RGY INC EAGLE GLE ENERG NC. Investor Presentation | January 2016 - - PowerPoint PPT Presentation

EAGLE GLE ENERG RGY™ INC NC.

Investor Presentation | January 2016 TSX: EGL

EXPERTISE • QUALITY • INCOME

Advisory Regarding Forward Looking Statements:

This presentation includes statements that contain forward looking information (“forward-looking statements”) in respect of Eagle Energy Inc.’s expectations regarding its future operations, including Eagle’s investment and business strategy, and forecast estimates for Eagle’s capital budget, production, drilling plans, operating costs, funds flow from operations, commodity split, debt to trailing cashflow, corporate payout ratios, annual dividend, tax pools, estimated field netback, hedging and reserves and resources. These forward looking statements involve estimates and assumptions including those relating to timing to drill and bring wells on production, production rates, operating and capital costs, marketability of crude oil, natural gas and natural gas liquids, future commodity prices, future currency exchange rates, anticipated cash flow based on estimated production, size of reserves and reservoir performance, among other things. These estimates and assumptions necessarily involve known and unknown risks, delays, challenges and other uncertainties inherent in the oil and gas industry including those relating to geology, production, drilling, technology, operations, human error, mechanical failures, transportation, processing problems and poor reservoir performance, among others things, as well as the business risks discussed in the company’s annual information form dated March 19, 2015 under the headings “Risk Factors” and “Advisory-Forward-Looking Statements and Risk Factors”. The forward-looking statements included in this presentation should not be unduly relied upon. Actual results may differ from the forward-looking information in this presentation, and the difference may be material and adverse to the company and its shareholders. No assurance is given that the company’s expectations or assumptions will prove to be correct. Accordingly, all such statements are qualified in their entirety by reference to, and are accompanied by, the information and factors discussed throughout this presentation. These statements speak only as of the date of this presentation and may not be appropriate for other purposes. Eagle does not undertake any obligation, except as required by applicable securities legislation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or

• therwise. Eagle’s annual information form dated March 19, 2015 contains important detailed information about Eagle and its shares. Copies of the annual information form may be viewed at www.sedar.com

and on Eagle’s website at www.eagleenergy.com.

Advisory Regarding Non-IFRS financial measures:

Statements throughout this presentation make reference to the terms “funds flow from operations,” “field netbacks,” and “corporate payout ratio,” which are non-IFRS financial measures that do not have any standardized meaning prescribed by IFRS and therefore may not be comparable to similar measures presented by other issuers. Investors should be cautioned that these measures should not be construed as an alternative to earnings (loss) calculated in accordance with IFRS. Management believes that these measures provide useful information to investors and management since they reflect the quality of production, the level of profitability, the ability to drive growth through the funding of future capital expenditures and the sustainability of dividends to shareholders. “Funds flow from operations” is calculated before changes in non-cash working capital and abandonment expenditures. Management considers funds flow from operations to be a key measure as it demonstrates Eagle’s ability to generate the cash necessary to pay dividends, repay debt, fund decommissioning liabilities and make capital investments. Management believes that by excluding the temporary impact of changes in non-cash

• perating working capital, funds flow from operations provides a useful measure of Eagle’s ability to generate cash that is not subject to short-term movements in non-cash working capital.

“Field netback” is calculated by subtracting royalties and operating expenses from revenue. “Corporate payout ratio” is calculated by dividing capital expenditures plus shareholder dividends by funds flow from operations.

Advisory Regarding Oil and Gas Measures and Estimates

This presentation contains disclosure expressed as barrel of oil equivalency (“boe”) or boe per day (“boe/d”). All oil and natural gas equivalency volumes have been derived using the conversion ratio of 6Mcf of natural gas: 1 bbl of oil. Equivalency measures may be misleading, particularly if used in isolation. A 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. In addition, given that the value ratio based on the current price of oil as compared to natural gas is significantly different from the energy equivalent of six to one, utilizing a boe conversion ratio of 6 Mcf: 1 bbl would be misleading as an indication of value. The estimated values of the future net revenues of the reserves disclosed in this presentation do not represent the market value of such reserves. There is no assurance that such price and cost assumptions will be attained and variances could be material. The recovery and estimates of reserves provided in this presentation are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual reserves may be greater than or less than the estimates provided.

Advisories

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“Eagle is created to provide investors with a sustainable business while delivering stable production and overall growth through accretive investments and acquisitions.”

Expertise Quality Income

Eagle’s trusted management team brings an average of 25 years of experience to the oil and gas sector. Eagle owns stable petroleum producing assets in Canada and the U.S. Eagle strives to deliver sustainable monthly dividends to shareholders.

Strategy

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Acquisition of Maple Leaf(1)

On January 27, 2016, Eagle closed the previously announced arrangement agreement (the “Arrangement”) with Maple Leaf Royalties Corp. (“Maple”) for all of the issued and outstanding common shares of Maple and converted into a corporation called “Eagle Energy Inc.”

Acquisition Highlights:

• Approximately 235 boe/d of royalty interest production (30% oil and liquids) and 161 boe/d of working

interest production (30% oil and liquids) added to Eagle’s 2016 average production.

• Estimated total net proved reserves of 0.94 million boe.
• Total net proved plus probable reserves of 1.09 million boe.
• No additional debt, capital expenditures or overhead needed to manage the incremental production and

cash flow.

Note: 1) For more information, see Eagle’s news release issued on November 20, 2015, “Eagle Energy Trust Announces the Acquisition of Maple Leaf Royalties Corp. and Conversion to a Dividend-Paying Corporation,” and the news release issued on January 27, 2016, “Eagle Announces the Closing of Arrangement with Maple Leaf Royalties

• Corp. and Conversion into a Corporation.”

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Conversion into a Corporation(1)

Conversion Highlights:

• Giving effect to Arrangement, Eagle Energy Trust has converted into a TSX-listed corporation called Eagle

Energy Inc., with the same Board of Directors and executive officers.

• Access to an expanded shareholder base with existing Eagle shareholders holding approximately 82% of

the newly formed corporation.

• Eagle trades with the new symbol “EGL” (formerly EGL.UN) on the TSX.
• The board’s existing policy of declaring the dividend amount monthly remains unchanged, with payments

now in the form of dividends to shareholders rather than distributions to unitholders.

• For Canadian tax purposes, Eagle shareholders with an adjusted cost base above the market price of the

newly formed corporation’s shares received may be able to claim a capital loss(2).

• Estimated combined Canadian tax pools of $194 million.

Notes: 1) For more information, see Eagle’s news release issued on November 20, 2015, “Eagle Energy Trust Announces the Acquisition of Maple Leaf Royalties Corp. and Conversion to a Dividend-Paying Corporation,” and the news release issued on January 27, 2016, “Eagle Announces the Closing of Arrangement with Maple Leaf Royalties Corp. and Conversion into a Corporation.” 2) Shareholders should consult their own legal and tax advisors as to the tax consequences in their particular circumstances.

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Current Estimated Production 3,600 boe/d 2016 Full Year Production Guidance 3,400 to 3,800 boe/d Production Split 88% oil, 2% NGLs, 10% gas 2016 Ending Debt to Trailing Cashflow 3.1x(2) 2016 Corporate Payout Ratio 88%(2) Dividend $0.18 per unit US Tax Pools $US 175 million CDN Tax Pools $CA 194 million

Corporate Profile(1)

Notes:

1) Including the January 2016 acquisition of Maple Leaf. 2) Based on forecast pricing of $US 50.00 per barrel WTI oil, $US 3.16 per Mcf NYMEX gas, $CAD 2.57 per Mcf AECO and $US 17.50 per barrel of NGL (NGL price is calculated as 35% of the WTI price).

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Ticker Shares Outstanding (basic) 34.8 million 52 Week Range $0.65 - $3.40 Recent price $0.80(1) Average daily trading volume (30 day) 126,667 shares Market Cap $27 million Directors’ & Officers’ Ownership 2.8% basic, 10.1% fully diluted(2) Equity Research Acumen Capital Partners Paradigm Capital Scotiabank Global

TSX: EGL

Market Data

Notes: 1) TSX closing price on January 26, 2016. 2) Average exercise price of options = $5.64.

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2016 Guidance and Budget Highlights

• A 37% year-over-year decrease in the 2016 capital budget to $10.2 million ($US 7.0 million for its operations in the United

States and $0.9 million for its operations in Canada)

• A corporate payout ratio of under 100% at a WTI price as low as $US 45.00 per barrel of oil.
• A 50% reduction in the monthly dividend to $0.015 per unit per month.
• Based on the forecast key variables, including oil prices and US/Canada foreign exchange rates, Eagle believes this dividend

level can be sustainable while staying within acceptable bands of its key performance metrics.

• A 23% or $3.0 million reduction in year-over-year general and administrative expenses.
• 2016 production guidance of 3,400 to 3,800 boe/d (pro-forma Maple Leaf acquisition; excludes 235 boe/d of royalty interest

production).

• 41% undrawn on its existing $US 80 million credit facility at the end of 2016.(1)
• 2016 year-end projected debt to trailing cash flow of approximately 3.1x.(1)

Note: 1) The above metrics are based on the following assumptions: $US 50.00 per barrel WTI oil, $US 3.16 per Mcf NYMEX gas, $CAD 2.57 per Mcf AECO gas, a foreign exchange rate of $US 1.00 equal to $CAD 1.33, and a monthly dividend of $0.015 per unit ($0.18 annualized).

“A Continued Focus on Sustainability and Financial Liquidity in Light of Ongoing Commodity Price Uncertainty”

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2016 Guidance

(including Maple Leaf)

Capital Budget(1) $10.2 MM Working Interest Production(2) 3,400 to 3,800 boe/d Operating Costs per Month $2.2 to $2.6 MM Funds Flow from Operations(3) $20.2 MM Debt to Trailing Cash Flow 3.1x Field Netback (excluding hedges) $21.25/boe

2016 Guidance & Budget Summary

Notes:

(1)

Consists of $US 7.0 million for Eagle’s operations in the United States and $0.9 million for Eagle’s operations in Canada.

(2)

Consists of 88% oil, 2% natural gas liquids (“NGLs”) and 10% gas. These numbers are working interest production numbers only and excludes 235 boe/d of royalty interest production from Maple Leaf.

(3)

Based on the following assumptions: (a) average working interest production of 3,600 boe/d (the mid-point of the guidance range); (b) pricing at $US 50.00 per barrel WTI oil, $US 3.16 per Mcf NYMEX gas, $CAD 2.57 per Mcf AECO and $US 17.50 per barrel of NGL (NGL price is calculated as 35% of the WTI price); (c) differential to WTI is $US 3.10 discount per barrel in Salt Flat, $US 3.50 discount per barrel in Hardeman, $CAD 16.17 discount per barrel in Dixonville and $CAD 12.67 discount per barrel in Twining; (d) average operating costs of $2.4 million per month ($US 0.9 million per month for Eagle’s operations in the United States and $1.2 million per month for Eagle’s operations in Canada), the mid-point of the guidance range; and (e) foreign exchange rate of $US 1.00 equal to $CAD 1.33.

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• 2016 capital budget of $10.2 million:

Texas and Oklahoma ($US 7.0 MM)

• Salt Flat Property
• 3 (3.0 net) horizontal oil wells
• Seismic processing, facilities, pump changes
• Hardeman Property
• 2 (2.0 net) vertical wells
• Seismic processing, pump installs

Alberta ($0.9 MM)

• Dixonville Property (Non-operated)
• Pipeline and facilities
• Twining Property
• Facility Capital

2016 Guidance & Capital Budget

Note: 1) The capital budget excludes corporate and property acquisitions, which are evaluated separately on their own merit.

“Eagle’s drilling program is expected to exceed a 30% rate of return at $US 45.00 WTI flat oil pricing.”

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2016 Guidance & Sustainability Benchmarks

Notes:

(1) Eagle calculates its Basic Payout Ratio as follows: (2) Eagle calculates its Corporate Payout Ratio as follows:

2016 Guidance (including Maple Leaf) Notes Basic Payout Ratio 37% (1) Plus: Capital Expenditures 51% Equals: Corporate Payout Ratio 88% (2) Debt to Trailing Cash Flow 3.1x

shareholder dividends = Basic Payout Ratio Funds flow from Operations Capital Expenditures + shareholder dividends = Corporate Payout Ratio Funds flow from Operations

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2016 Sensitivities

2016 Average WTI (Production = 3,600 boe/d) $US 45 (F/X 1.38) $US 50 (F/X 1.33) $US 55 (F/X 1.28) Cash Flow $18.6 $20.2 $21.1 Corporate Payout Ratio 97% 88% 82% Leverage 3.5x 3.1x 2.9x 2016 Average Production (boe/d) WTI = $US 50 / F/X 1.33 3,400 3,600 3,800 Cash Flow $18.6 $20.2 $21.7 Corporate Payout Ratio 95% 88% 82% Leverage 3.4x 3.1x 2.9x

Assumptions:

(1)

Assumes that the Maple Leaf Arrangement will be completed and 7.6 million shares will be issued to acquire Maple Leaf in January 2016.

(2)

Annualized dividends are assumed to be $0.18 per unit per year.

(3)

Operating costs are assumed to be $2.4 million per month (mid-point of guidance range).

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Strong Balance Sheet Stable Production Capital Discipline Sustainable Dividends with Growth Potential

Exercising Fiscal Prudence and Discipline in a Low Commodity Price Market

“We intend to continue to monitor and realign our business to operate near or within our cash flow.”

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• Eagle owns stable, oil producing properties with development

and exploitation potential located in Canada (Alberta) and in the US (Texas and Oklahoma).

• Twining Field Properties, AB:
• Located in the Pekisko oil pool formation at the Twining field in East-Central Alberta
• 92 gross (48 net) producing wells
• Approximately 41,502 gross (32,650 net) acres
• Dixonville Properties, AB:
• Non-operated
• Located 50 kms northwest of Peace River
• 110 gross (55 net) producing oil wells
• 80 gross (40 net) water injectors
• 18,000 acres
• Salt Flat Properties, TX:
• Located in Salt Flat field in Caldwell County, TX
• 56 gross (42 net) producing wells
• 19 gross (13 net) non producing wells
• 3,300 (2,700 net) acres
• Hardeman Properties, TX & OK:
• Located in Hardeman Basin in Hardeman County, TX, and Greer, Harmon and

Jackson Counties, OK

• 47 gross (37 net) producing wells
• 14 gross (13 net) non-producing
• 79,000 acres

Our Properties

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CDN Properties – Twining Field (Alberta)

• 80% working interest in the largest Pekisko oil pool in the Western Canadian Sedimentary Basin
• 64% light oil and natural gas liquids
• 92 gross (48 net) producing wells
• 30° API medium/light oil, 4 mD permeability and 7-8% average porosity
• Approximately 41,502 gross acres (32,650 net)
• Approx. 70 km from

Three Hills, AB

Lower MNVL Upper Pekisko Middle Pekisko Lower Pekisko Banff

Pekisko Type Log

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CDN Properties – Twining Field (Alberta)

Source: IHS public data

The largest Pekisko oil pool in the WCSB

• Increase to Eagle’s inventory of

quality prospects during this low commodity price environment

Significant upside potential

• 10 horizontal wells drilled to date with
• ver 30 additional drilling locations
• Waterflood in certain areas of the field

has the potential to double recovery factors in the area

Low declines, long reserve life

• Decline rate below 5%
• Reserve life index
• Total Proved – 2.1 Mmboe(1)
• Total Proved Plus Probable –

7.2 Mmboe(1)

Note:

1) Per Coda Petroleum Inc.’s independent reserves evaluator with an effective date of March 31, 2015.

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• 50% non-operated working interest in a horizontal oil waterflood in the Montney “C” Formation
• perated by Spyglass Resources Corp.
• Primary development started in 2004 with full scale waterflood by 2012
• 190 horizontal wells (110 producers, 80 injectors)
• 30◦API Oil, 18 mD permeability and 16-26% average porosity
• Approximately 18,000 acres

50 km from Peace River

CDN Properties – Dixonville (Alberta)

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A premier waterflood in Western Canada

• Low decline property
• Low abandonment liabilities due to long

life asset

Long-term potential

• Decline rate below 10%
• Reserve life index
• Total Proved - 15 years
• Total Proved Plus Probable - 22

years

Refurbished, optimized gathering system

• Pipeline remediation program, including

poly liner installation in emulsion gathering system

Low maintenance and capital costs

• Maintenance capital below $1 million

per year to Eagle

• Operating costs of $16 to $18/boe

CDN Properties – Dixonville (Alberta)

Source: IHS public data

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US Properties – Salt Flat (Texas)

Light oil producing

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• API oil from the Edwards limestone

formation, located in the Salt Flat field in Caldwell County, South Central Texas

• Acquired an 80% working interest in 2010

Low cost development technology

• Eagle is redeveloping the pool using low cost

horizontal well drilling technology to capture additional oil:

• Eagle has drilled over 55 horizontal

wells

• Completed numerous successful

production enhancement and

• perating cost reduction projects
• Shot a comprehensive 3D seismic

program in 2014

Additional location opportunity

• Eagle continues to identify additional

locations and optimizations to capture additional recovery

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Light oil producing

• 45
• API oil from the Chappel and Atoka

Conglomerate formations located in Hardeman County, Texas and Greer, Harmon and Jackson Counties, Oklahoma

79,000 gross acres of land

• ~50 producing wells, gathering

systems and associated assets

Low risk, low cost, high opportunity

• Eagle will drill low risk development

wells and deploy capital to reduce

• perating costs, while processing

newly acquired seismic data to define future drilling opportunities

US Properties – Hardeman (Texas & Oklahoma)

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• Total proved plus probable reserves of approximately 16 million boe (71% proved, 61% proved

producing)

• PV10 value on total proved reserves of approximately $216 million or $5.10/unit
• Proved reserve life index of 14 years based on the mid-point of 2015 average working interest

production guidance

61% 2% 8% 29%

Reserves by Category (Mboe)

PDP PDNP PUD Probable $180 $11 $24 $62

PV10 Value ($ MM)

PDP PDNP PUD Probable

WTI Crude Oil Year $US/bbl ____________________________ 2015 $65.00 2016 $75.00 2017 $80.00 2018 $84.90 2019 $89.30 2020 $93.80

McDaniel & Associates Price forecast (as of Jan 1, 2015)

2014 Year-End Reserves(1)

Excellent year over year reserve performance

Note:

1) Per McDaniel and Associates Consultants Ltd., Eagle’s independent reserves evaluator, with an effective date of December 31, 2014.

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2014 Year-End Reserves Highlights

+88% Strong increase in proved developed producing (PDP) reserves +29% Increase in net present value of PDP reserves (discounted at 10%) +4% Increase in total proved reserves volumes 145% Stability reflected in total proved reserves replacement ratio 265% Excellent total proved plus probable reserves replacement ratio

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• Eagle has 990 barrels of oil per day (“bbl/d”) hedged in Q4 2015 at an average price of $US 74.98/bbl
• Eagle’s hedging program in 2016 is well above its peers(1)
• 35% of production hedged (based on mid-point production guidance)
• 1,000 bbl/d of oil hedged at an average WTI price of $US 59.16/bbl
• 1,430 Mcf/d (240 boe/d) of natural gas hedged at $CAD 2.97/Mcf
• Eagle also hedged the differential between the Edmonton Light Sweet oil price and the

WTI oil price at $US 3.65 per barrel on 1,000 bbl/d for 2016

Q4 2015 Avg Oil Price = $US 74.98/bbl 2016 Avg Oil Price = $US 59.16/bbl 2016 Avg Gas price = $CAD 2.97/Mcf

Hedging Program

200 400 600 800 1000 1200 1400 1600

BOE/D

Note: 1) Source: Company Reports; National Bank of Canada, “Producer Q3 Hedge Positions” issued on December 4, 2015.

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Management Experience

• Eagle’s management team has an average of 25 years of experience

Years 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30

Richard Clark Corporate Finance Law - Shiningbank Energy Trust General Counsel Corporate Finance Law Eagle - President & CEO Wayne Wisniewski Petroleum Engineering- Anders Energy, Occidental Petroleum Pennzoil E&P BP - Various Senior Leadership Engineering and Operations Roles Eagle - COO Kelly Tomyn Controller - Various Junior O&G Companies CFO - Various Junior O&G Companies Eagle - CFO Eric McFadden Co-head Investment Banking, Calgary - Scotia Capital Windpower Development

• CEO

EVP, Business Development - Superior Plus Eagle - VP, Capital Markets & BusDev Scott Lovett Senior Reserves Evaluator - GLJ Petroleum Consultants Business Development - Shiningbank Energy; Enerplus Business Development, COO - Native American Res. Ptnrs Eagle - VP, Corporate & BusDev Jo-Anne Bund Corporate Securities Lawyer at a Boutique Oil and Gas Firm Senior Legal Counsel - Alberta Securities Commission Corporate Securities Lawyer at a National Law Firm In-House Corporate Counsel Eagle - General Counsel & Corporate Secretary

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Value Proposition Why Invest in Eagle?

• Strong balance sheet
• Stable production base
• Capital discipline
• Experienced management team
• Sustainable monthly income

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APPENDIX

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Richard Clark, B.A. (Econ), LLB, Director, President and Chief Executive Officer

• 19 years in the legal profession as a founding partner at a boutique oil and

gas law firm, then 10 years at a Canadian national law firm, specializing in corporate finance, securities, M&A and venture capital

• Extensive experience in the royalty trust sector

Wayne Wisniewski, P.E., MBA, Chief Operating Officer (Houston)

• 30 years of oil and gas engineering and operations experience
• Last 13 years of career spent in a senior operations and engineering

management role in the Houston office of a major international E&P company

Kelly Tomyn, CA, Chief Financial Officer

• Former VP Finance and CFO for numerous public & private companies

with over 25 years of financial experience with E&P companies

• Former controller for Shiningbank

Continued..

Management

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Continued… Scott Lovett, M.Sc., MBA, P.Eng, Vice President, Corporate & Business

Development

• Over 18 years experience in the oil and gas industry, including

reservoir evaluations, acquisitions and divestments, business planning and strategic analysis

Eric McFadden, Vice President, Capital Markets & Business Development

• Over 25 years of experience in the corporate finance, capital

markets, management and business development industries, including eleven years in the energy industry

Jo-Anne Bund, B.A., LLB, General Counsel and Corporate Secretary

• 19 years of experience in corporate finance, securities, and M&A,

including with a national law firm, with a securities regulator and as in-house corporate counsel

Management

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David Fitzpatrick, P.Eng., Chairman

• President and Chief Executive Officer, Veresen Midstream
• Former Chief Executive Officer of Shiningbank

Bruce Gibson, CA, Chair of Audit Committee

• Former Chief Financial Officer of Shiningbank

Warren Steckley, P.Eng., Chair of Reserves and Governance Committee

• Former President and Chief Operating Officer, Barnwell of

Canada, Former Director of Shiningbank

Richard Clark, B.A. (Econ), LLB, Director

• President and Chief Executive Officer of Eagle; Former Director
• f Shiningbank

Board of Directors

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• Current working interest production of 3,600 boe/d
• 2016 production guidance is 3,400 to 3,800 boe/d (including 161 boe/d of working interest

production, but excluding 235 boe/d of royalty interest production from the acquisition of Maple Leaf)

Production History

Notes: 1) Q4/14 production is after the Permian asset disposition and before the Dixonville asset acquisition. 2) 2016 guidance on the chart is the mid-point of the full year 2016 guidance range and includes working interest production from the acquisition of Maple Leaf.

Q1/11 Q2/11 Q3/11 Q4/11 Q1/12 Q2/12 Q3/12 Q4/12 Q1/13 Q2/13 Q3/13 Q4/13 Q1/14 Q2/14 Q3/14 Q4/14 Q1/15 Q2/15 Q3/15 2016 Guidance Production 1,269 1,214 995 2,023 2,169 2,400 2,825 2,986 2,928 3,022 3,052 2,994 3,010 3,341 2,859 1,929 2,995 3,034 3,607 3,600 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000

Average WI Production per Quarter (boe/d)

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Contact

Kelly Tomyn, Chief Financial Officer

Tel: (403) 531-1574

Eric McFadden, Vice President, Capital Markets & Business Development

Tel: (587) 233-1799

Richard W. Clark, President and Chief Executive Officer

Tel: (403) 531-1575

Eagle Energy Inc. Eagle Hydrocarbons Inc.

2710, 500 – 4th Avenue SW 3005, 333 Clay Street Calgary, AB T2P 2V6 Houston, TX 77002 info@EagleEnergy.com www.EagleEnergy.com TSX: EGL

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