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