El Paso Corporation Doug Foshee President & Chief Executive Officer Raymond James 30th Annual Institutional Investor Conference March 10, 2009
May 29, 2015
El Paso Corporation
Doug FosheePresident & Chief Executive Officer
Raymond James 30th AnnualInstitutional Investor Conference
March 10, 2009
2
Cautionary StatementRegarding Forward-looking Statements
This presentation includes certain forward-looking statements and projections. 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 release, including, without limitation, changes in unaudited and/or unreviewed financial information; our ability to meet our 2009 debt maturities; volatility in, and access to, the capital markets; our ability to implement and achieve our objectives in our 2009 plan, including achieving our earnings and cash flow targets; the effects of any changes in accounting rules and guidance; our ability to meet production volume targets in our Exploration and Production segment; our ability to comply with the covenants in our various financing documents; our ability to obtain necessary governmental approvals for proposed pipeline and E&P 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 close asset sales, as well as transactions with partners on one or more of our expansion projects that are included in the plan on a timely basis; credit and performance risk of our lenders, trading counterparties, customers, vendors and suppliers ;changes in commodity prices and basis differentials for oil, natural gas, and power; our ability to obtain targeted cost savings in our businesses; inability to realize anticipated synergies and cost savings on a timely basis or at all; 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, including the risk of a global recession and negative impact on natural gas demand; 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, EBITDA, and the required reconciliations under Regulation G, are set forth in this presentation or in the appendix hereto. El Paso defines Resource Potential or Resource Inventory 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.
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Our Purpose
El Paso Corporation provides natural gas and related energy
products in a safe, efficient, and dependable manner
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the place to workthe neighbor to havethe company to own
Our Vision & Values
5
Meeting Challenges, Preserving Opportunities
Raised liquidity to $3.3 billion
Reduced capital thoughtfully
Reviewing capitaland financing options continuously
Delivering pipeline backlog
On-time, on-budget
Preserving E&P inventory
Improving credit metrics
Today Longer-Term
6
2009 Financial Targets
EPS*: $0.85–$1.05
EBIT* total: $2.0–$2.3 Pipelines: $1.4; E&P: $0.8–$0.9
EBITDA*: $3.1–$3.3 Pipelines: $1.8; E&P: $1.4–$1.6
Cash flow from operations: $1.7–$2.0
Capex: $2.7–$3.1Pipelines: $1.7; E&P: $0.9–$1.3
$ Billions, Except EPS
Note: 2009 Plan assumes natural gas price of $5.00 per MMBtu (NYMEX) and oil prices of $40.00 per Bbl (WTI)*Excludes MTM changes on hedge derivatives and includes cash proceeds on settlements based on Plan prices
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Substantial Increase in Liquidity$ Billions
Sep. 30,2008
Dec. 31,2008
Jan. 31,2009
Feb. 28,2009
Bank Lines Cash
$1.9$2.2
$1.2
$1.0
$1.3
$1.2
$1.4
$1.9$2.5
$3.3
$1.2
$0.7
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12/31/08 YTD NetFinancings
& AssetSales
OCF RemainingAssetSales
MayMaturity
Dividends& Minority
Interest
Capex YELiquidity
Liquidity Outlook
$2.2
$ Billions
$1.9
$0.2$0.9
$2.7–$3.1 $1.2–
$1.6
Note: Forecast assumes most of $500 MM LC facility replaced and EPEP $300 MM facility renewed
$0.2
E&P Capex
Ample liquidity for 2009
$1.1
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Premier Pipeline Franchise
El PasoNatural Gas
Mexico Ventures
MojavePipeline
ColoradoInterstate Gas
Wyoming Interstate
Cheyenne Plains Pipeline
TennesseeGas Pipeline
SouthernNatural Gas
Florida GasTransmission (50%)
Elba IslandLNG
Source: El Paso Corporation 2008 dataNote: Includes El Paso Corporation and El Paso Pipeline Partners, L.P.
19% of total U.S. interstate pipeline mileage19% of total U.S. interstate pipeline mileage26 Bcf/d capacity (15% of total U.S.)26 Bcf/d capacity (15% of total U.S.)19 Bcf/d throughput (30% of gas delivered to U.S. consumers)19 Bcf/d throughput (30% of gas delivered to U.S. consumers)
Gulf LNG(50%)
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TGP Carthage Expansion
$39 MMMay 2009
100 MMcf/d
SNG South System III/ SESH Phase II
$352 MM / $69 MM2011–2012
370 MMcf/d / 350 MMcf/d
Elba Expansion III & Elba Express
$1.1 Billion2010–2014
8.4 Bcf / 0.9 Bcf/d & 1.2 Bcf/d
SNG Cypress Phase III $86 MM
2011160 MMcf/d
CIG Totem Storage$154 MM (100%)
July 2009200 MMcf/d
WIC Piceance Lateral$62 MM4Q 2009
220 MMcf/d
El Paso PipelineEl Paso Pipeline Partners, LP
TGP Concord$21 MM
Nov 200930 MMcf/d
Gulf LNG$1+ Billion (100%)
20116.6 Bcf / 1.3 Bcf/d
CIG Raton 2010 Expansion$146 MM2Q 2010
130 MMcf/d
Committed Growth Backlog:Large, Profitable
FGT Phase VIII Expansion
$2.4 Billion (100%)2011
800 MMcf/d
~$8 billion capex; construct at 7x run rate EBITDA
Note: As of February 26, 2009; El Paso Pipeline Partners owns 25% of SNG & 40% of CIG
Ruby Pipeline$3 Billion
20111.3–1.5 Bcf/d
WIC System Expansion $71 MM
2010–2011320 MMcf/d
TGP 300 Line Project $750 MM
2011290 MMcf/d
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Backlog Spent to Date 2009 FundedCapital
RemainingRuby
2010-2013Remaining
Backlog
Financing the Pipeline Backlog
$7.8$ Billions
$1.3$1.0
$1.3
$2.4
$1.8
Backlog expected to generate $1.2 billion of incremental EBITDA*
Gulf LNG/Expected FGT
Financing
*EBITDA run-rate on proportional basis
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Construction Risk Management
Elba ExpansionElba Express
Gulf LNG (50%)
Ruby
FGT Phase VIII (50%)
TGP 300 Line
$ 1.1
$ 0.5
$ 3.0
$ 1.2
$ 0.8
El Paso Capital($ Billions) Steel Construction
Fixed-Price EPC ContractFixed
Fixed-Price EPC Contract
Fixed
Fixed
Fixed
Unit-Priced
Incentive-Based
Unit-Priced
Negotiating
Backlog has been significantly de-risked
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Pipeline Outlook
Stability from demand-based revenues
Highly focused on execution of project backlogSignificant risk mitigation in place
Committed to grow El Paso Pipeline Partners$3.0 B NOL offsets potential gains on drop downs
Selectively review future opportunitiesMitigate potential financing and steel costs
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Top 10 Domestic Independent
DomesticLow to medium-risk repeatable plays98% drilling success rateGrowing unconventional inventory
Note: Based on 2008 data except Egypt acres include January 2009 transaction with RWE
Brazil2 significant development projectsAdditional exploration potential
Egypt
Onshore conventional exploration1.05 MM net acresFirst drilling January 09
Nile Delta
Egypt
Rio de Janeiro
Brazil
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Exploration & Production
Significant progress in 2008595 Bcfe of reserves adds in 20081
195% domestic reserve replacement ratio2
27% inventory growth in 2008$0.9 B–$1.3 B capital for 2009
Focused on: value creation, inventory preservation, low-risk programsHighly flexible capital plan
725–815 MMcfe/d production3
1Prior to revisions; does not include Four Star2Prior to price-related revisions; does not include Four Star3 Includes Four Star
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Improving Domestic Reserve Metrics
2006 2007 2008 2006 2007 2008
$3.92
$3.26
$2.87
109%
255%
195%
Reserve Replacement Costs(RRC, $/Mcfe)
Reserve Replacement Ratio(RRR)
Note: 2008 RRC and RRR do not include price revisions. Prior years RRC and RRR include proved reserves additions, acquisitions, price, and performance revisions. Results do not include Four Star
$3.22129%
Reflects acquisitions
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2009 Capital ProgramFocused on Lower-Risk Programs
$0.9 billion–$1.3 billioncapital program
Flexible capital programfocusing on value creation
Increased focus on low-risk programs with significantinventory and repeatability
HaynesvilleCotton Valley HorizontalAltamont OilBlack Warrior CBM
International completing development of Camarupim
2008 2009
Central Western TGCGOM Intl Acq.
$1,742
$1,300
Capital Spending ($ MM)
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UpsidePotential
Heavily weighted to U.S. Onshore (75%)645 Bcfe Proved Undeveloped ReservesR/P of 8.6
6.6 Tcfe unrisked non-proved resources2.8 Tcfe risked unconventional and low riskInfill drilling (Raton CBM, Altamont oil)
Additional shale gas potential (Raton, Haynesville)International exploration success
Preserving Significant Resource Inventory*
2.5 TcfeProved
Reserves
* As of 12/31/08 and includes interest in Four Star
3.5 TcfeRisked
UnprovedInventory
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Raton Basin: CBM
Key PlaysVermejo & Raton Coals
Depth of 2,000' – 2,500’2008 Production: 76 MMcfe/dR/P of 20.5 years
Production(MMcfe/d)
2006 2007 2008NM
CO
Vermejo Park Ranch76 75 76
Upside80-acre CBM in-fillsCost reductions
606 M net fee and mineral acres
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UTWY
Altamont
Key Plays—Wasatch,Green River
Depth of 9,000' – 14,000’2008 Production: 32 MMcfe/d
Production(MMcfe/d)
2006 2007 2008
Altamont-Bluebell
20% CAGR before2008 acquisition
22 26 32
UpsideWorkovers and recompletionsInfillSecondary recovery
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Arklatex
Key Plays—Hosston/Cotton Valley, Haynesville
Depth of 7,500' – 12,800’2008 Production: 152 MMcfe/dR/P of 10 years
Production (MMcfe/d)
2006 2007 2008
Minden/SEBrachfield
TX
AK
LA
Vacherie Dome/Bear Creek
Holly/Bethany Longstreet/Logansport
122136 152
UpsideHorizontal Cotton ValleyHaynesvilleInfill drilling
12% CAGR
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Improving Results in Arklatex Program
4 Wells Producing IP (MMcfe/d)
Miller Land Co 10H #1 4.5
Travis Lynch GU #4-H 8.0
RF Gamble 24H #1 14.6
Blake 10H #1 20.3
2009 Activity
Spud in March: Hamilton 12H #1 and Annette Green 22H #1
J R Gamble will TD in March with first sales in April
2–4 rigs running during 2009
Haynesville Shale(currently producing 27 MMcfe/d
as of February 21, 2009)
0
20
40
60
80
100
120
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
MillerLand Co.10H #1
TravisLynch
GU #4-H
R.F.Gamble24H #1
Blake10H #1
Spud
to F
irst S
ales
(Day
s)
$/Lateral Ft.
Drilling Completion $/Lateral Ft.
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Rio deRio deJaneiroJaneiro
Brazil
Brazil to Become aMeaningful Contributor
Copaiba Well (18%)Drilled, testing and currently evaluating
Tot Well (35%)Drilled and currently evaluating
Pinaúna (100%)15–20 MBOE/d peak productionEnvironmental permitting has slowed pace
Camarupim (24%)50-60 MMcfe/d peak rateFirst production 2Q 2009
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E&P Outlook
2009 capital program focused onlow-risk, value-adding programs
Plan is highly flexible
Capital pace slowed while seeking to capture lower service costs
Preserving inventory while advancing key programs
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Balance atMarket Price
Note: See full Production-related Derivative Schedule in Appendix1Reflects positions after monetization of oil swaps2Includes proportionate share of Four Star equity volumes
151 TBtuAverage cap $14.97/MMBtu
8 TBtu$7.33
fixed price176 TBtu
Average floor $9.02/MMBtu
Ceiling
Floor
1.5 MMBbls$45.00
fixed price
2009 Gas
2009 Oil1
2009 Hedge Positions
143 TBtu$15.41ceiling
168 TBtu$9.10floor
~75% of domestic natural gas2; gas hedges valued at $730 MM as of 12/31/08$110/Bbl oil swaps monetized for $186 MM
Full-Year 2009
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2010 Hedge Positions
Balance atMarket Price
66 TBtuAverage floor $6.86/MMBtu
FloorFloor
2010 Gas
CeilingCeiling
Positions as of March 3, 2009
Note: See full ProductionNote: See full Production--related Derivative Schedule in Appendixrelated Derivative Schedule in Appendix
45 TBtuAverage cap $7.88/MMBtu
24.7 TBtu$6.61
fixed price
41.7 TBtu$7.00floor
19.8 TBtu$9.45
ceiling
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Focus Going Forward
Execute on committed pipeline backlogOn time/budgetMajority of capital risk has been mitigated
Create value at E&P Flexible capital expenditures Preserve inventory of opportunities
Ensure adequate liquidity
El Paso Corporation
Doug FosheePresident & Chief Executive Officer
Raymond James 30th AnnualInstitutional Investor Conference
March 10, 2009
29
Appendix
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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 attached. Additional detail regarding non-GAAP financial measures can be reviewed in El Paso’s full operating statistics, which will be posted at www.elpaso.com in the Investors section.
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 and discontinued operations; (ii) income taxes; and (iii) interest and debt expense. The company excludes interest and debt expense so that investors may evaluate the company’s operating results without regard to its financing methods or capital structure. EBITDA is defined as EBIT excluding depreciation, depletion and amortization. El Paso’s business operations consist of both consolidated businesses as well as investments in unconsolidated affiliates. As a result, the company believes that EBIT, which includes 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. Adjusted EBITDA is defined as EBITDA including the proportional share of EBITDA less our recorded equity earnings from our equity investments in Citrus and Four Star. The company believes that adjusted EBITDA is useful to its investors because it allows them to evaluate more effectively the performance of our businesses regardless of the type of ownership structure. Exploration and Production per-unit total cash costs or cash operating costs equal total operating expenses less DD&A, cost of products and services, transportation costs, and ceiling test charges divided by total production. It is a valuable measure of operating efficiency. For 2008, Adjusted EPS is earnings per share from continuing operations excluding the gain or loss related to the change in fair value of an indemnification from the sale of an ammonia plant in 2005, the gain related to an adjustment of the liability for indemnification of medical benefits for retirees of the Case Corporation, the gain related to the disposition of a portion of the company’s investment in its telecommunications business, changes in fair value of power contracts, changes in fair value of the production-related derivatives in Marketing, impact of mark-to-market E&P derivatives, ceiling test charges and Four Star impairment, other legacy litigation adjustments, legal restructuring benefit, and the effect of the change in the number of diluted shares. For 2007, Adjusted EPS is earnings per share from continuing operations excluding changes in fair value of production-related derivatives in Marketing, the loss related to Brazilian power impairments, the gain related to the crude oil trading liability, changes in the fair value of power contracts, the loss related to an adjustment of the liability for indemnification of medical benefits for retirees of the Case Corporation, debt repurchase costs, and the effect of the change in the number of diluted shares. Adjusted EPS is useful in analyzing the company’s on-going earnings potential.
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 operating measurements.
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32
33
Committed Projects In-Service Timeline
Note: $ in each column represents total costs for each project, shown in year placed in service (actual spend over multiple years). WIC is owned by El Paso Pipeline Partners
WIC System ExpansionElba ExpressTGP Carthage
$6.5$1.1$0.2Net project cost
Cypress III
SNG SESH Phase II
SNG South System III
Gulf LNG (50%)Elba III Phase B
FGT Phase VIII (50%)CIG Totem (50%)
TGP 300 Line ProjectCIG Raton 2010TGP Concord
RubyElba III Phase AWIC Piceance2011 & Beyond20102009$ Billions
34
YE 2008 Reserves
YE 2007 Extensions &Discoveries
Production Purchases &Sales
Revisions YE 2008
Commodity Prices Henry Hub WTIYE07 $6.80/MMbtu $95.98/BblYE08 $5.71/MMbtu $44.60/Bbl
Approx.3.0 Tcfe at
$7/$70
582
2992851
5602
3,109 2,547
Bcfe
Note: Includes proportionate share of Four Star equity volumes1Includes (303) Bcfe of sales and 18 Bcfe of acquisitions2Includes (490) Bcfe of price-related revisions and (70) Bcfe of performance-related revisions
35
Production-Related Derivatives Schedule
Note: Positions are as of March 3, 2009 (Contract months: Jan 2009–Forward)
Economic—EPEPFixed price—LegacyFixed priceCeilingFloor
Avg. ceilingAvg. floor
Economic—EPEPFixed price
4.63.6
142.9167.7
151.1175.9
1.50
$ 3.56$12.06$15.41$ 9.10
$14.97$ 9.02
$45.00
NotionalVolume(TBtu)
Avg. HedgePrice
($/MMBtu)
NotionalVolume(TBtu)
Avg. HedgePrice
($/MMBtu)
NotionalVolume(TBtu)
Avg. HedgePrice
($/MMBtu)
4.620.119.841.7
44.566.4
$3.70$7.289.45
$7.00
$7.88$6.86
6.8
6.86.8
$3.88
$3.88$3.88
Natural Gas
NotionalVolume
(MMBbls)
Avg. HedgePrice
($/Bbl)Crude Oil
2009 2010 2011–2012
2009
36
Reserves Update
1/1/08
ProductionExtensions & DiscoveriesPurchasesSalesPrice RevisionsPerform. Revisions
12/31/08
2,606
(268)57718
(303)(299)(72)
2,259
247
(4)–––
(177)–
66
2,853
(272)57718
(303)(476)(72)
2,325
256
(27)5––
(14)2
222
3,109
(299)58218
(303)(490)(70)
2,547
Domestic Int’l Subtotal Four Star Total E&P(Bcfe)
37
Non-GAAP Reconciliation2009 EBIT & EBITDA
EBITDA
Less: DD&A
EBIT
Less: Interest
Less: Taxes
Net Income
EPS
3.1–3.3
1.0-1.1
2.0–2.3
1.0
0.4 – 0.5
0.6–0.8
$0.85–$1.05
$ Billions, Except EPS
Note: Numbers may not foot due to rounding