Corporate Presentation

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1 Corporate Presentation exploring new roads TSX: JOY September, 2018

2 Snapshot 10,200 boe/d balanced producer; 49% liquids (1) 16% corporate decline; interest in early stage oil resource play $0.66-$0.73/share funds flow; $26-29 million annual funds flow for 2018 $196 million enterprise value ; <$20,000 boe/d 38.5 million $1.70/share; $65 million market cap $100 million credit facility ($66 million drawn) Target Net Debt $126 - $129 YE 2018 (1) Projected H average production 2

3 Forward-Looking Statements and Financial Measures This presentation contains forward-looking statements including estimates of future production, cash flows and reserves, business plans for drilling and exploration, the estimated amounts and timing of capital expenditures, the assumptions upon which estimates are based and related sensitivity analyses, and other statements about future events or performance (often, but not always, using words or phrases such as expects or does not expect, is expected, anticipates or does not anticipate, plans, estimated or intends, or stating that certain actions, events or results may, could, would, might or will be taken, occur or be achieved). Forward-looking statements are based on current expectations, estimates and projections that involve a number of risks and uncertainties, which could cause actual results to differ materially from those reflected in the statements. Forward-looking statements are based on the estimates and opinions of the Company s management at the time the statements are made. Although the Company believes that the expectations reflected in these forward-looking statements are reasonable, such statements are subject to known or unknown risks and uncertainties that may cause actual results to differ materially from those anticipated. Journey assumes no obligation to update forward-looking statements should circumstances or management s estimates or opinions change. Throughout this presentation the Company uses the terms funds flow from operations, funds flow from operations per share, operating netback, net debt. These terms do not have a standardized prescribed meaning under GAAP and these measurements may not be comparable with the calculation of similar measurements by other entities. Funds flow is calculated based on cash flow from operating activities before changes in non-cash working capital, transaction costs and decommissioning expenditures. Journey believes the timing of collection, payment or incurrence of these items involves a high degree of discretion and as such may not be useful for evaluating Journey s operating performance. Funds flow from operations per share is calculated using the same weighted average number of shares outstanding used in calculating earnings per share. Management utilizes funds flow from operations as a key measure to assess the ability of the Company to finance dividends, operating activities and capital expenditures. Funds flow from operations should not be construed as an alternative to net earnings or cash flow from operating activities determined in accordance with GAAP as an indication of Journey s performance. The term net debt is calculated as total bank debt (long term bank debt plus the current portion of bank debt) plus the deferred lease obligation plus other current liabilities (excluding derivative contract fair values and decommissioning liabilities) less current assets (excluding derivative contract fair values). Net debt is used by management to analyze the financial position and leverage of the Company. Operating netback is calculated on a per boe basis and is determined by deducting royalties, transportation costs and operating expenses from petroleum and natural gas revenue before hedging gains and losses. Operating netback is utilized by Journey to analyze the operating performance of its petroleum and natural gas assets against prior periods as well as its peers. 3

4 Forward-Looking Statements and Financial Measures OIL AND GAS ADVISORY The crude oil, natural gas and natural gas liquid reserves and related future net revenue of Journey presented herein were evaluated by GLJ, Journey s independent reserves evaluators, in accordance with the requirements of National Instrument ( NI ) and the Canadian Oil and Gas Evaluation Handbook effective as of December 31, Forecast pricing used is the average of the published price forecasts for GLJ Petroleum Consultants Ltd., Sproule Associates Ltd. and McDaniel & Associates Consultants Ltd. as at December 31, Where applicable, oil equivalent amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. Boes may be misleading, particularly if used in isolation. A boe conversion ratio of six thousand cubic feet of natural gas to one barrel of oil 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 the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 Mcf: 1 Bbl, utilizing a conversion ratio at 6 Mcf: 1 Bbl may be misleading as an indication of value. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein. Reserves included herein are stated on a company gross basis (working interest before deduction of royalties without including any royalty interests) unless noted otherwise. The estimates of reserves for individual properties may not reflect the same confidence level as estimates of reserves for all properties due to the effects of aggregation. Drilling Locations: this presentation discloses drilling locations in three categories: (i) proved locations; (ii) probable locations; and (iii) unbooked locations. Proved locations and probable locations, which are sometimes collectively referred to as booked locations, are derived from the Company s most recent independent reserves evaluation as prepared by GLJ as of December 31, 2017 and account for drilling locations that have associated proved or probable reserves, as applicable. Unbooked locations are internal estimates based on the Company s prospective acreage and an assumption as to the number of wells that can be drilled per section based on industry practice and internal review. Unbooked locations do not have attributed reserves or resources. Unbooked locations have specifically been identified by management as an estimation of our multi-year drilling activities based on evaluation of applicable geologic, seismic, and engineering, production and reserves data on prospective acreage and geologic formations. The drilling locations on which we actually drill wells will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results and other factors. While certain of the unbooked drilling locations have been derisked by drilling existing wells in relative close proximity to such unbooked drilling locations, the majority of other unbooked drilling locations are farther away from existing wells where management has less information about the characteristic of the reservoir and therefore there is more uncertainty whether wells will be drilled in such locations and if drilled there is more uncertainty that such wells will result in additional oil and gas reserves, resources or production. 4

5 East Duvernay World Class Emerging Resource Accelerating Activity in East Duvernay Play Significant industry capital being allocated to projects focused in the oil window 3 rigs running West side of Rimbey Leduc trend Repsol/Paramount drilling south of Journey Baytex(Raging River)/Crescent Point/Teine drilling north of Journey Thick Shale on Journey Land Source rock analysis and vertical penetrations highlight light oil window and thick shale offsetting Rimbey Leduc trend Thick (>30m) continuous shale package with favourable porosity, thermal maturity, well control and rock mechanics Medium depth overpressured reservoir; (2,800m, 8,000psi) Source: Journey internal, Geoscout. 5

6 Gilby Duvernay Resource Captured Drill Depth Gamma Ray Total Phi ELAN Swe Total Organic Carbon frac JOY well License 6-28 Strat Vertical JOY well License lead well Significant Land and Infrastructure Ownership Interest in ~140 Sections of Duvernay PNG Rights Lowest average royalties in oil fairway 43.3% ownership in underutilized Gilby 1-4 Gas Plant % ownership in significant pipeline GGS egress Vertical Test Well Drilled in May Some of the thickest shale in the East Duvernay oil fairway 6-28 vertical strat well confirmed 31m shale thickness The well ~ 8km to the south has similar characteristics with both wells containing continuous shale packages Thermal maturity similar to most other light oil wells in the area. 6

7 Gilby Duvernay Experienced Partner Selected Joint Venture Partner Kiwetinohk Resources Corp (KRC Operator) Operator has extensive experience in commercializing early stage resource plays JOY to retain 37.5% working interest (WI) after Commitment and Option phases Commitment and Option Phases (6-24 months) Well placement will be finalized in order to preserve lands, delineate resource and test commercial development strategies 2 well Commitment phase; KRC pays 100% of capital to drill, complete, equip and tie-in; JOY has 3.75% GORR that converts to 29.17% WI after payout of 58.33% of capital 5 well Option phase; KRC pays 100% of capital to drill, complete, equip and tie-in; JOY converts to 29.17% WI after payout of 33.33% of capital Early Development Phase (2 yr Post Option Period) KRC 62.5%WI and JOY 37.5% WI Mutual agreement required for >10 wells/year 7

8 10% Before Tax - $millions Gilby Duvernay - Development Potential Commercial Development Significant running room over large acreage position for KRC (62.5% WI) and JOY (37.5% WI) Existing lands could support 250+ wells on 400m interwell spacing (tighter spacing already being tested by others) High impact, high netback light oil additions Capital efficiencies, technology and cost improvements will evolve over time Gilby Duvernay HZ Oil Well (Gross) NPV@10% (1) AECO $1.60/MMbtu (flat) Single Well Parameters (1) 2,400m horizontal 350 Mboe EUR (82% liquids) Light oil, 1,500 scf/bbl GOR DCET $8 MM/well Royalties 2/3 Crown, 1/3 Freehold $60 $70 $80 $CAN/bbl - EDM Light Sweet Big pools get bigger with time and technology (1) Journey internal estimate 8

9 Journey Provides Investors with Growth, Value and Upside Journey s low decline rate provides a stable platform for sustainable growth S U S T A I N A B L E C O M P E L L I N G F U T U R E G R O W T H V A L U E U P S I D E 9

10 Balanced Production in Two Concentrated Core Areas Resource Fairway Shallow, low-risk development drilling in conventional oil pools ~10,000 boe/d produced in Q2 from pools in our Resource Fairway Central Region (~4,800 boe/d; 56% oil and NGLs) Gilby-Duvernay, Crystal, Cherhill South Region (~5,200 boe/d; 38% oil and NGLs) Matziwin, Skiff, Herronton Current pricing is sufficient to maintain production levels while improving netbacks and increasing liquids weighting 10

11 PDP Reserve Life Index (1) Lowest Declines Peer Group Includes AAV, ARX, BNP, BNE, CJ, CR, DEE, GXE, GXO, IPO, JOY, KEL, NVA, PONY, PRQ, PEY, SPE, SRX, SGY, TVE, TOG, WCP, YGR (1) PDP Reserve Life Index on this page is calculated by dividing PDP reserves at December 31, 2017 by annualized Q Production 11

12 How to make a Low Decline even LOWER JOY net barrels of OOIP by category 385 MM on waterflood 95 MM conventional 240 MM to be flooded 60 MM to } be delineated and flooded 780 MM net barrels of OOIP (1) 385 MMbbls on waterflood Remaining conventional convert conventional 300 MMbbls conventional ~10% decline ~19% decline ~23% recovery <5% recovery higher decline pools to low decline waterflood to be flooded and delineated/flooded Waterflood expansion will not only increase Journey s be oil flooded recovery, but will also maintain our low decline (1) Journey estimate of Original Oil in Place (OOIP) in key Journey conventional oil pools 12

13 Sustainable Growth in Future Funds Current Strip Pricing Production Operating Highlights Average (boe/d) 2016 Actual 2017 Actual 8,712 9, Forecast 10,100 10, First Look ~10,000 Oil and NGLs (%) 53% 46% 48% 50% Corporate Decline Rate (%) 20% 17% 16% 16% Reference Prices AECO ($/MMBtu) $2.18 $2.20 $1.55 $2.00 Oil WTI ($US/bbl) $43.32 $50.95 $67.00 $68.00 F/X ($USD/$CAD) $0.76 $0.77 $0.78 $0.77 Funds Flow Netback $/boe $8.65 $8.56 $7.40 $13.48 Capital Net of A&D ($millions) $7 $66 $29 $41 Wells Drilled Gross/Net 7/6.1 12/11.5 9/9.0 15/14.9 Financial Funds Flow ($millions) $27.5 $31 $26 $29 $48 $50 Hedging gain (loss) ($millions) $4.5 $1.4 ($15 $17) ($5 $6) Year End Net Debt ($millions) $86.9 $103 $126 $129 $116 $118 Basic Weighted Average Shares (millions) Funds Flow/Share ($/Share) $0.63 $0.63 $0.66 $0.73 $1.25 $1.30 Sustainable growth in 2018 becomes cash flow growth for 2019 as hedges disappear 13

14 AECO GAS ($/MCF) AECO GAS ($/MCF) Funds Flow Sensitivity Based on 2018 Guidance Funds Flow ($millions) (Including Hedges) $1.25 $1.35 $1.45 $1.55 $1.65 $1.75 $1.85 Funds $1.95 Flow ($millions) (Excluding Hedges) WTI ($USD/bbl) $57.00 $59.50 $62.00 $64.50 $67.00 $69.50 $72.00 $74.50 $ WTI ($USD/bbl) $57.00 $59.50 $62.00 $64.50 $67.00 $69.50 $72.00 $74.50 $77.00 $ $ $ $ $ $ $ $

15 Hedging Bbls/d Pricing Point Average Price CAD $/bbl Term 3,000 WTI NYMEX $ Q3, ,000 WTI NYMEX $ Q4, ,500 WTI NYMEX $ Q1, ,500 WTI NYMEX $ $73.33 Q2, ,000 WTI NYMEX $ $ H, WTI NYMEX $ $77.00 Q1, 2020 Oil GJ/d Pricing Point Gas Average Price CAD $/GJ Term 3,500 AECO $ 2.47 Q3, ,500 AECO $ 2.63 Q4,

16 Journey Provides Investors with Growth, Value and Upside 16 Journey trades at a significant discount to our peer group S U S T A I N A B L E G R O W T H F U T U R E U P S I D E C O M P E L L I N G V A L U E

17 2017 YE Reserves Summary Gross Company (WI) Reserves (1) Reserve Category Oil (Mbbl) Gas (Bcf) NGLs (Mbbl) Mboe RLI Proved Developed Producing 8, ,962 27, Total Proved 12, ,028 37, Proved + Probable Producing 12, ,746 36, Total Proved + Probable 23, ,866 60, Value of Reserves Reserve Category 10% (1) ($ million) Net Asset Value (2) ($ million) Net Asset Value (3) ($/share) FDC (4) ($ million) Proved Developed Producing Total Proved Proved + Probable Producing Total Proved + Probable (1) Reserves, and NPV (net present value) as per the GLJ report on a before tax basis, discounted at 10% effective December 31, RLI (Reserve Life Index) is calculated by dividing reserves by first year production. Forecast pricing used is the average of the published price forecasts for GLJ Petroleum Consultants Ltd., Sproule Associates Ltd. and McDaniel & Associates Consultants Ltd. as at December 31, (2) Net Asset Value is a Pro-forma estimate calculated by taking the and adding estimated undeveloped land value of approximately $13.8 million and deducting net debt at December 31, 2017 of approximately $103 million plus the additional debt of $21.3 million incurred by Journey for the 12.7 million share buyback which closed on February 2, (3) Net Asset Value Per Share is a Pro-forma estimate calculated using the total basic shares outstanding as at December 31, 2017 of 51.2 million minus the 12.7 million share buyback which closed on February 2, (4) FDC is future development capital in the GLJ report effective December 31,

18 Net Asset Value (Pro-forma as at December 31, 2017) Reserves 10% P+P $527 million $124 million Pro forma YE Net Debt plus $14 million Undeveloped Land Net Asset Value Net Asset Value per Share P+PDP $326 million P+P $417 million 38.5 million Pro-forma Shares O/S P+P $10.81/share $197 million of FDC adds $201 million NPV@10% of P+P non-producing value; $1.02 of NPV@10% for every $ of FDC PDP $252 million P+PDP $216 million P+PDP $5.60/share PDP $141 million PDP $3.66/share Note: See prior page for definitions and assumptions 18

19 Trading Price as a % of NAV per Share (1) Trading Price as a % of PDP NAV per Share 600% 550% 500% 450% 400% Most Undervalued 350% 300% 250% 200% 150% 100% 50% 0% 100% Peer Group Includes AAV, ARX, BNP, BNE, CJ, CR, DEE, GXE, GXO, IPO, JOY, KEL, NVA, PONY, PRQ, PEY, SPE, SRX, SGY, TVE, TOG, WCP, YGR 120% Trading Price as a % of P+P NAV per Share 80% 60% Most Undervalued 40% 20% 0% (1) Trading as % of NAV per share is calculated by dividing share price as of March 27, 2018 by NAV per share. NAV (Net Asset Value) per share is calculated by subtracting net debt from the reserve category NPV@10% as of December 31, 2017 and dividing by basic shares outstanding. For Journey, NAV is a Pro-forma estimate calculated by taking the NPV@10% and deducting net debt at December 31, 2017 of approximately $103 million plus the additional debt of $21.3 million incurred by Journey for the 12.7 million share buyback which closed on February 2,

20 Journey Provides Investors with Growth, Value and Upside 20 Journey is built on a strong foundation of large OOIP reservoirs with low recovery factors S U S T A I N A B L E G R O W T H C O M P E L L I N G V A L U E F U T U R E U P S I D E

21 Journey s Future Growth is Driven by Economic Plays Our plays are valuable add $201 million in P+P non-producing with $197 million in FDC; $1.02 of net present value is created for each dollar of FDC spent significant position in early stage Duvernay shale oil resource play Our future is currently unbooked $3.47/P+P boe FDC is lower than the average of our peer group only 29% of our HZ oil location inventory is booked in the reserve report $472 million capital in unbooked inventory (outside of the Duvernay) has the potential to more than double the value of the company no reserve value currently assigned for the Gilby Duvernay In 2019 we can utilize higher cash flow to grow our base business 21

22 Remaining Resource (2) Becomes Future Target 780 MM net barrels of OOIP (1)(2) 2.1% unbooked inventory 82.3% of oil left behind 17.7% ultimate recovery Ultimate Recovery 2.6% booked inventory 13.0% recovery to date Oil left behind becomes Target Resource Infill Drilling Journey can double P+P oil reserves by recovering 3% more of the oil left behind Waterflood Optimization Waterflood Expansion Pool Delineation (1) Journey estimate of Original Oil in Place (OOIP) in key Journey oil pools (2) Excludes Gilby Duveray oil 22

23 Extensive Conventional Development Drilling Inventory Journey has identified 233 (net) horizontal oil drilling opportunities Horizontal Oil Well Drilling Locations (1) Total (2) % Booked (3) in Reserve Report Region Gross Net South % Central % Total % Booked Projects (3) $209 million in Capital Waterflood Conventional Oil Gas Weighted Horizontal Multi-Stage Oil Conventional Oil Gas Weighted Unbooked Projects (2) $472 million in Capital Waterflood Horizontal Multi-Stage Oil Journey s Booked development projects generate average half cycle rates of return of >60% at historically low prices (4) (1) Includes multistage and conventional horizontal oil wells at key development properties (2) Total is sum of Booked + Unbooked. Unbooked is a management estimate effective December 31, 2017 (3) Booked is proved plus probable reserves as per GLJ effective December 31, 2017 (4) Refers to the P+P non-producing reserves as per GLJ effective December 31, 2017 with price forecast as per 3 consultants average effective January 1,

24 Improving Recovery in our Legacy Oil Pools $67 WTI USD/bbl, $0.78 USD/CAD, $1.55/MMbtu AECO, No Inflation HZ Drilling Economics (1) Drilling Metric Crystal HZ Viking Cherhill HZ Banff Matziwin HZ Regional Glauconite Herronton HZ Elkton Capital Cost ($MM) $2.8 $2.0 $2.2 $2.4 Ultimate Recovery (Mboe) % Oil and Liquids 81% 90% 49% 69% IP30 (boe/day) IP365 (boe/day) First Year Opex ($/boe) $8.94 $8.48 $5.45 $7.04 F&D ($/boe) $14.14 $7.60 $10.43 $14.29 Net Present Value@10% BT ($MM) $2.1 $3.7 $1.2 $1.3 Internal Rate of Return BT (%) 56% 84% 47% 39% Payout (Years) First Year Netback ($/boe) $45.87 $47.00 $24.68 $39.25 Recycle Ratio (Times) (1) Journey internal unrisked estimate 24

25 Sustainable Mid Term Growth Matziwin Undrained Extension Journey Operated: 100% WI Significant discovery in the Regional Glauconite in Q HZ well encountered near virgin pressure in an undrained extension of East Matziwin pool Followed up with 3 additional wells in Q2, all encountered virgin pressure Undrained extension estimated to contain up to 20 million barrels of OOIP based on mapping Undrained extension supports 5 additional wells Aggregate initial production exceeding Journey budget estimate 5 HZ wells planned for

26 Drilling & Waterflood Development Skiff Sawtooth Sections 7,8 & 9 HZ Waterflood Area Journey Operated: 100% WI Recoveries in established portions of the pool exceed 30% of OOIP Limited recovery to date in the southern portion of the pool 15 HZ wells drilled in pool to date no frac required Successful horizontal waterflood area in sections 7, 8 and 9 o Includes 7 HZ wells currently 4 HZ and 2 Vertical producers o 4 HZs drilled and 3 HZs converted to water injection in 2016/2017 o Very good production response to water injection Expanding development area; Initial horizontal drilling to the south o Drilled 3 HZ wells; 16-32, 9-32 and 8-32 in June/July 2018 o Initial production very encouraging o Plan to convert 9-32 HZ well to injection by yearend Additional development planned for

27 Oil - bbls/d Horizontal Light Oil Drilling Crystal Viking Existing Journey Pipelines Acquired Pipelines analog well 1-30 Months Journey Operated: 100% WI Control of key processing infrastructure to improve netbacks and allow for easier expansion of play Drilled 9-30 HZ location in Q Drilled HZ and 1-30 HZ in 2017 Plan to drill 2 to 3 additional HZ wells in

28 New Roads Lead to Bright Future Security Well positioned to profit from recovering oil price Value Trades at a discount to produce out value Upside Legacy pools and emerging Duvernay oil resource play provide medium and long term growth Team Business Model Assets Experienced management Skilled board of directors Acquire and develop mentality Experience in full cycle resource play development Control legacy underdeveloped oil pools along a fairway Blend acquisitions, drilling and secondary recovery Development of emerging Duvernay oil resource play Control of ~780 million bbls of OOIP with ~13% recovery factor in conventional legacy oil pools Ability to capitalize on inventory that is highly attractive in the current commodity price environment Potential to realize step change in value through Duvernay oil resource development 28

29 Appendix- Content Drilling inventory Central Region South Region Finding, Development and Acquisition Costs Strong Governance Experienced Management 29

30 Appendix - Central Region Conventional Drilling program currently planned for Crystal in Q Horizontal Oil Well Drilling Locations (2) Booked (1) Unbooked (3) Property Formations Gross Net Gross Net Poplar Creek/ Westerose Belly River, Cardium, Banff Cherhill Banff Crystal Viking Central Remainder Total Central Region (1) Booked locations are included in the proved plus probable reserves as per GLJ effective December 31, 2017 (2) Includes multistage and conventional horizontal oil wells at key development properties (3) Unbooked is a management estimate effective January 1,

31 Appendix - South Region Conventional Skiff 2018 drilling program Matziwin and Skiff finished. Additional drilling planned for 2019 Horizontal Oil Well Drilling Locations (1) Booked (2) Unbooked (3) Property Formations Gross Net Gross Net Matziwin Glauconite, Colony Skiff Sawtooth Countess / Brooks Glauconite, Sunburst, Pekisko Herronton Elkton Total South Region (1) Includes multistage and conventional horizontal oil wells at key development (2) Booked locations are included in the proved plus probable reserves as per GLJ effective December 31, 2017 (3) Unbooked is a management estimate effective January 1,

32 Finding, Development & Acquisition Costs For the years ending December 31, 2015 to December 31, (3 Yr) Acquisitions and Divestiture Capital ($millions) $6.6 $(9.3) $33.3 $30.5 Exploration and Development Capital ($millions) $41.5 $16.3 $32.2 $90.0 Total Capital Expenditures ($millions) $48.1 $7.0 $65.5 $120.5 Total Proved Reserve Additions (MMboe) $/boe Including Change in Future Development Costs $11.73 $4.67 $7.90 $7.71 Recycle Ratio (1) Proved + Probable Reserve Additions (MMboe) $/boe Including Change in Future Development Costs $5.13 $(2.77) $6.68 $5.90 Recycle Ratio (1) 2.6 NA (2) Journey s portfolio approach has yielded consistent results over the long term, while allowing us to continue to grow in areas where others are not focused (1) Based upon the respective annual Operating Netbacks and including changes in Future Development Capital (FDC) (2) Negative number, not meaningful 32

33 Board of Directors - Strong Governance Howard Crone Glenn Hamilton Dana Laustsen Ryan Shay Alex Verge Chairman of the Board Executive Vice President and Director of Cequence Energy Ltd.; Director of Karve Energy Inc. Audit Committee Chair Independent businessman, former Senior Vice President and Chief Financial Officer of Bonavista Energy Corporation; current director of Ember Resources Inc. Reserve Committee Chair Independent businessman, former Executive Vice President and Chief Operating Officer of GLJ Petroleum Consultants Ltd. Compensation and Governance Committee Chair Independent businessman and former Managing Director, Head of Investment Banking at Cormark Securities Inc.; formerly with Peter s & Co. and Deloitte & Touche; current director of Perpetual Energy Inc. and Crew Energy Inc. See Management Team 33

34 Experienced Management Team Alex G. Verge, P.Eng., M.Eng. President and Chief Executive Officer, and Director Over 35 years of experience: Seven years as Director of Journey (six as CEO), President and CEO of NuVista Energy, VP Engineering at Bonavista, and senior positions at Poco Petroleums, Rising Resources, Shell, and Gulf. Gerry N. Gilewicz, CPA, CMA Chief Financial Officer 28 years experience: Previously CFO of Vero Energy, CFO of Devlan Exploration and Senior Manager at Deloitte & Touche. Terry J. Moore, P.Eng. Vice President, Engineering Over 35 years experience: Executive roles with Sword Energy and PRL Resources. Previously with Enerplus Resources Fund. Anthony V. Polini, B. Comm, MBA Vice President, Land 26 years of experience: Previously VP Land at Vigilant Exploration and Outrider Energy; senior land positions with Koch and PanCanadian. Brett R. Boklaschuk, P. Geol. Vice President, Exploration 23 years of experience: Progressive roles at Canadian Hunter Exploration, Burlington Resources and NuVista Energy. 34