Edgar Filing: ENTERPRISE PRODUCTS PARTNERS L P

e424b5

Filed Pursuant to Rule 424(b)(5)

Registration No. 333-123150

333-123150-01

PROSPECTUS SUPPLEMENT

(To Prospectus Dated March 23, 2005)

4,000,000 Common Units

Enterprise Products Partners L.P.

$25.03 per common unit

We are selling 4,000,000 common units representing limited partner interests in Enterprise Products Partners L.P.

Our common units are listed on the New York Stock Exchange under the symbol “EPD.” The last reported sales price of our common units on the New York Stock Exchange on November 29, 2005 was $25.54 per common unit.

Investing in our common units involves risk. See “Risk Factors” beginning on page S-14 of this prospectus supplement and on page 3 of the accompanying prospectus.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or determined if this prospectus supplement or the accompanying prospectus is truthful or complete. Any representation to the contrary is a criminal offense.


	Per Common Unit		Total

Public Offering Price		$25.03		$100,120,000

Underwriting Discount		$0.51		$2,040,000

Proceeds to us (before expenses)		$24.52		$98,080,000

We have granted the underwriter a 30-day option to purchase up to 600,000 additional common units to cover over-allotments, if any, on the same terms and conditions as set forth above.

UBS Securities LLC expects to deliver the common units to purchasers on or about December 5, 2005.

UBS Investment Bank

November 30, 2005

This document is in two parts. The first part is this prospectus supplement, which describes the terms of this offering of our common units. The second part is the accompanying prospectus, which gives more general information, some of which may not apply to this offering of common units. If the information varies between this prospectus supplement and the accompanying prospectus, you should rely on the information in this prospectus supplement.

You should rely only on the information contained or incorporated by reference in this prospectus supplement or the accompanying prospectus. We have not authorized anyone to provide you with additional or different information. We are not making an offer to sell these securities in any state where the offer is not permitted. You should not assume that the information contained in this prospectus supplement or the accompanying prospectus is accurate as of any date other than the date on the front of these documents or that any information we have incorporated by reference is accurate as of any date other than the date of the document incorporated by reference. Our business, financial condition, results of operations and prospects may have changed since these dates.

TABLE OF CONTENTS


	Page

Prospectus Supplement
Summary		S-1
Risk Factors		S-14
Use of Proceeds		S-18
Price Range of Common Units and Distributions		S-19
Capitalization		S-20
Management		S-22
Tax Consequences		S-26
Investment in Us by Employee Benefit Plans		S-27
Underwriting		S-29
Legal Matters		S-32
Experts		S-32
Incorporation of Documents by Reference		S-33
Forward-Looking Statements		S-34
Index to Unaudited Pro Forma Condensed Consolidated Financial Statements		F-1

Prospectus
About This Prospectus		iv
Our Company		1
Risk Factors		3
Use of Proceeds		18
Ratio of Earnings to Fixed Charges		18
Description of Debt Securities		18
Description of Our Common Units		35
Cash Distribution Policy		37
Description of Our Partnership Agreement		42
Material Tax Consequences		47
Selling Unitholders		62
Plan of Distribution		64
Where You Can Find More Information		67
Forward-Looking Statements		69
Legal Matters		69
Experts		70

Summary

This summary highlights information from this prospectus supplement and the accompanying prospectus to help you understand our business and the common units. It does not contain all of the information that is important to you. You should read carefully the entire prospectus supplement, the accompanying prospectus, the documents incorporated by reference and the other documents to which we refer for a more complete understanding of this offering. You should read “Risk Factors” beginning on page S-14 of this prospectus supplement and on page 3 of the accompanying prospectus for more information about important risks that you should consider before making a decision to purchase common units in this offering.

The information presented in this prospectus supplement assumes that the underwriter does not exercise its over-allotment option, unless otherwise indicated. All references in this prospectus supplement and the accompanying prospectus to number of units, earnings per unit or unit price give effect to our two-for-one unit split on May 15, 2002. “Our,” “we,” “us” and “Enterprise” as used in this prospectus supplement and the accompanying prospectus refer to Enterprise Products Partners L.P. and its wholly owned subsidiaries. “GulfTerra” as used in this prospectus supplement refers to GulfTerra Energy Partners, L.P. and its wholly owned subsidiaries, and “El Paso Corporation” as used in this prospectus supplement refers to El Paso Corporation and its wholly owned subsidiaries. Effective February 3, 2005, GulfTerra’s name was changed to Enterprise GTM Holdings L.P., and GulfTerra’s general partner’s name was changed to Enterprise GTMGP, LLC.

Unless otherwise indicated, pro forma financial results presented in this prospectus supplement give effect to the completion of the merger-related and other transactions described in the unaudited pro forma consolidated financial statements included elsewhere in this prospectus supplement, and pro forma as adjusted financial results presented in this prospectus supplement also give effect to this offering. For a complete description of the adjustments we have made to arrive at the pro forma financial measures that we present in this prospectus supplement, please read the unaudited pro forma consolidated financial statements included elsewhere in this prospectus supplement.

ENTERPRISE PRODUCTS PARTNERS L.P.

We are a leading North American midstream energy company that provides a wide range of services to producers and consumers of natural gas and natural gas liquids, or NGLs, and crude oil, and we are an industry leader in the development of pipeline and other midstream infrastructure in the continental United States and deepwater Gulf of Mexico. We operate an integrated midstream asset base within the United States, which includes: natural gas transportation, gathering, processing and storage; NGL fractionation (or separation), transportation, storage and import and export terminaling; and crude oil transportation and offshore production platform services. NGLs are used by the petrochemical and refining industries to produce plastics, motor gasoline and other industrial and consumer products and also are used as residential, agricultural and industrial fuels.

For the year ended December 31, 2004, we had revenues of $8.3 billion, operating income of $423 million and net income of $268.3 million. On a pro forma as adjusted basis for the year ended December 31, 2004, we had revenues of $9.6 billion, operating income of $572.7 million and income from continuing operations of $323.2 million. For the nine months ended September 30, 2005, we had revenues of $8.5 billion, operating income of $485.4 million and net income of $311.1 million. On a pro forma as adjusted basis for the nine months ended September 30, 2005, we had revenues of $8.5 billion, operating income of $479.6 million and income from continuing operations of $309.4 million. Please read “—Summary Historical and Pro Forma Financial and Operating Data” and our unaudited pro forma financial statements beginning on page F-1 of this prospectus supplement for a description of the transactions we have included in our pro forma presentation.

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Our business segments

We have four reportable business segments that are generally organized and managed along our midstream asset base according to the type of services rendered (or technology employed) and products produced and sold (i) Offshore Pipelines & Services, (ii) Onshore Natural Gas Pipelines & Services, (iii) NGL Pipelines & Services, and (iv) Petrochemical Services.

Offshore Pipelines & Services. Our Offshore Pipelines & Services segment consists of (i) approximately 1,150 miles of natural gas pipelines strategically located to serve production activities in some of the most active drilling and development regions in the Gulf of Mexico, (ii) approximately 810 miles of Gulf of Mexico offshore crude oil pipeline systems, and (iii) seven multi-purpose offshore hub platforms located in the Gulf of Mexico.

Onshore Natural Gas Pipelines & Services. Our Onshore Natural Gas Pipelines & Services segment includes onshore natural gas pipeline systems aggregating approximately 17,200 miles that provide for the gathering and transmission of natural gas in Alabama, Colorado, Louisiana, Mississippi, New Mexico and Texas. Included in this segment are two salt dome natural gas storage facilities located in Mississippi, which are strategically located to serve the Northeast, Mid-Atlantic and Southeast natural gas markets. We also lease natural gas storage facilities located in Texas and Louisiana.

NGL Pipelines & Services. Our NGL Pipelines & Services segment is comprised of (i) our natural gas processing business and related NGL marketing activities, (ii) NGL pipelines aggregating approximately 12,810 miles and related storage facilities, which include our strategic Mid-America and Seminole NGL pipeline systems and (iii) NGL fractionation facilities located in Texas and Louisiana. This segment also includes our NGL import and export terminaling operations.

Petrochemical Services. Our Petrochemical Services segment includes our four propylene fractionation facilities, our isomerization complex, and our octane additive production facility. This segment also includes approximately 530 miles of petrochemical pipeline systems.

Business strategy

Our business strategy is to:


•	capitalize on expected increases in natural gas, NGL and oil production resulting from development activities in the deepwater and continental shelf areas of the Gulf of Mexico and in the Rocky Mountain region;

•	maintain a balanced and diversified portfolio of midstream energy assets and expand this asset base through organic development projects and accretive acquisitions of complementary midstream energy assets;

•	share capital costs and risks through joint ventures or alliances with strategic partners that will provide the raw materials for these projects or purchase the projects’ end products; and

•	increase fee-based cash flows by investing in pipelines and other fee-based businesses and de-emphasize commodity-based activities.

Competitive strengths

We believe we have the following competitive strengths:

Large-Scale, Integrated Network of Diversified Assets in Strategic Locations. We operate an integrated natural gas and NGL transportation, fractionation, processing, storage and import/export network within the United States. Our operations are strategically located to serve the major supply basins for NGL-rich natural gas, the major NGL storage hubs in North America and international

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markets. We believe that our location in these markets provides better access to natural gas, NGL and petrochemical supply volumes, anticipated demand growth and business expansion opportunities.

Cash-Flow Stability Through Fee-Based Businesses and Balanced Asset Mix. Our cash flow is derived primarily from fee-based businesses which are not directly affected by volatility in energy commodity prices. As a result of the GulfTerra merger, we have a more diversified asset portfolio that provides operating income from a broad range of sources. GulfTerra’s historical operations generally benefited from strong or average hydrocarbon prices, while our historical operations prior to the merger generally benefited from stable or lower hydrocarbon prices. This relationship results in a natural hedge to natural gas prices that has provided greater cash flow stability.

Relationships with Major Oil, Natural Gas and Petrochemical Companies. We have long-term relationships with many of our suppliers and customers, and we believe that we will continue to benefit from these relationships. We jointly own facilities with many of our customers who either provide raw materials to, or consume the end products from, our facilities. These joint venture partners include major oil, natural gas and petrochemical companies, including BP, Burlington Resources, ChevronTexaco, Dow Chemical, Duke Energy Field Services, El Paso Corporation, ExxonMobil, Marathon and Shell.

Strategic Platform for Continued Expansion. We have strong business positions across our midstream energy asset base in key producing and consuming regions in North America. In addition, we have a significant portfolio of organic growth opportunities to construct new facilities or expand existing assets. These projects include the Independence Trail and Independence Hub projects and the Constitution oil and natural gas pipeline projects in the deepwater areas of the Gulf of Mexico; the expansion of some of our key western NGL assets and the construction of additional facilities to support new production in the Rocky Mountain and San Juan regions; and enhancements to some of our existing facilities on the Texas Gulf Coast to serve our refining and petrochemical customers.

Lower Cost of Capital. We believe that our general partner’s maximum incentive distribution level of 25% (as compared to 50% for many publicly traded master limited partnerships) combined with our investment grade credit profile provides us with a lower cost of capital than many of our competitors, enabling us to compete more effectively in acquiring assets and expanding our asset base.

Experienced Operator and Management Team. We have historically operated our largest natural gas processing and fractionation facilities and most of our pipelines. As the leading provider of NGL related services, we have established a reputation in the industry as a reliable and cost-effective operator. Affiliates of Dan L. Duncan, our co-founder and the chairman of our general partner, own a 100% membership interest in our general partner, Enterprise Products GP, LLC. In addition, following this offering, Mr. Duncan and his affiliates, including EPCO, Inc., or EPCO, and Enterprise GP Holdings L.P., collectively will own an approximate 36.1% limited partner interest in us. The officers of our general partner average more than 25 years of industry experience.

Recent developments

Enterprise GP Holdings Initial Public Offering. On August 29, 2005, Enterprise GP Holdings L.P., the sole member of our general partner, completed its initial public offering of 14,216,785 units, including 1,821,428 units sold to a partnership established for the benefit of certain employees of EPCO. In connection the closing of that offering, EPCO and its affiliates contributed an aggregate 100% membership interest in our general partner and 13,454,498 of our common units to Enterprise GP Holdings in exchange for 74,667,332 units of Enterprise GP Holdings and the assumption of indebtedness by Enterprise GP Holdings. As of the date hereof, Mr. Duncan and his affiliates own 100% of the membership interests in Enterprise GP Holdings’ general partner and 86.5% of Enterprise GP Holdings’ outstanding units.

Amendment to Revolving Credit Facility. On October 7, 2005, our operating partnership amended its revolving credit facility to increase total bank commitments from $750 million to $1.25 billion (which

S- 3

may be further increased to $1.4 billion upon our request, subject to certain conditions) and to reduce the facility fee and the Eurodollar borrowing rate by 0.375%. The amendment also extended the maturity date of the credit facility from September 30, 2009 to October 5, 2010, and we may request up to two one-year extensions of the maturity date. The amendment also removed the $100 million limit on the total amount of standby letters of credit that can be outstanding under the credit facility.

Increase in Quarterly Cash Distribution Rate. On November 8, 2005, we paid a quarterly cash distribution for the third quarter of 2005 of $0.43 per common unit, or $1.72 per unit on an annualized basis.

Election of Chief Operating Officer. On November 23, 2005, the board of directors of our general partner elected Dr. Ralph S. Cunningham to serve as Group Executive Vice President and Chief Operating Officer of our general partner, effective December 1, 2005.

Expansion Projects at Mont Belvieu. On November 29, 2005, we announced that we are expanding our NGL and petrochemical storage services at our complex in Mont Belvieu, Texas to improve our ability to receive and deliver NGLs and petrochemicals at our underground storage facilities in Mont Belvieu. The increased storage rate capacity will further enable us to enhance product storage services and movement to transportation and distribution pipelines which serve the Gulf Coast region, as well as to our import and export facilities on the Houston Ship Channel. As part of these projects, we will more than double our brine storage capabilities to 19 million barrels and will increase our capacity to produce brine for injection service by drilling two new brine production wells. These projects are expected to be placed in service in 2006.

S- 4

The following chart depicts our organizational structure and ownership after giving effect to this offering.

The table below shows the current ownership of our common units and the ownership of our common units after giving effect to this offering (assuming the underwriter does not exercise its over-allotment option).


						Ownership after
		Current ownership				the offering

				Percentage				Percentage
		Units		interest		Units		interest

Public common units			212,811,292		54.0%		216,811,292		54.5%
EPCO common units(1)			130,187,829		33.1%		130,187,829		32.7%
Enterprise GP Holdings common units			13,454,498		3.4%		13,454,498		3.4%
Shell common units			29,407,549		7.5%		29,407,549		7.4%
General partner interest(2)			—		2.0%		—		2.0%

	Total		385,861,168		100.0%		389,861,168		100.0%


(1)	Includes common units beneficially owned by Dan Duncan, related family trusts and other EPCO affiliates (excluding Enterprise GP Holdings).
(2)	Owned by Enterprise GP Holdings L.P.

Information regarding our management is set forth under “Management” beginning on page S-22 of this prospectus supplement. Our principal executive offices are located at 2727 North Loop West, Houston, Texas 77008, and our telephone number is (713) 880-6500.

S- 5

The offering


Common units offered		4,000,000 common units; or

		4,600,000 common units if the underwriter exercises its over-allotment option in full.

Units outstanding after this offering		389,861,168 common units, or 390,461,168 common units if the underwriter exercises its over-allotment option in full.

Use of proceeds		We will use the net proceeds from this offering, including our general partner’s proportionate capital contribution, to reduce borrowings outstanding under our multi-year revolving credit facility. Please read “Use of Proceeds.”

Cash distributions		Under our partnership agreement, we must distribute all of our cash on hand as of the end of each quarter, less reserves established by our general partner. We refer to this cash as “available cash,” and we define its meaning in our partnership agreement.

		On November 8, 2005, we paid a quarterly cash distribution for the third quarter of 2005 of $0.43 per common unit, or $1.72 per unit on an annualized basis.

		When quarterly cash distributions exceed $0.253 per unit in any quarter, our general partner receives a higher percentage of the cash distributed in excess of that amount, in increasing percentages up to 25% if the quarterly cash distributions exceed $0.3085 per unit. For a description of our cash distribution policy, please read “Cash Distribution Policy” in the accompanying prospectus.

Estimated ratio of taxable income to distributions		We estimate that if you own the common units you purchase in this offering through December 31, 2007, you will be allocated, on a cumulative basis, an amount of federal taxable income for the taxable years 2005 through 2007 that will be less than 10% of the cash distributed with respect to that period. Please read “Tax Consequences” in this prospectus supplement and “Material Tax Consequences” in the accompanying prospectus for the basis of this estimate.

New York Stock Exchange symbol		EPD

Risk Factors		There are risks associated with this offering and our business. You should consider carefully the risk factors beginning on page S-14 of this prospectus supplement and beginning on page 3 of the accompanying prospectus before making a decision to purchase common units in this offering.

S- 6

Summary historical and pro forma financial and

operating data

The following tables set forth, for the periods and at the dates indicated, summary historical and pro forma financial and operating data for Enterprise. The summary historical income statement and balance sheet data for the three years in the period ended December 31, 2004 are derived from and should be read in conjunction with the audited financial statements of Enterprise, GulfTerra and the South Texas midstream assets that are incorporated by reference into this prospectus supplement. The summary historical income statement data for the nine-month periods ended September 30, 2004 and 2005 and balance sheet data at September 30, 2005 are derived from and should be read in conjunction with our unaudited financial statements that are incorporated by reference into this prospectus supplement.

Our summary unaudited pro forma financial and operating data gives effect to the following transactions:


•	The completion of our merger with GulfTerra and the related transactions on September 30, 2004 (including our purchase of certain midstream assets located in South Texas, effective as of September 1, 2004, and the sale of our 50% equity interest in Starfish Pipeline Company, LLC on March 31, 2005).

•	The issuance by our operating partnership of $2 billion of senior unsecured notes on October 4, 2004, and the application of the net proceeds therefrom to reduce debt amounts outstanding under our 364-day acquisition credit facility that was used to fund a portion of the purchase price at the closing of the GulfTerra merger and related transactions on September 30, 2004.

•	The completion on October 5, 2004 of our operating partnership’s four cash tender offers for $915 million in principal amount of GulfTerra’s senior and senior subordinated notes using $1.1 billion in cash borrowed under our 364-day acquisition credit facility.

•	Our public offerings of 17,250,000 common units in both May 2004 and August 2004 and the issuance of a total of 5,183,591 common units in connection with our distribution reinvestment plan, or DRIP, and related programs during 2004.

•	The conversion of 80 Series F2 convertible units, which were originally issued by GulfTerra, into 1,950,317 of our common units in October 2004 and November 2004.

•	Our public offering of 17,250,000 common units in February 2005 and the application of the net proceeds therefrom to repay debt amounts outstanding under and terminate our 364-day acquisition credit facility and to reduce indebtedness outstanding under our multi-year revolving credit facility.

•	The issuance of 2,729,740 common units by us during 2005 in connection with our DRIP and related programs.

•	The issuance by our operating partnership in February 2005 of $250 million in principal amount of 5.00% senior notes due March 2015 and $250 million in principal amount of 5.75% senior notes due March 2035 and the application of the net proceeds therefrom to refinance $350 million in principal amount 8.25% senior notes due March 15, 2005, and for general partnership purposes, including the repayment of indebtedness outstanding under our multi-year revolving credit facility.

•	Our issuance in June 2005 of $500 million in principal amount of our 4.95% senior notes due June 2010 and the application of the net proceeds therefrom to temporarily reduce borrowings under our multi-year revolving credit facility and for general partnership purposes, including capital expenditures and acquisitions.

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Our summary unaudited pro forma as adjusted financial data also gives effect to the sale of 4,000,000 of our common units to the public in this offering at an offering price of $25.03 per unit and the application of the net proceeds as described in “Use of Proceeds.” Net proceeds from this offering, including our general partner’s proportionate net capital contribution of $2.0 million, are $99.6 million, after deducting applicable underwriting discounts, commissions and estimated offering expenses.

The unaudited pro forma financial data for the year ended December 31, 2004 and for the nine months ended September 30, 2005 assume the pro forma transactions described above and this offering all occurred on January 1, 2004 (to the extent not already reflected in our historical statement of operations). The unaudited pro forma condensed consolidated balance sheet data shows the financial effects of the pro forma transactions described above and this offering as if they had occurred on September 30, 2005 (to the extent these transactions are not already recorded in our historical balance sheet).

The non-generally accepted accounting principle, or non-GAAP, financial measures of gross operating margin and earnings before interest, income taxes, depreciation and amortization, which we refer to as “EBITDA,” are presented in our summary historical and pro forma financial data. In supplemental sections titled “—Non-GAAP Financial Measures” and “—Non-GAAP Reconciliations,” we have provided the necessary explanations and reconciliations for the non-GAAP financial measures presented in this prospectus supplement.

For additional information regarding our pro forma and pro forma as adjusted amounts, please see the pro forma financial information beginning on page F-1 of this prospectus supplement.

S- 8

Summary historical and pro forma financial and

operating data


				Consolidated historical
													For year ended
													December 31, 2004
				For year ended December 31,
																Pro forma
Income statement data:				2002			2003			2004			Pro forma			as adjusted

													(unaudited)
				(dollars in millions, except per unit amounts)
Revenues				$	3,584.8		$	5,346.4		$	8,321.2		$	9,615.1		$	9,615.1
	Costs and expenses:
		Operating costs and expenses			3,382.8			5,046.8			7,904.3			8,974.1			8,974.1
		General and administrative			42.9			37.5			46.7			93.2			93.2

			Total costs and expenses		3,425.7			5,084.3			7,951.0			9,067.3			9,067.3

	Equity in income (loss) of unconsolidated affiliates				35.2			(14.0	)		52.8			24.9			24.9

	Operating income				194.3			248.1			423.0			572.7			572.7

	Other income (expense):
		Interest expense			(101.6	)		(140.8	)		(155.7	)		(231.6	)		(226.8	)
		Other, net			7.3			6.4			2.1			(12.6	)		(12.6	)

			Total other income (expense)		(94.3	)		(134.4	)		(153.6	)		(244.2	)		(239.4	)

	Income before provision for income taxes and minority interest				100.0			113.7			269.4			328.5			333.3
	Provision for income taxes				(1.6	)		(5.3	)		(3.8	)		(3.8	)		(3.8	)

	Income before minority interest				98.4			108.4			265.6			324.7			329.5
	Minority interest				(2.9	)		(3.9	)		(8.1	)		(6.3	)		(6.3	)

	Income from continuing operations				95.5			104.5			257.5		$	318.4		$	323.2

	Cumulative effect of change in accounting principle				—			—			10.8

	Net income			$	95.5		$	104.5		$	268.3

Basic earnings per unit (net of general partner interest):
	Income from continuing operations per unit			$	0.55		$	0.42		$	0.83		$	0.69		$	0.70

Diluted earnings per unit (net of general partner interest):
	Income from continuing operations per unit			$	0.48		$	0.41		$	0.83		$	0.69		$	0.69

Distributions to limited partners:
	Per common unit			$	1.36		$	1.47		$	1.54

Balance sheet data:
	Total assets			$	4,230.3		$	4,802.8		$	11,315.5
	Total debt				2,246.5			2,139.5			4,281.2
	Total partners’ equity				1,200.9			1,705.9			5,328.8

Other financial data:
	Cash provided by operating activities			$	329.8		$	424.7		$	391.5
	Cash flows used in investing activities				1,711.3			662.1			941.4
	Cash provided by financing activities				1,263.3			254.0			544.0
	Distributions received from unconsolidated affiliates				57.7			31.9			68.0
	Gross operating margin				332.3			410.4			655.2		$	1,047.5		$	1,047.5
	EBITDA				284.8			366.4			623.2			945.3			945.3

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				Consolidated
				historical

				For nine						For nine months ended
				months ended						September 30, 2005
				September 30,
													Pro forma
Income statement data:				2004			2005			Pro forma			as adjusted

				(unaudited)
				(dollars in millions, except per unit amounts)
Revenues				$	5,458.5		$	8,476.6		$	8,476.6		$	8,476.6
	Costs and expenses:
		Operating costs and expenses			5,226.4			7,959.1			7,964.6			7,964.6
		General and administrative			26.6			46.7			46.7			46.7

			Total costs and expenses		5,253.0			8,005.8			8,011.3			8,011.3

	Equity in income of unconsolidated affiliates				42.2			14.6			14.3			14.3

	Operating income				247.7			485.4			479.6			479.6

	Other income (expense):
		Interest expense			(97.0	)		(170.7	)		(170.2	)		(166.6	)
		Other, net			1.0			3.6			3.6			3.6

			Total other income (expense)		(96.0	)		(167.1	)		(166.6	)		(163.0	)

	Income before provision for income taxes, minority interest and change in accounting principles				151.7			318.3			313.0			316.6
	Provision for income taxes				(2.7	)		(4.0	)		(4.0	)		(4.0	)

	Income before minority interest and changes in accounting principles				149.0			314.3			309.0			312.6
	Minority interest				(6.9	)		(3.2	)		(3.2	)		(3.2	)

	Income from continuing operations				142.1			311.1		$	305.8		$	309.4

	Cumulative effect of change in accounting principles				10.8			—

	Net income			$	152.9		$	311.1

Basic earnings per unit (net of general partner interest):
	Income from continuing operations per unit			$	0.57		$	0.69		$	0.66		$	0.66

Diluted earnings per unit (net of general partner interest):
	Income from continuing operations per unit			$	0.57		$	0.69		$	0.66		$	0.66

Distributions to limited partners:
	Per common unit			$	1.14		$	1.26

Balance sheet data:
	Total assets			$	12,183.4		$	12,391.4		$	12,391.4		$	12,391.4
	Total debt				5,579.4			4,803.8			4,793.7			4,694.1
	Total partners’ equity				5,279.6			5,647.7			5,657.8			5,757.4

Other financial data:
	Cash provided by operating activities			$	36.0		$	344.6
	Cash used in investing activities				737.7			881.9
	Cash provided by financing activities				817.9			545.4
	Distributions received from unconsolidated affiliates				54.6			47.4
	Gross operating margin				376.0			833.0		$	832.7		$	832.7
	EBITDA				347.6			794.9			789.1			789.1


		Enterprise consolidated historical

								For nine
		For year ended						months ended
		December 31,						September 30,

Selected volumetric operating data by segment:		2002		2003		2004		2004		2005

Offshore Pipelines & Services, net:
	Natural gas transportation volumes in billion British thermal units per day (BBtus/d)		500		433		2,081		423		1,876
	Crude oil transportation volumes in thousands of barrels per day (MBbls/d)						138				134
	Platform gas treating in thousands of decatherms per day (Mdth/d)						306				285
	Platform oil treating (MBbls/d)						14				8
Onshore Natural Gas Pipelines & Services, net:
	Natural gas transportation volumes (BBtus/d)		701		600		5,638		650		5,933
NGL Pipelines & Services, net:
	NGL transportation volumes (MBbls/d)		1,306		1,275		1,411		1,358		1,463
	NGL fractionation volumes (MBbls/d)		235		227		307		235		311
	Equity NGL production (MBbls/d)		73		43		129		84		94
	Fee-based natural gas processing in million cubit feet per day (MMcf/d)		*		194		1,692		1,544		1,828
Petrochemical Services, net:
	Butane isomerization volumes (MBbls/d)		84		77		76		73		82
	Propylene fractionation volumes (MBbls/d)		55		57		56		58		55
	Octane additive production volumes (MBbls/d)		5		4		10		9		5
	Petrochemical transportation volumes (MBbls/d)		46		68		71		72		65

* Fee-based natural gas processing volumes prior to 2003 were negligible.

S- 10

Non-GAAP financial measures

We include in this prospectus supplement the non-GAAP financial measures of gross operating margin and EBITDA and provide reconciliations of these non-GAAP financial measures to their most directly comparable financial measure or measures calculated and presented in accordance with GAAP.

GROSS OPERATING MARGIN

We define gross operating margin as operating income before: (1) depreciation and amortization expense; (2) operating lease expenses for which we do not have the cash payment obligation; (3) gains and losses on the sale of assets; and (4) selling, general and administrative expenses. We view gross operating margin as an important performance measure of the core profitability of our operations. This measure forms the basis of our internal financial reporting and is used by our senior management in deciding how to allocate capital resources among business segments. We believe that investors benefit from having access to the same financial measures that our management uses. The GAAP measure most directly comparable to gross operating margin is operating income.

EBITDA

EBITDA is defined as net income (income from continuing operations with regards to pro forma information) plus interest expense, provision for income taxes and depreciation and amortization expense. EBITDA is used as a supplemental financial measure by our management and by external users of financial statements such as investors, commercial banks, research analysts and ratings agencies, to assess:


•	the financial performance of our assets without regard to financing methods, capital structures or historical costs basis;

•	the ability of our assets to generate cash sufficient to pay interest cost and support our indebtedness;

•	our operating performance and return on capital as compared to those of other companies in the midstream energy sector, without regard to financing and capital structure; and

•	the viability of projects and the overall rates of return on alternative investment opportunities.

EBITDA should not be considered an alternative to net income or income from continuing operations, operating income, cash flow from operating activities or any other measure of financial performance presented in accordance with GAAP. This non-GAAP financial measure is not intended to represent GAAP-based cash flows. We have reconciled our historical and pro forma EBITDA amounts to our consolidated net income (income from continuing operations with regards to pro forma information) and historical EBITDA amounts further to operating activities cash flows.

S- 11

Non-GAAP reconciliations

The following table presents a reconciliation of our non-GAAP financial measure of gross operating margin to the GAAP financial measure of operating income and a reconciliation of the non-GAAP financial measure of EBITDA to the GAAP financial measures of net income (income from continuing operations with regards to pro forma information) and of operating activities cash flows, on a historical and pro forma as adjusted basis, as applicable, for each of the periods indicated:


			Consolidated historical
												For year ended
												December 31, 2004
			For year ended December 31,
															Pro forma
			2002			2003			2004			Pro forma			as adjusted

												(unaudited)
			(dollars in millions)
Reconciliation of Non-GAAP “Gross operating margin” to GAAP “Operating income”
Operating income			$	194.3		$	248.1		$	423.0		$	572.7		$	572.7
	Adjustments to reconcile Operating income to Gross operating margin:
		Depreciation and amortization in operating costs and expenses		86.0			115.7			193.7			389.8			389.8
		Retained lease expense, net in operating costs and expenses		9.1			9.1			7.7			7.7			7.7
		Gain on sale of assets in operating costs and expenses		—			—			(15.9	)		(15.9	)		(15.9	)
		General and administrative costs		42.9			37.5			46.7			93.2			93.2

Total Gross Operating Margin			$	332.3		$	410.4		$	655.2		$	1,047.5		$	1,047.5

Reconciliation of Non-GAAP “EBITDA” to GAAP “Net income” or “Income from continuing operations” and GAAP “Cash provided by operating activities”
Net income (Income from continuing operations with regards to pro forma information)			$	95.5		$	104.5			268.3		$	318.4		$	323.2
	Adjustments to derive EBITDA:
		Interest expense		101.6			140.8			155.7			231.6			226.8
		Provision for income taxes		1.6			5.3			3.8			3.8			3.8
		Depreciation and amortization (excluding amortization component in interest expenses)		86.1			115.8			195.4			391.5			391.5

EBITDA				284.8			366.4			623.2		$	945.3		$	945.3

	Interest expense			(101.6	)		(140.8	)		(155.7	)
	Amortization in interest expense			8.8			12.6			3.5
	Provision for income taxes			(1.6	)		(5.3	)		(3.8	)
	Provision for impairment charge						1.2			4.1
	Equity in loss (income) of unconsolidated affiliates			(35.2	)		14.0			(52.8	)
	Distributions from unconsolidated affiliates			57.7			31.9			68.0
	Gain on sale of assets			—			—			(15.9	)
	Operating lease expense paid by EPCO (excluding minority interest portion)			9.0			9.0			7.7
	Other expenses paid by EPCO			—			0.4			—
	Minority interest			2.9			3.9			8.1
	Deferred income tax expense			2.1			10.5			9.6
	Changes in fair market value of financial instruments			10.2			—			—
	Cumulative effect of changes in accounting principles			—			—			(10.8	)
	Net effect of changes in operating accounts			92.7			120.9			(93.7	)

Cash provided by operating activities			$	329.8		$	424.7		$	391.5

S- 12


			Consolidated
			historical

			For nine						For nine months ended
			months ended						September 30, 2005
			September 30,
											Pro forma
			2004			2005			Pro forma		as adjusted

			(unaudited)
			(dollars in millions)
Reconciliation of Non-GAAP “Gross operating margin” to GAAP “Operating income”
Operating Income			$	247.7		$	485.4		$	479.6	$	479.6
	Adjustments to reconcile Operating income to Gross operating margin:
		Depreciation and amortization in operating costs and expenses		94.7			304.0			304.0		304.0
		Retained lease expense, net in operating costs and expenses		6.8			1.6			1.6		1.6
		Loss (gain) on sale of assets in operating costs and expenses		0.2			(4.7	)		0.8		0.8
		General and administrative costs		26.6			46.7			46.7		46.7

Gross operating margin			$	376.0		$	833.0		$	832.7	$	832.7

Reconciliation of Non-GAAP “EBITDA” to GAAP “Net income” or “Income from continuing operations” and GAAP “Cash provided by operating activities”
Net income (Income from continuing operations with regards to pro forma information)			$	152.9		$	311.1		$	305.8	$	309.4
	Adjustments to derive EBITDA:
		Interest expense		97.0			170.7			170.2		166.6
		Provision for income taxes		2.7			4.0			4.0		4.0
		Depreciation and amortization (excluding amortization component in interest expenses)		95.0			309.1			309.1		309.1

EBITDA				347.6			794.9		$	789.1	$	789.1

	Interest expense			(97.0	)		(170.7	)
	Amortization in interest expense			2.9			(0.1	)
	Provision for income taxes			(2.7	)		(4.0	)
	Cumulative effect of change in accounting principle			4.0			—
	Equity in income of unconsolidated affiliates			(42.2	)		(14.6	)
	Distributions from unconsolidated affiliates			54.6			47.4
	Loss (gain) on sale of assets			0.2			(4.7	)
	Operating lease expense paid by EPCO (excluding minority interest portion)			6.8			1.6
	Minority interest			6.8			3.2
	Deferred income tax expense			6.3			5.8
	Changes in fair market value of financial instruments			(10.8	)		—
	Net effect of changes in operating accounts			(240.5	)		(314.2	)

Cash provided by operating activities			$	36.0		$	344.6

S- 13

Risk factors

An investment in our common units involves risks. You should consider carefully the risk factors included below, under the caption “Risk Factors” beginning on page 3 of the accompanying prospectus, and under “Business and Properties— Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2004, together with all of the other information included in, or incorporated by reference into, this prospectus supplement, when evaluating an investment in our common units. If any of these risks were to occur, our business, financial condition or results of operations could be materially adversely affected. In that case, the trading price of our common units could decline and you could lose all or part of your investment.

RISKS RELATED TO OUR BUSINESS

Our debt level may limit our future financial and operating flexibility.

As of September 30, 2005, on a pro forma as adjusted basis, we had approximately $4.7 billion of consolidated debt outstanding. Our debt level could have significant effects on our future operations, including, among other things:


•	a significant portion of our cash flow from operations will be dedicated to the payment of principal and interest on outstanding debt and will not be available for other purposes, including capital expenditures;

•	credit rating agencies may view our debt level negatively;

•	covenants contained in our existing debt arrangements will require us to continue to meet financial tests that may adversely affect our flexibility in planning for and reacting to changes in our business;

•	our ability to obtain additional financing for working capital, capital expenditures, acquisitions and general partnership purposes may be limited;

•	we may be at a competitive disadvantage relative to similar companies that have less debt; and

•	we may be more vulnerable to adverse economic and industry conditions as a result of our significant debt level.

Our public debt indentures currently do not limit the amount of future indebtedness that we can create, incur, assume or guarantee. Our multi-year revolving credit facility, however, restricts our ability to incur additional debt, though any debt we may incur in compliance with these restrictions may still be substantial.

Our multi-year revolving credit facility and indentures for our public debt contain conventional financial covenants and other restrictions. A breach of any of these restrictions by us could permit the lenders to declare all amounts outstanding under those debt agreements to be immediately due and payable and, in the case of the credit facility, to terminate all commitments to extend further credit.

S- 14

Risk factors

our short-term securities or to refinance some of our debt obligations through bank credit, as opposed to long-term public debt securities or equity securities. The price and terms upon which we might receive such extensions or additional bank credit, if at all, could be more onerous than those contained in existing debt agreements. Any such arrangements could, in turn, increase the risk that our leverage may adversely affect our future financial and operating flexibility and thereby impact our ability to make cash distributions.

We could be required to divest significant assets as a result of a non-public investigation by the Bureau of Competition of the Federal Trade Commission.

On February 24, 2005, an affiliate of EPCO acquired Texas Eastern Products Pipeline Company, LLC, or TEPPCO GP, from Duke Energy Field Services, LLC. TEPPCO GP owns a 2% general partner interest in and is the general partner of TEPPCO Partners, L.P., or TEPPCO. On March 11, 2005, the Bureau of Competition of the Federal Trade Commission delivered written notice to the EPCO affiliate’s legal advisor that it was conducting a non-public investigation to determine whether such affiliate’s acquisition of TEPPCO GP may substantially lessen competition. No filings were required under the Hart-Scott-Rodino Act in connection with the EPCO affiliate’s purchase of TEPPCO GP. EPCO and its affiliates may receive similar inquiries from other regulatory authorities. We intend to cooperate fully with any such investigation and inquiries. In response to such FTC investigation or any inquiries EPCO and its affiliates may receive from other regulatory authorities, we may be required to divest certain assets. In the event we are required to divest significant assets, our future financial and operating flexibility may be materially adversely affected, which could impact our ability to make cash distributions.

Substantially all of the equity interests in us that are owned by EPCO and its affiliates and by Enterprise GP Holdings are pledged as security under EPCO’s and Enterprise GP Holding’s credit facility, respectively. Upon an event of default under either of these credit facilities, a change in control of us could result.

EPCO has pledged substantially all of its limited partner interests in us as security under its revolving credit facility with a syndicate of banks. EPCO’s revolving credit facility contains customary and other events of default relating to defaults of EPCO and certain of its subsidiaries, including certain defaults by us and other EPCO affiliates. An event of default, followed by a foreclosure on EPCO’s pledged collateral, could result in a change in control of us. In addition, the 100% membership interest in our general partner and the 13,454,498 of our common units that are owned by Enterprise GP Holdings are pledged under Enterprise GP Holdings’ credit facility. Enterprise GP Holdings’ credit facility contains customary and other events of default. Upon an event of default, the lenders under Enterprise GP Holdings’ credit facility could foreclose on Enterprise GP Holdings’ assets, which could result in a change in control of us.

The credit and risk profile of our general partner and its owners could adversely affect our credit ratings and profile.

The credit and business risk profiles of the general partner or owners of a general partner may be factors in credit evaluations of a master limited partnership. This is because the general partner can exercise significant influence over the business activities of the partnership, including its cash distribution and acquisition strategy and business risk profile. Another factor that may be considered is the financial condition of the general partner and its owners, including the degree of their financial leverage and their dependence on cash flow from the partnership to service their indebtedness. Entities controlling the owner of our general partner have significant indebtedness outstanding and are dependent principally on the cash flow from their general partner and limited partner equity interests

S- 15

Risk factors

in us to service such indebtedness. Any distributions by us to such entities will be made only after satisfying our then current obligations to our creditors. Although we have taken certain steps in our organizational structure, financial reporting and contractual relationships to reflect the separateness of us and our general partner from the entities that control our general partner, our credit ratings and business risk profile could be adversely affected if the ratings and risk profiles of the entities that control our general partner were viewed as substantially lower or more risky than ours.

An impairment of goodwill could reduce our earnings.

We had $489.4 million of goodwill and $941.5 million of intangible assets recorded on our consolidated balance sheet at September 30, 2005. Goodwill is recorded when the purchase price of a business exceeds the fair market value of the tangible and separately measurable intangible net assets. GAAP will require us to test goodwill for impairment on an annual basis or when events or circumstances occur indicating that goodwill might be impaired. Long-lived assets such as intangible assets with finite useful lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. If we determine that any of our goodwill or intangible assets were impaired, we would be required to take an immediate charge to earnings with a correlative effect on partners’ equity and balance sheet leverage as measured by debt to total capitalization.

Increases in interest rates could adversely affect our business.

In addition to our exposure to commodity prices, we have significant exposure to increases in interest rates. As of September 30, 2005, we had approximately $4.8 billion of consolidated debt, of which approximately $3.3 billion was at fixed interest rates and approximately $1.5 billion was at variable interest rates, after giving effect to existing interest rate swap arrangements. We may from time to time enter into additional interest rate swap arrangements, which could increase our exposure to variable interest rates. As a result, our results of operations, cash flows and financial condition, could be materially adversely affected by significant increases in interest rates.

Some of our executive officers face conflicts in the allocation of their time to our business.

Some of our general partner’s executive officers allocate their time among EPCO, Enterprise GP Holdings, TEPPCO and other EPCO affiliates. These officers face conflicts regarding the allocation of their time, which may adversely affect our business, results of operations and financial condition.

The sale or exchange of 50% or more of our capital and profits interests during any twelve-month period will result in the termination of our partnership for federal income tax purposes.

We will be considered to have terminated for federal income tax purposes if there is a sale or exchange of 50% or more of the total interests in our capital and profits within a twelve-month period. Our termination would, among other things, result in the closing of our taxable year for all unitholders and could result in a deferral of depreciation deductions allowable in computing our taxable income. Please read “Material Tax Consequences—Disposition of Common Units—Constructive Termination” in the accompanying prospectus for a discussion of the consequences of our termination for federal income tax purposes.

Federal, state or local regulatory measures could materially adversely affect our business.

S- 16

Risk factors

regulatory agencies regulate our intrastate natural gas and NGL pipelines, intrastate storage facilities and gathering lines.

For example, in December 2002, High Island Offshore System, L.L.C., or HIOS, an interstate natural gas pipeline owned by us, filed a rate case pursuant to Section 4 of the Natural Gas Act before FERC to increase its transportation rates. FERC accepted HIOS’ tariff sheets implementing the new rates, subject to refund, and set certain issues for hearing before an Administrative Law Judge, or ALJ. The ALJ issued an initial decision on the issues set for hearing on April 22, 2004, proposing rates lower than the rate initially proposed by HIOS. In response to the ALJ’s initial decision, HIOS filed, on August 5, 2004, a settlement agreement whereby HIOS proposed to implement its rates in effect prior to this proceeding for a prospective three-year period.

On January 24, 2005, FERC issued an order rejecting HIOS’s settlement offer and generally affirming the ALJ’s initial decision, resulting in rates significantly lower than the rate proposed in HIOS’ settlement offer. On July 7, 2005, FERC denied the requests for rehearing of FERC’s January 24 order and ordered HIOS to implement the approved rates and make refunds to its customers. HIOS has complied with the directives. HIOS also filed a request for rehearing and clarification of certain aspects of the July 7 order as well as a petition for review with the U.S. Court of Appeals for the D.C. Circuit. We are not able to predict the outcome of the HIOS proceeding.

Our latest Quarterly Report on Form 10-Q and Annual Report on Form 10-K, which are incorporated by reference into this prospectus, contain a general overview of FERC and state regulation applicable to our energy infrastructure assets. This regulatory oversight can affect certain aspects of our business and the market for our products and could materially adversely affect our cash flow. Please read “Business and Properties—Regulation and Environmental Matters” in our latest Annual Report on Form 10-K.

S- 17

Use of proceeds

We will receive net proceeds of approximately $99.6 million from the sale of the 4,000,000 common units in this offering (including the net capital contribution of $2.0 million from our general partner to maintain its 2% general partner interest) after deducting underwriting discounts, commissions and estimated offering expenses payable by us. If the underwriter exercises its over-allotment option in full, we will receive net proceeds of approximately $114.6 million, including a proportionate net capital contribution of $2.3 million from our general partner. We will use the net proceeds of this offering to temporarily reduce borrowings outstanding under our multi-year revolving credit facility. In general, our indebtedness under the multi-year revolving credit facility was incurred for working capital purposes, capital expenditures and business combinations. Amounts repaid under our multi-year revolving credit facility may be reborrowed from time to time for acquisitions, capital expenditures and other general partnership purposes. An affiliate of the underwriter is a lender under our multi-year revolving credit facility and, as such, will receive its share of any repayment of amounts outstanding under this facility.

As of November 29, 2005, we had $610.0 million of borrowings outstanding under our multi-year revolving credit facility that bears interest at a variable rate, which is currently approximately 4.8% per annum. Our multi-year revolving credit facility matures in October 2010.

S- 18

Price range of common units and distributions

On November 29, 2005, we had 385,861,168 common units outstanding, beneficially held by approximately 150,000 holders. Our common units are traded on the New York Stock Exchange under the symbol “EPD.”

The following table sets forth, for the periods indicated, the high and low sales price ranges for our common units, as reported on the New York Stock Exchange Composite Transaction Tape, and the amount, record date and payment date of the quarterly cash distributions paid per common unit. The last reported sales price of our common units on the New York Stock Exchange on November 29, 2005 was $25.54 per common unit.


						Cash distribution history
		Price ranges
						Per
		High		Low		unit⁽¹⁾			Record date		Payment date

2003
	1st Quarter	$	21.00	$	17.85	$	0.3625			April 30, 2003		May 12, 2003
	2nd Quarter		24.69		20.62		0.3625			July 31, 2003		August 11, 2003
	3rd Quarter		24.10		20.25		0.3725			October 31, 2003		November 12, 2003
	4th Quarter		24.98		20.76		0.3725			January 30, 2004		February 11, 2004
2004
	1st Quarter	$	24.72	$	21.75	$	0.3725			April 30, 2004		May 12, 2004
	2nd Quarter		23.84		20.00		0.3725			July 30, 2004		August 6, 2004
	3rd Quarter		23.70		20.19		0.3950			October 29, 2004		November 5, 2004
	4th Quarter		25.99		22.73		0.4000			January 31, 2005		February 14, 2005
2005
	1st Quarter	$	28.35	$	23.92	$	0.4100			April 29, 2005		May 10, 2005
	2nd Quarter		27.09		24.77		0.4200			July 29, 2005		August 10, 2005
	3rd Quarter		27.66		23.50		0.4300			October 31, 2005		November 8, 2005
	4th Quarter⁽²⁾		26.02		24.30		—	⁽³⁾		—		—


(1)	For each quarter, we paid an identical cash distribution on all outstanding subordinated units. The remaining outstanding subordinated units converted into an equal number of common units on August 1, 2003. In addition, we paid an identical cash distribution per unit to the holder of our Class B special units prior to their conversion to common units on July 29, 2004.

(2)	Through November 29, 2005.

(3)	The distribution with respect to the fourth quarter of 2005 has neither been declared nor paid.

S- 19

Capitalization

The following table sets forth our capitalization as of September 30, 2005:


•	on a consolidated historical basis;

•	on a pro forma basis to give effect to (i) the sale of 403,118 common units in November 2005 in connection with our DRIP and related programs, (ii) our general partner’s proportionate net capital contribution and (iii) the application of the net proceeds to temporarily reduce debt outstanding under our multi-year revolving credit facility; and

•	on a pro forma as adjusted basis to give effect to (i) the sale of 4,000,000 common units in this offering at an offering price of $25.03 per common unit, (ii) our general partner’s proportionate net capital contribution and (iii) the application of the net proceeds as described under “Use of Proceeds.”

The historical data in the table on the following page are derived from and should be read in conjunction with our historical financial statements, including the accompanying notes, incorporated by reference in this prospectus supplement. Please read our unaudited pro forma condensed consolidated financial statements beginning on page F-1 this prospectus supplement for a complete description of the adjustments we have made to arrive at the pro forma as adjusted capitalization that we present in the following table. You should also read our financial statements and notes that are incorporated by reference in this prospectus supplement for additional information regarding our capital structure.

S- 20

Capitalization

Historical and pro forma capitalization

As of September 30, 2005


									Pro forma
			Historical			Pro forma			As adjusted

			(dollars in millions)
Cash and cash equivalents			$	32.7		$	32.7		$	32.7

Long-term borrowings, including current portions:
	Multi-Year Revolving Credit Facility, variable rate, due October 2010		$	335.0		$	324.9		$	225.3
	30-Day Promissory Note, variable rate, repaid October 2005			100.0			100.0			100.0
	Seminole Notes, 6.67% fixed-rate, $15 million due in December 2005			15.0			15.0			15.0
	Pascagoula MBFC Loan, 8.70% fixed-rate, due March 2010			54.0			54.0			54.0
	Senior Notes B, 7.50% fixed-rate, due February 2011			450.0			450.0			450.0
	Senior Notes C, 6.375% fixed-rate, due February 2013			350.0			350.0			350.0
	Senior Notes D, 6.875% fixed-rate, due March 2033			500.0			500.0			500.0
	Senior Notes E, 4.00% fixed-rate, due October 2007			500.0			500.0			500.0
	Senior Notes F, 4.625% fixed-rate, due October 2009			500.0			500.0			500.0
	Senior Notes G, 5.60% fixed-rate, due October 2014			650.0			650.0			650.0
	Senior Notes H, 6.65% fixed-rate, due October 2034			350.0			350.0			350.0
	Senior Notes I, 5.00% fixed-rate, due March 2015			250.0			250.0			250.0
	Senior Notes J, 5.75% fixed-rate, due March 2035			250.0			250.0			250.0
	Senior Notes K, 4.95% fixed-rate, due June 2010			500.0			500.0			500.0
	Dixie revolving credit facility, due June 2007			17.0			17.0			17.0
	GulfTerra senior notes and senior subordinated notes			5.6			5.6			5.6
	Other, including unamortized discounts and premiums			(22.8	)		(22.8	)		(22.8	)

		Total debt obligations		4,803.8			4,793.7			4,694.1

Minority interest				90.2			90.2			90.2

Partners’ equity
	Limited partners			5,530.2			5,540.1			5,637.7
	General partner			112.9			113.1			115.1
	Accumulated other comprehensive income			20.2			20.2			20.2
	Other			(15.6	)		(15.6	)		(15.6	)

		Total partners’ equity		5,647.7			5,657.8			5,757.4

		Total capitalization	$	10,541.7		$	10,541.7		$	10,541.7

S- 21

Management

OUR MANAGEMENT

The following table sets forth certain information with respect to the executive officers and members of the board of directors of our general partner. Executive officers and directors are elected for one-year terms. Each executive officer holds the same respective office shown below in the general partner of our subsidiary operating partnership.


Name	Age		Position with General Partner of Enterprise

Dan L. Duncan		72	Director and Chairman
O.S. Andras		70	Director
Robert G. Phillips		51	Director, President and Chief Executive Officer
E. William Barnett		72	Director*
Philip C. Jackson		77	Director*
W. Matt Ralls		56	Director*
Richard S. Snell		63	Director*
Richard H. Bachmann		52	Executive Vice President, Secretary and Chief Legal Officer
Michael A. Creel		51	Executive Vice President and Chief Financial Officer
Dr. Ralph S. Cunningham		65	Group Executive Vice President and Chief Operating Officer**
James H. Lytal		48	Executive Vice President
A. James Teague		60	Executive Vice President
Charles E. Crain		72	Senior Vice President
W. Ordemann		46	Senior Vice President
Gil H. Radtke		44	Senior Vice President
James M. Collingsworth		51	Senior Vice President
James A. Cisarik		47	Senior Vice President
Lynn L. Bourdon, III		43	Senior Vice President
Richard A. Hoover		48	Senior Vice President
Michael J. Knesek		51	Senior Vice President, Controller and Principal Accounting Officer
W. Randall Fowler		49	Senior Vice President and Treasurer
Rudy A. Nix		48	Senior Vice President


*	Independent directors


**	Effective December 1, 2005

Dan L. Duncan was elected Chairman and a Director of our general partner in April 1998 and Chairman and a Director of the general partner of our operating partnership in December 2003. Mr. Duncan has served as Chairman and a Director of the general partner of Enterprise GP Holdings since August 2005, and has served as Chairman of the Board of our predecessor, EPCO, Inc., since 1979.

O.S. Andras served as Vice Chairman and a Director of our general partner from February 2005 until July 1, 2005, at which time he retired as Vice Chairman but continues to serve as a non-executive

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Management

director. Mr. Andras served as Chief Executive Officer, Vice Chairman and a Director of our general partner from September 2004 to February 2005. Mr. Andras served as President, Chief Executive Officer and a Director of our general partner from April 1998 until September 2004. He served as a Director of the general partner of our operating partnership from December 2003 to July 1, 2005. Mr. Andras served as President and Chief Executive Officer of EPCO from 1996 to February 2001 and served as Vice Chairman of the Board of EPCO until July 1, 2005.

Robert G. Phillips was elected President and Chief Executive Officer of our general partner in February 2005. Mr. Phillips served as President, Chief Operating Officer and Director of our general partner from September 2004 to February 2005. Mr. Phillips served as a Director of GulfTerra’s general partner from August 1998 until September 2004, and he has served as a Director of the general partner of our operating partnership since September 2004. He served as Chief Executive Officer for GulfTerra and its general partner from November 1999 and as Chairman from October 2002 until September 2004. He served as Executive Vice President from August 1998 to October 1999. Mr. Phillips served as President of El Paso Field Services Company between June 1997 and September 2004. He served as President of El Paso Energy Resources Company from December 1996 to June 1997, President of El Paso Field Services Company from April 1996 to December 1996 and Senior Vice President of El Paso Corporation from September 1995 to April 1996. For more than five years prior, Mr. Phillips was Chief Executive Officer of Eastex Energy, Inc.

E. William Barnett was elected a Director of our general partner in March 2005. Mr. Barnett practiced law with Baker Botts L.L.P. from 1958 until his retirement in 2004. In 1984, he became Managing Partner of Baker Botts L.L.P. and continued in that role for 14 years until 1998. He was Senior Counsel to the firm from 1998 until June 1, 2004 when he retired from the firm. Mr. Barnett is Chairman of the Board of Trustees of Rice University; a Life Trustee of The University of Texas Law School Foundation; a director of St. Luke’s Episcopal Health System; a director of the Center for Houston’s Future and a current director and former Chairman of the Board of Directors of the Houston Zoo, Inc. (the operating arm of the Houston Zoo). He is a director of Reliant Energy, Inc., a publicly traded electric services company. He is also a director and former Chairman of the Greater Houston Partnership. He also served as a trustee of Baylor College of Medicine from 1993 until 2004. Mr. Barnett is a member of our general partner’s Audit and Conflicts Committee and serves as Chairman of its Governance Committee.

Philip C. Jackson was elected a director of our general partner in August 2005. Mr. Jackson was an Adjunct Professor of Finance at Birmingham-Southern College from 1989 until his retirement in 1999. Mr. Jackson also served as Vice Chairman of Compass Bancshares, Inc. from 1980 until 1989 and as a consultant and outside director from 1978 until 1980. He was a member of the Board of Governors of the Federal Reserve System from 1975 until 1978. Mr. Jackson is currently a member of the Advisory Board of Compass Bank, a Trustee of Birmingham-Southern College, a Director of Saul Centers, Inc., a publicly traded real estate investment trust, and a Governor of the Mortgage Bankers Association of America. Mr. Jackson is a member of our general partner’s Audit and Conflicts Committee.

W. Matt Ralls was elected a Director of our general partner in September 2004. Mr. Ralls served as a Director of GulfTerra’s general partner from May 2003 to September 2004 and is the Senior Vice President and Chief Financial Officer of GlobalSantaFe, an international contract drilling company. From 1997 to 2001, he was Vice President, Chief Financial Officer, and Treasurer of Global Marine, Inc. Previously, he served as Executive Vice President, Chief Financial Officer, and Director of Kelley Oil and Gas Corporation and as Vice President of Capital Markets and Corporate Development for The Meridian Resource Corporation before joining Global Marine. He spent the first 17 years of his career in commercial banking at the senior management level. Mr. Ralls serves as Chairman of our general partner’s Audit and Conflicts Committee and is a member of our general partner’s Governance Committee.

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Management

Richard S. Snell was elected a Director of our general partner in June 2000. Mr. Snell was an attorney with the Snell & Smith, P.C. law firm in Houston, Texas from the founding of the firm in 1993 until May 2000. Since May 2000, he has been a partner with the law firm of Thompson & Knight LLP in Houston, Texas. Mr. Snell is also a certified public accountant. Mr. Snell is a member of our general partner’s Governance Committee.

Richard H. Bachmann was elected Executive Vice President, Chief Legal Officer and Secretary of our general partner and EPCO in January 1999. Mr. Bachmann served as a Director of our general partner from June 2000 to January 2004. Mr. Bachmann has served as a Director of the general partner of our operating partnership since December 2003, and has served as Executive Vice President, Chief Legal Officer and Secretary of the general partner of Enterprise GP Holdings since August 2005.

Michael A. Creel was elected an Executive Vice President of our general partner and EPCO in February 2001, having served as a Senior Vice President of our general partner and EPCO since November 1999. In June 2000, Mr. Creel, a certified public accountant, assumed the role of Chief Financial Officer of our general partner and EPCO along with his other responsibilities. Mr. Creel has served as a Director of the general partner of our operating partnership since December 2003, and has served as President and Chief Executive Officer and a Director of the general partner of Enterprise GP Holdings since August 2005. In addition, Mr. Creel was appointed to the board of directors of Edge Petroleum Corporation (a publicly traded oil and natural gas exploration and production company) in October 2005.

Dr. Ralph S. Cunningham was elected Group Executive Vice President and Chief Operating Officer of our general partner on November 23, 2005, effective December 1, 2005. Dr. Cunningham previously served as a Director of our general partner from 1998 until March 2005, and served as Chairman and a Director of the general partner of TEPPCO Partners, L.P. from March 2005 until November 2005. He retired in 1997 from CITGO Petroleum Corporation, where he had served as President and Chief Executive Officer since 1995. He serves as a director of Tetra Technologies, Inc. (a publicly traded energy services and chemicals company), EnCana Corporation (a Canadian publicly traded independent oil and natural gas company) and Agrium, Inc. (a Canadian publicly traded agricultural chemicals company) and was a director of EPCO from 1987 to 1997.

James H. Lytal was elected Executive Vice President of our general partner in September 2004. Mr. Lytal served as a Director of GulfTerra’s general partner from August 1994 until September 2004 and as GulfTerra’s President and the President of GulfTerra’s general partner from July 1995 until September 2004. He served as Senior Vice President of GulfTerra and its general partner from August capacities in the oil and gas exploration and production and gas pipeline industries with United Gas Pipeline Company, Texas Oil and Gas, Inc. and American Pipeline Company.

A.J. Teague was elected an Executive Vice President of our general partner in November 1999. From 1998 to 1999, he served as President of Tejas Natural Gas Liquids, LLC, then a Shell affiliate.

Charles E. Crain was elected a Senior Vice President of our general partner in April 1998. Mr. Crain served as Senior Vice President of Operations for EPCO from 1991 to 1998.

William Ordemann joined us as a Vice President of our general partner in October 1999 and was elected a Senior Vice President in September 2001. From January 1997 to February 1998, Mr. Ordemann was a Vice President of Shell Midstream Enterprises, LLC, and from February 1998 to September 1999 was a Vice President of Tejas Natural Gas Liquids, LLC, both Shell affiliates. In July 2005, Mr. Ordemann was elected a Senior Vice President of Texas Eastern Products Pipeline Company LLC.

Gil H. Radtke was elected a Senior Vice President of our general partner in February 2002. Mr. Radtke joined us in connection with our purchase of Diamond-Koch’s storage and propylene

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Management

fractionation assets in January and February 2002. Before joining us, Mr. Radtke served as President of the Diamond-Koch joint venture from 1999 to 2002, where he was responsible for its storage, propylene fractionation, pipeline and NGL fractionation businesses. From 1997 to 1999 he was Vice President, Petrochemicals and Storage of Diamond-Koch.

James M. Collingsworth joined our general partner as a Vice President in November 2001 and was elected a Senior Vice President in November 2002. Previously, he served as a board member of Texaco Canada Petroleum Inc. from July 1998 to October 2001 and was employed by Texaco from 1991 to 2001 in various management positions, including Senior Vice President of NGL Assets and Business Services from July 1998 to October 2001.

James A. Cisarik was elected a Senior Vice President of our general partner in February 2003. Mr. Cisarik joined us in April 2001 when we acquired Acadian Gas from Shell. His primary responsibility since joining us has been oversight of the commercial activities of our natural gas businesses, principally those of Acadian Gas and our Gulf of Mexico natural gas pipeline investments. From February 1999 through March 2001, Mr. Cisarik was a Senior Vice President of Coral Energy, LLC, and from 1997 to February 1999 was Vice President, Market Development of Tejas Energy, LLC, both affiliates of Shell, with responsibilities in market development for their Texas and Louisiana natural gas pipeline systems.

Lynn L. Bourdon, III was elected a Senior Vice President of our general partner on December 10, 2003. His primary responsibility since joining us has been oversight of all NGL supply and marketing functions. Previously, Mr. Bourdon served as Senior Vice President and Chief Commercial Officer of Orion Refining Corporation from July 2001 through November 2003, and was a shareholder in En*Vantage, Inc., a business investment and energy services company serving the petrochemicals and energy industries, from September 1999 through July 2001. He also served as a Senior Vice President of PG&E Corporation for gas transmission commercial operations from August 1997 through August 1999.

Richard A. Hoover was elected Senior Vice President of our general partner in September 2004. Mr. Hoover served as GulfTerra’s Vice President Western Division— Commercial from January 2001 until September 2004. This position included management of GulfTerra’s San Juan and Permian Basin assets. Mr. Hoover has held various other commercial positions since joining GulfTerra in June 1996 including management of assets in the Texas Gulf Coast, Anadarko Basin, Mid Continent and Rockies. Prior to joining GulfTerra, Mr. Hoover held various positions over 16 years in the Midstream, Independent Power and E&P sectors with Delhi Gas Pipeline Corporation, Panda Energy Corporation and Champlin Petroleum Corporation.

Michael J. Knesek was elected Senior Vice President and Principal Accounting Officer of our general partner in February 2005. Mr. Knesek served as Principal Accounting Officer and a Vice President of our general partner from August 2000 to February 2005. Mr. Knesek has served as Senior Vice President, Controller and Principal Accounting Officer of Enterprise GP Holdings since August 2005. Since 1990, Mr. Knesek, a certified public accountant, has been the Controller and a Vice President of EPCO.

W. Randall Fowler was elected Senior Vice President and Treasurer of our general partner in February 2005. Mr. Fowler, a certified public accountant (inactive), joined us as director of investor relations in January 1999 and served as Treasurer and a Vice President of our general partner and EPCO from August 2000 to February 2005. Mr. Fowler has served as Senior Vice President and Chief Financial Officer of Enterprise GP Holdings since August 2005.

Rudy A. Nix was elected Senior Vice President of our general partner in August 2005. Mr. Nix served as Vice President of Distribution for our general partner for the preceding five years.

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Tax consequences

The tax consequences to you of an investment in common units will depend in part on your own tax circumstances. For a discussion of the principal federal income tax considerations associated with our operations and the ownership and disposition of common units, please read “Material Tax Consequences” beginning on page 47 of the accompanying prospectus. We recommend that you consult your own tax advisor about the federal, state, local and foreign tax consequences that are specific to your particular circumstances.

We estimate that if you purchase common units in this offering and own them through December 31, 2007, then you will be allocated, on a cumulative basis, an amount of federal taxable income for that period that will be less than 10% of the cash distributed with respect to that period. If you own common units purchased in this offering for a shorter period, the percentage of federal taxable income allocated to you may be higher. These estimates are based upon the assumption that our available cash for distribution will approximate the amount required to distribute cash to the holders of the common units in an amount equal to the quarterly distribution of $0.43 per unit and other assumptions with respect to capital expenditures, cash flow and anticipated cash distributions. These estimates and assumptions are subject to, among other things, numerous business, economic, regulatory, competitive and political uncertainties beyond our control. Further, the estimates are based on current tax law and certain tax reporting positions that we have adopted with which the IRS could disagree. In addition, subsequent issuances of equity securities by us could also affect the percentage of distributions that will constitute taxable income. Accordingly, we cannot assure you that the estimates will be correct. The actual percentage of distributions that will constitute taxable income could be higher or lower, and any differences could be material and could materially affect the value of the common units.

For example, the ratio of allocable taxable income to cash distributions to a purchaser of common units in this offering may be greater, and perhaps substantially greater, than 10% with respect to the period described above if:


•	gross profit exceeds the amount required to make quarterly distributions of $0.43 on all common units, yet we only distribute $0.43 per common unit each quarter; or

•	we make a future offering of common units and use the proceeds of the offering in a manner that does not produce substantial additional deductions during the period described above, such as to repay indebtedness outstanding at the time of this offering or to acquire property that is not eligible for depreciation or amortization for federal income tax purposes or that is depreciable or amortizable at a rate significantly slower than the rate applicable to our assets at the time of this offering.

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Investment in us by employee benefit plans

An investment in our units by an employee benefit plan is subject to additional considerations because the investments of these plans are subject to the fiduciary responsibility and prohibited transaction provisions of ERISA, and restrictions imposed by Section 4975 of the Internal Revenue Code. For these purposes, the term “employee benefit plan” includes, but is not limited to, qualified pension, profit-sharing and stock bonus plans, Keogh plans, simplified employee pension plans and tax deferred annuities or IRAs established or maintained by an employer or employee organization. Among other things, consideration should be given to:


•	whether the investment is prudent under Section 404(a)(l)(B) of ERISA;

•	whether in making the investment, that plan will satisfy the diversification requirements of Section 404(a)(l)(C) of ERISA; and

•	whether the investment will result in recognition of unrelated business taxable income (please read “Material Tax Consequences— Tax-Exempt Organizations and Other Investors”) by the plan and, if so, the potential after-tax investment return.

In addition, the person with investment discretion with respect to the assets of an employee benefit plan, often called a fiduciary, should determine whether an investment in our units is authorized by the appropriate governing instrument and is a proper investment for the plan.

Section 406 of ERISA and Section 4975 of the Internal Revenue Code prohibit employee benefit plans, and IRAs that are not considered part of an employee benefit plan, from engaging in specified transactions involving “plan assets” with parties that are “parties in interest” under ERISA or “disqualified persons” under the Internal Revenue Code with respect to the plan. Therefore, a fiduciary of an employee benefit plan or an IRA accountholder that is considering an investment in our units should consider whether the entity’s purchase or ownership of such units would or could result in the occurrence of such a prohibited transaction.

In addition to considering whether the purchase of units is or could result in a prohibited transaction, a fiduciary of an employee benefit plan should consider whether the plan will, by investing in our units, be deemed to own an undivided interest in our assets, with the result that our general partner also would be a fiduciary of the plan and our operations would be subject to the regulatory restrictions of ERISA, including fiduciary standard and its prohibited transaction rules, as well as the prohibited transaction rules of the Internal Revenue Code.

The Department of Labor regulations provide guidance with respect to whether the assets of an entity in which employee benefit plans acquire equity interests would be deemed “plan assets” under some circumstances. Under these regulations, an entity’s assets would not be considered to be “plan assets” if, among other things:


•	the equity interests acquired by employee benefit plans are publicly offered securities; i.e., the equity interests are widely held by 100 or more investors independent of the issuer and each other, freely transferable and registered under some provisions of the federal securities laws;

•	the entity is an “operating company;” i.e., it is primarily engaged in the production or sale of a product or service other than the investment of capital either directly or through a majority owned subsidiary or subsidiaries; or

•	there is no significant investment by benefit plan investors, which is defined to mean that less than 25% of the value of each class of equity interest, disregarding some interests held by our general partner, its affiliates, and some other persons, is held by the employee benefit plans referred to above, IRAs and other employee benefit plans not subject to ERISA, including governmental plans.

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Investment in us by employee benefit plans

Our assets should not be considered “plan assets” under these regulations because it is expected that the investment will satisfy the requirements in the first bullet point above.

Plan fiduciaries contemplating a purchase of units should consult with their own counsel regarding the consequences under ERISA and the Internal Revenue Code in light of the serious penalties imposed on persons who engage in prohibited transactions or other violations.

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Underwriting

We are offering the common units described in this prospectus supplement through UBS Securities LLC, the sole underwriter in this offering. Subject to the terms and conditions stated in the underwriting agreement dated the date of this prospectus supplement, which we will file as an exhibit to a Current Report on Form 8-K, the underwriter has agreed to purchase from us all 4,000,000 common units offered by this prospectus supplement. However, the underwriter is not required to take or pay for the common units covered by the underwriter’s over-allotment option described below.

The underwriting agreement provides that the underwriter’s obligation to purchase the common units depends on the satisfaction of the conditions contained in the underwriting agreement, and that if any of the common units are purchased by the underwriter, all of the common units must be purchased. The conditions contained in the underwriting agreement include the condition that all the representations and warranties made by us and our affiliates to the underwriter are true, that there has been no material adverse change in the condition of us or in the financial markets and that we deliver to the underwriter customary closing documents.

Over-Allotment Option

We have granted to the underwriter an option to purchase up to an aggregate of 600,000 additional common units at the offering price to the public less the underwriting discount set forth on the cover page of this prospectus supplement exercisable to cover over-allotments. Such option may be exercised in whole or in part at any time until 30 days after the date of this prospectus supplement. If this option is exercised, the underwriter will be committed, subject to satisfaction of the conditions specified in the underwriting agreement, to purchase such additional common units, and we will be obligated, pursuant to the option, to sell these common units to the underwriter.

Commissions and Expenses

The following table shows the underwriting fees to be paid to the underwriter by us in connection with this offering. These amounts are shown assuming both no exercise and full exercise of the underwriter’s option to purchase additional common units. This underwriting fee is the difference between the offering price to the public and the amount the underwriter pays to us to purchase the common units.


		Paid By Us

		No Exercise		Exercise

Price per common unit		$	0.51	$	0.51
	Total	$	2,040,000	$	2,346,000

We have been advised by the underwriter that the underwriter proposes to offer the common units directly to the public at the offering price to the public set forth on the cover page of this prospectus supplement and to dealers at this price to the public less a concession not in excess of $0.45 per common unit.

The underwriter may allow, and the dealers may reallow, a concession not in excess of $0.10 per common unit to certain brokers and dealers. After the offering, the underwriter may change the offering price and other selling terms.

We estimate that total expenses of the offering, other than underwriting discounts and commissions, will be approximately $500,000.

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Underwriting

Indemnification

We and certain of our affiliates have agreed to indemnify the underwriter against certain liabilities, including liabilities under the Securities Act of 1933, as amended, and to contribute to payments that may be required to be made in respect of these liabilities.

Lock-Up Agreements

We, certain of our affiliates, Shell and the directors and executive officers of our general partner have agreed that we and they will not, directly or indirectly, sell, offer, pledge or otherwise dispose of any common units or enter into any derivative transaction with similar effect as a sale of common units for a period of 45 days after the date of this prospectus supplement without the prior written consent of UBS Securities LLC. The restrictions described in this paragraph do not apply to:


•	the issuance and sale of common units by us to the underwriter pursuant to the underwriting agreement;

•	the issuance and sale of common units, phantom units, restricted units and options under our existing employee benefits plans, including sales pursuant to “cashless-broker” exercises of options to purchase common units in accordance with such plans as consideration for the exercise price and withholding taxes applicable to such exercises;

•	the issuance and sale of common units pursuant to our distribution reinvestment plan; or

•	the filing of a “universal” shelf registration statement on Form S-3, which may also include common units of selling unitholders; provided, that (1) we and our affiliates remain subject to the 45-day lock-up period with respect to any common units registered under any such registration statement, (2) such registration statement contains only a generic and undetermined plan of distribution with respect to the common units during the 45-day lock-up period, and (3) any selling unitholders registering common units under such registration statement agree in writing to be subject to the 45-day lock-up period.

The underwriter may release the units subject to lock-up agreements in whole or in part at any time with or without notice. When determining whether or not to release units from lock-up agreements, the underwriter will consider, among other factors, the reasons for requesting the release, the number of common units for which the release is being requested and market conditions at the time.

Price Stabilization and Short Positions

In connection with this offering, the underwriter may engage in stabilizing transactions, overallotment transactions and covering transactions in accordance with Regulation M under the Securities Exchange Act of 1934.


•	Stabilizing transactions permit bids to purchase the underlying security so long as the stabilizing bids do not exceed a specified maximum.

•	Over-allotment transactions involve sales by the underwriter of the common units in excess of the number of units the underwriter is obligated to purchase, which creates a short position. The short position may be either a covered short position or a naked short position. In a covered short position, the number of units over-allotted by the underwriter is not greater than the number of units the underwriter may purchase in the over-allotment option. In a naked short position, the number of units involved is greater than the number of units in the over-allotment option. The underwriter may close out any short position by either exercising its over-allotment option and/or purchasing common units in the open market.

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Underwriting

•

Covering transactions involve purchases of the common units in the open market after the distribution has been completed in order to cover short positions. In determining the source of the common units to close out the short position, the underwriter will consider, among other things, the price of common units available for purchase in the open market as compared to the price at which the underwriter may purchase common units through the over-allotment option. If the underwriter sells more common units than could be covered by the over-allotment option, a naked short position, the position can only be closed out by buying common units in the open market. A naked short position is more likely to be created if the underwriter is concerned that there could be downward pressure on the price of the common units in the open market after pricing that could adversely affect investors who purchase in the offering.

These stabilizing transactions, over-allotment transactions and covering transactions may have the effect of raising or maintaining the market price of the common units or preventing or retarding a decline in the market price of the common units. As a result, the price of the common units may be higher than the price that might otherwise exist in the open market. These transactions may be effected on the New York Stock Exchange or otherwise and, if commenced, may be discontinued at any time.

Neither we nor the underwriter make any representation or prediction as to the direction or magnitude of any effect that the transactions described above may have on the price of the common units. In addition, neither we nor the underwriter make any representation that the underwriter will engage in any stabilizing transactions or that any transaction, if commenced, will not be discontinued without notice.

Listing

Our common units are traded on the New York Stock Exchange under the symbol “EPD.”

Affiliations

The underwriter has performed investment banking, commercial banking and advisory services for us from time to time for which the underwriter has received customary fees and expenses. The underwriter and its affiliates may, from time to time in the future, engage in transactions with and perform services for us in the ordinary course of business.

UBS Loan Finance LLC, an affiliate of UBS Securities LLC, is a lender under our multi-year revolving credit facility. UBS Loan Finance LLC will receive its respective share of any repayment by us of amounts outstanding under this credit facility from the proceeds of this offering.

NASD Conduct Rules

Because the National Association of Securities Dealers, Inc. views the common units offered by this prospectus supplement as interests in a direct participation program, this offering is being made in compliance with Rule 2810 of the NASD’s Conduct Rules.

Electronic Distribution

A prospectus in electronic format may be made available by the underwriter or one or more of its affiliates. The underwriter may allocate a number of common units for sale to its online brokerage account holders. In addition, common units may be sold by the underwriter to securities dealers who resell common units to online brokerage account holders.

Other than this prospectus supplement and accompanying prospectus in electronic format, the information on the underwriter’s website and any information contained in any other website maintained by the underwriter is not part of the prospectus supplement and accompanying prospectus

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Underwriting

or the registration statement of which this prospectus supplement and accompanying prospectus form a part, has not been approved and/or endorsed by us or the underwriter in its capacity as an underwriter and should not be relied upon by investors.

Legal matters

Certain legal matters with respect to the common units will be passed upon for us by Vinson & Elkins L.L.P., Houston, Texas. Certain legal matters with respect to the common units will be passed upon for the underwriter by Baker Botts L.L.P., Houston, Texas. Attorneys at Vinson & Elkins L.L.P. who have participated in the preparation of this prospectus supplement, the accompanying prospectus, the registration statement of which they are a part and the related transaction documents beneficially own approximately 3,200 of our common units.

Experts

The (1) consolidated financial statements and the related consolidated financial statement schedule and management’s report on the effectiveness of internal control over financial reporting of Enterprise Products Partners L.P. and subsidiaries incorporated in this prospectus supplement, by reference from Enterprise Products Partners L.P.’s Annual Report on Form 10-K for the year ended December 31, 2004 filed with the Securities and Exchange Commission on March 15, 2005, and (2) the balance sheet of Enterprise Products GP, LLC as of December 31, 2004, incorporated in this prospectus supplement by reference from Enterprise Products Partners L.P.’s Current Report on Form 8-K filed with the Securities and Exchange Commission on March 31, 2005, have been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their reports, which are incorporated herein by reference, and have been so incorporated in reliance upon the reports of such firm given upon their authority as experts in accounting and auditing.

The (1) consolidated financial statements of GulfTerra Energy Partners, L.P. (“GulfTerra”), (2) the financial statements of Poseidon Oil Pipeline Company, L.L.C. (“Poseidon”) and (3) the combined financial statements of El Paso Hydrocarbons, L.P. and El Paso NGL Marketing Company, L.P. (the “Companies”) all incorporated in this prospectus supplement by reference to Enterprise Products Partners L.P.’s Current Reports on Form 8-K dated April 20, 2004 for (1) and (2) and April 16, 2004 for (3), have been so incorporated in reliance on the reports (which (i) report on the consolidated financial statements of GulfTerra contains an explanatory paragraph relating to GulfTerra’s agreement to merge with Enterprise Products Partners L.P. as described in Note 2 to the consolidated financial statements, (ii) report on the financial statements of Poseidon contains an explanatory paragraph relating to Poseidon’s restatement of its prior year financial statements as described in Note 1 to the financial statements, and (iii) report on the combined financial statements of the Companies contains an explanatory paragraph relating to the Companies’ significant transactions and relationships with affiliated entities as described in Note 5 to the combined financial statements) of PricewaterhouseCoopers LLP, an independent registered public accounting firm, given on the authority of said firm as experts in auditing and accounting.

Information derived from the report of Netherland, Sewell & Associates, Inc., independent petroleum engineers and geologists, with respect to GulfTerra’s estimated oil and natural gas reserves incorporated in this prospectus supplement and accompanying base prospectuses by reference to the Current Report on Form 8-K dated April 20, 2004 of Enterprise Products Partners L.P. has been so

S- 32

incorporated in reliance on the authority of said firm as experts with respect to such matters contained in their report.

Incorporation of documents by reference

The Commission allows us to incorporate by reference into this prospectus supplement and the accompanying prospectus the information we file with it, which means that we can disclose important information to you by referring you to those documents. The information incorporated by reference is considered to be part of this prospectus supplement and the accompanying prospectus, and later information that we file with the Commission will automatically update and supersede this information. We incorporate by reference the documents listed below and any future filings we make with the Commission under section 13(a), 13(c), 14 or 15(d) of the Securities Exchange Act of 1934 until our offering is completed (other than information furnished under Items 2.02 or 7.01 of any Form 8-K that is listed below or is filed in the future and which is not deemed filed under the Exchange Act):


•	Annual Report on Form 10-K for the year ended December 31, 2004, Commission File No. 1-14323;

•	Quarterly Reports on Form 10-Q for the quarters ended March 31, 2005, June 30, 2005 and September 30, 2005, Commission File No. 1-14323;

•	Current Reports on Form 8-K filed with the Commission on April 16, 2004, April 20, 2004, August 11, 2004, January 4, 2005, January 18, 2005, February 11, 2005, February 14, 2005, February 16, 2005, March 3, 2005, March 23, 2005, March 31, 2005, April 12, 2005, May 27, 2005, June 2, 2005, June 20, 2005, June 24, 2005, July 1, 2005, August 10, 2005, August 16, 2005, August 22, 2005, September 1, 2005, October 7, 2005, November 14, 2005 and November 28, 2005, Commission File Nos. 1-14323; and

•	Current Report on Form 8-K filed with the Commission on September 30, 2004, as amended by the Current Reports on Form 8-K/A filed with the Commission on October 5, 2004 (Amendment No. 1), October 18, 2004 (Amendment No. 2), December 3, 2004 (Amendment No. 3), December 6, 2004 (Amendment No. 4) and December 27, 2004 (Amendment No. 5), Commission File Nos. 1-14323.

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Forward-looking statements

This prospectus supplement, the related prospectus and some of the documents we have incorporated herein and therein by reference contain various forward-looking statements and information that are based on our beliefs and those of our general partner, as well as assumptions made by and information currently available to us. These forward-looking statements are identified as any statement that does not relate strictly to historical or current facts. When used in this prospectus supplement, the accompanying prospectus or the documents we have incorporated herein or therein by reference, words such as “anticipate,” “project,” “expect,” “plan,” “goal,” “forecast,” “intend,” “could,” “believe,” “may,” and similar expressions and statements regarding our plans and objectives for future operations, are intended to identify forward-looking statements. Although we and our general partner believe that such expectations reflected in such forward-looking statements are reasonable, neither we nor our general partner can give assurances that such expectations will prove to be correct. Such statements are subject to a variety of risks, uncertainties and assumptions. If one or more of these risks or uncertainties materialize, or if underlying assumptions prove incorrect, our actual results may vary materially from those anticipated, estimated, projected or expected. Among the key risk factors that may have a direct bearing on our results of operations and financial condition are:


•	fluctuations in oil, natural gas and NGL prices and production due to weather and other natural and economic forces;

•	a reduction in demand for our products by the petrochemical, refining or heating industries;

•	the effects of our debt level on our future financial and operating flexibility;

•	a decline in the volumes of NGLs delivered by our facilities;

•	the failure of our credit risk management efforts to adequately protect us against customer non-payment;

•	terrorist attacks aimed at our facilities; and

•	our failure to successfully integrate our operations with assets or companies we acquire.

You should not put undue reliance on any forward-looking statements. When considering forward-looking statements, please review the risk factors described under “Risk Factors” in this prospectus supplement and the accompanying prospectus.

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Enterprise Products Partners L.P.

INDEX TO UNAUDITED PRO FORMA CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Enterprise Products Partners L.P. Unaudited Pro Forma Condensed Consolidated Financial Statements:


Introduction			F-2
Unaudited Pro Forma Condensed Statements of Consolidated Operations for the nine months ended September 30, 2005			F-4
Unaudited Pro Forma Condensed Statements of Consolidated Operations for the year ended December 31, 2004			F-5
Unaudited Pro Forma Condensed Consolidated Balance Sheet at September 30, 2005			F-7
Notes to Unaudited Pro Forma Condensed Consolidated Financial Statements			F-8

F- 1

Enterprise Products Partners L.P.

UNAUDITED PRO FORMA CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Introduction

Unless the context requires otherwise, for purposes of this pro forma presentation, references to “we,” “our,” “us,” “the Company” or “Enterprise” are intended to mean the consolidated business and operations of Enterprise Products Partners L.P. References to “Operating Partnership” are intended to mean the consolidated business and operations of our primary operating subsidiary, Enterprise Products Operating L.P. References to “GulfTerra” are intended to mean the consolidated business and operations of GulfTerra Energy Partners, L.P. References to “El Paso” are intended to mean El Paso Corporation, its subsidiaries and affiliates. References to “EPCO” are intended to mean EPCO, Inc., an affiliate of the Company and our ultimate parent company.

The unaudited pro forma condensed consolidated financial statements give effect to the following transactions:


•	The completion by Enterprise of its merger with GulfTerra and related transactions on September 30, 2004 (the “GulfTerra Merger”). The GulfTerra Merger transactions took place in three steps as described beginning on page F-8. In addition, this pro forma financial information reflects the related sale of our 50% equity interest in Starfish Pipeline Company, LLC (“Starfish”) on March 31, 2005.

•	The issuance by our Operating Partnership of $2 billion of senior unsecured notes on October 4, 2004. Net proceeds from this offering were used to reduce debt amounts outstanding under our Operating Partnership’s $2.25 billion 364-Day Acquisition Credit Facility, which was used to fund certain payment obligations related to the GulfTerra Merger.

•	The completion on October 5, 2004 of the Operating Partnership’s four cash tender offers for $915 million in principal amount of GulfTerra’s senior and senior subordinated notes using $1.1 billion borrowed under our Operating Partnership’s $2.25 billion 364-Day Acquisition Credit Facility on September 30, 2004.

•	The sale of 17,250,000 common units to the public (including the subsequent over-allotment amounts) in each May 2004 and August 2004. In addition, Enterprise issued a total of 5,183,591 common units in connection with its distribution reinvestment plan (“DRIP”) and related programs during 2004.

•	The conversion of 80 Series F2 convertible units, which were originally issued by GulfTerra, into 1,950,317 of our common units in October 2004 and November 2004.

•	The sale of 17,250,000 common units to the public (including the subsequent over-allotment amount) in February 2005. In addition, Enterprise issued a total of 2,729,740 common units in connection with its DRIP and related programs during 2005.

•	The issuance by our Operating Partnership in February 2005 of $250 million in principal amount of 5.00% senior notes due March 2015 and $250 million in principal amount of 5.75% senior notes due March 2035 and the related use of proceeds.

•	The issuance by our Operating Partnership in May 2005 of $500 million in principal amount of 4.95% senior notes due June 2010 and related use of proceeds.

The unaudited pro forma as adjusted condensed consolidated financial statements also give effect to the sale of 4,000,000 of our common units in this offering to the public at an offering price of $25.03 per unit and the application of the net proceeds therefrom as described in Note (x) on page F-19.

F- 2

Enterprise Products Partners L.P.

The unaudited pro forma condensed statements of consolidated operations for the nine months ended September 30, 2005 and for the year ended December 31, 2004 assumes the pro forma transactions noted herein occurred on January 1, 2004 (to the extent not already reflected in the historical statements of consolidated operations of each entity). The unaudited pro forma condensed consolidated balance sheet shows the financial effects of the pro forma transactions noted herein as if they has occurred on September 30, 2005 (to the extent not already recorded in the historical balance sheet of Enterprise). GulfTerra’s historical income statement for the year ended December 31, 2004 included $19.9 million in merger-related costs incurred prior to September 30, 2004.

Dollar amounts and number of units outstanding (except per unit amounts) presented in the tabular data within these pro forma condensed consolidated financial statements and footnotes are stated in millions, unless otherwise indicated.

The unaudited pro forma condensed consolidated financial statements and related pro forma information are based on assumptions that Enterprise believes are reasonable under the circumstances and are intended for informational purposes only. They are not necessarily indicative of the financial results that would have occurred if the transactions described herein had taken place on the dates indicated, nor are they indicative of the future consolidated results of the combined company.

The unaudited pro forma condensed consolidated financial statements of Enterprise should be read in conjunction with and are qualified in their entirety by reference to the notes accompanying such unaudited pro forma condensed consolidated financial statements and with the historical consolidated financial statements and related notes of Enterprise included in our annual report on Form 10-K for the year ended December 31, 2004 and quarterly report on Form 10-Q for the three and nine months ended September 30, 2005, which have been filed by Enterprise with the Securities and Exchange Commission (the “Commission,” File No. 1-14323).

The condensed consolidated financial statements of GulfTerra incorporated by reference herein were derived from the historical accounts and records of GulfTerra for the three and nine months ended September 30, 2004, contained in Enterprise’s Current Report on Form 8-K/A (Amendment No. 5) filed with the Commission on December 27, 2004.

The combined financial statements for the eight months ended August 31, 2004 of El Paso Hydrocarbons, L.P. and El Paso NGL Marketing Company, L.P. (collectively, the “South Texas midstream assets”) incorporated by reference herein were derived from the historical accounts and records of these entities.

Unless noted otherwise, our pro forma adjustments related to variable interest rate-based amounts reflect the Operating Partnership’s current variable rate of approximately 4.8% for borrowings under its Multi-Year Revolving Credit Facility. If this current rate were to increase by ¹/8%, it would be 5.4%.

F- 3

Enterprise Products Partners L.P.

Unaudited pro forma condensed statements of consolidated operations

For the nine months ended September 30, 2005


												Adjustments			Adjusted
			Enterprise			Pro forma			Enterprise			due to this			Enterprise
			historical			adjustments			pro forma			offering			pro forma

REVENUES			$	8,476.6					$	8,476.6					$	8,476.6
COSTS AND EXPENSES
Operating costs and expenses				7,959.1		$	5.5	(r)		7,964.6						7,964.6
General and administrative costs				46.7						46.7						46.7

		Total costs and expenses		8,005.8			5.5			8,011.3						8,011.3

EQUITY IN INCOME OF UNCONSOLIDATED AFFILIATES				14.6			(0.3	)(r)		14.3						14.3

OPERATING INCOME				485.4			(5.8	)		479.6						479.6

OTHER INCOME (EXPENSE)
	Interest expense			(170.7	)		2.9	(n)		(170.2	)	$	3.6	(x)		(166.6	)
							2.5	(p)
							(0.4	)(q)
							(4.3	)(t)
							(0.6	)(u)
							0.4	(w)
Other, net				3.6						3.6						3.6

		Total		(167.1	)		0.5			(166.6	)		3.6			(163.0	)

INCOME BEFORE PROVISION FOR INCOME TAXES AND MINORITY INTEREST				318.3			(5.3	)		313.0			3.6			316.6
Provision for income taxes				(4.0	)					(4.0	)					(4.0	)

INCOME BEFORE MINORITY INTEREST				314.3			(5.3	)		309.0			3.6			312.6
MINORITY INTEREST				(3.2	)					(3.2	)					(3.2	)

INCOME FROM CONTINUING OPERATIONS			$	311.1		$	(5.3	)	$	305.8		$	3.6		$	309.4

INCOME ALLOCATION
	Limited partners		$	259.9					$	253.9					$	257.0

	General partner		$	51.2					$	51.9					$	52.4

BASIC EARNINGS PER UNIT
	Number of units used in denominator			381.0			3.1	(n)		385.2			4.0	(x)		389.2

							0.2	(o)
							0.2	(s)
							0.3	(v)
							0.4	(w)
	Income from continuing operations		$	0.69					$	0.66					$	0.66

DILUTED EARNINGS PER UNIT
	Number of units used in denominator			381.6			3.1	(n)		385.8			4.0	(x)		389.8

							0.2	(o)
							0.2	(s)
							0.3	(v)
							0.4	(w)
	Income from continuing operations		$	0.69					$	0.66					$	0.66

See Notes to Unaudited Pro Forma Condensed Consolidated Financial Statements.

F- 4

Enterprise Products Partners L.P.

Unaudited pro forma condensed statements of consolidated operations

For the year ended December 31, 2004 (part 1)


									South Texas
									Midstream						Enterprise
			Enterprise			GulfTerra			assets			Pro forma			pro forma
			historical			historical			historical			adjustments			(to part 2)

REVENUES			$	8,321.2		$	676.7		$	1,103.2		$	(426.6	)(i)	$	9,615.1
													(59.4	)(m)
COSTS AND EXPENSES
Operating costs and expenses				7,904.3			432.3			1,058.3			106.6	(h)		8,974.1
													(421.5	)(i)
													(46.5	)(l)
													(59.4	)(m)
General and administrative costs				46.7									46.5	(l)		93.2

		Total costs and expenses		7,951.0			432.3			1,058.3			(374.3	)		9,067.3

EQUITY IN INCOME (LOSS) OF UNCONSOLIDATED AFFILIATES				52.8									(32.0	)(j)		24.9
													7.6	(l)
													(3.5	)(r)

OPERATING INCOME				423.0			244.4			44.9			(139.6	)		572.7

OTHER INCOME (EXPENSE)
	Interest expense			(155.7	)		(82.7	)					5.2	(a)		(231.6	)
													(68.8	)(d)
													(8.1	)(e)
													3.0	(f)
													56.3	(g)
													21.8	(n)
													8.7	(p)
													(0.5	)(q)
													(10.4	)(t)
													(0.9	)(u)
													0.5	(w)
Loss due to early redemptions of debt							(16.3	)								(16.3	)
Earnings from unconsolidated affiliates							7.6						(7.6	)(1)
Other, net				2.1			0.5			(0.1	)		1.2	(k)		3.7

		Total		(153.6	)		(90.9	)		(0.1	)		0.4			(244.2	)

INCOME BEFORE PROVISION FOR INCOME TAXES AND MINORITY INTEREST				269.4			153.5			44.8			(139.2	)		328.5
PROVISION FOR INCOME TAXES				(3.8	)											(3.8	)

INCOME BEFORE MINORITY INTEREST				265.6			153.5			44.8			(139.2	)		324.7
Minority interest				(8.1	)		1.8									(6.3	)

INCOME FROM CONTINUING OPERATIONS			$	257.5		$	155.3		$	44.8		$	(139.2	)	$	318.4

INCOME ALLOCATION
	Limited partners		$	220.6											$	266.1

	General partner		$	36.9											$	52.3

BASIC EARNINGS PER UNIT
	Number of units used in denominator			265.5									19.2	(a)		384.3

													1.6	(b)
													78.0	(c)
													17.3	(n)
													1.5	(o)
													0.4	(s)
													0.4	(v)
													0.4	(w)
	Income from continuing operations		$	0.83											$	0.69

DILUTED EARNINGS PER UNIT
	Number of units used in denominator			266.0									19.2	(a)		384.8

													1.6	(b)
													78.0	(c)
													17.3	(n)
													1.5	(o)
													0.4	(s)
													0.4	(v)
													0.4	(w)
	Income from continuing operations		$	0.83											$	0.69

See Notes to Unaudited Pro Forma Condensed Consolidated Financial Statements.

F- 5

Enterprise Products Partners L.P.

Unaudited pro forma condensed statements

of consolidated operations

For the year ended December 31, 2004 (part 2)


			Enterprise			Adjustments			Adjusted
			pro forma			due to this			Enterprise
			(from part 1)			offering			pro forma

REVENUES			$	9,615.1					$	9,615.1
COSTS AND EXPENSES
Operating costs and expenses				8,974.1						8,974.1
General and administrative costs				93.2						93.2

		Total		9,067.3						9,067.3

EQUITY IN INCOME (LOSS) OF UNCONSOLIDATED AFFILIATES				24.9						24.9

OPERATING INCOME				572.7						572.7

OTHER INCOME (EXPENSE)
	Interest expense			(231.6	)	$	4.8	(x)		(226.8	)
Loss due to early redemptions of debt				(16.3	)					(16.3	)
Other, net				3.7						3.7

		Total		(244.2	)		4.8			(239.4	)

INCOME BEFORE PROVISION FOR INCOME TAXES AND MINORITY INTEREST				328.5			4.8			333.3
PROVISION FOR INCOME TAXES				(3.8	)					(3.8	)

INCOME BEFORE MINORITY INTEREST				324.7			4.8			329.5
Minority interest				(6.3	)					(6.3	)

INCOME FROM CONTINUING OPERATIONS			$	318.4		$	4.8		$	323.2

INCOME ALLOCATION:
	Limited partners		$	266.1					$	270.3

	General partner		$	52.3					$	52.9

BASIC EARNINGS PER UNIT:
	Number of units used in denominator			384.3			4.0	(x)		388.3

	Income from continuing operations		$	0.69					$	0.70

DILUTED EARNINGS PER UNIT:
	Number of units used in denominator			384.8			4.0	(x)		388.8

	Income from continuing operations		$	0.69					$	0.69

See Notes to Unaudited Pro Forma Condensed Consolidated Financial Statements.

F- 6

Enterprise Products Partners L.P.

Unaudited pro forma condensed consolidated

balance sheet

September 30, 2005


												Adjustments			Adjusted
			Enterprise			Pro forma			Enterprise			due to this			Enterprise
			historical			adjustments			pro forma			offering			pro forma

ASSETS
Current assets
Cash and cash equivalents			$	32.7		$	10.1	(w)	$	32.7		$	99.6	(x)	$	32.7
							(10.1	)(w)					(99.6	)(x)
Restricted cash				6.9						6.9						6.9
Accounts and notes receivable, net				1,294.7						1,294.7						1,294.7
Inventories				573.1						573.1						573.1
Other current assets				105.3						105.3						105.3

		Total current assets		2,012.7			—			2,012.7			—			2,012.7
Property, plant and equipment, net				8,415.6						8,415.6						8,415.6
Investments in and advances to unconsolidated affiliates				470.0						470.0						470.0
Intangible assets, net				941.5						941.5						941.5
Goodwill				489.4						489.4						489.4
Other assets				62.2						62.2						62.2

		Total assets	$	12,391.4		$	—		$	12,391.4		$	—		$	12,391.4

LIABILITIES AND PARTNERS’ EQUITY
Current liabilities
Current maturities of debt			$	15.0					$	15.0					$	15.0
Accounts payable and accrued expenses				1,492.0						1,492.0						1,492.0
Other current liabilities				283.6						283.6						283.6

		Total current liabilities		1,790.6						1,790.6						1,790.6
Long-term debt				4,788.8		$	(10.1	)(w)		4,778.7		$	(99.6	)(x)		4,679.1
Other long-term liabilities				74.1						74.1						74.1
Minority interest				90.2						90.2						90.2
Commitments and contingencies
Partners’ equity
	Limited partners			5,530.2			9.9	(w)		5,540.1			97.6	(x)		5,637.7
	General partner			112.9			0.2	(w)		113.1			2.0	(x)		115.1
	Accumulated other comprehensive income			20.2						20.2						20.2
	Other			(15.6	)					(15.6	)					(15.6	)

		Total partners’ equity		5,647.7			10.1			5,657.8			99.6			5,757.4

		Total liabilities and partners’ equity	$	12,391.4		$	—		$	12,391.4		$	—		$	12,391.4

See Notes to Unaudited Pro Forma Condensed Consolidated Financial Statements.

F- 7

Enterprise Products Partners L.P.

Notes to unaudited pro forma condensed consolidated financial statements

These unaudited pro forma condensed consolidated financial statements and underlying pro forma adjustments are based upon information currently available and certain estimates and assumptions made by the management of Enterprise; therefore, actual results could materially differ from the pro forma information. However, Enterprise believes the assumptions provide a reasonable basis for presenting the significant effects of the transactions noted herein. Enterprise believes the pro forma adjustments give appropriate effect to those assumptions and are properly applied in the pro forma information.

Completion of the GulfTerra Merger transactions

On September 30, 2004, Enterprise and GulfTerra completed the merger of GulfTerra with a wholly owned subsidiary of Enterprise, with GulfTerra being the surviving entity thereof. Additionally, Enterprise completed certain other transactions related to the merger, including receipt of Enterprise’s general partner (“Enterprise Products GP”) contribution of a 50% membership interest in GulfTerra’s general partner (“GulfTerra GP”), which was acquired by Enterprise Products GP from El Paso, and the purchase of certain midstream energy assets located in South Texas from El Paso. The aggregate value of the total consideration Enterprise paid or issued to complete the GulfTerra Merger was approximately $4 billion. These transactions were accounted for using purchase accounting.

Our historical September 30, 2005, Consolidated Balance Sheet reflects the GulfTerra Merger. Since the GulfTerra Merger closed during the day of September 30, 2004, our historical Statement of Consolidated Operations for the year ended December 31, 2004 includes three months of results of operations from the GulfTerra assets. The effective closing date of our purchase of the South Texas midstream assets was September 1, 2004. As a result, our historical Statement of Consolidated Operations for the year ended December 31, 2004 includes four months of results of operations from the South Texas midstream assets. Our historical Statement of Consolidated Operations for the nine months ended September 30, 2005 includes nine months of results of operations from the GulfTerra assets and South Texas midstream assets.

As a result of the GulfTerra Merger, GulfTerra and GulfTerra GP became wholly owned subsidiaries of Enterprise on September 30, 2004. On October 1, 2004, we contributed our ownership interests in GulfTerra and GulfTerra GP to our Operating Partnership, which resulted in GulfTerra and GulfTerra GP becoming wholly owned subsidiaries of our Operating Partnership.

GulfTerra manages a balanced, diversified portfolio of interests and assets relating to the midstream energy sector, which involves gathering, transporting, separating, processing, fractionating and storing natural gas, oil and NGLs. GulfTerra’s interests and assets included (i) offshore oil and natural gas pipelines, platforms, processing facilities and other energy infrastructure in the Gulf of Mexico, primarily offshore Louisiana and Texas; (ii) onshore natural gas pipelines and processing facilities in Alabama, Colorado, Louisiana, Mississippi, New Mexico and Texas; (iii) onshore NGL pipelines and fractionation facilities in Texas; and (iv) onshore natural gas and NGL storage facilities in Louisiana, Mississippi and Texas.

The South Texas midstream assets consist of nine natural gas processing plants with a combined capacity of 1.9 Bcf/d, a 294-mile natural gas gathering system, a natural gas treating facility with a capacity of 150 MMcf/d and a small NGL pipeline.

F- 8

Notes to unaudited pro forma condensed consolidated financial statements

The GulfTerra Merger transactions

The GulfTerra Merger occurred in several interrelated steps as described below.


•	Step One. On December 15, 2003, Enterprise purchased a 50% membership interest in GulfTerra GP from El Paso for $425 million in cash. GulfTerra GP owned a 1% general partner interest in GulfTerra. Prior to completion of the GulfTerra Merger, Enterprise accounted for its investment in GulfTerra GP using the equity method of accounting. The $425 million in funds required to complete Step One were borrowed by our Operating Partnership under an Interim Term Loan and its pre-merger revolving credit facilities. These borrowings were fully repaid with the net proceeds from equity offerings completed during 2004 by Enterprise.

•	Step Two. On September 30, 2004, the GulfTerra Merger was consummated and GulfTerra and GulfTerra GP became wholly owned subsidiaries of Enterprise. Step Two of the GulfTerra Merger included the following:


	-	Immediately prior to closing the GulfTerra Merger, Enterprise GP acquired El Paso’s remaining 50% membership interest in GulfTerra GP for $370 million in cash paid to El Paso and the issuance of a 9.9% membership interest in Enterprise GP to El Paso. Subsequently, Enterprise Products GP contributed this 50% membership interest in GulfTerra GP to us without the receipt of additional general partner interest, common units or other consideration. Enterprise Products GP borrowed the foregoing $370 million from one of its members, Dan Duncan LLC, which obtained the funds through a loan from EPCO.

	-	Immediately prior to closing the GulfTerra Merger, Enterprise paid $500 million in cash to El Paso for 10,937,500 Series C units of GulfTerra and 2,876,620 common units of GulfTerra. The remaining 57,762,369 GulfTerra common units (7,433,425 of which were owned by El Paso) were converted into 104,549,823 Enterprise common units (13,454,498 of which were held by El Paso) at the time of the consummation of the GulfTerra Merger.


•	Step Three. Immediately after Step Two was completed, Enterprise acquired certain South Texas midstream assets from El Paso for $155.3 million in cash. Pursuant to written agreements, our purchase of the South Texas midstream assets was effective September 1, 2004.

In connection with the closing of the GulfTerra Merger on September 30, 2004, our Operating Partnership borrowed an aggregate of $2.6 billion under its 364-Day Acquisition Credit Facility and Multi-Year Revolving Credit Facility (collectively referred to as the “Merger Credit Facilities”) in order to fund its cash payment obligations under Step Two and Step Three of the GulfTerra Merger, including the tender offers for GulfTerra’s outstanding senior and senior subordinated notes.

F- 9

Notes to unaudited pro forma condensed consolidated financial statements

The total consideration paid or granted for the GulfTerra Merger Transactions is summarized below:


Step One transaction:
	Cash payment by Enterprise to El Paso for initial 50% membership interest in GulfTerra GP (a non-voting interest) made in December 2003		$	425.0

		Total Step One consideration		425.0

Step Two transactions:
	Cash payment by Enterprise to El Paso for 10,937,500 GulfTerra Series C units and 2,876,620 GulfTerra common units			500.0
	Fair value of equity interests granted to acquire remaining 50% membership interest in GulfTerra GP (voting interest) and cash payment of $370 million by Enterprise GP to El Paso⁽¹⁾			461.3
	Fair value of Enterprise common units issued in exchange for remaining GulfTerra common units			2,445.4
	Fair value of other Enterprise equity interests granted for unit awards and Series F convertible units			4.0
	Fair value of receivable from El Paso for transition support payments⁽²⁾			(40.3	)
	Transaction fees and other direct costs incurred by Enterprise as a result of the GulfTerra Merger⁽³⁾			31.1

		Total Step Two consideration		3,401.5

		Total Step One and Step Two consideration		3,826.5

Step Three transaction:
	Purchase of South Texas midstream assets from El Paso			155.3

		Total consideration for Steps One through Three	$	3,981.8


(1)	This fair value is based on 50% of an implied $922.7 million total value of GulfTerra GP, which assumes that the $370 million cash payment made by Enterprise Products GP to El Paso represented consideration for a 40.1% interest in GulfTerra GP. The 40.1% interest was derived by deducting the 9.9% membership interest in Enterprise Products GP granted to El Paso in this transaction from the 50% membership interest in GulfTerra GP that Enterprise Products GP received. The fair value of $461.3 million assigned to this voting membership interest in GulfTerra GP compares favorably to the $425 million paid to El Paso by Enterprise to purchase its initial 50% non-voting membership interest in GulfTerra GP in December 2003. The contribution of this 50% membership interest to Enterprise is allocated for financial reporting purposes to Enterprise’s limited partners and general partner based on the respective ownership percentages and the related allocation of profits and losses of 98% and 2%, respectively, both of which are consistent with the Partnership Agreement.

(2)	Reflects the present value of a contract-based receivable from El Paso received as part of the negotiated net consideration reached in Step One of the GulfTerra Merger. The agreements between Enterprise and El Paso provide that for a period of three years following the closing of the GulfTerra Merger, El Paso will make transition support payments to Enterprise in annual amounts of $18 million, $15 million and $12 million for the first, second and third years of such period, respectively, payable in twelve equal monthly installments for each such year. The $45 million receivable from El Paso has been discounted to fair value and recorded as a reduction in the purchase consideration for GulfTerra. This contract-based receivable was recorded at its fair value of $40.3 million and classified within other assets on Enterprise’s condensed Consolidated Balance Sheet at December 31, 2004.

(footnotes continued on following page)

F- 10

Notes to unaudited pro forma condensed consolidated financial statements

(3)

As a result of the GulfTerra Merger, Enterprise incurred expenses of approximately $31.1 million for various transaction fees and other direct costs. These direct costs include fees for legal, accounting, printing, financial advisory and other services rendered by third-parties to Enterprise over the course of the GulfTerra Merger transactions. This amount also includes $3.4 million of involuntary severance costs.

Allocation of purchase price of GulfTerra Merger transactions

The GulfTerra Merger transactions were recorded using the purchase method of accounting. Purchase accounting requires us to allocate the cost of a business combination to the assets acquired and liabilities assumed based on their estimated fair values. Enterprise engaged an independent third-party business valuation expert to assess the fair value of GulfTerra’s and the South Texas midstream asset’s tangible and intangible assets. As of September 30, 2005, our purchase price and purchase price allocation related to the GulfTerra Merger were final.

The following table reflects our final purchase price and purchase price allocation related to the GulfTerra Merger.


				Merger-related transactions

							Step three
							purchase of
				Step two of			South Texas
				GulfTerra			midstream
				Merger			assets			Total

Purchase price allocation:
	Assets acquired in business combination:
		Current assets, including cash of $40,453		$	203.1		$	7.6		$	210.7
		Property, plant and equipment, net			4,601.4			112.7			4,714.1
		Investments in and advances to unconsolidated affiliates			202.7						202.7
		Intangible assets			705.5			38.0			743.5
		Other assets			23.2						23.2

			Total assets acquired		5,735.9			158.3			5,894.2

	Liabilities assumed in business combination:
		Current liabilities			(233.3	)		(3.0	)		(236.3	)
		Long-term debt, including current maturities			(2,015.6	)					(2,015.6	)
		Other long-term liabilities			(47.9	)					(47.9	)

			Total liabilities assumed		(2,296.8	)		(3.0	)		(2,299.8	)

			Total assets acquired less liabilities assumed		3,439.1			155.3			3,594.4
			Total consideration given		3,826.5			155.3			3,981.8

	Remaining Goodwill			$	387.4		$	—		$	387.4

As a result of the final purchase price allocation for Steps Two and Three of the GulfTerra Merger transactions, Enterprise recorded $743.5 million of amortizable intangible assets, primarily those related to customer relationships and contracts. The remaining amount represents goodwill of $387.4 million associated with our view of the future results from GulfTerra’s operations, based on the strategic location of GulfTerra’s assets as well as their industry relationships.

F- 11

Notes to unaudited pro forma condensed consolidated financial statements

Pro forma adjustments

The pro forma adjustments made to the condensed consolidated historical financial statements of Enterprise, GulfTerra and the South Texas midstream assets are described as follows:


	(a) During 2004, Enterprise sold 39,683,591 common units, which generated aggregate net proceeds of approximately $805.2 million. The issuance of these common units was as follows:


	•	1,053,861 common units issued in February 2004 in connection with Enterprise’s DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution, total net proceeds from this offering were $23.1 million. Enterprise used the net proceeds from this offering for general partnership purposes.

	•	17,250,000 common units sold to the public and 1,757,347 common units issued in connection with the DRIP and related programs in May 2004. Including Enterprise Products GP’s related 2% capital contribution, total net proceeds from these offerings were $388.4 million. Enterprise used $353.1 million of the net proceeds from its May 2004 public offering to repay the Operating Partnership’s $225 million Interim Term Loan and to temporarily reduce borrowings outstanding under the Operating Partnership’s then existing revolving credit facilities by approximately $130 million. Enterprise used the $35.3 million in net proceeds received in connection with its DRIP for general partnership purposes.

	•	17,250,000 common units sold to the public and 173,033 common units issued in connection with the DRIP and related programs in August 2004. Including Enterprise Products GP’s related 2% capital contribution, total net proceeds from these offerings were $344.4 million. Enterprise used $210 million of the net proceeds from its August 2004 public offering to temporarily reduce borrowings outstanding under the Operating Partnership’s then existing revolving credit facilities and the remainder to fund its payment obligations to El Paso in connection with Step Two of the GulfTerra Merger.

	•	2,199,350 common units issued in November 2004 in connection with the DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution, total net proceeds from this offering were $49.3 million. Enterprise used the net proceeds for general partnership purposes.


	As a result of the February, May, August and November 2004 offerings described above, the weighted average number of Enterprise common units outstanding increased 19.2 million for the year ended December 31, 2004. Since the receipt of proceeds from these offering and the related increases in partners’ equity are already reflected in Enterprise’s historical condensed consolidated balance sheet at June 30, 2005, no pro forma adjustments to the balance sheet are necessary.

	As a result of the use of proceeds from these offerings, pro forma interest expense decreased $5.2 million for the year ended December 31, 2004. In calculating the pro forma adjustment to interest expense for the year ended December 31, 2004, we used an average historical variable interest rate of approximately 1.8%, which was determined by reference to the debt obligations that were either completely repaid or temporarily reduced using proceeds from such offerings of common units. If the variable interest rates used to determine the pro forma adjustments to interest expense were ¹/8% higher, the pro forma reduction in interest expense would have been $5.7 million for the year ended December 31, 2004.

F- 12

Notes to unaudited pro forma condensed consolidated financial statements


	(b) In May 2003, GulfTerra issued 80 Series F convertible units in a registered offering to an institutional investor. Each Series F convertible unit was comprised of two separate detachable units— a Series F1 convertible unit and Series F2 convertible unit— that had identical terms except for vesting and termination dates and the number of common units into which they could be converted upon payment of the calculated purchase price per common unit. Prior to the GulfTerra Merger, all the Series F1 convertible units were converted into GulfTerra common units by the holder. As a result of the GulfTerra Merger, Enterprise assumed GulfTerra’s obligation associated with the Series F2 convertible units. All Series F2 convertible units outstanding at the merger date were converted into rights to purchase Enterprise common units. The Series F2 units were convertible into to up to $40 million of Enterprise common units.

	On October 29, 2004, 60 of the 80 outstanding Series F2 convertible units were converted into 1,458,434 Enterprise common units. On November 8, 2004, the remaining 20 outstanding Series F2 convertible units were converted into 491,883 Enterprise common units. As a result of these conversions, Enterprise received net proceeds of approximately $39.6 million, which includes the related 2% capital contributions made by Enterprise Products GP. Enterprise used the net proceeds from these conversions for general partnership purposes. As a result of these transactions, the weighted-average number of common units outstanding increased 1.6 million for the year ended December 31, 2004.

	(c) Reflects the pro forma adjustment to common units outstanding resulting from the issuance of 104,549,823 Enterprise common units in the exchange with GulfTerra’s common unit holders on September 30, 2004 under Step Two of the GulfTerra Merger. The pro forma effect of these new common units on the weight-average number of Enterprise units outstanding is an increase of 78 million common units for the year ended December 31, 2004.

	(d) On September 30, 2004, our Operating Partnership borrowed approximately $2.6 billion under its Merger Credit Facilities to (i) fund cash payment obligations to El Paso under Step Two and Step Three of the GulfTerra Merger transactions, (ii) escrow $1.1 billion in cash to finance its tender offers for GulfTerra’s senior and senior subordinated notes and (iii) repay $962 million outstanding under GulfTerra’s revolving credit facility and secured term loans on the merger closing date.

	The pro forma adjustment to interest expense resulting from these borrowings is $68.8 million for the year ended December 31, 2004. In calculating the pro forma adjustment to interest expense, we used an estimated variable interest rate of 4.8%, which approximates the interest rate we are currently being charged on amounts borrowed under our Operating Partnership’s Multi-Year Revolving Credit Facility. If this estimated interest rate were ¹/8% higher, the pro forma adjustment to interest expense would be $71.2 million for the year ended December 31, 2004. The pro forma adjustment to interest expense also reflects the removal of historical interest expense amounts recorded by GulfTerra related to its revolving credit facility and secured term loans of $22.5 million for the year ended December 31, 2004. Enterprise’s condensed consolidated historical balance sheet at September 30, 2005 already reflects these borrowings; therefore, no pro forma adjustment is required.

	(e) On October 4, 2004, our Operating Partnership issued $2 billion of senior unsecured notes in a private offering. The net proceeds from this offering were used to reduce debt outstanding under the Merger Credit Facilities. The fixed-interest rate, principal amount issued

F- 13

Notes to unaudited pro forma condensed consolidated financial statements


	and net proceeds (before offering expenses) of each senior note in this offering were as follows:


	Fixed						Proceeds to
	interest		Principal		Bond		us, before
Senior note issued	rate		amount		discount		expenses

Senior Notes E, due October 2007		4.000%	$	500.0	$	2.1	$	497.9
Senior Notes F, due October 2009		4.625%		500.0		4.4		495.6
Senior Notes G, due October 2014		5.600%		650.0		4.8		645.2
Senior Notes H, due October 2034		6.650%		350.0		4.2		345.8

Totals			$	2,000.0	$	15.5	$	1,984.5


	After giving effect to the application of proceeds to reduce principal amounts outstanding under our Operating Partnership’s variable-rate Merger Credit Facilities, the pro forma adjustment to interest expense resulting from the issuance of these senior notes is $8.1 million for the year ended December 31, 2004. If the variable interest rate used to calculate the reduction in interest expense associated with the repayment of amounts outstanding under the Merger Credit Facilities were ¹/8% higher, the pro forma adjustment to interest expense would have been $6.3 million for the year ended December 31, 2004. Enterprise’s condensed consolidated historical balance sheet at September 30, 2005 already reflects this transaction; therefore, no pro forma adjustment is required.

	(f) During 2004, our Operating Partnership entered into eight forward-starting interest rate swap transactions in anticipation of financing activities associated with closing the GulfTerra Merger transactions. The Operating Partnership’s purpose in entering into these transactions was to effectively hedge the underlying U.S. treasury rate related to its expected issuance of $2 billion of fixed-rate debt. On October 4, 2004, the Operating Partnership issued $2 billion of senior unsecured notes in a private offering (see Note (e)). Each of the forward starting swaps was designated as a cash flow hedge in accordance with applicable accounting guidance.

	In April 2004, the Operating Partnership elected to terminate the initial four forward-starting swaps in order to manage and maximize the value of the swaps and to reduce future debt service costs. As a result, it received $104.5 million in cash from the counterparties. In September 2004, the remaining four swaps were settled resulting in an $85.1 million payment to the counterparties. The net gain of $19.4 million from these eight swaps was recorded in accumulated other comprehensive income and will be amortized to earnings over the life of the associated debt as a reduction in interest expense and accumulated other comprehensive income. The pro forma amortization of this gain reduced interest expense by $3 million for the year ended December 31, 2004. No pro forma adjustment to the condensed consolidated balance sheet of Enterprise at September 30, 2005 is required.

	(g) On October 4, 2004, all of the cash tender offers made by the Operating Partnership for any and all of GulfTerra’s outstanding senior and senior subordinated notes expired. As of the expiration time, the Operating Partnership had received tenders of such notes aggregating $915 million, or 99.3% of the notes outstanding. On October 5, 2004, the Operating Partnership purchased the notes for a total price of approximately $1.1 billion using amounts borrowed under the Merger Credit Facilities. The following table shows the four GulfTerra senior debt obligations affected, including the principal amount of each series of notes

F- 14

Notes to unaudited pro forma condensed consolidated financial statements


	tendered, as well as the payment made by the Operating Partnership to complete the tender offers.


				Cash payments
				made by Enterprise
		Principal
		amount		Accrued		Tender
Description		tendered		interest		price⁽¹⁾		Total paid

8.50% Senior Subordinated Notes due 2010 (Represented 98.2% of principal amount outstanding)		$	212.1	$	6.2	$	246.4	$	252.6
10.625% Senior Subordinated Notes due 2012 (Represented 99.9% of principal amount outstanding)			133.9		4.9		167.6		172.5
8.50% Senior Subordinated Notes due 2011 (Represented 99.5% of principal amount outstanding)			319.8		9.4		359.4		368.8
6.25% Senior Notes due 2010 (Represented 99.7% of principal amount outstanding)			249.3		5.4		274.0		279.4

	Totals	$	915.1	$	25.9	$	1,047.4	$	1,073.3


(1)	Tender price includes consent payment of $30 per $1,000 principal amount tendered.


	The pro forma adjustments to interest expense reflect the removal of historical interest expense amounts recorded by GulfTerra associated with such senior note obligations. These adjustments decreased pro forma fixed-rate interest expense by $56.3 million for the year ended December 31, 2004. Enterprise’s condensed consolidated historical balance sheet at September 30, 2005 already reflects these transactions; therefore, no pro forma adjustment is required.

	(h) Reflects the pro forma depreciation and amortization adjustment for GulfTerra’s and the South Texas midstream assets’ property, plant and equipment and intangible assets based on the final purchase price allocation for the GulfTerra Merger transactions (see page ). For purposes of calculating pro forma depreciation expense, we applied the straight-line method using remaining useful lives ranging from 10 years to 33 years (depending on the type of asset) to Enterprise’s new basis in such assets of approximately $4.7 billion.

	In addition, Enterprise recorded $743.5 million of amortizable intangible assets, which are primarily comprised of the fair value of certain customer relationships and storage contracts. For purposes of calculating pro forma amortization expense attributable to the customer relationship intangible assets, we based such expense primarily on the patterns in which the economic benefits of each intangible asset are expected to be consumed by referencing the forecasted production rates of the underlying resource bases (i.e., the oil and gas reserves associated with the customer relationship intangible assets) from which the customers produce. For purposes of calculating pro forma amortization expense attributable to the storage contract intangible assets, we applied the straight-line method to the remainder of the respective contract terms, which we estimate could range from 2 to 18 years.

	Overall, the pro forma depreciation and amortization expense adjustment was $106.6 million for the year ended December 31, 2004, after taking into account the historical expense amounts recorded by GulfTerra and the South Texas midstream assets.

	(i) In accordance with the purchase and sale agreement between Enterprise and El Paso for the South Texas midstream assets, El Paso retained a number of natural gas liquids marketing contracts. Enterprise’s pro forma condensed statement of consolidated operations for the year

F- 15

Notes to unaudited pro forma condensed consolidated financial statements


	ended December 31, 2004 includes adjustments to remove $426.6 million of revenues and $421.5 million of operating costs and expenses associated with these retained contracts.

	(j) After Step Two of the GulfTerra Merger was completed on September 30, 2004, GulfTerra GP became a wholly owned subsidiary of Enterprise. This pro forma adjustment reflects the replacement of equity earnings from GulfTerra GP that Enterprise recorded under Step One of the merger, with consolidated earnings from GulfTerra, as if Step Two had occurred on January 1, 2004. This adjustment required the removal of $32 million of equity earnings from GulfTerra GP that Enterprise recorded during the first nine months of 2004. Enterprise acquired its initial 50% membership interest in GulfTerra GP on December 15, 2003 under Step One of the GulfTerra Merger.

	(k) In connection with the GulfTerra Merger transactions, Enterprise recorded the present value of a contract-based receivable from El Paso totaling $40.3 million, which was part of the negotiated net consideration reached in Step Two of the GulfTerra Merger. Our pro forma condensed statement of consolidated operations reflects $1.2 million of imputed interest income that would have been recognized from this agreement during 2004.

	(l) Reflects pro forma classification adjustments necessary to conform GulfTerra’s and the South Texas midstream assets’ historical condensed statements of consolidated operations to Enterprise’s method of presentation. The reclassifications were as follows:


	•	GulfTerra’s and the South Texas midstream assets’ general and administrative costs were reclassified to a separate line item within operating expenses to conform to Enterprise’s method of presentation. GulfTerra’s and the South Texas midstream assets’ general and administrative costs were $46.5 million for the year ended December 31, 2004.

	•	GulfTerra’s operating income increased as a result of reclassifying its equity earnings from unconsolidated affiliates to a separate component of operating income to conform with Enterprise’s presentation of such earnings. As a result of this reclassification, GulfTerra’s operating income increased by $7.6 million for the year ended December 31, 2004. Enterprise’s equity investments with industry partners are a vital component of its business strategy. Such investments are a means by which Enterprise conducts its operations to align its interests with those of its customers, which may be a supplier of raw materials or a consumer of finished products. This method of operation also enables Enterprise to achieve favorable economies of scale relative to the level of investment and business risk assumed versus what Enterprise could accomplish on a stand-alone basis. Many of these equity investments perform supporting or complementary roles to Enterprise’s other business operations. GulfTerra has a similar relationship with its equity investees.


	(m) Reflects the pro forma elimination of significant revenues and expenses between Enterprise, GulfTerra and the South Texas midstream assets as appropriate in consolidation. Upon completion of the GulfTerra Merger, GulfTerra and the South Texas midstream assets became wholly owned subsidiaries of Enterprise.

	(n) Reflects the sale of 17,250,000 Enterprise common units at an offering price of $27.05 per unit in February 2005 (including the over-allotment amount of 2,250,000 common units issued in March 2005). Total net proceeds from this sale were approximately $456.7 million after deducting applicable underwriting discounts, commissions and offering expenses of approximately $19 million. Included in total net proceeds of $456.7 million is a net capital contribution made by Enterprise Products GP of $9.1 million to maintain its 2% general partner interest in Enterprise, after deducting the general partner’s share of the underwriting discounts, commissions and offering expenses. For pro forma purposes, the net

F- 16

Notes to unaudited pro forma condensed consolidated financial statements


	proceeds from this equity offering, including Enterprise GP’s net capital contribution, were used to reduce debt outstanding under the Merger Credit Facilities. As a result of this offering, the weight-average number of common units outstanding increased 3.1 million for the nine months ended September 30, 2005 and 17.3 million for the year ended December 31, 2004.

	As a result of our pro forma application of proceeds from this offering to reduce debt outstanding, pro forma interest expense decreased by $2.9 million for the nine months ended September 30, 2005 and $21.8 million for the year ended December 31, 2004. If the variable interest rate used to calculate the reduction in interest expense was ¹/8% higher, the pro forma adjustment to interest expense would have been $3.1 million for the nine months ended September 30, 2005 and $22.4 million for the year ended December 31, 2004.

	(o) Reflects Enterprise’s February 2005 issuance of 1,516,561 common units in connection with its DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution of approximately $0.8 million, total net proceeds from this offering were approximately $39 million. Enterprise used the net proceeds from this offering for general partnership purposes. As a result of this offering, the weighted-average number of common units outstanding increased 0.2 million for the nine months ended September 30, 2005 and 1.5 million for the year ended December 31, 2004.

	(p) Reflects the Operating Partnership’s combined issuance of $500 million of senior notes in February 2005 comprised of $250 million in principal amount of 5.00% senior notes due March 2015 (“Senior Notes I”) and $250 million in principal amount of 5.75% senior notes due March 2035 (“Senior Notes J”). The Operating Partnership used the $490.6 million in net proceeds from the issuance of these fixed-rate senior notes to retire its $350 million in principal amount 8.25% Senior Notes A (due March 2005) and to temporarily reduce indebtedness outstanding under its Multi-Year Revolving Credit Facility.

	After giving effect to the issuance of Senior Notes I and J in February 2005 and the related application of net proceeds, pro forma interest expense would decrease by $2.5 million for the nine months ended September 30, 2005 and $8.7 million for the year ended December 31, 2004. If the variable interest rate used to calculate the reduction in interest expense were ¹/8% higher, the pro forma decrease in interest expense would have been $2.6 million for the nine months ended September 30, 2005 and $8.9 million for the year ended December 31, 2004.

	(q) The net proceeds from issuance of Senior Notes I and J described in Note (p) reflect the payment of $9.4 million in bond discounts and debt issuance costs. For pro forma purposes, we have amortized these costs over the term of the senior notes they are associated with using the straight-line method. As a result, pro forma interest expense increased $0.4 million for the nine months ended September 30, 2005 and $0.5 million for the year ended December 31, 2004.

	(r) Reflects the sale by Enterprise of its 50% equity investment in Starfish, which owns the Stingray natural gas pipeline and related gathering pipelines and dehydration and other facilities located in south Louisiana and the Gulf of Mexico offshore Louisiana. In connection with obtaining regulatory approval for the GulfTerra Merger, Enterprise was required by the FTC to sell its ownership interest in Starfish by March 31, 2005. On March 31, 2005, Enterprise sold this asset to a third-party for approximately $42.1 million in cash and realized a gain on the sale of $5.5 million.

F- 17

Notes to unaudited pro forma condensed consolidated financial statements


	Enterprise recognized equity earnings from Starfish of $0.3 million for the nine months ended September 30, 2005 and $3.5 million for the year ended December 31, 2004. Our pro forma adjustments reflect the removal of these equity earnings since, for pro forma earnings purposes, we have assumed that the sale of Starfish occurred immediately prior to January 1, 2004. Likewise, we have removed the $5.5 million gain on the sale of Starfish from our results of operations for the nine months ended September 30, 2005. Our September 30, 2005 historical condensed balance sheet already reflects the sale of Starfish; therefore, no pro forma adjustments are required.

	(s) Reflects Enterprise’s May 2005 issuance of 410,249 common units in connection with its DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution of approximately $0.2 million, total net proceeds from this offering were approximately $10.4 million. Enterprise used the net proceeds from this offering for general partnership purposes. As a result of this offering, the weighted-average number of common units outstanding increased 0.2 million for the nine months ended September 30, 2005 and 0.4 million for the year ended December 31, 2004.

	(t) Reflects the Operating Partnership’s issuance in June 2005 of $500 million in principal amount of 4.95% senior notes due June 2010 (“Senior Notes K”). The Operating Partnership used the $495.7 million in net proceeds from the issuance of these fixed-rate senior notes to temporarily reduce debt outstanding under its Multi-Year Revolving Credit Facility and for general partnership purposes, including capital expenditures and business combinations.

	After giving effect to the issuance of Senior Notes K in June 2005 and the related application of net proceeds, pro forma interest expense would increase by $4.3 million for the nine months ended September 30, 2005 and $10.4 million for the year ended December 31, 2004. If the variable interest rate underlying the Multi-Year Revolving Credit Facility were ¹/8% higher, the pro forma decrease in interest expense would have been $4.2 million for the nine months ended September 30, 2005 and $10.1 million for the year ended December 31, 2004.

	(u) The net proceeds from issuance of Senior Notes K described in Note (t) reflect the payment of $4.3 million in bond discounts and debt issuance costs. For pro forma purposes, we have amortized these costs over the term of the senior notes they are associated with using the straight-line method. As a result, pro forma interest expense increased $0.6 million for the nine months ended September 30, 2005 and $0.9 million for the year ended December 31, 2004.

	(v) Reflects Enterprise’s August 2005 issuance of 399,812 common units in connection with its DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution of approximately $0.2 million, total net proceeds from this offering were approximately $10.1 million. Enterprise used the net proceeds from this offering for general partnership purposes. As a result of this offering, the weighted-average number of common units outstanding increased 0.3 million for the nine months ended September 30, 2005 and 0.4 million for the year ended December 31, 2004.

	(w) Reflects Enterprise’s November 2005 issuance of 403,118 common units in connection with its DRIP and related programs. Including Enterprise Products GP’s related 2% capital contribution of approximately $0.2 million, total net proceeds from this offering were approximately $10.1 million. Enterprise used the net proceeds from this offering to temporarily reduce indebtedness outstanding under the Operating Partnership’s Multi-Year Revolving Credit Facility. As a result of this offering, the weighted-average number of common units outstanding increased 0.4 million for the nine months ended September 30, 2005 and for the year ended December 31, 2004.

F- 18

Notes to unaudited pro forma condensed consolidated financial statements


	As a result of our pro forma application of proceeds from this sale of common units to reduce debt outstanding, pro forma interest expense decreased by $0.4 million for the nine months ended September 30, 2005 and $0.5 million for the year ended December 31, 2004. If the variable interest rate used to calculate the reduction in interest expense were ¹/8% higher, the pro forma adjustment to interest expense for both periods would not have been materially different from that noted above.

	(x) Reflects the sale in this offering of 4,000,000 Enterprise common units at an offering price of $25.03 per unit. Total net proceeds from this sale are expected to be approximately $99.6 million after deducting applicable underwriting discounts, commissions and offering expenses of $2.5 million. Included in the total net proceeds of $99.6 million is a net capital contribution made by Enterprise Products GP of $2.0 million to maintain its 2% general partner interest in Enterprise, after deducting the general partners’ share of the underwriting discounts, commissions and offering expenses. For pro forma purposes, the net proceeds from this equity offering, including Enterprise Products GP’s net capital contribution will be used to temporarily reduce debt outstanding under our Operating Partnership’s Multi-Year Revolving Credit Facility.

	As a result of our pro forma application of proceeds from this offering to reduce debt outstanding, pro forma interest expense will decrease by $3.6 million for the nine months ended September 30, 2005 and $4.8 million for the year ended December 31, 2004. If the variable interest rate used to calculate the reduction in interest expense were ¹/8% higher, the pro forma adjustment to interest expense would have been $3.6 million for the nine months ended September 30, 2005 and $4.9 million for the year ended December 31, 2004.

F- 19

PROSPECTUS

Enterprise Products Partners L.P.

Enterprise Products Operating L.P.

Common Units

Debt Securities

We may offer up to $4,000,000,000 of the following securities under this prospectus:


•	common units representing limited partner interests in Enterprise Products Partners L.P.; and

•	debt securities of Enterprise Products Operating L.P., which will be guaranteed by its parent company, Enterprise Products Partners L.P.

This prospectus provides you with a general description of the securities we may offer. Each time we sell securities we will provide a prospectus supplement that will contain specific information about the terms of that offering. The prospectus supplement may also add, update or change information contained in this prospectus. You should read carefully this prospectus and any prospectus supplement before you invest. You should also read the documents we have referred you to in the “Where You Can Find More Information” section of this prospectus for information about us, including our financial statements.

In addition, up to 41,000,000 common units may be offered from time to time by the selling unitholders named herein. Specific terms of certain offerings by such selling unitholders may be specified in a prospectus supplement to this prospectus. We will not receive proceeds of any sale of common units by any such selling unitholders unless otherwise indicated in a prospectus supplement. For a more detailed discussion of selling unitholders, please read “Selling Unitholders.”

Our common units are listed on the New York Stock Exchange under the trading symbol “EPD.”

Unless otherwise specified in a prospectus supplement, the senior debt securities, when issued, will be unsecured and will rank equally with our other unsecured and unsubordinated indebtedness. The subordinated debt securities, when issued, will be subordinated in right of payment to our senior debt.

Limited partnerships are inherently different from corporations. You should review carefully “Risk Factors” beginning on page 3 for a discussion of important risks you should consider before investing on our securities.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

This prospectus may not be used to consummate sales of securities by the registrants unless accompanied by a prospectus supplement.

The date of this prospectus is March 23, 2005.

Table of contents


			Page

ABOUT THIS PROSPECTUS				iv
OUR COMPANY				1
RISK FACTORS				3
	Risks Related to Our Business			3
		Changes in the prices of hydrocarbon products may materially adversely affect our results of operations, cash flows and financial condition		3
		A decline in the volume of natural gas, NGLs and crude oil delivered to our facilities could adversely affect our results of operations, cash flows and financial condition		3
		A reduction in demand for NGL products by the petrochemical, refining or heating industries could materially adversely affect our results of operations, cash flows and financial position		4
		We face competition from third parties in our midstream businesses		4
		Our debt level may limit our future financial and operating flexibility		5
		We may not be able to fully execute our growth strategy if we encounter illiquid capital markets or increased competition for qualified assets		6
		Our growth strategy may adversely affect our results of operations if we do not successfully integrate the businesses that we acquire, including GulfTerra, or if we substantially increase our indebtedness and contingent liabilities to make acquisitions		6
		Our operating cash flows from our capital projects may not be immediate		7
		Our actual construction, development and acquisition costs could exceed forecasted amounts		7
		We may be unable to cause our joint ventures to take or not to take certain actions unless some or all of our joint venture participants agree		7
		The interruption of distributions to us from our subsidiaries and joint ventures may affect our ability to satisfy our obligations and to make cash distributions to our unitholders		7
		A natural disaster, catastrophe or other event could result in severe personal injury, property damage and environmental damage, which could curtail our operations and otherwise materially adversely affect our cash flow		8
		An impairment of goodwill could reduce our earnings		8
		Increases in interest rates could adversely affect our business and may cause the market price of our common units to decline		9
		The use of derivative financial instruments could result in material financial losses by us		9
		Our pipeline integrity program may impose significant costs and liabilities on us		9
		Environmental costs and liabilities and changing environmental regulation could materially affect our cash flow		9
		Federal, state or local regulatory measures could materially adversely affect our business		10
		Terrorist attacks aimed at our facilities could adversely affect our business		11

Table of contents


			Page

	Risks Related to Our Common Units as a Result of Our Partnership Structure			12
		We may not have sufficient cash from operations to pay distributions at the current level following establishment of cash reserves and payments of fees and expenses, including payments to our general partner		12
		We do not have the same flexibility as other types of organizations to accumulate cash and equity to protect against illiquidity in the future		12
		Cost reimbursements due our general partner may be substantial and will reduce our cash available for distribution to holders of common units		12
		Our general partner and its affiliates have limited fiduciary responsibilities and conflicts of interest with respect to our partnership		13
		Even if unitholders are dissatisfied, they cannot easily remove our general partner		13
		We may issue additional common units without the approval of common unitholders, which would dilute their existing ownership interests		14
		Our general partner has a limited call right that may require common unitholders to sell their units at an undesirable time or price		14
		Common unitholders may not have limited liability if a court finds that limited partner actions constitute control of our business		14
		A large number of our outstanding common units may be sold in the market, which may depress the market price of our common units		14
	Tax Risks to Common Unitholders			15
		The IRS could treat us as a corporation for tax purposes, which would substantially reduce the cash available for distribution to common unitholders		15
		A successful IRS contest of the federal income tax positions we take may adversely impact the market for common units, and the costs of any contests will be borne by our unitholders and our general partner		15
		Common unitholders may be required to pay taxes even if they do not receive any cash distributions		16
		Tax gain or loss on the disposition of common units could be different than expected		16
		Tax-exempt entities, regulated investment companies and foreign persons face unique tax issues from owning common units that may result in adverse tax consequences to them		16
		We will treat each purchaser of common units as having the same tax benefits without regard to the units purchased. The IRS may challenge this treatment, which could adversely affect the value of our common units		16
		Common unitholders will likely be subject to state and local taxes and return filing requirements in states where they do not live as a result of an investment in our common units		16
USE OF PROCEEDS				18
RATIO OF EARNINGS TO FIXED CHARGES				18
DESCRIPTION OF DEBT SECURITIES				18
	General			19
	Guarantee			20
	Certain Covenants			20
	Events of Default			25
	Amendments and Waivers			26
	Defeasance and Discharge			28

Table of contents


		Page

	Subordination		29
	Book-Entry System		30
	Limitations on Issuance of Bearer Securities		32
	No Recourse Against General Partner		33
	Concerning the Trustee		33
	Governing Law		34
DESCRIPTION OF OUR COMMON UNITS			35
	Meetings/ Voting		35
	Status as Limited Partner or Assignee		35
	Limited Liability		35
	Reports and Records		36
CASH DISTRIBUTION POLICY			37
	Distributions of Available Cash		37
	Operating Surplus and Capital Surplus		37
	Distributions of Available Cash from Operating Surplus		38
	Incentive Distributions		38
	Distributions from Capital Surplus		39
	Adjustment to the Minimum Quarterly Distribution and Target Distribution Levels		39
	Distributions of Cash upon Liquidation		40
DESCRIPTION OF OUR PARTNERSHIP AGREEMENT			42
	Purpose		42
	Power of Attorney		42
	Voting Rights		42
	Reimbursements of Our General Partner		43
	Issuance of Additional Securities		43
	Amendments to Our Partnership Agreement		43
	Withdrawal or Removal of Our General Partner		44
	Liquidation and Distribution of Proceeds		45
	Transfer of Ownership Interests in Our General Partner		45
	Change of Management Provisions		45
	Limited Call Right		46
	Indemnification		46
	Registration Rights		46
MATERIAL TAX CONSEQUENCES			47
	Partnership Status		47
	Limited Partner Status		49
	Tax Consequences of Unit Ownership		49
	Tax Treatment of Operations		54
	Disposition of Common Units		55
	Uniformity of Units		57
	Tax-Exempt Organizations and Other Investors		58
	Administrative Matters		58
	State, Local, Foreign and Other Tax Considerations		60
	Tax Consequences of Ownership of Debt Securities		61
SELLING UNITHOLDERS			62
PLAN OF DISTRIBUTION			64
	Distribution by Selling Unitholders		65
WHERE YOU CAN FIND MORE INFORMATION			67
FORWARD-LOOKING STATEMENTS			69
LEGAL MATTERS			69
EXPERTS			70

You should rely only on the information contained or incorporated by reference in this prospectus or any prospectus supplement. We have not authorized any other person to provide you with different information. If anyone provides you with different or inconsistent information, you should not rely on it. You should not assume that the information incorporated by reference or provided in this prospectus or any prospectus supplement is accurate as of any date other than the date on the front of each document.

“Our,” “we,” “us” and “Enterprise” as used in this prospectus refer to Enterprise Products Partners L.P. and Enterprise Products Operating L.P. and their wholly owned subsidiaries. “GulfTerra” as used in this prospectus supplement refers to Enterprise GTM Holdings L.P. (formerly known as GulfTerra Energy Partners, L.P.) and its wholly owned subsidiaries.

iii

About this prospectus

This prospectus is part of a registration statement that we file with the Securities and Exchange Commission (the “Commission”) using a “shelf” registration process. Under this shelf process, we may offer from time to time up to $4,000,000,000 of our securities and the selling unitholders may offer from time to time up to 41,000,000 of their common units. Each time we offer securities, we will provide you with a prospectus supplement that will describe, among other things, the specific amounts and prices of the securities being offered and the terms of the offering. The selling unitholders may offer common units pursuant to this prospectus or may provide you with a prospectus supplement that will describe, among other things, the specific amounts and prices of the securities being offered and the terms of the offering. Any prospectus supplement may add, update or change information contained in this prospectus. Any statement that we make in this prospectus will be modified or superseded by any inconsistent statement made by us in a prospectus supplement. Therefore, you should read this prospectus and any attached prospectus supplement before you invest in our securities.

Our company

We are a publicly traded limited partnership that was formed in April 1998 to acquire, own, and operate all of the NGL processing and distribution assets of EPCO, Inc., or EPCO, formerly known as Enterprise Products Company. We conduct all of our business through our 100% owned subsidiary, Enterprise Products Operating L.P. (our “Operating Partnership”) and its subsidiaries and joint ventures. Our general partner, Enterprise Products GP, LLC, owns a 2% interest in us.

We are a leading North American midstream energy company that provides a wide range of services to producers and consumers of natural gas, natural gas liquids, or NGLs, and crude oil, and we are an industry leader in the development of midstream infrastructure in the deepwater trend of the Gulf of Mexico. We have the only integrated North American midstream network, which includes natural gas transportation, gathering, processing and storage; NGL fractionation (or separation), transportation, storage and import and export terminalling; and crude oil transportation and offshore production platform services. Our midstream network links producers of natural gas, NGLs and crude oil from the largest supply basins in the United States, Canada and the Gulf of Mexico with the largest consumers and international markets. NGLs are used by the petrochemical and refining industries to produce plastics, motor gasoline and other industrial and consumer products and also are used as residential, agricultural and industrial fuels. We provide integrated services to our customers and generate fee-based cash flow from multiple sources along our midstream energy “value chain.”

Our midstream energy services include:


•	gathering and transportation of raw natural gas from both onshore and offshore Gulf of Mexico developments;

•	gathering and transportation of crude oil from offshore Gulf of Mexico developments;

•	offshore production platform services;

•	processing of raw natural gas into a marketable product that meets industry quality specifications by removing mixed NGLs and impurities;

•	purchase of natural gas for resale to our industrial, utility and municipal customers;

•	transportation of mixed NGLs to fractionation facilities by pipeline;

•	fractionation (or separation) of mixed NGLs produced as by-products of crude oil refining and natural gas production into component NGL products: ethane, propane, isobutane, normal butane and natural gasoline;

•	transportation of NGL products to end-users by pipeline, railcar and truck;

•	import and export of NGL products and petrochemical products through our dock facilities;

•	fractionation of refinery-sourced propane/propylene mix into high-purity propylene, propane and mixed butane;

•	transportation of high-purity propylene to end-users by pipeline;

•	storage of natural gas, mixed NGLs, NGL products and petrochemical products;

•	conversion of normal butane to isobutane through the process of isomerization;

•	production of high-octane additives for motor gasoline from isobutane; and

•	sale of NGLs and petrochemical products we produce and/or purchase for resale.

In addition to our current strategic position in the Gulf of Mexico, we have access to major natural gas and NGL supply basins throughout the United States and Canada, including the Rocky Mountains, the San Juan and Permian basins, the Mid-Continent region and, through third-party pipeline

connections, north into Canada’s Western Sedimentary basin. Our system of assets in the Gulf Coast region of the United States, combined with our Mid-America and Seminole pipeline systems, create the only integrated North American midstream network.

Certain of our facilities are owned jointly by us and other industry partners, either through co-ownership arrangements or joint ventures. Some of our jointly owned facilities are operated by other owners.

We do not have any employees. All of our management, administrative and operating functions are performed by employees of EPCO, our ultimate parent company, pursuant to the Administrative Services Agreement. For a discussion of the Administrative Services Agreement, please read Item 13 of our latest Annual Report on Form 10-K.

Our principal executive offices are located at 2727 North Loop West, Houston, Texas 77008-1038, and our telephone number is (713) 880-6500.

Risk factors

An investment in our securities involves risks. You should consider carefully the following risk factors, together with all of the other information included in, or incorporated by reference into, this prospectus and any prospectus supplement in evaluating an investment in our securities. This prospectus also contains forward-looking statements that involve risks and uncertainties. Please read “Forward-Looking Statements.” Our actual results could differ materially from those anticipated in the forward-looking statements as a result of certain factors, including the risks described below and the other information included in, or incorporated by reference into, this prospectus. If any of these risks occur, our business, financial condition or results of operations could be adversely affected.

RISKS RELATED TO OUR BUSINESS

Changes in the prices of hydrocarbon products may materially adversely affect our results of operations, cash flows and financial condition.

We operate predominantly in the midstream energy sector which includes gathering, transporting, processing, fractionating and storing natural gas, NGLs and crude oil. As such, our results of operations, cash flows and financial condition may be materially adversely affected by changes in the prices of these hydrocarbon products and by changes in the relative price levels among these hydrocarbon products. In general terms, the prices of natural gas, NGLs, crude oil and other hydrocarbon products are subject to fluctuations in response to changes in supply, market uncertainty and a variety of additional factors that are impossible to control. These factors include:


•	the level of domestic production;

•	the availability of imported oil and natural gas;

•	actions taken by foreign oil and natural gas producing nations;

•	the availability of transportation systems with adequate capacity;

•	the availability of competitive fuels;

•	fluctuating and seasonal demand for oil, natural gas and NGLs; and

•	conservation and the extent of governmental regulation of production and the overall economic environment.

We are also exposed to natural gas and NGL commodity price risk under natural gas processing and gathering and NGL fractionation contracts that provide for our fee to be calculated based on a regional natural gas or NGL price index or to be paid in-kind by taking title to natural gas or NGLs. A decrease in natural gas and NGL prices can result in lower margins from these contracts, which may materially adversely affect our results of operations, cash flows and financial position.

A decline in the volume of natural gas, NGLs and crude oil delivered to our facilities could adversely affect our results of operations, cash flows and financial condition.

Our profitability could be materially impacted by a decline in the volume of natural gas, NGLs and crude oil transported, gathered or processed at our facilities. A material decrease in natural gas or crude oil production or crude oil refining, as a result of depressed commodity prices, a decrease in exploration and development activities or otherwise, could result in a decline in the volume of natural gas, NGLs and crude oil handled by our facilities.

The crude oil, natural gas and NGLs available to our facilities will be derived from reserves produced from existing wells, which reserves naturally decline over time. To offset this natural decline, our

Risk factors

facilities will need access to additional reserves. Additionally, some of our facilities will be dependent on reserves that are expected to be produced from newly discovered properties that are currently being developed.

Exploration and development of new oil and natural gas reserves is capital intensive, particularly offshore in the Gulf of Mexico. Many economic and business factors are out of our control and can adversely affect the decision by producers to explore for and develop new reserves. These factors could include relatively low oil and natural gas prices, cost and availability of equipment, regulatory changes, capital budget limitations or the lack of available capital. For example, a sustained decline in the price of natural gas and crude oil could result in a decrease in natural gas and crude oil exploration and development activities in the regions where our facilities are located. This could result in a decrease in volumes to our offshore platforms, natural gas processing plants, natural gas, crude oil and NGL pipelines, and NGL fractionators which would have a material adverse affect on our results of operations, cash flows and financial position. Additional reserves, if discovered, may not be developed in the near future or at all.

A reduction in demand for NGL products by the petrochemical, refining or heating industries could materially adversely affect our results of operations, cash flows and financial position.

A reduction in demand for NGL products by the petrochemical, refining or heating industries, whether because of general economic conditions, reduced demand by consumers for the end products made with NGL products, increased competition from petroleum-based products due to pricing differences, adverse weather conditions, government regulations affecting prices and production levels of natural gas or the content of motor gasoline or other reasons, could materially adversely affect our results of operations, cash flows and financial position. For example:

Ethane. If natural gas prices increase significantly in relation to ethane prices, it may be more profitable for natural gas producers to leave the ethane in the natural gas stream to be burned as fuel than to extract the ethane from the mixed NGL stream for sale.

Propane. The demand for propane as a heating fuel is significantly affected by weather conditions. Unusually warm winters could cause the demand for propane to decline significantly and could cause a significant decline in the volumes of propane that the combined company transports.

Isobutane. Any reduction in demand for motor gasoline additives may reduce demand for isobutane. During periods in which the difference in market prices between isobutane and normal butane is low or inventory values are high relative to current prices for normal butane or isobutane, our operating margin from selling isobutane could be reduced.

Propylene. Any downturn in the domestic or international economy could cause reduced demand for propylene, which could cause a reduction in the volumes of propylene that we produce and expose our investment in inventories of propane/ propylene mix to pricing risk due to requirements for short-term price discounts in the spot or short-term propylene markets.

We face competition from third parties in our midstream businesses.

Even if reserves exist in the areas accessed by our facilities and are ultimately produced, we may not be chosen by the producers in these areas to gather, transport, process, fractionate, store or otherwise handle the hydrocarbons that are produced. We compete with others, including producers of oil and natural gas, for any such production on the basis of many factors, including:


•	geographic proximity to the production;

•	costs of connection;

Risk factors


•	available capacity;

•	rates; and

•	access to markets.

Our debt level may limit our future financial and operating flexibility.

As of December 31, 2004, we had approximately $4.3 billion of consolidated debt outstanding. The amount of our debt could have significant effects on our future operations, including, among other things:


•	a significant portion of our cash flow from operations will be dedicated to the payment of principal and interest on outstanding debt and will not be available for other purposes, including payment of distributions on our common units and capital expenditures;

•	credit rating agencies may view our debt level negatively;

•	covenants contained in our existing debt arrangements will require us to continue to meet financial tests that may adversely affect our flexibility in planning for and reacting to changes in our business;

•	our ability to obtain additional financing for working capital, capital expenditures, acquisitions and general partnership purposes may be limited;

•	we may be at a competitive disadvantage relative to similar companies that have less debt; and

•	we may be more vulnerable to adverse economic and industry conditions as a result of our significant debt level.

Our public debt indentures currently do not limit the amount of future indebtedness that we can create, incur, assume or guarantee. Our revolving credit facilities, however, restrict our ability to incur additional debt, though any debt we may incur in compliance with these restrictions may still be substantial.

Our multi-year revolving credit facility and the indentures governing our public debt contain conventional financial covenants and other restrictions. A breach of any of these restrictions by us could permit the lenders to declare all amounts outstanding under those debt agreements to be immediately due and payable and, in the case of the credit facility, to terminate all commitments to extend further credit.

Our ability to access the capital markets to raise capital on favorable terms will be affected by our debt level, the amount of our debt maturing in the next several years and current maturities, and by adverse market conditions resulting from, among other things, general economic conditions, contingencies and uncertainties that are difficult to predict and impossible to control. Moreover, if the rating agencies were to downgrade our corporate credit, then we could experience an increase in our borrowing costs, difficulty assessing capital markets or a reduction in the market price of our common units. Such a development could adversely affect our ability to obtain financing for working capital, capital expenditures or acquisitions or to refinance existing indebtedness. If we are unable to access the capital markets on favorable terms in the future, we might be forced to seek extensions for some of our short-term securities or to refinance some of our debt obligations through bank credit, as opposed to long-term public debt securities or equity securities. The price and terms upon which we might receive such extensions or additional bank credit, if at all, could be more onerous than those contained in existing debt agreements. Any such arrangements could, in turn, increase the risk that our leverage may adversely affect our future financial and operating flexibility and our ability to pay cash distributions at expected rates.

Risk factors

We may not be able to fully execute our growth strategy if we encounter illiquid capital markets or increased competition for qualified assets.

Our strategy contemplates growth through the development and acquisition of a wide range of midstream and other energy infrastructure assets while maintaining a strong balance sheet. This strategy includes constructing and acquiring additional assets and businesses to enhance our ability to compete effectively and diversify our asset portfolio, thereby providing more stable cash flow. We regularly consider and enter into discussions regarding, and are currently contemplating, potential joint ventures, stand alone projects or other transactions that we believe will present opportunities to realize synergies, expand our role in the energy infrastructure business and increase our market position.

We may require substantial new capital to finance the future development and acquisition of assets and businesses. Limitations on our access to capital will impair our ability to execute this strategy. Expensive capital will limit our ability to develop or acquire accretive assets. We may not be able to raise the necessary funds on satisfactory terms, if at all.

In addition, we are experiencing increased competition for the assets we purchase or contemplate purchasing. Increased competition for a limited pool of assets could result in our losing to other bidders more often or acquiring assets at higher prices. Either occurrence would limit our ability to fully execute our growth strategy. Our inability to execute our growth strategy may materially adversely impact the market price of our securities.

Our growth strategy may adversely affect our results of operations if we do not successfully integrate the businesses that we acquire, including GulfTerra, or if we substantially increase our indebtedness and contingent liabilities to make acquisitions.

Our growth strategy includes making accretive acquisitions. As a result, from time to time, we will evaluate and acquire assets and businesses that we believe complement our existing operations. Similar to the risks associated with integrating our operations with GulfTerra’s operations, we may be unable to integrate successfully businesses we acquire in the future. We may incur substantial expenses or encounter delays or other problems in connection with our growth strategy that could negatively impact our results of operations, cash flows and financial condition. Moreover, acquisitions and business expansions involve numerous risks, including:


•	difficulties in the assimilation of the operations, technologies, services and products of the acquired companies or business segments;

•	establishing the internal controls and procedures that we are required to maintain under the Sarbanes-Oxley Act of 2002;

•	managing relationships with new joint venture partners with whom we have not previously partnered;

•	inefficiencies and complexities that can arise because of unfamiliarity with new assets and the businesses associated with them, including with their markets; and

•	diversion of the attention of management and other personnel from day-to-day business to the development or acquisition of new businesses and other business opportunities.

If consummated, any acquisition or investment would also likely result in the incurrence of indebtedness and contingent liabilities and an increase in interest expense and depreciation, depletion and amortization expenses. As a result, our capitalization and results of operations may change significantly following an acquisition. A substantial increase in our indebtedness and contingent liabilities could have a material adverse effect on our business. In addition, any anticipated benefits of a material acquisition, such as expected cost savings, may not be fully realized, if at all.

Risk factors

Our operating cash flows from our capital projects may not be immediate.

We are engaged in several capital expansion projects and “greenfield” projects for which significant capital has been expended, and our operating cash flow from a particular project may not increase immediately following its completion. For instance, if we build a new pipeline or platform or expand an existing facility, the design, construction, development and installation may occur over an extended period of time, and we may not receive any material increase in operating cash flow from that project until after it is placed in service. If we experience unanticipated or extended delays in generating operating cash flow from these projects, we may be required to reduce or reprioritize our capital budget, sell non-core assets, access the capital markets or decrease distributions to unitholders in order to meet our capital requirements.

Our actual construction, development and acquisition costs could exceed forecasted amounts.

We will have significant expenditures for the development, construction or other acquisition of energy infrastructure assets, including some construction and development projects with significant technological challenges. For example, underwater operations, especially those in water depths in excess of 600 feet, are very expensive and involve much more uncertainty and risk, and if a problem occurs, the solution, if one exists, may be very expensive and time consuming. We may not be able to complete our projects, whether in deepwater or otherwise, at the costs estimated at the time of initiation.

We may be unable to cause our joint ventures to take or not to take certain actions unless some or all of our joint venture participants agree.

We participate in several joint ventures. Due to the nature of some of these joint ventures, each participant in each of these joint ventures has made substantial investments in the joint venture and, accordingly, has required that the relevant organizational documents contain certain features designed to provide each participant with the opportunity to participate in the management of the joint venture and to protect its investment in that joint venture, as well as any other assets which may be substantially dependent on or otherwise affected by the activities of that joint venture. These participation and protective features include a corporate governance structure that requires at least a majority in interest vote to authorize many basic activities and requires a greater voting interest (sometimes up to 100%) to authorize more significant activities. Examples of these more significant activities are large expenditures or contractual commitments, the construction or acquisition of assets, borrowing money or otherwise raising capital, transactions with affiliates of a joint venture participant, litigation and transactions not in the ordinary course of business, among others. Thus, without the concurrence of joint venture participants with enough voting interests, we may be unable to cause any of our joint ventures to take or not to take certain actions, even though those actions may be in the best interest of us or the particular joint venture.

Moreover, any joint venture owner may sell, transfer or otherwise modify its ownership interest in a joint venture, whether in a transaction involving third parties or the other joint venture owners. Any such transaction could result in our partnering with different or additional parties.

The interruption of distributions to us from our subsidiaries and joint ventures may affect our ability to satisfy our obligations and to make cash distributions to our unitholders.

We are a holding company with no business operations. Our only significant assets are the equity interests we own in our subsidiaries and joint ventures. As a result, we depend upon the earnings and cash flow of our subsidiaries and joint ventures and the distribution of that cash to us in order to meet our obligations and to allow us to make distributions to our unitholders.

Risk factors

In addition, the management committees of the joint ventures in which we participate typically have sole discretion regarding the occurrence and amount of distributions. Some of the joint ventures in which we participate have separate credit arrangements that contain various restrictive covenants. Among other things, those covenants may limit or restrict the joint venture’s ability to make distributions to us under certain circumstances. Accordingly, our joint ventures may be unable to make distributions to us at current levels or at all.

A natural disaster, catastrophe or other event could result in severe personal injury, property damage and environmental damage, which could curtail our operations and otherwise materially adversely affect our cash flow.

Some of our operations involve risks of personal injury, property damage and environmental damage, which could curtail our operations and otherwise materially adversely affect our cash flow. For example, natural gas facilities operate at high pressures, sometimes in excess of 1,100 pounds per square inch. We also operate oil and natural gas facilities located underwater in the Gulf of Mexico, which can involve complexities, such as extreme water pressure. Virtually all of our operations are exposed to potential natural disasters, including hurricanes, tornadoes, storms, floods and/or earthquakes.

If one or more facilities that are owned by us or that deliver oil, natural gas or other products to us are damaged by severe weather or any other disaster, accident, catastrophe or event, our operations could be significantly interrupted. Similar interruptions could result from damage to production or other facilities that supply our facilities or other stoppages arising from factors beyond our control. These interruptions might involve significant damage to people, property or the environment, and repairs might take from a week or less for a minor incident to six months or more for a major interruption. Additionally, some of the storage contracts that we are a party to obligate us to indemnify our customers for any damage or injury occurring during the period in which the customers’ natural gas is in our possession. Any event that interrupts the fees generated by our energy infrastructure assets, or which causes us to make significant expenditures not covered by insurance, could reduce our cash available for paying our interest obligations as well as unitholder distributions and, accordingly, adversely affect the market price of our securities.

We believe that we maintain adequate insurance coverage, although insurance will not cover many types of interruptions that might occur. As a result of market conditions, premiums and deductibles for certain insurance policies can increase substantially, and in some instances, certain insurance may become unavailable or available only for reduced amounts of coverage. As a result, we may not be able to renew our existing insurance policies or procure other desirable insurance on commercially reasonable terms, if at all. If we were to incur a significant liability for which we were not fully insured, it could have a material adverse effect on our financial position and results of operations. In addition, the proceeds of any such insurance may not be paid in a timely manner and may be insufficient if such an event were to occur.

An impairment of goodwill could reduce our earnings.

We had recorded $445.9 million of goodwill and $961.9 million of intangible assets on our consolidated balance sheet as of September 30, 2004. Goodwill is recorded when the purchase price of a business exceeds the fair market value of the tangible and separately measurable intangible net assets. GAAP will require us to test goodwill for impairment on an annual basis or when events or circumstances occur indicating that goodwill might be impaired. Long-lived assets such as intangible assets with finite useful lives are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount may not be recoverable. If we determine that any of our goodwill or intangible assets were impaired, we would be required to take an immediate charge to earnings with a

Risk factors

correlative effect on partners’ equity and balance sheet leverage as measured by debt to total capitalization.

Increases in interest rates could adversely affect our business and may cause the market price of our common units to decline.

In addition to our exposure to commodity prices, we have significant exposure to increases in interest rates. As of December 31, 2004, we had approximately $4.3 billion of consolidated debt, of which approximately $2.9 billion was at fixed interest rates and approximately $1.4 billion was at variable interest rates, after giving effect to existing interest swap arrangements. We may from time to time enter into additional interest rate swap arrangements, which could increase our exposure to variable interest rates. As a result, our results of operations, cash flows and financial condition, could be materially adversely affected by significant increases in interest rates.

An increase in interest rates may also cause a corresponding decline in demand for equity investments in general, and in particular for yield-based equity investments such as our common units. Any such reduction in demand for our common units resulting from other more attractive investment opportunities may cause the trading price of our common units to decline.

The use of derivative financial instruments could result in material financial losses by us.

We historically have sought to limit a portion of the adverse effects resulting from changes in oil and natural gas commodity prices and interest rates by using financial derivative instruments and other hedging mechanisms from time to time. To the extent that we hedge our commodity price and interest rate exposures, we will forego the benefits we would otherwise experience if commodity prices or interest rates were to change in our favor. In addition, even though monitored by management, hedging activities can result in losses. Such losses could occur under various circumstances, including if a counterparty does not perform its obligations under the hedge arrangement, the hedge is imperfect, or hedging policies and procedures are not followed.

Our pipeline integrity program may impose significant costs and liabilities on us.

In December 2003, the U.S. Department of Transportation issued a final rule (effective as of February 14, 2004) requiring pipeline operators to develop integrity management programs to comprehensively evaluate their pipelines, and take measures to protect pipeline segments located in what the rule refers to as “high consequence areas.” The final rule resulted from the enactment of the Pipeline Safety Improvement Act of 2002. At this time, we cannot predict the outcome of this rule on us. However, we will continue our pipeline integrity testing programs, which are intended to assess and maintain the integrity of our pipelines. While the costs associated with the pipeline integrity testing itself are not large, the results of these tests could cause us to incur significant and unanticipated capital and operating expenditures for repairs or upgrades deemed necessary to ensure the continued safe and reliable operation of our pipelines.

Environmental costs and liabilities and changing environmental regulation could materially affect our cash flow.

Our operations are subject to extensive federal, state and local regulatory requirements relating to environmental affairs, health and safety, waste management and chemical and petroleum products. Governmental authorities have the power to enforce compliance with applicable regulations and permits and to subject violators to civil and criminal penalties, including substantial fines, injunctions or both. Third parties may also have the right to pursue legal actions to enforce compliance.

Risk factors

We will make expenditures in connection with environmental matters as part of normal capital expenditure programs. However, future environmental law developments, such as stricter laws, regulations, permits or enforcement policies, could significantly increase some costs of our operations, including the handling, manufacture, use, emission or disposal of substances and wastes. Moreover, as with other companies engaged in similar or related businesses, our operations have some risk of environmental costs and liabilities because we handle petroleum products.

Federal, state or local regulatory measures could materially adversely affect our business.

The Federal Energy Regulatory Commission, or FERC, regulates our interstate natural gas pipelines, interstate natural gas storage facilities and interstate NGL and petrochemical pipelines, while state regulatory agencies regulate our intrastate natural gas and NGL pipelines, intrastate storage facilities and gathering lines. This federal and state regulation extends to such matters as:


•	rate structures;

•	rates of return on equity;

•	recovery of costs;

•	the services that our regulated assets are permitted to perform;

•	the acquisition, construction and disposition of assets; and

•	to an extent, the level of competition in that regulated industry.

Our latest Annual Report on Form 10-K, which is incorporated by reference into this prospectus, contains a general overview of FERC and state regulation applicable to our energy infrastructure assets. This regulatory oversight can affect certain aspects of our business and the market for our products and could materially adversely affect our cash flow. Please read “Business and Properties— Regulation and Environmental Matters” in our latest Annual Report on Form 10-K.

Under the Natural Gas Act, FERC has authority to regulate our natural gas companies that provide natural gas pipeline transportation services in interstate commerce. Its authority to regulate those services includes the rates charged for the services, terms and conditions of service, certification and construction of new facilities, the acquisition, extension, disposition or abandonment of facilities, the maintenance of accounts and records, the initiation and discontinuation of services, and various other matters. Pursuant to FERC’s jurisdiction over interstate gas pipeline rates, existing pipeline rates may be challenged by customer complaint or by the FERC and proposed rate increases may be challenged by protest.

On January 24, 2005, FERC issued an order rejecting HIOS’s settlement offer and generally affirming the ALJ’s initial decision, resulting in rates significantly lower than the rate proposed in HIOS’ settlement offer. FERC’s January 24 order may be subject to requests for rehearing and appeal to federal court. We are not able to predict the outcome of the HIOS proceeding, but an adverse outcome

Risk factors

in this proceeding or any other rate case proceedings to which we may be a party in the future could adversely affect our results of operations, cash flows and financial position.

FERC also has authority under the Interstate Commerce Act, or ICA, to regulate the rates, terms, and conditions applied to our interstate pipelines engaged in the transportation of NGLs and petrochemicals (commonly known as “oil pipelines”). Pursuant to the ICA, oil pipeline rates can be challenged at FERC either by protest, when they are initially filed or increased, or by complaint at any time they remain on file with the jurisdictional agency.

We have interests in natural gas pipeline facilities offshore from Texas and Louisiana. These facilities are subject to regulation by FERC and other federal agencies, including the Department of Interior, under the Outer Continental Shelf Lands Act, and by the Department of Transportation’s Office of Pipeline Safety under the Natural Gas Pipeline Safety Act.

Our intrastate NGL and natural gas pipelines are subject to regulation in Alabama, Colorado, Louisiana, Mississippi, New Mexico and Texas. We also have natural gas underground storage facilities in Louisiana, Mississippi and Texas. Some of our intrastate natural gas pipelines and storage facilities are subject to regulation by the FERC pursuant to Section 311 of the Natural Gas Policy Act, or NGPA. Although state regulation is typically less onerous than at FERC, proposed and existing rates subject to state regulation are also subject to challenge by protest and complaint, respectively.

On July 20, 2004, the United States Court of Appeals for the District of Columbia Circuit issued its opinion in BP West Coast Products, LLC v. FERC, which upheld FERC’s determination that SFPP’s rates were grandfathered rates under the Energy Policy Act and that SFPP’s shippers had not demonstrated substantially changed circumstances that would justify modification of those rates. The court also stated that FERC had not provided reasonable decision-making in support of its Lakehead policy. In Lakehead, the FERC allowed a regulated entity organized as a master limited partnership to include in its cost of service an income tax allowance to the extent that its unitholders were corporations subject to income tax. The court remanded the issue of the appropriate income tax allowance for a pipeline owned by a master limited partnership and the issue of whether SFPP’s revised cost of service without the tax allowance would qualify as a substantially changed circumstance that would justify modification of SFPP’s rates. Because the court remanded to the FERC and because the FERC’s ruling will focus on the facts and record presented to it, it is not clear what impact, if any, the opinion will have on our rates or on the rates of other FERC-jurisdictional pipelines organized as tax pass-through entities. On December 2, 2004, the FERC issued a Notice of Inquiry in Docket No. PL05-5 suggesting that BP West Coast may not be limited to the specific facts. Specifically, FERC requested comments regarding whether the court’s opinion should apply only to the specific facts of that case, or whether it should apply more broadly, and, if the latter, what effect that ruling might have on energy infrastructure investments. It is not clear what action the FERC will take in response to BP West Coast after considering comments filed, to what extent such action will be challenged and, if so, whether it will withstand further FERC or judicial review.

Parties could challenge the rates of our common carrier interstate liquid pipelines and our interstate natural gas pipelines and argue that the rationale in the BP West Coast decision, regarding tax allowances, should be applied. While it is possible that party might challenge these rates, it is not possible to predict the likelihood that such a challenge would succeed at the FERC.

Terrorist attacks aimed at our facilities could adversely affect our business.

Since the September 11, 2001 terrorist attacks on the United States, the United States government has issued warnings that energy assets, including our nation’s pipeline infrastructure, may be the future target of terrorist organizations. Any terrorist attack on our facilities, those of our customers and, in some cases, those of other pipelines, could have a material adverse effect on our business. An

Risk factors

escalation of political tensions in the Middle East and elsewhere, such as the recent commencement of United States military action in Iraq, could result in increased volatility in the world’s energy markets and result in a material adverse effect on our business.

RISKS RELATED TO OUR COMMON UNITS AS A RESULT OF OUR PARTNERSHIP STRUCTURE

We may not have sufficient cash from operations to pay distributions at the current level following establishment of cash reserves and payments of fees and expenses, including payments to our general partner.

Because distributions on our common units are dependent on the amount of cash we generate, distributions may fluctuate based on our performance. We cannot guarantee that we will continue to pay distributions at the current level each quarter. The actual amount of cash that is available to be distributed each quarter will depend upon numerous factors, some of which are beyond our control and the control of our general partner. These factors include but are not limited to the following:


•	the level of our operating costs;

•	the level of competition in our business segments;

•	prevailing economic conditions;

•	the level of capital expenditures we make;

•	the restrictions contained in our debt agreements and our debt service requirements;

•	fluctuations in our working capital needs;

•	the cost of acquisitions, if any; and

•	the amount, if any, of cash reserves established by our general partner, in its discretion.

In addition, you should be aware that our ability to pay the minimum quarterly distribution each quarter depends primarily on our cash flow, including cash flow from financial reserves and working capital borrowings, and not solely on profitability, which is affected by non-cash items. As a result, we may make cash distributions during periods when we record losses and we may not make distributions during periods when we record net income.

We do not have the same flexibility as other types of organizations to accumulate cash and equity to protect against illiquidity in the future.

Unlike a corporation, our partnership agreement requires us to make quarterly distributions to our unitholders of all available cash reduced by any amounts of reserves for commitments and contingencies, including capital and operating costs and debt service requirements. The value of our common units may decrease in direct correlation with decreases in the amount we distribute per common unit. Accordingly, if we experience a liquidity problem in the future, we may not be able to issue more equity to recapitalize.

Cost reimbursements due our general partner may be substantial and will reduce our cash available for distribution to holders of common units.

Prior to making any distribution on our common units, we will reimburse our general partner and its affiliates, including officers and directors of our general partner, for expenses they incur on our behalf. The reimbursement of expenses could adversely affect our ability to pay cash distributions to holders of common units. Our general partner has sole discretion to determine the amount of these expenses,

Risk factors

subject to an annual limit. In addition, our general partner and its affiliates may provide us other services for which we will be charged fees as determined by our general partner.

Our general partner and its affiliates have limited fiduciary responsibilities and conflicts of interest with respect to our partnership.

The directors and officers of our general partner and its affiliates have duties to manage the general partner in a manner that is beneficial to its members. At the same time, our general partner has duties to manage our partnership in a manner that is beneficial to us. Therefore, our general partner’s duties to us may conflict with the duties of its officers and directors to its members.

Such conflicts may include, among others, the following:


•	decisions of our general partner regarding the amount and timing of asset purchases and sales, cash expenditures, borrowings, issuances of additional units and reserves in any quarter may affect the level of cash available to pay quarterly distributions to unitholders and the general partner;

•	under our partnership agreement, our general partner determines which costs incurred by it and its affiliates are reimbursable by us;

•	our general partner is allowed to take into account the interests of parties other than us, such as EPCO, in resolving conflicts of interest, which has the effect of limiting its fiduciary duty to unitholders;

•	affiliates of our general partner may compete with us in certain circumstances;

•	our general partner may limit its liability and reduce its fiduciary duties, while also restricting the remedies available to unitholders for actions that might, without the limitations, constitute breaches of fiduciary duty. As a result of purchasing units, you are deemed to consent to some actions and conflicts of interest that might otherwise constitute a breach of fiduciary or other duties under applicable law;

•	we do not have any employees and we rely solely on employees of the general partner and its affiliates; and

•	in some instances, our general partner may cause us to borrow funds in order to permit the payment of distributions, even if the purpose or effect of the borrowing is to make incentive distributions.

Even if unitholders are dissatisfied, they cannot easily remove our general partner.

Unlike the holders of common stock in a corporation, unitholders have only limited voting rights on matters affecting our business and, therefore, limited ability to influence management’s decisions regarding our business. Unitholders did not elect our general partner or the directors of the general partner and will have no right to elect our general partner or the directors of our general partner on an annual or other continuing basis.

Furthermore, if unitholders are dissatisfied with the performance of our general partner, they will have little ability to remove our general partner without its consent. Our general partner may not be removed except upon the vote of the holders of at least 64% of the outstanding units voting together as a single class. Because affiliates of our general partner own more than 36% of our outstanding units, the general partner currently cannot be removed without the consent of the general partner and its affiliates.

Unitholders’ voting rights are further restricted by the partnership agreement provision stating that any units held by a person that owns 20% or more of any class of units then outstanding, other than our

Risk factors

general partner and its affiliates, cannot be voted on any matter. In addition, the partnership agreement contains provisions limiting the ability of unitholders to call meetings or to acquire information about our operations, as well as other provisions limiting the unitholders’ ability to influence the manner or direction of management.

As a result of these provisions, the price at which the common units will trade may be lower because of the absence or reduction of a takeover premium in the trading price.

We may issue additional common units without the approval of common unitholders, which would dilute their existing ownership interests.

The issuance of additional common units or other equity securities of equal or senior rank will have the following effects:


•	the proportionate ownership interest of common unitholders in us will decrease;

•	the amount of cash available for distribution on each unit may decrease;

•	the relative voting strength of each previously outstanding unit may be diminished; and

•	the market price of the common units may decline.

Our general partner has a limited call right that may require common unitholders to sell their units at an undesirable time or price.

If at any time our general partner and its affiliates own 85% more of the common units then outstanding, our general partner will have the right, but not the obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the remaining common units held by unaffiliated persons at a price not less than their then current market price. As a result, common unitholders may be required to sell their common units at an undesirable time or price and may therefore not receive any return on their investment. They may also incur a tax liability upon a sale of their units. Under our partnership agreement, Shell is not deemed to be an affiliate of our general partner for purposes of this limited call right.

Common unitholders may not have limited liability if a court finds that limited partner actions constitute control of our business.

Under Delaware law, common unitholders could be held liable for our obligations to the same extent as a general partner if a court determined that the right of limited partners to remove our general partner or to take other action under the partnership agreement constituted participation in the “control” of our business.

Under Delaware law, the general partner generally has unlimited liability for the obligations of the partnership, such as its debts and environmental liabilities, except for those contractual obligations of the partnership that are expressly made without recourse to the general partner.

In addition, Section 17-607 of the Delaware Revised Uniform Limited Partnership Act provides that, under some circumstances, a limited partner may be liable to us for the amount of a distribution for a period of three years from the date of the distribution.

A large number of our outstanding common units may be sold in the market, which may depress the market price of our common units.

Sales of a substantial number of our common units in the public market could cause the market price of our common units to decline. As of March 1, 2005, a total of approximately 381.3 million of our

Risk factors

common units were outstanding. Shell owns 36,572,122 of our common units, representing approximately 9.6% of our outstanding common units at March 1, 2005, and has publicly announced its intention to reduce its holdings of our common units on an orderly schedule over a period of years, taking into account market conditions. Under a registration rights agreement, we are obligated, subject to certain limitations and conditions, to register the common units held by Shell for resale. All of the common units held by Shell are registered for resale under the registration statement of which this prospectus is a part. Please read “Selling Unitholders” and “Plan of Distribution— Distribution by Selling Unitholders.”

Sales of a substantial number of these common units in the trading markets, whether in a single transaction or series of transactions, or the possibility that these sales may occur, could reduce the market price of our outstanding common units. In addition, these sales, or the possibility that these sales may occur, could make it more difficult for us to sell our common units in the future.

TAX RISKS TO COMMON UNITHOLDERS

You are urged to read “Material Tax Consequences” beginning on page 41 for a more complete discussion of the expected material federal income tax consequences of owning and disposing of common units.

The IRS could treat us as a corporation for tax purposes, which would substantially reduce the cash available for distribution to common unitholders.

The anticipated after-tax economic benefit of an investment in the common units depends largely on our being treated as a partnership for federal income tax purposes. We have not requested, and do not plan to request, a ruling from the IRS on this matter.

If we were classified as a corporation for federal income tax purposes, we would pay federal income tax on our income at the corporate tax rate, which is currently a maximum of 35%, and we likely would pay state taxes as well. Distributions to you would generally be taxed again to you as corporate distributions, and no income, gains, losses or deductions would flow through to you. Because a tax would be imposed upon us as a corporation, the cash available for distribution to you would be substantially reduced. Therefore, treatment of us as a corporation would result in a material reduction in the after-tax return to you, likely causing a substantial reduction in the value of the common units.

A change in current law or a change in our business could cause us to be taxed as a corporation for federal income tax purposes or otherwise subject us to entity-level taxation. Our partnership agreement provides that, if a law is enacted or existing law is modified or interpreted in a manner that subjects us to taxation as a corporation or otherwise subjects us to entity-level taxation for federal, state or local income tax purposes, then the minimum quarterly distribution and the target distribution levels will be decreased to reflect that impact on us.

A successful IRS contest of the federal income tax positions we take may adversely impact the market for common units, and the costs of any contests will be borne by our unitholders and our general partner.

We have not requested a ruling from the IRS with respect to any matter affecting us. The IRS may adopt positions that differ from the conclusions of our counsel expressed in the accompanying prospectus or from the positions we take. It may be necessary to resort to administrative or court proceedings to sustain some or all of our counsel’s conclusions or the positions we take. A court may not agree with some or all of our counsel’s conclusions or the positions we take. Any contest with the IRS may materially and adversely impact the market for common units and the price at which they

Risk factors

trade. In addition, the costs of any contest with the IRS, principally legal, accounting and related fees, will be borne indirectly by our unitholders and our general partner.

Common unitholders may be required to pay taxes even if they do not receive any cash distributions.

Common unitholders will be required to pay federal income taxes and, in some cases, state, local and foreign income taxes on their share of our taxable income even if they do not receive any cash distributions from us. They may not receive cash distributions from us equal to their share of our taxable income or even equal to the actual tax liability that results from their share of our taxable income.

Tax gain or loss on the disposition of common units could be different than expected.

If you sell your common units, you will recognize gain or loss equal to the difference between the amount realized and your tax basis in those common units. Prior distributions to you in excess of the total net taxable income you were allocated for a common unit, which decreased your tax basis in that common unit, will, in effect, become taxable income to you if the common unit is sold at a price greater than your tax basis in that common unit, even if the price you receive is less than your original cost. A substantial portion of the amount realized, whether or not representing gain, may be ordinary income to you.

Tax-exempt entities, regulated investment companies and foreign persons face unique tax issues from owning common units that may result in adverse tax consequences to them.

Investment in common units by tax-exempt entities, such as individual retirement accounts (known as IRAs), regulated investment companies (known as mutual funds) and foreign persons raises issues unique to them. For example, virtually all of our income allocated to unitholders who are organizations exempt from federal income tax, including individual retirement accounts and other retirement plans, will be unrelated business taxable income and will be taxable to them. Recent legislation treats net income derived from the ownership of certain publicly traded partnerships (including us) as qualifying income to a regulated investment company. However, this legislation is only effective for taxable years beginning after October 22, 2004, the date of enactment. For taxable years beginning prior to the date of enactment, very little of our income will be qualifying income to a regulated investment company. Distributions to non-U.S. persons will be reduced by withholding taxes at the highest applicable effective tax rate, and non-U.S. persons will be required to file United States federal income tax returns and pay tax on their share of our taxable income.

We will treat each purchaser of common units as having the same tax benefits without regard to the units purchased. The IRS may challenge this treatment, which could adversely affect the value of our common units.

Because we cannot match transferors and transferees of common units, we adopt depreciation and amortization positions that may not conform with all aspects of applicable Treasury regulations. A successful IRS challenge to those positions could adversely affect the amount of tax benefits available to a common unitholder. It also could affect the timing of these tax benefits or the amount of gain from a sale of common units and could have a negative impact on the value of the common units or result in audit adjustments to the common unitholder’s tax returns.

Risk factors

Common unitholders will likely be subject to state and local taxes and return filing requirements in states where they do not live as a result of an investment in our common units.

In addition to federal income taxes, common unitholders will likely be subject to other taxes, including state and local income taxes, unincorporated business taxes and estate, inheritance or intangible taxes that are imposed by the various jurisdictions in which we do business or own property and in which they do not reside. Common unitholders will likely be required to file state and local income tax returns and pay state and local income taxes in some or all of the various jurisdictions in which we do business or own property. Further, they may be subject to penalties for failure to comply with those requirements. It is the responsibility of the common unitholder to file all United States federal, state and local tax returns. Our counsel has not rendered an opinion on the state or local tax consequences of an investment in the common units.

Use of proceeds

We will use the net proceeds from any sale of securities described in this prospectus for future business acquisitions and other general corporate purposes, such as working capital, investments in subsidiaries, the retirement of existing debt and/or the repurchase of common units or other securities. The prospectus supplement will describe the actual use of the net proceeds from the sale of securities. The exact amounts to be used and when the net proceeds will be applied to corporate purposes will depend on a number of factors, including our funding requirements and the availability of alternative funding sources.

We will not receive any proceeds from any sale of common units by any selling unitholders unless otherwise indicated in a prospectus supplement.

Ratio of earnings to fixed charges

The ratios of earnings to fixed charges for Enterprise Products Partners for each of the periods indicated are as follows:


Year ended December 31,										Nine Months Ended
										September 30,
1999		2000		2001		2002		2003		2004

	5.8		6.4		5.1		2.1		2.0		2.5

For purposes of computing the ratio of earnings to fixed charges, “earnings” is the aggregate of the following items:


•	pre-tax income or loss from continuing operations before adjustment for minority interests in consolidated subsidiaries or income or loss from equity investees;

•	plus fixed charges;

•	plus distributed income of equity investees;

•	less capitalized interest; and

•	less minority interest in pre-tax income of subsidiaries that have not incurred fixed charges.

The term “fixed charges” means the sum of the following:


•	interest expensed and capitalized, including amortized premiums, discounts and capitalized expenses related to indebtedness; and

•	an estimate of the interest within rental expenses.

Description of debt securities

In this Description of Debt Securities references to the “Issuer” mean only Enterprise Products Operating L.P. and not its subsidiaries. References to the “Guarantor” mean only Enterprise Products Partners L.P. and not its subsidiaries. References to “we” and “us” mean the Issuer and the Guarantor collectively.

The debt securities will be issued under an Indenture dated as of October 4, 2004 (the “Indenture”), among the Issuer, the Guarantor, and Wells Fargo Bank, National Association, as trustee (the

Description of debt securities

“Trustee”). The terms of the debt securities will include those expressly set forth in the Indenture and those made part of the Indenture by reference to the Trust Indenture Act of 1939, as amended (the “Trust Indenture Act”). Capitalized terms used in this Description of Debt Securities have the meanings specified in the Indenture.

This Description of Debt Securities is intended to be a useful overview of the material provisions of the debt securities and the Indenture. Since this Description of Debt Securities is only a summary, you should refer to the Indenture for a complete description of our obligations and your rights.

GENERAL

The Indenture does not limit the amount of debt securities that may be issued thereunder. Debt securities may be issued under the Indenture from time to time in separate series, each up to the aggregate amount authorized for such series. The debt securities will be general obligations of the Issuer and the Guarantor and may be subordinated to Senior Indebtedness of the Issuer and the Guarantor. See “—Subordination.”

A prospectus supplement and a supplemental indenture (or a resolution of our Board of Directors and accompanying officers’ certificate) relating to any series of debt securities being offered will include specific terms relating to the offering. These terms will include some or all of the following:


•	the form and title of the debt securities;

•	the total principal amount of the debt securities;

•	the portion of the principal amount which will be payable if the maturity of the debt securities is accelerated;

•	the currency or currency unit in which the debt securities will be paid, if not U.S. dollars;

•	any right we may have to defer payments of interest by extending the dates payments are due whether interest on those deferred amounts will be payable as well;

•	the dates on which the principal of the debt securities will be payable;

•	the interest rate which the debt securities will bear and the interest payment dates for the debt securities;

•	any optional redemption provisions;

•	any sinking fund or other provisions that would obligate us to repurchase or otherwise redeem the debt securities;

•	any changes to or additional Events of Default or covenants;

•	whether the debt securities are to be issued as Registered Securities or Bearer Securities or both; and any special provisions for Bearer Securities;

•	the subordination, if any, of the debt securities and any changes to the subordination provisions of the Indenture; and

•	any other terms of the debt securities.

The prospectus supplement will also describe any material United States federal income tax consequences or other special considerations applicable to the applicable series of debt securities, including those applicable to:


•	Bearer Securities;

Description of debt securities


•	debt securities with respect to which payments of principal, premium or interest are determined with reference to an index or formula, including changes in prices of particular securities, currencies or commodities;

•	debt securities with respect to which principal, premium or interest is payable in a foreign or composite currency;

•	debt securities that are issued at a discount below their stated principal amount, bearing no interest or interest at a rate that at the time of issuance is below market rates; and

•	variable rate debt securities that are exchangeable for fixed rate debt securities.

At our option, we may make interest payments, by check mailed to the registered holders thereof or, if so stated in the applicable prospectus supplement, at the option of a holder by wire transfer to an account designated by the holder. Except as otherwise provided in the applicable prospectus supplement, no payment on a Bearer Security will be made by mail to an address in the United States or by wire transfer to an account in the United States.

Registered Securities may be transferred or exchanged, and they may be presented for payment, at the office of the Trustee or the Trustee’s agent in New York City indicated in the applicable prospectus supplement, subject to the limitations provided in the Indenture, without the payment of any service charge, other than any applicable tax or governmental charge. Bearer Securities will be transferable only by delivery. Provisions with respect to the exchange of Bearer Securities will be described in the applicable prospectus supplement.

Any funds we pay to a paying agent for the payment of amounts due on any debt securities that remain unclaimed for two years will be returned to us, and the holders of the debt securities must thereafter look only to us for payment thereof.

GUARANTEE

The Guarantor will unconditionally guarantee to each holder and the Trustee the full and prompt payment of principal of, premium, if any, and interest on the debt securities, when and as the same become due and payable, whether at maturity, upon redemption or repurchase, by declaration of acceleration or otherwise.

CERTAIN COVENANTS

Except as set forth below or as may be provided in a prospectus supplement and supplemental indenture, neither the Issuer nor the Guarantor is restricted by the Indenture from incurring any type of indebtedness or other obligation, from paying dividends or making distributions on its partnership interests or capital stock or purchasing or redeeming its partnership interests or capital stock. The Indenture does not require the maintenance of any financial ratios or specified levels of net worth or liquidity. In addition, the Indenture does not contain any provisions that would require the Issuer to repurchase or redeem or otherwise modify the terms of any of the debt securities upon a change in control or other events involving the Issuer which may adversely affect the creditworthiness of the debt securities.

Limitations on Liens. The Indenture provides that the Guarantor will not, nor will it permit any Subsidiary to, create, assume, incur or suffer to exist any mortgage, lien, security interest, pledge, charge or other encumbrance (“liens”) other than Permitted Liens (as defined below) upon any Principal Property (as defined below) or upon any shares of capital stock of any Subsidiary owning or leasing, either directly or through ownership in another Subsidiary, any Principal Property (a “Restricted Subsidiary”), whether owned or leased on the date of the Indenture or thereafter acquired,

Description of debt securities

to secure any indebtedness for borrowed money (“debt”) of the Guarantor or the Issuer or any other person (other than the debt securities), without in any such case making effective provision whereby all of the debt securities outstanding shall be secured equally and ratably with, or prior to, such debt so long as such debt shall be so secured.

In the Indenture, the term “Consolidated Net Tangible Assets” means, at any date of determination, the total amount of assets of the Guarantor and its consolidated subsidiaries after deducting therefrom:


	(1) all current liabilities (excluding (A) any current liabilities that by their terms are extendable or renewable at the option of the obligor thereon to a time more than 12 months after the time as of which the amount thereof is being computed, and (B) current maturities of long-term debt); and

	(2) the value (net of any applicable reserves) of all goodwill, trade names, trademarks, patents and other like intangible assets,

all as set forth, or on a pro forma basis would be set forth, on the consolidated balance sheet of the Guarantor and its consolidated subsidiaries for the Guarantor’s most recently completed fiscal quarter, prepared in accordance with generally accepted accounting principles.

“Permitted Liens” means:


	(1) liens upon rights-of-way for pipeline purposes;

	(2) any statutory or governmental lien or lien arising by operation of law, or any mechanics’, repairmen’s, materialmen’s, suppliers’, carriers’, landlords’, warehousemen’s or similar lien incurred in the ordinary course of business which is not yet due or which is being contested in good faith by appropriate proceedings and any undetermined lien which is incidental to construction, development, improvement or repair; or any right reserved to, or vested in, any municipality or public authority by the terms of any right, power, franchise, grant, license, permit or by any provision of law, to purchase or recapture or to designate a purchaser of, any property;

	(3) liens for taxes and assessments which are (a) for the then current year, (b) not at the time delinquent, or (c) delinquent but the validity or amount of which is being contested at the time by the Guarantor or any Subsidiary in good faith by appropriate proceedings;

	(4) liens of, or to secure performance of, leases, other than capital leases; or any lien securing industrial development, pollution control or similar revenue bonds;

	(5) any lien upon property or assets acquired or sold by the Guarantor or any Subsidiary resulting from the exercise of any rights arising out of defaults on receivables;

	(6) any lien in favor of the Guarantor or any Subsidiary; or any lien upon any property or assets of the Guarantor or any Subsidiary in existence on the date of the execution and delivery of the Indenture;

	(7) any lien in favor of the United States of America or any state thereof, or any department, agency or instrumentality or political subdivision of the United States of America or any state thereof, to secure partial, progress, advance, or other payments pursuant to any contract or statute, or any debt incurred by the Guarantor or any Subsidiary for the purpose of financing all or any part of the purchase price of, or the cost of constructing, developing, repairing or improving, the property or assets subject to such lien;

	(8) any lien incurred in the ordinary course of business in connection with workmen’s compensation, unemployment insurance, temporary disability, social security, retiree health or

Description of debt securities


	similar laws or regulations or to secure obligations imposed by statute or governmental regulations;

	(9) liens in favor of any person to secure obligations under provisions of any letters of credit, bank guarantees, bonds or surety obligations required or requested by any governmental authority in connection with any contract or statute; or any lien upon or deposits of any assets to secure performance of bids, trade contracts, leases or statutory obligations;

	(10) any lien upon any property or assets created at the time of acquisition of such property or assets by the Guarantor or any Subsidiary or within one year after such time to secure all or a portion of the purchase price for such property or assets or debt incurred to finance such purchase price, whether such debt was incurred prior to, at the time of or within one year after the date of such acquisition; or any lien upon any property or assets to secure all or part of the cost of construction, development, repair or improvements thereon or to secure debt incurred prior to, at the time of, or within one year after completion of such construction, development, repair or improvements or the commencement of full operations thereof (whichever is later), to provide funds for any such purpose;

	(11) any lien upon any property or assets existing thereon at the time of the acquisition thereof by the Guarantor or any Subsidiary and any lien upon any property or assets of a person existing thereon at the time such person becomes a Subsidiary by acquisition, merger or otherwise; provided that, in each case, such lien only encumbers the property or assets so acquired or owned by such person at the time such person becomes a Subsidiary;

	(12) liens imposed by law or order as a result of any proceeding before any court or regulatory body that is being contested in good faith, and liens which secure a judgment or other court-ordered award or settlement as to which the Guarantor or the applicable Subsidiary has not exhausted its appellate rights;

	(13) any extension, renewal, refinancing, refunding or replacement (or successive extensions, renewals, refinancing, refunding or replacements) of liens, in whole or in part, referred to in clauses (1) through (12) above; provided, however, that any such extension, renewal, refinancing, refunding or replacement lien shall be limited to the property or assets covered by the lien extended, renewed, refinanced, refunded or replaced and that the obligations secured by any such extension, renewal, refinancing, refunding or replacement lien shall be in an amount not greater than the amount of the obligations secured by the lien extended, renewed, refinanced, refunded or replaced and any expenses of the Guarantor and its Subsidiaries (including any premium) incurred in connection with such extension, renewal, refinancing, refunding or replacement; or

	(14) any lien resulting from the deposit of moneys or evidence of indebtedness in trust for the purpose of defeasing debt of the Guarantor or any Subsidiary.

“Principal Property” means, whether owned or leased on the date of the Indenture or thereafter acquired:


	(1) any pipeline assets of the Guarantor or any Subsidiary, including any related facilities employed in the transportation, distribution, storage or marketing of refined petroleum products, natural gas liquids, and petrochemicals, that are located in the United States of America or any territory or political subdivision thereof; and

	(2) any processing or manufacturing plant or terminal owned or leased by the Guarantor or any Subsidiary that is located in the United States or any territory or political subdivision thereof,

Description of debt securities


	except, in the case of either of the foregoing clauses (1) or (2):

	(a) any such assets consisting of inventories, furniture, office fixtures and equipment (including data processing equipment), vehicles and equipment used on, or useful with, vehicles; and

	(b) any such assets, plant or terminal which, in the opinion of the board of directors of the general partner of the Issuer, is not material in relation to the activities of the Issuer or of the Guarantor and its Subsidiaries taken as a whole.

“Subsidiary” means:


	(1) the Issuer; or

	(2) any corporation, association or other business entity of which more than 50% of the total voting power of the equity interests entitled (without regard to the occurrence of any contingency) to vote in the election of directors, managers or trustees thereof or any partnership of which more than 50% of the partners’ equity interests (considering all partners’ equity interests as a single class) is, in each case, at the time owned or controlled, directly or indirectly, by the Guarantor, the Issuer or one or more of the other Subsidiaries of the Guarantor or the Issuer or combination thereof.

Notwithstanding the preceding, under the Indenture, the Guarantor may, and may permit any Subsidiary to, create, assume, incur, or suffer to exist any lien (other than a Permitted Lien) upon any Principal Property or capital stock of a Restricted Subsidiary to secure debt of the Guarantor, the Issuer or any other person (other than the debt securities), without securing the debt securities, provided that the aggregate principal amount of all debt then outstanding secured by such lien and all similar liens, together with all Attributable Indebtedness from Sale-Leaseback Transactions (excluding Sale-Leaseback Transactions permitted by clauses (1) through (4), inclusive, of the first paragraph of the restriction on sale-leasebacks covenant described below) does not exceed 10% of Consolidated Net Tangible Assets.

Restriction on Sale-Leasebacks. The Indenture provides that the Guarantor will not, and will not permit any Subsidiary to, engage in the sale or transfer by the Guarantor or any Subsidiary of any Principal Property to a person (other than the Issuer or a Subsidiary) and the taking back by the Guarantor or any Subsidiary, as the case may be, of a lease of such Principal Property (a “Sale-Leaseback Transaction”), unless:


	(1) such Sale-Leaseback Transaction occurs within one year from the date of completion of the acquisition of the Principal Property subject thereto or the date of the completion of construction, development or substantial repair or improvement, or commencement of full operations on such Principal Property, whichever is later;

	(2) the Sale-Leaseback Transaction involves a lease for a period, including renewals, of not more than three years;

	(3) the Guarantor or such Subsidiary would be entitled to incur debt secured by a lien on the Principal Property subject thereto in a principal amount equal to or exceeding the Attributable Indebtedness from such Sale-Leaseback Transaction without equally and ratably securing the debt securities; or

	(4) the Guarantor or such Subsidiary, within a one-year period after such Sale-Leaseback Transaction, applies or causes to be applied an amount not less than the Attributable Indebtedness from such Sale-Leaseback Transaction to (a) the prepayment, repayment, redemption, reduction or retirement of any debt of the Guarantor or any Subsidiary that is not

Description of debt securities


	subordinated to the debt securities, or (b) the expenditure or expenditures for Principal Property used or to be used in the ordinary course of business of the Guarantor or its Subsidiaries.

“Attributable Indebtedness,” when used with respect to any Sale-Leaseback Transaction, means, as at the time of determination, the present value (discounted at the rate set forth or implicit in the terms of the lease included in such transaction) of the total obligations of the lessee for rental payments (other than amounts required to be paid on account of property taxes, maintenance, repairs, insurance, assessments, utilities, operating and labor costs and other items that do not constitute payments for property rights) during the remaining term of the lease included in such Sale-Leaseback Transaction (including any period for which such lease has been extended). In the case of any lease that is terminable by the lessee upon the payment of a penalty or other termination payment, such amount shall be the lesser of the amount determined assuming termination upon the first date such lease may be terminated (in which case the amount shall also include the amount of the penalty or termination payment, but no rent shall be considered as required to be paid under such lease subsequent to the first date upon which it may be so terminated) or the amount determined assuming no such termination.

Notwithstanding the preceding, under the Indenture the Guarantor may, and may permit any Subsidiary to, effect any Sale-Leaseback Transaction that is not excepted by clauses (1) through (4), inclusive, of the first paragraph under “—Restrictions on Sale-Leasebacks,” provided that the Attributable Indebtedness from such Sale-Leaseback Transaction, together with the aggregate principal amount of all other such Attributable Indebtedness deemed to be outstanding in respect of all Sale-Leaseback Transactions and all outstanding debt (other than the debt securities) secured by liens (other than Permitted Liens) upon Principal Properties or upon capital stock of any Restricted Subsidiary, do not exceed 10% of Consolidated Net Tangible Assets.

Merger, Consolidation or Sale of Assets. The Indenture provides that each of the Guarantor and the Issuer may, without the consent of the holders of any of the debt securities, consolidate with or sell, lease, convey all or substantially all of its assets to, or merge with or into, any partnership, limited liability company or corporation if:


	(1) the entity surviving any such consolidation or merger or to which such assets shall have been transferred (the “successor”) is either the Guarantor or the Issuer, as applicable, or the successor is a domestic partnership, limited liability company or corporation and expressly assumes all the Guarantor’s or the Issuer’s, as the case may be, obligations and liabilities under the Indenture and the debt securities (in the case of the Issuer) and the Guarantee (in the case of the Guarantor);

	(2) immediately after giving effect to the transaction no Default or Event of Default has occurred and is continuing; and

	(3) the Issuer and the Guarantor have delivered to the Trustee an officers’ certificate and an opinion of counsel, each stating that such consolidation, merger or transfer complies with the Indenture.

The successor will be substituted for the Guarantor or the Issuer, as the case may be, in the Indenture with the same effect as if it had been an original party to the Indenture. Thereafter, the successor may exercise the rights and powers of the Guarantor or the Issuer, as the case may be, under the Indenture, in its name or in its own name. If the Guarantor or the Issuer sells or transfers all or substantially all of its assets, it will be released from all liabilities and obligations under the Indenture and under the debt securities (in the case of the Issuer) and the Guarantee (in the case of the Guarantor) except that no such release will occur in the case of a lease of all or substantially all of its assets.

Description of debt securities

EVENTS OF DEFAULT

Each of the following will be an Event of Default under the Indenture with respect to a series of debt securities:


	(1) default in any payment of interest on any debt securities of that series when due, continued for 30 days;

	(2) default in the payment of principal of or premium, if any, on any debt securities of that series when due at its stated maturity, upon optional redemption, upon declaration or otherwise;

	(3) failure by the Guarantor or the Issuer to comply for 60 days after notice with its other agreements contained in the Indenture;

	(4) certain events of bankruptcy, insolvency or reorganization of the Issuer or the Guarantor (the “bankruptcy provisions”); or

	(5) the Guarantee ceases to be in full force and effect or is declared null and void in a judicial proceeding or the Guarantor denies or disaffirms its obligations under the Indenture or the Guarantee.

However, a default under clause (3) of this paragraph will not constitute an Event of Default until the Trustee or the holders of at least 25% in principal amount of the outstanding debt securities of that series notify the Issuer and the Guarantor of the default such default is not cured within the time specified in clause (3) of this paragraph after receipt of such notice.

An Event of Default for a particular series of debt securities will not necessarily constitute an Event of Default for any other series of debt securities that may be issued under the Indenture. If an Event of Default (other than an Event of Default described in clause (4) above) occurs and is continuing, the Trustee by notice to the Issuer, or the holders of at least 25% in principal amount of the outstanding debt securities of that series by notice to the Issuer and the Trustee, may, and the Trustee at the request of such holders shall, declare the principal of, premium, if any, and accrued and unpaid interest, if any, on all the debt securities of that series to be due and payable. Upon such a declaration, such principal, premium and accrued and unpaid interest will be due and payable immediately. If an Event of Default described in clause (4) above occurs and is continuing, the principal of, premium, if any, and accrued and unpaid interest on all the debt securities will become and be immediately due and payable without any declaration or other act on the part of the Trustee or any holders. However, the effect of such provision may be limited by applicable law. The holders of a majority in principal amount of the outstanding debt securities of a series may rescind any such acceleration with respect to the debt securities of that series and its consequences if rescission would not conflict with any judgment or decree of a court of competent jurisdiction and all existing Events of Default with respect to that series, other than the nonpayment of the principal of, premium, if any, and interest on the debt securities of that series that have become due solely by such declaration of acceleration, have been cured or waived.

Subject to the provisions of the Indenture relating to the duties of the Trustee, if an Event of Default with respect to a series of debt securities occurs and is continuing, the Trustee will be under no obligation to exercise any of the rights or powers under the Indenture at the request or direction of any of the holders of debt securities of that series, unless such holders have offered to the Trustee reasonable indemnity or security against any loss, liability or expense. Except to enforce the right to

Description of debt securities

receive payment of principal, premium, if any, or interest when due, no holder of debt securities of any series may pursue any remedy with respect to the Indenture or the debt securities of that series unless:


	(1) such holder has previously given the Trustee notice that an Event of Default with respect to the debt securities of that series is continuing;

	(2) holders of at least 25% in principal amount of the outstanding debt securities of that series have requested the Trustee to pursue the remedy;

	(3) such holders have offered the Trustee reasonable security or indemnity against any loss, liability or expense;

	(4) the Trustee has not complied with such request within 60 days after the receipt of the request and the offer of security or indemnity; and

	(5) the holders of a majority in principal amount of the outstanding debt securities of that series have not given the Trustee a direction that, in the opinion of the Trustee, is inconsistent with such request within such 60-day period.

Subject to certain restrictions, the holders of a majority in principal amount of the outstanding debt securities of each series have the right to direct the time, method and place of conducting any proceeding for any remedy available to the Trustee or of exercising any trust or power conferred on the Trustee with respect to that series of debt securities. The Trustee, however, may refuse to follow any direction that conflicts with law or the Indenture or that the Trustee determines is unduly prejudicial to the rights of any other holder of debt securities of that series or that would involve the Trustee in personal liability.

The Indenture provides that if a Default (that is, an event that is, or after notice or the passage of time would be, an Event of Default) with respect to the debt securities of a particular series occurs and is continuing and is known to the Trustee, the Trustee must mail to each holder of debt securities of that series notice of the Default within 90 days after it occurs. Except in the case of a Default in the payment of principal of, premium, if any, or interest on the debt securities of that series, the Trustee may withhold notice, but only if and so long as the Trustee in good faith determines that withholding notice is in the interests of the holders of debt securities of that series. In addition, the Issuer is required to deliver to the Trustee, within 120 days after the end of each fiscal year, an officers’ certificate as to compliance with all covenants in the Indenture and indicating whether the signers thereof know of any Default or Event of Default that occurred during the previous year. The Issuer also is required to deliver to the Trustee, within 30 days after the occurrence thereof, an officers’ certificate specifying any Default or Event of Default, its status and what action the Issuer is taking or proposes to take in respect thereof.

AMENDMENTS AND WAIVERS

Amendments of the Indenture may be made by the Issuer, the Guarantor and the Trustee with the consent of the holders of a majority in principal amount of all debt securities of each series affected thereby then outstanding under the Indenture (including consents obtained in connection with a tender offer or exchange offer for the debt securities). However, without the consent of each holder of outstanding debt securities affected thereby, no amendment may, among other things:


	(1) reduce the percentage in principal amount of debt securities whose holders must consent to an amendment;

	(2) reduce the stated rate of or extend the stated time for payment of interest on any debt securities;

Description of debt securities


	(3) reduce the principal of or extend the stated maturity of any debt securities;

	(4) reduce the premium payable upon the redemption of any debt securities or change the time at which any debt securities may be redeemed;

	(5) make any debt securities payable in money other than that stated in the debt securities;

	(6) impair the right of any holder to receive payment of, premium, if any, principal of and interest on such holder’s debt securities on or after the due dates therefor or to institute suit for the enforcement of any payment on or with respect to such holder’s debt securities;

	(7) make any change in the amendment provisions which require each holder’s consent or in the waiver provisions;

	(8) release any security that may have been granted in respect of the debt securities; or

	(9) release the Guarantor or modify the Guarantee in any manner adverse to the holders.

The holders of a majority in aggregate principal amount of the outstanding debt securities of each series affected thereby, may waive compliance by the Issuer and the Guarantor with certain restrictive covenants on behalf of all holders of debt securities of such series, including those described under “—Certain Covenants— Limitations on Liens” and “—Certain Covenants— Restriction on Sale-Leasebacks.” The holders of a majority in principal amount of the outstanding debt securities of each series affected thereby, on behalf of all such holders, may waive any past Default or Event of Default with respect to that series (including any such waiver obtained in connection with a tender offer or exchange offer for the debt securities), except a Default or Event of Default in the payment of principal, premium or interest or in respect of a provision that under the Indenture that cannot be amended without the consent of all holders of the series of debt securities that is affected.

Without the consent of any holder, the Issuer, the Guarantor and the Trustee may amend the Indenture to:


	(1) cure any ambiguity, omission, defect or inconsistency;

	(2) provide for the assumption by a successor of the obligations of the Guarantor or the Issuer under the Indenture;

	(3) provide for uncertificated debt securities in addition to or in place of certificated debt securities (provided that the uncertificated debt securities are issued in registered form for purposes of Section 163(f) of the Code, or in a manner such that the uncertificated debt securities are described in Section 163(f)(2)(B) of the Code);

	(4) add or release guarantees by any Subsidiary with respect to the debt securities, in either case as provided in the Indenture;

	(5) secure the debt securities or a guarantee;

	(6) add to the covenants of the Guarantor or the Issuer for the benefit of the holders or surrender any right or power conferred upon the Guarantor or the Issuer;

	(7) make any change that does not adversely affect the rights of any holder;

	(8) comply with any requirement of the Commission in connection with the qualification of the Indenture under the Trust Indenture Act; and

	(9) issue any other series of debt securities under the Indenture.

The consent of the holders is not necessary under the Indenture to approve the particular form of any proposed amendment. It is sufficient if such consent approves the substance of the proposed

Description of debt securities

amendment. After an amendment requiring consent of the holders becomes effective, the Issuer is required to mail to the holders of an affected series a notice briefly describing such amendment. However, the failure to give such notice to all such holders, or any defect therein, will not impair or affect the validity of the amendment.

DEFEASANCE AND DISCHARGE

The Issuer at any time may terminate all its obligations under the Indenture as they relate to a series of debt securities (“legal defeasance”), except for certain obligations, including those respecting the defeasance trust and obligations to register the transfer or exchange of the debt securities of that series, to replace mutilated, destroyed, lost or stolen debt securities of that series and to maintain a registrar and paying agent in respect of such debt securities.

The Issuer at any time may terminate its obligations under covenants described under “—Certain Covenants” (other than “Merger, Consolidation or Sale of Assets”) and the bankruptcy provisions with respect to the Guarantor, and the Guarantee provision, described under “—Events of Default” above with respect to a series of debt securities (“covenant defeasance”).

The Issuer may exercise its legal defeasance option notwithstanding its prior exercise of its covenant defeasance option. If the Issuer exercises its legal defeasance option, payment of the defeased series of debt securities may not be accelerated because of an Event of Default with respect thereto. If the Issuer exercises its covenant defeasance option, payment of the affected series of debt securities may not be accelerated because of an Event of Default specified in clause (3), (4), (with respect only to the Guarantor) or (5) under “—Events of Default” above. If the Issuer exercises either its legal defeasance option or its covenant defeasance option, each guarantee will terminate with respect to the debt securities of the defeased series and any security that may have been granted with respect to such debt securities will be released.

In order to exercise either defeasance option, the Issuer must irrevocably deposit in trust (the “defeasance trust”) with the Trustee money, U.S. Government Obligations (as defined in the Indenture) or a combination thereof for the payment of principal, premium, if any, and interest on the relevant series of debt securities to redemption or maturity, as the case may be, and must comply with certain other conditions, including delivery to the Trustee of an opinion of counsel (subject to customary exceptions and exclusions) to the effect that holders of that series of debt securities will not recognize income, gain or loss for federal income tax purposes as a result of such deposit and defeasance and will be subject to federal income tax on the same amounts and in the same manner and at the same times as would have been the case if such defeasance had not occurred. In the case of legal defeasance only, such opinion of counsel must be based on a ruling of the Internal Revenue Service or other change in applicable federal income tax law.

In the event of any legal defeasance, holders of the debt securities of the relevant series would be entitled to look only to the trust fund for payment of principal of and any premium and interest on their debt securities until maturity.

Although the amount of money and U.S. Government Obligations on deposit with the Trustee would be intended to be sufficient to pay amounts due on the debt securities of a defeased series at the time of their stated maturity, if the Issuer exercises its covenant defeasance option for the debt securities of any series and the debt securities are declared due and payable because of the occurrence of an Event of Default, such amount may not be sufficient to pay amounts due on the debt securities of that series at the time of the acceleration resulting from such Event of Default. The Issuer would remain liable for such payments, however.

Description of debt securities

In addition, the Issuer may discharge all its obligations under the Indenture with respect to debt securities of any series, other than its obligation to register the transfer of and exchange notes of that series, provided that it either:


•	delivers all outstanding debt securities of that series to the Trustee for cancellation; or

•	all such debt securities not so delivered for cancellation have either become due and payable or will become due and payable at their stated maturity within one year or are called for redemption within one year, and in the case of this bullet point the Issuer has deposited with the Trustee in trust an amount of cash sufficient to pay the entire indebtedness of such debt securities, including interest to the stated maturity or applicable redemption date.

SUBORDINATION

Debt securities of a series may be subordinated to our “Senior Indebtedness,” which we define generally to include all notes or other evidences of indebtedness for money borrowed by the Issuer, including guarantees, that are not expressly subordinate or junior in right of payment to any other indebtedness of the Issuer. Subordinated debt securities and the Guarantor’s guarantee thereof will be subordinate in right of payment, to the extent and in the manner set forth in the Indenture and the prospectus supplement relating to such series, to the prior payment of all indebtedness of the Issuer and Guarantor that is designated as “Senior Indebtedness” with respect to the series.

The holders of Senior Indebtedness of the Issuer will receive payment in full of the Senior Indebtedness before holders of subordinated debt securities will receive any payment of principal, premium or interest with respect to the subordinated debt securities:


•	upon any payment of distribution of our assets of the Issuer to its creditors;

•	upon a total or partial liquidation or dissolution of the Issuer; or

•	in a bankruptcy, receivership or similar proceeding relating to the Issuer or its property.

Until the Senior Indebtedness is paid in full, any distribution to which holders of subordinated debt securities would otherwise be entitled will be made to the holders of Senior Indebtedness, except that such holders may receive units representing limited partner interests and any debt securities that are subordinated to Senior Indebtedness to at least the same extent as the subordinated debt securities.

If the Issuer does not pay any principal, premium or interest with respect to Senior Indebtedness within any applicable grace period (including at maturity), or any other default on Senior Indebtedness occurs and the maturity of the Senior Indebtedness is accelerated in accordance with its terms, the Issuer may not:


•	make any payments of principal, premium, if any, or interest with respect to subordinated debt securities;

•	make any deposit for the purpose of defeasance of the subordinated debt securities; or

•	repurchase, redeem or otherwise retire any subordinated debt securities, except that in the case of subordinated debt securities that provide for a mandatory sinking fund, we may deliver subordinated debt securities to the Trustee in satisfaction of our sinking fund obligation,

unless, in either case,


•	the default has been cured or waived and the declaration of acceleration has been rescinded;

•	the Senior Indebtedness has been paid in full in cash; or

Description of debt securities


•	the Issuer and the Trustee receive written notice approving the payment from the representatives of each issue of “Designated Senior Indebtedness.”

Generally, “Designated Senior Indebtedness” will include any specified issue of Senior Indebtedness of at least $100 million.

During the continuance of any default, other than a default described in the immediately preceding paragraph, that may cause the maturity of any Senior Indebtedness to be accelerated immediately without further notice, other than any notice required to effect such acceleration, or the expiration of any applicable grace periods, the Issuer may not pay the subordinated debt securities for a period called the “Payment Blockage Period.” A Payment Blockage Period will commence on the receipt by us and the Trustee of written notice of the default, called a “Blockage Notice,” from the representative of any Designated Senior Indebtedness specifying an election to effect a Payment Blockage Period.

The Payment Blockage Period may be terminated before its expiration:


•	by written notice from the person or persons who gave the Blockage Notice;

•	by repayment in full in cash of the Senior Indebtedness with respect to which the Blockage Notice was given; or

•	if the default giving rise to the Payment Blockage Period is no longer continuing.

Unless the holders of Senior Indebtedness shall have accelerated the maturity of the Senior Indebtedness, we may resume payments on the subordinated debt securities after the expiration of the Payment Blockage Period.

Generally, not more than one Blockage Notice may be given in any period of 360 consecutive days. The total number of days during which any one or more Payment Blockage Periods are in effect, however, may not exceed an aggregate of 179 days during any period of 360 consecutive days.

After all Senior Indebtedness is paid in full and until the subordinated debt securities are paid in full, holders of the subordinated debt securities shall be subrogated to the rights of holders of Senior Indebtedness to receive distributions applicable to Senior Indebtedness.

By reason of the subordination, in the event of insolvency, our creditors who are holders of Senior Indebtedness, as well as certain of our general creditors, may recover more, ratably, than the holders of the subordinated debt securities.

BOOK-ENTRY SYSTEM

We will issue the debt securities in the form of one or more global securities in fully registered form initially in the name of Cede & Co., as nominee of DTC, or such other name as may be requested by an authorized representative of DTC. The global securities will be deposited with the Trustee as custodian for DTC and may not be transferred except as a whole by DTC to a nominee of DTC or by a nominee of DTC to DTC or another nominee of DTC or by DTC or any nominee to a successor of DTC or a nominee of such successor.

DTC has advised us as follows:


•	DTC is a limited-purpose trust company organized under the New York Banking Law, a “banking organization” within the meaning of the New York Banking Law, a member of the Federal Reserve System, a “clearing corporation” within the meaning of the New York Uniform Commercial Code, and a “clearing agency” registered pursuant to the provisions of Section 17A of the Exchange Act.

•	DTC holds securities that its participants deposit with DTC and facilitates the settlement among direct participants of securities transactions, such as transfers and pledges, in deposited securities,

Description of debt securities


	through electronic computerized book-entry changes in direct participants’ accounts, thereby eliminating the need for physical movement of securities certificates.

•	Direct participants include securities brokers and dealers, banks, trust companies, clearing corporations and certain other organizations.

•	DTC is owned by a number of its direct participants and by the New York Stock Exchange, Inc., the American Stock Exchange LLC and the National Association of Securities Dealers, Inc.

•	Access to the DTC system is also available to others such as securities brokers and dealers, banks and trust companies that clear through or maintain a custodial relationship with a direct participant, either directly or indirectly.

•	The rules applicable to DTC and its direct and indirect participants are on file with the Commission.

Purchases of debt securities under the DTC system must be made by or through direct participants, which will receive a credit for the debt securities on DTC’s records. The ownership interest of each actual purchaser of debt securities is in turn to be recorded on the direct and indirect participants’ records. Beneficial owners of the debt securities will not receive written confirmation from DTC of their purchase, but beneficial owners are expected to receive written confirmations providing details of the transaction, as well as periodic statements of their holdings, from the direct or indirect participants through which the beneficial owner entered into the transaction. Transfers of ownership interests in the debt securities are to be accomplished by entries made on the books of direct and indirect participants acting on behalf of beneficial owners. Beneficial owners will not receive certificates representing their ownership interests in the debt securities, except in the event that use of the book-entry system for the debt securities is discontinued.

To facilitate subsequent transfers, all debt securities deposited by direct participants with DTC are registered in the name of DTC’s partnership nominee, Cede & Co., or such other name as may be requested by an authorized representative of DTC. The deposit of debt securities with DTC and their registration in the name of Cede & Co. or such other nominee do not effect any change in beneficial ownership. DTC has no knowledge of the actual beneficial owners of the debt securities; DTC’s records reflect only the identity of the direct participants to whose accounts such debt securities are credited, which may or may not be the beneficial owners. The direct and indirect participants will remain responsible for keeping account of their holdings on behalf of their customers.

Conveyance of notices and other communications by DTC to direct participants, by, direct participants to indirect participants, and by direct participants and indirect participants to beneficial owners will be governed by arrangements among them, subject to any statutory or regulatory requirements as may be in effect from time to time.

Neither DTC nor Cede & Co. (nor any other DTC nominee) will consent or vote with respect to the global securities. Under its usual procedures, DTC mails an omnibus proxy to the issuer as soon as possible after the record date. The omnibus proxy assigns Cede & Co.’s consenting or voting rights to those direct participants to whose accounts the debt securities are credited on the record date (identified in the listing attached to the omnibus proxy).

All payments on the global securities will be made to Cede & Co., as holder of record, or such other nominee as may be requested by an authorized representative of DTC. DTC’s practice is to credit direct participants’ accounts upon DTC’s receipt of funds and corresponding detail information from us or the Trustee on payment dates in accordance with their respective holdings shown on DTC’s records. Payments by participants to beneficial owners will be governed by standing instructions and customary practices, as is the case with securities held for the accounts of customers in bearer form or

Description of debt securities

registered in “street name,” and will be the responsibility of such participant and not of DTC, us or the Trustee, subject to any statutory or regulatory requirements as may be in effect from time to time. Payment of principal, premium, if any, and interest to Cede & Co. (or such other nominee as may be requested by an authorized representative of DTC) shall be the responsibility of us or the Trustee. Disbursement of such payments to direct participants shall be the responsibility of DTC, and disbursement of such payments to the beneficial owners shall be the responsibility of direct and indirect participants.

DTC may discontinue providing its service as securities depositary with respect to the debt securities at any time by giving reasonable notice to us or the Trustee. In addition, we may decide to discontinue use of the system of book-entry transfers through DTC (or a successor securities depositary). Under such circumstances, in the event that a successor securities depositary is not obtained, note certificates in fully registered form are required to be printed and delivered to beneficial owners of the global securities representing such debt securities.

Neither we nor the Trustee will have any responsibility or obligation to direct or indirect participants, or the persons for whom they act as nominees, with respect to the accuracy of the records of DTC, its nominee or any participant with respect to any ownership interest in the debt securities, or payments to, or the providing of notice to participants or beneficial owners.

So long as the debt securities are in DTC’s book-entry system, secondary market trading activity in the debt securities will settle in immediately available funds. All payments on the debt securities issued as global securities will be made by us in immediately available funds.

LIMITATIONS ON ISSUANCE OF BEARER SECURITIES

The debt securities of a series may be issued as Registered Securities (which will be registered as to principal and interest in the register maintained by the registrar for the debt securities) or Bearer Securities (which will be transferable only by delivery). If the debt securities are issuable as Bearer Securities, certain special limitations and conditions will apply.

In compliance with United States federal income tax laws and regulations, we and any underwriter, agent or dealer participating in an offering of Bearer Securities will agree that, in connection with the original issuance of the Bearer Securities and during the period ending 40 days after the issue date, they will not offer, sell or deliver any such Bearer Securities, directly or indirectly, to a United States Person (as defined below) or to any person within the United States, except to the extent permitted under United States Treasury regulations.

Bearer Securities will bear a legend to the following effect: “Any United States person who holds this obligation will be subject to limitations under the United States federal income tax laws, including the limitations provided in Sections 165(j) and 1287(a) of the Internal Revenue Code.” The sections referred to in the legend provide that, with certain exceptions, a United States taxpayer who holds Bearer Securities will not be allowed to deduct any loss with respect to, and will not be eligible for capital gain treatment with respect to any gain realized on the sale, exchange, redemption or other disposition of, the Bearer Securities.

For this purpose, “United States” includes the United States of America and its possessions, and “United States person” means a citizen or resident of the United States, a corporation, partnership or other entity created or organized in or under the laws of the United States, or an estate or trust the income of which is subject to United States federal income taxation regardless of its source.

Pending the availability of a definitive global security or individual Bearer Securities, as the case may be, debt securities that are issuable as Bearer Securities may initially be represented by a single temporary global security, without interest coupons, to be deposited with a common depositary for the

Description of debt securities

Euroclear System as operated by Euroclear Bank S.A./ N.V. (“Euroclear”) and Clearstream Banking S.A. (“Clearstream”, formerly Cedelbank), for credit to the accounts designated by or on behalf of the purchasers thereof. Following the availability of a definitive global security in bearer form, without coupons attached, or individual Bearer Securities and subject to any further limitations described in the applicable prospectus supplement, the temporary global security will be exchangeable for interests in the definitive global security or for the individual Bearer Securities, respectively, only upon receipt of a “Certificate of Non-U.S. Beneficial Ownership,” which is a certificate to the effect that a beneficial interest in a temporary global security is owned by a person that is not a United States Person or is owned by or through a financial institution in compliance with applicable United States Treasury regulations. No Bearer Security will be delivered in or to the United States. If so specified in the applicable prospectus supplement, interest on a temporary global security will be paid to each of Euroclear and Clearstream with respect to that portion of the temporary global security held for its account, but only upon receipt as of the relevant interest payment date of a Certificate of Non-U.S. Beneficial Ownership.

NO RECOURSE AGAINST GENERAL PARTNER

The Issuer’s general partner, the Guarantor’s general partner and their respective directors, officers, employees and members, as such, shall have no liability for any obligations of the Issuer or the Guarantor under the debt securities, the Indenture or the guarantee or for any claim based on, in respect of, or by reason of, such obligations or their creation. Each holder by accepting a note waives and releases all such liability. The waiver and release are part of the consideration for issuance of the debt securities. Such waiver may not be effective to waive liabilities under the federal securities laws, and it is the view of the Commission that such a waiver is against public policy.

CONCERNING THE TRUSTEE

The Indenture contains certain limitations on the right of the Trustee, should it become our creditor, to obtain payment of claims in certain cases, or to realize for its own account on certain property received in respect of any such claim as security or otherwise. The Trustee is permitted to engage in certain other transactions. However, if it acquires any conflicting interest within the meaning of the Trust Indenture Act, it must eliminate the conflict or resign as Trustee.

The holders of a majority in principal amount of all outstanding debt securities (or if more than one series of debt securities under the Indenture is affected thereby, all series so affected, voting as a single class) will have the right to direct the time, method and place of conducting any proceeding for exercising any remedy or power available to the Trustee for the debt securities or all such series so affected.

If an Event of Default occurs and is not cured under the Indenture and is known to the Trustee, the Trustee shall exercise such of the rights and powers vested in it by the Indenture and use the same degree of care and skill in its exercise as a prudent person would exercise or use under the circumstances in the conduct of his own affairs. Subject to such provisions, the Trustee will not be under any obligation to exercise any of its rights or powers under the Indenture at the request of any of the holders of debt securities unless they shall have offered to such Trustee reasonable security and indemnity.

Wells Fargo Bank, National Association is the Trustee under the Indenture and has been appointed by the Issuer as Registrar and Paying Agent with regard to the debt securities. Wells Fargo Bank, National Association is a lender under the Issuer’s credit facilities.

Description of debt securities

GOVERNING LAW

The Indenture, the debt securities and the guarantee are governed by, and will be construed in accordance with, the laws of the State of New York.

Description of our common units

Generally, our common units represent limited partner interests that entitle the holders to participate in our cash distributions and to exercise the rights and privileges available to limited partners under our partnership agreement. For a description of the relative rights and preferences of holders of common units and our general partner in and to cash distributions, please read “Cash Distribution Policy” elsewhere in this prospectus:


	Our outstanding common units are listed on the NYSE under the symbol “EPD.” Any additional common units we issue will also be listed on the NYSE.

	The transfer agent and registrar for our common units is Mellon Investor Services LLC.

MEETINGS/ VOTING

Each holder of common units is entitled to one vote for each common unit on all matters submitted to a vote of the unitholders.

STATUS AS LIMITED PARTNER OR ASSIGNEE

Except as described below under “—Limited Liability,” the common units will be fully paid, and unitholders will not be required to make additional capital contributions to us.

Each purchaser of our common units must execute a transfer application whereby the purchaser requests admission as a substituted limited partner and makes representations and agrees to provisions stated in the transfer application. If this action is not taken, a purchaser will not be registered as a record holder of common units on the books of our transfer agent or issued a common unit certificate. Purchasers may hold common units in nominee accounts.

An assignee, pending its admission as a substituted limited partner, is entitled to an interest in us equivalent to that of a limited partner with respect to the right to share in allocations and distributions, including liquidating distributions. Our general partner will vote and exercise other powers attributable to common units owned by an assignee who has not become a substituted limited partner at the written direction of the assignee. Transferees who do not execute and deliver transfer applications will be treated neither as assignees nor as record holders of common units and will not receive distributions, federal income tax allocations or reports furnished to record holders of common units. The only right the transferees will have is the right to admission as a substituted limited partner in respect of the transferred common units upon execution of a transfer application in respect of the common units. A nominee or broker who has executed a transfer application with respect to common units held in street name or nominee accounts will receive distributions and reports pertaining to its common units.

LIMITED LIABILITY

Assuming that a limited partner does not participate in the control of our business within the meaning of the Delaware Revised Uniform Limited Partnership Act (the “Delaware Act”) and that he otherwise acts in conformity with the provisions of our partnership agreement, his liability under the Delaware Act will be limited, subject to some possible exceptions, generally to the amount of capital he is obligated to contribute to us in respect of his units plus his share of any undistributed profits and assets.

Under the Delaware Act, a limited partnership may not make a distribution to a partner to the extent that at the time of the distribution, after giving effect to the distribution, all liabilities of the partnership, other than liabilities to partners on account of their partnership interests and liabilities for

Description of our common units

which the recourse of creditors is limited to specific property of the partnership, exceed the fair value of the assets of the limited partnership.

For the purposes of determining the fair value of the assets of a limited partnership, the Delaware Act provides that the fair value of the property subject to liability of which recourse of creditors is limited shall be included in the assets of the limited partnership only to the extent that the fair value of that property exceeds the nonrecourse liability. The Delaware Act provides that a limited partner who receives a distribution and knew at the time of the distribution that the distribution was in violation of the Delaware Act is liable to the limited partnership for the amount of the distribution for three years from the date of the distribution.

REPORTS AND RECORDS

As soon as practicable, but in no event later than 120 days after the close of each fiscal year, our general partner will furnish or make available to each unitholder of record (as of a record date selected by our general partner) an annual report containing our audited financial statements for the past fiscal year. These financial statements will be prepared in accordance with generally accepted accounting principles. In addition, no later than 45 days after the close of each quarter (except the fourth quarter), our general partner will furnish or make available to each unitholder of record (as of a record date selected by our general partner) a report containing our unaudited financial statements and any other information required by law.

Our general partner will use all reasonable efforts to furnish each unitholder of record information reasonably required for tax reporting purposes within 90 days after the close of each fiscal year. Our general partner’s ability to furnish this summary tax information will depend on the cooperation of unitholders in supplying information to our general partner. Each unitholder will receive information to assist him in determining his U.S. federal and state and Canadian federal and provincial tax liability and filing his U.S. federal and state and Canadian federal and provincial income tax returns.

A limited partner can, for a purpose reasonably related to the limited partner’s interest as a limited partner, upon reasonable demand and at his own expense, have furnished to him:


•	a current list of the name and last known address of each partner;

•	a copy of our tax returns;

•	information as to the amount of cash and a description and statement of the agreed value of any other property or services, contributed or to be contributed by each partner and the date on which each became a partner;

•	copies of our partnership agreement, our certificate of limited partnership, amendments to either of them and powers of attorney which have been executed under our partnership agreement;

•	information regarding the status of our business and financial condition; and

•	any other information regarding our affairs as is just and reasonable.

Our general partner may, and intends to, keep confidential from the limited partners trade secrets and other information the disclosure of which our general partner believes in good faith is not in our best interest or which we are required by law or by agreements with third parties to keep confidential.

Cash distribution policy

DISTRIBUTIONS OF AVAILABLE CASH

General. Within approximately 45 days after the end of each quarter, we will distribute all of our available cash to unitholders of record on the applicable record date.

Definition of Available Cash. Available cash is defined in our partnership agreement and generally means, with respect to any calendar quarter, all cash on hand at the end of such quarter:


•	less the amount of cash reserves that is necessary or appropriate in the reasonable discretion of the general partner to:


	-	provide for the proper conduct of our business;

	-	comply with applicable law or any debt instrument or other agreement (including reserves for future capital expenditures and for our future credit needs); or

	-	provide funds for distributions to unitholders and our general partner in respect of any one or more of the next four quarters;

	-	plus all cash on hand on the date of determination of available cash for the quarter resulting from working capital borrowings made after the end of the quarter. Working capital borrowings are generally borrowings that are made under our credit facilities and in all cases are used solely for working capital purposes or to pay distributions to partners.

OPERATING SURPLUS AND CAPITAL SURPLUS

General. Cash distributions are characterized as distributions from either operating surplus or capital surplus. We distribute available cash from operating surplus differently than available cash from capital surplus.

Definition of Operating Surplus. Operating surplus is defined in the partnership agreement and generally means:


•	our cash balance on July 31, 1998, the closing date of our initial public offering of common units (excluding $46.5 million to fund certain capital commitments existing at such closing date); plus

•	all of our cash receipts since the closing of our initial public offering, excluding cash from interim capital transactions such as borrowings that are not working capital borrowings, sales of equity and debt securities and sales or other disposition of assets for cash, other than inventory, accounts receivable and other assets sold in the ordinary course of business or as part of normal retirements or replacements of assets; plus

•	up to $60.0 million of cash from interim capital transactions; plus

•	working capital borrowings made after the end of a quarter but before the date of determination of operating surplus for the quarter; less

•	all of our operating expenditures since the closing of our initial public offering, including the repayment of working capital borrowings, but not the repayment of other borrowings, and including maintenance capital expenditures; less

•	the amount of cash reserved that we deem necessary or advisable to provide funds for future operating expenditures.

Cash distribution policy

Definition of Capital Surplus. Capital surplus is generally generated only by borrowings (other than borrowings for working capital purposes), sales of debt and equity securities and sales or other dispositions of assets for cash (other than inventory, accounts receivable and other assets disposed of in the ordinary course of business).

Characterization of Cash Distributions. To avoid the difficulty of trying to determine whether available cash we distribute is from operating surplus or from capital surplus, all available cash we distribute from any source will be treated as distributed from operating surplus until the sum of all available cash distributed since July 31, 1998 equals the operating surplus as of the end of the quarter prior to such distribution. Any available cash in excess of such amount (irrespective of its source) will be deemed to be from capital surplus and distributed accordingly.

If available cash from capital surplus is distributed in respect of each common unit in an aggregate amount per common unit equal to the $11.00 initial public offering price of the common units, the distinction between operating surplus and capital surplus will cease, and all distributions of available cash will be treated as if they were from operating surplus. We do not anticipate that there will be significant distributions from capital surplus.

DISTRIBUTIONS OF AVAILABLE CASH FROM OPERATING SURPLUS

Commencing with the quarter ending on September 30, 2003, we will make distributions of available cash from operating surplus with respect to any quarter in the following manner:


•	first, 98% to all common unitholders, pro rata and 2% to the general partner, until there has been distributed in respect of each unit an amount equal to the minimum quarterly distribution of $0.225; and

•	thereafter, in the manner described in “Incentive Distributions” below.

INCENTIVE DISTRIBUTIONS

Incentive distributions represent the right to receive an increasing percentage of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and the target distribution levels have been achieved. For any quarter for which available cash from operating surplus is distributed to the common unitholders in an amount equal to the minimum quarterly distribution of $0.225 per unit on all units, then any additional available cash from operating surplus in respect of such quarter will be distributed among the common unitholders and the general partner in the following manner:


•	first, 98% to all common unitholders, pro rata, and 2% to the general partner, until the common unitholders have received a total of $0.253 for such quarter in respect of each outstanding unit (the “First Target Distribution”);

•	second, 85% to all common unitholders, pro rata, and 15% to the general partner, until the unitholders have received a total of $0.3085 for such quarter in respect of each outstanding unit (the “Second Target Distribution”); and

•	thereafter, 75% to all common unitholders, pro rata, and 25% to the general partner.

Cash distribution policy

DISTRIBUTIONS FROM CAPITAL SURPLUS

How Distributions from Capital Surplus Will Be Made. We will make distributions of available cash from capital surplus in the following manner:


•	first, 98% to all common unitholders, pro rata, and 2% to the general partner, until we have distributed, in respect of each outstanding common unit issued in our initial public offering, available cash from capital surplus in an aggregate amount per common unit equal to the initial unit price of $11.00; and

•	thereafter, all distributions of available cash from capital surplus will be distributed as if they were from operating surplus.

Effect of a Distribution from Capital Surplus. Our partnership agreement treats a distribution of capital surplus on a common unit as the repayment of the common unit price from its initial public offering, which is a return of capital. The initial public offering price less any distributions of capital surplus per common unit is referred to as the unrecovered initial common unit price. Each time a distribution of capital surplus is made on a common unit, the minimum quarterly distribution and the target distribution levels for all units will be reduced in the same proportion as the corresponding reduction in the unrecovered initial common unit price. Because distributions of capital surplus will reduce the minimum quarterly distribution, after any of these distributions are made, it may be easier for our general partner to receive incentive distributions. However, any distribution by us of capital surplus before the unrecovered initial common unit price is reduced to zero cannot be applied to the payment of the minimum quarterly distribution.

Once we distribute capital surplus on a common unit in any amount equal to the unrecovered initial common unit price, it will reduce the minimum quarterly distribution and the target distribution levels to zero and it will make all future distributions of available cash from operating surplus, with 25% being paid to the holders of units, as applicable, and 75% to our general partner.

ADJUSTMENT TO THE MINIMUM QUARTERLY DISTRIBUTION AND TARGET DISTRIBUTION LEVELS

In addition to reductions of the minimum quarterly distribution and target distribution levels made upon a distribution of available cash from capital surplus, if we combine our units into fewer units or subdivide our units into a greater number of units, we will proportionately adjust:


•	the minimum quarterly distribution;

•	the target distribution levels; and

•	the unrecovered initial common unit price.

For example, in the event of a two-for-one split of the common units (assuming no prior adjustments), the minimum quarterly distribution, each of the target distribution levels and the unrecovered capital of the common units would each be reduced to 50% of its initial level.

In addition, if legislation is enacted or if existing law is modified or interpreted in a manner that causes us to become taxable as a corporation or otherwise subject to taxation as an entity for federal, state or local income tax purposes, then we will reduce the minimum quarterly distribution and the target distribution levels by multiplying the same by one minus the sum of the highest effective federal corporate income tax rate that could apply and any increase in the effective overall state and local income tax rates. For example, if we became subject to a maximum effective federal, state and local income tax rate of 35%, then the minimum quarterly distribution and the target distribution levels would each be reduced to 65% of their previous levels.

Cash distribution policy

DISTRIBUTIONS OF CASH UPON LIQUIDATION

If we dissolve in accordance with the partnership agreement, we will sell or otherwise dispose of our assets in a process called a liquidation. We will first apply the proceeds of liquidation to the payment of our creditors in the order of priority provided in the partnership agreement and by law and, thereafter, we will distribute any remaining proceeds to the common unitholders and our general partner in accordance with their respective capital account balances as so adjusted.

Manner of Adjustments for Gain. The manner of the adjustment is set forth in the partnership agreement. Upon our liquidation, we will allocate any net gain (or unrealized gain attributable to assets distributed in kind to the partners) as follows:


•	first, to the general partner and the holders of common units having negative balances in their capital accounts to the extent of and in proportion to such negative balances:

•	second, 98% to the holders of common units, pro rata, and 2% to the general partner, until the capital account for each common unit is equal to the sum of


	-	the unrecovered capital in respect of such common unit; plus

	-	the amount of the minimum quarterly distribution for the quarter during which our liquidation occurs.


•	third, 98% to all common unitholders, pro rata, and 2% to the general partner, until there has been allocated under this paragraph third an amount per unit equal to:


	-	the sum of the excess of the First Target Distribution per unit over the minimum quarterly distribution per unit for each quarter of our existence; less

	-	the cumulative amount per unit of any distributions of available cash from operating surplus in excess of the minimum quarterly distribution per unit that were distributed 98% to the unitholders, pro rata, and 2% to the general partner for each quarter of our existence;


•	fourth, 85% to all common unitholders, pro rata, and 15% to the general partner, until there has been allocated under this paragraph fourth an amount per unit equal to:


	-	the sum of