.hall@ga.gov.au Address: Cnr Jerrabomberra Avenue and Hindmarsh Drive, Symonston ACT 2609 Postal Address: GPO Box 37, Canberra ACT 2601
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