Tangle Creek Corporate May 2018 FORWARD-LOOKING STATEMENTS This - - PowerPoint PPT Presentation

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Tangle Creek Corporate May 2018 FORWARD-LOOKING STATEMENTS This - - PowerPoint PPT Presentation

Tangle Creek Corporate May 2018 FORWARD-LOOKING STATEMENTS This presentation contains forward-looking statements. More particularly, this presentation contains statements concerning anticipated: business strategies, plans and objectives;


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Tangle Creek Corporate

May 2018

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SLIDE 2

FORWARD-LOOKING STATEMENTS

2 This presentation contains forward-looking statements. More particularly, this presentation contains statements concerning anticipated: business strategies, plans and objectives; potential development opportunities and drilling locations, expectations and assumptions concerning the success of future drilling and development activities, the performance of existing wells, the performance of new wells, decline rates, recovery factors, the successful application of technology and the geological characteristics of our properties; cash flow; timing and amount of future dividend payments; oil & natural gas production growth and mix; reserves; debt and bank facilities; amounts and timing of capital expenditures; hedging results; primary and secondary recovery potentials and implementation thereof; and drilling, completion and operating costs. Statements relating to "reserves" are deemed to be forward looking statements, as they involve the implied assessment, based on certain estimates and assumptions, that the reserves described exist in the quantities predicted or estimated and that the reserves can be profitably produced in the future. Actual reserve values may be greater than or less than the estimates provided in this presentation. The forward-looking statements are based on certain key expectations and assumptions made by Tangle Creek, including expectations and assumptions concerning the performance of existing wells and success obtained in drilling new wells, anticipated expenses, cash flow and capital expenditures and the application of regulatory and royalty regimes. Although Tangle Creek believes that the expectations and assumptions on which the forward-looking statements are based are reasonable, undue reliance should not be placed on the forward-looking statements because Tangle Creek can give no assurance that they will prove to be correct. Since forward-looking statements address future events and conditions, by their very nature they involve inherent risks and uncertainties. Actual results could differ materially from those currently anticipated due to a number of factors and risks. These include, but are not limited to, risks associated with the oil and gas industry in general (e.g., operational risks in development, exploration and production; delays or changes in plans with respect to exploration or development projects or capital expenditures; the uncertainty of reserve estimates; the uncertainty of estimates and projections relating to production, costs and expenses, and health, safety and environmental risks), commodity price and exchange rate fluctuations and uncertainties resulting from potential delays or changes in plans with respect to exploration or development projects or capital expenditures. Readers are cautioned that the foregoing list of risk factors is not exhaustive. Furthermore, new risk factors emerge from time to time, and it is not possible for Tangle Creek to predict all of such factors and to assess in advance the impact of each such factor on our business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking

  • statements. The above summary of assumptions and risks related to forward-looking statements in this presentation has been provided in
  • rder to provide potential investors with a more complete perspective of our current and future operations and as such information may be not

appropriate for other purposes. The forward-looking statements contained in this presentation are made as of the date hereof and Tangle Creek undertakes no obligation to update publicly or revise any forward-looking statements or information, whether as a result of new information, future events or otherwise, unless so required by applicable securities laws.

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Board of Directors Company Summary 3

➢ Private energy company focused on quality, innovation, margins & operating efficiency:

✓ One operating area, two primary light-tight oil development projects - Montney and Dunvegan ✓ Top quartile netbacks and operating costs ✓ Concentrated, contiguous land position & infrastructure control ✓ Product egress secured

➢ Strong, motivated management team; track record of capturing large resource opportunities and innovating – driven to quality & margins (well economics 40% to 100% IRR & 12 to 24 month payouts) ➢ Actively consolidating offsetting operators at discounted metrics - control of infrastructure

Experienced Leadership Team

Tangle Creek Overview

Ben Makar

Vice President Engineering Senior Manager - Land

Jim Junker

Nordegg, Burmis, Wascana, Shell

Jeff Prentice

ARC Financial Corp

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The Value Proposition – Total Return – Existing Assets

➢ Return 2x – 4x investment over 2 to 4 years – Flat Pricing ($US55/bbl)

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Since Q1 2017… ✓ RESERVES UP 23% PER SHARE ✓ LOCATIONS UP 290% PER SHARE

…DRIVING GROWTH

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Production Growth – Annual growth since Inception > 40%

35% 15% 25% 10%

Prior 12 month decline 2014 Drilling 2013 Drilling 2012 Drilling 2011 Drilling 2015 Drilling

3rd Party Solution Gas Processing Restriction Beringer Acquisition

2017 Drilling 2016 Drilling

6%

2011 Drilling

RMP Acquisition

Commodity Price Decline Restricted Drilling

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Tangle Creek Today - Operating Metrics

Today

March 2017 % Change

Current Production H1 2018 (boe/d) 8,000 boe/d

6,000 33%

% Oil 55% 60%

  • 8%

2018 Forecast Cash Flow ($MM) $55

$40 38%

Cash Flow per Share $0.18 $0.16 (actual) 10%

June 30, 2018 est Net Debt ($MM) $80 MM

$69 16%

Net Debt/CF 1.5x 1.7x

  • 10%

Bank Line ($MM) $130 MM $100 30%

2P Reserves (mmboe) 53

29 83%

Total Land 345 net sections

265 30%

Total Montney Land 98 net sections

Game Changer!

Net Drilling Locations 400+

90 290%

Q1 Operating Netback $24/boe

(US$59/bbl & Fx=$0.80 & US$9 Diff)

$19 26%

Est 2018 Capital $60 MM

$19

Shares Outstanding (million Mar 31, 2018) 336

226 49%

Equity Value (US$55/bbl flat pricing NPV10 Developed

NPV20 undeveloped)

$300MM

$146 100%

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Background – North American Resource Plays

Unconventional Tight Oil & Gas Plays Basins

Dunvegan - Deep Basin

➢ The Montney is among the most prolific & largest unconventional resources plays, comparable to the Permian, Marcellus, Eagle Ford & Bakken in the US

Estimated at ~50,000 sq. miles in total size

Reservoir thickness exceeding 300 meters in certain areas, requiring > 12 wells / section to properly exploit the resources

➢ Tangle Creek’s Dunvegan light oil property at Kaybob is a water free resource play within the Deep Basin ➢ Tangle Creek’s experience with unconventional reservoirs uniquely positions us to capture & create significant shareholder value

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Tangle Creek West Central Alberta Operating Fairway

Waskahigan, Kaybob, Windfall, Carrot/Pembiina

Hwy 43 Hwy 32 Hwy 16

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Waskahigan Kaybob Windfall Carrot Creek Total Land Montney Gross Net Net Sections Sections Sections Waskahigan 86 85 73 Kaybob 125 82 25 Windfall 69 66 Carrot 130 102 Other 17 10 Total 345 98

Tangle Field Office March 1, 2018

Pembina

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Stacked Oil Reservoirs – Dunvegan, Rock Creek and Montney

Montney Montney Gething Rock Creek / Falher

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Kaybob Carrot/Pembina Waskahigan

1,600 m 2,200 m

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Innovation - Applying What We’ve Learned – Type Curves for Two Main Plays

Tier 1 – IP 365 = 222 boe/d (35 wells) Tier 2 – IP 365 =117 boe/d (23 wells) Tier 3 – IP 365 = 65 boe/d (16 wells) All Wells 10

Kaybob Dunvegan – Type Curves

➢Higher intensity slickwater fracs are shifting Tier 3 & Tier 2 locations into Tier 2 & Tier 1

Waskahigan Montney – Type Curves

➢50 older “oil frac’d” wells supplemented with newer slickwater ➢Opportunity to apply newer, higher intensity fracs including reduced spacing and higher tonnage

Older oil frac type curve based on initial 50 wells

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Completion Technologies – Unlocking Light Tight Oil

Tangle Creek Montney Multistage Fracturing System

➢ One to two mile lateral length ➢ 3,500m to 5,500m total measured well length ➢ 50 to 75 frac ports

Lateral Schematic: http://www.loganinternationalinc.com/lcs/PDF/LCS_MS-Brochure_R1_web - Chart: RSEG Nov 2017

✓ 30m to 60m port spacing ✓ 30 tonnes to 100 tonnes proppant ✓ 1 T/m to 2 T/m proppant intensity ✓ (700 lbs/ft to 1400 lbs/ft)

11 Evolution of Completion Designs in North America

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Waskahigan – Innovation Opportunities & Evidence of Results

Phase 1: Oil based fracs, 12-20 stages, 10-15T/stage, 70-120m inter-frac spacing Phase 2: Hybrid Slickwater fracs, 17-30 stages, 50T/stage, 80m inter-frac spacing Tangle Creek: Slickwater fracs, 50 stages, 50T+/stage, 40-50m inter-frac spacing. Default to 1.5mile long wells

➢ Prior Completion Practices

 Previous Operator used oil based fracs with ball drop system – limits stage count  Cross-linked gels demonstrated to reduce near well-bore perms  Small (5-25T), wide spaced design with 1 mile laterals

➢ Revised Frac Spacing

 Historically 70 - 120m (<30 stages)  Tangle Creek: 40 - 50m (50+ stages)

➢ Revised Proppant Intensity

 Historically 0.2T to 0.6T/meter – oil

  • r hybrid slickwater

 Tangle Creek (slickwater): 1.0 - 2.0T/m in first three wells  Investigating increases beyond 2 T/m later in 2018

➢ Other Initiatives

 Historically – limited >1 mi laterals  Revised to 1.5 mile lateral where possible  Refrac or redrill infill program – convert low intensity, short fracs to longer, higher intensity fracs.

Continued use of gelling agents and short laterals Tangle Creek: Slickwater fracs, 50 stages, 50T+/stage, 40-50m inter-frac spacing. Default to 1.5mile long wells

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Waskahigan Montney Resource – Over 500 million Barrels Oil In Place

Increasing Increasing Gas Oil

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2018 – Proof of Concept (Negative FCF)

➢ Prove completions hypothesis - increased proppant / tighter spacing = higher reserves / IP’s ➢ Prove drilling hypothesis - Drill longer laterals lowers FDC ➢ Reduce CAPEX / well – balance with improved performance ➢ Address water handling issues / lower OPEX – both access & disposal

2019 – Expand (Growing Cash Flow)

➢ Consolidate other operators

➢ Increase # of wells drilled / annum to optimize existing infrastructure, maximize returns & minimize cycle times – improve investment velocity ➢ Accelerate drilling to grow production /&cash flow (>25% / annum target)

2020+ – Crystalize (Growing FCF)

➢ 8-10 years drilling inventory provides continuing production and FCF growth ➢ Increasing focus on technological optimizations to lower declines and improve cash generation Development Strategy – 3-year Development Plan for Waskahigan

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Waskahigan – Infrastructure and Q1 2018 Activity

H1 – 2018 Capital Program ($22mm) - 3 new Montney drills, 1 Belloy disposal well, 1 re- frac, two existing well tie-ins & facilities work

Designed to evaluate:

➢ completion techniques, proppant intensity, frac spacing, pumping rates ➢ Re-frac potential

Challenges & learnings in Q1:

➢ Water disposal – acid stimulations & new disposal well ➢ Water sourcing – shallow source wells and flowback water re-use. ➢ Commence optimizing field operations – lower pressures, re-activate wells, tie-in existing drilled wells ➢ HCDP – Refrig plant improves liquids recovery

New Montney drills 10-15, 15-15 & 4-23 Montney re-frac 3-11 Tie in two existing wells 13-10 & 4-15 Belloy Disposal Well 5-13 Belloy Disposal Well re-stimulation 15

Nova/TCPL main line 12-7 battery – 6,000 to 10,000 bopd capacity + 20mmcf/d compression & refrig 8,500 bwpd disposal capacity Direct tie-in to Pembina and Alliance

Services & Infrastructure:

➢ Year-round access (Valleyview, Grand Prairie, and Whitecourt services) ➢ 6,000-10,000 bopd battery – compression, refrig and water disposal ➢ Egress secured

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16 Purchase Price 5x - Unconstrained values at US$55 ✓ assumes improved capex and well performance, which Tangle Creek is targeting

$80mm $274mm $451mm

Montney Asset Purchase – Price Paid and Value Creation

Timing: Complete Complete 2019 2022 $187mm

NPV10 @ US$55

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Kaybob Dunvegan OOIP = 460MMbbl 17

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➢ Less than 4% recovery forecast – double is achievable with current technology

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Innovation – Steady Improvement in Dunvegan well performance

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Kaybob Dunvegan – Annual Drilling Programs

➢Continuous improvement of drilling and completions – improved well performance

Cumulative Production - boe

Days on Production

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Continue to Drill Best in Class Wells

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➢ Tangle Creek regularly drills top performing oil wells in Alberta

Source: AltaCorp Capital Inc March 2018 report

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Value Creation - Dunvegan Enhanced Oil Recovery ➢ 18 sections - 175 mmbbls OOIP

➢ Enhanced Oil Recovery adds 10-15 mmbbls

➢ Oil Reserves increase – 50% to 100%

➢ Reserve Additions at $2.50/bbl

➢ 1/2 section pilot ➢ Good Response after 8 months

  • GOR Decreasing
  • Oil Rate Increasing
  • No Water Breakthrough from Hz Injector

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Kaybob Dunvegan Operational Excellence – Template for Ongoing Operations

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Operating Cost Reduction focus:

  • consistently driving down operating costs
  • big wins in reducing trucking and road & lease

maintenance charges

  • recent RMP acquisition provides $/BOE reductions (i.e.

utilizing one field office for all assets, very few additional staff requirements)

$8/boe

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Single Well Economics – Metric Analysis

Unit Waskahigan Montney – 1 Mile Low Type Curve Waskahigan Montney – 1 Mile Expected Type Curve Waskahigan Montney - 1.5 Mile Low Type Curve Waskahigan Montney - 1.5Mile Expected Type Curve Dunvegan / Rock Creek Wells Wellhead IP30 boe/d 456 488 519 637 279 Wellhead IP30 Oil bbls/d 342 366 389 478 228 Wellhead IP365 boe/d 196 213 238 294 113 Total Sales Oil mbbl 135 170 185 225 135 Total Sales Volume mboe 232 293 327 397 180 DCET C$mm $3.6 $3.6 $4.6 $4.6 $2.5 B-Tax NPV 10% C$mm $2.1 $3.1 $3.2 $4.5 $1.6 B-Tax Return % 46% 58% 48% 73% 37% Payout Months 22 19 22 16 27

➢ Future development concentrates on high netback, low F&D projects within our portfolio (Montney, Dunvegan, Rock Creek) – recycle ratios on future drilling campaigns north of 2x ➢ At WTIUS$55 - type curves generate ~50% IRR with 1st year recycle ratios > 2.0x ➢ Paybacks generally less than key threshold of 24 months

US$55 / bbl – US$6 / bbl differential / $2.00 / mcf blended nat gas (Alliance proxy) - FX - $0.78 22

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Organic Investment – New Well Netbacks & Recycle Ratios – Current Commodity Prices

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New Wells Waskahigan Waskahigan Dunvegan/ Low (1 mi) Expected (1 mi) Rock Creek

Volumes

  • il (mbbls)

135 170 135 mboe 232 293 180 $CAD $CAD $CAD

Prices

Oil 1 WTI US$60 $72.44 $72.44 $72.44 Gas 2 Wellhead C$/mcf $2.00 $2.00 $2.00

Revenue

$/boe $44.26 $44.26 $54.83

Royalties ($2.21) ($2.21) ($2.74) Opex ($8.00) ($8.00) ($8.00) Transportation ($4.00) ($4.00) ($4.00)

Field Netback ($boe) $30.05 $30.05 $40.09

F&D ($/boe) $15.52 $12.29 $13.89 Field Recycle Ratio 1.9x 2.4x 2.9x Corp Cash Costs ($.boe) ($3.90) ($3.90) ($3.90)

Corporate Netback $26.15 $26.15 $36.19 Corporate Recycle 1.7x 2.1x 2.6x Drilling Inventory 270 270 140

(locations)

NPV10 ($million) $1.7 $2.9 $2.0

  • 1. Assume Cushing Diff US$3.50 CAD $0.78
  • 2. Gas is 55% Chicago, 25% AECO and 20% ATP - Jan actual - C$3.50 - Q1 est C$2.20
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Value Creation –Proofing Corporate 2x Recycle

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Corporate Jan Actual Volume

  • il (mbbls)

138

One Dunv/RC Well per month

% oil 55%

Corp Gas rate high due to acquired gas properties

$CAD

Prices

Oil 1 WTI 55 $74.04 Gas 2 $/mcf $3.50

January Chicago was US$3.79/mmBTU

Revenue $/boe $48.51

Corp Gas rate high due to acquired gas properties

Royalties ($3.88)

Older wells off Royalty Incentive Period

Opex ($9.50)

Integrating Acquired Assets

Transportation ($4.75)

Higher Gas rate and Chicago Transport

Field Netback ($boe) $30.38 F&D ($/boe) $17.03

Tangle Corp Historic FD&A since inception

Field Recycle Ratio 1.8x

Corp Cash Costs ($.boe) $3.68

Corp Recycle 1.6x

Corp Cash Flow ($mm) $5

Corporate Cash Flow Per Month ($million)

Corp Recycle 2x

Dunvegan well cost is $2.5mm – drill 12 per year

Drilling Inventory 410

One mile drilling locations

Producing 1 Dunvegan/Rock Creek well per month – cash flowing $5million per month – all in capex on new wells is <$2.5 million per well – Corporate Recycle = 2x

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1. Top Quartile Margins – Light oil yields best operating netbacks of over $20/boe (includes gas)

✓ Low cost structure – opex <$10/boe & focus on light crude production ensures high margins & economic sustainability

2. Egress - Firm service on Alliance (gas) and Pembina (oil)

✓ Firm egress - unique among juniors ensures reliable takeaway, lower costs & higher realized pricing ✓ Oil via Pembina – 100% firm service ✓ Gas – 55% sold in Chicago via Alliance, 20% ATP via Alliance and 25% AECO via TCPL – 100% firm service

3. Hedging – protecting cash flows, capital programs & balance sheet

Over 60% of oil production hedged in 2018 at north of C$60/bbl (Cushing basis)

Regular, disciplined program of layering on new hedges every quarter with volume targets of north of 50% hedged over coming 12 months and north of 25% over subsequent 12 months

4. Expanding Drilling Inventory Facilitates Growth

Innovation and application of evolving technologies to organic growth

Consolidation opportunities identified

Light oil drilling inventory of over 350+ locations

5. Environmental, Social and Governance – program of continuous improvement.

Proactive businesses attract investor interest and fetch a premium price by developing and implementing technologies to reduce emissions, reduce impact and by increase transparency & governance

6. Maintaining Optionality & Discipline – US$5/bbl price change impacts annual cash flow C$5mm

Ability to quickly adjust drilling production and reserves growth

Disciplined – “bullet-proof” balance sheet while growing the business

Strong relationships – top quality partners and shareholders

Business Principles Focus on a Sustainable, High Margin Business

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➢ Scale & organic growth potential ➢ Internal 400+ locations ➢ Sustainable growth at 20%+ per year ➢ Follow-on acquisition opportunities identified ➢ Consolidation within operating fairway ➢ C$35 - $100+ million targets ➢ Enables rapid growth to 20,000 boe/d & beyond

Avenues to Growth Today Target – 2 to 3 years

➢ IPO Ready ➢ Organic growth to deliver PE returns ➢ Increasing oil weighting with production growth ➢ Path to 20,000+ boed, 100 MMboe ➢ $120 MM+ / annum cash flow ➢ Debt : CF < 1x ➢ 500+ locations inventory ➢ 20% annual production growth within cash flow ➢ Monetization options include IPO, sale, merger

  • r combination with other firm to affect IPO

➢ Private Company - 44 shareholders ➢ 8,000 boed, 53 MMboe, 55% light sweet crude ➢ Development & expanding production - oil assets ➢ 2018 - $60 MM+ cash flow at US$55/bbl ➢ Debt : CF < 1.5x ➢ 400+ Location Drilling Inventory

Production History

Growth 2011 - 2014

(US$80 –$100/bbl WTI)

Consolidation 2015 – 2016

(US$26 - $45/bbl WTI)

Production CAGR of 40% since 2012 – to ~8,000 boed Q4 2017

Growth 2017+

(US$55/bbl WTI)

Tangle Creek Business Plan – Next Steps

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The Vision – Creating a Quality, Sustainable Growth Business To create a “must own”, high quality, growth producer with the capital, cash flow, balance sheet and assets to deliver value appreciation & multiple expansion

➢ Strategically position Tangle in quality, high margin plays with running room ➢ Capitalize on history of efficiency gains – depth of team expertise ➢ Consolidation - in core fairway with specific technical attributes ➢ High-grade development - focus on highest return highest margin projects ➢ Balanced risk profile – growth within cash flow

➢ Deliver 15% to 25% per year production & CFPS growth at strip ➢ Shareholder value creation by delivering steady, repeatable per share growth

  • f production, reserves, cash flow, and net asset value

“Growing a quality business to position for an IPO/RTO

  • ver coming 24 to 48 months”

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Logo Placement

TANGLE CREEK ENERGY

May 2018

Contact:

Tangle Creek Energy Ltd

Glenn Gradeen President and CEO d: +1 (403) 648-4901 m: +1(403) 618-0434 ggradeen@tanglecreekenergy.com 2100, 715 – 5th Ave S.W. Calgary, AB T2P 2X6 John Pantazopoulos Senior VP Finance and CFO d: +1 (403) 648-4903 m: +1(403) 828-8084 jpantazopoulos@tanglecreekenergy.com