the north montney - progress energy canada ltd. north montney daniel topolinsky executive vice...
TRANSCRIPT
The North MontneyDaniel Topolinsky
Executive Vice President,
Exploration & Development
Jim Stannard
Senior Vice President, Development
22
North MontneyEstablished as a World Class Gas Play
Q3 - 2008
• First vertical test
Q1 - 2009
• First horizontal test
Q1 - 2010
• First commercial developments
2011
• 80 producing horizontal wells
• 8 commercial developments
• 3 International joint ventures
Why the Global Interest?
• 300 m gas charged column
• Top tier economics
• Access to North American market & LNG
CYPRESS
FARRELL
TOWNCARIBOU
KOBES
SEPTIMUS
GROUNDBIRCH
DAWSON
SWAN
PARKLAND
3333
Putting North Montney in Perspective
Relative size compared to the entire Horn River Basin
Top Ten Montney Land Holders
190 km
SOURCE Cormark Securties
0100200300400500600700800900
10001100120013001400
Pro
gre
ss
En
can
a
CN
RL
Cel
tic
Gal
leo
n
AR
C
Sh
ell
Tal
ism
an
Bir
chcl
iff
To
urm
alin
e
Mo
ntn
ey L
and
Po
sitio
n (N
et S
ectio
ns)
190 km
4444
Best Leverage in Shale Gas
Play Largest Land Holder Acreage Held Enterprise Value
(as of 09/30/2011)
Montney Progress 825,000 acres C$ 3.4 B
Horn River Imperial/Exxon 309,000 acres US$ 365 B
Haynesville Chesapeake 440,000 acres US$ 29.8 B
Eagleford Petrohawk1 270,000 acres US$ 15.6 B
Barnett Devon 527,000 acres US$ 24.3 B
Fayetteville Southwestern 851,000 acres US$ 12.8 B
Marcellus Range 1,400,000 acres US$ 11.1 B
1 Acquired by BHP Billiton 08/26/2011 US$14.8B
SOURCE CIBC, EIA, Bloomberg
5
Geological Attributes
• 280 to 360 m thick
• Continuous gas charged productive section
• Permeable siltstone
• Over-pressured 11-17 kPa/m
• Area well control of over 150 Montneypenetrations
280m
360m
66
Continuous Stratigraphic Section
PRQ CARIBOUc-58-J/94-G-2
PRQ TOWN SOUTHc-50-J/94-B-16
PRQ KOBESD-57-H/94-B-9
1940.00
2240.00
1880.00
2240.00
LOWER MONTNEY
UPPER MONTNEY
HIGH ORGANICS
225m THICK
75m THICK
MIDDLE MONTNEY
7777
Relative Thickness
North Montney300m (985ft)
Haynesville90m (300ft)
Eagleford & Marcellus60m (200ft)
Fayetteville30m (100ft)
Concentrated Development
Frac Height Growth >100m
Monitoring Well
Meters
to surface• Microseismic used extensively
• Frac envelope typically 100m high and 400m wide
• Stagger pattern allows for up to 16 wells per section
8
9999
• Evaluated area represents 22% of North
Montney land base
• Estimate of Discovered Petroleum Initially in
Place (DPIIP) of 27 TCF
• Best estimate Contingent Resource of 8 TCF
• Best estimate Contingent Resource NPV8 of
$8.6B
Contingent Resource W.I. Raw BCF
Low Estimate 5.4
Best Estimate 8.1
High Estimate 10.2
TownDPIIP Area
Town Area DPIIP
190 km
10101010
TOWN NORTH
TOWN SOUTH
GUNDY
• Evaluated using 34 horizontal
and 15 vertical wells
• Detailed petrophysical and core
analysis
• Approximately the same
acreage as the NMJV
• Progress booked 590 Bcf of
P+P reserves in the area @
December 31,2010
Town Area DPIIP
KOBES
WESTGUNDY
1111
Progress North Montney Advantages
• Sweet Gas – lower processing costs
• High heat content
• Liquids-rich stream – significant revenue lift (~20 bbls/mmcf)
• BC deep drilling credit – royalty free production for 1 to 3 years
• Few surface stakeholders
• North Montney is Progress’ backyard – operating in the area for ten years
• Extensive 3D seismic in the area
1212
Among the Best Economics in Shale
SOURCE Morgan Stanley
$-
$1.00
$2.00
$3.00
$4.00
$5.00
$6.00
US$/mmbtu Required Strip for 10% IRR
Marcellus Wet
Pinedale
Marcellus Dry
Fayetville
Granite Wash
Montney
Huron Shale
Deep Bossier
Eagle Ford
Horn River
Cordova Embayment
Cana-Woodford
Nikanassin
Piceance
Barnett
Appalachian
Haynesville
Marcellus Dry (Tier
Eagle Ford
Montney-AB
Fayetteville
Jonah
AB Deep Basin
Woodford
Cardium
Wattenburg
Uinta
Piceance
Raton
GoM Shelf
AB Shallow Gas
Warwick
Barnett (Tier 2)
Group Average
1313
North Montney has Strong Economics
SOURCE Peters & Co. Limited estimates. Liquids are converted at 6:1.
$-
$1.00
$2.00
$3.00
$4.00
$5.00
Hzl
Mo
ntn
ey B
reak
even
Pri
ces-
Hal
f C
yle
(C$/
mcf
)
Kay
bo
b
PR
Q T
ow
n S
ou
th
Daw
son
/Par
klan
d
Gre
ater
To
wn
Ko
bes
Po
uce
Co
up
e
Sw
an
Gro
un
db
irch
141414
B.C. Deep Drilling Credit
EAST/WEST ROYALTY LINE
• East/West line to account for higher cost to the West
• Progress receives a credit of ~$2MM per well on the
West side
• Results in 1-3 years of royalty free production
• East Montney credit is ~$0.8-1MM per well
• Majority of Progress’ developments qualify for the
higher West credit
1515
Production Compares Favorably
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
1 2 3 4 5 6 7 8 9 10 11 12
Months
Rat
e (m
mcf
/d)
PRQ Town Dawson/Parkland Groundbirch
PRQ Kobes Pouce Coupe Swan
SOURCE Peters & Co. Limited, Accumap
1616
High Netback Growth
3.75Station #2 ($/GJ)
AECO (C$/GJ) 4.00
Typical Station 2 to AECO Differential (0.25)
Station #2 ($/mcf) 4.04
High Sales Stream Heat Premium ($/mcf) 0.63
Liquids Sales Premium ($/mcf) 0.70
Plant Gate Price ($/mcf including liquids) 5.37
InitialAfter Royalty
Credit
Average Royalty (@ $4.00/GJ) 0% 14%
Field Op Costs ($/mcf) 0.30 0.30
Processing and Transportation ($/mcf) 0.46 0.46
Operating Netback ($/mcf) 4.61 3.86
High Heat Content Gas
Significant price lift from liquids production
Royalty free production for 1 to 3 years
1717
High Return North Montney Projects
Reserves (bcf)
Initial Rate (mcf/d)
Risked Payout(years)
Rate of Return
F&D ($/BOE)
Cost of Production ($BOE/D) PIR
NPV10($MM)
Months Royalty Free
$4.00/GJ Case
4 4000 1.5 68% $7.87 $8,436 1.1 6.0 26
5 5000 1.2 103% $6.24 $6,740 1.5 8.4 19
$5.00/GJ Case
4 4000 1.1 103% $7.87 $8,436 1.5 8.4 19
5 5000 0.9 157% $6.24 $6,740 2.1 11.4 14
18
Attractive Full Cycle Economics
Typical 50 MMcf/d Development Pod
Wells required ~23
Capital to 50 mmcf/d $145 million
All-in cost of production $17,000/boepd
At Full Production ($4.00/GJ)
Royalty rate 14%
Operating Netback (per year) $72 million
Annual maintenance capex $33 million
Free cash flow (per year) $39 million
Remaining drilling inventory 10+ years
NPV10 @ C$4.00/GJ $264 million
0
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v-08
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09
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-09
No
v-09
Jan
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Mar
-10
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-10
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v-10
Jan
-11
Mar
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May
-11
Jul-
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Sep
-11
Gro
ss P
rod
uct
ion
(m
mcf
)
PRQ Gross Montney
19
Real Production Growth
McMahon Plant Turnaround
September 2011> 100 mmcf/d
20202020
TOWN NORTH
CARIBOU
KOBES
Ten Active Development Pods
TOWN SOUTH
WEST GUNDY
GUNDY
NIG
KAHTA JV
LILY JV
ALTARES JV
21
Pod Developments Phases
Town South
Kobes
Gundy
Town North
Caribou
West Gundy
Nig
JVs
22
Development Timeline
HORIZONTALPILOT PHASE(Horizontal follow-up of successful vertical)
PHASE 1 DEVELOPMENT(multiple Horizontal wells & initial facilities)
FULL DEVELOPMENT PHASE(drilling to fill expanded facilities)
MAINTENANCE PHASE(drilling to offset declines, keep facilities full)
Town South ���� Q3 2009 ���� Q1 2010 ���� Q1 2011 Q4 2011 ����
Kobes ���� Q3 2010 ���� Q4 2010 ���� Q1 2011 Q4 2012 ����
Town North ���� Q3 2010 ���� Q1 2011 ���� Q3 2011 Q1 2013 ����
Gundy ���� Q4 2010 ���� Q3 2011 Q1 2012 Q4 2012 ����
West Gundy ���� Q4 2011 Q1 2012 Q3 2012 Q3 2013 ����
Caribou ���� Q4 2010 Q3 2012 Q4 2012 Q4 2013 ����
Nig ���� Q2 2011 Q3 2012 Q4 2012 Q4 2013 ����
232323
2012 Development Wells
End 2011 2012 Drills
Town North 10 2
Town South 21 7-9
Gundy 11 8-11
West Gundy 1 8-12
Kobes 7 4
Total 50 35
TOWNNORTH
Number of Horizontal Wells
TOWNSOUTH
KOBES
WESTGUNDY
GUNDY
2424
Town South Development Pod
0
10
20
30
40
50
60
1 91 181
271
361
451
541
631
721
Days
Pro
du
ctio
n (
mm
cf)
0
5
10
15
20
25
Wells
Rate Wells on Production
Target Actual
Total cost ($MM) 145 166
Prod Cost ($/boepd) 16,667 19,137
252525
Well Developed Infrastructure
PRQ Kobes25 mmcf/d
PRQ West Gundy Q1 2012
25 mmcf/d
PRQ Town North25 mmcf/d
PRQ Town South 50 mmcf/d
Gundy Facility50 mmcf/d
Spectra RGTPipeline
T-North Pipeline
Non-operated Kobes25 mmcf/d
Spectra Highway Plant
Spectra AitkenCreek Plant
26
North Montney Infrastructure
Leader in Water Management
TOWN AREA
• 280,000m3 of water storage in twelve reservoirs
• Reservoirs constructed to capture spring runoff – “big rain barrels”
• 35,000m3 of recycled water storage
• Constructing over 15km of pipeline to interconnect the pods
2012 SOURCE FORECAST
• 40% Runoff capture
• 20% Re-used frac water
• 25% Recycled produced water
• 15% Other sources
27
28
West Gundy New Pod Development
• 20 sections of 100% land
• Close proximity to our existing
Kobes and Gundy pods
• First 25 MMcf/d phase of facility
planned for Q1 2012
TOWNNORTH
TOWNSOUTH
KOBES
WESTGUNDY
GUNDY
29
Nig – New Pod Development
• Updated graphic• 25 km east of Town
• 50% working interest
• First horizontal 4.2 mmcf/d with 25
bbls/mmcf of liquids
• Three additional horizontals in 2011
Pipeline to McMahon Plant
30
Cost Structure Continuing to Improve
Drill ($MM)
Completion ($MM)
Tie-in ($MM)
Total ($MM)
Q1 2010 2.6 3.9 0.3 6.8
Q3 2010 2.2 3.6 0.3 6.1
Q3 2011 2.2 3.2 0.3 5.7
TARGET 2.1 3.1 0.3 5.5
Potential CostSaving Measures
Cost Savings ($MM)
Drilling Top drive rigs, bit selection 0.2
Completion Toe fracs, fluid optimization 0.2
Completion Flow through plugs 0.3
Completion Open hole packer completion 0.5
313131
Managing Cost Inflation
• Long term relationships with service companies
- Working together through the best and worst times
• Load levelled program
- Maintain an active program
• Continuous improvement
- Detailed tracking of costs and results
• Repeatable model for facilities and well design
- Improvement through repetition
• Developing New Solutions
- Centralized frac water handling
32
Progress North Montney Expertise
• Microseismic
- Over 160 fracs monitored
• 3-D Seismic
- 3,300 square kilometres to date with 650 planned for H1 2012
• Completions practices
- Over 400 fracs
• Facilities Construction
- 15 compressor stations constructed over 10 years
• Water handling
- Setting new standards for the Canadian industry
Monitor Well
~3.2 km
North Well – 5.6 mmcf/d
South Well – 4.0 mmcf/d
Cutting Edge Use of Seismic Information
Utilize 3-D seismic to better position well path
33
3434
Completion Optimization
0.00
1.00
2.00
3.00
4.00
5.00
6.00
0 30 60 90 120
150
180
210
240
270
300
330
360
390
420
450
480
510
540
570
Days
Rat
e (m
mcf
/d)
Town South Single Perf Town South Cluster 5 Bcf Curve 4 Bcf Base Case