Permian Basin Oil & Liquids Focus IPAA OGIS New York April 16-17, 2012
Safe Harbor Disclosure This presentation contains statements expressing expectations of future plans, objectives, and performance that constitute forward-looking statements made pursuant to the Safe Harbor Provision of the Private Securities Litigation Reform Act of 1995. Unless noted, these statements do not reflect possible or pending acquisitions, divestitures, or restructurings. Statements based on expectations are forward-looking statements that are dependent on certain events, risks, and uncertainties that could cause actual results to differ materially from those anticipated. A discussion of risks and uncertainties may be found in the Company s periodic reports filed with the SEC. 1
Today s Energen Top 20 independent producer of domestic oil, NGL & natural gas 3P reserves: >900 MMBOE Permian Basin/liquids focus Financial strength and capacity to drill & develop Permian assets Hedging program that supports predictable cash flows * Based on North American Proved Reserves at YE10, Bloomberg 2
Top 20 Independent Producer* 343 MMBOE of proved reserves at YE2011 Onshore domestic driller San Juan Basin: 130 MMBOE (38%) CO Farmington Black Warrior Basin: 23 MMBOE (7%) 591 MMBOE of unproved reserves at 3/31/11 Major presence in 3 largest areas of operation NM Midland Permian Basin: 184 MMBOE (54%) TX Arcadia Birmingham N. LA/E. TX/Other: 6 MMBOE (1%) * Based on North American Proved Reserves at YE10, Bloomberg 3
YE Proved Reserves Up 13% Proved Reserves Mix Proved Reserves by Basin MMBOE 400 350 300 250 200 150 258 30 78 303 41 103 343 54 130 MMBOE 400 350 300 250 200 150 258 34 132 303 34 136 343 30 129 100 50 150 159 160 100 50 92 133 184 0 2009 2010 2011 Gas Oil Liquids 0 2009 2010 2011 Permian San Juan Other 4
2012 E&P Capital, Drilling Plans Record Capital Investment (existing properties): $890 MM 95% in Permian Basin 34% 16% 4% Wolfberry - $415 MM 46% Delaware Basin - $300 MM Other Permian - $140 MM San Juan - $35 MM Wolfberry Play 7-8 rigs 170 net wells Est. production: 4.2 MMBOE Delaware Basin Trends 5-7 rigs 39 net wells Est. production: 2.1 MMBOE Other Permian Basin 1-2 rigs 119 net wells* Est. production: 5 MMBOE San Juan Basin 1-2 rigs first half of 2012 8 net wells Est. production : 9.9 MMBOE * Includes 33 injector wells 5
Liquids Focus Drives Growth Production (MMBOE) 11.0 10.0 9.0 8.0 7.0 6.0 5.0 4.0 3.0 2.0 1.0 2.3 4.2 0.6 2.1 4.9 5.0 9.6 9.9 3.0 2.8 30.0 25.0 20.0 15.0 10.0 5.0 20.5 18.8 25.0-27.0 24.0 3.2 2.8 2.2 1.9 8.5 10.3 5.1 6.3 11.8 12.0 12.7 12.5 52% 48% 0.0 Wolfberry Delaware Basin Other Permian San Juan Basin Other 0.0 2010 2011 2012e 2013e* 2011 2012e Gas Oil Liquids * 2013e production graphed at midpoint of guidance range 6
Preliminary 2013 E&P Plans Capital investment : $855 MM More than 85% in Permian Basin Wolfberry 7-8 rigs 170 net wells Delaware Basin 5 rigs 31 net wells Other Permian 1-2 rigs 83 wells* 3-Year Growth CAGR Aggregate Oil 25-27% 96-106% NGL 16-23% 58-84% Total Liquids 23-26% 86-100% Natural Gas 1-3% 2-10% TOTAL 10-13% 33-44% San Juan 1-2 rigs 45 wells * Includes 34 injector wells 7
PERMIAN OVERVIEW 6 major acquisitions 2009-11 $65.8 MM acquisition in February 2012 Midland Basin Wolfberry Delaware Basin 3 rd Bone Spring Wolfcamp shale Avalon shale Wolfbone Pre-acquisition Producing Properties Recently Acquired Properties 2012 Acquisition Northwest Shelf eddy Delaware Basin reeves lea Avalon, 3rd Bone Spring, Wolfcamp, loving Wolfbone Trends Hobbs ward winkler yoakum gaines andrews Odessa Central Basin Platform Midland Basin Midland dawson martin midland upton borden howard glasscock Wolfberry Play reagan Eastern Shelf mitchell Central Basin Platform: San Andres (Fuhrman-Mascho) Waterfloods Diablo Platform Sheffield Channel Southern Shelf pecos Marathon-Ouachita Fad Belt Ozona Arch Val Verde Basin 8
Midland Basin Strata NW SE Upper Lower Platform Carbonates Platform detrital carbonates Limestones Sandy siltstones Shale siltstones Shale 9
Midland Basin WOLFBERRY PLAY Multi-stage fracs (6-8) Completion interval: 7,500-10,500 Gaines Dawson Borden Andrews Martin Howard EUR: 155 MBOE NRI: 75% 2012 drill & complete cost: $2.3 MM Avg. product mix (basin-wide): 63% oil/25% NGL/12% gas 34,600 net undeveloped acres; 865 potential locations on 40-acre spacing Midland Midland Upton ERC acreage 2012 acquisition Glasscock Reagan 10
7,550 7,875 8,050 8,450 8,900 9,1 00 9,600 10,200 10,600 11,900 Top of Bone Spring Upper Avalon Shale Avalon Carbonate Lower Avalon Shale 1 st Bone Spring Carbonate 1 st Bone Spring Sands 2 nd Bone Spring Carbonate 2nd Bone Spring Sands 3rd Bone Spring Carbonate 3rd Bone Spring Sands Upper Wolfcamp Lower Wolfcamp Base Wolfcamp Delaware Basin Strata Western Shelf W Central Basin Platform Platform Shelf Carbonates Carbonates Sandstones Sandstones and Siltstones Shale E 11
Delaware Basin 20 net 3rd Bone Spring wells completed in 2011 LOVING ERC acreage NM TX WINKLER 3RD BONE SPRING SANDS Multi-stage fracs (8-10) EUR: 400-450 MBOE NRI: 75% 2012 drill & complete cost: $7.5 MM Weighted avg. product mix (basin-wide): 57% oil/21% NGL/22% gas 68,000 net undeveloped acres; 210 potential locations on 320-acre spacing Avalon/Wolfcamp Area of Interest REEVES WARD 3 rd Bone Spring Area of Interest WOLFCAMP & AVALON SHALES 110,000 net undeveloped acres; 340 potential locations on 320-acre spacing in each trend 12
Exploration Option Acreage BHP Billiton buys 50% undivided interest in 3 wells - $18 MM After initiating horizontal completions on 2 wells, BHP will own 50% undivided interest in 4,829 net acres ERC Retained Acreage Exploration Option Acreage Producing Formation Excluded BHP-Operated AMI ERC-Operated AMI Wells Purchased by BHP REEVES WARD BHP will carry Energen in completion operations of the 2 wells BHP has option to purchase 50% undivided interest in 51,720 net acres by May 1, 2012 If BHP exercises purchase option, Energen expects to recoup its investment in the acreage while still retaining 50% interest 13
NIOBRARA SHALE HBP Long-term Optionality La Plata Durango Niobrara Shale Gas Archuleta Gas phase 58,500 net undeveloped acres 854 Bcfe of possible reserves Oil phase 54,000 net undeveloped acres Williams Farmington Niobrara Shale Oil San Juan Rio Arriba Black Hills (EGN 20% WI) Sandoval Enervest 51.5 MMBOE of possible reserves Niobrara wells (horizontal) drilled by other operators ERC acreage 14
After-tax Cash Flows ASSUMPTIONS Production: 24 MMBOE 63% hedged 17% total growth 33% liquids growth $900 $800 $700 $600 $576 $697 $696 $764- $793 Unhedged price assumptions: $3.00 gas, $95 oil, $1.11 NGL $MM $500 $400 Est. expenses/boe: $300 LOE: $9.47 $200 Prod. Taxes $2.41 $100 DD&A: $15.34 G&A: $2.93 Interest : $2.01 $0 2009 2010 2011 2012e Utility E&P Range 15
HEDGING MINIMIZES PRICE RISK 63% of 2012(e) production hedged 2012(e) cash costs: $15/BOE 2012 (e) net income break-even: $30/BOE Hedged Volumes 2012 Estimated Production Hedge % NYMEXe Price Oil 6.9 MMBO 8.5 MMBO 82% $ 88.13 NGL 58.5 MMgal 117.9 MMgal 50% $ 0.98 Gas 40.5 Bcf 76.5 Bcf 53% $ 4.86 50% NGL Hedged at $0.98 Hedge Volumes 2013 Estimated Production NYMEXe Price 82% Oil Hedged at NYMEXe $88.13 53% Gas Hedged at NYMEXe $4.86 Oil 8.1 MMBO 10.0-10.5 MMBO $ 90.52 NGL 44.5 MMgal 126.0-147.0 MMgal $ 1.02 Gas 38.9 Bcf 72.0-78.0 Bcf $ 5.04 2014 Hedge Volumes NYMEXe Price 2012 Oil 7.1 MMBO $ 91.75 Gas 29.8 Bcf $ 5.07 16
UTILITY OPERATIONS Single-state utility >425,000 customers Allowed ROE: 13.15-13.65% Forward-looking test year Temperature adjustment Birmingham Montgomery RY ROE(%) 2007 2008 2009 2010 2011 Allowed 13.15-13.65 Earned 13.3 13.1 13.3 13.5 13.3 17
30 YEARS OF DIVIDEND GROWTH 2012 dividend raised 3.7% Alagasco funds dividend at utility payout 65% ERC may make small payout contribution Annual Dividend Rate $0.80 $0.60 $0.40 $0.54 $0.56 $0.46 $0.48 $0.50 $0.52 $0.20 $0.00 2007 2008 2009 2010 2011 2012 18
ENERGEN: IN SUMMARY Liquids-focused Significant Hedges Strong Cash Flows Excellent Fundamentals Proven Track Record 19
ATCF RECONCILIATION TO GAAP ENERGEN Years Ended 12/31 ($ in millions) 2010 2011 2012e Net income (GAAP) $ 291 $ 260 $ 228 - $ 257 DD&A $ 248 $ 284 $ 415 - $ 415 Deferred income taxes, net $ 134 $ 129 $ 121 - $ 126 Other $ 67 $ 64 - After-tax cash flows (Non-GAAP) $740 $ 737 $ 764 - $ 793 Changes in assets & liabilities and other $ (69) $ 25 $ (13) - $ (13) Net cash provided by operating activities (GAAP) $ 671 $ 762 $ 751 - $ 780 Note: 2012e data constitute forward-looking statements The U.S. Securities and Exchange Commission (SEC) requires public companies to reconcile Non-GAAP financial measures to related GAAP measures. GAAP refers to generally accepted accounting principles. After-tax Cash Flow (ATCF) is a Non-GAAP financial measure. Energen believes ATCF is relevant as a measure of cash available to fund its capital expenditures, dividends, debt reduction, and other investments. 20
E&P ATCF RECONCILIATION ENERGEN Years Ended 12/31 ($ in millions) 2010 2011 2012e Net income (GAAP) $ 291 $ 260 $ 228 - $ 257 DD&A $ 248 $ 284 $ 415 - $ 415 Deferred income taxes, net $ 134 $ 129 $ 121 - $ 126 Other $ 67 $ 64 - After-tax cash flows (Non-GAAP) $ 740 $ 737 $ 764 - $ 793 Less: AGC cash flows from operations $(120) $ (115) $ (100) - $ (100) Adj. cash flows from ops excl. AGC (Non-GAAP) $ 620 $ 622 $ 664 - $ 693 Note: 2012e data constitute forward-looking statements The U.S. Securities and Exchange Commission (SEC) requires public companies to reconcile Non-GAAP financial measures to related GAAP measures. GAAP refers to generally accepted accounting principles. After-tax Cash Flow (ATCF) is a Non-GAAP financial measure. Energen believes ATCF is relevant as a measure of cash available to fund its capital expenditures, dividends, debt reduction, and other investments. 21
FOR MORE INFORMATION Julie S. Ryland Vice President Investor Relations 205-326-8421 jryland@energen.com www.energen.com 22