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Assessment of Hydrocarbon Potential in Cooper Basin, Australia

Assessment of Hydrocarbon Potential in Cooper Basin, Australia. University of Miami Rosenstiel School of Marine and Atmospheric Science. Team Members : Putri el Akmal Caitlin Augustin (Team Captain) Ben Galfond Paul Hagan Deniz Kula. April 12, 2013. Executive Summary.

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Assessment of Hydrocarbon Potential in Cooper Basin, Australia

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  1. Assessment of Hydrocarbon Potential in Cooper Basin, Australia University of Miami Rosenstiel School of Marine and Atmospheric Science Team Members: Putri el Akmal Caitlin Augustin (Team Captain) Ben Galfond Paul Hagan Deniz Kula April 12, 2013

  2. Executive Summary Reynolds et all, 2006 • Economic viability • Multiple revenue streams • Oil and Gas Generation • Primary play is the Patchawarra formation • Secondary plays are the Mooga and Tirrawarra formations • Prospects • Hurricane: 71% chance of success • Ibis: 76% chance of success • Sebastian: 80% chance of success • Leads • Merrimelia Formation • Coal Seam Gas

  3. Introduction Location: Southeast Australia Study area Data given 3D seismic Well logs Well reports

  4. Introduction Exploration History 40% success rate for gas exploration 18% success rate for oil exploration Underexplored relative to other basins Focus on “low hanging fruit” Commercial standards 1.23 MMBOE Oil .638 MMBOE Gas

  5. Regional Context Tectonic setting • Regional context • Analogues

  6. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations The Basin Complex Hallman, et al, 2007 • Proterozoic basement of volcanics, radiogenic elements and granitic intrusions • Earliest tectonic evidence is tensional rifting • Compressional foreland basin throughout the remainder of sedimentary deposition Hallman, et al, 2007

  7. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Warburton Development Roberts, et al, 1990 • Tasman Line – paleo east coast • Cambrian-Ordovician deposition • Early volcanics • Marine & terrestrial deposits • Compressional folding and faulting Hallman, et al, 2007

  8. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations UnderlyingCompressional Structures Patchawarra Trough Merimella high Nappamerri Trough Troughs fill during Cooper deposition Create closures and angular unconformities Pearson Scott Foresman, 2007 Image: DMITRE, Australia

  9. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Cooper Development Apak, et al, 1997 Hallman, et al, 2007 Alexander, et al, PGSA vol 4

  10. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Eromanga Development Hallman, et al, 2007 Alexander, Sansom, Cotton, 1996

  11. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Analogue – Junggar Basin China Sun, et al, 2010 • Same compressive regime • Foreland basin • Rejuvenated faults • Permian and Triassic hydrocarbons • Lacustrine and fluvial deposition • Channel sand reservoirs • Oil and Gas reserves • Over 100 billion m3 (630 billion MMBOE) of Kelameili gas field is confirmed by the National Mineral Reserves Committee • Annual production capacity 710 million m3 (4465 million MMBOE) at the end of 2009 China National Petroleum Corporation

  12. Integrated Petroleum System Analysis Source • Generation • Reservoir • Trap Formation • Seal• Migration

  13. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Generation Window Mix of Type II/III kerogens, from lacustrine and terrigenous sources (C/D/E) results in narrow oil window and dominantly gas production

  14. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Thermal Models • Cooba well logs reported an average thermal gradient of 2.8 °F/100’ • AFTA and ZFTA show that this high gradient is a recent thermal spike • A thermal gradient of 2.1 °F/100’, closer to historical steady state, best fits our data

  15. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Source Maturation: Below the Nappamerri seal Tirrawarra formation in our seismic range is peak mature for oil but only early mature for gas Patchawarra maturity is very similar to Tirrawarra, peak mature for oil, but too early for significant gas. (6.2 miles) (6.2 miles)

  16. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Source Maturation:Below the Nappamerri seal (62 miles) Large, deep gas kitchen down-dip from our study area is likely gas source for Tirrawarra and Patchawarra formations Map generated in Trinity with data provided by DMITRE

  17. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Source Maturation: Mooga Maturation Mooga is not mature, and any hydrocarbons would have had to migrated up from deeper source rock. Nappamerri maturation is early oil, residual gas likely migration from regional gas kitchen. (6.2 miles) (6.2 miles)

  18. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Patchawarra Facies Analysis Primary play target Tested pay in all three wells Large coal source interbedded sandstone reservoir

  19. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Pressure v. Depth Plot Cooba Water Gradient Slope=.43 Seals Gas Gradient Slope=.1

  20. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Pressure v. Depth Plot Meranji Water Gradient Slope=.43 Seals Gas Gradient Slope=.1

  21. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Pressure v. Depth Plot Pelican Water Gradient Slope=.43 Seals Gas Gradient Slope=.1

  22. Technical Interpretations Well-log interpretation • Consistency of seismic • Geologic concepts• Play Element Maps

  23. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Well Analysis Hallman, et al, 2007

  24. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Well Log Correlation DT GR GR LLD DT GR LLD DT 4.21 miles 4.76 miles Early to Late Cretaceous 5000 ft 5000 ft 5000 ft L.Jura Residual gas and oil Residual gas only M.Juras E.Trias E. Permıan 7500 ft 7500 ft 7500 ft Permıan L.Carbonıfe L.Carbon 10000 ft 10000 ft

  25. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Seismic Ties GR LLD DT RHOB Cadna-owie Early Cretaous Namur Middle Jurassic-E.Creta Nappameri Seal Early Trassic Patchawarra Coal Early Permian Tirrawarra Sandstone Late Carboniferous-E.P

  26. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Cross Section A B 1)Fault Type: Transpressional Fault 2) Uplift: Folding to Eromanga 3)Erosion: Patchawarra and Toolache A B

  27. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Stratigraphic Traps A Pelican B Stratigraphic Trap: Patchawarra Formation Pinch out A B

  28. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play Events Charts #1: Tirrawarra #2: Patchawarra #3: Mooga

  29. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #1 Tirrawarra Formation Pelican well is shown to be outside of structural closure despite flowing water and showing hydrocarbons Cooba contains shows tight gas, yet no trap (6.2 miles)

  30. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #1 Tirrawarra Formation • SW in the Tirrawarra was 70-80% with good porosity of 10-14% • Produced 204’ of slightly gas cut mud with oil film. • Well has hydrocarbons, but the good porosity and high rate of water production combined with moderately high SW indicate that Pelican well is in a trap, it is in the bottom of the transition zone close to free water.

  31. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #1 Tirrawarra Formation To include the Pelican in the trap, we can extend the trap as shown. This indicates the structure may close in the Northeast, creating a much larger trap. Cooba’s 4-way closure is believed to extend beyond our map. Meranji tests and logs also reveal gas and oil shows and it is thus in the trap (6.2 miles)

  32. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Tirrawarra Play Source Reservoir Seal DMITRE, Australia Source: oil and gas mature Play Risk Reservoir: tested pay, traps Seal: Murtee shale .9 .75 1 .83

  33. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #2 Patchawarra Formation Cooba 4-way again is outside the scope of our seismic, though hydrocarbon presence lets us know it is in a trap Meranji is tight, but has movable gas and condensate, fitting with our seismic interpretation of being in a trap (6.2 miles)

  34. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #2 PatchawarraFormation Pelican well logs corroborate the structural trap at this level, as the SW measured at the well logs agree with expected SW values 60ft above free water from pseudo capillary pressure estimates

  35. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #2: Patchawarra Play Source Reservoir Seal DMITRE, Australia Source: oil and gas mature Play Risk Reservoir: tested pay, traps Seal: Nappamerri Shale .9 .75 .83 1

  36. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #3 : Mooga Formation Pelican is reported to be water saturated with only trace oil and gas, indicating it is likely just outside the trap as mapped Cooba logs show gas that is interpreted as residual Meranji tests movable oil, confirming it is in the trap (6.2 miles)

  37. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Play #3: Mooga Formation Source Seal Reservoir DMITRE, Australia Source: immature, oil migrates to reservoir Play Risk Reservoir: tested pay, traps Seal: Cadna-owie formation .3 .3 1 1

  38. Risk assessment, hydrocarbon occurrence, volumetrics and technical recommendations

  39. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Prospect Locations

  40. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Prospect Locations Each prospect reaches three plays Each prospect is in a trap on each play (6.2 miles) (6.2 miles) (6.2 miles)

  41. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Hurricane Prospect: Traps Mooga is a 4-way trap Patchawarra and Tirrawarra are stratigraphic traps against the unconformity

  42. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Hurricane Prospect: Play and Risk Mooga Patchawarra Tirrawarra

  43. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Hurricane Prospect: Probability and Volumetrics 71% probability that we will be successful in one of the three plays Volumetrics calculated using Palisade @Risk software Recovery factor of 21% oil, 64% gas (DMITRE, Australia) Lithology and facies information from well logs

  44. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Ibis Prospect: Traps B A 4-way closures, possibly bounded by faults B A

  45. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Ibis Prospect: Play and Risk Mooga Patchawarra Tirrawarra

  46. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Ibis Prospect: Probability and Volumetrics 76% probability that we will be successful in one of the three plays Volumetrics calculated using Palisade @Risk software Recovery factor of 21% oil, 64% gas (DMITRE, Australia) Lithology and facies information from well logs

  47. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Patchawarra Coal (Pinch out ) unconformity Merimelia Fm Limit of Tirrawarra Ss + A Sebastian Prospect: Traps • Stratigraphic traps • East-west compression oblique to NE trending basement features A B Tirrawarra Patchawarra B A A

  48. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Sebastian Prospect: Play and Risk Mooga Patchawarra Tirrawarra

  49. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations Sebastian Prospect: Probability and Volumetrics 80% probability that we will be successful in one of the three plays Volumetrics calculated using Palisade @Risk software Recovery factor of 21% oil, 64% gas (DMITRE, Australia) Lithology and facies information from well logs

  50. Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations New Technologies Hydraulic fracturing effectively creates permeability in tight rock by inducing fractures to release and conduct hydrocarbons Our targeted reservoirs all have good porosity and hold hydrocarbons; hydraulic fracturing will allow us to extract this large volume from tight rock previously deemed noncommercial (Suchy and Newell,2012)

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