2012 Wells Fargo Securities Research & Economics 11 th Annual Pipeline, MLP & Energy Symposium. December 4, 2012
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1 2012 Wells Fargo Securities Research & Economics 11 th Annual Pipeline, MLP & Energy Symposium December 4, 2012
2 Risks and Forward-Looking Statements This presentation includes forward-looking statements as defined by the Securities and Exchange Commission. All statements, other than statements of historical facts, included in this presentation that address activities, events or developments that the partnership expects, believes or anticipates will or may occur in the future are forward-looking statements. Words such as anticipates, intends, plans, projects, believes, and similar words are intended to identify such forward-looking statements. These statements are based on certain assumptions made by the partnership based on its experience and perception of historical trends, current conditions, expected future developments and other factors it believes are appropriate in the circumstances. Such statements are subject to a number of assumptions, risks and uncertainties, many of which are beyond the control of the partnership, which may cause our actual results to differ materially from those implied or expressed by the forward-looking statements. These include risks relating to financial performance and results, availability of sufficient cash flow to pay distributions and execute our business plan, prices and demand for natural gas and oil, our ability to replace reserves and efficiently develop and produce our current reserves and other important factors that could cause actual results to differ materially from those projected as described in more detail in our reports filed with the Securities and Exchange Commission, which are available at or on our web site, or by calling us at We undertake no obligation to publicly update any forward-looking statements, whether as a result of new information or future events. Investors are urged to consider closely the disclosure in our Form 10-K, available from us at or from the SEC at 2
3 Why EV Energy Partners? Proven Track Record in Acquisitions Multiple Acquisition Sources EnerVest Provides Operating Leverage and Scale in Multiple l Basins Diverse Set of Properties with Organic Growth Potential Capital a Structure, u Hedging g and Financing Philosophies Utica Shale Upside 3
4 EVEP Performance IPO to Date Upstream MLP Created in September 2006 (Nasdaq: EVEP) GP Ownership EnerVest & Management (76.25%) Encap (23.75%) 42.3 million outstanding units $3.4 billion enterprise value Strong balance sheet Current yield of 5.1% Solid returns since IPO Total return 287% Compound annual rate of return 29% Note: Current yield based on $0.766/unit 3Q12 distribution paid on Nov. 14, Includes 3,873,357 Class B Units. Unit price as of Nov. 28, 2012 and AMZX as of Nov. 23,
5 Diverse Asset Base Total Proved Reserves: 1,144 Bcfe Percent Developed: 68% Percent Gas: 71% 3Q12 Avg. Production: MMcfe/d Reserve-Life Index: 19 years Gross Productive Wells: Over 18,000 Michigan Proved Reserves: 44.9 Bcfe San Juan Basin Proved Reserves: 68.6 Bcfe Mid-Continent Proved Reserves: 81.2 Bcfe Appalachian Basin Proved Reserves: Bcfe Permian Basin Proved Reserves: 54.1 Bcfe Monroe Field Proved Reserves: 60.9 Bcfe Barnett Shale Proved Reserves: Bcfe Central and East Texas Proved Reserves: 60.9 Bcfe 5
6 A Strong Strategic Partnership with EnerVest EVEP EnerVest Institutional EnerVest is recognized as one of the largest and most successful managers of oil and gas assets for institutional investors Sizeable EnerVest operating base ~ 3.8 Tcfe of Proved Reserves > 515 Mmcfe daily production million gross acres under lease Over $6.8 billion of acquisitions since inception > 800 employees EnerVest currently investing $1.5 billion Fund XII EnerVest operates 93% of EVEP s assets 6
7 Disciplined Acquirer Since 2007 Since 2011 Since 2007 Since 2011 Since 2007 Since 2011 (Since 1/1/2007) EVEP Upstream MLPs¹ Number of Deals: Total ($b): $1.8 $18.3 R/P Ratio: ¹Source: Wells Fargo Securities, LLC. (Excludes EVEP) and company press releases from 1/1/2007 to 11/27/2012 ²Source: Royal Bank of Canada onshore US acquisitions greater than $20mm from 1/1/2007 to 8/20/2012 7
8 Diversification, Growth and Resource Play Entry September 2006 (at IPO) December 31, 2011 Appalachia Appalachia 11% 69% Monroe 31% 51 Bcfe 2 Basins 1,144 Bcfe 8 Basins 8
9 2012 Organic Growth Activity Appalachian Basin: Ongoing CHK JV activity Initial EnerVest Utica Drilling Potential Utica Monetization/Swap Ongoing Knox Activity Mid Continent: Continuing Granite Wash, Cleveland and Cano/Woodford Drilling Barnett Shale: 3-5 Rig Drilling Program Austin Chalk: 1-2 Rig Drilling Program Horizontal and Multistage Fracs 9
10 Resource Plays Creating Opportunities for MLPs Private Equity Private Equity Source: RBC Richardson Barr 10
11 Barnett Shale EVEP / EnerVest is a Top 6 Barnett Shale Producer Reserves Located primarily in core and combo areas 647 Bcfe Proved Reserves 72% natural gas / 28% liquids 52% Proved Developed Current net production: ~ 72 Mmcfe/d Reserve-life index: 26 years Over 1,000 active wells and over 700 PUDS (~ 99% Operated) Actively drilling and permitting ~ $70 million capital budget Joint purchases with EnerVest Institutional Partnerships totaling over $2.2 billion since December 2010 $695 million net to EVEP EVEP Acreage Acreage Position ~ 113,000 gross acres (~ 32,000 net acres) 29% average WI 11
12 EVEP Utica Shale Position EnerVest entities control 1.2 million gross acres Over 700,000 net acres ~ 60% operated by EnerVest Legend EVEP JV Acreage EVEP Non-JV Acreage EnerVest Fund Acreage EVEP net Utica leasehold Over 150,000 net WI acres ~ 20,000 net acres in CHK JV (Blue) ~ 130, non-jv net acres (Red)» EnerVest operated Average 2% ORRI on ~ 880,000 gross acres Average 1.3% ORRI on 460,000 gross acres associated with CHK JV (Blue) Average 2.7% ORRI on 420,000 non-jv gross acres (Red) 12
13 Utica Shale Activity & EVEP Strategy Overall Utica Activity 458 permitted wells 29 active rigs 186 spud wells 45 producing wells EVEP Strategy Current monetization process for part of Utica Shale working interest position Maintain ORRI s Continue midstream implementation Cardinal Gas Services gathering Utica East Ohio pipeline, processing and fractionation 13
14 Midstream Activity Ramping Up ~2 BCF/d proposed processing projects 4Q12- YE14 Ethane takeaway capacity ATEX to Gulf Coast Marine West & East to Canada Liquids takeaway capacity Boardwalk Williams Residue Gas M3 Processing: 600 MMcf/d NGL Storage: 870 MBBL/d Frac Capacity: 90 MBBL/d Ethane: ATEX Residue: TPG, DEO In Service: 2Q 2013 MarkWest Existing Frac - Houston PA Processing: 325 MMcf/d Frac Capacity: 100 MBBL/d Ethane: MARINER WEST & MARINER Residue: TETCO, DTI, TCO In Service: 1Q 2014 Mariner West Deliver Ethane from SUNOCO to SARNIA Design: 65 MBBL/d In Service: Mid 2013 NiSource/Hilcorp Processing: 200 MMcf/d Residue: TETCO, REX, NiSource In Service: 3Q 2013 Shell Cracker Proposed Caiman Processing: 520 MMcf/d Frac Capacity: 43 MBBL/d Ethane: MARINER WEST Residue: TETCO In Service: 4Q 2012 Sunoco Delmont PA to MARINER WEST ATEX Washington PA to Mont Belvieu In Service: 1Q 2014 MarkWest/Antero Processing: 45,000; 200,000; 400,000 MMcf/d Frac Capacity: To Harrison Complex Ethane: ATEX In Service 2Q 2013; 3Q 2013; 4Q 2013 DTI Processing: 200 MMcf/d; 400 MMcf/d Frac Capacity: 36 MBBL/d; 59 MBBL/d Ethane: ATEX Residue: DTI In Service: 12/2012; 3Q
15 EVEP Midstream Activities Cardinal Gas Services Gather low pressure wet gas from JV wells Deliver to UEO plants Partners with CHK (Access) & Total EVEP at 9% ~$1.2 billion investment over 3 years Utica East Ohio 600 Mmcfe/d capacity high pressure gathering, processing and fractionation Partners with Momentum & CHK (Access) EVEP at 8%, up to 21% ~$1 billion investment t over 3 years 1st phase operational June
16 Capital Structure ($ millions) Bank 9/30 $ 320 Senior Notes Due 2019 $ 500 Equity Market Capitalization $ 2,567 Enterprise Value $ 3,387 Note: Equity market capitalization based on unit price at November 28, Includes 3,873,357 Class B Units. 16
17 Disciplined Financing Strategy Since 2006, completed $1.9 billion of acquisitions, approximately 60% of which were financed with equity and free cash flow Capital Activity (1) Acquisition Financing Since IPO Equity $1,027 54% Free Cash Flow $94 4% Debt Financing $797 42% Total Acquisitions $1, % = Equity = Debt = Free Cash Flow (1) Total dollar amounts represent acquisition activity by period. 17
18 Commodity Hedging Hedges used to reduce the effects of commodity price volatility and support initial acquisition economics We are approximately hedged 91% for the remainder of 2012, 81% for 2013, 40% for 2014 and 27% for 2015 Note: Percentage hedged based on the midpoint of 4Q12 production guidance. 18
19 Commodity Hedging: Natural Gas Gas Volume Hedged (MMbtu/d) Gas Prices Hedged ($/MMbtu) Note: Estimated NYMEX Henry Hub equivalent with basis differentials of: Dominion Appalachia $0.18, MichCon Citygate $0.27, Houston Ship Channel ($0.05) and El Paso Permian ($0.27), El Paso San Juan ($0.35), NGPL TX/OK ($0.12) and TCO $
20 Commodity Hedging: Oil Oil Volume Hedged (Bbl/d) Oil Prices Hedged ($/Bbl) 20
21 Commodity Hedging: NGLs Ethane Volume Hedged (Bbl/d) Propane Volume Hedged (Bbl/d) 2,500 2,500 2,000 $ ,000 1,500 1,500 1,000 2,000 1,000 $ ,000-4q12-4q12 Swap Volumes Swap Volumes 21
22 Why EV Energy Partners? Proven Track Record in Acquisitions Multiple Acquisition Sources EnerVest Provides Operating Leverage and Scale in Multiple l Basins Diverse Set of Properties with Organic Growth Potential Capital a Structure, u Hedging g and Financing Philosophies Utica Shale Upside 22
23 2012 Wells Fargo Securities Research & Economics 11 th Annual Pipeline, MLP & Energy Symposium December 4, 2012
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