el paso 04_08fosheehowardweil(web)2
TRANSCRIPT
a meaningful companydoing meaningful workdelivering meaningful results
Doug FosheePresident and Chief Executive Officer
Howard Weil Energy ConferenceApril 8, 2008
22
Cautionary StatementRegarding Forward-looking Statements
This presentation includes forward-looking statements and projections, made in reliance on the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. The company has made every reasonable effort to ensure that the information and assumptions on which these statements and projections are based are current, reasonable, and complete. However, a variety of factors could cause actual results to differ materially from the projections, anticipated results or other expectations expressed in this presentation, including, without limitation, changes in unaudited and/or unreviewed financial information; our ability to implement and achieve our objectives in the 2008 plan, including earnings and cash flow targets; the effects of any changes in accounting rules and guidance; our ability to meet production volume targets in our E&P segment; uncertainties and potential consequences associated with the outcome of governmental investigations, including, without limitation, those related to the reserve revisions; outcome of litigation; our ability to comply with the covenants in our various financing documents; our ability to obtain necessary governmental approvals for proposed pipeline projects and our ability to successfully construct and operate such projects; the risks associated with recontracting of transportation commitments by our pipelines; regulatory uncertainties associated with pipeline rate cases; actions by the credit rating agencies; the successful close of our financing transactions; our ability to successfully exit the energy trading business; our ability to close our announced asset sales on a timely basis; changes in commodity prices and basis differentials for oil, natural gas, and power and relevant basis spreads; inability to realize anticipated synergies and cost savings associated with restructurings and divestitures on a timely basis; general economic and weather conditions in geographic regions or markets served by the company and its affiliates, or where operations of the company and its affiliates are located; the uncertainties associated with governmental regulation; political and currency risks associated with international operations of the company and its affiliates; competition; and other factors described in the company’s (and its affiliates’) Securities and Exchange Commission filings. While the company makes these statements and projections in good faith, neither the company nor its management can guarantee that anticipated future results will be achieved. Reference must be made to those filings for additional important factors that may affect actual results. The company assumes no obligation to publicly update or revise any forward-looking statements made herein or any other forward-looking statements made by the company, whether as a result of new information, future events, or otherwise.
Certain of the production information in this presentation include the production attributable to El Paso’s 49 percent interest in Four Star Oil & Gas Company (“Four Star”). El Paso’s Supplemental Oil and Gas disclosures, which are included in its Annual Report on Form 10-K, reflect its proportionate share of the proved reserves of Four Star separate from its consolidated proved reserves. In addition, the proved reserves attributable to its proportionate share of Four Star represent estimates prepared by El Paso and not those of Four Star.
Cautionary Note to U.S. Investors—The United States Securities and Exchange Commission permits oil and gas companies, in their filings with the SEC, to disclose only proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. We use certain terms in this presentation that the SEC's guidelines strictly prohibit us from including in filings with the SEC. U.S. Investors are urged to consider closely the disclosures regarding proved reserves in this presentation and the disclosures contained in our Form 10-K for the year ended December 31, 2007, File No. 001-14365, available by writing; Investor Relations, El Paso Corporation, 1001 Louisiana St., Houston, TX 77002. You can also obtain this form from the SEC by calling 1-800-SEC-0330.
Non-GAAP Financial MeasuresThis presentation includes certain Non-GAAP financial measures as defined in the SEC’s Regulation G. More information on these Non-GAAP financial measures, including EBIT and the required reconciliations under Regulation G, are set forth in this presentation or in the appendix hereto. El Paso defines Resource Potential as subsurface volumes of oil and natural gas the company believes may be present and eventually recoverable. The company utilizes a net, geologic risk mean to represent this estimated ultimate recoverable amount.
33
Sustainable Long-Term Growth
6%–8% EBIT Growth 2007–2012 8%–12% production growth 2007–2010Pipelines E&P
• Unprecedented infrastructure opportunities
• Committed project inventory nearly $4 billion
• 2.8 Tcfe proved reserves*• Multi-year drilling inventory
*Post 2008 divestitures—Includes proportionate share of Four Star
44
Outlook Favors Both Businesses
Pipelines• Assets well positioned
– Rockies expansions: CIG, WIC, Ruby– LNG related: Elba Express, Cypress
E&P• Improved portfolio• Increased profitability• Drilling success
Favorable Macro Outlook• Increasing demand for natural gas• Strong commodity prices• Infrastructure opportunities with
shifting supply source
Environmental• Carbon emissions• Power generation turning to natural gas
55
El Paso Pipeline Group
Source: El Paso Corporation based on 2007 dataNote: Includes El Paso Corporation and El Paso Pipeline Partners, L.P.
El PasoNatural Gas
Mexico Ventures
MojavePipeline
ColoradoInterstate Gas
Wyoming Interstate
Cheyenne Plains Pipeline
TennesseeGas Pipeline
SouthernNatural Gas
Florida GasTransmission (50%)
Elba IslandLNG
• 19% of total U.S. interstate pipeline mileage• 24 Bcf/d capacity (16% of total U.S.)• 17 Bcf/d throughput (28% of gas delivered to U.S. consumers)
Gulf LNG(50%)
North America’s Leading Natural Gas Pipeline Company
66
The Enduring Value of“Last Mile” and “First Mile” Service
High Value High ValueCommodityService
Integrated withSuppliers
Supply Hub
Integrated withMarkets
Point-to-PointTransportation
Wellheads
Processing
LNG
Storage
Pipelines
LDC Citygate
Direct Connects(Industrial, Power Gen)
StorageMarket Hub
Pipeline
Excellent Connectivity in Markets
• 97 delivery meters into 26 LDCs
VT
NH
NY
PA NJ
CT RIMA Boston
New York
• 348 delivery meters in Arizona
CA AZ
UTNV
NMPhoenix
• 155 delivery meters into Alagasco and AGL
AL GA
SC
FL
Birmingham Atlanta
• 66 supply meters in the Rockies• 110 delivery meters along the Front Range
WY
CO
ID
UT
NESD
Denver
88
CIG High Plains Pipeline$196 MM (100%)November 2008
900 MMcf/d
TGP Carthage Expansion
$39 MMMay 2009
100 MMcf/dSNG South System III/
SESH Phase II$286 MM/ $33 MM
2010–2012375 MMcf/d/ 360MMcfd
Elba Expansion III & Elba Express$1.1 Billion2010–20131.2 Bcf/d
SNG Cypress Phase II & III $20 MM/$82 MM
May 2008/ Jan 2011114 MMcf/d/ 161 MMcf/d
CIG Totem Storage$120 MM (100%)
July 2009200 MMcf/d
WIC Piceance Lateral$62 MM4Q 2009
219 MMcf/d
SNG SESH –Phase I$137 MMJun 2008
140 MMcf/d
El PasoEl Paso Pipeline Partners
TGP Concord$21 MM
Nov 200930 MMcf/d
Gulf LNG$1.1 Billion (100%)
Oct 20111.3 Bcf/d
CP Coral Expansion$23 MM
July 200870 MMcf/d
Committed Growth BacklogApproaching $4 Billion
WIC Medicine Bow Expansion
$32 MMJuly 2008
330 MMcf/d
FGT Phase VIII Expansion
$2+ Billion (100%)2011
0.8 Bcf/d
Note: El Paso Pipeline Partners owns 10% of SNG and CIG
99
Market Demand Driving Pipeline Growth
FL
• $2+ billion (100%)• 50% EP, 50% SUG• 500 miles• 0.8 Bcf/d capacity• PA with FPL for 0.4 Bcf/d for
25-year term• 2011 in-service
Proposed Pipeline ExpansionFGT
Residential, Commercial,& Industrial
Power generation
0.0
1.0
2.0
3.0
4.0
2007 2017
Florida
Natural Gas DemandGrowth (Bcf)
Florida Gas Transmission VIII Project
Source: EEA/ICF
1010
Leveraging LNG ExperienceGulf LNG
Pascagoula, MSElba Island LNG
Savannah, GA
• $1.1 billion terminal expansion andElba Express Pipeline
• 8.4 Bcf incremental storage capacity• 0.9 Bcf/d incremental send-out capacity• Fully contracted with Shell and BG• Current expansion will double facility
• $1.1 Billion (100%); 50% EP• $870 MM non-recourse financing
completed• 1.3 Bcf/d base sendout• Fully contracted with Angola LNG and ENI• EPC with Aker Kvaerner• 2011 In-service
Investing more than $2 billion on LNG and related projects
1111
De-risking of Backlog Capital Costs
30%–35% 35%–40%
• Pipe • Contractor-related • Right-of-way• Other
Typical Pipeline Capex Breakdown
$1.70.81.4
$3.9
ContractorCustomerEl Paso
$ BillionPrimary Party
At-Risk for Capex
25%–35%
1212
El Paso Pipeline Partners• Primary focus is natural gas transmission
and storage assets• Three FERC regulated interstate pipelines:
– 100% of WIC: 800 miles, 2.7 Bcf/d– 10% of CIG: 4,000 miles, 3.0 Bcf/d– 10% of SNG: 7,600 miles, 3.7 Bcf/d
• Demand-based revenues from high-quality customers with strong credit profiles
• Several organic expansions underway
Diverse, Growing Supply Regions High Connectivity to Growing Markets
WICCIG SNG
1313
Pipeline Summary
• High-quality, committed growth backlog
– Approaching $4 billion
• Focus on project execution
• Manage capital costs
• Long-term EBIT growth expectation 6%–8%
– Higher with continued success
1414
Top 10 Domestic Independent
Note: All data is pro forma 2007 to exclude production and reserves related to properties divested in 2008 and to include a full year of production from our Peoples acquisition in 2007
Rio de Janeiro
Brazil
Brazil• 2 discoveries in 2007• 15,000–20,000 BOE/d
beginning 2H 2009• 20 undrilled prospects• 247 Bcfe of proved reserves• 14 MMcfe/d of production
Egypt
• Onshore conventional exploration
• 1 MM acres• First drilling 2H 2008
GOM• Medium to high-risk exploration• Large acreage position• 46% success rate in 2007• 152 Bcfe of proved reserves• 133 MMcfe/d of production• 3.1-year reserve life
Egypt
NileDelta
Sinai
EgyptGulf
ofSuez
Total Company
• Well-situated in key U.S. basins• Focused on unconventional and
low-risk conventional programs• ~80% natural gas• 97% drilling success rate• 2.8 Tcfe of proved reserves• 798 MMcfe/d of production• 9.6-year reserve life
Onshore-US• Primarily coal seam and
tight-gas programs• Low to medium risk
repeatable plays• 98% drilling success rate• 2.4 Tcfe of proved reserves• 650 MMcfe/d of production• 10.1-year reserve life
1515
High Grading Our Portfolio
• Divested 309 Bcfe of properties for $845 MM (sales price and assumed asset retirement obligation)—$2.73/Mcfe
– Low inventory, high operating costs
• Purchased Peoples Energy Production for $887 MM
• End result—more focused; more profitable, faster growing; added 450 total gross drilling locations
1616
Reserves More Weighted to Onshore Region
Onshore65%
GOM/SLA9%
TGC18%
INTL8%
Onshore70%
GOM/SLA5%
TGC16%
INTL9%
2007 YE Reported2007 Post
Divestitures
3.1 Tcfe 2.8 TcfeNote: Includes proportionate share of Four Star
1717
E&P ProductionSolid Growth Trajectory Through 2010
Note: Includes proportionate share of Four Star1 Excludes volumes from domestic assets sold; assumes full year of Peoples2 Assumes 25 MMcfe/d annualized contributed by the divestiture assets prior to closing
862798
870–930
MMcfe/d
8%–12% CAGR
2007 2007Pro Forma1
20082 2009 2010
1818
2006 2007A 2008E
E&P ProfitabilityGrowing Faster Than Peers
EBITDA*/Mcfe, Including Hedging
$6.04
$4.82$5.58 $5.84
$5.75–$6.00
Peer Average El Paso
Peer group: APA, APC, CHK, DVN, EOG, FST, NBL, NFX, PXD, PXD, XEC, XTOActual results from Peer company reports for 2006 and 2007; Analyst 2008E* EBITDA excludes exploration and dry hole expense for successful efforts companies
$5.61
1919
Significant Undrilled Inventory
PUD* UnconventionalRaton, Arkoma,Black Warrior,New Albany
ConventionalLow-Risk
Arklatex, Rockies, TGC, Brazil
ConventionalHigher-RiskGOM, TGC,
Int’l Exploration,Brazil, Egypt
869495 530
1,460
2,130
835
3,400
Non-ProvedRiskedUnrisked
*As of 12/31/07 and Includes proportionate share of Four Star
Res
ourc
e Po
tent
ial (
Bcf
e)
• 6.1 Tcfe unrisked non-proved resources• 2.8 Tcfe risked non-proved resources• Risked resources grew 12% in 2007• Excludes domestic divestiture properties
2020
Arklatex
Program Statistics:1,047 operating wells80% avg. WI426 PUD locations222 Bcfe PUD reserves404 non-proved locations540 Bcfe unrisked resource potential504 Bcfe risked resource potential11 R/P
2008 Plan:111 gross wells$319 MM net capital
Value Upside:Cotton Valley HorizontalsHaynesville ShaleInfill potential
Minden/SEBrachfield
0
50
100
150
200
2006 2007 2008 2009 2010
Production (MMcfe/d)
TX
AK
LA
Vacherie Dome/Bear Creek
Holly/Bethany Longstreet/Logansport
2121
Arklatex Economics
Objective:
Depth:
Well costs:
Reserves:
Initial prod:
Spacing:
IRR:
PVR:
F&D:
Hosston, Cotton Valley
7,500'–12,800'
$2.5 MM–$3.1 MM
1.0–1.4 Bcfe
1–5 MMcfe/d
40–80 acres
20%–30%
1.15–1.25
$2.70–$3.10/Mcfe
Cotton Valley 10,500 ft.
Hosston 8,500 ft.
0
200
400
600
800
1,000
1 2 3 4 5 6 7 8 9 10
Type Curve
Normalized Years
Mcf
e/d
Note: PVR and rate of return based on $7.50 MMBtu and $70.00/Bbl
2222
Haynesville Shale Play Outline—North Louisiana
Panola
Natchitoches
Marion
Bossier
Webster Claiborne
Harrison
Caddo
Shelby
Bienville
Red River
Desoto
Comstock Test
Petrohawk Discovery
Approx. 36,000 gross/ 27,000 net acres of Haynesville leases
ChesapeakeDiscovery
Encana Test
LA
TX
2323
E&P Summary
• E&P better positioned post high grading
• Greater Onshore focus
• More profitable
• Deeper inventory
• Visible 8% – 12% multi-year production growth
E&P moving towards top-tier performance
2424
2008 Natural Gas andOil Hedge Positions
0.9 MMBbls$57.03 ceiling/
$55.00 floor
Balance atMarket Price
Ceiling
Floors
4.0 MMBblsAverage cap $82.76/Bbl
4.0 MMBblsAverage floor $82.29/Bbl
Note: See full Production-Related Derivative Schedule in Appendix
2008 Gas
2008 Oil
188 TBtuAverage cap $10.21/MMBtu
155 TBtu$10.75 ceiling/
$8.00 floor
33 TBtu$7.65
fixed price
188 TBtuAverage floor $7.94/MMBtu
Ceiling
Floors
Positions as of April 4, 2008(Positions are for full-year 2008)
3.1 MMBbls$90.48
fixed price
2525
Substantial Leverage toHigher Commodity Prices
$0.50
$0.70
$0.90
$1.10
$1.30
$1.50
$1.70
Assumes$7.50 Gas
Assumes$9.00 Gas
Assumes$10.00 Gas
Assumes$11.00 Gas
$1.00–$1.10
$1.25–$1.35
$1.44–$1.54
$1.62–$1.72
Note: All data includes $70.00 WTI assumption
$ Earnings Per Share
Base Case
Current Market
2626
El Paso Offers Sustainable Long-Term Growth
• Focus on growth opportunities• Pipelines working to expand committed inventory • E&P more profitable, more focused, increased
opportunities post high grading • Committed to grow El Paso Pipeline Partners• Visible multi-year growth for both businesses
– Pipelines 6%–8% EBIT growth– E&P 8%–12% production growth
a meaningful companydoing meaningful workdelivering meaningful results
Doug FosheePresident and Chief Executive Officer
Howard Weil Energy ConferenceApril 8, 2008
2828
Appendix
2929
Disclosure of Non-GAAPFinancial Measures
The SEC’s Regulation G applies to any public disclosure or release of material information that includes a non-GAAP financial measure. In the event of such a disclosure or release, Regulation G requires (i) the presentation of the most directly comparable financial measure calculated and presented in accordance with GAAP and (ii) a reconciliation of the differences between the non-GAAP financial measure presented and the most directly comparable financial measure calculated and presented in accordance with GAAP. The required presentations and reconciliations are provided herein.
El Paso uses the non-GAAP financial measure “earnings before interest expense and income taxes” or “EBIT” to assess the operating results and effectiveness of the company and its business segments. The company defines EBIT as net income (loss) adjusted for (i) items that do not impact its income (loss) from continuing operations, such as extraordinary items, discontinued operations, and the impact of accounting changes; (ii) income taxes; (iii) interest and debt expense; and (iv) distributions on preferred interests of consolidated subsidiaries. The company excludes interest and debt expense and distributions on preferred interests of consolidated subsidiaries so that investors may evaluate the company’s operating results without regard to its financing methods or capital structure. EBITDA is defined as EBIT plus depreciation, depletion, and amortization. El Paso’s business operations consist of both consolidated businesses as well as substantial investments in unconsolidated affiliates. As a result, the company believes that EBIT and EBITDA, which include the results of both these consolidated and unconsolidated operations, is useful to its investors because it allows them to evaluate more effectively the performance of all of El Paso’s businesses and investments.
El Paso defines Resource Potential as subsurface volumes of oil and natural gas the company believes may be present and eventually recoverable. The company utilizes a net, geologic risk mean to represent this estimated ultimate recoverable amount.
El Paso believes that the non-GAAP financial measures described above are also useful to investors because these measurements are used by many companies in the industry as a measurement of operating and financial performance and are commonly employed by financial analysts and others to evaluate the operating and financial performance of the company and its business segments and to compare the operating and financial performance of the company and its business segments with the performance of other companies within the industry.
These non-GAAP financial measures may not be comparable to similarly titled measurements used by other companies and should not be used as a substitute for net income, earnings per share or other GAAP measurements.
30
3131
Production-Related Derivative Schedule
Note: Positions are as of April 4, 2008 (positions for full-year 2008)
Designated—EPEPFixed price—LegacyFixed priceCeilingFloor
Economic—EPEPFixed priceCeilingFloor
Economic—EPMCeilingFloor
Avg. ceilingAvg. floor
Designated—EPEPFixed price
Economic—EPMCeilingFloor
Avg. ceilingAvg. floor
4.621.0
121.1121.1
7.333.833.8
187.8187.8
3.10
0.930.93
4.04.0
$ 3.42$ 8.37$ 10.84$ 8.00
$ 8.24$ 10.43$ 8.00
$ 10.21$ 7.94
$ 90.48
$ 57.03$ 55.00
$ 82.76$ 82.29
4.6
47.547.5
16.8
68.952.1
$ 3.56
$ 11.01$ 8.35
$ 8.75
$ 9.96$ 7.93
4.6
4.64.6
$3.70
$3.70$3.70
2008
NotionalVolume(TBtu)
Avg. HedgePrice
($/MMBtu)
2009
NotionalVolume(TBtu)
Avg. Hedge Price
($/MMBtu)
NotionalVolume(TBtu)
Avg. Hedge Price
($/MMBtu)
2010
NotionalVolume
(MMBbls)
Avg. HedgePrice
($/Bbl)
2008
Natural Gas
Crude Oil
6.8
6.86.8
$3.88
$3.88$3.88
NotionalVolume(TBtu)
Avg. Hedge Price
($/MMBtu)
2011–2012