The data contained in this presentation that are not historical facts are forward-looking statements within the meaning of the Private Securities

Transcription

1 April 17,

2 The data contained in this presentation that are not historical facts are forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995, Section 27A of the Securities Act and Section 21E of the Exchange Act. Such statements may relate to capital expenditures, drilling and exploitation activities, production efforts and sales volumes, proved, probable, and possible reserves, operating and administrative costs, future operating or financial results, cash flow and anticipated liquidity, business strategy, property acquisitions, and the availability of drilling rigs and other oil field equipment and services. These forward-looking statements are generally accompanied by words such as estimated, projected, potential, anticipated, forecasted or other words that convey the uncertainty of future events or outcomes. Although we believe the expectations and forecasts reflected in these and other forward-looking statements are reasonable, we can give no assurance they will prove to have been correct. These statements are based on our current plans and assumptions and are subject to a number of risks and uncertainties as further outlined in our most recent 10-K and 10-Q. Therefore, the actual results may differ materially from the expectations, estimates or assumptions expressed in or implied by any forward-looking statement made by or on behalf of the Company. Cautionary Note to U.S. Investors The SEC has recently modified its rules regarding oil and gas reserve information that may be included in filings with the SEC. The newly applicable rules allow oil and gas companies to disclose not only proved reserves, but also probable and possible reserves that meet the SEC s definitions of such terms. We disclose proved, probable and possible reserves in our filings with the SEC. Our reserves as of June 30, 2011 were estimated by DeGolyer & MacNaughton, W.D Von Gonten & Co. ( Von Gonten ), and Lee Keeling and Associates, Inc. ( Keeling ), independent petroleum engineering firms. In this presentation, we make reference to probable reserves. These estimates are by their nature more speculative than estimates of proved reserves and are subject to greater uncertainties, and accordingly the likelihood of recovering those reserves is subject to substantially greater risk. 2

3 Four Factors for Repeating Success and Building Value per Share Every Day Oil-Weighted Assets Building Value per Share Known Oil & Gas Fields Innovation Engineering 3

4 Name/Title Background Achievements Robert Herlin CEO & Chairman Sterling McDonald Chief Financial Officer Daryl Mazzanti VP-Operations Edward Schell General Manager for Drilling and Unconventional Development Co-founded EPM in 2003 using $8.3 MM in capital (multiple raises). B.S. and M.E. Chemical Engineering, Rice University. MBA, Harvard Joined EPM B.S. and MBA (University of Tulsa) Joined EPM mid-2005 B.S. Petroleum Engineering, Univ. of Oklahoma Joined EPM in 2006 B.S. in Petroleum Engineering, University of Texas 30 years leadership experience in M&A, development, operations and finance in public and private sectors. Former CFO for PetroAmerican Services, PetroStar Energy and Treasurer for Reading & Bates Corporation. Former Manager of US Business Development for Anadarko. Former Production Manager, Austin Chalk for Anadarko/UPRC responsible for 1200 wells, staff of 65 and 25,000 BOEPD of production. Innovator in horizontal drilling 30 years experience in oil & gas industry. Management positions in drilling, operations and business development with Anadarko Petroleum. Drilled 800 wells, 200 of them horizontal and 2/3 rd in unconventional reservoirs. 4

5 Total Value, $MM $500 Transformed $8.3 MM Investment into $461 MM Value $461 MM $400 $300 $200 $100 $0 -$100 Investment Cash Proved PV10 Delhi (1) Probable PV10 Delhi (1) Proved PV10 Giddings (2) Proved PV10 Lopez Total Value Notes: (1) Delhi PV10 values based on report from independent reserve engineers, DeGolyer & MacNaughton, and includes proved and probable reserves as of 6/30/2011 at SEC pricing of $94.81/bbl. (2) Giddings properties are being evaluated for monetization. 5

6 MMBoe 25 Reserves (84% Oil) $M $8,000 Revenue (Years ended June 30) $7, $6, $5,000 $4, $3,000 5 $2,000 $1,000 0 $0 Proved PUD Probable 6

7 $M $5,000 $4,500 $4,000 Quarterly Revenue $M $1,400 $1,200 Quarterly Net Income to Common $3,500 $1,000 $3,000 $2,500 $800 $2,000 $600 $1,500 $1,000 $400 $500 $200 $0 $0 7

8 S Lopez Field Producing Vertical redevelopment of previous waterflood, 100% oil Delhi Field - Producing CO 2 EOR - 100% oil 10.9 MMBO Proved 5.8 MMBO Probable 41% of 2P is developed producing Giddings Field Producing Horizontal wells in naturally fractured Austin Chalk, Georgetown, Buda plus Woodbine potential. 2.7 MMBOE Proved, 15% developed and 47% oil & NGL 8

9 13.8 MMBOE Proved Reserves $MM $400 SEC PV10 $375.3 $350 5% 11% $300 $266.0 $250 $200 $150 84% $100 $50 $35.8 Oil NGL Natural Gas $

10 Application of Strengths to Grow Oil Production, Reserves and Value

11 Phase 1: Form the Base Acquired and farmed-out Delhi, commenced EOR. Phase 2: Positioning for Growth Delhi net proceeds reinvested into shale gas and oil projects. Breakeven cash flow and no earnings. Phase 3: Invest for Growth Delhi and Giddings cash flow reinvested into oil projects and GARP technology. Growing operating cash flow and earnings. Phase 4: Consistent Growth Ongoing development drilling to grow production, reserves and cash flow. Grow the franchise. Negative cash flow and no earnings. 11

12 2012 $ S. Texas Oil Expansion 2013 $ 2014 $ Cash to be Redeployed New Oil Project 2015 $ GARP 12

13 Oil Weighted Onshore US Engineering Driven HZ Drilling Potential Repeatable Results Known Oil & Gas Fields New Oily Asset(s) to Grow Value Per-Share 13

14 Our Foundation Asset CO 2 Enhanced Oil Recovery

15 Gross cum production Low-Risk Cash Flow for Reinvestment into Growth Assets 192 MMBO Current production >5,000 BOPD Jackson Dome Reserves Projected EOR recovery (% of OOIP) Unit size Tax preferences Acquired by EPM in 2006 Acquired royalty in MMBO Proved 5.8 MMBO Probable (41% of 2P producing) 30% of 2P from royalty interest & free of exp. 13% Proved (PV10: $334 MM) 4% Probable ($ 73 MM) 13,366 acres Severance tax holiday Acquired for $2.8 MM Invested $2.5 MM Paid $1.5 MM Delhi Farm-out to DNR in 2006 Upside Potential Received $50 MM + EOR Development + Reversionary interest More OOIP Higher EOR % recovery similar to other DNR projects Utilization of lower cost (CO 2 + water) injection process 15

16 7.4% Royalty Interest EPM receives 7.4% of gross revenues No Cap Ex or Op Ex forever Exempt from state severance tax until project payout of all actual costs plus capital cost Royalty interest = 30% of total Delhi reserves volumes Delhi crude priced at LA Light Sweet (premium to WTI) 23.9% Reversionary Working Interest Calendar YE 2013 payout = projected net field cumulative cash flow of $200 million Net field cash flow = revenue minus field Op Ex (including CO 2 ) After payout, EPM bears pro-rata CapEx and Op Ex and will own proportional field assets, reserves and purchased CO 2 EPM projected to bear ~$12.7 MM total CapEx for proved reserves APO Free Cash Flow 16

17 $MM $80 $70 $60 $50 $40 $30 $20 $10 $ Royalty Reversionary WI Note: Based on report from independent reserve engineers, DeGolyer & MacNaughton, and includes proved and probable reserves as of 6/30/2011 at SEC pricing of $94.81/bbl. LLS at $ on 4/11/

18 $MM $900 $800 $700 $600 $500 $400 $300 $200 $100 $ Remaining PV10 Cum Pretax Notes: Residual PV10 is the PV10 of remaining cash flows from given year to project end. Includes proved and probable reserves from independent report of 6/30/2011 at SEC pricing of $94.81/bbl. LLS at $ on 4/11/

19 Impact of Additional EOR Recovery on EPM Share Price Oil Price Impact on EPM Share Price $/ diluted share $14 $13 $12 $11 $10 $9 1P PV10* vs Gross Oil Recovery (flat pricing) 2P (4/11/2012) $ / diluted share $20 $16 $12 $8 $4 PV10* vs 2012 Oil Price 2P PV10 3% inflation 2P PV10 SEC Flat $ $ Gross Recovery in MMBO $- $- $20 $40 $60 $80 $ Oil Price * From independent report of 6/30/2011 including proved and probable reserves at SEC pricing of $94.81/bbl. Escalated pricing analysis begins with 6/30/11 SEC price. Diluted shares include 5.5 MM options and warrants without effect of exercise proceeds. 19

20 Growing Per-Share Value

21 Oily Texas, Oklahoma or Kansas location Utilizes our horizontal drilling expertise Cost per well ~$3MM Running room with multi-year development Investment sink for Delhi cash flow develop >>1 barrel of oil reserves from 1 barrel of Delhi production 21

22 Mirando sandstone within previous waterflood Moving from test phase into development phase, despite ongoing challenges in re-injecting produced water Developing BOPD per well of long life, low decline production at a cost of $550K per well, or $35K to $68K per net BOPD 3 test producers drilled to date to confirm oil cut and capability of high fluid rate production and injection Goal and upside is in expanding from current 40 drilling locations to similar nearby fields with hundreds of potential drilling locations 22

23 8,560 net acres Net production ~205 BOEPD from ten wells Proved undeveloped reserves in 11 drilling locations Reserves in Georgetown, Austin Chalk and Buda formations Exposure to new Woodbine oil play Transitional asset, evaluating divestment options due to lack of running room to redeploy Delhi cash flow and >50% gas content 23

24 Innovation for Increasing Recovery

25 Reestablishes economic production of the Tail Supplements & enhances existing rod pump Mobilizes remaining fluid to rod pump inlet Successful applications in Giddings Field Two field tests underway Fee/participation for service model 25

26 BEFORE: Conventional Rod Pump Either fluid level eventually drops to a level where rod pump or gas lift are no longer effective, or Fluid production in gas well builds and eventually shuts off gas production This can leave substantial volumes of oil and gas unrecovered (the Tail ) AFTER: GARP Adds substantial new reserves at low cost Benefit = up to 25% incremental recovery Benefit = extends life of lease(s) Cost $75K - $150K per application Patented 26

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28 Conservative, Strong and Aligned

29 EPM AREX REN MHR WRES DNR PQ 45% 40% 35% 30% 25% Debt to Market Cap 33% 29% 26% 24% 40% $MM $25 $20 $15 Liquidity Sources & Uses $5 $5 CFFO Availability 20% 15% 10% 5% 0% 0% 11% $10 $5 $- $14 Resources 12/31/11 W/C $7 $4 CapEx (2012E) Potential Current 29

30 Total Value, $MM $500 $461 MM $400 $300 $212 MM Gap to NAV $249 MM $200 $100 $0 -$100 Investment Cash Proved PV10 Delhi (1) Probable PV10 Delhi (1) Proved PV10 Giddings (2) Proved PV10 Lopez LLS at $ on 4/11/2012 Total Value Market Cap (4/11/12) (3) Notes: (1) Delhi PV10 values based on report from independent reserve engineers, DeGolyer & MacNaughton, and includes proved and probable reserves as of 6/30/2011 at SEC pricing of $94.81/bbl. (2) Giddings properties are being evaluated for monetization. (3) Market capitalization based on MM shares outstanding. 30

31 Total Value Per Share $16 $14 $13.89 $12 $10 $4.93 Gap to NAV $8.96 $8 $6 $4 $2 $0 -$2 Investment Cash Proved PV10 Delhi Probable PV10 Delhi Proved PV10 Giddings Proved PV10 Lopez Total Value Share Price (4/11/12) Note: Per-share values are based on 33.2 MM diluted shares.. PV10 from 6/30/11 reserves report, Delhi at $94.81/bbl. LLS at $ on 4/11/

32 Team with track record of growing value per-share Growing value and cash flow at Delhi foundation asset (100% LLS oil) $212 MM value gap between intrinsic value and market value (or $4.93 per diluted share) Pending exposure to new oil play GARP upside from synergistic incremental recovery Low financial risk with no debt balance sheet aligned with business strategy Reinvesting cash flow into oil growth assets Management owns 19% of diluted shares leadership aligned with shareholders 32