corridor resources 2013 agm slides
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AGM 2013MAY 10, 2013
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Highlights - Introduction
Eastern Canadian E&P Companywith enormous upside potential &sustainability
Three high-impact plays at variousstages of maturity
TSX Symbol CDH- 88 million shares outstanding
Focused on de-risking plays,acquiring partners for high-impactprospects & maintainingsustainability as we emerge fromperiod of unusually low gas prices
Corridor is well-positioned:- No Debt- Premium netbacks/cash/workingcapital
- Catalysts for significant upsidepotential
Anticosti900,000 Net Acres
Old Harry250,000 Net Acres
Southern New Brunswick320,000 Net Acres
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Eastern Canada Focused
Large, relatively unexplored areawith significant resource potential
Commanding land position of ~1.5million net acres in Eastern Canada
Licenses for high-impact prospectsrange from approximately 4-8 years
New Brunswick Frederick Brook
shale- 67 TCF gross discovered resources of
shale gas (best estimate)
Anticosti shale prospect has 20 Bboenet undiscovered resources of
petroleum (best estimate); promisingresults from 2012 core program
Corridors Old Harry offshoreprospect is one of the largestidentified geological structuresoffshore NFLD
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2012 Financial Results
$ in thousands 2012 2011
Average gas price (Q4 $5.63/mscf) $4.05 $5.17
Production (mmscfpd) 9.0 11.5
Sales $14,795 $22,993
Net G&A 3,021 4,247
Production expenses 2,982 3,969
Capital expenditures 3,763 8,951
Cash flow from operations 1 4,404 9,250
Net loss2
(47,899) (79,585)Net working capital (cash $8M) 10,237 9,507
Notes: 1 Cash flow from operations is a non-IFRS measure. For a reconciliation to IFRS, see Non-IFRS Financial Measures inCorridors Q1 2013 MD&A
2 includes impairment losses of $56M & $90M relating to the McCully Field
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Q1 2013 Netback
Q1 2013 Q1 2012
Netback($/mscf)
Average gas price $10.19 $4.16
Transportation expense $ 1.23 $1.21
Royalty expense $ 0.65 $0.01
Production expense $ 0.96 $0.88
Netback $ 7.35 $2.06
Production (mmscfpd) 8.5 9.9
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Q1 2013 Financial Results
$ in thousands Q1 2013 Q1 2012
Sales $ 8,114 $ 4,156
Cash flow from operations1 5,261 1,290
Net working capital (cash $12.5M) 15,075 10,055
Net income/(loss) 2,529 (1,654)
Net income/(loss) per share
- Basic and diluted 0.029 (0.019)
Notes: 1 Cash flow from operations is a non-IFRS measure. For a reconciliation to IFRS, see Non-IFRS Financial Measuresin Corridors Q1 2013 MD&A
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2013 Outlook
$ in thousands 2013
Production (mmscfpd) - net 7.7
Netback($/mscf)
Average gas price (2012 actual $4.05/mscf) $ 6.70
Transportation expense 1.24
Royalty expense 0.18
Production expense 1.21Netback (2012 $1.88/mscf) $ 4.07
Sales $18,500
Net G&A 3,000
Cash flow from operations 1 8,300Capital expenditures 3,000
Net working capital 15,500
Note 1 Cash flow from operations is a non-IFRS measure. For a reconciliation to IFRS, see Non -IFRS Financial Measuresin Corridors Q1 2013 MD&A
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2012 Summary
Corridor completed Anticosti core program (with partner), including 3 stratigraphiccoreholes, with positive results indicating TOCs at 4% average
Reduced G&A costs and capital program in 2012 due to low gas prices to ensuresustainability
Corridors netback for Q4 2012 averaged $3.43/mmbtu versus $2.30/mmbtu inQ4 2011 due to higher premiums in New England market
Locked in Q1 2013 sales prices for 2/3 of McCully production at US$8.52/mmbtu
Maintained licenses in New Brunswick, Quebec and offshore NFLD (approximately1.3 million net acres) for Corridors high impact prospects with approximately 4-8years remaining
Corridors proven reserves for McCully of 57.6 BCF (Dec 2012) declined by 2%
(including production). GLJ has assigned a reserve life of over 25 years forCorridors 2P reserves at McCully
Corridor worked extensively with New Brunswick government to promoteadoption of best practices in their review of regulations (N.B. announced new regulationsearly 2013)
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2012 2013
Industry Challenges Corridors Status
Prolonged low N.A. natural gas pricingcycle created by supply overhang
Dry gas resource plays currently morechallenging to farm out
Challenging environmental & socialacceptance issues for oil/gas industry
Eastern Canadian resource plays face highcost and lack of maturity
Junior oil & gas companies undersignificant market pressure
Numerous N.A. J.V. opportunities onmarket for potential partners creating
intensive competition for available capital
Resource plays the size of Corridorsprospects require significant capitalresources and time to mature in order todemonstrate value potential
N.A. Supply/demand more balanced; N.A.pricing improving & higher N.E. premiums
Offset by N.E. premiums & infrastructureadvantages
Industry wide; N.B. Govt indicates localsupport for gas development; industryneeds gas supply in N.B.
Offset by higher netbacks & infrastructureadvantages, growing demand
Corridor has sustainability, no debt andsignificant potential upside
Corridor has sustainability, no debt andmassive high-impact prospects that offer
advantages to potential partners Requires sustainability & retention of
licenses and strategic advantages
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Corridor N.B. Assets Corridors New Brunswick gas assets
connected to M&NP with access topremium N.E. markets and Repsols
LNG facility in N.B. Premium netbacks due to strong basis
differential. Q1 2013 netback averaged$7.35/mmbtu, and premiums for gasin Maritimes & N.E. expected to be
strong for foreseeable future Existing cash flow allows Corridor
sustainability, while sourcing partners
Potential for LNG Export terminal atRepsols Canaport LNG facility optimum East Coast option significant arbitrage potential and10 BCF storage
Potential for LNG export terminal atGoldboro (Pieridae Energy Proposal)
Ability to source additional
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Infrastructure in Place
East Coast
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North East Gas Prices
Anticipate elevated premium to Henry Hub for next several years Anticipate supply short fall for market in Maritimes served by MNP CNG & demand growth in Maritimes pushing up supply shortfall
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Strategic Priorities
Advance our three high impact prospects by sourcing J.V. arrangements
Maintain licenses for Corridors high impact prospects
Continue to mature our prospects within available capital
Maximize cash flow and ensure we optimize value of McCully assets
Evaluate and implement program of additional production at McCully fromboth Hiram Brook and F.B. Shale due to premium prices
Continue to promote export potential for LNG from Atlantic Canadabecause of existing infrastructure and location advantages as well as otheropportunities such as CNG that will promote commercialization of F.B.
Shale
Continue to advance regulatory approvals and social licenses for Corridorprospects in various appropriate jurisdictions
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Over 300,000 net acres in N.B.;high working interests
Frederick Brook shale gas:- 67 TCF gross discovered
resources (best estimate)
Producing up to 12 mmcf/d grossfrom McCully area
- Hiram Brook gas McCully
Field 94.5 BCF 2P grossreserves- ~25 year reserve life index
(GLJ estimate)
Advancing F.B. Shale potentialthrough stimulation programs atMcCully and/or Elgin, 1st half of
2014 Recent N.B. Government
announcements on :- Oil/Gas Environmental
Protection Plan- Supports natural gas
exploration/development in N.B.
McCully/F.B. Shale Exploration
& Development Area
McCully Plant
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Frederick Brook Shale
Highlights
Proven producibility, peaking at12 mmcf/d from Green Roadwell
Up to 600 bcf potentialresources of shale gas persection (TerraTek analysis)
Up to 1100 m in grossthickness
Upside in overlying sands
Connected to M&NP & LNG
Terminal premium marketpotential for export
Next stage includes pilot plantdevelopment at Elgin ~$150MM
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AnticostiMacasty Liquids-Rich Shale Highlights
Over 1.5 millioncontinuous gross acreslicensed
Large areas of the Islandwithin the liquids window
Schlumberger
petrophysics estimates80% Soil and 6% effectiveporosity
Depth 2300 6500 feet
34 billion bboe grossundiscovered resources ofpetroleum (best estimate)
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AnticostiMacasty Shale Oil Large UntestedLiquids
Thickness of MacastyShale ranged from 31 to92 metres on 3 coreholes
drilled in 2012 program
Coreholes show 4%average TOC
Additional analysis
expected soon (rockparameters & maturation studies)
Similar to Ohio Utica shale
Quebec Govt indicatessupport for oil exploration/development on Anticosti
Next stage includes:- Appraisal program to
demonstrate oil/gasproduction - $50+ MM
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Old Harry Highlights One of the largest undrilled geological
structures in Eastern Canada (43,000acres/67 sq miles) under simple four-way
closure
Several direct hydrocarbon indicatorsidentified: satellite seepage slicks,frequency anomalies, amplitude
anomalies, and AVO anomalies Over 1,000 km of modern 2-D seismic
available
Structures aerial extent and potentialreservoir thickness presents huge
opportunity for billion barrel oil ormulti TCF gas discovery
Basin Modeling indicates light oil (~55API) was initially generated and couldbe filling the structure
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Old Harry Prospect Highlights
Potential for good primaryreservoir in Bradelle Formation
Very thick secondary reservoir,Brion Island Formation
Thick light-oil source rock
NFLD exploration well targetedfor 2015/2016, pendingapprovals
Corridor has identified drilling
assets available in the 2015-2016 window
20Miles
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Old Harry Regulatory Summary Corridor submitted its Old Harry Exploratory
Drilling Project Description and Environmental
Assessment (E.A.) to the C-NLOPB in February2011
C-NLOPB eventually (with Federal Environment
Ministers recommendation) decided that a Strategic
Environmental Assessment (SEA) for NFLD side ofGulf was required; expected to be completed 2nd
Qtr 2013
Corridors E.A. and drilling permits now expectedto be completed in late 2013
Due to lengthy regulatory processes, Corridor wasgranted extension of drilling window (Phase I oflicence) to Jan 2016
The Quebec and Federal Governments signed anaccord in Mar 2011 to jointly regulate the offshoreon Quebecs side of the Gulf
Quebec has completed SEA and is expected to
decide on opening sections of Quebec side of theGulf for oil and gas activities in 2014 20
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