SOUTH AUSTRALIAN COOPER BASIN EXPLORATION OPPORTUNITIES - 2004 Elinor Alexander
Assessment of Hydrocarbon Potential in Cooper Basin, Australia
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Transcript of Assessment of Hydrocarbon Potential in Cooper Basin, Australia
ASSESSMENT OF HYDROCARBON POTENTIAL IN COOPER BASIN, AUSTRALIAUniversity of Miami Rosenstiel School of Marine and Atmospheric ScienceTeam Members: Putri el AkmalCaitlin Augustin (Team Captain)Ben GalfondPaul HaganDeniz Kula
April 12, 2013
Executive Summary• 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
Sebastian 116.77 MMBOE
Hurricane 28.54 MMBOE
Ibis 58.04 MMBOE
Reynolds et all, 2006
Location: Southeast Australia•Study area•Data given
• 3D seismic• Well logs• Well reports
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
0 50 100 150 200 250 300 350 400 450 5000
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Cooper Basin Gas Commercial Success Rate
Gas Exploration WellsG
as D
isco
verie
s
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Cooper Basin Oil Commercial Success Rate
Oil Exploration Wells
Oil
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cove
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0 50 100 150 200 250 3001960
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Cumulative Commercial Discoveries Oil and Gas
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Introduction
REGIONAL CONTEXTTectonic setting • Regional context • Analogues
• Proterozoic basement of volcanics, radiogenic elements and granitic intrusions
• Earliest tectonic evidence is tensional rifting
• Compressional foreland basin throughout the remainder of sedimentary deposition
The Basin Complex
Hallman, et al, 2007
Hallman, et al, 2007
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Warburton Development
• Tasman Line – paleo east coast• Cambrian-Ordovician deposition
• Early volcanics• Marine & terrestrial deposits
• Compressional folding and faulting
Roberts, et al, 1990
Hallman, et al, 2007
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
Image: DMITRE, AustraliaPearson Scott Foresman, 2007
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Cooper Development
Alexander, et al, PGSA vol 4
Hallman, et al, 2007
Apak, et al, 1997
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Eromanga Development
Alexander, Sansom, Cotton, 1996
Hallman, et al, 2007
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Analogue – Junggar Basin China
• 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
Sun, et al, 2010
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
INTEGRATED PETROLEUM SYSTEM ANALYSISSource • Generation • Reservoir • Trap Formation • Seal • Migration
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
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
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)
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
• Large, deep gas kitchen down-dip from our study area is likely gas source for Tirrawarra and Patchawarra formations
Source Maturation:Below the Nappamerri seal
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(62 miles)
Map generated in Trinity with data provided by DMITRE
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)
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
Patchawarra Facies Analysis
• Primary play target• Tested pay in all three wells• Large coal source• interbedded sandstone reservoir
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
3200.00 3300.00 3400.00 3500.00 3600.00 3700.00 3800.00 3900.00 4000.00 4100.00 4200.007000
7500
8000
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9500 Pressure (psig)
dept
h (ft
adj
uste
d fo
r kb)
Pressure v. Depth
PlotCooba
Water Gradient
Slope=.43
Seals
Gas GradientSlope=.1
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
1500 1750 2000 2250 2500 2750 3000 3250 3500 3750 4000 4250 4500 4750 50005000
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Pressure v. Depth
PlotMeranji
Water Gradient
Slope=.43
Seals
Gas GradientSlope=.1
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
3600 3700 3800 3900 4000 4100 4200 4300 44008000
8100
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Pressure v. Depth
PlotPelican
Water Gradient
Slope=.43
Seals
Gas GradientSlope=.1
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
TECHNICAL INTERPRETATIONSWell-log interpretation • Consistency of seismic • Geologic concepts • Play Element Maps
Well Analysis
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Hallman, et al, 2007
Well Log CorrelationDT DT DTGR GR LLD GR LLD
L.C
arbo
n
L.C
arbo
nıfe
E.
Per
mıa
n
Per
mıa
nE
.Tria s
M.J
uras
L.Ju
raE
arly
to L
ate
Cre
tace
ous
4.21 miles 4.76 miles
5000 ft 5000 ft 5000 ft
10000 ft 10000 ft
7500 ft 7500 ft 7500 ft
Residualgas only
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Residualgas and oil
Seismic Ties
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
GR RHOBDTLLD
Cadna-owieEarly Cretaous
Nappameri SealEarly Trassic
NamurMiddle Jurassic-E.Creta
Patchawarra CoalEarly Permian
Tirrawarra Sandstone
Late Carboniferous-E.P
Cross Section
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
1)Fault Type: Transpressional Fault2) Uplift: Folding to Eromanga3)Erosion:Patchawarra and Toolache
A B
B
A
Stratigraphic Traps
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Stratigraphic Trap:Patchawarra Formation
A BPelican
B
A
Pinch out
Play Events Charts
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
#1: Tirrawarra
#2: Patchawarra
#3: Mooga
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
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
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.
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
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
Tirrawarra Play
Source: oil and gas mature
.9
Reservoir: tested pay, traps
1
Seal: Murtee shale
.83
Play Risk
.75
SourceSeal
Reservoir
DMITRE, Australia
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
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
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
0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 10
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Pseudo Capillary Pressure Relationship (Drainage direction)HC Column Height (Meters) (method of Hawkins, Luffel, and Harris, 1993)
Patchwarra 1Patchawarra 2Patchawarra 3Patchawarra 4
Non-wetting phase saturation (%)
Equi
vale
nt H
C C
olum
n H
eigh
t (m
eter
s)
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Play #2: Patchawarra Play
Source: oil and gas mature
.9
Reservoir: tested pay, traps
.83
Seal: Nappamerri Shale
1
Play Risk
.75
SourceSeal
Reservoir
DMITRE, Australia
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
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
Play #3: Mooga Formation
Source: immature, oil migrates to reservoir
.3
Reservoir: tested pay, traps
1
Seal: Cadna-owie formation
1
Play Risk
.3
Source SealReservoirDMITRE, Australia
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
RISK ASSESSMENT, HYDROCARBON OCCURRENCE, VOLUMETRICS AND TECHNICAL RECOMMENDATIONS
Prospect Locations
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
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
(6.2 miles)
(6.2 miles)
(6.2 miles)
Hurricane Prospect: Traps
Patchawarra and Tirrawarra are stratigraphic traps against the unconformity
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Mooga is a 4-way trap
Hurricane Prospect: Play and RiskTrap .9
Porosity .8
Sw .8
Reservoir Quality
1
x .58
Trap .9Porosity .8
Sw .8Reservoir
Quality1
X .58
Trap .9
Porosity .8
Sw .8
Reservoir Quality
.9
x .52
Mooga
Tirrawarra
PatchawarraFormation GCOS (Play
Risk x Prospect Risk)
Mooga .17
Patchawarra .43
Tirrawarra .39
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Hurricane Prospect: Probability and
Volumetrics
FormationMin
RecoverableMMBOE
Most Likely
RecoverableMMBOE
Max Recoverable MMBOE
Tirrawarra 5.45 9.01 13.48
Tirrawarra, 25% CO2
3.93 6.83 10.11
Patchawarra 9.51 15.680 23.47
Patchawarra, 25% CO2
7.13 11.76 17.61
Mooga(Oil) 6.04 9.95 14.85
71% probability
that we will be successful in
one of the three plays
Volumetrics calculated using Palisade @Risk softwareRecovery factor of 21% oil, 64% gas (DMITRE, Australia)Lithology and facies information from well logs
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Ibis Prospect: Traps
4-way closures, possibly bounded by faults
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
A B
BA
Ibis Prospect: Play and RiskTrap 1
Porosity .8
Sw .8
Reservoir Quality
1
x .64
Trap 1
Porosity .8
Sw .8
Reservoir Quality
1
x .64
Trap 1
Porosity .8
Sw .8
Reservoir Quality
.9
x .58
Mooga
Tirrawarra
PatchawarraFormation GCOS (Play
Risk x Prospect Risk)
Mooga .19
Patchawarra .49
Tirrawarra .44
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
FormationMin
RecoverableMMBOE
Most Likely
RecoverableMMBOE
Max Recoverable MMBOE
Tirrawarra 24.54 16.28 16.38Tirrawarra, 25% CO2 18.41 12.21 12.29
Patchawarra 30.813 51.118 76.158
Patchawarra, 25% CO2 23.10 38.34 57.19
Mooga(Oil) 4.55 7.49 11.18
Volumetrics calculated using Palisade @Risk softwareRecovery factor of 21% oil, 64% gas (DMITRE, Australia)Lithology and facies information from well logs
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Sebastian Prospect: Traps
A B
B
unconformity
Merimelia Fm Limit of Tirrawarra Ss +
Patchawarra Coal (Pinch out )
A
TirrawarraPatchawarra
AA
• Stratigraphic traps• East-west compression oblique to NE trending basement
features
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Sebastian Prospect: Play and RiskTrap 1
Porosity .9
Sw .9
Reservoir Quality
1
x .81
Trap 1
Porosity .9
Sw .9
Reservoir Quality
1
x .81
Trap .6
Porosity .9
Sw .9
Reservoir Quality
.9
x .44
Mooga
Tirrawarra
PatchawarraFormation GCOS (Play
Risk x Prospect Risk)
Mooga .24
Patchawarra .61
Tirrawarra .35
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
FormationMin
RecoverableMMBOE
Most Likely
RecoverableMMBOE
Max Recoverable MMBOE
Tirrawarra 23.66 39.205 58.59Tirrawarra, 25% CO2 17.75 29.4 43.94
Patchawarra 22.793 15.288 9.279Patchawarra,
25% CO2 6.96 11.47 17.09
Mooga 45.985 75.901 113.483
Volumetrics calculated using Palisade @Risk softwareRecovery factor of 21% oil, 64% gas (DMITRE, Australia)Lithology and facies information from well logs
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)
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Mid Term Lead: Merimellia Formation
• Near the large gas kitchen
• Similar structures to the Patchawarra and Tirrawarra
• Deep formation, poor seismic—not low hanging fruit, which is why it has not been explored
DMITRE, Australia
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
Long Term Lead: Coal Seam Gas
•Depth of 1800 M•Natural closure of the cleat system
•Thick early Permian coal seams in the Patchawarra Trough are target
5.0% 90.0% 5.0%
1.24 9.76
02
46
810
1214
1618
0.00
0.02
0.04
0.06
0.08
0.10
0.12
0.14
0.16
0.18
Recoverable
Recoverable
Minimum0.251Maximum17.14Mean 4.67Std Dev 2.64Values 5000
Volumetrics for a sample basin, 550 acre flooding plainMin 13.993
Most Likely 38.65
Max 25.464
DMITRE, Australia
Regional Context • Integrated Petroleum System • Technical Interpretations • Risk Assessment, Hydrocarbon Occurrence, Volumetrics and Technical Recommendations
STEPS TO SUCCESS AND CONCLUSIONS
Next Steps
• Data needs• Deeper, higher resolution seismic to explore deeper plays and look at channel sands
• Well data from prospect wells to determine if they are in pressure communication in large traps (Mooga formation)
• Contingency plans• Drought prone region, will negotiate water rights to the Cooper’s Creek with neighboring tenements
Steps to Success and Conclusions
Political and Economic Environment
• Political Environment• New tenements for sale• Global increase in demand for hydrocarbon products
• Australian demand for energy independence
• Economic Environment• Technological improvements• Substantial network of buyers for unconventionals
• Increased market value of oil/gas
Steps to Success and Conclusions
Refining and ShippingAvailable gas and liquids pipelines exist from prospect sites to processing facilities in Mooba
Steps to Success and Conclusions
Diverse revenue streams
$$$
Oil
Wet Gas
Shale Gas
Unconventionals
Coal Seam Gas
Carbon
Dioxide
Steps to Success and Conclusions
Executive Summary• 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
Sebastian 116.77 MMBOE
Hurricane 28.54 MMBOE
Ibis 58.04 MMBOE
Steps to Success and Conclusions
THANK YOU FOR YOUR TIME
QUESTIONS?Special thanks to:
John Dolson, Chris Piela, Ralf WegerPalisade, Zetaware