Completed a technical assessment of the petroleum potential of the Taranaki Basin. Defined the key plays, petroleum systems, leads/prospects, and risks. Made recommendations on future exploration activity based on prevailing technical and economic conditions. Datasets were regional in scale, with 2D seismic and well data (e.g. petrophysical logs, cores, core analysis results, pressures, fluids, well tests).
All-domain Anomaly Resolution Office U.S. Department of Defense (U) Case: “Eg...
Assessment of Exploration Opportunities within the Taranaki Basin, New Zealand
1. Assessment of Exploration Opportunities within the
Taranaki Basin, New Zealand
Nathan Quick- Introduction
Anne Brennan- Basin History
Zach Ghalayini- Seismic
Hunter Lipman- Petroleum System
Joseph Morris- Risk Analysis
4. • 9 Wells with 8 having various
digital well logs 1976-2004
• 215 2D Seismic Lines; ranging
over 17 different surveys from
1975-2007
• Only 1 survey after 1997
• Geochemical Data from 4 wells
• Study Area: 38, 465 mi2
19911977
Gas-Condensate
Well
Dry Well
Oil Well
2D Seismic Line
Study Area
Oil Field
Gas/Gas-
Condensate
Field
5. Gas-Condensate Well
Dry Well
Oil Well
Prospects
Lead
Study Area
Oil Field
Gas/Gas-Condensate
Field
Maui
Field:
3.66 TCF
Maari-
Manai:
120.1
mmbbl
Kupe Field:
243 BCF
Kapuni
Field:
1.96 TCF
6. Late Cretaceous Fluvial to Coastal
Sandstone Play
Paleocene Marine Transgressive Sandstone
Play
Miocene Turbidites, Terrestrial to Marginal Marine
Sandstone Play
R
R
R
R
S
Se
Se
Se
Neogene Turbidite Fan Play
S
Se
Prospect Play Reserves (Risked
P10)
Weathertop L.
Cretaceous
SS
Prospect Play Reserves
(Risked P10)
Isengard Paleocene
Fluvial SS
191 BCFE
Miocene
Turbidites
40 BCFE
Prospec
t
Play Area
Rivendel
l
Neogene
Turbidite Fan
130,000 Acres
Isengard ProspectWeathertop ProspectRivendell Lead
7. Introduction
Integrated Regional Setting
Seismic Interpretation
Play Concepts
Petroleum Systems
Prospect Evaluation
Conclusion &
Recommendation
s
https://www.pinterest.com/pin/526569381402188308/
8. K
Pg
Ng
Q
Period EW
J
Epoch
PaleoceneEoceneOligoceneLateMiocenePliocenePleistocene
toRecent
Early
Basement
Late
Back arc rift
Subduction
S
Se
R
R
R
Organic Shale
Sands Carbonates
Fine-grained clastics
Hiatus
Stratigraphy Column Key:
Volcanics S
R
Se
Source
Reservoir
Seal
R 8 mi.
Paleocene
Cretaceou
s
Miocene
Eocene
Pliocene
A’ A
15000’
5000’
10000’
Depth
Ngatoro Gp
Wai-iti Gp
Rotokare Gp
Moa Gp
Kapuni Gp
Pakawau Gp
Syn-Rift
Subsidence
Compression
Extension
AA’
Location of 2D seismic line
Se
Drift
Images modified by terra.govt.nz.
Se
Se
R
Oligocene
9. K
Pg
Ng
Q
Period EW
J
Epoch
PaleoceneEoceneOligoceneLateMiocenePliocenePleistocene
toRecent
Early
Basement
S
R
8 mi.
Kapuni Gp
R
SW NE
Basement
Turi
Farewell
Rakopi
Fm
North Cape
Se
Pacific Plate
Australian Plate
N
Australia
Antarctica
150 Ma
Key
Plate Motion
New Zealand
Study Area
Modified from Ron Blakey and Colorado Plateau Geosystems Inc.
Rangitata Orogeny
120 MaN
New Zealand MovementAntarctica
Australia
Australia
Antarctica
New Zealand Movement
N 105 Ma
Tasman Sea
Australia
Antarctica
90 MaN
Australia
Antarctica
N 65 Ma
Pakawa
u Gp
UL IBA, 2016
Late Cretaceous
WN
UL IBA, 2016
Turi Farewell
W
N
Paleocen
e
10. UL IBA, 2016
WN
Eocene
Modified from Ron Blakey and Colorado Plateau Geosystems Inc.
K
Pg
Ng
Q
Period EW
J
Epoch
PaleoceneEoceneOligoceneLateMiocenePliocenePleistocene
toRecent
Early
Basement
S
R
Se
Se
New Zealand
Movement
Australia
Antarctica
N 50 Ma
Antarctica
Australia
35 MaN
Australia
25 MaN
8 mi.
Kapuni Gp
Ngatoro Gp
UL IBA, 2016
WN
Little
sediment
input
Late Oligocene
Australian
plate
Pacific plate
SW NE
Tikorangi
Turi
R
15. 5000 ft
5000 ft
10,000 ft
10,000 ft
Tane -1 Taranga -1 Witiora -1 Pateke -2 Tui -1
Wainui -1 Kora -1 Ariki -1 Pohokura - 2
Turi
Rakopi
North Cape
Farewell
Tikorangi
Ariki
Tikorangi
Farewell
Turi
Giant Foresets
Farewell
Tikorangi
Turi
Farewell
Turi
Tikorangi
Giant Foresets
16. A
1 s
-
2 s
-
3 s
-
4 s
-
A’
A
A’
Tane - 1
Ariki
Tikorangi
Farewell
Basemen
t
Tane - 1
17. Future Opportunities:
• Neogene Turbidite Fan Lobes
• Neogene Turbidite Ponding against
Aeotea Knoll
• Miocene Volcanoclastics
• Late Cretaceous North Cape Marine Transgressive sands
Present Opportunities:
• Isengard (Cretaceous through Miocene)
• Weathertop (Cretaceous)
• Paleocene Farewell Fluvial sands
• Mid Miocene Moki Turbidite sands
18. 5000 ft -
10,000 ft -
15,000 ft -
Structure
Moki SS
CI : 0.02s ≈ 140 ft
0 10mi
• Structural high Moki SS
• Sourced by Rakopi Coal Member
• Sealed Ariki Mudstone
• Trapped by 4-way closure (Rollover Anticline)
S
R
R
Se
Se
BB’
SE
B
NW
B’ Giant Foresets
Manganui
Tikorangi
Turi
North Cape/
Farewell
Rakopi
Basement
• Structural high Moki SS
• Sourced by Cretaceous Pakawau Group
• Sealed by Ariki Siltstone and Manganui Mudstone
• Trapped by 4-way closure (Rollover Anticline)
Moki Turbidites
19. 5000 ft -
10,000 ft -
15,000 ft -
20,000 ft -
Structure
North Cape SS
CI : 0.02s ≈ 140 ftSe
R
S
R
Se
NW
C’
C
C’
0 10mi
Giant Foresets
Moki Turbidites
Manganui
Tikorangi
Turi
North Cape
Rakopi
Basement
• Drape over Feature of the Creataceous North Cape
Reservoir
• Sourced by Cretaceous Pakawau Group
• Sealed by Turi Mudstone and Tikorangi Limestone
SE
C
Wainui - 1
Facies Distribution and Impact on Petroleum Migration in the Canterbury Basin,
New Zealand* Tusar R. Sahoo1 , Karsten F. Kroeger1 , Glenn Thrasher1 , Stuart
Munday2 , Hugh Mingard3 , Nick Cozens2 , and Matthew Hill1 Search and
Discovery Article #10816 (2015)
21. Pakawau Group
• Coal and Shale Formations
• Swamp, fluvial, and overbank
deposits
I Oil Prone
III Gas Prone
II Oil Prone
HydrogenIndex
Oxygen Index
1000
0 300
Offshore Wells
Onshore Wells
Composite
Type Log
Increase in Type 2 Kerogen
Se
Se
R
R
R
R
S
S
S
S
• Type 2 & 3 Kerogen
• Average TOC-10%
Pakawau
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau Pakawau
Reservoir Farewell/Miocene North Cape
Seal Turi/Manganui Manganui
22. Structure of Pakawau Base
Need Scale from
Seismic
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau Pakawau
Reservoir Farewell/Miocene North Cape
Seal Turi/Manganui Manganui
23. Deepwater Virtual
Deepwater Maturation
• Pakawau buried to
depths of 8000m
Graben Complex
Maturation
• High Heat flow
(120mW/m2) during
initial rifting in late
Cretaceous
0m
2000m
4000m
6000m
8000m
Deepwater Virtual Well Pohokura Well
0m
2000m
4000m
24. HIGH RISK:
• No well control
• Immature/oil
generation
window
MODERATE RISK:
• Well control in oil
generation
window
• No well control in
Deepwater basin
LOW RISK:
• Well Control
• Oil & Gas
Expulsion
Windows
.9.7
.7
.6
.8
.5
.5
.6
<.4
<.4
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(.9) Pakawau(.6)
Reservoir Farewell/Miocene North Cape
Seal Turi/Manganui Manganui
>.9
25. Miocene Turbidites
• Moki and Mt. Messenger
• 14-31% Porosity
• Average perm. 135mD
• Production: Maari,
Kaimiro, and Ngataro
fields
Farewell Fluvial
Sandstone
• Up to 20% Porosity
• Several hundred mD of
permeability
• Production: Maui and Tui
fields
Northcape Sandstone
• Porosity up to 25%
• Permeability over 500mD
3
2
Se
Se
R
R
R
R
S
S
S
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(1) Pakawau(.6)
Reservoir Farewell/Miocene North Cape
Seal Turi/Manganui Manganui
Outcrop of Miocene Turbidites
Composite
Type Log
Miocene
Turbidites
Farewell
Northcape
Pakawau
26. MODERATE RISK:
Presence of
Northcape Formation
that has had variable
exploration
LOW RISK: Presence
of Farewell and
Miocene Reservoirs
HIGH RISK: No well
control, no known
effective reservoirs
<.4
.5-.7
.8
.9
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(.1) Pakawau(.6)
Reservoir Farewell(.8)/Miocene(.9) North Cape(.7)
Seal Turi/Manganui Manganui
27. Manganui
Mudstone
• Calcareous
Mudstone
interbedded
with
limestone
cement
Turi
Mudstone
• Argillaceous,
non-
calcareous.
• Mean pore
throat size of
<.035 um
• Vsh ranges
.25-.85
Turi SEM
Pohokura-2 Witoria-1 Wainui-1 Taranga-1 Tane-1 Pateke-2 Kora-1 Ariki-1
Manganui
Turi
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(.1) Pakawau(.6)
Reservoir Farewell/Miocene(.9) North Cape(.7)
Seal Turi/Manganui Manganui
Controlling Factors: Sedimentation Rate,
Overpressuring, Hydrostatic Gradient, and Tectonic Breaching
Composite
Type Log
Miocene
Turbidites
Farewell
Northcape
Pakawau
Se
Se
R
R
R
R
S
S
Turi
Manganui
28. Turi Vshale- Grainsize Turi Thickness(m) Turi Porosity+Density
Neutron Porosity(m/m3)
BulkDensity(g/cc)
Poor Seal
Moderate Seal
Good Seal
0.0 .45
2.951.95
Modified from cns.gov
250
200
150
100
.4
.5
.6
.3
.8.7
Vsh=(GRlog-GRclean)
(GRshale-GRclean)
(1) (.6)
(.9) (.7)
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(.9) Pakawau(.6)
Reservoir Farewell/Miocene(.9) North Cape(.7)
Seal Turi/Manganui Manganui
+ +
29. MODERATE RISK:
location of
moderate seal
effectiveness
LOW RISK:
Location of a
thick, shaly,
dense, low
porosity seal
HIGH RISK: No
well control and
believed to be
location of poor
quality seal
Risking PSE Elements
Element Isengard Weathertop
Source Pakawau(.9) Pakawau(.6)
Reservoir Farewell/Miocene(.9) North Cape(.7)
Seal Turi/Manganui(.8) Manganui(.6)
.9.8
.7
.6
.5
<.4
33. Rock Properties p90 p10
Net Sand (ft)
Effective Porosity
(%)
Sw Saturation (%) 45 10
Gas RF (%) 58 83
Permeability (mD) 20-800
Miocene Turbidite
Sand
Paleocene Fluvial
SandRock Properties p90 p10
Net Sand h (ft)
Effective Porosity
(%)
Sw Saturation (%) 45 10
Gas RF (%) 58 83
Permeability (mD) 1-350
Composite
Type Log
0
5
10
15
20
25
30
35
0 5 10 15
Effective Porosity
Miocene-Paleocene Sands
Mt. Messenger
Porosity
Moki Porosity
Paleocene
Porosity
0
20
40
60
80
1 2 3 4 5
Net Sand Distribution
Miocene-Paleocene Sands
Moki Farewell
S
R
S
S
R
R
S
e
S
e
S
e
p90
p10
p90
p10
p10
p90
p90
p10
64 147
11 25
72 108
9 21
Miocene
Paleocene
34. Miocene Risked
Reserves (BCFE)
p90 5
pMean 19
p10 40
p1 99
Miocene
Potential
Reserves (BCFE)
p90 8
pMean 29
p10 62
p1 152
Miocene Geologic
Probability of
Success
Source 1
Migration .7
Reservoir .8
Trap .7
Seal .9
Geol P.O.S. 35%
Paleocene Geologic
Probability of
Success
Source 1
Migration .9
Reservoir .7
Trap .6
Seal .8
Geol P.O.S. 30%
Paleocene
Risked Reserves
(BCFE)
p90 33
pMean 97
p10 191
p1 388
Acreage
400 3400
Acreage
1050 4150
Strengths
Reservoir
Seal
Risks
Structure
Trap
Paleocene
Potential
Reserves (BCFE)
p90 47
pMean 139
p10 273
p1 554
High
Low
Structure Map
Miocene Moki Sand
CI : 0.02s ≈ 140 ft
mile
s
Structure Map
Paleocene Farwell
Sand
CI : 0.02s ≈ 140 ft
mile
s
Stacked Miocene,
Paleocene Sand Map
5 miles
Structure Map
Miocene Moki Sand
CI : 0.02s ≈ 140 ft
mile
s
35. PTD 17,000’
Farewell
Sand
Moki Sand
2.0s
1.0s
3.0s
4.0s
W E
Stacked Miocene,
Paleocene Sand Map
S
e
R
R
S
e
S
5,000’
10,000’
15,000’
mile
s
Structure Map
Miocene Moki Sand
CI : 0.02s ≈ 140 ft
mile
High
Low
Structure Map
Miocene Moki Sand
CI : 0.02s ≈ 140 ft
mile
s
Miocene Targets
Total Potential for
Play Type:
8,500 MMboe/ac-ft
36. Source maturity
Oil window
Miocene +Paleocene
Stacked Sand Overlay
Well Logs
Sands Thicken
Less Overburden
. Weathertop Lead
Tane-1 Wainui-1
38. Rock
Properties
p90 p10
Net Sand h (ft.)
60 504
Effective Porosity (%)
13 16
HC Saturation (%)
40 60
RF (%)
20 40
Permeability (mD)
>500
Late Cretaceous Transgressive
Sands
Composite
Type Log
R
S
e
S
Canterbury Basin Analog Map
Example of future target:
Strat drape/onlap seismic
image
Source: Resource Assessment of the
Kaheru Prospect, Taranaki Basin, NZ (May
31, 2011) for Tag Oil
Facies Distribution and Impact on Petroleum Migration in the Canterbury Basin, New
Zealand
39. Structure map
Of Miocene, Paleocene time,
show spill point,
Show idea,
P1 value
Map grid spacing,
show location of
opportunity
Cretaceous
Potential Reserves
(MMBO)
p90 185
pMean 2,300
p10 6,050
p1 24,900
Cretaceous Geologic
Probability of
Success
Source .8
Migration .9
Reservoir .6
Trap .5
Seal .5
Geol P.O.S. 11%
Cretaceous Risked
Reserves (BCFE)
p90 20
pMean 250
p10 665
p1 2,750
Strengths
Gather data to de-risk new
Play Type in Basin
Risks
Trap
Seal
Acreage
2,300 41,000
Structure Map
Late Cretaceous
North Cape Sand
CI : 0.02s ≈ 140 ft
scale
43. • 3 Target Reservoirs with Hydrocarbon
Potential
• Along Trend with Producing Fields
• Potential for Exploration Expansion 2
New Play Types Deep in the Basin
• Massive Potential for High-Quality
Turbidite Sand Deposit (Rivendell)
• All Within Thermally Mature Hydrocarbon
Producing Source Rocks
Gas-Condensate Well
Dry Well
Oil Well
Prospects
Lead
Study Area
Oil Field
Gas/Gas-Condensate
Field
Volcano
2 Untested Fault/Structure Bound
Prospects with x BCFE of P10
Reserves
44. Play Prospect Mean Risked
Reserves
(BCFE)
Geologic P.O.S.
L. Cretaceous
Sands
Weathertop
Paleocene Fluvial
Sands
Isengard (Deep) 97 30%
Miocene Turbidite
Sands
Isengard (Shallow) 19 35%
Seismic Lines through Prospects
Reservoir Depth
PTD
• Excellent Proven
Source (Pakawau
Group) Still Producing
• Efficient Multi-
Objective Wells
• Four Distinct Play Types
• Late Cretaceous Transgressive
Marine Sands
• Paleocene Fluvial Sands
• Miocene Turbidite Sands
• Miocene Turbidite Sheet Deposit
• Hydrocarbon Production within Our
Study Area (Tui-1, Kora-1, Pohokura-
2, & Pateke-2) and in Close Proximity
(Maui, Kupe, Kapuni, Maari-Manaia
Fields)
• Successful Tests Could Expand
Exploration within the Taranaki Basin,
Creating New Opportunities
46. Plannin
g
Year 1 Year 2 Year 3
Jan-Apr May-Aug Sep
-
Dec
Jan-Apr May-
Aug
Sep-Dec Jan-Apr May-Aug
Leasing &
Permitting
Acquire Well Logs
& Seismic
Perform Economic
& Engineering
Risk Evaluation
Acquire
Available
Seismic Data
to Confirm
Structure for
Isengard
Prospect
Process and Depth
Migrate Data
Around Isengard
Prospect
*Farm out lease
if structure not
confirmed
Test
Paleocene &
Miocene
Reservoirs in
Isengard
Prospect
Test North
Cape
Reservoir in
Weathertop
Prospect
*If Successful, Locate Similar
Structures Within Deep Water
Taranaki
*If Unsuccessful, Analyze Data
Acquired from Well, and Re-evaluate
Play Type
* If No
Structure
Found, Farm
Out Lease
for Rivendell
Acquire 3D
Seismic for
Process and Depth
Migrate 3D Seismic
Perform
Economic &
Test Rivendell
Turbidite
Deposit
47. Year 1 2 3 4 5 6
Purchase
existing 3D
data
Reprocess
Data
Re-evaluate
Possibility
of Success
Drill
Isengard
Develop
play-type
Re-evaluate
other
prospects
Drill
Weathertop
Prospect
Success Success
Develop play
Drill
Rivendell
Exit
48.
49.
50. K
Pg
Ng
Q
J
PaleoceneEoceneOligoceneLateMiocenePliocenePleistocene
toRecent
Early
Basement
Late
Petroleum System: Weathertop
Trap Stratigraphic: drape across rift blocks
Seal Late Cretaceous marine shale
Reservoir Primary: Rakopi Sands (Late
Cretaceous); North Cape Fm Marine,
Fluvial Sands (Late Cretaceous)
Source Rakopi Equivalent delta and time-
Legend
Oil Shows
Gas-Condensate Test
Dry Hole
CRETACEOUS
PLAY MAP
- Pertinent wells
- Prospect
Zoom of
prospect
Log snips of
Cretaceous
sands, Wainui,
Tane GREAT SOUTH
BASIN ANALOG
51. Legend
Oil Discovery Well
Gas-Condensate Test
Dry Hole
Migration Path
Unrisked
volume
PLAY MAP
- Pertinent wells
- Prospect
Log snips of
Miocene sands
WN
Moki Formation
K
Pg
Ng
Q
Period EW
J
Epoch
PaleoceneEoceneOligoceneLateMiocenePliocenePleistocene
toRecent
Early
Basement
Late
Petroleum System: Isengard
Trap Structural: 4-way dip closure
Seal Manganui Shale (Miocene); Tane marine
Shale (Paleocene)
Reservoi
r
Primary: Moki Sands (Miocene);
Secondary: Farewell Fm (Paleocene)
Source Rakopi Coaly Sands (Type II) and
marine shale (Type III)
RESERVES
52.
53.
54. • Geomorphology:
• No marine reworked margin (shoreline)
• No distributary mouth bar
• Up-dip bypass channel (trap/lateral seal!)
• Sequence stratigraphy:
• Basin floor fan above sequence boundary
• Downlap of lowstand wedge from above
• Overlain by highstand deltas
• Implications:
• Adjacent shales possible resource play! (outcrop analog
of
Editor's Notes
Type log?
Prospect risked reserves
Annotated Seismic lines for prospects