corporate presentation - crew energy · 2015-02-06 · degree of certainty in resource assessments;...
TRANSCRIPT
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CORPORATE
PRESENTATION
February, 2015
SHARPENING OUR FOCUS
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Forward Looking Statements
This presentation contains certain forward–looking information and statements within the meaning of applicable securities laws. The use of any of the words "expect", "anticipate", "continue", "estimate", "may", "will",
"project", "should", "believe", "plans", "intends“, “forecast” and similar expressions are intended to identify forward-looking information or statements. In particular, but without limiting the forgoing, this presentation
contains forward-looking information and statements pertaining to the following: the volumes and estimated value of Crew's oil and gas reserves; resource estimates and volumes in respect of Crew’s Montney lands in
N.E.B.C.; the volume and product mix of Crew's oil and gas production; production estimates including 2014 forecast average and exit productions; the recognition of significant resources in the Montney region of
northeast British Columbia; future oil and natural gas prices and Crew's commodity risk management programs; future liquidity and financial capacity; future results from operations and operating metrics; future costs,
expenses and royalty rates; future interest costs; the exchange rate between the $US and $Cdn; future development, exploration, acquisition and development activities and related capital expenditures and the timing
thereof; the amount and timing of capital projects; operating costs; the total future capital associated with development of reserves and resources; methods of funding our capital program including possible non-core asset
divestitures; and forecast reductions in operating expenses. In this presentation reference is made to the Company's long range Montney growth scenario. All information derived therefrom are not estimates or forecasts
of metrics that may actually be achieved. Such information reflects internal projections used by management for the purposes of making capital investment decisions and for internal long range planning and budget
preparation. Accordingly, undue reliance should not be placed on same.
The recovery, reserve and resources estimates of Crew's reserves and resources provided herein are estimates only and there is no guarantee that the estimated reserves or resources with be recovered. In addition,
forward-looking statements or information are based on a number of material factors, expectations or assumptions of Crew which have been used to develop such statements and information but which may prove to be
incorrect. Although Crew believes that the expectations reflected in such forward-looking statements or information are reasonable, undue reliance should not be placed on forward-looking statements because Crew can
give no assurance that such expectations will prove to be correct. In addition to other factors and assumptions which may be identified herein, assumptions have been made regarding, among other things: the impact of
increasing competition; the general stability of the economic and political environment in which Crew operates; the timely receipt of any required regulatory approvals; the ability of Crew to obtain qualified staff, equipment
and services in a timely and cost efficient manner; drilling results; the ability of the operator of the projects in which Crew has an interest in to operate the field in a safe, efficient and effective manner; the ability of Crew to
obtain financing on acceptable terms; field production rates and decline rates; the ability to replace and expand oil and natural gas reserves through acquisition, development and exploration; risks associated with the
degree of certainty in resource assessments; the timing and cost of pipeline, storage and facility construction and expansion and the ability of Crew to secure adequate product transportation; future commodity prices;
currency, exchange and interest rates; regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which Crew operates; and the ability of Crew to successfully market its oil and
natural gas products. There are a number of assumptions associated with the potential of resource volumes assigned to the Evaluated Areas in Crew's Montney area of operations in northeast British Columbia, including
the quality of the Montney reservoir, future drilling programs and the funding thereof, continued performance from existing wells and performance of new wells, the growth of infrastructure, well density per section and
recovery factors and discovery and development of the Evaluated Areas necessarily involves known and unknown risks and uncertainties, including those identified in this presentation and including the business risks
discussed in Crew's annual and quarterly MD&A and other continuous disclosure documents. The forward-looking information and statements included in this presentation are not guarantees of future performance and should not be unduly relied upon. Such information and statements; including the assumptions made in respect thereof, involve known and unknown risks, uncertainties and other factors that may cause actual results or events to defer materially from those anticipated in such forward-looking information or statements including, without limitation: changes in commodity prices; the potential for variation in the quality of the Montney formation; changes in the demand for or supply of Crew's products; unanticipated operating results or production declines; changes in tax or environmental laws, royalty rates or other regulatory matters; changes in development plans of Crew or by third party operators of Crew's properties, increased debt levels or debt service requirements; inaccurate estimation of Crew's oil and gas reserve and resource volumes; limited, unfavourable or a lack of access to capital markets; increased costs; a lack of inadequate insurance coverage; the impact of competitors; and certain other risks detailed from time-to-time in Crew's public disclosure documents, (including, without limitation, those risks identified in this presentation and Crew's Annual Information Form). The forward-looking information and statements contained in this presentation speak only as of the date of this presentation, and Crew does not assume any obligation to publicly update or revise any of the included forward-looking statements or information, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.
CAUTIONARY STATEMENT
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MONTNEY FOCUS LONG-TERM GROWTH
• Exposure to world-class
Montney resource (109 TCFE)
• Large, contiguous land base
(487 net sections) with light oil,
liquids-rich natural gas & dry
gas
• Multiple egress options
• Strong balance sheet and 2015
hedge position lends financial
flexibility to support ongoing
development
• Massive resource in early
stages of development (0.6 TCFE 2P reserves booked)
• 5 TCFE best estimate
contingent resource with
NPV101 of $3.518 Billion
• Technology enhancements
continuously improve
production rates, recoverable
reserves & returns
INVESTMENT HIGHLIGHTS
1April 30, 2014
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Estimated as at, or for the year ended Dec 31, 2014 TSX:CR
TSX trading symbol CR
Basic shares outstanding (mm) 123.4
Trading range (52 week) $4.84 - $12.74
Average daily trading volume (m) 1,153
Market capitalization @ $5.90/sh (mm) $728
Enterprise value (mm) $978
Net debt (mm) $250
Total debt capacity (mm) $430
Employee/Director ownership – diluted 9%
CORPORATE SNAPSHOT
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Montney (Core focus)
Resource play with long-term
growth potential
Lloydminster Heavy Oil
Low maintenance capex
generates free cash flow to
support Montney development
Montney
Lloydminster
Oil / Liquids rich
natural gas / dry gas
Heavy Oil
Edmonton
Calgary
Fort St. John
FOCUSED OPERATIONS
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2015 CAPITAL BUDGET HIGHLIGHTS
$185MM – MAINTAIN BALANCE SHEET STRENGTH
WITH MONTNEY GROWTH
• Commission West Septimus facility mid-year; on-stream in Q3
• Install necessary infrastructure at Septimus to replace trucking of
condensate; adds $4 per bbl to the netback
• Complete & tie-in 12 wells at W. Septimus
• Tie-in 2 wells at Groundbirch and 1 at Attachie
• Drill and complete 8 new pad wells at Septimus
• Drill 2 new wells & complete 4 wells at Tower
• 2015 Q4 average volumes forecast at >13% increase over 2014 Q4 average
− ‘15 exit: 24,000–25,000 boe/d; ‘15 annual avg: 20,000–22,000 boe/d
− Attractive capital efficiencies of ~$20,000 per flowing boe; a result of significant infrastructure and drilling capex in 2014
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BALANCE SHEET STRENGTH
• Borrowing capacity: $430MM
$150MM high yield bond termed out to Oct. 2020
Covenant light with no material financial covenants
$280MM revolving facility, ~$180MM available capacity at year end 2014
Borrowing base review and renewal in spring 2015 to be completed prior to June 8, 2015
Financial covenants; debt to EBITDA of 4:1 or less (1.0:1 – Sept. 30, 2014), secured debt to EBITDA of 3:1 or less
(0.0:1 – Sept. 30, 2014)
• Strong hedge position through 2015 reduces volatility and supports cash flows
Budgeted volumes hedged: 39% natural gas (C$3.92/mcf) and 27% oil (C$103/bbl)
• 2015 Budget structured to manage and preserve the balance sheet and provide
development and growth in our Montney resource
Financial Flexibility
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FIRST HALF 2015 OPERATIONAL FOCUS
Optimize Capital Efficiencies and Control Costs
• Drill wellbores with improved costs; build inventory of wells that can be
completed & tied-in when economics warrant
• Meaningful cost reduction initiatives underway:
Installation of LACT (Lease Automatic Custody Transfer) unit at Septimus to reduce trucking and
increase netbacks by ~$4/bbl
Consolidate well testing to reduce the number of testers
Stagger fraccing and flowback on pad drills to reduce water usage and trucking costs
Enhanced frac port location and frac design to optimize productivity / returns
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World-Class
Montney Resource
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Montney and US shale play comparables – Key attributes
Source: RBC Rundle, Company Reports, NEB, U.S. Department of Energy and RBC Capital Markets
• Exceptionally thick: up to 1,000 feet
• Permeability 20-80 times greater than
comparable resource plays in North America
• Excellent fracability
• Lowest Royalty regime in North America
“Not a shale: It’s a siltstone” Montney Competitive Attributes:
NEBC MONTNEY: A GLOBALLY COMPETITIVE PLAY
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0
1
2
3
4
5
6
0%
10%
20%
30%
40%
50%
60%
70% BTax IRR IP 30 (mmcf/d)
Crew’s 487 sections of land are situated in
the ‘sweet spot’ of the play (Area 4)
Highest IRR & IP30 MONTNEY SUB-GROUP REGIONS
1 Altares/Caribou/Farrell/Kobes/Town/
Lily
2 Groundbirch/Sundown/Swan /Tupper
3 Dawson/Monias/Saturn/Sunrise/
Sunset
4 Parkland/ Septimus/ Tower
5 Glacier/Pouce Coupe
6 Elmworth/Gold Creek/Wapiti
7 Kakwa/Karr/Resthaven/Simonette
8 Bigstone/Fir/Kaybob
at Parkland / Septimus / Tower1
IRR
– B
TA
X
IP 3
0 r
ate
s (
mm
cf/d)
Parkland /
Septimus /
Tower
Kakwa /
Karr /
Resthaven/
Simonette
Elmworth/
Gold Creek/
Wapiti
Dawson/
Monias/
Saturn/
Sunrise/
Sunset
Bigstone/
Fir/
Kaybob
Groundbirch/
Sundown/
Swan/
Tupper
Altares/
Caribou/
Farrell/
Kobes/
Town/ Lily
Glacier/
Pouce Coupe
Source: AccuMap and RBC Capital Markets, Aug. 2014
1See Appendix for detailed comparative of Montney sub-group areas (page 33)
SEPTIMUS: SWEET SPOT OF THE MONTNEY
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Montney (2007) Montney (2010) Montney (2015)
Sharpens Focus
CREW ACREAGE BREAKDOWN:
Oil Sections: 138
Wet Gas Sections: 239
Dry Gas Sections: 110
Total Sections: 487
GROWING MONTNEY ACREAGE
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0
2,000
4,000
6,000
8,000
10,000
12,000
2009 2010 2011 2012 2013 2014
Light oil bopd NGLs boepd
Gas boepd
Montney Resource Estimate
33.7
60.6
42.0
48.3
0
20
40
60
80
100
120
2013 2014
-
20.0
40.0
60.0
80.0
100.0
120.0
2008 2009 2010 2011 2012 2013
Liquids mmbblsGas mboe
P+P Montney Reserves Growth (MMBOE)
109 TCFE
76 TCFE
99.2
48.1 46.7
27.7 21.6
15.3
Growth in Resource & Reserves
Liquids tcfe
Gas tcf
Montney Area Production Growth (BOE/D)
Forecast
SUCCESSFUL EXECUTION
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Crew 2014 Drilled Unbooked Location
Sproule 2013 Yearend Booked Reserve Lands
Crew Montney Gas Tests
Tower
Goose
Attachie
Portage
Groundbirch
Flatrock
Septimus
MONTNEY RESERVES: EARLY STAGES –
92% UNDEVELOPED
Crew Montney Rights
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ABUNDANT AND
GROWING
INFRASTRUCTURE
• Acreage is optimally situated to
feed potential long term demand
• Multiple egress options diversify
markets and mitigate risk
• Three pipeline options running
West, East and South to reach
Canadian, US and international
markets
• Crew has negotiated 200 mmcf/d
of long term takeaway capacity
Source: RBC Capital Markets, TD Securities, NEB and CEPA
AECO Gas
Storage Hub
Spectra P/L
TCPL Nova P/L
Pacific Northern Gas P/L
Alliance P/L
Spectra Gas Plant
Septimus Gas Plant
Crew’s Montney Lands
DELIVERY OPTIONS TCPL
Spectra
Alliance
PROPOSED
INFRASTRUCTURE
LNG P/L
North Montney Mainline
LNG Port
To Eastern CND
& NE US
GTN
Kingsgate Export
Point to US
Kingsvale
Proposed
Canadian LNG
Ports
Ruby
Crew Montney
Lands
Jordan Cove
LNG
Opal
Huntington/
Sumas Export
Point to US
STN 2
Malin Hub
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• >300,000 acres of Montney rights close to numerous gas plant
and pipeline options
Tower
Goose
Attachie
Portage
Septimus Groundbirch
Flatrock
Planned West Septimus Gas Plant Q3/15
Crew Operated Septimus Gas Plant
Crew Montney Rights
Crew Operated Pipeline
Proposed North Montney Mainline Project
Alliance Operated Pipeline
Spectra Westcoast Pipelines
Spectra McMahon Gas Plant
Planned Groundbirch Gas Plant Q3/16
Multiple infrastructure options
and growing processing capacity
ACREAGE PROXIMAL TO INFRASTRUCTURE
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West Portage Attachie Goose Groundbirch West Septimus Septimus Tower
Monias High
50
0 F
ee
t
AA
A
C
B
Up
pe
r M
on
tne
y
Lo
we
r M
on
tne
y
Belloy
Doig
• Crew recognizes four major clinoform units in the Upper Montney (AA, A, B, C)
• The majority of Crew horizontals (65%) have been drilled in the “B” clinoform
• The “Lower B” and “C” clinoforms are still basically undrilled
• The Lower Montney unit also has excellent prospectivity, especially at Tower and Attachie
2
1
1
2
3
11
19
36
2
1
2
7
# of Crew wells drilled to date
CREW MONTNEY “STRATIGRAPHIC STACK”
1
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• Active drilling and development
program
• Adoption of new technology
• Existing 60 mmcf/d gas plant
currently at capacity from area
production
• Long-range plan features
180 mmcf/d capacity in the area
• Superior returns
Initial Montney Development Area
57 wells drilled to date
SEPTIMUS
Crew Septimus plant 60 mmcf/d capacity
Crew Operated Pipeline Spectra Westcoast Pipelines
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0
500
1,000
1,500
2,000
2,500
0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 45.0
Cu
mu
lative
Ga
s P
rod
uctio
n (
mm
cf)
Months on Production
Septimus Type Wells
Q4 2013 Onward Frac Port Avg (8 wells) 2013 2P Avg Booking (4.3 Bcf EUR)
Frac Port Forecast (4.6 Bcf EUR) 2012 2P Avg Booking (3.2 Bcf EUR)
2012 to Present Frac Port Average (18 Wells) 2011 2P Avg Booking (2.8 Bcf EUR)
1On 239 sections in Upper Montney liquids rich window
SEPTIMUS: EXCELLENT RETURNS &
IMPROVING EURs
• Attractive well economics at current commodity
price levels – continued development planned
through 2015
• Positive results in Septimus to date support
expansion into other areas of the Montney:
West Septimus, Tower & Groundbirch
• Improved efficiencies have lead to 1 BCF of
production in one year versus three years in
2011
4.3 bcf EUR per well
>500 boe/d IP365
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• Step-out area - Montney expansion
• Over pressured area with proven
liquids-rich gas
− Up to 220 bbls condensate / mmcf provides
strong economics
• Building 60 mmcf/d plant with start-up
expected Q3 ‘15
− Existing and future pad drills will supply production
to new plant
• Full 3D seismic coverage
Continuation of Septimus Trend
0.00
0.01
0.10
1.00
0% 1% 2% 3% 4% 5% 6% 7% 8% 9% 10%
Pe
rme
ab
ilit
y (
mD
)
Porosity 102/07-05-082-19W6/0 100/08-22-082-20W6/0
Greater porosity, permeability
and liquids than Septimus
Core sample data from Septimus 102/07-05-082-19W6 and 100/ 08-22-082-20W6
Site of planned West Septimus
60 mmcf/d capacity plant – Q3 ’15 expected completion
02/7-5
00/8-22
WEST SEPTIMUS
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• First of several light oil weighted areas in
Crew’s portfolio to be developed
• 4 recently drilled wells brought on
production in early Q4 ‘14 at ~3,975 boe/d
(67% liquids)
• Light oil/condensate support higher
netbacks
• Significant future upside; end of 2013
only 5 wells booked at 160 mboe / well
Crew 1-24 (2014) 13 day test: 861 boepd (71% oil)
51 net sections Emerging Montney Light Oil Play
Recently drilled wells
Crew B9-30 (2014) 25 day test: 695 boepd (63% oil)
TOWER
Crew 5,000 bopd oil facility
Phase 1 Q4/2014 operational
Crew Septimus
facility
Q4/14 wells
Near to mid-term growth potential
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12-15 wells / section drilling plan
90
m
45
m
1600 m
200 m
TOWER
• Able to benefit from industry experience to
optimize efficiencies
• Adoption of new technology will reduce
costs + enhance performance
• Tighter spacing using pad drilling
enhances efficiencies, lowers costs and
reduces environmental footprint
• 2015 first half – drill wellbores to build
inventory of wells that can be quickly
completed as prices recover
Light Oil/Condensate Support
Higher Netbacks
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Montney Next Steps:
Future Growth
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Delineation Area with Long-Term
Upside
• Offsetting vertical + horizontal development
• Over-pressured with liquids-rich natural gas
• Large pay thickness (500 ft. – Upper
Montney)
• Drilled 2 wells that tested at 3.5 and 4.5
mmcf/d with confirmed bottom-hole
pressures of >4,000 psi (1.5x normal
pressure)
• Next step is 3D seismic shoot
Planned gas plant and
pipeline infrastructure
supports area growth
NEXT STEPS: GROUNDBIRCH
Site of planned Groundbirch 60 mmcf/d plant (2016)
Proposed North Montney Mainline
Crew 2-4 Pad - recent wells drilled
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Proof of Concept Stage
• Several prolific offsetting producers in
Upper and Lower Montney
• Over-pressured with liquids-rich natural
gas
• Large pay thickness (500 ft. – Upper
Montney)
• Crew 10-22 well tested at 10.5 mmcf/d @ 1,230 psi FCP (after 4 days flow)
• Crew 15-36 well tested at 7.9 mmcf/d @ 1,250 psi FCP (after 2.5 days flow)
Excellent test rates from
initial wells
NEXT STEPS: ATTACHIE
Crew 10-22 well
Crew 15-36 well
Recently drilled wells
Proposed North Montney Mainline
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• Technology advancements lead to enhanced recovery factors
and lower costs over time
• Unique access to infrastructure – able to reach multiple
potential markets
• Opportunity to feed potential LNG demand longer-term
TPIIP =
109 TCFE
Achieving our 5 year plan requires
‘…A DROP IN THE BUCKET’
5.0 TCFE Contingent Resource Remaining2
0.6 TCFE 2P Reserves Currently Booked
1 Includes 86 locations booked as 2P Undeveloped 2 Based on Sproule April 30, 2014 resource reports with 5.0 TCFE Contingent Resource
<1% of TPIIP (~1 TCFE) be produced (241 locations1);
SIGNIFICANT MONTNEY RESOURCE UPSIDE
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Lloydminster Heavy Oil
Low-Risk Funding Source
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• Current production 5,000-5,500
boe/d
• Low capex and strong capital
efficiencies drive stable production
• 97,219 net acres of land in the area;
average working interest of 94%
• 2015 capital program to focus on
low-cost work-overs and
recompletions which optimize
production efficiencies
LLOYDMINSTER HEAVY OIL
ALBERTA SASKATCHEWAN
SWIMMING
BRIGHTSAND
WILDMERE
LLOYD
Lloydminster
LOW LAKE
LASHBURN
NEILBURG
BALDWINTON
UNWIN/EPPING VIKING/ KINSELLA
FOREST
BANK
UNITY
Crew 100% W.I. Dulwich
Heavy Oil Facility
Lloydminster
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MONTNEY FOCUS • Large, high-quality Montney land base with growing infrastructure;
flexibility in capital allocation
• Access to multiple markets, growing egress and potential to feed long-
term demand
• Emerging light oil play at Tower, one of several light oil areas
• Estimated 109 TCFE TPIIP Resource offers significant long-term
growth potential
UNIQUE INVESTMENT OPPORTUNITY
POSITIONED FOR SUCCESS • Adoption of evolving technologies increases EURs, IP’s and rates of
return while reducing costs
• Financial flexibility provided by $150MM high yield bond due 2020 and
$280MM revolving facility, ~$180MM available capacity at end of 2014
• Strong hedge position through 2015 supports cash flows
• >13% increase in volumes forecast for Q4 2014 to Q4 2015
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Contact Info: Suite 800, 250 - 5th Street SW
Calgary, Alberta T2P 0R4
Telephone: (403) 266-2088
Email: [email protected]
Dale O. Shwed, President & CEO
John G. Leach, Senior Vice President & CFO
Rob J. Morgan, Senior Vice President & COO
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APPENDIX
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0%
10%
20%
30%
40%
50%
60%
70%Illustrative half cycle economics of Montney and US gas/liquids plays
IRR
– H
alf C
ycle
Montney half-cycle per-well economics are strong and comparable to many key US shale plays even
when including prevailing FX / basis
COMPARATIVE: MONTNEY VS OTHER NORTH
AMERICAN RESOURCE PLAYS – ECONOMICS
Note: Assumes US$4.00/mcf for US gas plays, $0.92 $US/$CDN, US $0.35/mmbtu AECO basis, CDN $4.00/mcf for Montney gas plays, $100 WTI
Source: RBC Capital Markets estimates
Areas in which Crew has acreage
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Fields
Capex/ well
(mm)
IP 30
(mmcf/d)
Recovery
(bcfe)
Liquids Yield
(bbl/mmcf)
BTax IRR
BTax NPV
8.5% (mm)
Area 4 Parkland, Septimus, Tower $5.3 5.0 7.6 30 63% $8.5
Area 7 Kakwa, Karr, Resthaven, Simonette $9.5 5.0 8.6 110 54% $13.9
Area 6 Elmworth, Gold Creek, Wapiti $8.8 4.9 8.6 60 49% $12.0
Area 3 Dawson, Monias, Saturn, Sunrise, Sunset $5.0 4.5 9.1 6 43% $6.2
Area 8 Bigstone, Fir, Kaybob $5.0 5.0 4.0 30 37% $4.4
Area 2 Groundbirch, Sundown, Swan, Tupper $5.3 5.0 7.3 6 33% $4.3
Area 1 Altares, Caribou, Farrell, Kobes, Town, Lily $6.5 4.0 6.3 20 31% $4.9
Area 5 Glacier, Pouce Coupe $5.3 3.5 5.4 14 27% $3.9
Source: Company Reports and RBC Capital Markets estimates, Aug. 2014 ($100/bbl and $4.00/mcf)
Montney Well Economics by Area
SEPTIMUS MONTNEY: SWEET SPOT OF THE
BASIN EQUALS LEADING ECONOMICS
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2015 Hedging Summary
Volume Period Derivative Reference Price
Natural Gas
33,781 GJ/Day 2015 Swap AECO $3.71/GJ
$3.92/mcf
Oil
2,122 bopd 2015 Swap C$WTI $102.82
2,000 bopd 2015 Swap C$WCS-WTI -$21.59
2015 CAPITAL PROGRAM AND BUDGET
Forecast: Fiscal 2015
Average daily production (boe per day) 20,000 – 22,000
Exit production (boe per day) 24,000 – 25,000
Capital expenditures ($millions) 185
Total debt capacity ($millions) 430
High yield debt (2020 maturity) ($millions) 150
Bank credit facility borrowing limit ($millions) 280
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Natural Gas Resource Categories (1)(2)(3) Tcf
Total Petroleum Initially In Place (TPIIP)
Discovered Petroleum Initially In Place (DPIIP)
Undiscovered Petroleum Initially In Place (UPIIP)
60.6
26.1
34.5
(1) All volumes in table are company gross and raw gas volumes.
(2) Sproule’s analysis identified four intervals in the Montney consisting of one interval in the Upper Montney
and three intervals in the Lower Montney.
(3) Crew’s acreage was divided into six (6) areas in the “gas window”. Crew owns 276 net sections in the gas
window at April 30, 2014.
Oil Resource Categories (1)(2)(3)(4) Mmbbls
Total Petroleum Initially In Place (TPIIP)
Discovered Petroleum Initially In Place (DPIIP)
Undiscovered Petroleum Initially In Place (UPIIP)
8,052
1,363
6,689
(1) All volumes in table are company gross.
(2) The oil volumes are quoted as Stock Tank Barrels (“STB”).
(3) Sproule’s analysis identified four intervals in the Montney consisting of one interval in the Upper Montney
and three intervals in the Lower Montney.
(4) Crew’s acreage was divided into five (5) areas in the “oil window”. Crew owns 138 net sections in the oil
window at April 30, 2014
Reserves and Contingent Resources (1)(2)(3)(6)(7) Best Estimate
Natural Gas (Tcf)
Reserves (3)
Contingent Resources
0.5
4.0
Natural Gas Liquids (mmbbls) (4)(5)
Reserves (3)
Contingent Resources
14.7
160.7
Oil (mmbbls)
Reserves (3)
Contingent Resources
0.4
10.9
(1) All DPIIP other than cumulative production, reserves, and Contingent Resources has been categorized as unrecoverable at
this time.
(2) All volumes in table are company gross and sales volumes.
(3) For reserves, the volume under the heading Best Estimate are proved plus probable reserves as at December 31, 2013.
(4) The liquid yields are based on average yield over the producing life of the property.
(5) Liquid yields are unique to each area. They are estimated based on gas composition of gas samples in the area and
expected plant recoveries.
(6) There is no certainty that it will be commercially viable to produce an of the resources.
(7) Contingent Resources includes 85% development factor.
Prospective Resources (1)(2)(5)(6) Best Estimate
Natural gas (Tcf)
Natural gas liquids (mmbbls)
Oil (mmbbls)
6.3
254.4
14.4
(1) All UPIIP other than Prospective Resources has been categorized as unrecoverable at this time.
(2) All volumes in table are company gross and sales volumes.
(3) The liquid yields are based on average yield over the producing life of the property.
(4) Liquid yields are unique to each area. They are estimated based on gas composition of gas samples in the area and
expected plan recoveries.
(5) There is no certainty that it will be commercially viable to produce an of the resources.
(6) Prospective Resources includes an 85% development factor.
NE BC MONTNEY RESOURCE EVALUATION
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Reserves are estimated remaining quantities of oil and natural gas and related substances anticipated to be recoverable from known accumulations, as of a given date, based on the analysis of drilling, geological,
geophysical and engineering data; the use of established technology; and specified economic conditions, which are generally accepted as being reasonable. Reserves are classified according to the degree of
certainty associated with the estimates as follows:
• Proved Reserves are those reserves that can be estimated with a high degree of certainty to be recoverable. It is likely that the actual remaining quantities recovered will exceed the estimated proved
reserves.
• Probable Reserves are those additional reserves that are less certain to be recovered than proved reserves. It is equally likely that the actual remaining quantities recovered will be greater or less than the
sum of the estimated proved plus probable reserves.
• Possible Reserves are those additional reserves that are less certain to be recovered than probable reserves. It is unlikely that the actual remaining quantities recovered will exceed the sum of the estimated
proved plus probable plus possible reserves.
Cumulative Production is the cumulative quantity of petroleum that has been recovered at a given date.
Resources encompasses all petroleum quantities that originally existed on or within the earth's crust in naturally occurring accumulations, including Discovered and Undiscovered (recoverable and unrecoverable)
plus quantities already produced. "Total resources" is equivalent to "Total Petroleum Initially-In-Place". Resources are classified in the following categories:
• Total Petroleum Initially-In-Place ("TPIIP") is that quantity of petroleum that is estimated to exist originally in naturally occurring accumulations. It includes that quantity of petroleum that is estimated, as of a
given date, to be contained in known accumulations, prior to production, plus those estimated quantities in accumulations yet to be discovered.
• Discovered Petroleum Initially-In-Place ("DPIIP") is that quantity of petroleum that is estimated, as of a given date, to be contained in known accumulations prior to production. The recoverable portion of
discovered petroleum initially in place includes production, reserves, and contingent resources; the remainder is unrecoverable.
• Contingent Resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from known accumulations using established technology or technology under development
but which are not currently considered to be commercially recoverable due to one or more contingencies. Contingencies may include such factors as economic, legal, environmental, political and regulatory
matters or a lack of markets. It is also appropriate to classify as Contingent Resources the estimated discovered recoverable quantities associated with a project in the early evaluation stage.
• Undiscovered Petroleum Initially-In-Place ("UPIIP") is that quantity of petroleum that is estimated, on a given date, to be contained in accumulations yet to be discovered. The recoverable portion of
undiscovered petroleum initially in place is referred to as "prospective resources" and the remainder as "unrecoverable."
• Prospective Resources are those quantities of petroleum estimated, as of a given date, to be potentially recoverable from undiscovered accumulations by application of future development projects.
Prospective resources have both an associated chance of discovery and a chance of development.
• Unrecoverable is that portion of DPIIP and UPIIP quantities which is estimated, as of a given date, not to be recoverable by future development projects. A portion of these quantities may become recoverable
in the future as commercial circumstances change or technological developments occur; the remaining portion may never be recovered due to the physical/chemical constraints represented by subsurface
interaction of fluids and reservoir rocks.
• Uncertainty Ranges are described by the Canadian Oil and Gas Evaluation Handbook as low, best, and high estimates for reserves and resources. The Best Estimate is considered to be the best estimate of
the quantity that will actually be recovered. It is equally likely that the actual remaining quantities recovered will be greater or less than the best estimate. If probabilistic methods are used, there should be at
least a 50 percent probability (P50) that the quantities actually recovered will equal or exceed the best estimate.
• BOE equivalent Barrel of oil equivalents or BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different than the energy equivalency of the 6:1 conversion ratio, utilizing the 6:1 conversion ratio may be misleading as an indication of value.
• Test Results and Initial Production Rates a pressure transient analysis or well test interpretation has not been carried out thus certain of the test results provided herein should be considered to be
preliminary until such analysis or interpretation has been completed. Test results and initial production rates disclosed in this presentation may not be necessarily indicative of long-term performance or of
ultimate recovery.
DEFINITIONS OF OIL & GAS RESOURCES AND
RESERVES
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All amounts in this presentation are stated in Canadian dollars unless otherwise specified. Throughout the presentation, the terms Boe (barrels of oil equivalent), Mmboe (millions of barrels of oil equivalent), and
Tcfe (trillion cubic feet of gas equivalent) are used. Such terms when used in isolation, may be misleading. Where applicable, natural gas has been converted to barrels of oil equivalent ("BOE") based on 6 Mcf:1
BOE and oil and liquids have been converted to natural gas equivalent on the basis of 1 bbl:6 mcfe. The BOE rate is based on an energy equivalent conversion method primarily applicable at the burner tip, and
given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different than the energy equivalency of the 6:1 conversion ratio, utilizing the 6:1 conversion ratio may be
misleading as an indication of value. The BOE rate is based on an energy equivalent conversion method primarily applicable at the burner tip and does not represent a value equivalent at the wellhead. In
accordance with Canadian practice, production volumes and revenues are reported on a company gross basis, before deduction of Crown and other royalties, unless otherwise stated. Unless otherwise specified, all
reserves volumes in this news release (and all information derived therefrom) are based on "company gross reserves" using forecast prices and costs. Our oil and gas reserves statement for the year-ended
December 31, 2013 includes complete disclosure of our oil and gas reserves and other oil and gas information in accordance with NI 51-101, and is contained within our Annual Information Form which is available
on our SEDAR profile at www.sedar.com.
This presentation contains references to estimates of proved plus probable reserves attributed to the assets acquired by the Company pursuant to the Montney Acquisition. Such reserves reflect Company internally
estimated "gross" reserves prepared by a qualified reserves evaluator effective December 31, 2013 in accordance with the definitions and provisions contained in the COGE Handbook. Estimates of proved plus
probable reserves contained herein attributed to the assets being disposed of pursuant to the Alberta Gas Disposition reflect "gross" reserves assigned by the Company's independent reserves evaluator, Sproule
Associates Limited, effective December 31, 2013.
This presentation contains reference to Crew's updated independent Montney resource evaluation prepared by Sproule Associates Limited effective as of April 30, 2014, prepared in accordance with the Canadian oil and gas evaluation handbook (the "Montney Resource Evaluation"). Sproule was engaged to conduct an updated independent Montney Resource Evaluation of Crew's 452 net Montney sections located in northeast British Columbia (the "Evaluated Areas"). This presentation contains references to estimates of oil and gas classified as TPIIP, DPIIP, UPIIP, Contingent Resources and Prospective Resources in the Montney region in northeastern British Columbia which are not, and should not be confused with, oil and gas reserves. See "Definitions of Oil and Gas Resources and Reserves". TPIIP, DPIIP and UPIIP have been estimated using a zero percent porosity cutoff. The Prospective Resources have not been risked for chance of discovery. There is no certainty that any portion of the Prospective Resources will be discovered. There is no certainty that it will be commercially viable to produce any portion of the Prospective (if discovered) or Contingent Resources. The Contingent Resource contingencies are identified as economic or non-technical; there are no technical contingencies. It should not be assumed that the estimate of net present value associated with the Contingent Resources disclosed in this presentation represents fair market value. Such estimate is based on certain assumptions and there are no assurances that such assumptions including forecast prices and costs, will be attained and variances could be material. Significant positive factors are historical drilling success and production history on the more fully developed Montney acreage, abundant well log and production test data. Potential negative factors include lack of long-term production history over the majority of the Evaluated Areas, lack of infrastructure, potential for variations in the quality of the Montney formation where minimal well data currently exists, access to the substantial amount of capital which would be required to develop the resources, low commodity prices that would curtail the economics of development and the future performance of wells, regulatory approvals, access to the required services at the appropriate cost and topographic or service restrictions.
Projects have not been defined to develop the resources in the Evaluated Areas as at the evaluation date. Such projects, in the case of the Montney resource development, have historically been developed sequentially
over a number of drilling seasons and are subject to annual budget constraints, Crew's policy of orderly development on a staged basis, the timing of the growth of third party infrastructure, the short and long-term
view of Crew on gas prices, the results of exploration and development activities of Crew and others in the area and possible infrastructure capacity constraints. As with any resource estimates, the evaluation will
change over time as new information becomes available.
Crew's belief that it will establish significant additional reserves over time with the conversion of Prospective Resource into Contingent Resource, Contingent Resource into probable reserves and probable reserves
into proved reserves is a forward looking statement and is based on certain assumptions and is subject to certain risks, as discussed below under the heading "Forward Looking Information and Statements".
INFORMATION ON RESERVES, RESOURCES
AND OPERATIONAL INFORMATION