View Filing Data

Cash and cash equivalents

$ 1,061.6

$ 56.9

Restricted cash

6.6

65.6

Accounts receivable - trade, net of allowance for doubtful accounts of $14.8 at September 30, 2014 and $7.5 at December 31, 2013

5,320.8

5,475.5

2.6

6.8

1,589.5

1,093.1

384.4

325.5

8,365.5

7,023.4

27,963.3

26,946.6

Intangible assets, net of accumulated amortization of $1,208.4 at September 30, 2014 and $1,150.0 at December 31, 2013

2,938.3

2,437.1

1,391.1

1,462.2

^[1]

2,079.9

2,080.0

167.4

189.4

42,905.5

40,138.7

Current maturities of debt (see Note 9)

^[2]

1,939.9

1,125.0

728.0

723.7

122.6

150.5

5,564.6

5,608.7

172.5

304.3

444.2

326.5

8,971.8

8,238.7

17,706.5

16,226.5

63.2

60.8

Commitments and contingencies (see Note 14)

182.1

172.3

Limited partners:

Limited partners' equity

16,063.6

15,573.8

Accumulated other comprehensive loss

(306.1)

(359.0)

Total partners' equity

15,757.5

15,214.8

224.4

225.6

15,981.9

15,440.4

General Accounting Matters [Abstract]

$ 42,905.5

$ 40,138.7

[1]

The total carrying amount of goodwill at September 30, 2014 and December 31, 2013 is net of $1.3 million of accumulated impairment charges. No goodwill impairment charges were recorded during the nine months ended September 30, 2014.

[2]

We expect to refinance the current maturities of our debt obligations at or prior to their maturity. Long-term and current maturities of debt reflect the classification of such obligations at September 30, 2014 after taking into consideration the long-term refinancing of Senior Notes G and $650 million of Commercial Paper Notes using proceeds from the issuance of senior notes in October 2014 (see Note 18).

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Current assets:
Accounts receivable, allowance for doubtful accounts	$ 14.8	$ 7.5
Intangible assets, accumulated amortization	$ 1,208.4	$ 1,150.0
Limited partners:
Capital account, units outstanding (in units)	1,880,223,189	1,871,370,016

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Revenues:
Third parties	$ 12,319.2	$ 12,085.6	$ 37,697.1	$ 34,605.4
Related parties	11.0	7.7	63.8	20.3
Total revenues (see Note 11)	12,330.2	12,093.3	37,760.9	34,625.7
Operating costs and expenses:
Third parties	11,198.1	11,055.3	34,198.9	31,404.5
Related parties	216.7	218.2	735.5	656.6
Total operating costs and expenses	11,414.8	11,273.5	34,934.4	32,061.1
General and administrative costs:
Third parties	18.1	17.4	60.0	54.6
Related parties	31.9	26.5	90.9	84.3
Total general and administrative costs	50.0	43.9	150.9	138.9
Total costs and expenses	11,464.8	11,317.4	35,085.3	32,200.0
Equity in income of unconsolidated affiliates	72.3	44.0	179.1	126.1
Operating income	937.7	819.9	2,854.7	2,551.8
Other income (expense):
Interest expense	(229.8)	(208.3)	(679.6)	(604.4)
Interest income	0.3	0.2	1.1	0.7
Other, net	(1.3)	0.4	(1.3)	(0.5)
Total other expense, net	(230.8)	(207.7)	(679.8)	(604.2)
Income before income taxes	706.9	612.2	2,174.9	1,947.6
Provision for income taxes	(7.7)	(19.4)	(22.5)	(46.2)
Net income	699.2	592.8	2,152.4	1,901.4
Net income attributable to noncontrolling interests (see Note 10)	(8.1)	(0.8)	(24.8)	(3.4)
Net income attributable to limited partners	$ 691.1	$ 592.0	$ 2,127.6	$ 1,898.0
Earnings per unit: (see Note 13)
Basic earnings per unit (in dollars per unit)	$ 0.38	$ 0.33	$ 1.16	$ 1.07
Diluted earnings per unit (in dollars per unit)	$ 0.37	$ 0.32	$ 1.13	$ 1.03

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
Net income	$ 699.2	$ 592.8	$ 2,152.4	$ 1,901.4
Commodity derivative instruments:
Changes in fair value of cash flow hedges	58.1	(8.6)	16.1	(22.1)
Reclassification of losses (gains) to net income	(18.0)	14.6	12.9	14.7
Interest rate derivative instruments:
Changes in fair value of cash flow hedges	0.0	0.0	0.0	6.7
Reclassification of losses to net income	8.0	7.7	23.9	21.4
Total cash flow hedges	48.1	13.7	52.9	20.7
Other	0.0	0.0	0.0	0.4
Total other comprehensive income (loss)	48.1	13.7	52.9	21.1
Comprehensive income	747.3	606.5	2,205.3	1,922.5
Comprehensive income attributable to noncontrolling interests	(8.1)	(0.8)	(24.8)	(3.4)
Comprehensive income attributable to limited partners	$ 739.2	$ 605.7	$ 2,180.5	$ 1,919.1

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Operating activities:
Net income	$ 2,152.4	$ 1,901.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	992.4	902.3
Non-cash asset impairment charges (see Note 4)	18.2	53.3
Equity in income of unconsolidated affiliates	(179.1)	(126.1)
Distributions received from unconsolidated affiliates	260.7	187.6
Net gains attributable to asset sales and insurance recoveries (see Note 16)	(99.0)	(68.4)
Deferred income tax expense	2.6	32.1
Changes in fair market value of derivative instruments	(3.8)	(5.3)
Net effect of changes in operating accounts (see Note 16)	(435.8)	(513.9)
Other operating activities	(4.2)	3.2
Net cash flows provided by operating activities	2,704.4	2,366.2
Investing activities:
Capital expenditures	(1,879.5)	(2,413.2)
Contributions in aid of construction costs	20.0	19.9
Decrease (increase) in restricted cash	59.0	(31.6)
Investments in unconsolidated affiliates	(583.3)	(768.4)
Proceeds from asset sales and insurance recoveries (see Note 16)	121.5	256.3
Other investing activities	(5.8)	(0.5)
Cash used in investing activities	(2,268.1)	(2,937.5)
Financing activities:
Borrowings under debt agreements	7,167.5	10,139.2
Repayments of debt	(4,856.3)	(8,791.6)
Debt issuance costs	(18.1)	(23.7)
Monetization of interest rate derivative instruments (see Note 4)	0.0	(168.8)
Cash distributions paid to limited partners (see Note 10)	(1,948.2)	(1,778.3)
Cash payments made in connection with distribution equivalent rights	(2.4)	0.0
Cash distributions paid to noncontrolling interests	(29.4)	(6.4)
Cash contributions from noncontrolling interests (see Note 10)	4.0	104.2
Net cash proceeds from the issuance of common units	304.9	1,134.7
Other financing activities	(53.6)	(44.5)
Cash provided by financing activities	568.4	564.8
Net change in cash and cash equivalents	1,004.7	(6.5)
Cash and cash equivalents, beginning balance	56.9	16.1
Cash and cash equivalents, ending balance	$ 1,061.6	$ 9.6

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED EQUITY - USD ($) $ in Millions	Total	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interests [Member]	Limited Partners [Member]
Balance at Dec. 31, 2012	$ 13,296.0	$ (370.4)	$ 108.3	$ 13,558.1
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	1,901.4	0.0	3.4	1,898.0
Cash distributions paid to limited partners	(1,778.3)	0.0	0.0	(1,778.3)
Cash distributions paid to noncontrolling interests	(6.4)	0.0	(6.4)	0.0
Cash contributions from noncontrolling interests	104.2	0.0	104.2	0.0
Net cash proceeds from the issuance of common units	1,134.7	0.0	0.0	1,134.7
Amortization of fair value of equity-based awards	53.5	0.0	0.0	53.5
Cash flow hedges	20.7	20.7	0.0	0.0
Other	(43.6)	0.4	0.6	(44.6)
Balance at Sep. 30, 2013	14,682.2	(349.3)	210.1	14,821.4
Balance at Dec. 31, 2013	15,440.4	(359.0)	225.6	15,573.8
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	2,152.4	0.0	24.8	2,127.6
Cash distributions paid to limited partners	(1,948.2)	0.0	0.0	(1,948.2)
Cash payments made in connection with distribution equivalent rights	(2.4)	0.0	0.0	(2.4)
Cash distributions paid to noncontrolling interests	(29.4)	0.0	(29.4)	0.0
Cash contributions from noncontrolling interests	4.0	0.0	4.0	0.0
Net cash proceeds from the issuance of common units	304.9	0.0	0.0	304.9
Amortization of fair value of equity-based awards	61.6	0.0	0.0	61.6
Cash flow hedges	52.9	52.9	0.0	0.0
Other	(54.3)	0.0	(0.6)	(53.7)
Balance at Sep. 30, 2014	$ 15,981.9	$ (306.1)	$ 224.4	$ 16,063.6

Partnership Operations and Organization	9 Months Ended
Partnership Operations and Organization	Sep. 30, 2014
Partnership Operations and Organization [Abstract]
Partnership Operations and Organization	Note 1. Partnership Operations and Organization General We are a publicly traded Delaware limited partnership, the common units of which are listed on the New York Stock Exchange ("NYSE") under the ticker symbol "EPD." We were formed in April 1998 to own and operate certain natural gas liquids ("NGLs") related businesses of EPCO and are a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, petrochemicals and refined products. Our integrated midstream energy asset network links producers of natural gas, NGLs and crude oil from some of the largest supply basins in the United States ("U.S."), Canada and Gulf of Mexico with domestic consumers and international markets. Our midstream energy operations currently include: natural gas gathering, treating, processing, transportation and storage; NGL transportation, fractionation, storage, and import and export terminals (including liquefied petroleum gas or "LPG"); crude oil gathering, transportation, storage and terminals; offshore production platforms; petrochemical and refined products transportation, storage and terminals, and related services; and a marine transportation business that operates primarily on the U.S. inland and Intracoastal Waterway systems and in the Gulf of Mexico. Our assets include approximately 52,000 miles of onshore and offshore pipelines; 220 million barrels ("MMBbls") of storage capacity for NGLs, petrochemicals, refined products and crude oil; and 14 billion cubic feet ("Bcf") of natural gas storage capacity. In addition, our asset portfolio includes 24 natural gas processing plants, 22 NGL and propylene fractionators, six offshore hub platforms located in the Gulf of Mexico, a butane isomerization complex, NGL import and LPG export terminals, and octane enhancement and high-purity isobutylene production facilities. We have five reportable business segments: (i) NGL Pipelines & Services; (ii) Onshore Natural Gas Pipelines & Services; (iii) Onshore Crude Oil Pipelines & Services; (iv) Offshore Pipelines & Services; and (v) Petrochemical & Refined Products Services. We are 100% owned by our limited partners from an economic perspective. We are managed and controlled by Enterprise GP, which has a non-economic general partner interest in us. We, Enterprise GP, EPCO and Dan Duncan LLC are affiliates under the collective common control of the DD LLC Trustees and the EPCO Trustees. We have no employees. All of our operating functions and general and administrative support services are provided by employees of EPCO pursuant to an administrative services agreement (the "ASA") or by other service providers. See Note 12 for information regarding the ASA and other related party matters. On October 1, 2014, we announced our acquisition of the general partner and certain limited partner interests of Oiltanking Partners, L.P. See Note 18 for information regarding this subsequent event.

General Accounting Matters

9 Months Ended

Sep. 30, 2014

General Accounting Matters

Note 2. General Accounting Matters

Our results of operations for the three and nine months ended September 30, 2014 are not necessarily indicative of results expected for the full year of 2014. In our opinion, the accompanying Unaudited Condensed Consolidated Financial Statements include all adjustments consisting of normal recurring accruals necessary for fair presentation. Although we believe the disclosures in these financial statements are adequate and make the information presented not misleading, certain information and footnote disclosures normally included in annual financial statements prepared in accordance with U.S. generally accepted accounting principles ("GAAP") have been condensed or omitted pursuant to the rules and regulations of the U.S. Securities and Exchange Commission ("SEC").

These Unaudited Condensed Consolidated Financial Statements and Notes thereto should be read in conjunction with the Audited Consolidated Financial Statements and Notes thereto included in our annual report on Form 10-K for the year ended December 31, 2013 (the "2013 Form 10-K") filed with the SEC on March 3, 2014.

See Note 10 for information regarding a two-for-one common unit split completed on August 21, 2014. All per unit amounts and number of units outstanding in these Unaudited Condensed Consolidated Financial Statements and Notes thereto are presented on a post-split basis.

Contingencies

Certain conditions may exist as of the date our consolidated financial statements are issued, which may result in a loss to us but which will only be resolved when one or more future events occur or fail to occur. Management has regular quarterly litigation reviews, including updates from legal counsel, to assess the need for accounting recognition or disclosure of these contingencies, and such assessment inherently involves an exercise in judgment. In assessing loss contingencies related to legal proceedings that are pending against us or unasserted claims that may result in such proceedings, our management and legal counsel evaluate the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein.

We accrue an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when it is believed to be only reasonably possible or remote.

For contingencies where an unfavorable outcome is reasonably possible and the impact would be material, we disclose the nature of the contingency and, if feasible, an estimate of the possible loss or range of loss.

Loss contingencies considered remote are generally not disclosed unless they involve guarantees, in which case the guarantees would be disclosed. See Note 14 for additional information regarding our contingencies.

Derivative Instruments

We use derivative instruments such as futures, swaps, options, forward contracts and other arrangements to manage price risks associated with inventories, firm commitments, interest rates, foreign currencies and certain anticipated future commodity transactions. To qualify for hedge accounting, the hedged item must expose us to risk and the related derivative instrument must reduce the exposure to that risk and meet specific hedge documentation requirements related to designation dates, expectations for hedge effectiveness and the probability that hedged future transactions will occur as forecasted. We formally designate derivative instruments as hedges and document and assess their effectiveness at inception of the hedge and on a monthly basis thereafter. Forecasted transactions are evaluated for the probability of occurrence and are periodically back-tested once the forecasted period has passed to determine whether similarly forecasted transactions are probable of occurring in the future.

For certain physical forward commodity derivative contracts, we apply the normal purchase/normal sale exception, whereby changes in the mark-to-market values of such contracts are not recognized in income. As a result, the revenues and expenses associated with such physical transactions are recognized during the period when volumes are physically delivered or received. Physical forward commodity contracts subject to this exception are evaluated for the probability of future delivery and are periodically back-tested once the forecasted period has passed to determine whether similar forward contracts are probable of physical delivery in the future. See Note 4 for additional information regarding our derivative instruments.

Estimates

Preparing our consolidated financial statements in conformity with U.S. GAAP requires us to make estimates that affect amounts presented in the financial statements. Our most significant estimates relate to (i) the useful lives and depreciation/amortization methods used for fixed and identifiable intangible assets; (ii) measurement of fair value and projections used in impairment testing of fixed and intangible assets (including goodwill); (iii) contingencies; and (iv) revenue and expense accruals.

Actual results could differ materially from our estimates. On an ongoing basis, we review our estimates based on currently available information. Any changes in the facts and circumstances underlying our estimates may require us to update such estimates, which could have a material impact on our consolidated financial statements.

Recent Accounting Developments

In May 2014, the Financial Accounting Standards Board ("FASB") and the International Accounting Standards Board finished their joint project to converge U.S. GAAP and International Financial Reporting Standards in the area of revenue recognition. The resulting accounting standards update eliminates the transaction- and industry-specific revenue recognition guidance under current U.S. GAAP and replaces it with a principles based approach for determining revenue recognition.

The core principle in the new guidance is that a company should recognize revenue in a manner that depicts the transfer of goods or services to customers in an amount that reflects the consideration the company expects to receive for those goods or services. In order to apply this core principle, companies will apply the following five steps in determining the amount of revenues to recognize:



identify the contract;



identify the performance obligations in the contract;



determine the transaction price;



allocate the transaction price to the performance obligations in the contract; and



recognize revenue when (or as) the performance obligation is satisfied.

Each of these steps involves judgment and an analysis of the contract's terms and conditions.

We are continuing to evaluate this recently issued accounting guidance; therefore, we are currently not in a position to estimate its impact on our consolidated financial statements. The effective date of the new standard is January 1, 2017. At present, we expect to adopt the new standard using the modified retrospective method. This modified approach allows us to apply the new standard to (i) all new contracts after the effective date and (ii) all existing contracts as of the effective date through a cumulative adjustment to equity. Consolidated revenues for periods prior to the effective date would not be retrospectively adjusted.

Restricted Cash

Restricted cash represents amounts held in segregated bank accounts by our clearing brokers as margin in support of our commodity derivative instruments portfolio and related physical purchases and sales of natural gas, crude oil, refined products and NGLs. Additional cash may be restricted to maintain our commodity derivative instruments portfolio as prices fluctuate or deposit requirements change. At September 30, 2014 and December 31, 2013, our restricted cash amounts were $6.6 million and $65.6 million, respectively. See Note 4 for information regarding our derivative instruments and hedging activities.

Equity-based Awards

9 Months Ended

Sep. 30, 2014

Equity-based Awards [Abstract]

Equity-based Awards

Note 3. Equity-based Awards

An allocated portion of the fair value of EPCO's equity-based awards is charged to us under the ASA. The following table summarizes compensation expense we recognized in connection with equity-based awards for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Equity-classified awards:
Restricted common unit awards		$	8.7		$	17.8		$	29.3		$	52.7
Unit option awards			--			0.1			--			0.7
Phantom unit awards			12.9			--			32.3			--
Liability-classified awards			0.1			0.1			0.4			0.4
Total		$	21.7		$	18.0		$	62.0		$	53.8

The fair value of equity-classified awards is amortized into earnings over the requisite service or vesting period. Equity-classified awards are expected to result in the issuance of common units upon vesting. Compensation expense for liability-classified awards is recognized over the requisite service or vesting period based on the fair value of the award remeasured at each reporting date. Liability-classified awards are settled in cash upon vesting.

At September 30, 2014, EPCO's significant long-term incentive plans applicable to us were the Enterprise Products 1998 Long-Term Incentive Plan ("1998 Plan") and the 2008 Enterprise Products Long-Term Incentive Plan (Third Amendment and Restatement) ("2008 Plan"). Up to 14,000,000 of our common units may be issued as awards under the 1998 Plan. The maximum number of common units available for issuance under the 2008 Plan was 25,000,000 at September 30, 2014. This amount will automatically increase under the terms of the 2008 Plan by 5,000,000 common units on January 1, 2015 and will continue to automatically increase annually on January 1 thereafter during the term of the 2008 Plan; provided, however, that in no event shall the maximum aggregate number exceed 70,000,000 common units. After giving effect to awards granted under the 1998 Plan and 2008 Plan through September 30, 2014, a total of 2,704,337 and 12,782,238 additional common units could be issued under these plans, respectively.

Restricted Common Unit Awards

Restricted common unit awards allow recipients to acquire our common units (at no cost to the recipient apart from fulfilling service and other conditions) once a defined vesting period expires, subject to customary forfeiture provisions. Restricted common unit awards generally vest at a rate of 25% per year beginning one year after the grant date and are non-vested until the required service periods expire. Restricted common units are included in the number of common units outstanding as presented on our Unaudited Condensed Consolidated Balance Sheets.

The following table presents information regarding restricted common unit awards for the period indicated:

	Number of Units			Weighted- Average Grant Date Fair Value per Unit (1)
Restricted common units at December 31, 2013		7,221,214		$	25.83
Vested		(2,586,398	)	$	23.92
Forfeited		(267,200	)	$	26.36
Restricted common units at September 30, 2014		4,367,616		$	26.93

(1) Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.

Each recipient of a restricted common unit award is entitled to nonforfeitable cash distributions equal to the product of the number of restricted common units outstanding for the participant and the cash distribution per unit paid by Enterprise to its common unitholders. These distributions are included in "Cash distributions paid to limited partners" as presented on our Unaudited Condensed Statements of Consolidated Cash Flows.

The following table presents supplemental information regarding our restricted common unit awards for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Cash distributions paid to restricted common unitholders		$	1.6		$	2.6		$	5.7		$	8.2
Total intrinsic value of restricted common unit awards that vested during period		$	1.3		$	1.0		$	85.4		$	107.4

For the EPCO group of companies, the unrecognized compensation cost associated with restricted common unit awards was an aggregate $37.8 million at September 30, 2014, of which our allocated share of the cost is currently estimated to be $33.6 million. Due to the graded vesting provisions of these awards, we expect to recognize our share of the unrecognized compensation cost for these awards over a weighted-average period of 1.6 years.

Unit Option Awards

EPCO's long-term incentive plans provide for the issuance of non-qualified incentive options denominated in the common units of Enterprise Products Partners L.P. In general, unit option awards have a vesting period of four years from the date of grant and expire at the end of the calendar year following the year of vesting (e.g., an option vesting on May 29, 2013 will expire on December 31, 2014). However, unit option awards only become exercisable at certain times during the calendar year following the year in which they vest (typically the months of February, May, August and November).

The following table presents unit option award activity for the period indicated:

	Number of Units (2)			Weighted- Average Strike Price (dollars/unit)		Weighted- Average Remaining Contractual Term (in years)		Aggregate Intrinsic Value (1)
Unit option awards at December 31, 2013		4,050,000		$	13.24		1.3	$	57.0
Exercised		(2,720,000	)	$	11.83
Forfeited		(60,000	)	$	16.14
Unit option awards at September 30, 2014		1,270,000		$	16.14		1.3	$	30.7

(1) Aggregate intrinsic value reflects fully vested unit option awards at the dates indicated.
(2) None of the unit option awards outstanding at September 30, 2014 and December 31, 2013 were exercisable as of such dates, respectively.

In order to fund its unit option award-related obligations, EPCO may purchase common units at fair value either in the open market or directly from us. When employees exercise unit option awards, we reimburse EPCO for the cash difference between the strike price paid by the employee and the actual purchase price paid by EPCO for the units issued to the employee.

The following table presents supplemental information regarding unit option awards during the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Total intrinsic value of unit option awards exercised during period		$	--		$	--		$	57.5		$	19.8
Cash received from EPCO in connection with the exercise of unit option awards			--			--			33.4			11.5
Unit option award-related cash reimbursements to EPCO			--			--			57.5			19.8

As of September 30, 2014, all compensation expense related to unit option awards had been recognized.

Phantom Unit Awards

Phantom unit awards allow recipients to acquire our common units (at no cost to the recipient apart from fulfilling service and other conditions) once a defined vesting period expires, subject to customary forfeiture provisions. Phantom unit awards generally vest at a rate of 25% per year beginning one year after the grant date and are non-vested until the required service periods expire.

At September 30, 2014, substantially all of our phantom unit awards are expected to result in the issuance of common units upon vesting; therefore, the applicable awards are accounted for as equity-classified awards. Compensation expense attributable to these awards is based on the grant date fair value of the award, net of an allowance for estimated forfeitures, amortized over the requisite service or vesting period. The grant date fair value of a phantom unit award is based on the market price per unit of Enterprise's common units on the date of grant. These awards were first issued in February 2014.

The following table presents phantom unit award activity for the period indicated:

	Number of Units			Weighted- Average Grant Date Fair Value per Unit (1)
Phantom unit awards at December 31, 2013		--		$	--
Granted (2)		3,522,990		$	33.12
Vested		(34,800	)	$	33.04
Forfeited		(92,800	)	$	33.04
Phantom unit awards at September 30, 2014		3,395,390		$	33.12

(1) Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.
(2) The aggregate grant date fair value of phantom unit awards issued during 2014 was $116.7 million based on a grant date market price of our common units ranging from $33.04 to $37.59 per unit. An estimated annual forfeiture rate of 3.4% was applied to these awards.

Our long-term incentive plans provide for the issuance of distribution equivalent rights ("DERs") in connection with phantom unit awards. A DER entitles the participant to nonforfeitable cash payments equal to the product of the number of phantom unit awards outstanding for the participant and the cash distribution per common unit paid by Enterprise to its common unitholders. Cash payments made in connection with DERs are charged to partners' equity when the phantom unit award is expected to result in the issuance of common units; otherwise, such amounts are expensed.

The following table presents supplemental information regarding our phantom unit awards and DERs for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Cash payments made in connection with DERs		$	1.2		$	--		$	2.4		$	--
Total intrinsic value of phantom unit awards that vested during period		$	0.1		$	--		$	1.3		$	--

For the EPCO group of companies, the unrecognized compensation cost associated with phantom unit awards was $72.2 million at September 30, 2014, of which our allocated share of the cost is currently estimated to be $66.1 million. Due to the graded vesting provisions of these awards, we expect to recognize our share of the unrecognized compensation cost for these awards over a weighted-average period of 2.2 years.

Derivative Instruments, Hedging Activities and Fair Value Measurements

9 Months Ended

Sep. 30, 2014

Derivative Instruments, Hedging Activities and Fair Value Measurements [Abstract]

Derivative Instruments, Hedging Activities and Fair Value Measurements

Note 4. Derivative Instruments, Hedging Activities and Fair Value Measurements

In the normal course of our business operations, we are exposed to certain risks, including changes in interest rates and commodity prices. In order to manage risks associated with assets, liabilities and certain anticipated future transactions, we use derivative instruments such as futures, forward contracts, swaps, options and other instruments with similar characteristics. Substantially all of our derivatives are used for non-trading activities.

Interest Rate Hedging Activities

We may utilize interest rate swaps, forward starting swaps and similar derivative instruments to manage our exposure to changes in interest rates charged on borrowings under certain consolidated debt agreements. The following table summarizes our portfolio of interest rate swaps at September 30, 2014:

Hedged Transaction	Number and Type of Derivatives Outstanding	Notional Amount				Period of Hedge	Rate Swap	Accounting Treatment
Senior Notes AA	10 fixed-to-floating swaps		$	750.0		1/2011 to 2/2016	3.2% to 1.2%	Fair value hedge

As a result of market conditions in early October 2014, we elected to terminate all of our outstanding interest rate swaps. We terminated 10 fixed-to-floating swaps that were outstanding at September 30, 2014 having an aggregate notional value of $750 million, which resulted in cash gains totaling $17.6 million. In addition, we terminated 16 fixed-to-floating swaps having a notional value of $800 million entered into in connection with the issuance of Senior Notes LL in October 2014 (see Note 18). The early termination of these 16 swaps resulted in cash gains totaling $10.0 million. Since both groups of swaps were accounted for as fair value hedges, the aggregate $27.6 million of gains will be carried as a component of long-term debt and amortized into earnings (as a decrease in interest expense) using the effective interest method over the remaining life of the associated debt obligations. The $17.6 million gain will be amortized through January 2016 and the $10.0 million gain will be amortized through October 2019.

In July 2014, six undesignated floating-to-fixed swaps having an aggregate notional amount of $600.0 million expired. These swaps were accounted for as mark-to-market instruments with changes in fair value recorded in "Interest expense" on our Unaudited Condensed Statements of Consolidated Operations.

In connection with the issuance of Senior Notes II and HH in March 2013, we terminated 16 forward starting swaps having an aggregate notional amount of $1.0 billion, which resulted in cash losses totaling $168.8 million. As cash flow hedges, losses on these derivative instruments are a component of accumulated other comprehensive loss and are being amortized into earnings (as an increase in interest expense) over the remaining life of the associated debt obligations using the effective interest method. The $168.8 million loss will be amortized through March 2023.

Commodity Hedging Activities

The prices of natural gas, NGLs, crude oil, refined products and petrochemical products are subject to fluctuations in response to changes in supply and demand, market conditions and a variety of additional factors that are beyond our control. In order to manage such price risks, we enter into commodity derivative instruments such as physical forward contracts, futures contracts, fixed-for-float swaps, basis swaps and option contracts. The following table summarizes our portfolio of commodity derivative instruments outstanding at September 30, 2014 (volume measures as noted):

	Volume (1)		Accounting
Derivative Purpose	Current (2)	Long-Term (2)	Treatment
Derivatives designated as hedging instruments:
Natural gas processing:
Forecasted natural gas purchases for plant thermal reduction (Bcf)	1.1	n/a	Cash flow hedge
Forecasted sales of NGLs (MMBbls) (3)	0.3	n/a	Cash flow hedge
Octane enhancement:
Forecasted purchases of NGLs (MMBbls)	0.3	n/a	Cash flow hedge
Forecasted sales of octane enhancement products (MMBbls)	0.2	n/a	Cash flow hedge
Natural gas marketing:
Forecasted sales of natural gas (Bcf)	1.7	n/a	Cash flow hedge
Natural gas storage inventory management activities (Bcf)	5.1	n/a	Fair value hedge
NGL marketing:
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)	5.2	0.1	Cash flow hedge
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)	8.8	n/a	Cash flow hedge
Refined products marketing:
Forecasted purchases of refined products (MMBbls)	0.7	n/a	Cash flow hedge
Forecasted sales of refined products (MMBbls)	1.3	n/a	Cash flow hedge
Crude oil marketing:
Forecasted purchases of crude oil (MMBbls)	5.0	0.5	Cash flow hedge
Forecasted sales of crude oil (MMBbls)	7.0	0.5	Cash flow hedge
Derivatives not designated as hedging instruments:
Natural gas risk management activities (Bcf) (4,5)	63.5	15.3	Mark-to-market
Crude oil risk management activities (MMBbls) (5)	6.7	n/a	Mark-to-market

(1) Volume for derivatives designated as hedging instruments reflects the total amount of volumes hedged whereas volume for derivatives not designated as hedging instruments reflects the absolute value of derivative notional volumes.
(2) The maximum term for derivatives designated as cash flow hedges, derivatives designated as fair value hedges and derivatives not designated as hedging instruments is December 2015, October 2015 and March 2018, respectively.
(3) Forecasted sales of NGL volumes under natural gas processing exclude 0.3 MMBbls of additional hedges executed under contracts that have been designated as normal sales agreements.
(4) Current and long-term volumes include 28.9 Bcf and 0.9 Bcf, respectively, of physical derivative instruments that are predominantly priced at a marked-based index plus a premium or minus a discount related to location differences.
(5) Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.

At September 30, 2014, our predominant commodity hedging strategies consisted of (i) hedging anticipated future purchases and sales of commodity products associated with transportation, storage and blending activities, (ii) hedging the fair value of commodity products held in inventory, (iii) hedging natural gas processing margins, and (iv) hedging octane enhancement margins.

Tabular Presentation of Fair Value Amounts, and Gains and Losses on

Derivative Instruments and Related Hedged Items

The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated:

	Asset Derivatives						Liability Derivatives
	September 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
	Balance Sheet Location	Fair Value		Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
Derivatives designated as hedging instruments
Interest rate derivatives	Other current assets	$	15.9	Other current assets	$	20.2	Other current liabilities	$	--	Other current liabilities	$	--
Interest rate derivatives	Other assets		3.5	Other assets		12.4	Other liabilities		--	Other liabilities		--
Total interest rate derivatives			19.4			32.6			--			--
Commodity derivatives	Other current assets		38.1	Other current assets		30.9	Other current liabilities		19.5	Other current liabilities		46.5
Commodity derivatives	Other assets		1.2	Other assets		--	Other liabilities		1.4	Other liabilities		0.3
Total commodity derivatives			39.3			30.9			20.9			46.8
Total derivatives designated as hedging instruments		$	58.7		$	63.5		$	20.9		$	46.8

Derivatives not designated as hedging instruments
Interest rate derivatives	Other current assets	$	--	Other current assets	$	--	Other current liabilities	$	--	Other current liabilities	$	7.8
Interest rate derivatives	Other assets		--	Other assets		--	Other liabilities		--	Other liabilities		--
Total interest rate derivatives			--			--			--			7.8
Commodity derivatives	Other current assets		1.4	Other current assets		7.6	Other current liabilities		0.8	Other current liabilities		5.5
Commodity derivatives	Other assets		1.0	Other assets		2.8	Other liabilities		0.3	Other liabilities		2.8
Total commodity derivatives			2.4			10.4			1.1			8.3
Total derivatives not designated as hedging instruments		$	2.4		$	10.4		$	1.1		$	16.1

Certain of our commodity derivative instruments are subject to master netting arrangements or similar agreements. The following tables present our derivative instruments subject to such arrangements at the dates indicated:

	Offsetting of Financial Assets and Derivative Assets
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received				Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of September 30, 2014:
Interest rate derivatives		$	19.4		$	--		$	19.4		$	--			$	--			$	19.4
Commodity derivatives			41.7			--			41.7			(24.8	)			(16.9	)			--
As of December 31, 2013:
Interest rate derivatives		$	32.6		$	--		$	32.6		$	(2.6	)		$	--			$	30.0
Commodity derivatives			41.3			--			41.3			(41.0	)			--				0.3

	Offsetting of Financial Liabilities and Derivative Liabilities
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Financial Instruments				Cash Collateral Paid				Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of September 30, 2014:
Interest rate derivatives		$	--		$	--		$	--		$	--			$	--			$	--
Commodity derivatives			22.0			--			22.0			(24.8	)			7.8				5.0
As of December 31, 2013:
Interest rate derivatives		$	7.8		$	--		$	7.8		$	(2.6	)		$	--			$	5.2
Commodity derivatives			55.1			--			55.1			(41.0	)			(9.3	)			4.8

Derivative assets and liabilities recorded on our Unaudited Condensed Consolidated Balance Sheets are presented on a gross-basis and determined at the individual transaction level. The tabular presentation above provides a means for comparing the gross amount of derivative assets and liabilities, excluding associated accounts payable and receivable, to the net amount that would likely be receivable or payable under a default scenario based on the existence of rights of offset in the respective derivative agreements. Any cash collateral paid or received is reflected in this table, but only to the extent that it represents variation margins. Any amounts associated with derivative prepayments or initial margins that are not influenced by the derivative asset or liability amounts or those that are determined solely on their volumetric notional amounts are excluded from this table.

The following tables present the effect of our derivative instruments designated as fair value hedges on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended September 30,								For the Nine Months Ended September 30,
		2014				2013				2014				2013
Interest rate derivatives	Interest expense		$	(4.1	)		$	(0.5	)		$	(9.5	)		$	(10.6	)
Commodity derivatives	Revenue			(0.3	)			(3.1	)			0.6				3.1
Total			$	(4.4	)		$	(3.6	)		$	(8.9	)		$	(7.5	)

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Hedged Item
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014			2013				2014				2013
Interest rate derivatives	Interest expense		$	3.9		$	0.4			$	9.3			$	10.3
Commodity derivatives	Revenue			1.0			(0.4	)			(1.4	)			(12.0	)
Total			$	4.9		$	--			$	7.9			$	(1.7	)

With respect to our derivative instruments designated as fair value hedges, amounts attributable to ineffectiveness and those excluded from the assessment of hedge effectiveness were not material to our Unaudited Condensed Consolidated Financial Statements during the periods presented.

The following tables present the effect of our derivative instruments designated as cash flow hedges on our Unaudited Condensed Statements of Consolidated Operations and Unaudited Condensed Statements of Consolidated Comprehensive Income for the periods indicated:

Derivatives in Cash Flow Hedging Relationships	Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)
	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014		2013
Interest rate derivatives	$	--		$	--		$	--	$	6.7
Commodity derivatives – Revenue (1)		58.8			(8.6	)		15.2		(22.1	)
Commodity derivatives – Operating costs and expenses (1)		(0.7	)		--			0.9		--
Total	$	58.1		$	(8.6	)	$	16.1	$	(15.4	)

(1) The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)
		For the Three Months Ended September 30,								For the Nine Months Ended September 30,
		2014				2013				2014				2013
Interest rate derivatives	Interest expense		$	(8.0	)		$	(7.7	)		$	(23.9	)		$	(21.4	)
Commodity derivatives	Revenue			17.8				(14.6	)			(14.5	)			(15.1	)
Commodity derivatives	Operating costs and expenses			0.2				--				1.6				0.4
Total			$	10.0			$	(22.3	)		$	(36.8	)		$	(36.1	)

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014				2013			2014			2013
Commodity derivatives	Revenue		$	0.1			$	0.1		$	--		$	--
Commodity derivatives	Operating costs and expenses			(0.1	)			--			--			--
Total			$	--			$	0.1		$	--		$	--

Over the next twelve months, we expect to reclassify $34.8 million of losses attributable to interest rate derivative instruments from accumulated other comprehensive loss to earnings as an increase in interest expense. Likewise, we expect to reclassify $14.5 million of net gains attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, $14.3 million as an increase in revenue and $0.2 million as a decrease in operating costs and expenses.

The following table presents the effect of our derivative instruments not designated as hedging instruments on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:

Derivatives Not Designated as Hedging Instruments	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014			2013				2014				2013
Interest rate derivatives	Interest expense		$	--		$	(0.5	)		$	(0.1	)		$	(0.6	)
Commodity derivatives	Revenue			0.8			8.1				(26.8	)			17.0
Total			$	0.8		$	7.6			$	(26.9	)		$	16.4

Fair Value Measurements

Our fair value estimates are based on either (i) actual market data or (ii) assumptions that other market participants would use in pricing an asset or liability, including estimates of risk, in the principal market of the asset or liability at a specified measurement date. Recognized valuation techniques employ inputs such as contractual prices, quoted market prices or rates, operating costs, discount factors and business growth rates. These inputs may be either readily observable, corroborated by market data or generally unobservable. In developing our estimates of fair value, we endeavor to utilize the best information available and apply market-based data to the highest extent possible. Accordingly, we utilize valuation techniques (such as the market approach) that maximize the use of observable inputs and minimize the use of unobservable inputs.

A three-tier hierarchy has been established that classifies fair value amounts recognized in the financial statements based on the observability of inputs used to estimate such fair values. The hierarchy considers fair value amounts based on observable inputs (Levels 1 and 2) to be more reliable and predictable than those based primarily on unobservable inputs (Level 3). At each balance sheet reporting date, we categorize our financial assets and liabilities using this hierarchy.

Recurring Fair Value Measurements

The following tables set forth, by level within the fair value hierarchy, the carrying values of our financial assets and liabilities at September 30, 2014 and December 31, 2013. These assets and liabilities are measured on a recurring basis and are classified based on the lowest level of input used to estimate their fair value. Our assessment of the relative significance of such inputs requires judgment.

	September 30, 2014 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	19.4	$	--	$	19.4
Commodity derivatives		14.4		24.4		2.9		41.7
Total	$	14.4	$	43.8	$	2.9	$	61.1

Financial liabilities:
Interest rate derivatives	$	--	$	--	$	--	$	--
Commodity derivatives		8.2		10.2		3.6		22.0
Total	$	8.2	$	10.2	$	3.6	$	22.0

	December 31, 2013 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	32.6	$	--	$	32.6
Commodity derivatives		17.2		20.2		3.9		41.3
Total	$	17.2	$	52.8	$	3.9	$	73.9

Financial liabilities:
Interest rate derivatives	$	--	$	7.8	$	--	$	7.8
Commodity derivatives		30.8		23.6		0.7		55.1
Total	$	30.8	$	31.4	$	0.7	$	62.9

The following table sets forth a reconciliation of changes in the fair values of our recurring Level 3 financial assets and liabilities on a combined basis for the periods indicated:

		For the Nine Months Ended September 30,
	Location	2014			2013
Financial asset (liability) balance, net, January 1		$	3.2		$	(1.5	)
Total gains (losses) included in:
Net income (1)	Revenue		4.6			(0.6	)
Settlements	Revenue		(0.1	)		1.5
Financial asset (liability) balance, net, March 31			7.7			(0.6	)
Total gains (losses) included in:
Net income (1)	Revenue		(3.3	)		(0.2	)
Settlements	Revenue		(1.8	)		0.6
Financial asset (liability) balance, net, June 30			2.6			(0.2	)
Total gains (losses) included in:
Net income (1)	Revenue		(0.9	)		1.1
Other comprehensive income	Commodity derivative instruments – changes in fair value of cash flow hedges		(2.5	)		(0.9	)
Settlements	Revenue		0.1			0.1
Financial asset (liability) balance, net, September 30 (2)		$	(0.7	)	$	0.1

(1) There were $0.8 million and $1.3 million of unrealized losses included in these amounts for the three and nine months ended September 30, 2014, respectively. There were unrealized gains of $1.1 million and $2.4 million included in these amounts for the three and nine months ended September 30, 2013, respectively.
(2) There were no transfers into or out of Level 3 during the three or nine months ended September 30, 2014 and 2013.

The following table provides quantitative information about our recurring Level 3 fair value measurements at September 30, 2014:

	Fair Value
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	2.6	$	0.9	Discounted cash flow	Forward commodity prices	$70.32-$91.82/barrel
Commodity derivatives – Propane		--		0.1	Discounted cash flow	Forward commodity prices	$1.02-$1.05/gallon
Commodity derivatives – Natural gasoline		0.1		2.5	Discounted cash flow	Forward commodity prices	$1.84-$1.94/gallon
Commodity derivatives – Natural gas		0.2		0.1	Discounted cash flow	Forward commodity prices	$3.72-$4.54/MMBtu
Total	$	2.9	$	3.6

We believe forward commodity prices are the most significant unobservable inputs in determining our Level 3 recurring fair value measurements at September 30, 2014. In general, changes in the price of the underlying commodity increases or decreases the fair value of a commodity derivative depending on whether the derivative was purchased or sold. We generally expect changes in the fair value of our derivative instruments to be offset by corresponding changes in the fair value of our hedged exposures.

Nonrecurring Fair Value Measurements

The following table summarizes our non-cash impairment charges by segment during each of the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	1.2	$	0.3	$	6.6	$	10.0
Onshore Natural Gas Pipelines & Services		0.4		--		0.7		--
Onshore Crude Oil Pipelines & Services		0.4		--		2.2		16.6
Offshore Pipelines & Services		--		13.2		--		13.2
Petrochemical & Refined Products Services		3.7		1.7		8.7		13.5
Total	$	5.7	$	15.2	$	18.2	$	53.3

These impairment charges are a component of "Operating costs and expenses" on our Unaudited Condensed Statements of Consolidated Operations.

Our non-cash asset impairment charges for the nine months ended September 30, 2014 primarily relate to the abandonment of assets classified as property, plant and equipment. The following table summarizes our non-recurring fair value measurements for the nine months ended September 30, 2014:

				Fair Value Measurements Using
	Carrying Value at September 30, 2014			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Non-Cash Impairment Loss
Impairment of long-lived assets disposed of other than by sale		$	--		$	--		$	--		$	--		$	11.7
Impairment of long-lived assets to be disposed of by sale			1.1			--			--			1.1			6.5
Total														$	18.2

During the nine months ended September 30, 2013, we recorded $53.3 million of non-cash asset impairment charges. These charges primarily represent the abandonment of crude oil and natural gas pipeline segments in Texas, Oklahoma and the Gulf of Mexico, certain refined products terminal assets in Texas, and an NGL storage cavern in Arizona. The following table summarizes our non-recurring fair value measurements for the nine months ended September 30, 2013:

			Fair Value Measurements Using
	Carrying Value at September 30, 2013		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Non-Cash Impairment Loss
Impairment of long-lived assets disposed of other than by sale	$	--	$	--	$	--	$	--	$	43.3
Impairment of long-lived assets held and used		6.1		--		--		6.1		4.2
Impairment of long-lived assets to be disposed of by sale		11.7		11.7		--		--		5.8
Total									$	53.3

Other Fair Value Information

The carrying amounts of cash and cash equivalents (including restricted cash balances), accounts receivable, commercial paper notes and accounts payable approximate their fair values based on their short-term nature. The estimated total fair value of our fixed-rate debt obligations was $20.1 billion and $17.93 billion at September 30, 2014 and December 31, 2013, respectively. The aggregate carrying value of these debt obligations was $18.38 billion and $16.88 billion at September 30, 2014 and December 31, 2013, respectively. These values are based on quoted market prices for such debt or debt of similar terms and maturities (Level 2), our credit standing and the credit standing of our counterparties. Changes in market rates of interest affect the fair value of our fixed-rate debt. The carrying values of our variable-rate long-term debt obligations approximate their fair values since the associated interest rates are market-based. We do not have any long-term investments in debt or equity securities recorded at fair value.

Inventories

9 Months Ended

Sep. 30, 2014

Inventories [Abstract]

Property, Plant and Equipment [Abstract]

Note 5. Inventories

Our inventory amounts by product type were as follows at the dates indicated:

	September 30, 2014		December 31, 2013
NGLs	$	973.4	$	593.8
Petrochemicals and refined products		338.7		395.1
Crude oil		238.8		42.6
Natural gas		38.6		61.6
Total	$	1,589.5	$	1,093.1

Due to fluctuating commodity prices, we recognize lower of cost or market adjustments when the carrying value of our available-for-sale inventories exceeds their net realizable value. The following table presents our total cost of sales amounts and lower of cost or market adjustments for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
Cost of sales (1)	$	10,455.1	$	10,371.3	$	32,213.1	$	29,522.1
Lower of cost or market adjustments		6.7		4.5		14.6		14.9

(1) Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. Period-to-period fluctuations in these amounts are primarily due to changes in energy commodity prices and sales volumes associated with our marketing activities.

Property, Plant and Equipment

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment

Note 6. Property, Plant and Equipment

The historical costs of our property, plant and equipment and related accumulated depreciation balances were as follows at the dates indicated:

	Estimated Useful Life in Years	September 30, 2014		December 31, 2013
Plants, pipelines and facilities (1)	3-45 (6)	$	30,096.7	$	27,540.4
Underground and other storage facilities (2)	5-40 (7)		2,164.9		2,101.8
Platforms and facilities (3)	20-31		659.7		659.6
Transportation equipment (4)	3-10		142.0		138.9
Marine vessels (5)	15-30		782.3		744.8
Land			185.0		176.6
Construction in progress			1,805.7		2,655.5
Total			35,836.3		34,017.6
Less accumulated depreciation			7,873.0		7,071.0
Property, plant and equipment, net		$	27,963.3	$	26,946.6

(1) Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; office furniture and equipment; buildings; laboratory and shop equipment and related assets.
(2) Underground and other storage facilities include underground product storage caverns; above ground storage tanks; water wells and related assets.
(3) Platforms and facilities include offshore platforms and related facilities and other associated assets located in the Gulf of Mexico.
(4) Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations.
(5) Marine vessels include tow boats, barges and related equipment used in our marine transportation business.
(6) In general, the estimated useful lives of major assets within this category are: processing plants, 20-35 years; pipelines and related equipment, 5-45 years; terminal facilities, 10-35 years; office furniture and equipment, 3-20 years; buildings, 20-40 years; and laboratory and shop equipment, 5-35 years.
(7) In general, the estimated useful lives of assets within this category are: underground storage facilities, 5-35 years; storage tanks, 10-40 years; and water wells, 5-35 years.

The following table summarizes our depreciation expense and capitalized interest amounts for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
Depreciation expense (1)	$	283.2	$	253.4	$	822.1	$	749.6
Capitalized interest (2)		17.2		27.8		53.4		95.1

(1) Depreciation expense is a component of "Costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations.
(2) We capitalize interest costs incurred on funds used to construct property, plant and equipment while the asset is in its construction phase. The capitalized interest is recorded as part of the asset to which it relates and is amortized over the asset's estimated useful life as a component of depreciation expense. When capitalized interest is recorded, it reduces interest expense from what it would be otherwise.

In March 2013, we sold the Stratton Ridge-to-Mont Belvieu segment of the Seminole Pipeline, along with a related storage cavern, for cash proceeds of $86.9 million. As a result, net income for the nine months ended September 30, 2013 includes a $52.5 million gain attributable to the sale of these assets. The Seminole Pipeline remains connected to our Mont Belvieu complex through a newly constructed NGL pipeline that we own.

In April 2013, we sold certain lubrication oil and specialty chemical distribution assets for cash proceeds of $35.3 million. As a result, net income for the nine months ended September 30, 2013 includes a $6.7 million gain from the sale of these assets.

Asset Retirement Obligations

Property, plant and equipment at September 30, 2014 and December 31, 2013 includes $31.8 million and $37.4 million, respectively, of asset retirement costs capitalized as an increase in the associated long-lived asset.

The following table presents information regarding our asset retirement obligations ("AROs") during the nine months ended September 30, 2014:

ARO liability balance, December 31, 2013	$	90.2
Liabilities incurred		0.1
Liabilities settled		(2.3	)
Revisions in estimated cash flows		2.7
Accretion expense		4.5
ARO liability balance, September 30, 2014	$	95.2

The following table presents our forecast of accretion expense for the periods indicated:

Remainder of 2014				2015				2016				2017				2018
	$	1.6			$	6.3			$	6.5			$	7.0			$	7.5

Certain of our unconsolidated affiliates have AROs recorded at September 30, 2014 and December 31, 2013 relating to contractual agreements and regulatory requirements. These amounts are immaterial to our consolidated financial statements.

Investments in Unconsolidated Affiliates

9 Months Ended

Sep. 30, 2014

Investments in Unconsolidated Affiliates [Abstract]

Investments in Unconsolidated Affiliates

Note 7. Investments in Unconsolidated Affiliates

The following table presents our investments in unconsolidated affiliates by business segment at the dates indicated. We account for these investments using the equity method.

	Ownership Interest at September 30, 2014	September 30, 2014		December 31, 2013
NGL Pipelines & Services:
Venice Energy Service Company, L.L.C.	13.1%	$	26.9	$	27.6
K/D/S Promix, L.L.C.	50%		46.1		45.4
Baton Rouge Fractionators LLC	32.2%		19.1		19.5
Skelly-Belvieu Pipeline Company, L.L.C.	50%		39.7		40.8
Texas Express Pipeline LLC	35%		348.4		339.9
Texas Express Gathering LLC	45%		37.8		37.8
Front Range Pipeline LLC	33.3%		167.8		134.5
Onshore Natural Gas Pipelines & Services:
White River Hub, LLC	50%		23.5		24.2
Onshore Crude Oil Pipelines & Services:
Seaway Crude Pipeline Company LLC	50%		1,372.2		940.7
Eagle Ford Pipeline LLC	50%		279.5		224.5
Offshore Pipelines & Services:
Poseidon Oil Pipeline Company, L.L.C. ("Poseidon")	36%		34.3		41.7
Cameron Highway Oil Pipeline Company	50%		204.2		207.7
Deepwater Gateway, L.L.C.	50%		81.1		84.5
Neptune Pipeline Company, L.L.C.	25.7%		35.4		38.7
Southeast Keathley Canyon Pipeline Company L.L.C.	50%		147.4		159.2
Petrochemical & Refined Products Services:
Baton Rouge Propylene Concentrator, LLC	30%		6.7		7.6
Centennial Pipeline LLC ("Centennial")	50%		65.6		60.1
Other	Various		2.6		2.7
Total		$	2,938.3	$	2,437.1

The following table presents our equity in income (loss) of unconsolidated affiliates by business segment for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
NGL Pipelines & Services	$	11.7		$	4.1		$	19.2		$	11.8
Onshore Natural Gas Pipelines & Services		0.9			1.0			2.7			2.9
Onshore Crude Oil Pipelines & Services		46.8			34.3			131.7			101.0
Offshore Pipelines & Services		17.1			9.8			35.8			24.9
Petrochemical & Refined Products Services		(4.2	)		(5.2	)		(10.3	)		(14.5	)
Total	$	72.3		$	44.0		$	179.1		$	126.1

The following table presents our unamortized excess cost amounts by business segment at the dates indicated:

	September 30, 2014		December 31, 2013
NGL Pipelines & Services	$	26.8	$	27.7
Onshore Crude Oil Pipelines & Services		17.3		17.8
Offshore Pipelines & Services		9.2		10.0
Petrochemical & Refined Products Services		2.5		2.6
Total	$	55.8	$	58.1

The following table presents our amortization of excess cost amounts by business segment for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	0.2	$	0.3	$	0.9	$	0.9
Onshore Crude Oil Pipelines & Services		0.2		0.1		0.5		0.5
Offshore Pipelines & Services		0.3		0.3		0.8		1.0
Petrochemical & Refined Products Services		--		0.1		0.1		0.1
Total	$	0.7	$	0.8	$	2.3	$	2.5

Other

The credit agreements of Poseidon and Centennial restrict their ability to pay cash dividends if a default or event of default (as defined in each credit agreement) has occurred and is continuing at the time such payments are scheduled to be paid. These businesses were in compliance with the terms of their credit agreements at September 30, 2014.

Intangible Assets and Goodwill

9 Months Ended

Sep. 30, 2014

Intangible Assets and Goodwill [Abstract]

Intangible Assets and Goodwill

Note 8. Intangible Assets and Goodwill

The following table summarizes our intangible assets by business segment at the dates indicated:

	September 30, 2014							December 31, 2013
	Gross Value		Accumulated Amortization			Carrying Value		Gross Value		Accumulated Amortization			Carrying Value
NGL Pipelines & Services:
Customer relationship intangibles	$	340.8	$	(179.0	)	$	161.8	$	340.8	$	(165.7	)	$	175.1
Contract-based intangibles		277.9		(175.1	)		102.8		281.3		(171.2	)		110.1
Segment total		618.7		(354.1	)		264.6		622.1		(336.9	)		285.2
Onshore Natural Gas Pipelines & Services:
Customer relationship intangibles		1,163.6		(302.3	)		861.3		1,163.6		(281.2	)		882.4
Contract-based intangibles		466.0		(343.7	)		122.3		466.1		(330.7	)		135.4
Segment total		1,629.6		(646.0	)		983.6		1,629.7		(611.9	)		1,017.8
Onshore Crude Oil Pipelines & Services:
Customer relationship intangibles		9.6		(6.1	)		3.5		10.7		(6.3	)		4.4
Contract-based intangibles		0.4		(0.3	)		0.1		0.4		(0.3	)		0.1
Segment total		10.0		(6.4	)		3.6		11.1		(6.6	)		4.5
Offshore Pipelines & Services:
Customer relationship intangibles		195.8		(152.6	)		43.2		203.9		(150.0	)		53.9
Contract-based intangibles		1.2		(0.5	)		0.7		1.2		(0.4	)		0.8
Segment total		197.0		(153.1	)		43.9		205.1		(150.4	)		54.7
Petrochemical & Refined Products Services:
Customer relationship intangibles		104.3		(42.1	)		62.2		104.3		(38.2	)		66.1
Contract-based intangibles		39.9		(6.7	)		33.2		39.9		(6.0	)		33.9
Segment total		144.2		(48.8	)		95.4		144.2		(44.2	)		100.0
Total all segments	$	2,599.5	$	(1,208.4	)	$	1,391.1	$	2,612.2	$	(1,150.0	)	$	1,462.2

The following table presents the amortization expense of our intangible assets by business segment for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	8.1	$	8.6	$	25.4	$	27.7
Onshore Natural Gas Pipelines & Services		11.1		13.3		34.2		38.0
Onshore Crude Oil Pipelines & Services		0.3		0.3		0.9		1.0
Offshore Pipelines & Services		2.5		2.9		7.6		8.8
Petrochemical & Refined Products Services		1.5		1.5		4.6		4.7
Total	$	23.5	$	26.6	$	72.7	$	80.2

The following table presents our forecast of amortization expense associated with existing intangible assets for the periods indicated:

Remainder of 2014				2015				2016				2017				2018
	$	22.2			$	86.0			$	81.6			$	86.1			$	89.5

Goodwill

Goodwill represents the excess of the purchase price of an acquired business over the amounts assigned to assets acquired and liabilities assumed in the transaction. The following table presents changes in the carrying amount of goodwill during the nine months ended September 30, 2014:

	NGL Pipelines & Services		Onshore Natural Gas Pipelines & Services		Onshore Crude Oil Pipelines & Services		Offshore Pipelines & Services			Petrochemical & Refined Products Services			Consolidated Total
Balance at December 31, 2013 (1)	$	341.2	$	296.3	$	305.1	$	82.1		$	1,055.3		$	2,080.0
Reclassification of goodwill		520.0		--		--		--			(520.0	)		--
Goodwill related to the sale of assets		--		--		--		(0.1	)		--			(0.1	)
Balance at September 30, 2014 (1)	$	861.2	$	296.3	$	305.1	$	82.0		$	535.3		$	2,079.9

(1) The total carrying amount of goodwill at September 30, 2014 and December 31, 2013 is net of $1.3 million of accumulated impairment charges. No goodwill impairment charges were recorded during the nine months ended September 30, 2014.

In January 2014, our Appalachia-to-Texas Express ("ATEX") ethane pipeline commenced operations. In addition to the construction of new assets, this project involved repurposing portions of the TE Products Pipeline to accommodate the southbound delivery of ethane produced from the Marcellus and Utica Shales to the U.S. Gulf Coast. The repurposed assets were reclassified from the Petrochemical & Refined Products Services business segment to the NGL Pipelines & Services business segment in January 2014 when the ATEX pipeline commenced operations. Pipeline assets that continue to be utilized by the TE Products Pipeline in the northbound delivery of refined products and other hydrocarbons from the U.S. Gulf Coast remain in the Petrochemical & Refined Products Services business segment.

In total, the carrying value of the fixed assets at January 1, 2014 that were transferred from the TE Products Pipeline to the ATEX pipeline was $73.7 million. Based on the relative fair values of the assets involved, we also transferred $520.0 million of goodwill from the Petrochemical & Refined Products Services business segment to the NGL Pipelines & Services business segment. The relative fair values of the segment assets were determined based on assumptions regarding the future economic prospects of the ATEX pipeline versus the other assets that would remain in the associated reporting unit. These assumptions included: (i) discrete financial forecasts for the pipelines and related businesses contained within the reporting unit, which, in turn, relied on management's estimates of future operating margins, throughput volumes and similar factors; (ii) long-term growth rates for cash flows beyond the discrete forecast period; and (iii) appropriate discount rates. We believe our assumptions are consistent with those that market participants would utilize in estimating the reporting unit's fair value.

The entire disclosure for the aggregate amount of goodwill and a description of intangible assets, which may include (a) for amortizable intangible assets (also referred to as finite-lived intangible assets), the carrying amount, the amount of any significant residual value, and the weighted-average amortization period, (b) for intangible assets not subject to amortization (also referred to as indefinite-lived intangible assets), the carrying amount, and (c) the amount of research and development assets acquired and written off in the period, including the line item in the income statement in which the amounts written off are aggregated, if not readily apparent from the income statement. Also discloses (a) for amortizable intangibles assets in total and by major class, the gross carrying amount and accumulated amortization, the total amortization expense for the period, and the estimated aggregate amortization expense for each of the five succeeding fiscal years, (b) for intangible assets not subject to amortization the carrying amount in total and by major class, and (c) for goodwill, in total and for each reportable segment, the changes in the carrying amount of goodwill during the period (including the aggregate amount of goodwill acquired, the aggregate amount of impairment losses recognized, and the amount of goodwill included in the gain (loss) on disposal of a reporting unit). If any part of goodwill has not been allocated to a reportable segment, discloses the unallocated amount and the reasons for not allocating. For each impairment loss recognized related to an intangible asset (excluding goodwill), discloses: (a) a description of the impaired intangible asset and the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method for determining fair value, (c) the caption in the income statement or the statement of activities in which the impairment loss is aggregated, and (d) the segment in which the impaired intangible asset is reported. For each goodwill impairment loss recognized, discloses: (a) a description of the facts and circumstances leading to the impairment, (b) the amount of the impairment loss and the method of determining the fair value of the associated reporting unit, and (c) if a recognized impairment loss is an estimate not finalized and the reasons why the estimate is not final. May also disclose the nature and amount of any significant adjustments made to a previous estimate of an impairment loss.

Debt Obligations

9 Months Ended

Sep. 30, 2014

Debt Obligations [Abstract]

Debt Obligations

Note 9. Debt Obligations

The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated:

	September 30, 2014			December 31, 2013
EPO senior debt obligations:
Commercial Paper Notes, fixed-rates (1)	$	1,290.0		$	475.0
Senior Notes O, 9.75% fixed-rate, due January 2014		--			500.0
Senior Notes G, 5.60% fixed-rate, due October 2014		650.0			650.0
Senior Notes I, 5.00% fixed-rate, due March 2015		250.0			250.0
Senior Notes X, 3.70% fixed-rate, due June 2015		400.0			400.0
Senior Notes FF, 1.25% fixed-rate, due August 2015		650.0			650.0
$1.5 Billion 364-Day Credit Agreement, variable-rate, due September 2015		--			--
Senior Notes AA, 3.20% fixed-rate, due February 2016		750.0			750.0
Senior Notes L, 6.30% fixed-rate, due September 2017		800.0			800.0
Senior Notes V, 6.65% fixed-rate, due April 2018		349.7			349.7
$3.5 Billion Multi-Year Revolving Credit Facility, variable-rate, due June 2018		--			--
Senior Notes N, 6.50% fixed-rate, due January 2019		700.0			700.0
Senior Notes Q, 5.25% fixed-rate, due January 2020		500.0			500.0
Senior Notes Y, 5.20% fixed-rate, due September 2020		1,000.0			1,000.0
Senior Notes CC, 4.05% fixed-rate, due February 2022		650.0			650.0
Senior Notes HH, 3.35% fixed-rate, due March 2023		1,250.0			1,250.0
Senior Notes JJ, 3.90% fixed-rate, due February 2024		850.0			--
Senior Notes D, 6.875% fixed-rate, due March 2033		500.0			500.0
Senior Notes H, 6.65% fixed-rate, due October 2034		350.0			350.0
Senior Notes J, 5.75% fixed-rate, due March 2035		250.0			250.0
Senior Notes W, 7.55% fixed-rate, due April 2038		399.6			399.6
Senior Notes R, 6.125% fixed-rate, due October 2039		600.0			600.0
Senior Notes Z, 6.45% fixed-rate, due September 2040		600.0			600.0
Senior Notes BB, 5.95% fixed-rate, due February 2041		750.0			750.0
Senior Notes DD, 5.70% fixed-rate, due February 2042		600.0			600.0
Senior Notes EE, 4.85% fixed-rate, due August 2042		750.0			750.0
Senior Notes GG, 4.45% fixed-rate, due February 2043		1,100.0			1,100.0
Senior Notes II, 4.85% fixed-rate, due March 2044		1,000.0			1,000.0
Senior Notes KK, 5.10% fixed-rate, due February 2045		1,150.0			--
TEPPCO senior debt obligations:
TEPPCO Senior Notes, 6.65% fixed-rate, due April 2018		0.3			0.3
TEPPCO Senior Notes, 7.55% fixed-rate, due April 2038		0.4			0.4
Total principal amount of senior debt obligations		18,140.0			15,825.0
EPO Junior Subordinated Notes A, fixed/variable-rate, due August 2066 (2)		550.0			550.0
EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 (3)		285.8			285.8
EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 (4)		682.7			682.7
TEPPCO Junior Subordinated Notes, fixed/variable-rate, due June 2067		14.2			14.2
Total principal amount of senior and junior debt obligations		19,672.7			17,357.7
Other, non-principal amounts		(26.3	)		(6.2	)
Less current maturities of debt (5)		(1,939.9	)		(1,125.0	)
Total long-term debt	$	17,706.5		$	16,226.5

(1) Principal amounts outstanding at September 30, 2014 have fixed rates ranging from 0.22% and 0.29% and are due in October 2014.
(2) Fixed rate of 8.375% through August 1, 2016; thereafter, variable rate based on 3-month LIBOR plus 3.7075%.
(3) Fixed rate of 7.0% through September 1, 2017; thereafter, variable rate based on 3-month LIBOR plus 2.7775%.
(4) Fixed rate of 7.034% through January 15, 2018; thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.68%.
(5) We expect to refinance the current maturities of our debt obligations at or prior to their maturity. Long-term and current maturities of debt reflect the classification of such obligations at September 30, 2014 after taking into consideration the long-term refinancing of Senior Notes G and $650 million of Commercial Paper Notes using proceeds from the issuance of senior notes in October 2014 (see Note 18).

The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at September 30, 2014 for the next five years, and in total thereafter:

			Scheduled Maturities of Debt
	Total		Remainder of 2014		2015		2016		2017		2018		After 2018
Commercial Paper	$	1,290.0	$	1,290.0	$	--	$	--	$	--	$	--	$	--
Senior Notes		16,850.0		650.0		1,300.0		750.0		800.0		350.0		13,000.0
Junior Subordinated Notes		1,532.7		--		--		--		--		--		1,532.7
Total	$	19,672.7	$	1,940.0	$	1,300.0	$	750.0	$	800.0	$	350.0	$	14,532.7

In October 2014, EPO issued $2.75 billion in aggregate principal amount of additional senior notes (see Note 18). Net proceeds from the issuance of these senior notes of $2.73 billion were used as follows: (i) to repay debt principal amounts outstanding under EPO's 364-Day Credit Agreement and commercial paper program (both of which were used to partially fund the cash consideration paid in Step 1 of the Oiltanking acquisition (see Note 18)), (ii) to repay $650.0 million in principal amount of Senior Notes G that matured in October 2014, and (iii) for general company purposes.

Parent-Subsidiary Guarantor Relationships

Enterprise Products Partners L.P. acts as guarantor of the consolidated debt obligations of EPO with the exception of the remaining debt obligations of TEPPCO. If EPO were to default on any of its guaranteed debt, Enterprise Products Partners L.P. would be responsible for full and unconditional repayment of that obligation.

Issuance of Senior Notes in February 2014

In February 2014, EPO issued $850 million in principal amount of 3.90% senior notes due February 2024 ("Senior Notes JJ") and $1.15 billion in principal amount of 5.10% senior notes due February 2045 ("Senior Notes KK"). Senior Notes JJ were issued at 99.811% of their principal amount and Senior Notes KK were issued at 99.845% of their principal amount. Proceeds from the issuance of Senior Notes JJ and KK were used to repay debt, including amounts then outstanding under EPO's commercial paper program (which EPO used to repay $500.0 million in principal amount of Senior Notes O that matured in January 2014) and for general company purposes.

Enterprise Products Partners L.P. has unconditionally guaranteed Senior Notes JJ and KK on an unsecured and unsubordinated basis. These senior notes rank equal with EPO's existing and future unsecured and unsubordinated indebtedness and are senior to any existing and future subordinated indebtedness of EPO. These senior notes are subject to make-whole redemption rights and were issued under indentures containing certain covenants, which generally restrict EPO's ability (with certain exceptions) to incur debt secured by liens and engage in sale and leaseback transactions.

364-Day Credit Agreement due June 2014 Terminated on May 1, 2014

Effective May 1, 2014, EPO elected to terminate its $1.0 billion 364-Day credit agreement in advance of the facility's scheduled maturity date of June 18, 2014. No borrowings were made under this variable-rate revolving credit facility since its inception.

New 364-Day Credit Agreement due September 2015

On September 30, 2014, EPO entered into a new 364-Day Revolving Credit Agreement (the "364-Day Credit Agreement"). Under the terms of the 364-Day Credit Agreement, EPO may borrow up to $1.5 billion (which may be increased by up to $200 million to $1.7 billion at EPO's election) at a variable interest rate for a term of 364 days, subject to the terms and conditions set forth therein. On October 1, 2014, we borrowed $1.5 billion under the 364-Day Credit Agreement to partially fund the cash consideration paid under Step 1 of the Oiltanking acquisition (see Note 18). This amount was subsequently repaid using proceeds from the issuance of senior notes in October 2014 (see Note 18).

To the extent that principal amounts are outstanding, EPO's obligations under the 364-Day Credit Agreement are not secured by any collateral; however, they are guaranteed by Enterprise Products Partners L.P. Any amounts borrowed under the 364-Day Credit Agreement mature on September 29, 2015, although EPO may, between 15 and 60 days prior to the maturity date, elect to have the entire principal balance then outstanding continued as non-revolving term loans for a period of one additional year, payable on September 29, 2016.

The 364-Day Credit Agreement contains customary representations, warranties, covenants (affirmative and negative) and events of default, the occurrence of which would permit the lenders to accelerate the maturity date of any amounts borrowed under the 364-Day Credit Agreement. The 364-Day Credit Agreement also restricts EPO's ability to pay cash distributions to its parent, Enterprise Products Partners L.P., if a default or an event of default (as defined in the 364-Day Credit Agreement) has occurred and is continuing at the time such distribution is scheduled to be paid or would result therefrom.

Letters of Credit

At September 30, 2014, EPO had $2.5 million of letters of credit outstanding related to operations at our facilities and motor fuel tax obligations.

Lender Financial Covenants

We were in compliance with the financial covenants of our consolidated debt agreements at September 30, 2014.

Information Regarding Variable Interest Rates Paid

The following table presents the range of interest rates and weighted-average interest rates paid on our consolidated variable-rate debt during the nine months ended September 30, 2014:

	Range of Interest Rates Paid	Weighted-Average Interest Rate Paid
EPO $3.5 Billion Multi-Year Revolving Credit Facility	1.13% to 1.14%	1.13%

Equity and Distributions

9 Months Ended

Sep. 30, 2014

Equity and Distributions [Abstract]

Equity and Distributions

Note 10. Equity and Distributions

Partners' equity reflects the various classes of limited partner interests (i.e., common units, including restricted common units) that we have outstanding. The following table summarizes changes in the number of Enterprise's outstanding units since December 31, 2013:

	Common Units (Unrestricted)			Restricted Common Units			Total Common Units
Number of units outstanding at December 31, 2013		1,864,148,802			7,221,214			1,871,370,016
Common units issued in connection with at-the-market program		1,590,334			--			1,590,334
Common units issued in connection with DRIP and EUPP		7,355,904			--			7,355,904
Common units issued in connection with the vesting and exercise of unit options		1,014,108			--			1,014,108
Common units issued in connection with the vesting of phantom unit awards		20,842			--			20,842
Common units issued in connection with the vesting of restricted common unit awards		2,586,398			(2,586,398	)		--
Forfeiture of restricted common unit awards		--			(267,200	)		(267,200	)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards		(878,017	)		--			(878,017	)
Other		17,202			--			17,202
Number of units outstanding at September 30, 2014		1,875,855,573			4,367,616			1,880,223,189

On October 1, 2014, in order to fund the equity consideration paid in Step 1 of the Oiltanking acquisition, we issued 54,807,352 common units to Oiltanking Holding Americas, Inc. Pursuant to a Registration Rights Agreement, we granted the seller registration rights with respect to these common units. See Note 18 for additional information regarding the Oiltanking acquisition and the Registration Rights Agreement.

We may issue additional equity or debt securities to assist us in meeting our future liquidity and capital spending requirements. We have a universal shelf registration statement (the "2013 Shelf") on file with the SEC. The 2013 Shelf allows Enterprise Products Partners L.P. and EPO (on a standalone basis) to issue an unlimited amount of equity and debt securities, respectively. EPO utilized the 2013 Shelf to issue $2.0 billion of senior notes in February 2014 (see Note 9) and $2.75 billion of senior notes in October 2014 (see Note 18).

We have a registration statement on file with the SEC covering the issuance of up to $1.25 billion of our common units in amounts, at prices and on terms to be determined by market conditions and other factors at the time of such offerings. Pursuant to this "at-the-market" program, we may sell common units under an equity distribution agreement between Enterprise Products Partners L.P. and certain broker-dealers from time-to-time by means of ordinary brokers' transactions through the NYSE at market prices, in block transactions or as otherwise agreed to with the broker-dealer parties to the agreement. During the nine months ended September 30, 2014, we sold 1,590,334 common units under the "at-the-market" program for aggregate gross proceeds of $58.3 million, resulting in net cash proceeds of $57.7 million. During the nine months ended September 30, 2013, we sold 14,569,614 common units under the program for aggregate gross proceeds of $439.6 million, resulting in net cash proceeds of $435.5 million. After taking into account the aggregate sale price of common units sold under our at-the-market program through September 30, 2014, we have the capacity to issue additional common units under this program up to an aggregate sales price of $1.19 billion.

We also have registration statements on file with the SEC collectively authorizing the issuance of up to 140,000,000 of our common units in connection with a distribution reinvestment plan (or "DRIP"). We issued 7,148,778 common units under our DRIP during the nine months ended September 30, 2014, which generated net cash proceeds of $240.0 million. During the nine months ended September 30, 2013, we issued 7,298,646 common units, which generated net cash proceeds of $206.0 million. After taking into account the number of common units issued under the DRIP through September 30, 2014, we have the capacity to issue an additional 29,812,978 common units under this plan.

In January 2014, privately held affiliates of EPCO expressed their willingness to consider purchasing through the DRIP a total of $100 million of our common units during 2014. During the nine months ended September 30, 2014, these EPCO affiliates reinvested $75.0 million, resulting in the issuance of 2,232,872 common units under our DRIP (this amount being a component of the total common units issued under the DRIP for the nine months ended September 30, 2014). On November 7, 2014, these EPCO affiliates reinvested an additional $25.0 million through the DRIP.

In addition to the DRIP, we have registration statements on file with the SEC authorizing the issuance of up to 8,000,000 of our common units in connection with an employee unit purchase plan (or "EUPP"). We issued 207,126 common units under our EUPP during the nine months ended September 30, 2014, which generated net cash proceeds of $7.4 million. During the nine months ended September 30, 2013, we issued 221,662 common units, which generated net cash proceeds of $6.6 million. After taking into account the number of common units issued under the EUPP through September 30, 2014, we may issue an additional 7,219,762 common units under this plan.

The net cash proceeds we received from the issuance of common units during the nine months ended September 30, 2014 were used to temporarily reduce amounts outstanding under EPO's commercial paper program and for general company purposes.

Two-for-One Split of Limited Partner Units

On July 15, 2014, we announced that our general partner approved a two-for-one split of our common units. The common unit split was completed on August 21, 2014 by distributing one additional common unit for each common unit outstanding (to holders of record as of the close of business on August 14, 2014).

Accumulated Other Comprehensive Loss

The following tables present the components of accumulated other comprehensive income (loss) as reported on our Unaudited Condensed Consolidated Balance Sheets at the dates indicated:

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other		Total
Balance, December 31, 2013	$	(14.7	)	$	(347.2	)	$	2.9	$	(359.0	)
Other comprehensive income before reclassifications		16.1			--			--		16.1
Amounts reclassified from accumulated other comprehensive loss		12.9			23.9			--		36.8
Total other comprehensive income		29.0			23.9			--		52.9
Balance, September 30, 2014	$	14.3		$	(323.3	)	$	2.9	$	(306.1	)

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other		Total
Balance, December 31, 2012	$	10.1		$	(383.0	)	$	2.5	$	(370.4	)
Other comprehensive income before reclassifications		(22.1	)		6.7			0.4		(15.0	)
Amounts reclassified from accumulated other comprehensive loss		14.7			21.4			--		36.1
Total other comprehensive income (loss)		(7.4	)		28.1			0.4		21.1
Balance, September 30, 2013	$	2.7		$	(354.9	)	$	2.9	$	(349.3	)

The following table presents reclassifications out of accumulated other comprehensive income (loss) into net income during the periods indicated:

		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
	Location	2014				2013			2014				2013
Losses (gains) on cash flow hedges:
Interest rate derivatives	Interest expense		$	8.0			$	7.7		$	23.9			$	21.4
Commodity derivatives	Revenue			(17.8	)			14.6			14.5				15.1
Commodity derivatives	Operating costs and expenses			(0.2	)			--			(1.6	)			(0.4	)
Total			$	(10.0	)		$	22.3		$	36.8			$	36.1

Noncontrolling Interests

Noncontrolling interests as presented on our Unaudited Condensed Consolidated Financial Statements represent third party ownership interests in joint ventures that we consolidate for financial reporting purposes, including Tri-States NGL Pipeline L.L.C., Independence Hub LLC, Rio Grande Pipeline Company, Wilprise Pipeline Company LLC and Enterprise EF78 LLC.

Cash Distributions

The following table presents Enterprise's declared quarterly cash distribution rates per common unit with respect to the quarter indicated:

	Distribution Per Common Unit		Record Date	Payment Date
2013:
1st Quarter	$	0.3350	4/30/2013	5/7/2013
2nd Quarter	$	0.3400	7/31/2013	8/7/2013
3rd Quarter	$	0.3450	10/31/2013	11/7/2013
2014:
1st Quarter	$	0.3550	4/30/2014	5/7/2014
2nd Quarter	$	0.3600	7/31/2014	8/7/2014
3rd Quarter	$	0.3650	10/31/2014	11/7/2014

As a result of the unit split completed on August 21, 2014, our historical distributions per unit were reduced (e.g., a $0.72 per unit distribution rate was adjusted to a $0.36 per unit distribution rate), but not the total amount of cash distributions paid since the number of common units outstanding doubled.

In November 2010, we completed our merger with Enterprise GP Holdings L.P. (the "Holdings Merger"). In connection with the Holdings Merger, a privately held affiliate of EPCO agreed to temporarily waive the regular quarterly cash distributions it would otherwise receive from us with respect to a certain number of our common units it owns (the "Designated Units"). Distributions paid during 2014 exclude 45,120,000 Designated Units. Distributions to be paid, if any, during 2015 will exclude 35,380,000 Designated Units.

The entire disclosure for shareholders' equity comprised of portions attributable to the parent entity and noncontrolling interest, including other comprehensive income. Includes, but is not limited to, balances of common stock, preferred stock, additional paid-in capital, other capital and retained earnings, accumulated balance for each classification of other comprehensive income and amount of comprehensive income.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(d),(e))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 4
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21484-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 10
-Section S99
-Paragraph 2
-Subparagraph (SAB TOPIC 4.E)
-URI http://asc.fasb.org/extlink&oid=27010918&loc=d3e74512-122707

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 5
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21488-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.29-31)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 4
-Subparagraph (SAB TOPIC 4.C)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187143-122770

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.3-04)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187085-122770

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 30
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6405834&loc=d3e23285-112656

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Glossary Preferred Stock
-URI http://asc.fasb.org/extlink&oid=6521494

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21463-112644

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 11
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21564-112644

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Paragraph d
-Article 4

Reference 15: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 29, 30, 31
-Article 5

Reference 16: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section E

Reference 17: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 08
-Article 4

Reference 18: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Staff Accounting Bulletin (SAB)
-Number Topic 4
-Section C

Reference 19: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 04
-Article 3

+ Details

Business Segments

9 Months Ended

Sep. 30, 2014

Business Segments [Abstract]

Business Segments

Note 11. Business Segments

We have five reportable business segments: (i) NGL Pipelines & Services; (ii) Onshore Natural Gas Pipelines & Services; (iii) Onshore Crude Oil Pipelines & Services; (iv) Offshore Pipelines & Services; and (v) Petrochemical & Refined Products Services. Our business segments are generally organized and managed according to the types of services rendered (or technologies employed) and products produced and/or sold.

We evaluate segment performance based on the non-GAAP financial measure of gross operating margin. Gross operating margin (either in total or by individual segment) is 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 executive 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 in evaluating segment results. The GAAP financial measure most directly comparable to total segment gross operating margin is operating income.

In total, gross operating margin represents operating income exclusive of (1) depreciation, amortization and accretion expenses, (2) impairment charges, (3) gains and losses attributable to asset sales and insurance recoveries and (4) general and administrative costs. Gross operating margin includes equity in income of unconsolidated affiliates and non-refundable deferred transportation revenues relating to the make-up rights of committed shippers associated with certain pipelines. Gross operating margin by segment is calculated by subtracting segment operating costs and expenses (net of the adjustments noted above) from segment revenues, with both segment totals before the elimination of intercompany transactions. In accordance with GAAP, intercompany accounts and transactions are eliminated in consolidation. Gross operating margin is exclusive of other income and expense transactions, income taxes, the cumulative effect of changes in accounting principles and extraordinary charges. Gross operating margin is presented on a 100% basis before any allocation of earnings to noncontrolling interests.

Segment revenues include intersegment and intrasegment transactions, which are generally based on transactions made at market-based rates. Our consolidated revenues reflect the elimination of intercompany transactions. Substantially all of our consolidated revenues are earned in the U.S. and derived from a wide customer base.

Segment assets consist of property, plant and equipment, investments in unconsolidated affiliates, intangible assets and goodwill. The carrying values of such amounts are assigned to each segment based on each asset's or investment's principal operations and contribution to the gross operating margin of that particular segment. Since construction-in-progress amounts (a component of property, plant and equipment) generally do not contribute to segment gross operating margin, such amounts are excluded from segment asset totals until the underlying assets are placed in service. Intangible assets and goodwill are assigned to each segment based on the classification of the assets to which they relate. Substantially all of our plants, pipelines and other fixed assets are located in the U.S.

The following table presents our measurement of non-GAAP total segment gross operating margin for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Revenues	$	12,330.2		$	12,093.3		$	37,760.9		$	34,625.7
Subtract operating costs and expenses		(11,414.8	)		(11,273.5	)		(34,934.4	)		(32,061.1	)
Add equity in income of unconsolidated affiliates		72.3			44.0			179.1			126.1
Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin		322.7			285.2			936.5			851.7
Add impairment charges not reflected in gross operating margin		5.7			15.2			18.2			53.3
Subtract net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin		(2.6	)		(10.2	)		(99.0	)		(68.4	)
Add non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin		21.6			--			66.8			--
Total segment gross operating margin	$	1,335.1		$	1,154.0		$	3,928.1		$	3,527.3

The following table presents a reconciliation of total segment gross operating margin to operating income and further to income before income taxes for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Total segment gross operating margin	$	1,335.1		$	1,154.0		$	3,928.1		$	3,527.3
Adjustments to reconcile total segment gross operating margin to operating income:
Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin		(322.7	)		(285.2	)		(936.5	)		(851.7	)
Subtract impairment charges not reflected in gross operating margin		(5.7	)		(15.2	)		(18.2	)		(53.3	)
Add net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin (see Note 16)		2.6			10.2			99.0			68.4
Subtract non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin		(21.6	)		--			(66.8	)		--
Subtract general and administrative costs not reflected in gross operating margin		(50.0	)		(43.9	)		(150.9	)		(138.9	)
Operating income		937.7			819.9			2,854.7			2,551.8
Other expense, net		(230.8	)		(207.7	)		(679.8	)		(604.2	)
Income before income taxes	$	706.9		$	612.2		$	2,174.9		$	1,947.6

Information by business segment, together with reconciliations to our consolidated financial statement totals, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Onshore Natural Gas Pipelines & Services		Onshore Crude Oil Pipelines & Services		Offshore Pipelines & Services		Petrochemical & Refined Products Services			Adjustments and Eliminations			Consolidated Total
Revenues from third parties:
Three months ended September 30, 2014	$	4,024.0	$	1,026.5	$	5,435.6	$	41.1	$	1,792.0		$	--		$	12,319.2
Three months ended September 30, 2013		4,230.6		831.4		5,435.4		38.2		1,550.0			--			12,085.6
Nine months ended September 30, 2014		13,217.2		3,261.0		16,236.6		112.4		4,869.9			--			37,697.1
Nine months ended September 30, 2013		11,686.0		2,658.6		15,358.1		118.0		4,784.7			--			34,605.4
Revenues from related parties:
Three months ended September 30, 2014		2.7		5.4		1.5		1.4		--			--			11.0
Three months ended September 30, 2013		0.1		4.1		2.1		1.4		--			--			7.7
Nine months ended September 30, 2014		10.2		16.5		31.1		6.0		--			--			63.8
Nine months ended September 30, 2013		0.6		12.1		2.1		5.5		--			--			20.3
Intersegment and intrasegment revenues:
Three months ended September 30, 2014		3,603.8		231.0		2,529.5		1.2		452.2			(6,817.7	)		--
Three months ended September 30, 2013		2,542.3		215.6		3,591.3		1.8		384.4			(6,735.4	)		--
Nine months ended September 30, 2014		10,789.7		835.8		10,714.5		4.8		1,317.6			(23,662.4	)		--
Nine months ended September 30, 2013		7,631.7		726.7		8,333.0		8.0		1,200.7			(17,900.1	)		--
Total revenues:
Three months ended September 30, 2014		7,630.5		1,262.9		7,966.6		43.7		2,244.2			(6,817.7	)		12,330.2
Three months ended September 30, 2013		6,773.0		1,051.1		9,028.8		41.4		1,934.4			(6,735.4	)		12,093.3
Nine months ended September 30, 2014		24,017.1		4,113.3		26,982.2		123.2		6,187.5			(23,662.4	)		37,760.9
Nine months ended September 30, 2013		19,318.3		3,397.4		23,693.2		131.5		5,985.4			(17,900.1	)		34,625.7
Equity in income (loss) of unconsolidated affiliates:
Three months ended September 30, 2014		11.7		0.9		46.8		17.1		(4.2	)		--			72.3
Three months ended September 30, 2013		4.1		1.0		34.3		9.8		(5.2	)		--			44.0
Nine months ended September 30, 2014		19.2		2.7		131.7		35.8		(10.3	)		--			179.1
Nine months ended September 30, 2013		11.8		2.9		101.0		24.9		(14.5	)		--			126.1
Gross operating margin:
Three months ended September 30, 2014		711.5		195.4		190.8		47.1		190.3			--			1,335.1
Three months ended September 30, 2013		639.6		213.4		146.0		37.9		117.1			--			1,154.0
Nine months ended September 30, 2014		2,172.4		618.8		534.5		120.0		482.4			--			3,928.1
Nine months ended September 30, 2013		1,777.0		601.9		579.6		118.1		450.7			--			3,527.3
Property, plant and equipment, net: (see Note 6)
At September 30, 2014		11,768.9		8,834.7		1,540.6		1,168.2		2,845.2			1,805.7			27,963.3
At December 31, 2013		9,957.8		8,917.3		1,479.9		1,223.7		2,712.4			2,655.5			26,946.6
Investments in unconsolidated affiliates: (see Note 7)
At September 30, 2014		685.8		23.5		1,651.7		502.4		74.9			--			2,938.3
At December 31, 2013		645.5		24.2		1,165.2		531.8		70.4			--			2,437.1
Intangible assets, net: (see Note 8)
At September 30, 2014		264.6		983.6		3.6		43.9		95.4			--			1,391.1
At December 31, 2013		285.2		1,017.8		4.5		54.7		100.0			--			1,462.2
Goodwill: (see Note 8)
At September 30, 2014		861.2		296.3		305.1		82.0		535.3			--			2,079.9
At December 31, 2013		341.2		296.3		305.1		82.1		1,055.3			--			2,080.0
Segment assets:
At September 30, 2014		13,580.5		10,138.1		3,501.0		1,796.5		3,550.8			1,805.7			34,372.6
At December 31, 2013		11,229.7		10,255.6		2,954.7		1,892.3		3,938.1			2,655.5			32,925.9

The following table presents additional information regarding our consolidated revenues and costs and expenses for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
NGL Pipelines & Services:
Sales of NGLs and related products	$	3,603.4		$	3,929.8		$	12,029.8		$	10,831.3
Midstream services		423.3			300.9			1,197.6			855.3
Total		4,026.7			4,230.7			13,227.4			11,686.6
Onshore Natural Gas Pipelines & Services:
Sales of natural gas		775.5			590.7			2,515.7			1,954.1
Midstream services		256.4			244.8			761.8			716.6
Total		1,031.9			835.5			3,277.5			2,670.7
Onshore Crude Oil Pipelines & Services:
Sales of crude oil		5,348.2			5,359.7			16,003.5			15,159.9
Midstream services		88.9			77.8			264.2			200.3
Total		5,437.1			5,437.5			16,267.7			15,360.2
Offshore Pipelines & Services:
Sales of natural gas		--			0.1			0.2			0.3
Sales of crude oil		2.5			1.5			7.5			3.7
Midstream services		40.0			38.0			110.7			119.5
Total		42.5			39.6			118.4			123.5
Petrochemical & Refined Products Services:
Sales of petrochemicals and refined products		1,605.4			1,390.1			4,338.2			4,271.5
Midstream services		186.6			159.9			531.7			513.2
Total		1,792.0			1,550.0			4,869.9			4,784.7
Total consolidated revenues	$	12,330.2		$	12,093.3		$	37,760.9		$	34,625.7

Consolidated costs and expenses
Operating costs and expenses:
Cost of sales	$	10,455.1		$	10,371.3		$	32,213.1		$	29,522.1
Other operating costs and expenses (1)		633.9			612.0			1,865.6			1,702.4
Depreciation, amortization and accretion		322.7			285.2			936.5			851.7
Net losses (gains) attributable to asset sales and insurance recoveries		(2.6	)		(10.2	)		(99.0	)		(68.4	)
Non-cash asset impairment charges		5.7			15.2			18.2			53.3
General and administrative costs		50.0			43.9			150.9			138.9
Total consolidated costs and expenses	$	11,464.8		$	11,317.4		$	35,085.3		$	32,200.0

(1) Represents cost of operating our plants, pipelines and other fixed assets, excluding depreciation, amortization and accretion charges.

Period-to-period fluctuations in our product sales revenues and related cost of sales amounts are explained in part by changes in energy commodity prices. In general, lower energy commodity prices result in a decrease in our revenues attributable to product sales; however, these lower commodity prices also decrease the associated cost of sales as purchase costs decline. The same correlation would be true in the case of higher energy commodity sales prices and purchase costs.

Related Party Transactions

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 34
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8981-108599

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 41
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9038-108599

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 33
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8971-108599

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 12
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8595-108599

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 1
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8380-108599

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 32
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8933-108599

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 26
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8844-108599

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 35
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8984-108599

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 40
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9031-108599

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e9054-108599

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 10
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8538-108599

Reference 12: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 29
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8864-108599

Reference 13: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 31
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8924-108599

Reference 14: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 30
-URI http://asc.fasb.org/extlink&oid=6534315&loc=d3e8906-108599

+ Details

Related Party Transactions

9 Months Ended

Sep. 30, 2014

Note 12. Related Party Transactions

The following table summarizes our related party transactions for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Revenues – related parties:
Unconsolidated affiliates		$	11.0		$	7.7		$	63.8		$	20.3
Costs and expenses – related parties:
EPCO and affiliates		$	212.8		$	218.8		$	688.0		$	654.4
Unconsolidated affiliates			35.8			25.9			138.4			86.5
Total		$	248.6		$	244.7		$	826.4		$	740.9

The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated:

	September 30, 2014		December 31, 2013
Accounts receivable - related parties:
Unconsolidated affiliates	$	2.6	$	6.8

Accounts payable - related parties:
EPCO and affiliates	$	102.3	$	116.3
Unconsolidated affiliates		20.3		34.2
Total	$	122.6	$	150.5

We believe that the terms and provisions of our related party agreements are fair to us; however, such agreements and transactions may not be as favorable to us as we could have obtained from unaffiliated third parties.

Relationship with EPCO and Affiliates

We have an extensive and ongoing relationship with EPCO and its privately held affiliates (including Enterprise GP, our general partner), which are not a part of our consolidated group of companies. At September 30, 2014, EPCO and its privately held affiliates (including Dan Duncan LLC and certain Duncan family trusts, the beneficiaries of which include the estate of Dan L. Duncan) beneficially owned the following limited partner interests in us:

Number of Units	Percentage of Total Units Outstanding
683,993,630	36.4%

We and Enterprise GP are both separate legal entities apart from each other and apart from EPCO and its other affiliates, with assets and liabilities that are also separate from those of EPCO and its other affiliates. EPCO and its privately held affiliates depend on the cash distributions they receive from us and other investments to fund their other activities and to meet their debt obligations. During the nine months ended September 30, 2014 and 2013, we paid EPCO and its privately held affiliates cash distributions totaling $652.8 million and $601.2 million, respectively.

From time-to-time, EPCO and its privately held affiliates elect to reinvest a portion of the cash distributions they receive from us into the purchase of additional common units under our DRIP. See Note 10 for information regarding reinvestments made during 2014.

We have no employees. All of our operating functions and general and administrative support services are provided by employees of EPCO pursuant to the ASA or by other service providers.

The following table presents our costs and expenses attributable to the ASA and other related party transactions with EPCO for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Operating costs and expenses		$	179.1		$	190.5		$	591.7		$	564.7
General and administrative expenses			33.7			28.3			96.3			89.7
Total costs and expenses		$	212.8		$	218.8		$	688.0		$	654.4

The entire disclosure for related party transactions. Examples of related party transactions include transactions between (a) a parent company and its subsidiary; (b) subsidiaries of a common parent; (c) and entity and its principal owners; and (d) affiliates.

Supplemental Cash Flow Information [Abstract]

Earnings Per Unit

9 Months Ended

Sep. 30, 2014

Earnings Per Unit [Abstract]

Earnings Per Unit

Note 13. Earnings Per Unit

The following table presents our calculation of basic and diluted earnings per unit for the periods indicated:

	For the Three Months Ended September 30,					For the Nine Months Ended September 30,
	2014			2013		2014			2013
BASIC EARNINGS PER UNIT
Net income attributable to limited partners	$	691.1		$	592.0	$	2,127.6		$	1,898.0
Undistributed earnings allocated and cash payments on phantom unit awards (1)		(1.3	)		--		(4.0	)		--
Net income available to common unitholders	$	689.8		$	592.0	$	2,123.6		$	1,898.0

Basic weighted-average number of common units outstanding		1,834.2			1,792.6		1,831.1			1,778.2

Basic earnings per unit	$	0.38		$	0.33	$	1.16		$	1.07

DILUTED EARNINGS PER UNIT
Net income attributable to limited partners	$	691.1		$	592.0	$	2,127.6		$	1,898.0

Diluted weighted-average number of units outstanding:
Distribution-bearing common units		1,834.2			1,792.6		1,831.1			1,778.2
Designated Units		45.1			47.4		45.1			47.4
Class B units (2)		--			3.8		--			7.2
Phantom units (1)		3.4			--		2.8			--
Incremental option units		0.7			2.2		1.0			2.4
Total		1,883.4			1,846.0		1,880.0			1,835.2

Diluted earnings per unit	$	0.37		$	0.32	$	1.13		$	1.03

(1) Each phantom unit award includes a DER, which entitles the recipient to receive cash payments equal to the product of the number of phantom unit awards and the cash distribution per unit paid to Enterprise's common unitholders. Cash payments made in connection with DERs are nonforfeitable. As a result, the phantom units are considered participating securities for purposes of computing basic earnings per unit. Phantom unit awards were first issued in February 2014.
(2) The Class B units automatically converted into an equal number of distribution-bearing common units in August 2013.

See Note 10 for information regarding a two-for-one common unit split announced on July 15, 2014 and completed on August 21, 2014.

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 2014
Commitments and Contingencies [Abstract]
Commitments and Contingencies	Note 14. Commitments and Contingencies Litigation As part of our normal business activities, we may be named as defendants in legal proceedings, including those arising from regulatory and environmental matters. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to fully indemnify us against losses arising from future legal proceedings. We will vigorously defend the partnership in litigation matters. Management has regular quarterly litigation reviews, including updates from legal counsel, to assess the possible need for accounting recognition and disclosure of these contingencies. We accrue an undiscounted liability for those contingencies where the loss is probable and the amount can be reasonably estimated. If a range of probable loss amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum amount in the range is accrued. We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when the likelihood of loss is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material to our consolidated financial statements, we disclose the nature of the contingency and, where feasible, an estimate of the possible loss or range of loss. Based on a consideration of all relevant known facts and circumstances, we do not believe that the ultimate outcome of any currently pending litigation directed against us will have a material impact on our consolidated financial statements either individually at the claim level or in the aggregate. At September 30, 2014 and December 31, 2013, our accruals for litigation contingencies were $2.5 million and $3.7 million, respectively, and were recorded in our Unaudited Condensed Consolidated Balance Sheets as a component of "Other current liabilities." Our evaluation of litigation contingencies is based on the facts and circumstances of each case and predicting the outcome of these matters involves uncertainties. In the event the assumptions we use to evaluate these matters change in future periods or new information becomes available, we may be required to record additional accruals. In an effort to mitigate expenses associated with litigation, we may settle legal proceedings out of court. ETP Matter. In connection with a proposed pipeline project, we and Energy Transfer Partners, L.P. ("ETP") signed a non-binding letter of intent in April 2011 that disclaimed any partnership or joint venture related to such project absent executed definitive documents and board approvals of the respective companies. Definitive agreements were never executed and board approval was never obtained for the potential pipeline project. In August 2011, the proposed pipeline project was cancelled due to a lack of customer support. In September 2011, ETP filed suit against us and a third party in connection with the cancelled project alleging, among other things, that we and ETP had formed a "partnership." The case was tried in the District Court of Dallas County, Texas, 298th Judicial District. While we firmly believe, and argued during our defense, that no agreement was ever executed forming a legal joint venture or partnership between the parties, the jury found that the actions of the two companies, nevertheless, constituted a legal partnership. As a result, the jury found that ETP was wrongfully excluded from a subsequent pipeline project involving a third party, and awarded ETP $319.4 million in actual damages on March 4, 2014. On July 29, 2014, the court entered judgment against us in an aggregate amount of $535.8 million, which includes (i) $319.4 million as the amount of actual damages awarded by the jury, (ii) an additional $150.0 million in disgorgement for the alleged benefit we received due to a breach of fiduciary duties by us against ETP and (iii) prejudgment interest in the amount of $66.4 million. The court also awarded post-judgment interest on such aggregate amount, to accrue at a rate of 5% per annum, compounded annually. We do not believe that the verdict or the judgment entered against us is supported by the evidence or the law and intend to vigorously oppose the judgment through the appeals process. As of September 30, 2014, we have not recorded a provision for this matter as management believes payment of damages in this case is not probable. Contractual Obligations Scheduled Maturities of Debt. With the exception of routine fluctuations in the balance of our revolving credit facility and commercial paper notes, the issuance of senior notes in February and October 2014 (see Note 18) and the scheduled repayment of maturing debt obligations, there have been no significant changes in our consolidated debt obligations since those reported in our 2013 Form 10-K. See Note 9 for additional information regarding our consolidated debt obligations. Operating Lease Obligations. Consolidated lease and rental expense was $23.5 million and $19.6 million during the third quarters of 2014 and 2013, respectively. For the nine months ended September 30, 2014 and 2013, consolidated lease and rental expense was $69.2 million and $64.9 million, respectively. During the second quarter of 2014, we entered into a long-term lease in connection with our plans to construct an ethane export terminal on the Houston Ship Channel. In addition, we entered into long-term railcar leases in connection with our other operations. On a combined basis, these agreements increased our estimated long-term operating lease obligations by approximately $39 million over the next five years and $150 million overall. Apart from these new agreements, there have been no other material changes in our operating lease commitments since those reported in our 2013 Form 10-K. Purchase Obligations. There have been no material changes in our consolidated purchase obligations since those reported in our 2013 Form 10-K.

Insurance Matters	9 Months Ended
Insurance Matters	Sep. 30, 2014
Insurance Matters [Abstract]
Insurance Matters	Note 15. Insurance Matters We participate as a named insured in EPCO's insurance program, which provides us with property damage, business interruption and other insurance coverage, the scope and amounts of which we believe are customary and prudent for the nature and extent of our operations. While we believe EPCO maintains adequate insurance coverage on our behalf, insurance may not fully cover every type of damage, interruption or other loss that might occur. We elected to forego windstorm coverage for our Gulf of Mexico offshore assets during the 2014 Atlantic hurricane season, which extends from June 1 through November 30. The combination of increasingly high deductibles and proposed premiums resulted in such coverage being uneconomic to us. Although EPCO's coverage does not provide any windstorm coverage for our offshore assets during the annual policy period that began on June 1, 2014, producers affiliated with our Independence Hub and Marco Polo platforms will continue to provide certain levels of physical damage windstorm coverage for each of these key offshore assets. West Storage Claims In February 2011, we experienced an NGL release and fire at the West Storage location of our Mont Belvieu, Texas underground storage facility. We collected $95.0 million and $8.8 million of nonrefundable cash insurance proceeds attributable to this incident during the nine months ended September 30, 2014 and 2013, respectively. The payments we received during the first quarter of 2014 represent the final installments on this property damage claim. Operating income for the nine months ended September 30, 2014 and 2013 includes $95.0 million and $8.8 million, respectively, of gains related to these insurance recoveries. To the extent that we received nonrefundable cash insurance proceeds related to this incident, we recorded gains equal to such proceeds as a reduction in operating costs and expenses.

Supplemental Cash Flow Information

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Information

Note 16. Supplemental Cash Flow Information

The following table presents the net effect of changes in our operating accounts for the periods indicated:

	For the Nine Months Ended September 30,
	2014			2013
Decrease (increase) in:
Accounts receivable – trade	$	153.6		$	(1,130.0	)
Accounts receivable – related parties		4.0			(9.6	)
Inventories		(536.9	)		(674.2	)
Prepaid and other current assets		(44.5	)		(31.5	)
Other assets		20.0			3.2
Increase (decrease) in:
Accounts payable – trade		(14.2	)		114.3
Accounts payable – related parties		(27.7	)		(30.4	)
Accrued product payables		(13.1	)		1,358.1
Accrued interest		(131.7	)		(132.6	)
Other current liabilities		143.5			29.3
Other liabilities		11.2			(10.5	)
Net effect of changes in operating accounts	$	(435.8	)	$	(513.9	)

We incurred liabilities for construction in progress that had not been paid at September 30, 2014 and December 31, 2013 of $264.9 million and $205.3 million, respectively. Such amounts are not included under the caption "Capital expenditures" on the Unaudited Condensed Statements of Consolidated Cash Flows.

On certain of our capital projects, third parties are obligated to reimburse us for all or a portion of project expenditures. The majority of such arrangements are associated with projects related to pipeline construction activities and production well tie-ins. These cash receipts are presented as "Contributions in aid of construction costs" within the investing activities section of our Unaudited Condensed Statements of Consolidated Cash Flows.

The following table presents our cash proceeds from asset sales and insurance recoveries for the periods indicated:

	For the Nine Months Ended September 30,
	2014		2013
Sale of Stratton Ridge-to-Mont Belvieu segment of Seminole Pipeline (see Note 6)	$	--	$	86.9
Sale of lubrication oil and specialty chemical distribution assets (see Note 6)		--		35.3
Sale of chemical trucking assets		--		29.5
Sale of pipeline linefill		7.4		65.0
Insurance recoveries attributable to West Storage claims (see Note 15)		95.0		8.8
Other cash proceeds		19.1		30.8
Total	$	121.5	$	256.3

The following table presents net gains attributable to asset sales and insurance recoveries for the periods indicated:

	For the Nine Months Ended September 30,
	2014		2013
Sale of Stratton Ridge-to-Mont Belvieu segment of Seminole Pipeline (see Note 6)	$	--	$	52.5
Gains attributable to West Storage insurance recoveries (see Note 15)		95.0		8.8
Net gains attributable to other asset sales		4.0		7.1
Total	$	99.0	$	68.4

Condensed Consolidating Financial Information

9 Months Ended

Sep. 30, 2014

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Financial Information

Note 17. Condensed Consolidating Financial Information

EPO conducts all of our business. Currently, we have no independent operations and no material assets outside those of EPO.

EPO has issued publicly traded debt securities. Enterprise Products Partners L.P., as the parent company of EPO, guarantees the debt obligations of EPO, with the exception of the remaining debt obligations of TEPPCO. If EPO were to default on any of its guaranteed debt, Enterprise Products Partners L.P. would be responsible for full and unconditional repayment of that obligation. EPO's consolidated subsidiaries have no significant restrictions on their ability to pay distributions or make loans to Enterprise Products Partners L.P. See Note 9 for additional information regarding our consolidated debt obligations.

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	1,019.7	$	52.1	$	(3.6	)	$	1,068.2	$	--	$	--		$	1,068.2
Accounts receivable – trade, net		1,625.8		3,700.7		(5.7	)		5,320.8		--		--			5,320.8
Accounts receivable – related parties		104.0		1,380.9		(1,481.8	)		3.1		--		(0.5	)		2.6
Inventories		1,244.3		346.2		(1.0	)		1,589.5		--		--			1,589.5
Prepaid and other current assets		167.7		226.2		(10.3	)		383.6		0.1		0.7			384.4
Total current assets		4,161.5		5,706.1		(1,502.4	)		8,365.2		0.1		0.2			8,365.5
Property, plant and equipment, net		2,360.6		25,601.2		1.5			27,963.3		--		--			27,963.3
Investments in unconsolidated affiliates		32,198.8		3,452.0		(32,712.5	)		2,938.3		15,758.0		(15,758.0	)		2,938.3
Intangible assets, net		80.2		1,326.2		(15.3	)		1,391.1		--		--			1,391.1
Goodwill		458.8		1,621.1		--			2,079.9		--		--			2,079.9
Other assets		124.5		44.7		(1.9	)		167.3		0.1		--			167.4
Total assets	$	39,384.4	$	37,751.3	$	(34,230.6	)	$	42,905.1	$	15,758.2	$	(15,757.8	)	$	42,905.5

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	1,939.9	$	--	$	--		$	1,939.9	$	--	$	--		$	1,939.9
Accounts payable – trade		304.5		426.9		(3.6	)		727.8		0.2		--			728.0
Accounts payable – related parties		1,472.6		146.0		(1,496.0	)		122.6		0.5		(0.5	)		122.6
Accrued product payables		2,003.7		3,568.1		(7.2	)		5,564.6		--		--			5,564.6
Accrued interest		172.2		0.3		--			172.5		--		--			172.5
Other current liabilities		63.1		392.4		(11.3	)		444.2		--		--			444.2
Total current liabilities		5,956.0		4,533.7		(1,518.1	)		8,971.6		0.7		(0.5	)		8,971.8
Long-term debt		17,691.6		14.9		--			17,706.5		--		--			17,706.5
Deferred tax liabilities		4.3		57.3		(1.9	)		59.7		--		3.5			63.2
Other long-term liabilities		10.4		172.2		(0.5	)		182.1		--		--			182.1
Commitments and contingencies
Equity:
Partners' and other owners' equity		15,722.1		32,903.7		(32,892.1	)		15,733.7		15,757.5		(15,733.7	)		15,757.5
Noncontrolling interests		--		69.5		182.0			251.5		--		(27.1	)		224.4
Total equity		15,722.1		32,973.2		(32,710.1	)		15,985.2		15,757.5		(15,760.8	)		15,981.9
Total liabilities and equity	$	39,384.4	$	37,751.3	$	(34,230.6	)	$	42,905.1	$	15,758.2	$	(15,757.8	)	$	42,905.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

December 31, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	93.9	$	49.5	$	(20.9	)	$	122.5	$	--	$	--		$	122.5
Accounts receivable – trade, net		1,986.8		3,491.1		(2.4	)		5,475.5		--		--			5,475.5
Accounts receivable – related parties		384.7		1,348.1		(1,726.0	)		6.8		0.2		(0.2	)		6.8
Inventories		948.5		145.4		(0.8	)		1,093.1		--		--			1,093.1
Prepaid and other current assets		140.9		191.4		(6.8	)		325.5		--		--			325.5
Total current assets		3,554.8		5,225.5		(1,756.9	)		7,023.4		0.2		(0.2	)		7,023.4
Property, plant and equipment, net		1,945.0		24,999.7		1.9			26,946.6		--		--			26,946.6
Investments in unconsolidated affiliates		30,819.9		2,921.2		(31,304.0	)		2,437.1		15,214.5		(15,214.5	)		2,437.1
Intangible assets, net		76.9		1,385.3		--			1,462.2		--		--			1,462.2
Goodwill		458.9		1,621.1		--			2,080.0		--		--			2,080.0
Other assets		123.5		67.2		(1.4	)		189.3		0.1		--			189.4
Total assets	$	36,979.0	$	36,220.0	$	(33,060.4	)	$	40,138.6	$	15,214.8	$	(15,214.7	)	$	40,138.7

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	1,125.0	$	--	$	--		$	1,125.0	$	--	$	--		$	1,125.0
Accounts payable – trade		103.0		641.6		(20.9	)		723.7		--		--			723.7
Accounts payable – related parties		1,541.8		333.8		(1,724.9	)		150.7		--		(0.2	)		150.5
Accrued product payables		2,388.6		3,224.5		(4.4	)		5,608.7		--		--			5,608.7
Accrued interest		304.2		0.1		--			304.3		--		--			304.3
Other current liabilities		92.3		242.4		(6.7	)		328.0		--		(1.5	)		326.5
Total current liabilities		5,554.9		4,442.4		(1,756.9	)		8,240.4		--		(1.7	)		8,238.7
Long-term debt		16,211.6		14.9		--			16,226.5		--		--			16,226.5
Deferred tax liabilities		4.3		55.0		(1.4	)		57.9		--		2.9			60.8
Other long-term liabilities		11.8		160.5		--			172.3		--		--			172.3
Commitments and contingencies
Equity:
Partners' and other owners' equity		15,196.4		31,475.9		(31,482.4	)		15,189.9		15,214.8		(15,189.9	)		15,214.8
Noncontrolling interests		--		71.3		180.3			251.6		--		(26.0	)		225.6
Total equity		15,196.4		31,547.2		(31,302.1	)		15,441.5		15,214.8		(15,215.9	)		15,440.4
Total liabilities and equity	$	36,979.0	$	36,220.0	$	(33,060.4	)	$	40,138.6	$	15,214.8	$	(15,214.7	)	$	40,138.7

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	8,121.5		$	8,598.2		$	(4,389.5	)	$	12,330.2		$	--	$	--		$	12,330.2
Costs and expenses:
Operating costs and expenses		7,950.9			7,853.5			(4,389.6	)		11,414.8			--		--			11,414.8
General and administrative costs		8.2			40.4			--			48.6			1.4		--			50.0
Total costs and expenses		7,959.1			7,893.9			(4,389.6	)		11,463.4			1.4		--			11,464.8
Equity in income of unconsolidated affiliates		762.5			94.4			(784.6	)		72.3			692.5		(692.5	)		72.3
Operating income		924.9			798.7			(784.5	)		939.1			691.1		(692.5	)		937.7
Other income (expense):
Interest expense		(229.2	)		(0.6	)		--			(229.8	)		--		--			(229.8	)
Other, net		0.2			(1.2	)		--			(1.0	)		--		--			(1.0	)
Total other expense, net		(229.0	)		(1.8	)		--			(230.8	)		--		--			(230.8	)
Income before income taxes		695.9			796.9			(784.5	)		708.3			691.1		(692.5	)		706.9
Provision for income taxes		(4.0	)		(2.8	)		--			(6.8	)		--		(0.9	)		(7.7	)
Net income		691.9			794.1			(784.5	)		701.5			691.1		(693.4	)		699.2
Net loss (income) attributable to noncontrolling interests		--			0.1			(9.5	)		(9.4	)		--		1.3			(8.1	)
Net income attributable to entity	$	691.9		$	794.2		$	(794.0	)	$	692.1		$	691.1	$	(692.1	)	$	691.1

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	7,070.3		$	8,588.4		$	(3,565.4	)	$	12,093.3		$	--	$	--		$	12,093.3
Costs and expenses:
Operating costs and expenses		6,858.0			7,980.9			(3,565.4	)		11,273.5			--		--			11,273.5
General and administrative costs		7.6			36.0			--			43.6			0.3		--			43.9
Total costs and expenses		6,865.6			8,016.9			(3,565.4	)		11,317.1			0.3		--			11,317.4
Equity in income of unconsolidated affiliates		577.2			47.8			(581.0	)		44.0			592.3		(592.3	)		44.0
Operating income		781.9			619.3			(581.0	)		820.2			592.0		(592.3	)		819.9
Other income (expense):
Interest expense		(208.0	)		(0.3	)		--			(208.3	)		--		--			(208.3	)
Other, net		0.1			0.5			--			0.6			--		--			0.6
Total other expense, net		(207.9	)		0.2			--			(207.7	)		--		--			(207.7	)
Income before income taxes		574.0			619.5			(581.0	)		612.5			592.0		(592.3	)		612.2
Provision for income taxes		17.7			(36.8	)		--			(19.1	)		--		(0.3	)		(19.4	)
Net income		591.7			582.7			(581.0	)		593.4			592.0		(592.6	)		592.8
Net income attributable to noncontrolling interests		--			(0.2	)		(1.6	)		(1.8	)		--		1.0			(0.8	)
Net income attributable to entity	$	591.7		$	582.5		$	(582.6	)	$	591.6		$	592.0	$	(591.6	)	$	592.0

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	25,190.1		$	25,859.9		$	(13,289.1	)	$	37,760.9		$	--	$	--		$	37,760.9
Costs and expenses:
Operating costs and expenses		24,516.6			23,707.6			(13,289.8	)		34,934.4			--		--			34,934.4
General and administrative costs		23.1			126.0			--			149.1			1.8		--			150.9
Total costs and expenses		24,539.7			23,833.6			(13,289.8	)		35,083.5			1.8		--			35,085.3
Equity in income of unconsolidated affiliates		2,169.5			256.1			(2,246.5	)		179.1			2,129.4		(2,129.4	)		179.1
Operating income		2,819.9			2,282.4			(2,245.8	)		2,856.5			2,127.6		(2,129.4	)		2,854.7
Other income (expense):
Interest expense		(678.6	)		(1.0	)		--			(679.6	)		--		--			(679.6	)
Other, net		0.7			(0.9	)		--			(0.2	)		--		--			(0.2	)
Total other expense, net		(677.9	)		(1.9	)		--			(679.8	)		--		--			(679.8	)
Income before income taxes		2,142.0			2,280.5			(2,245.8	)		2,176.7			2,127.6		(2,129.4	)		2,174.9
Provision for income taxes		(15.5	)		(5.8	)		0.2			(21.1	)		--		(1.4	)		(22.5	)
Net income		2,126.5			2,274.7			(2,245.6	)		2,155.6			2,127.6		(2,130.8	)		2,152.4
Net loss (income) attributable to noncontrolling interests		--			0.2			(28.8	)		(28.6	)		--		3.8			(24.8	)
Net income attributable to entity	$	2,126.5		$	2,274.9		$	(2,274.4	)	$	2,127.0		$	2,127.6	$	(2,127.0	)	$	2,127.6

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	20,916.8		$	24,044.5		$	(10,335.6	)	$	34,625.7		$	--	$	--		$	34,625.7
Costs and expenses:
Operating costs and expenses		20,328.5			22,068.2			(10,335.6	)		32,061.1			--		--			32,061.1
General and administrative costs		19.7			118.0			--			137.7			1.2		--			138.9
Total costs and expenses		20,348.2			22,186.2			(10,335.6	)		32,198.8			1.2		--			32,200.0
Equity in income of unconsolidated affiliates		1,936.2			141.9			(1,952.0	)		126.1			1,899.2		(1,899.2	)		126.1
Operating income		2,504.8			2,000.2			(1,952.0	)		2,553.0			1,898.0		(1,899.2	)		2,551.8
Other income (expense):
Interest expense		(603.0	)		(1.4	)		--			(604.4	)		--		--			(604.4	)
Other, net		0.3			(0.1	)		--			0.2			--		--			0.2
Total other expense, net		(602.7	)		(1.5	)		--			(604.2	)		--		--			(604.2	)
Income before income taxes		1,902.1			1,998.7			(1,952.0	)		1,948.8			1,898.0		(1,899.2	)		1,947.6
Provision for income taxes		(4.9	)		(40.7	)		--			(45.6	)		--		(0.6	)		(46.2	)
Net income		1,897.2			1,958.0			(1,952.0	)		1,903.2			1,898.0		(1,899.8	)		1,901.4
Net income attributable to noncontrolling interests		--			(1.1	)		(4.9	)		(6.0	)		--		2.6			(3.4	)
Net income attributable to entity	$	1,897.2		$	1,956.9		$	(1,956.9	)	$	1,897.2		$	1,898.0	$	(1,897.2	)	$	1,898.0

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	708.9		$	825.2		$	(784.5	)		$	749.6			$	739.2		$	(741.5	)		$	747.3
Comprehensive loss (income) attributable to noncontrolling interests			--			0.1			(9.5	)			(9.4	)			--			1.3				(8.1	)
Comprehensive income attributable to entity		$	708.9		$	825.3		$	(794.0	)		$	740.2			$	739.2		$	(740.2	)		$	739.2

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)				EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	583.4		$	604.7			$	(580.9	)		$	607.2			$	605.7		$	(606.4	)		$	606.5
Comprehensive income attributable to noncontrolling interests			--			(0.2	)			(1.6	)			(1.8	)			--			1.0				(0.8	)
Comprehensive income attributable to entity		$	583.4		$	604.5			$	(582.5	)		$	605.4			$	605.7		$	(605.4	)		$	605.7

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	2,161.8		$	2,292.2		$	(2,245.5	)		$	2,208.5			$	2,180.5		$	(2,183.7	)		$	2,205.3
Comprehensive loss (income) attributable to noncontrolling interests			--			0.2			(28.8	)			(28.6	)			--			3.8				(24.8	)
Comprehensive income attributable to entity		$	2,161.8		$	2,292.4		$	(2,274.3	)		$	2,179.9			$	2,180.5		$	(2,179.9	)		$	2,180.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)				EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	1,911.5		$	1,964.7			$	(1,951.9	)		$	1,924.3			$	1,919.1		$	(1,920.9	)		$	1,922.5
Comprehensive income attributable to noncontrolling interests			--			(1.1	)			(4.9	)			(6.0	)			--			2.6				(3.4	)
Comprehensive income attributable to entity		$	1,911.5		$	1,963.6			$	(1,956.8	)		$	1,918.3			$	1,919.1		$	(1,918.3	)		$	1,919.1

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	2,126.5		$	2,274.7		$	(2,245.6	)	$	2,155.6		$	2,127.6		$	(2,130.8	)	$	2,152.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		114.3			878.5			(0.4	)		992.4			--			--			992.4
Equity in income of unconsolidated affiliates		(2,169.5	)		(256.1	)		2,246.5			(179.1	)		(2,129.4	)		2,129.4			(179.1	)
Distributions received from unconsolidated affiliates		3,475.8			229.0			(3,444.1	)		260.7			2,007.4			(2,007.4	)		260.7
Net effect of changes in operating accounts and other operating activities		(764.6	)		230.1			16.7			(517.8	)		(5.6	)		1.4			(522.0	)
Net cash flows provided by operating activities		2,782.5			3,356.2			(3,426.9	)		2,711.8			2,000.0			(2,007.4	)		2,704.4
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(329.1	)		(1,530.4	)		--			(1,859.5	)		--			--			(1,859.5	)
Proceeds from asset sales and insurance recoveries		4.2			117.3			--			121.5			--			--			121.5
Other investing activities		(2,059.3	)		(526.9	)		2,056.1			(530.1	)		(300.7	)		300.7			(530.1	)
Cash used in investing activities		(2,384.2	)		(1,940.0	)		2,056.1			(2,268.1	)		(300.7	)		300.7			(2,268.1	)
Financing activities:
Borrowings under debt agreements		7,167.5			--			--			7,167.5			--			--			7,167.5
Repayments of debt		(4,856.3	)		--			--			(4,856.3	)		--			--			(4,856.3	)
Cash distributions paid to partners		(2,007.4	)		(3,473.6	)		3,473.6			(2,007.4	)		(1,948.2	)		2,007.4			(1,948.2	)
Cash payments made in connection with DERs		--			--			--			--			(2.4	)		--			(2.4	)
Cash distributions paid to noncontrolling interests		--			--			(29.4	)		(29.4	)		--			--			(29.4	)
Cash contributions from noncontrolling interests		--			--			4.0			4.0			--			--			4.0
Net cash proceeds from issuance of common units		--			--			--			--			304.9			--			304.9
Cash contributions from owners		300.7			2,060.0			(2,060.0	)		300.7			--			(300.7	)		--
Other financing activities		(18.1	)		--			--			(18.1	)		(53.6	)		--			(71.7	)
Cash provided by (used in) financing activities		586.4			(1,413.6	)		1,388.2			561.0			(1,699.3	)		1,706.7			568.4
Net change in cash and cash equivalents		984.7			2.6			17.4			1,004.7			--			--			1,004.7
Cash and cash equivalents, January 1		28.4			49.5			(21.0	)		56.9			--			--			56.9
Cash and cash equivalents, September 30	$	1,013.1		$	52.1		$	(3.6	)	$	1,061.6		$	--		$	--		$	1,061.6

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	1,897.2		$	1,958.0		$	(1,952.0	)	$	1,903.2		$	1,898.0		$	(1,899.8	)	$	1,901.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		105.3			797.0			--			902.3			--			--			902.3
Equity in income of unconsolidated affiliates		(1,936.2	)		(141.9	)		1,952.0			(126.1	)		(1,899.2	)		1,899.2			(126.1	)
Distributions received from unconsolidated affiliates		3,421.1			180.7			(3,414.2	)		187.6			1,830.9			(1,830.9	)		187.6
Net effect of changes in operating accounts and other operating activities		(1,371.4	)		889.7			(11.0	)		(492.7	)		(6.6	)		0.3			(499.0	)
Net cash flows provided by operating activities		2,116.0			3,683.5			(3,425.2	)		2,374.3			1,823.1			(1,831.2	)		2,366.2
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(292.1	)		(2,101.2	)		--			(2,393.3	)		--			--			(2,393.3	)
Proceeds from asset sales and insurance recoveries		57.5			198.8			--			256.3			--			--			256.3
Other investing activities		(2,366.7	)		(485.6	)		2,051.8			(800.5	)		(1,135.2	)		1,135.2			(800.5	)
Cash used in investing activities		(2,601.3	)		(2,388.0	)		2,051.8			(2,937.5	)		(1,135.2	)		1,135.2			(2,937.5	)
Financing activities:
Borrowings under debt agreements		10,139.2			--			--			10,139.2			--			--			10,139.2
Repayments of debt		(8,761.7	)		(29.9	)		--			(8,791.6	)		--			--			(8,791.6	)
Cash distributions paid to partners		(1,831.2	)		(3,420.6	)		3,420.6			(1,831.2	)		(1,778.3	)		1,831.2			(1,778.3	)
Cash distributions paid to noncontrolling interests		--			--			(6.4	)		(6.4	)		--			--			(6.4	)
Cash contributions from noncontrolling interests		--			--			104.2			104.2			--			--			104.2
Net cash proceeds from issuance of common units		--			--			--			--			1,134.7			--			1,134.7
Cash contributions from owners		1,135.2			2,155.9			(2,155.9	)		1,135.2			--			(1,135.2	)		--
Other financing activities		(192.6	)		0.1			--			(192.5	)		(44.5	)		--			(237.0	)
Cash provided by (used in) financing activities		488.9			(1,294.5	)		1,362.5			556.9			(688.1	)		696.0			564.8
Net change in cash and cash equivalents		3.6			1.0			(10.9	)		(6.3	)		(0.2	)		--			(6.5	)
Cash and cash equivalents, January 1		--			28.0			(12.1	)		15.9			0.2			--			16.1
Cash and cash equivalents, September 30	$	3.6		$	29.0		$	(23.0	)	$	9.6		$	--		$	--		$	9.6

Subsequent Event	9 Months Ended
Subsequent Event	Sep. 30, 2014
Subsequent Event [Abstract]
Subsequent Event	Note 18. Subsequent Events Acquisition of Oiltanking's General Partner and 65.9% of Oiltanking's Limited Partner Interests; Enterprise Proposes Merger of Oiltanking On October 1, 2014, we announced our acquisition of the general partner and related incentive distribution rights, 15,899,802 common units and 38,899,802 subordinated units of Oiltanking Partners, L.P. ("Oiltanking") from Oiltanking Holding Americas, Inc. and its affiliates (collectively, "OTA"). We paid total consideration of approximately $4.41 billion to OTA comprised of $2.21 billion in cash and 54,807,352 of our common units. We also paid $228 million to acquire from OTA outstanding loans payable by Oiltanking or its subsidiaries. Collectively, these transactions are referred to as "Step 1" of the Oiltanking acquisition. Oiltanking owns marine terminals located on the Houston Ship Channel and at the Port of Beaumont with a total of 12 ship and barge docks and approximately 24 MMBbls of crude oil and petroleum products storage capacity. Oiltanking's marine terminal on the Houston Ship Channel is connected by pipeline to our Mont Belvieu complex and is integral to our growing LPG export, octane enhancement and propylene businesses. Our Enterprise Crude Houston ("ECHO") facilities are also connected to Oiltanking's system. We funded the cash consideration for Step 1 using borrowings under our new $1.5 billion 364-Day Credit Agreement (see Note 9), borrowings under our commercial paper program and cash on hand. As a second step of the Oiltanking acquisition, we submitted a proposal to the conflicts committee of the general partner of Oiltanking to merge Oiltanking with a wholly owned subsidiary of ours (the "Proposed Merger"). Under the terms of the Proposed Merger, we would exchange 1.23 Enterprise common units for each Oiltanking common unit outstanding. The proposed consideration, valued at approximately $1.4 billion as of the offer date, represents an at-the-market value for Oiltanking common units based upon the volume weighted average trading prices of both Oiltanking and Enterprise common units on September 30, 2014. As a result, the total consideration for Step 1 of the Oiltanking acquisition and the Proposed Merger would approximate $6.0 billion. The terms of the Proposed Merger are subject to negotiation, review and approval by the board of directors of our general partner and the conflicts committee of the board of directors of the general partner of Oiltanking. The Proposed Merger will also be subject to approval by holders of Oiltanking common units in accordance with the Oiltanking partnership agreement. We cannot predict whether the terms of a potential combination will be agreed upon by the conflicts committee of the board of directors of the general partner of Oiltanking or the board of directors of our general partner. Upon payment of Oiltanking's distribution with respect to the third quarter of 2014, which is expected to be paid in mid-November 2014, the subordination period with respect to the Oiltanking subordinated units will end. At that time, the subordinated units we now own will convert into common units on a one-for-one basis. Upon conversion, we will own 54,799,604 Oiltanking common units, or approximately 65.9% of its outstanding common units. In order to fund the equity consideration paid in Step 1, we issued 54,807,352 common units to OTA on October 1, 2014 in a transaction exempt from the registration requirements of the Securities Act of 1933, as amended (the "Securities Act"), pursuant to Section 4(a)(2) thereof, and we granted OTA registration rights with respect to these common units under a Registration Rights Agreement between us and OTA (the "Registration Rights Agreement"). The Registration Rights Agreement provides that, subject to the terms and conditions set forth therein, at any time after the earlier of (i) 90 days after October 1, 2014 and (ii) the execution of definitive agreements to acquire (through merger or otherwise) all or substantially all of the Oiltanking common units not owned by Enterprise or its affiliates, OTA may request that we prepare and file a registration statement to permit and otherwise facilitate the public resale of all or a portion of the 54,807,352 Enterprise common units that OTA owns. Our obligation to OTA to effect such transactions is limited to five registration statements and underwritten offerings. In connection with the Step 1 transaction, we entered into a Liquidity Option Agreement (the "Liquidity Option Agreement") with Marquard & Bahls, an affiliate of OTA ("M&B"). Pursuant to the Liquidity Option Agreement, we granted M&B the option (the "Liquidity Option") to sell to us 100% of the issued and outstanding capital stock of OTA (the "Option Securities"). The Liquidity Option may be exercised at any time within a 90-day period commencing on February 1, 2020. Pursuant to the Liquidity Option Agreement, the aggregate consideration to be paid by us for the Option Securities pursuant to the Liquidity Option would equal to 100% of the then-current fair market value of the OTA-owned Enterprise common units at the closing of the transactions contemplated under the Liquidity Option Agreement. The fair market value would be determined by multiplying the number of our common units owned by OTA at the time of exercise by the volume-weighted sales price per unit of our common units as reported by the New York Stock Exchange (or other national securities exchange, as applicable) for the ten (10) consecutive trading days preceding the exercise. We may pay this consideration in all cash, all common units, or in any mix of cash or units, as determined solely by us. If a defined "Trigger Event" occurs, the Liquidity Option may be exercised earlier within a 135-day period following notice of such event. Pursuant to the Liquidity Option Agreement, a "Trigger Event" means: (i) any transaction, event, circumstance, condition or state of facts by which our common units (or any other reference security) cease to be "regularly traded" within the meaning of Section 897 of the U.S. Internal Revenue Code (the "Code") and the Treasury Regulations thereunder; (ii) any transaction, event, circumstance, condition or state of facts by which OTA becomes the owner, for purposes of Section 897 of the Code, of our common units (or any other reference security) representing more than 5% of our outstanding common units (or such reference securities) other than as a result solely of the acquisition of our common units or other reference securities by OTA, M&B or any affiliate after the date of the Liquidity Option Agreement; or (iii) any "Enterprise Tax Event" as defined in the agreement, which includes certain events in which OTA would recognize taxable gain on the common units owned by OTA. The aggregate consideration to be paid by us for the Option Securities in connection with a Trigger Event exercise will be payable solely in cash, determined in the same manner as the price otherwise payable upon the exercise of the Liquidity Option. The Liquidity Option Agreement contains indemnification by M&B for certain specified liabilities of OTA following the closing of any exercise of the Liquidity Option, and certain conditions to closing. OTA is wholly owned by an affiliate of Oiltanking GmbH, an independent storage provider for crude oil, refined products, liquid chemicals and gases. Dr. Christian Flach, managing director of Oiltanking GmbH and former chairman of the board of Oiltanking, has been named as a director of our general partner. As a result of our acquisition of the general partner of Oiltanking, we began consolidating the financial statements of Oiltanking and its general partner on October 1, 2014. Prior to completion of the Proposed Merger, Oiltanking will also continue to file its periodic reports with the SEC. In October 2014, EPCO amended the ASA to add Oiltanking and its general partner to the agreement. These new subsidiaries are entitled to receive services from EPCO on the same terms as services are being provided to us. Issuance of $2.75 Billion of Senior Notes in October 2014 On October 14, 2014, EPO issued $800 million in principal amount of 2.55% senior notes due October 2019 ("Senior Notes LL"), $1.15 billion in principal amount of 3.75% senior notes due February 2025 ("Senior Notes MM") and $400 million in principal amount of 4.95% senior notes due October 2054 ("Senior Notes NN"). Senior Notes LL, MM and NN were issued at 99.981%, 99.681% and 98.356% of their principal amounts, respectively. EPO also issued an additional $400 million in principal amount of its 4.85% Senior Notes II due March 2044. The additional Senior Notes II were issued at 100.836% of their principal amount. Net proceeds from the issuance of these senior notes of $2.73 billion were used as follows: (i) to repay debt principal amounts outstanding under EPO's 364-Day Credit Agreement and commercial paper program (both of which were used to partially fund the cash consideration paid in Step 1 of the Oiltanking acquisition), (ii) to repay $650.0 million in principal amount of Senior Notes G that matured in October 2014, and (iii) for general company purposes. Enterprise Products Partners L.P. has unconditionally guaranteed these senior notes on an unsecured and unsubordinated basis. These senior notes rank equal with EPO's existing and future unsecured and unsubordinated indebtedness and are senior to any existing and future subordinated indebtedness of EPO. These senior notes are subject to make-whole redemption rights and were issued under indentures containing certain covenants, which generally restrict EPO's ability (with certain exceptions) to incur debt secured by liens and engage in sale and leaseback transactions.

General Accounting Matters (Policies)	9 Months Ended
General Accounting Matters (Policies)	Sep. 30, 2014
General Accounting Matters [Abstract]
Contingencies	Contingencies Certain conditions may exist as of the date our consolidated financial statements are issued, which may result in a loss to us but which will only be resolved when one or more future events occur or fail to occur. Management has regular quarterly litigation reviews, including updates from legal counsel, to assess the need for accounting recognition or disclosure of these contingencies, and such assessment inherently involves an exercise in judgment. In assessing loss contingencies related to legal proceedings that are pending against us or unasserted claims that may result in such proceedings, our management and legal counsel evaluate the perceived merits of any legal proceedings or unasserted claims as well as the perceived merits of the amount of relief sought or expected to be sought therein. We accrue an undiscounted liability for those contingencies where the incurrence of a loss is probable and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum of the range is accrued. We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when it is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material, we disclose the nature of the contingency and, if feasible, an estimate of the possible loss or range of loss. Loss contingencies considered remote are generally not disclosed unless they involve guarantees, in which case the guarantees would be disclosed. See Note 14 for additional information regarding our contingencies.
Derivative Instruments	Derivative Instruments We use derivative instruments such as futures, swaps, options, forward contracts and other arrangements to manage price risks associated with inventories, firm commitments, interest rates, foreign currencies and certain anticipated future commodity transactions. To qualify for hedge accounting, the hedged item must expose us to risk and the related derivative instrument must reduce the exposure to that risk and meet specific hedge documentation requirements related to designation dates, expectations for hedge effectiveness and the probability that hedged future transactions will occur as forecasted. We formally designate derivative instruments as hedges and document and assess their effectiveness at inception of the hedge and on a monthly basis thereafter. Forecasted transactions are evaluated for the probability of occurrence and are periodically back-tested once the forecasted period has passed to determine whether similarly forecasted transactions are probable of occurring in the future. For certain physical forward commodity derivative contracts, we apply the normal purchase/normal sale exception, whereby changes in the mark-to-market values of such contracts are not recognized in income. As a result, the revenues and expenses associated with such physical transactions are recognized during the period when volumes are physically delivered or received. Physical forward commodity contracts subject to this exception are evaluated for the probability of future delivery and are periodically back-tested once the forecasted period has passed to determine whether similar forward contracts are probable of physical delivery in the future. See Note 4 for additional information regarding our derivative instruments.
Estimates	Estimates Preparing our consolidated financial statements in conformity with U.S. GAAP requires us to make estimates that affect amounts presented in the financial statements. Our most significant estimates relate to (i) the useful lives and depreciation/amortization methods used for fixed and identifiable intangible assets; (ii) measurement of fair value and projections used in impairment testing of fixed and intangible assets (including goodwill); (iii) contingencies; and (iv) revenue and expense accruals. Actual results could differ materially from our estimates. On an ongoing basis, we review our estimates based on currently available information. Any changes in the facts and circumstances underlying our estimates may require us to update such estimates, which could have a material impact on our consolidated financial statements.
Restricted Cash	Restricted Cash Restricted cash represents amounts held in segregated bank accounts by our clearing brokers as margin in support of our commodity derivative instruments portfolio and related physical purchases and sales of natural gas, crude oil, refined products and NGLs. Additional cash may be restricted to maintain our commodity derivative instruments portfolio as prices fluctuate or deposit requirements change. At September 30, 2014 and December 31, 2013, our restricted cash amounts were $6.6 million and $65.6 million, respectively. See Note 4 for information regarding our derivative instruments and hedging activities.

Entity's cash and cash equivalents accounting policy with respect to restricted balances. Restrictions may include legally restricted deposits held as compensating balances against short-term borrowing arrangements, contracts entered into with others, or company statements of intention with regard to particular deposits; however, time deposits and short-term certificates of deposit are not generally included in legally restricted deposits.

Disclosure of accounting policy for its derivative instruments and hedging activities.

Equity-based Award Expense

Equity-based Awards (Tables)

9 Months Ended

Sep. 30, 2014

Equity-based Awards [Abstract]

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Equity-classified awards:
Restricted common unit awards		$	8.7		$	17.8		$	29.3		$	52.7
Unit option awards			--			0.1			--			0.7
Phantom unit awards			12.9			--			32.3			--
Liability-classified awards			0.1			0.1			0.4			0.4
Total		$	21.7		$	18.0		$	62.0		$	53.8

Restricted Common Unit Awards

The following table presents information regarding restricted common unit awards for the period indicated:

	Number of Units			Weighted- Average Grant Date Fair Value per Unit (1)
Restricted common units at December 31, 2013		7,221,214		$	25.83
Vested		(2,586,398	)	$	23.92
Forfeited		(267,200	)	$	26.36
Restricted common units at September 30, 2014		4,367,616		$	26.93

(1) Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.

Cash Distributions and Total Intrinsic Value of Restricted Common Unit Awards

The following table presents supplemental information regarding our restricted common unit awards for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Cash distributions paid to restricted common unitholders		$	1.6		$	2.6		$	5.7		$	8.2
Total intrinsic value of restricted common unit awards that vested during period		$	1.3		$	1.0		$	85.4		$	107.4

Unit Option Awards

The following table presents unit option award activity for the period indicated:

	Number of Units (2)			Weighted- Average Strike Price (dollars/unit)		Weighted- Average Remaining Contractual Term (in years)		Aggregate Intrinsic Value (1)
Unit option awards at December 31, 2013		4,050,000		$	13.24		1.3	$	57.0
Exercised		(2,720,000	)	$	11.83
Forfeited		(60,000	)	$	16.14
Unit option awards at September 30, 2014		1,270,000		$	16.14		1.3	$	30.7

(1) Aggregate intrinsic value reflects fully vested unit option awards at the dates indicated.
(2) None of the unit option awards outstanding at September 30, 2014 and December 31, 2013 were exercisable as of such dates, respectively.

Supplemental Information Regarding Unit Option Awards

The following table presents supplemental information regarding unit option awards during the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Total intrinsic value of unit option awards exercised during period		$	--		$	--		$	57.5		$	19.8
Cash received from EPCO in connection with the exercise of unit option awards			--			--			33.4			11.5
Unit option award-related cash reimbursements to EPCO			--			--			57.5			19.8

Phantom Unit Awards

The following table presents phantom unit award activity for the period indicated:

	Number of Units			Weighted- Average Grant Date Fair Value per Unit (1)
Phantom unit awards at December 31, 2013		--		$	--
Granted (2)		3,522,990		$	33.12
Vested		(34,800	)	$	33.04
Forfeited		(92,800	)	$	33.04
Phantom unit awards at September 30, 2014		3,395,390		$	33.12

(1) Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.
(2) The aggregate grant date fair value of phantom unit awards issued during 2014 was $116.7 million based on a grant date market price of our common units ranging from $33.04 to $37.59 per unit. An estimated annual forfeiture rate of 3.4% was applied to these awards.

Cash Distributions and Total Intrinsic Value of Phantom Unit Awards

The following table presents supplemental information regarding our phantom unit awards and DERs for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Cash payments made in connection with DERs		$	1.2		$	--		$	2.4		$	--
Total intrinsic value of phantom unit awards that vested during period		$	0.1		$	--		$	1.3		$	--

Derivative Instruments, Hedging Activities and Fair Value Measurements (Tables)

9 Months Ended

Sep. 30, 2014

Derivative Instruments, Hedging Activities and Fair Value Measurements [Abstract]

Hedging Instruments Under the FASB's Derivative and Hedging Guidance

Hedged Transaction	Number and Type of Derivatives Outstanding	Notional Amount				Period of Hedge	Rate Swap	Accounting Treatment
Senior Notes AA	10 fixed-to-floating swaps		$	750.0		1/2011 to 2/2016	3.2% to 1.2%	Fair value hedge

	Volume (1)		Accounting
Derivative Purpose	Current (2)	Long-Term (2)	Treatment
Derivatives designated as hedging instruments:
Natural gas processing:
Forecasted natural gas purchases for plant thermal reduction (Bcf)	1.1	n/a	Cash flow hedge
Forecasted sales of NGLs (MMBbls) (3)	0.3	n/a	Cash flow hedge
Octane enhancement:
Forecasted purchases of NGLs (MMBbls)	0.3	n/a	Cash flow hedge
Forecasted sales of octane enhancement products (MMBbls)	0.2	n/a	Cash flow hedge
Natural gas marketing:
Forecasted sales of natural gas (Bcf)	1.7	n/a	Cash flow hedge
Natural gas storage inventory management activities (Bcf)	5.1	n/a	Fair value hedge
NGL marketing:
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)	5.2	0.1	Cash flow hedge
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)	8.8	n/a	Cash flow hedge
Refined products marketing:
Forecasted purchases of refined products (MMBbls)	0.7	n/a	Cash flow hedge
Forecasted sales of refined products (MMBbls)	1.3	n/a	Cash flow hedge
Crude oil marketing:
Forecasted purchases of crude oil (MMBbls)	5.0	0.5	Cash flow hedge
Forecasted sales of crude oil (MMBbls)	7.0	0.5	Cash flow hedge
Derivatives not designated as hedging instruments:
Natural gas risk management activities (Bcf) (4,5)	63.5	15.3	Mark-to-market
Crude oil risk management activities (MMBbls) (5)	6.7	n/a	Mark-to-market

(1) Volume for derivatives designated as hedging instruments reflects the total amount of volumes hedged whereas volume for derivatives not designated as hedging instruments reflects the absolute value of derivative notional volumes.
(2) The maximum term for derivatives designated as cash flow hedges, derivatives designated as fair value hedges and derivatives not designated as hedging instruments is December 2015, October 2015 and March 2018, respectively.
(3) Forecasted sales of NGL volumes under natural gas processing exclude 0.3 MMBbls of additional hedges executed under contracts that have been designated as normal sales agreements.
(4) Current and long-term volumes include 28.9 Bcf and 0.9 Bcf, respectively, of physical derivative instruments that are predominantly priced at a marked-based index plus a premium or minus a discount related to location differences.
(5) Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.

Derivative Assets and Liabilities Balance Sheet

The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated:

	Asset Derivatives						Liability Derivatives
	September 30, 2014			December 31, 2013			September 30, 2014			December 31, 2013
	Balance Sheet Location	Fair Value		Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
Derivatives designated as hedging instruments
Interest rate derivatives	Other current assets	$	15.9	Other current assets	$	20.2	Other current liabilities	$	--	Other current liabilities	$	--
Interest rate derivatives	Other assets		3.5	Other assets		12.4	Other liabilities		--	Other liabilities		--
Total interest rate derivatives			19.4			32.6			--			--
Commodity derivatives	Other current assets		38.1	Other current assets		30.9	Other current liabilities		19.5	Other current liabilities		46.5
Commodity derivatives	Other assets		1.2	Other assets		--	Other liabilities		1.4	Other liabilities		0.3
Total commodity derivatives			39.3			30.9			20.9			46.8
Total derivatives designated as hedging instruments		$	58.7		$	63.5		$	20.9		$	46.8

Derivatives not designated as hedging instruments
Interest rate derivatives	Other current assets	$	--	Other current assets	$	--	Other current liabilities	$	--	Other current liabilities	$	7.8
Interest rate derivatives	Other assets		--	Other assets		--	Other liabilities		--	Other liabilities		--
Total interest rate derivatives			--			--			--			7.8
Commodity derivatives	Other current assets		1.4	Other current assets		7.6	Other current liabilities		0.8	Other current liabilities		5.5
Commodity derivatives	Other assets		1.0	Other assets		2.8	Other liabilities		0.3	Other liabilities		2.8
Total commodity derivatives			2.4			10.4			1.1			8.3
Total derivatives not designated as hedging instruments		$	2.4		$	10.4		$	1.1		$	16.1

Offsetting Financial Assets

	Offsetting of Financial Assets and Derivative Assets
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received				Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of September 30, 2014:
Interest rate derivatives		$	19.4		$	--		$	19.4		$	--			$	--			$	19.4
Commodity derivatives			41.7			--			41.7			(24.8	)			(16.9	)			--
As of December 31, 2013:
Interest rate derivatives		$	32.6		$	--		$	32.6		$	(2.6	)		$	--			$	30.0
Commodity derivatives			41.3			--			41.3			(41.0	)			--				0.3

Offsetting Financial Liabilities

	Offsetting of Financial Liabilities and Derivative Liabilities
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Financial Instruments				Cash Collateral Paid				Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of September 30, 2014:
Interest rate derivatives		$	--		$	--		$	--		$	--			$	--			$	--
Commodity derivatives			22.0			--			22.0			(24.8	)			7.8				5.0
As of December 31, 2013:
Interest rate derivatives		$	7.8		$	--		$	7.8		$	(2.6	)		$	--			$	5.2
Commodity derivatives			55.1			--			55.1			(41.0	)			(9.3	)			4.8

Derivative Instruments Effects on Statements of Operations

The following tables present the effect of our derivative instruments designated as fair value hedges on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended September 30,								For the Nine Months Ended September 30,
		2014				2013				2014				2013
Interest rate derivatives	Interest expense		$	(4.1	)		$	(0.5	)		$	(9.5	)		$	(10.6	)
Commodity derivatives	Revenue			(0.3	)			(3.1	)			0.6				3.1
Total			$	(4.4	)		$	(3.6	)		$	(8.9	)		$	(7.5	)

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Hedged Item
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014			2013				2014				2013
Interest rate derivatives	Interest expense		$	3.9		$	0.4			$	9.3			$	10.3
Commodity derivatives	Revenue			1.0			(0.4	)			(1.4	)			(12.0	)
Total			$	4.9		$	--			$	7.9			$	(1.7	)

Derivative Instruments Effects on Statements of Comprehensive Income

Derivatives in Cash Flow Hedging Relationships	Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)
	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014		2013
Interest rate derivatives	$	--		$	--		$	--	$	6.7
Commodity derivatives – Revenue (1)		58.8			(8.6	)		15.2		(22.1	)
Commodity derivatives – Operating costs and expenses (1)		(0.7	)		--			0.9		--
Total	$	58.1		$	(8.6	)	$	16.1	$	(15.4	)

(1) The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Gain/(Loss) Reclassified from Accumulated Other Comprehensive Income/(Loss) to Income (Effective Portion)

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)
		For the Three Months Ended September 30,								For the Nine Months Ended September 30,
		2014				2013				2014				2013
Interest rate derivatives	Interest expense		$	(8.0	)		$	(7.7	)		$	(23.9	)		$	(21.4	)
Commodity derivatives	Revenue			17.8				(14.6	)			(14.5	)			(15.1	)
Commodity derivatives	Operating costs and expenses			0.2				--				1.6				0.4
Total			$	10.0			$	(22.3	)		$	(36.8	)		$	(36.1	)

Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014				2013			2014			2013
Commodity derivatives	Revenue		$	0.1			$	0.1		$	--		$	--
Commodity derivatives	Operating costs and expenses			(0.1	)			--			--			--
Total			$	--			$	0.1		$	--		$	--

Gain/(Loss) Recognized in Income on Derivative

The following table presents the effect of our derivative instruments not designated as hedging instruments on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated:

Derivatives Not Designated as Hedging Instruments	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
		2014			2013				2014				2013
Interest rate derivatives	Interest expense		$	--		$	(0.5	)		$	(0.1	)		$	(0.6	)
Commodity derivatives	Revenue			0.8			8.1				(26.8	)			17.0
Total			$	0.8		$	7.6			$	(26.9	)		$	16.4

Fair Value Measurements of Financial Assets and Liabilities Measured on a Recurring Basis

	September 30, 2014 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	19.4	$	--	$	19.4
Commodity derivatives		14.4		24.4		2.9		41.7
Total	$	14.4	$	43.8	$	2.9	$	61.1

Financial liabilities:
Interest rate derivatives	$	--	$	--	$	--	$	--
Commodity derivatives		8.2		10.2		3.6		22.0
Total	$	8.2	$	10.2	$	3.6	$	22.0

	December 31, 2013 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	32.6	$	--	$	32.6
Commodity derivatives		17.2		20.2		3.9		41.3
Total	$	17.2	$	52.8	$	3.9	$	73.9

Financial liabilities:
Interest rate derivatives	$	--	$	7.8	$	--	$	7.8
Commodity derivatives		30.8		23.6		0.7		55.1
Total	$	30.8	$	31.4	$	0.7	$	62.9

Reconciliation of Changes in the Fair Value of Level 3 Financial Assets and Liabilities

The following table sets forth a reconciliation of changes in the fair values of our recurring Level 3 financial assets and liabilities on a combined basis for the periods indicated:

		For the Nine Months Ended September 30,
	Location	2014			2013
Financial asset (liability) balance, net, January 1		$	3.2		$	(1.5	)
Total gains (losses) included in:
Net income (1)	Revenue		4.6			(0.6	)
Settlements	Revenue		(0.1	)		1.5
Financial asset (liability) balance, net, March 31			7.7			(0.6	)
Total gains (losses) included in:
Net income (1)	Revenue		(3.3	)		(0.2	)
Settlements	Revenue		(1.8	)		0.6
Financial asset (liability) balance, net, June 30			2.6			(0.2	)
Total gains (losses) included in:
Net income (1)	Revenue		(0.9	)		1.1
Other comprehensive income	Commodity derivative instruments – changes in fair value of cash flow hedges		(2.5	)		(0.9	)
Settlements	Revenue		0.1			0.1
Financial asset (liability) balance, net, September 30 (2)		$	(0.7	)	$	0.1

(1) There were $0.8 million and $1.3 million of unrealized losses included in these amounts for the three and nine months ended September 30, 2014, respectively. There were unrealized gains of $1.1 million and $2.4 million included in these amounts for the three and nine months ended September 30, 2013, respectively.
(2) There were no transfers into or out of Level 3 during the three or nine months ended September 30, 2014 and 2013.

Fair Value Measurements, Valuation Techniques

The following table provides quantitative information about our recurring Level 3 fair value measurements at September 30, 2014:

	Fair Value
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	2.6	$	0.9	Discounted cash flow	Forward commodity prices	$70.32-$91.82/barrel
Commodity derivatives – Propane		--		0.1	Discounted cash flow	Forward commodity prices	$1.02-$1.05/gallon
Commodity derivatives – Natural gasoline		0.1		2.5	Discounted cash flow	Forward commodity prices	$1.84-$1.94/gallon
Commodity derivatives – Natural gas		0.2		0.1	Discounted cash flow	Forward commodity prices	$3.72-$4.54/MMBtu
Total	$	2.9	$	3.6

Noncash Impairment Charges by Segment

The following table summarizes our non-cash impairment charges by segment during each of the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	1.2	$	0.3	$	6.6	$	10.0
Onshore Natural Gas Pipelines & Services		0.4		--		0.7		--
Onshore Crude Oil Pipelines & Services		0.4		--		2.2		16.6
Offshore Pipelines & Services		--		13.2		--		13.2
Petrochemical & Refined Products Services		3.7		1.7		8.7		13.5
Total	$	5.7	$	15.2	$	18.2	$	53.3

Nonrecurring Fair Value Measurements

				Fair Value Measurements Using
	Carrying Value at September 30, 2014			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Non-Cash Impairment Loss
Impairment of long-lived assets disposed of other than by sale		$	--		$	--		$	--		$	--		$	11.7
Impairment of long-lived assets to be disposed of by sale			1.1			--			--			1.1			6.5
Total														$	18.2

			Fair Value Measurements Using
	Carrying Value at September 30, 2013		Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total Non-Cash Impairment Loss
Impairment of long-lived assets disposed of other than by sale	$	--	$	--	$	--	$	--	$	43.3
Impairment of long-lived assets held and used		6.1		--		--		6.1		4.2
Impairment of long-lived assets to be disposed of by sale		11.7		11.7		--		--		5.8
Total									$	53.3

Inventories (Tables)

9 Months Ended

Sep. 30, 2014

Inventories [Abstract]

Inventory Amounts by Product Type

Our inventory amounts by product type were as follows at the dates indicated:

	September 30, 2014		December 31, 2013
NGLs	$	973.4	$	593.8
Petrochemicals and refined products		338.7		395.1
Crude oil		238.8		42.6
Natural gas		38.6		61.6
Total	$	1,589.5	$	1,093.1

Cost of Sales and Lower of Cost or Market Adjustments

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
Cost of sales (1)	$	10,455.1	$	10,371.3	$	32,213.1	$	29,522.1
Lower of cost or market adjustments		6.7		4.5		14.6		14.9

(1) Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. Period-to-period fluctuations in these amounts are primarily due to changes in energy commodity prices and sales volumes associated with our marketing activities.

Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2014

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment and Accumulated Depreciation

The historical costs of our property, plant and equipment and related accumulated depreciation balances were as follows at the dates indicated:

	Estimated Useful Life in Years	September 30, 2014		December 31, 2013
Plants, pipelines and facilities (1)	3-45 (6)	$	30,096.7	$	27,540.4
Underground and other storage facilities (2)	5-40 (7)		2,164.9		2,101.8
Platforms and facilities (3)	20-31		659.7		659.6
Transportation equipment (4)	3-10		142.0		138.9
Marine vessels (5)	15-30		782.3		744.8
Land			185.0		176.6
Construction in progress			1,805.7		2,655.5
Total			35,836.3		34,017.6
Less accumulated depreciation			7,873.0		7,071.0
Property, plant and equipment, net		$	27,963.3	$	26,946.6

(1) Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; office furniture and equipment; buildings; laboratory and shop equipment and related assets.
(2) Underground and other storage facilities include underground product storage caverns; above ground storage tanks; water wells and related assets.
(3) Platforms and facilities include offshore platforms and related facilities and other associated assets located in the Gulf of Mexico.
(4) Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations.
(5) Marine vessels include tow boats, barges and related equipment used in our marine transportation business.
(6) In general, the estimated useful lives of major assets within this category are: processing plants, 20-35 years; pipelines and related equipment, 5-45 years; terminal facilities, 10-35 years; office furniture and equipment, 3-20 years; buildings, 20-40 years; and laboratory and shop equipment, 5-35 years.
(7) In general, the estimated useful lives of assets within this category are: underground storage facilities, 5-35 years; storage tanks, 10-40 years; and water wells, 5-35 years.

Depreciation Expense and Capitalized Interest

The following table summarizes our depreciation expense and capitalized interest amounts for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
Depreciation expense (1)	$	283.2	$	253.4	$	822.1	$	749.6
Capitalized interest (2)		17.2		27.8		53.4		95.1

(1) Depreciation expense is a component of "Costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations.
(2) We capitalize interest costs incurred on funds used to construct property, plant and equipment while the asset is in its construction phase. The capitalized interest is recorded as part of the asset to which it relates and is amortized over the asset's estimated useful life as a component of depreciation expense. When capitalized interest is recorded, it reduces interest expense from what it would be otherwise.

AROs

The following table presents information regarding our asset retirement obligations ("AROs") during the nine months ended September 30, 2014:

ARO liability balance, December 31, 2013	$	90.2
Liabilities incurred		0.1
Liabilities settled		(2.3	)
Revisions in estimated cash flows		2.7
Accretion expense		4.5
ARO liability balance, September 30, 2014	$	95.2

Forecasted Accretion Expense Associated with AROs

The following table presents our forecast of accretion expense for the periods indicated:

Remainder of 2014				2015				2016				2017				2018
	$	1.6			$	6.3			$	6.5			$	7.0			$	7.5

Investments in Unconsolidated Affiliates (Tables)

9 Months Ended

Sep. 30, 2014

Investments in Unconsolidated Affiliates [Abstract]

Investments in Unconsolidated Affiliates

The following table presents our investments in unconsolidated affiliates by business segment at the dates indicated. We account for these investments using the equity method.

	Ownership Interest at September 30, 2014	September 30, 2014		December 31, 2013
NGL Pipelines & Services:
Venice Energy Service Company, L.L.C.	13.1%	$	26.9	$	27.6
K/D/S Promix, L.L.C.	50%		46.1		45.4
Baton Rouge Fractionators LLC	32.2%		19.1		19.5
Skelly-Belvieu Pipeline Company, L.L.C.	50%		39.7		40.8
Texas Express Pipeline LLC	35%		348.4		339.9
Texas Express Gathering LLC	45%		37.8		37.8
Front Range Pipeline LLC	33.3%		167.8		134.5
Onshore Natural Gas Pipelines & Services:
White River Hub, LLC	50%		23.5		24.2
Onshore Crude Oil Pipelines & Services:
Seaway Crude Pipeline Company LLC	50%		1,372.2		940.7
Eagle Ford Pipeline LLC	50%		279.5		224.5
Offshore Pipelines & Services:
Poseidon Oil Pipeline Company, L.L.C. ("Poseidon")	36%		34.3		41.7
Cameron Highway Oil Pipeline Company	50%		204.2		207.7
Deepwater Gateway, L.L.C.	50%		81.1		84.5
Neptune Pipeline Company, L.L.C.	25.7%		35.4		38.7
Southeast Keathley Canyon Pipeline Company L.L.C.	50%		147.4		159.2
Petrochemical & Refined Products Services:
Baton Rouge Propylene Concentrator, LLC	30%		6.7		7.6
Centennial Pipeline LLC ("Centennial")	50%		65.6		60.1
Other	Various		2.6		2.7
Total		$	2,938.3	$	2,437.1

The following table presents our equity in income (loss) of unconsolidated affiliates by business segment for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
NGL Pipelines & Services	$	11.7		$	4.1		$	19.2		$	11.8
Onshore Natural Gas Pipelines & Services		0.9			1.0			2.7			2.9
Onshore Crude Oil Pipelines & Services		46.8			34.3			131.7			101.0
Offshore Pipelines & Services		17.1			9.8			35.8			24.9
Petrochemical & Refined Products Services		(4.2	)		(5.2	)		(10.3	)		(14.5	)
Total	$	72.3		$	44.0		$	179.1		$	126.1

The following table presents our unamortized excess cost amounts by business segment at the dates indicated:

	September 30, 2014		December 31, 2013
NGL Pipelines & Services	$	26.8	$	27.7
Onshore Crude Oil Pipelines & Services		17.3		17.8
Offshore Pipelines & Services		9.2		10.0
Petrochemical & Refined Products Services		2.5		2.6
Total	$	55.8	$	58.1

The following table presents our amortization of excess cost amounts by business segment for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	0.2	$	0.3	$	0.9	$	0.9
Onshore Crude Oil Pipelines & Services		0.2		0.1		0.5		0.5
Offshore Pipelines & Services		0.3		0.3		0.8		1.0
Petrochemical & Refined Products Services		--		0.1		0.1		0.1
Total	$	0.7	$	0.8	$	2.3	$	2.5

Intangible Assets and Goodwill (Tables)

9 Months Ended

Sep. 30, 2014

Intangible Assets and Goodwill [Abstract]

Intangible Assets by Segment

The following table summarizes our intangible assets by business segment at the dates indicated:

	September 30, 2014							December 31, 2013
	Gross Value		Accumulated Amortization			Carrying Value		Gross Value		Accumulated Amortization			Carrying Value
NGL Pipelines & Services:
Customer relationship intangibles	$	340.8	$	(179.0	)	$	161.8	$	340.8	$	(165.7	)	$	175.1
Contract-based intangibles		277.9		(175.1	)		102.8		281.3		(171.2	)		110.1
Segment total		618.7		(354.1	)		264.6		622.1		(336.9	)		285.2
Onshore Natural Gas Pipelines & Services:
Customer relationship intangibles		1,163.6		(302.3	)		861.3		1,163.6		(281.2	)		882.4
Contract-based intangibles		466.0		(343.7	)		122.3		466.1		(330.7	)		135.4
Segment total		1,629.6		(646.0	)		983.6		1,629.7		(611.9	)		1,017.8
Onshore Crude Oil Pipelines & Services:
Customer relationship intangibles		9.6		(6.1	)		3.5		10.7		(6.3	)		4.4
Contract-based intangibles		0.4		(0.3	)		0.1		0.4		(0.3	)		0.1
Segment total		10.0		(6.4	)		3.6		11.1		(6.6	)		4.5
Offshore Pipelines & Services:
Customer relationship intangibles		195.8		(152.6	)		43.2		203.9		(150.0	)		53.9
Contract-based intangibles		1.2		(0.5	)		0.7		1.2		(0.4	)		0.8
Segment total		197.0		(153.1	)		43.9		205.1		(150.4	)		54.7
Petrochemical & Refined Products Services:
Customer relationship intangibles		104.3		(42.1	)		62.2		104.3		(38.2	)		66.1
Contract-based intangibles		39.9		(6.7	)		33.2		39.9		(6.0	)		33.9
Segment total		144.2		(48.8	)		95.4		144.2		(44.2	)		100.0
Total all segments	$	2,599.5	$	(1,208.4	)	$	1,391.1	$	2,612.2	$	(1,150.0	)	$	1,462.2

Amortization Expense of Intangible Assets by Segment

The following table presents the amortization expense of our intangible assets by business segment for the periods indicated:

	For the Three Months Ended September 30,				For the Nine Months Ended September 30,
	2014		2013		2014		2013
NGL Pipelines & Services	$	8.1	$	8.6	$	25.4	$	27.7
Onshore Natural Gas Pipelines & Services		11.1		13.3		34.2		38.0
Onshore Crude Oil Pipelines & Services		0.3		0.3		0.9		1.0
Offshore Pipelines & Services		2.5		2.9		7.6		8.8
Petrochemical & Refined Products Services		1.5		1.5		4.6		4.7
Total	$	23.5	$	26.6	$	72.7	$	80.2

Forecasted Amortization Expense

The following table presents our forecast of amortization expense associated with existing intangible assets for the periods indicated:

Remainder of 2014				2015				2016				2017				2018
	$	22.2			$	86.0			$	81.6			$	86.1			$	89.5

Changes in Carrying Amount of Goodwill

	NGL Pipelines & Services		Onshore Natural Gas Pipelines & Services		Onshore Crude Oil Pipelines & Services		Offshore Pipelines & Services			Petrochemical & Refined Products Services			Consolidated Total
Balance at December 31, 2013 (1)	$	341.2	$	296.3	$	305.1	$	82.1		$	1,055.3		$	2,080.0
Reclassification of goodwill		520.0		--		--		--			(520.0	)		--
Goodwill related to the sale of assets		--		--		--		(0.1	)		--			(0.1	)
Balance at September 30, 2014 (1)	$	861.2	$	296.3	$	305.1	$	82.0		$	535.3		$	2,079.9

(1) The total carrying amount of goodwill at September 30, 2014 and December 31, 2013 is net of $1.3 million of accumulated impairment charges. No goodwill impairment charges were recorded during the nine months ended September 30, 2014.

Debt Obligations (Tables)

9 Months Ended

Sep. 30, 2014

Debt Obligations [Abstract]

Consolidated Debt Obligations

The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated:

	September 30, 2014			December 31, 2013
EPO senior debt obligations:
Commercial Paper Notes, fixed-rates (1)	$	1,290.0		$	475.0
Senior Notes O, 9.75% fixed-rate, due January 2014		--			500.0
Senior Notes G, 5.60% fixed-rate, due October 2014		650.0			650.0
Senior Notes I, 5.00% fixed-rate, due March 2015		250.0			250.0
Senior Notes X, 3.70% fixed-rate, due June 2015		400.0			400.0
Senior Notes FF, 1.25% fixed-rate, due August 2015		650.0			650.0
$1.5 Billion 364-Day Credit Agreement, variable-rate, due September 2015		--			--
Senior Notes AA, 3.20% fixed-rate, due February 2016		750.0			750.0
Senior Notes L, 6.30% fixed-rate, due September 2017		800.0			800.0
Senior Notes V, 6.65% fixed-rate, due April 2018		349.7			349.7
$3.5 Billion Multi-Year Revolving Credit Facility, variable-rate, due June 2018		--			--
Senior Notes N, 6.50% fixed-rate, due January 2019		700.0			700.0
Senior Notes Q, 5.25% fixed-rate, due January 2020		500.0			500.0
Senior Notes Y, 5.20% fixed-rate, due September 2020		1,000.0			1,000.0
Senior Notes CC, 4.05% fixed-rate, due February 2022		650.0			650.0
Senior Notes HH, 3.35% fixed-rate, due March 2023		1,250.0			1,250.0
Senior Notes JJ, 3.90% fixed-rate, due February 2024		850.0			--
Senior Notes D, 6.875% fixed-rate, due March 2033		500.0			500.0
Senior Notes H, 6.65% fixed-rate, due October 2034		350.0			350.0
Senior Notes J, 5.75% fixed-rate, due March 2035		250.0			250.0
Senior Notes W, 7.55% fixed-rate, due April 2038		399.6			399.6
Senior Notes R, 6.125% fixed-rate, due October 2039		600.0			600.0
Senior Notes Z, 6.45% fixed-rate, due September 2040		600.0			600.0
Senior Notes BB, 5.95% fixed-rate, due February 2041		750.0			750.0
Senior Notes DD, 5.70% fixed-rate, due February 2042		600.0			600.0
Senior Notes EE, 4.85% fixed-rate, due August 2042		750.0			750.0
Senior Notes GG, 4.45% fixed-rate, due February 2043		1,100.0			1,100.0
Senior Notes II, 4.85% fixed-rate, due March 2044		1,000.0			1,000.0
Senior Notes KK, 5.10% fixed-rate, due February 2045		1,150.0			--
TEPPCO senior debt obligations:
TEPPCO Senior Notes, 6.65% fixed-rate, due April 2018		0.3			0.3
TEPPCO Senior Notes, 7.55% fixed-rate, due April 2038		0.4			0.4
Total principal amount of senior debt obligations		18,140.0			15,825.0
EPO Junior Subordinated Notes A, fixed/variable-rate, due August 2066 (2)		550.0			550.0
EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 (3)		285.8			285.8
EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 (4)		682.7			682.7
TEPPCO Junior Subordinated Notes, fixed/variable-rate, due June 2067		14.2			14.2
Total principal amount of senior and junior debt obligations		19,672.7			17,357.7
Other, non-principal amounts		(26.3	)		(6.2	)
Less current maturities of debt (5)		(1,939.9	)		(1,125.0	)
Total long-term debt	$	17,706.5		$	16,226.5

(1) Principal amounts outstanding at September 30, 2014 have fixed rates ranging from 0.22% and 0.29% and are due in October 2014.
(2) Fixed rate of 8.375% through August 1, 2016; thereafter, variable rate based on 3-month LIBOR plus 3.7075%.
(3) Fixed rate of 7.0% through September 1, 2017; thereafter, variable rate based on 3-month LIBOR plus 2.7775%.
(4) Fixed rate of 7.034% through January 15, 2018; thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.68%.
(5) We expect to refinance the current maturities of our debt obligations at or prior to their maturity. Long-term and current maturities of debt reflect the classification of such obligations at September 30, 2014 after taking into consideration the long-term refinancing of Senior Notes G and $650 million of Commercial Paper Notes using proceeds from the issuance of senior notes in October 2014 (see Note 18).

Consolidated Debt Maturities

The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at September 30, 2014 for the next five years, and in total thereafter:

			Scheduled Maturities of Debt
	Total		Remainder of 2014		2015		2016		2017		2018		After 2018
Commercial Paper	$	1,290.0	$	1,290.0	$	--	$	--	$	--	$	--	$	--
Senior Notes		16,850.0		650.0		1,300.0		750.0		800.0		350.0		13,000.0
Junior Subordinated Notes		1,532.7		--		--		--		--		--		1,532.7
Total	$	19,672.7	$	1,940.0	$	1,300.0	$	750.0	$	800.0	$	350.0	$	14,532.7

Interest Rates and Weighted-Average Interest Rates Paid on Consolidated Variable-Rate Debt Obligations

The following table presents the range of interest rates and weighted-average interest rates paid on our consolidated variable-rate debt during the nine months ended September 30, 2014:

	Range of Interest Rates Paid	Weighted-Average Interest Rate Paid
EPO $3.5 Billion Multi-Year Revolving Credit Facility	1.13% to 1.14%	1.13%

Summary of Changes in Outstanding Units

Tabular disclosure of long-debt instruments or arrangements, including identification, terms, features, collateral requirements and other information necessary to a fair presentation. These are debt arrangements that originally required repayment more than twelve months after issuance or greater than the normal operating cycle of the entity, if longer.

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02.22)
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 2: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21475-112644

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 942
-SubTopic 470
-Section 50
-Paragraph 3
-URI http://asc.fasb.org/extlink&oid=6479336&loc=d3e64711-112823

Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08.(e),(f))
-URI http://asc.fasb.org/extlink&oid=26873400&loc=d3e23780-122690

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=34725769&loc=d3e28878-108400

Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21538-112644

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 6
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21506-112644

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=6451184&loc=d3e28551-108399

Reference 10: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
-Paragraph 7
-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21521-112644

Reference 11: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Regulation S-X (SX)
-Number 210
-Section 02
-Paragraph 22
-Article 5

+ Details

Equity and Distributions (Tables)

9 Months Ended

Sep. 30, 2014

Equity and Distributions [Abstract]

	Common Units (Unrestricted)			Restricted Common Units			Total Common Units
Number of units outstanding at December 31, 2013		1,864,148,802			7,221,214			1,871,370,016
Common units issued in connection with at-the-market program		1,590,334			--			1,590,334
Common units issued in connection with DRIP and EUPP		7,355,904			--			7,355,904
Common units issued in connection with the vesting and exercise of unit options		1,014,108			--			1,014,108
Common units issued in connection with the vesting of phantom unit awards		20,842			--			20,842
Common units issued in connection with the vesting of restricted common unit awards		2,586,398			(2,586,398	)		--
Forfeiture of restricted common unit awards		--			(267,200	)		(267,200	)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards		(878,017	)		--			(878,017	)
Other		17,202			--			17,202
Number of units outstanding at September 30, 2014		1,875,855,573			4,367,616			1,880,223,189

Components of Accumulated Other Comprehensive Income (Loss)

The following tables present the components of accumulated other comprehensive income (loss) as reported on our Unaudited Condensed Consolidated Balance Sheets at the dates indicated:

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other		Total
Balance, December 31, 2013	$	(14.7	)	$	(347.2	)	$	2.9	$	(359.0	)
Other comprehensive income before reclassifications		16.1			--			--		16.1
Amounts reclassified from accumulated other comprehensive loss		12.9			23.9			--		36.8
Total other comprehensive income		29.0			23.9			--		52.9
Balance, September 30, 2014	$	14.3		$	(323.3	)	$	2.9	$	(306.1	)

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other		Total
Balance, December 31, 2012	$	10.1		$	(383.0	)	$	2.5	$	(370.4	)
Other comprehensive income before reclassifications		(22.1	)		6.7			0.4		(15.0	)
Amounts reclassified from accumulated other comprehensive loss		14.7			21.4			--		36.1
Total other comprehensive income (loss)		(7.4	)		28.1			0.4		21.1
Balance, September 30, 2013	$	2.7		$	(354.9	)	$	2.9	$	(349.3	)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

The following table presents reclassifications out of accumulated other comprehensive income (loss) into net income during the periods indicated:

		For the Three Months Ended September 30,							For the Nine Months Ended September 30,
	Location	2014				2013			2014				2013
Losses (gains) on cash flow hedges:
Interest rate derivatives	Interest expense		$	8.0			$	7.7		$	23.9			$	21.4
Commodity derivatives	Revenue			(17.8	)			14.6			14.5				15.1
Commodity derivatives	Operating costs and expenses			(0.2	)			--			(1.6	)			(0.4	)
Total			$	(10.0	)		$	22.3		$	36.8			$	36.1

Declared Quarterly Cash Distribution Rates

The following table presents Enterprise's declared quarterly cash distribution rates per common unit with respect to the quarter indicated:

	Distribution Per Common Unit		Record Date	Payment Date
2013:
1st Quarter	$	0.3350	4/30/2013	5/7/2013
2nd Quarter	$	0.3400	7/31/2013	8/7/2013
3rd Quarter	$	0.3450	10/31/2013	11/7/2013
2014:
1st Quarter	$	0.3550	4/30/2014	5/7/2014
2nd Quarter	$	0.3600	7/31/2014	8/7/2014
3rd Quarter	$	0.3650	10/31/2014	11/7/2014

Business Segments (Tables)

9 Months Ended

Sep. 30, 2014

Business Segments [Abstract]

Measurement of Total Segment Gross Operating Margin

The following table presents our measurement of non-GAAP total segment gross operating margin for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Revenues	$	12,330.2		$	12,093.3		$	37,760.9		$	34,625.7
Subtract operating costs and expenses		(11,414.8	)		(11,273.5	)		(34,934.4	)		(32,061.1	)
Add equity in income of unconsolidated affiliates		72.3			44.0			179.1			126.1
Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin		322.7			285.2			936.5			851.7
Add impairment charges not reflected in gross operating margin		5.7			15.2			18.2			53.3
Subtract net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin		(2.6	)		(10.2	)		(99.0	)		(68.4	)
Add non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin		21.6			--			66.8			--
Total segment gross operating margin	$	1,335.1		$	1,154.0		$	3,928.1		$	3,527.3

Reconciliation of Total Segment Gross Operating Margin to Operating Income and Income Before Provision for Income Taxes

The following table presents a reconciliation of total segment gross operating margin to operating income and further to income before income taxes for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Total segment gross operating margin	$	1,335.1		$	1,154.0		$	3,928.1		$	3,527.3
Adjustments to reconcile total segment gross operating margin to operating income:
Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin		(322.7	)		(285.2	)		(936.5	)		(851.7	)
Subtract impairment charges not reflected in gross operating margin		(5.7	)		(15.2	)		(18.2	)		(53.3	)
Add net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin (see Note 16)		2.6			10.2			99.0			68.4
Subtract non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin		(21.6	)		--			(66.8	)		--
Subtract general and administrative costs not reflected in gross operating margin		(50.0	)		(43.9	)		(150.9	)		(138.9	)
Operating income		937.7			819.9			2,854.7			2,551.8
Other expense, net		(230.8	)		(207.7	)		(679.8	)		(604.2	)
Income before income taxes	$	706.9		$	612.2		$	2,174.9		$	1,947.6

Information by Business Segments

Information by business segment, together with reconciliations to our consolidated financial statement totals, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Onshore Natural Gas Pipelines & Services		Onshore Crude Oil Pipelines & Services		Offshore Pipelines & Services		Petrochemical & Refined Products Services			Adjustments and Eliminations			Consolidated Total
Revenues from third parties:
Three months ended September 30, 2014	$	4,024.0	$	1,026.5	$	5,435.6	$	41.1	$	1,792.0		$	--		$	12,319.2
Three months ended September 30, 2013		4,230.6		831.4		5,435.4		38.2		1,550.0			--			12,085.6
Nine months ended September 30, 2014		13,217.2		3,261.0		16,236.6		112.4		4,869.9			--			37,697.1
Nine months ended September 30, 2013		11,686.0		2,658.6		15,358.1		118.0		4,784.7			--			34,605.4
Revenues from related parties:
Three months ended September 30, 2014		2.7		5.4		1.5		1.4		--			--			11.0
Three months ended September 30, 2013		0.1		4.1		2.1		1.4		--			--			7.7
Nine months ended September 30, 2014		10.2		16.5		31.1		6.0		--			--			63.8
Nine months ended September 30, 2013		0.6		12.1		2.1		5.5		--			--			20.3
Intersegment and intrasegment revenues:
Three months ended September 30, 2014		3,603.8		231.0		2,529.5		1.2		452.2			(6,817.7	)		--
Three months ended September 30, 2013		2,542.3		215.6		3,591.3		1.8		384.4			(6,735.4	)		--
Nine months ended September 30, 2014		10,789.7		835.8		10,714.5		4.8		1,317.6			(23,662.4	)		--
Nine months ended September 30, 2013		7,631.7		726.7		8,333.0		8.0		1,200.7			(17,900.1	)		--
Total revenues:
Three months ended September 30, 2014		7,630.5		1,262.9		7,966.6		43.7		2,244.2			(6,817.7	)		12,330.2
Three months ended September 30, 2013		6,773.0		1,051.1		9,028.8		41.4		1,934.4			(6,735.4	)		12,093.3
Nine months ended September 30, 2014		24,017.1		4,113.3		26,982.2		123.2		6,187.5			(23,662.4	)		37,760.9
Nine months ended September 30, 2013		19,318.3		3,397.4		23,693.2		131.5		5,985.4			(17,900.1	)		34,625.7
Equity in income (loss) of unconsolidated affiliates:
Three months ended September 30, 2014		11.7		0.9		46.8		17.1		(4.2	)		--			72.3
Three months ended September 30, 2013		4.1		1.0		34.3		9.8		(5.2	)		--			44.0
Nine months ended September 30, 2014		19.2		2.7		131.7		35.8		(10.3	)		--			179.1
Nine months ended September 30, 2013		11.8		2.9		101.0		24.9		(14.5	)		--			126.1
Gross operating margin:
Three months ended September 30, 2014		711.5		195.4		190.8		47.1		190.3			--			1,335.1
Three months ended September 30, 2013		639.6		213.4		146.0		37.9		117.1			--			1,154.0
Nine months ended September 30, 2014		2,172.4		618.8		534.5		120.0		482.4			--			3,928.1
Nine months ended September 30, 2013		1,777.0		601.9		579.6		118.1		450.7			--			3,527.3
Property, plant and equipment, net: (see Note 6)
At September 30, 2014		11,768.9		8,834.7		1,540.6		1,168.2		2,845.2			1,805.7			27,963.3
At December 31, 2013		9,957.8		8,917.3		1,479.9		1,223.7		2,712.4			2,655.5			26,946.6
Investments in unconsolidated affiliates: (see Note 7)
At September 30, 2014		685.8		23.5		1,651.7		502.4		74.9			--			2,938.3
At December 31, 2013		645.5		24.2		1,165.2		531.8		70.4			--			2,437.1
Intangible assets, net: (see Note 8)
At September 30, 2014		264.6		983.6		3.6		43.9		95.4			--			1,391.1
At December 31, 2013		285.2		1,017.8		4.5		54.7		100.0			--			1,462.2
Goodwill: (see Note 8)
At September 30, 2014		861.2		296.3		305.1		82.0		535.3			--			2,079.9
At December 31, 2013		341.2		296.3		305.1		82.1		1,055.3			--			2,080.0
Segment assets:
At September 30, 2014		13,580.5		10,138.1		3,501.0		1,796.5		3,550.8			1,805.7			34,372.6
At December 31, 2013		11,229.7		10,255.6		2,954.7		1,892.3		3,938.1			2,655.5			32,925.9

Consolidated Revenues and Expenses

The following table presents additional information regarding our consolidated revenues and costs and expenses for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
NGL Pipelines & Services:
Sales of NGLs and related products	$	3,603.4		$	3,929.8		$	12,029.8		$	10,831.3
Midstream services		423.3			300.9			1,197.6			855.3
Total		4,026.7			4,230.7			13,227.4			11,686.6
Onshore Natural Gas Pipelines & Services:
Sales of natural gas		775.5			590.7			2,515.7			1,954.1
Midstream services		256.4			244.8			761.8			716.6
Total		1,031.9			835.5			3,277.5			2,670.7
Onshore Crude Oil Pipelines & Services:
Sales of crude oil		5,348.2			5,359.7			16,003.5			15,159.9
Midstream services		88.9			77.8			264.2			200.3
Total		5,437.1			5,437.5			16,267.7			15,360.2
Offshore Pipelines & Services:
Sales of natural gas		--			0.1			0.2			0.3
Sales of crude oil		2.5			1.5			7.5			3.7
Midstream services		40.0			38.0			110.7			119.5
Total		42.5			39.6			118.4			123.5
Petrochemical & Refined Products Services:
Sales of petrochemicals and refined products		1,605.4			1,390.1			4,338.2			4,271.5
Midstream services		186.6			159.9			531.7			513.2
Total		1,792.0			1,550.0			4,869.9			4,784.7
Total consolidated revenues	$	12,330.2		$	12,093.3		$	37,760.9		$	34,625.7

Consolidated costs and expenses
Operating costs and expenses:
Cost of sales	$	10,455.1		$	10,371.3		$	32,213.1		$	29,522.1
Other operating costs and expenses (1)		633.9			612.0			1,865.6			1,702.4
Depreciation, amortization and accretion		322.7			285.2			936.5			851.7
Net losses (gains) attributable to asset sales and insurance recoveries		(2.6	)		(10.2	)		(99.0	)		(68.4	)
Non-cash asset impairment charges		5.7			15.2			18.2			53.3
General and administrative costs		50.0			43.9			150.9			138.9
Total consolidated costs and expenses	$	11,464.8		$	11,317.4		$	35,085.3		$	32,200.0

(1) Represents cost of operating our plants, pipelines and other fixed assets, excluding depreciation, amortization and accretion charges.

Related Party Transactions (Tables)

9 Months Ended

Sep. 30, 2014

Related Party Transactions

The following table summarizes our related party transactions for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Revenues – related parties:
Unconsolidated affiliates		$	11.0		$	7.7		$	63.8		$	20.3
Costs and expenses – related parties:
EPCO and affiliates		$	212.8		$	218.8		$	688.0		$	654.4
Unconsolidated affiliates			35.8			25.9			138.4			86.5
Total		$	248.6		$	244.7		$	826.4		$	740.9

The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated:

	September 30, 2014		December 31, 2013
Accounts receivable - related parties:
Unconsolidated affiliates	$	2.6	$	6.8

Accounts payable - related parties:
EPCO and affiliates	$	102.3	$	116.3
Unconsolidated affiliates		20.3		34.2
Total	$	122.6	$	150.5

Number of Units	Percentage of Total Units Outstanding
683,993,630	36.4%

The following table presents our costs and expenses attributable to the ASA and other related party transactions with EPCO for the periods indicated:

	For the Three Months Ended September 30,						For the Nine Months Ended September 30,
	2014			2013			2014			2013
Operating costs and expenses		$	179.1		$	190.5		$	591.7		$	564.7
General and administrative expenses			33.7			28.3			96.3			89.7
Total costs and expenses		$	212.8		$	218.8		$	688.0		$	654.4

Earnings Per Unit (Tables)

9 Months Ended

Sep. 30, 2014

Earnings Per Unit [Abstract]

Basic and Diluted Earnings Per Unit

The following table presents our calculation of basic and diluted earnings per unit for the periods indicated:

	For the Three Months Ended September 30,					For the Nine Months Ended September 30,
	2014			2013		2014			2013
BASIC EARNINGS PER UNIT
Net income attributable to limited partners	$	691.1		$	592.0	$	2,127.6		$	1,898.0
Undistributed earnings allocated and cash payments on phantom unit awards (1)		(1.3	)		--		(4.0	)		--
Net income available to common unitholders	$	689.8		$	592.0	$	2,123.6		$	1,898.0

Basic weighted-average number of common units outstanding		1,834.2			1,792.6		1,831.1			1,778.2

Basic earnings per unit	$	0.38		$	0.33	$	1.16		$	1.07

DILUTED EARNINGS PER UNIT
Net income attributable to limited partners	$	691.1		$	592.0	$	2,127.6		$	1,898.0

Diluted weighted-average number of units outstanding:
Distribution-bearing common units		1,834.2			1,792.6		1,831.1			1,778.2
Designated Units		45.1			47.4		45.1			47.4
Class B units (2)		--			3.8		--			7.2
Phantom units (1)		3.4			--		2.8			--
Incremental option units		0.7			2.2		1.0			2.4
Total		1,883.4			1,846.0		1,880.0			1,835.2

Diluted earnings per unit	$	0.37		$	0.32	$	1.13		$	1.03

(1) Each phantom unit award includes a DER, which entitles the recipient to receive cash payments equal to the product of the number of phantom unit awards and the cash distribution per unit paid to Enterprise's common unitholders. Cash payments made in connection with DERs are nonforfeitable. As a result, the phantom units are considered participating securities for purposes of computing basic earnings per unit. Phantom unit awards were first issued in February 2014.
(2) The Class B units automatically converted into an equal number of distribution-bearing common units in August 2013.

Supplemental Cash Flow Information (Tables)

9 Months Ended

Sep. 30, 2014

Supplemental Cash Flow Information [Abstract]

Net Effect of Changes in Operating Assets and Liabilities

The following table presents the net effect of changes in our operating accounts for the periods indicated:

	For the Nine Months Ended September 30,
	2014			2013
Decrease (increase) in:
Accounts receivable – trade	$	153.6		$	(1,130.0	)
Accounts receivable – related parties		4.0			(9.6	)
Inventories		(536.9	)		(674.2	)
Prepaid and other current assets		(44.5	)		(31.5	)
Other assets		20.0			3.2
Increase (decrease) in:
Accounts payable – trade		(14.2	)		114.3
Accounts payable – related parties		(27.7	)		(30.4	)
Accrued product payables		(13.1	)		1,358.1
Accrued interest		(131.7	)		(132.6	)
Other current liabilities		143.5			29.3
Other liabilities		11.2			(10.5	)
Net effect of changes in operating accounts	$	(435.8	)	$	(513.9	)

Schedule of Significant Acquisitions and Disposals

The following table presents our cash proceeds from asset sales and insurance recoveries for the periods indicated:

	For the Nine Months Ended September 30,
	2014		2013
Sale of Stratton Ridge-to-Mont Belvieu segment of Seminole Pipeline (see Note 6)	$	--	$	86.9
Sale of lubrication oil and specialty chemical distribution assets (see Note 6)		--		35.3
Sale of chemical trucking assets		--		29.5
Sale of pipeline linefill		7.4		65.0
Insurance recoveries attributable to West Storage claims (see Note 15)		95.0		8.8
Other cash proceeds		19.1		30.8
Total	$	121.5	$	256.3

The following table presents net gains attributable to asset sales and insurance recoveries for the periods indicated:

	For the Nine Months Ended September 30,
	2014		2013
Sale of Stratton Ridge-to-Mont Belvieu segment of Seminole Pipeline (see Note 6)	$	--	$	52.5
Gains attributable to West Storage insurance recoveries (see Note 15)		95.0		8.8
Net gains attributable to other asset sales		4.0		7.1
Total	$	99.0	$	68.4

Condensed Consolidating Financial Information (Tables)

9 Months Ended

Sep. 30, 2014

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Balance Sheet

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	1,019.7	$	52.1	$	(3.6	)	$	1,068.2	$	--	$	--		$	1,068.2
Accounts receivable – trade, net		1,625.8		3,700.7		(5.7	)		5,320.8		--		--			5,320.8
Accounts receivable – related parties		104.0		1,380.9		(1,481.8	)		3.1		--		(0.5	)		2.6
Inventories		1,244.3		346.2		(1.0	)		1,589.5		--		--			1,589.5
Prepaid and other current assets		167.7		226.2		(10.3	)		383.6		0.1		0.7			384.4
Total current assets		4,161.5		5,706.1		(1,502.4	)		8,365.2		0.1		0.2			8,365.5
Property, plant and equipment, net		2,360.6		25,601.2		1.5			27,963.3		--		--			27,963.3
Investments in unconsolidated affiliates		32,198.8		3,452.0		(32,712.5	)		2,938.3		15,758.0		(15,758.0	)		2,938.3
Intangible assets, net		80.2		1,326.2		(15.3	)		1,391.1		--		--			1,391.1
Goodwill		458.8		1,621.1		--			2,079.9		--		--			2,079.9
Other assets		124.5		44.7		(1.9	)		167.3		0.1		--			167.4
Total assets	$	39,384.4	$	37,751.3	$	(34,230.6	)	$	42,905.1	$	15,758.2	$	(15,757.8	)	$	42,905.5

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	1,939.9	$	--	$	--		$	1,939.9	$	--	$	--		$	1,939.9
Accounts payable – trade		304.5		426.9		(3.6	)		727.8		0.2		--			728.0
Accounts payable – related parties		1,472.6		146.0		(1,496.0	)		122.6		0.5		(0.5	)		122.6
Accrued product payables		2,003.7		3,568.1		(7.2	)		5,564.6		--		--			5,564.6
Accrued interest		172.2		0.3		--			172.5		--		--			172.5
Other current liabilities		63.1		392.4		(11.3	)		444.2		--		--			444.2
Total current liabilities		5,956.0		4,533.7		(1,518.1	)		8,971.6		0.7		(0.5	)		8,971.8
Long-term debt		17,691.6		14.9		--			17,706.5		--		--			17,706.5
Deferred tax liabilities		4.3		57.3		(1.9	)		59.7		--		3.5			63.2
Other long-term liabilities		10.4		172.2		(0.5	)		182.1		--		--			182.1
Commitments and contingencies
Equity:
Partners' and other owners' equity		15,722.1		32,903.7		(32,892.1	)		15,733.7		15,757.5		(15,733.7	)		15,757.5
Noncontrolling interests		--		69.5		182.0			251.5		--		(27.1	)		224.4
Total equity		15,722.1		32,973.2		(32,710.1	)		15,985.2		15,757.5		(15,760.8	)		15,981.9
Total liabilities and equity	$	39,384.4	$	37,751.3	$	(34,230.6	)	$	42,905.1	$	15,758.2	$	(15,757.8	)	$	42,905.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

December 31, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	93.9	$	49.5	$	(20.9	)	$	122.5	$	--	$	--		$	122.5
Accounts receivable – trade, net		1,986.8		3,491.1		(2.4	)		5,475.5		--		--			5,475.5
Accounts receivable – related parties		384.7		1,348.1		(1,726.0	)		6.8		0.2		(0.2	)		6.8
Inventories		948.5		145.4		(0.8	)		1,093.1		--		--			1,093.1
Prepaid and other current assets		140.9		191.4		(6.8	)		325.5		--		--			325.5
Total current assets		3,554.8		5,225.5		(1,756.9	)		7,023.4		0.2		(0.2	)		7,023.4
Property, plant and equipment, net		1,945.0		24,999.7		1.9			26,946.6		--		--			26,946.6
Investments in unconsolidated affiliates		30,819.9		2,921.2		(31,304.0	)		2,437.1		15,214.5		(15,214.5	)		2,437.1
Intangible assets, net		76.9		1,385.3		--			1,462.2		--		--			1,462.2
Goodwill		458.9		1,621.1		--			2,080.0		--		--			2,080.0
Other assets		123.5		67.2		(1.4	)		189.3		0.1		--			189.4
Total assets	$	36,979.0	$	36,220.0	$	(33,060.4	)	$	40,138.6	$	15,214.8	$	(15,214.7	)	$	40,138.7

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	1,125.0	$	--	$	--		$	1,125.0	$	--	$	--		$	1,125.0
Accounts payable – trade		103.0		641.6		(20.9	)		723.7		--		--			723.7
Accounts payable – related parties		1,541.8		333.8		(1,724.9	)		150.7		--		(0.2	)		150.5
Accrued product payables		2,388.6		3,224.5		(4.4	)		5,608.7		--		--			5,608.7
Accrued interest		304.2		0.1		--			304.3		--		--			304.3
Other current liabilities		92.3		242.4		(6.7	)		328.0		--		(1.5	)		326.5
Total current liabilities		5,554.9		4,442.4		(1,756.9	)		8,240.4		--		(1.7	)		8,238.7
Long-term debt		16,211.6		14.9		--			16,226.5		--		--			16,226.5
Deferred tax liabilities		4.3		55.0		(1.4	)		57.9		--		2.9			60.8
Other long-term liabilities		11.8		160.5		--			172.3		--		--			172.3
Commitments and contingencies
Equity:
Partners' and other owners' equity		15,196.4		31,475.9		(31,482.4	)		15,189.9		15,214.8		(15,189.9	)		15,214.8
Noncontrolling interests		--		71.3		180.3			251.6		--		(26.0	)		225.6
Total equity		15,196.4		31,547.2		(31,302.1	)		15,441.5		15,214.8		(15,215.9	)		15,440.4
Total liabilities and equity	$	36,979.0	$	36,220.0	$	(33,060.4	)	$	40,138.6	$	15,214.8	$	(15,214.7	)	$	40,138.7

Condensed Consolidating Statement of Operations

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	8,121.5		$	8,598.2		$	(4,389.5	)	$	12,330.2		$	--	$	--		$	12,330.2
Costs and expenses:
Operating costs and expenses		7,950.9			7,853.5			(4,389.6	)		11,414.8			--		--			11,414.8
General and administrative costs		8.2			40.4			--			48.6			1.4		--			50.0
Total costs and expenses		7,959.1			7,893.9			(4,389.6	)		11,463.4			1.4		--			11,464.8
Equity in income of unconsolidated affiliates		762.5			94.4			(784.6	)		72.3			692.5		(692.5	)		72.3
Operating income		924.9			798.7			(784.5	)		939.1			691.1		(692.5	)		937.7
Other income (expense):
Interest expense		(229.2	)		(0.6	)		--			(229.8	)		--		--			(229.8	)
Other, net		0.2			(1.2	)		--			(1.0	)		--		--			(1.0	)
Total other expense, net		(229.0	)		(1.8	)		--			(230.8	)		--		--			(230.8	)
Income before income taxes		695.9			796.9			(784.5	)		708.3			691.1		(692.5	)		706.9
Provision for income taxes		(4.0	)		(2.8	)		--			(6.8	)		--		(0.9	)		(7.7	)
Net income		691.9			794.1			(784.5	)		701.5			691.1		(693.4	)		699.2
Net loss (income) attributable to noncontrolling interests		--			0.1			(9.5	)		(9.4	)		--		1.3			(8.1	)
Net income attributable to entity	$	691.9		$	794.2		$	(794.0	)	$	692.1		$	691.1	$	(692.1	)	$	691.1

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	7,070.3		$	8,588.4		$	(3,565.4	)	$	12,093.3		$	--	$	--		$	12,093.3
Costs and expenses:
Operating costs and expenses		6,858.0			7,980.9			(3,565.4	)		11,273.5			--		--			11,273.5
General and administrative costs		7.6			36.0			--			43.6			0.3		--			43.9
Total costs and expenses		6,865.6			8,016.9			(3,565.4	)		11,317.1			0.3		--			11,317.4
Equity in income of unconsolidated affiliates		577.2			47.8			(581.0	)		44.0			592.3		(592.3	)		44.0
Operating income		781.9			619.3			(581.0	)		820.2			592.0		(592.3	)		819.9
Other income (expense):
Interest expense		(208.0	)		(0.3	)		--			(208.3	)		--		--			(208.3	)
Other, net		0.1			0.5			--			0.6			--		--			0.6
Total other expense, net		(207.9	)		0.2			--			(207.7	)		--		--			(207.7	)
Income before income taxes		574.0			619.5			(581.0	)		612.5			592.0		(592.3	)		612.2
Provision for income taxes		17.7			(36.8	)		--			(19.1	)		--		(0.3	)		(19.4	)
Net income		591.7			582.7			(581.0	)		593.4			592.0		(592.6	)		592.8
Net income attributable to noncontrolling interests		--			(0.2	)		(1.6	)		(1.8	)		--		1.0			(0.8	)
Net income attributable to entity	$	591.7		$	582.5		$	(582.6	)	$	591.6		$	592.0	$	(591.6	)	$	592.0

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	25,190.1		$	25,859.9		$	(13,289.1	)	$	37,760.9		$	--	$	--		$	37,760.9
Costs and expenses:
Operating costs and expenses		24,516.6			23,707.6			(13,289.8	)		34,934.4			--		--			34,934.4
General and administrative costs		23.1			126.0			--			149.1			1.8		--			150.9
Total costs and expenses		24,539.7			23,833.6			(13,289.8	)		35,083.5			1.8		--			35,085.3
Equity in income of unconsolidated affiliates		2,169.5			256.1			(2,246.5	)		179.1			2,129.4		(2,129.4	)		179.1
Operating income		2,819.9			2,282.4			(2,245.8	)		2,856.5			2,127.6		(2,129.4	)		2,854.7
Other income (expense):
Interest expense		(678.6	)		(1.0	)		--			(679.6	)		--		--			(679.6	)
Other, net		0.7			(0.9	)		--			(0.2	)		--		--			(0.2	)
Total other expense, net		(677.9	)		(1.9	)		--			(679.8	)		--		--			(679.8	)
Income before income taxes		2,142.0			2,280.5			(2,245.8	)		2,176.7			2,127.6		(2,129.4	)		2,174.9
Provision for income taxes		(15.5	)		(5.8	)		0.2			(21.1	)		--		(1.4	)		(22.5	)
Net income		2,126.5			2,274.7			(2,245.6	)		2,155.6			2,127.6		(2,130.8	)		2,152.4
Net loss (income) attributable to noncontrolling interests		--			0.2			(28.8	)		(28.6	)		--		3.8			(24.8	)
Net income attributable to entity	$	2,126.5		$	2,274.9		$	(2,274.4	)	$	2,127.0		$	2,127.6	$	(2,127.0	)	$	2,127.6

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	20,916.8		$	24,044.5		$	(10,335.6	)	$	34,625.7		$	--	$	--		$	34,625.7
Costs and expenses:
Operating costs and expenses		20,328.5			22,068.2			(10,335.6	)		32,061.1			--		--			32,061.1
General and administrative costs		19.7			118.0			--			137.7			1.2		--			138.9
Total costs and expenses		20,348.2			22,186.2			(10,335.6	)		32,198.8			1.2		--			32,200.0
Equity in income of unconsolidated affiliates		1,936.2			141.9			(1,952.0	)		126.1			1,899.2		(1,899.2	)		126.1
Operating income		2,504.8			2,000.2			(1,952.0	)		2,553.0			1,898.0		(1,899.2	)		2,551.8
Other income (expense):
Interest expense		(603.0	)		(1.4	)		--			(604.4	)		--		--			(604.4	)
Other, net		0.3			(0.1	)		--			0.2			--		--			0.2
Total other expense, net		(602.7	)		(1.5	)		--			(604.2	)		--		--			(604.2	)
Income before income taxes		1,902.1			1,998.7			(1,952.0	)		1,948.8			1,898.0		(1,899.2	)		1,947.6
Provision for income taxes		(4.9	)		(40.7	)		--			(45.6	)		--		(0.6	)		(46.2	)
Net income		1,897.2			1,958.0			(1,952.0	)		1,903.2			1,898.0		(1,899.8	)		1,901.4
Net income attributable to noncontrolling interests		--			(1.1	)		(4.9	)		(6.0	)		--		2.6			(3.4	)
Net income attributable to entity	$	1,897.2		$	1,956.9		$	(1,956.9	)	$	1,897.2		$	1,898.0	$	(1,897.2	)	$	1,898.0

Condensed Consolidating Statement of Comprehensive Income

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	708.9		$	825.2		$	(784.5	)		$	749.6			$	739.2		$	(741.5	)		$	747.3
Comprehensive loss (income) attributable to noncontrolling interests			--			0.1			(9.5	)			(9.4	)			--			1.3				(8.1	)
Comprehensive income attributable to entity		$	708.9		$	825.3		$	(794.0	)		$	740.2			$	739.2		$	(740.2	)		$	739.2

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)				EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	583.4		$	604.7			$	(580.9	)		$	607.2			$	605.7		$	(606.4	)		$	606.5
Comprehensive income attributable to noncontrolling interests			--			(0.2	)			(1.6	)			(1.8	)			--			1.0				(0.8	)
Comprehensive income attributable to entity		$	583.4		$	604.5			$	(582.5	)		$	605.4			$	605.7		$	(605.4	)		$	605.7

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	2,161.8		$	2,292.2		$	(2,245.5	)		$	2,208.5			$	2,180.5		$	(2,183.7	)		$	2,205.3
Comprehensive loss (income) attributable to noncontrolling interests			--			0.2			(28.8	)			(28.6	)			--			3.8				(24.8	)
Comprehensive income attributable to entity		$	2,161.8		$	2,292.4		$	(2,274.3	)		$	2,179.9			$	2,180.5		$	(2,179.9	)		$	2,180.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)				EPO and Subsidiaries Eliminations and Adjustments				Consolidated EPO and Subsidiaries				Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments				Consolidated Total
Comprehensive income		$	1,911.5		$	1,964.7			$	(1,951.9	)		$	1,924.3			$	1,919.1		$	(1,920.9	)		$	1,922.5
Comprehensive income attributable to noncontrolling interests			--			(1.1	)			(4.9	)			(6.0	)			--			2.6				(3.4	)
Comprehensive income attributable to entity		$	1,911.5		$	1,963.6			$	(1,956.8	)		$	1,918.3			$	1,919.1		$	(1,918.3	)		$	1,919.1

Condensed Consolidating Statement of Cash Flows

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Nine Months Ended September 30, 2014

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	2,126.5		$	2,274.7		$	(2,245.6	)	$	2,155.6		$	2,127.6		$	(2,130.8	)	$	2,152.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		114.3			878.5			(0.4	)		992.4			--			--			992.4
Equity in income of unconsolidated affiliates		(2,169.5	)		(256.1	)		2,246.5			(179.1	)		(2,129.4	)		2,129.4			(179.1	)
Distributions received from unconsolidated affiliates		3,475.8			229.0			(3,444.1	)		260.7			2,007.4			(2,007.4	)		260.7
Net effect of changes in operating accounts and other operating activities		(764.6	)		230.1			16.7			(517.8	)		(5.6	)		1.4			(522.0	)
Net cash flows provided by operating activities		2,782.5			3,356.2			(3,426.9	)		2,711.8			2,000.0			(2,007.4	)		2,704.4
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(329.1	)		(1,530.4	)		--			(1,859.5	)		--			--			(1,859.5	)
Proceeds from asset sales and insurance recoveries		4.2			117.3			--			121.5			--			--			121.5
Other investing activities		(2,059.3	)		(526.9	)		2,056.1			(530.1	)		(300.7	)		300.7			(530.1	)
Cash used in investing activities		(2,384.2	)		(1,940.0	)		2,056.1			(2,268.1	)		(300.7	)		300.7			(2,268.1	)
Financing activities:
Borrowings under debt agreements		7,167.5			--			--			7,167.5			--			--			7,167.5
Repayments of debt		(4,856.3	)		--			--			(4,856.3	)		--			--			(4,856.3	)
Cash distributions paid to partners		(2,007.4	)		(3,473.6	)		3,473.6			(2,007.4	)		(1,948.2	)		2,007.4			(1,948.2	)
Cash payments made in connection with DERs		--			--			--			--			(2.4	)		--			(2.4	)
Cash distributions paid to noncontrolling interests		--			--			(29.4	)		(29.4	)		--			--			(29.4	)
Cash contributions from noncontrolling interests		--			--			4.0			4.0			--			--			4.0
Net cash proceeds from issuance of common units		--			--			--			--			304.9			--			304.9
Cash contributions from owners		300.7			2,060.0			(2,060.0	)		300.7			--			(300.7	)		--
Other financing activities		(18.1	)		--			--			(18.1	)		(53.6	)		--			(71.7	)
Cash provided by (used in) financing activities		586.4			(1,413.6	)		1,388.2			561.0			(1,699.3	)		1,706.7			568.4
Net change in cash and cash equivalents		984.7			2.6			17.4			1,004.7			--			--			1,004.7
Cash and cash equivalents, January 1		28.4			49.5			(21.0	)		56.9			--			--			56.9
Cash and cash equivalents, September 30	$	1,013.1		$	52.1		$	(3.6	)	$	1,061.6		$	--		$	--		$	1,061.6

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Nine Months Ended September 30, 2013

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	1,897.2		$	1,958.0		$	(1,952.0	)	$	1,903.2		$	1,898.0		$	(1,899.8	)	$	1,901.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		105.3			797.0			--			902.3			--			--			902.3
Equity in income of unconsolidated affiliates		(1,936.2	)		(141.9	)		1,952.0			(126.1	)		(1,899.2	)		1,899.2			(126.1	)
Distributions received from unconsolidated affiliates		3,421.1			180.7			(3,414.2	)		187.6			1,830.9			(1,830.9	)		187.6
Net effect of changes in operating accounts and other operating activities		(1,371.4	)		889.7			(11.0	)		(492.7	)		(6.6	)		0.3			(499.0	)
Net cash flows provided by operating activities		2,116.0			3,683.5			(3,425.2	)		2,374.3			1,823.1			(1,831.2	)		2,366.2
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(292.1	)		(2,101.2	)		--			(2,393.3	)		--			--			(2,393.3	)
Proceeds from asset sales and insurance recoveries		57.5			198.8			--			256.3			--			--			256.3
Other investing activities		(2,366.7	)		(485.6	)		2,051.8			(800.5	)		(1,135.2	)		1,135.2			(800.5	)
Cash used in investing activities		(2,601.3	)		(2,388.0	)		2,051.8			(2,937.5	)		(1,135.2	)		1,135.2			(2,937.5	)
Financing activities:
Borrowings under debt agreements		10,139.2			--			--			10,139.2			--			--			10,139.2
Repayments of debt		(8,761.7	)		(29.9	)		--			(8,791.6	)		--			--			(8,791.6	)
Cash distributions paid to partners		(1,831.2	)		(3,420.6	)		3,420.6			(1,831.2	)		(1,778.3	)		1,831.2			(1,778.3	)
Cash distributions paid to noncontrolling interests		--			--			(6.4	)		(6.4	)		--			--			(6.4	)
Cash contributions from noncontrolling interests		--			--			104.2			104.2			--			--			104.2
Net cash proceeds from issuance of common units		--			--			--			--			1,134.7			--			1,134.7
Cash contributions from owners		1,135.2			2,155.9			(2,155.9	)		1,135.2			--			(1,135.2	)		--
Other financing activities		(192.6	)		0.1			--			(192.5	)		(44.5	)		--			(237.0	)
Cash provided by (used in) financing activities		488.9			(1,294.5	)		1,362.5			556.9			(688.1	)		696.0			564.8
Net change in cash and cash equivalents		3.6			1.0			(10.9	)		(6.3	)		(0.2	)		--			(6.5	)
Cash and cash equivalents, January 1		--			28.0			(12.1	)		15.9			0.2			--			16.1
Cash and cash equivalents, September 30	$	3.6		$	29.0		$	(23.0	)	$	9.6		$	--		$	--		$	9.6

Partnership Operations and Organization (Details) bbl in Millions, ft³ in Billions	9 Months Ended
	Sep. 30, 2014 Plant Fractionator Platform Segment mi bbl ft³
Partnership Operations and Organization [Abstract]
Number of miles of onshore and offshore pipelines \| mi	52,000
Number of barrels of storage capacity \| bbl	220
Number of cubic feet of storage capacity \| ft³	14
Number of natural gas processing plants \| Plant	24
Number of fractionators \| Fractionator	22
Number of offshore hub platforms \| Platform	6
Number of reportable segments \| Segment	5
Limited partners ownership interest (in hundredths)	100.00%

General Accounting Matters (Details) $ in Millions	9 Months Ended
General Accounting Matters (Details) $ in Millions	Sep. 30, 2014 USD ($)	Dec. 31, 2013 USD ($)
General Accounting Matters [Abstract]
Unit split conversion ratio	2
Restricted cash [Abstract]
Restricted cash	$ 6.6	$ 65.6

Equity-based Awards (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
Equity-based Awards (Details) - USD ($) $ in Millions	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Equity-based compensation expense [Abstract]
Total compensation expense	$ 21.7	$ 18.0	$ 62.0	$ 53.8
Equity-classified awards [Member] \| Restricted Common Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	8.7	17.8	29.3	52.7
Equity-classified awards [Member] \| Unit Option Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	0.0	0.1	0.0	0.7
Equity-classified awards [Member] \| Phantom Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	12.9	0.0	32.3	0.0
Liability-classified awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	$ 0.1	$ 0.1	$ 0.4	$ 0.4
Long-Term Incentive Plan (2008) [Member]
Equity-based compensation expense [Abstract]
Maximum number of common units that may be issued as awards (in units)	25,000,000		25,000,000
Incremental number of units to be authorized annually (in units)			5,000,000
Maximum number of additional units to be authorized for issuance (in units)			70,000,000
Remaining number of common units available to be issued as awards (in units)	12,782,238		12,782,238
Long Term Incentive Plan (1998) [Member]
Equity-based compensation expense [Abstract]
Maximum number of common units that may be issued as awards (in units)	14,000,000		14,000,000
Remaining number of common units available to be issued as awards (in units)	2,704,337		2,704,337

Equity-based Awards, Restricted Unit Awards (Details) - Restricted Common Unit Awards [Member] - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting rate of restricted common unit awards (in hundredths)

25.00%

Summary of awards activity, equity instruments other than options [Roll Forward]

Beginning of period (in units)

7,221,214

Vested (in units)

(2,586,398)

Forfeited (in units)

(267,200)

End of period (in units)

4,367,616

Restricted units outstanding, weighted-average grant date fair value [Roll Forward]

Weighted-average grant date fair value per unit, at beginning of period (in dollars per unit)

^[1]

$ 25.83

Vested weighted-average grant date fair value per unit (in dollars per unit)

^[1]

23.92

Forfeited weighted-average grant date fair value per unit (in dollars per unit)

^[1]

26.36

Weighted-average grant date fair value per unit, at end of period (in dollars per unit)

^[1]

$ 26.93

Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]

Cash distributions paid to restricted common unitholders

$ 1.6

$ 2.6

$ 5.7

$ 8.2

Total intrinsic value of our restricted common unit awards that vested during period

1.3

$ 1.0

85.4

$ 107.4

Recognition period for total unrecognized compensation cost

37.8

$ 37.8

1 year 7 months 6 days

Enterprise [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

$ 33.6

[1]	Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.

Equity-based Awards, Unit Option Awards (Details) - Unit Option Awards [Member] - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

12 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Vesting period

4 years

Summary of awards activity, options [Roll Forward]

Beginning of period (in units)

^[1]

4,050,000

Exercised (in units)

(2,720,000)

Forfeited (in units)

(60,000)

End of period (in units)

^[1]

1,270,000

4,050,000

Options outstanding, weighted-average strike price [Roll Forward]

Weighted average strike price, beginning of period (in dollars per unit)

$ 13.24

Weighted average strike price, exercised (in dollars per unit)

11.83

Weighted average strike price, forfeited (in dollars per unit)

16.14

Weighted average strike price, end of period (in dollars per unit)

$ 16.14

$ 13.24

Weighted average remaining contractual term

1 year 3 months 18 days

Aggregate intrinsic value

^[2]

$ 30.7

$ 57.0

Total intrinsic value of unit option awards exercised during period

0.0

$ 0.0

57.5

$ 19.8

Cash received from EPCO in connection with the exercise of unit option awards

0.0

33.4

11.5

Unit option award-related cash reimbursements to EPCO

$ 0.0

$ 57.5

$ 19.8

[1]	None of the unit option awards outstanding at September 30, 2014 and December 31, 2013 were exercisable as of such dates, respectively.
[2]	Aggregate intrinsic value reflects fully vested unit option awards at the dates indicated.

Equity-based Awards, Phantom Unit Awards (Details) - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]

Cash payments made in connection with DERs

$ 2.4

$ 0.0

Phantom Unit Awards [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Vesting rate of phantom unit awards (in hundredths)

25.00%

Summary of awards activity, equity instruments other than options [Roll Forward]

Beginning of period (in units)

Granted (in units)

^[1]

3,522,990

Vested (in units)

(34,800)

Forfeited (in units)

(92,800)

End of period (in units)

3,395,390

Phantom units outstanding, weighted-average grant date fair value [Roll Forward]

Weighted-average grant date fair value per unit, at beginning of period (in dollars per unit)

^[2]

$ 0

Granted weighted-average grant date fair value per unit (in dollars per unit)

^[1],[2]

33.12

Vested weighted-average grant date fair value per unit (in dollars per unit)

^[2]

33.04

Forfeited weighted-average grant date fair value per unit (in dollars per unit)

^[2]

33.04

Weighted-average grant date fair value per unit, at end of period (in dollars per unit)

^[2]

$ 33.12

Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]

Aggregate grant date fair value

$ 116.7

Estimated forfeiture rate (in hundredths)

3.40%

Cash payments made in connection with DERs

$ 1.2

$ 0.0

$ 2.4

0.0

Total intrinsic value of phantom unit awards that vested during period

0.1

$ 0.0

1.3

$ 0.0

Recognition period for total unrecognized compensation cost

72.2

$ 72.2

2 years 2 months 12 days

Phantom Unit Awards [Member] | Minimum [Member]

Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]

Grant date market price of common units (in dollars per unit)

$ 33.04

Phantom Unit Awards [Member] | Maximum [Member]

Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]

Grant date market price of common units (in dollars per unit)

$ 37.59

Phantom Unit Awards [Member] | Enterprise [Member]

Interest rate derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Forward Starting Swaps [Member]

$ 66.1

[1]	The aggregate grant date fair value of phantom unit awards issued during 2014 was $116.7 million based on a grant date market price of our common units ranging from $33.04 to $37.59 per unit. An estimated annual forfeiture rate of 3.4% was applied to these awards.
[2]	Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.

Derivative Instruments, Hedging Activities and Fair Value Measurements (Details)
bbl in Millions, $ in Millions, ft³ in Billions

1 Months Ended

3 Months Ended

9 Months Ended

Oct. 31, 2014

USD ($)

Contract

Jul. 31, 2014

USD ($)

Contract

Mar. 31, 2013

USD ($)

Contract

Sep. 30, 2014

USD ($)

Contract

bbl

ft³

Oct. 14, 2014

USD ($)

Number of derivative instruments settled | Contract

Notional amount of settled derivative instruments | $

$ 1,000.0

Accumulated other comprehensive income (loss) related to interest rate derivative instruments | $

$ 168.8

Interest rate derivatives [Member] | Derivatives in fair value hedging relationships [Member]

Loss (gain) recognized due to settlement of derivative instruments | $

$ (27.6)

Interest rate derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Senior Notes AA [Member]

Number of Derivatives Outstanding | Contract

Type of Derivatives Outstanding

fixed-to-floating swaps

Notional Amount | $

$ 750.0

Period of Hedge

1/2011 to 2/2016

Rate Swap, fixed rate (in hundredths)

3.20%

Rate Swap, floating rate (in hundredths)

1.20%

Number of derivative instruments settled | Contract

Notional amount of settled derivative instruments | $

$ 750.0

Loss (gain) recognized due to settlement of derivative instruments | $

(17.6)

Interest rate derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Senior Notes LL [Member]

Number of derivative instruments settled | Contract

Notional amount of settled derivative instruments | $

$ 800.0

Loss (gain) recognized due to settlement of derivative instruments | $

$ (10.0)

Interest rate derivatives [Member] | Derivatives in mark-to-market relationships [Member] | Undesignated Swaps [Member]

Number of derivative instruments settled | Contract

Notional amount of settled derivative instruments | $

$ 600.0

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas processing: Forecasted natural gas purchases for plant thermal reduction (PTR) [Member]

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas processing: Forecasted sales of NGLs [Member]

^[1],[2]

1.1

Forecasted NGL sales designated as normal sales agreements

^[1],[2],[3]

0.3

0.3

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Octane enhancement: Forecasted purchases of NGLs [Member]

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Octane enhancement: Forecasted sales of octane enhancement products [Member]

^[1],[2]

0.3

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas marketing: Forecasted sales of natural gas [Member]

^[1],[2]

0.2

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products [Member]

^[1],[2]

1.7

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | NGL marketing: Forecasted sales of NGLs and related hydrocarbon products [Member]

^[1],[2]

5.2

Long Term Volume

^[1],[2]

0.1

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Refined products marketing: Forecasted purchases of refined products [Member]

^[1],[2]

8.8

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Refined products marketing: Forecasted sales of refined products [Member]

^[1],[2]

0.7

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Crude oil marketing: Forecasted purchases of crude oil [Member]

^[1],[2]

1.3

Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Crude oil marketing: Forecasted sales of crude oil [Member]

^[1],[2]

5.0

Long Term Volume

^[1],[2]

0.5

Commodity derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Natural gas marketing: Natural gas storage inventory management activities [Member]

^[1],[2]

7.0

Long Term Volume

^[1],[2]

0.5

Commodity derivatives [Member] | Derivatives in mark-to-market relationships [Member] | Natural gas risk management activities [Member]

^[1],[2]

5.1

Current natural gas hedging volumes designated as an index plus or minus a discount | ft³

^{[1],[2],[4],[5]}

63.5

Long Term Volume | ft³

^{[1],[2],[4],[5]}

15.3

28.9

Long-term natural gas hedging volumes designated as an index plus or minus a discount | ft³

0.9

Commodity derivatives [Member] | Derivatives in mark-to-market relationships [Member] | Crude oil risk management activities [Member]

Derivatives in fair value hedging relationships [Member]

^[1],[2],[5]

6.7

[1]	The maximum term for derivatives designated as cash flow hedges, derivatives designated as fair value hedges and derivatives not designated as hedging instruments is December 2015, October 2015 and March 2018, respectively.
[2]	Volume for derivatives designated as hedging instruments reflects the total amount of volumes hedged whereas volume for derivatives not designated as hedging instruments reflects the absolute value of derivative notional volumes.
[3]	Forecasted sales of NGL volumes under natural gas processing exclude 0.3 MMBbls of additional hedges executed under contracts that have been designated as normal sales agreements.
[4]	Current and long-term volumes include 28.9 Bcf and 0.9 Bcf, respectively, of physical derivative instruments that are predominantly priced at a marked-based index plus a premium or minus a discount related to location differences.
[5]	Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.

Derivative Instruments, Hedging Activities and Fair Value Measurements, Derivative Fair Value Amounts (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 19.4	$ 32.6
Liability Derivatives	0.0	7.8
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	41.7	41.3
Liability Derivatives	22.0	55.1
Derivatives designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	58.7	63.5
Liability Derivatives	20.9	46.8
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	19.4	32.6
Liability Derivatives	0.0	0.0
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	15.9	20.2
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	3.5	12.4
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.0	0.0
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.0	0.0
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	39.3	30.9
Liability Derivatives	20.9	46.8
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	38.1	30.9
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.2	0.0
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	19.5	46.5
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	1.4	0.3
Derivatives not designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	2.4	10.4
Liability Derivatives	1.1	16.1
Derivatives not designated as hedging instruments [Member] \| Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.0	0.0
Liability Derivatives	0.0	7.8
Derivatives not designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.0	0.0
Derivatives not designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.0	0.0
Derivatives not designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.0	7.8
Derivatives not designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.0	0.0
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	2.4	10.4
Liability Derivatives	1.1	8.3
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.4	7.6
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.0	2.8
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.8	5.5
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	$ 0.3	$ 2.8

Derivative Instruments, Hedging Activities and Fair Value Measurements, Asset Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Interest rate derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 19.4	$ 32.6
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Assets Presented in the Balance Sheet	19.4	32.6
Financial Instruments	0.0	(2.6)
Cash Collateral Received	0.0	0.0
Amounts That Would Have Been Presented On Net Basis	19.4	30.0
Commodity derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	41.7	41.3
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Assets Presented in the Balance Sheet	41.7	41.3
Financial Instruments	(24.8)	(41.0)
Cash Collateral Received	(16.9)	0.0
Amounts That Would Have Been Presented On Net Basis	$ 0.0	$ 0.3

Derivative Instruments, Hedging Activities and Fair Value Measurements, Liability Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Interest rate derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 0.0	$ 7.8
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Liabilities Presented in the Balance Sheet	0.0	7.8
Financial Instruments	0.0	(2.6)
Cash Collateral Paid	0.0	0.0
Amounts That Would Have Been Presented On Net Basis	0.0	5.2
Commodity derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	22.0	55.1
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Liabilities Presented in the Balance Sheet	22.0	55.1
Financial Instruments	(24.8)	(41.0)
Cash Collateral Paid	7.8	(9.3)
Amounts That Would Have Been Presented On Net Basis	$ 5.0	$ 4.8

Derivative Instruments, Hedging Activities and Fair Value Measurements, Gains and Losses on Derivative Instruments and Related Hedged Items (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Recognized in Income on Hedged Item

$ (4.4)

$ (3.6)

$ (8.9)

$ (7.5)

4.9

0.0

7.9

(1.7)

Derivatives in fair value hedging relationships [Member] | Interest rate derivatives [Member] | Location - Interest expense [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Recognized in Income on Hedged Item

(4.1)

(0.5)

(9.5)

(10.6)

3.9

0.4

9.3

10.3

Derivatives in fair value hedging relationships [Member] | Commodity derivatives [Member] | Location - Revenue [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Recognized in Income on Hedged Item

(0.3)

(3.1)

0.6

3.1

1.0

(0.4)

(1.4)

(12.0)

Derivatives in cash flow hedging relationships [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)

58.1

(8.6)

16.1

(15.4)

Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)

10.0

(22.3)

(36.8)

(36.1)

Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)

0.0

0.1

0.0

Derivatives in cash flow hedging relationships [Member] | Interest rate derivatives [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)

0.0

6.7

Accumulated other comprehensive loss related to interest rate derivative instruments expected to be reclassified to earnings in interest expense over the next twelve months

(34.8)

Derivatives in cash flow hedging relationships [Member] | Interest rate derivatives [Member] | Location - Interest expense [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)

(8.0)

(7.7)

(23.9)

(21.4)

Derivatives in cash flow hedging relationships [Member] | Commodity derivatives [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Net accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to earnings over the next twelve months

14.5

Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to revenue over the next twelve months

14.3

Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to operating costs and expenses over the next twelve months

0.2

Derivatives in cash flow hedging relationships [Member] | Commodity derivatives [Member] | Location - Revenue [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)

^[1]

58.8

(8.6)

15.2

(22.1)

Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)

17.8

(14.6)

(14.5)

(15.1)

Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)

0.1

0.0

Derivatives in cash flow hedging relationships [Member] | Commodity derivatives [Member] | Location - Operating costs and expenses [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)

^[1]

(0.7)

0.0

0.9

0.0

Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)

0.2

0.0

1.6

0.4

Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)

(0.1)

0.0

Derivatives not designated as hedging instruments [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Derivatives not designated as hedging instruments [Member] | Interest rate derivatives [Member] | Location - Interest expense [Member]

0.8

7.6

(26.9)

16.4

Derivative Instruments, Gain (Loss) [Line Items]

Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Location - Revenue [Member]

0.0

(0.5)

(0.1)

(0.6)

Derivative Instruments, Gain (Loss) [Line Items]

Unrealized gain (loss) recognized as a component of net income related to financial assets and liabilities

$ 0.8

$ 8.1

$ (26.8)

$ 17.0

[1]	The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Derivative Instruments, Hedging Activities and Fair Value Measurements, Recurring Fair Value Measurements (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Jun. 30, 2014

Mar. 31, 2014

Sep. 30, 2013

Jun. 30, 2013

Mar. 31, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Total gains (losses) included in:

$ 3.8

$ 5.3

Level 3 [Member]

$ 2.9

2.9

Fair Value, Measurements, Recurring [Member] | Level 3 [Member]

3.6

Reconciliation of changes in the fair value of Level 3 financial assets and liabilities [Roll Forward]

Financial asset (liability) balance, net, beginning of period

2.6

^[1]

$ 7.7

$ 3.2

$ (0.2)

^[1]

$ (0.6)

$ (1.5)

3.2

(1.5)

Total gains (losses) included in:

Net income

(0.9)

(3.3)

^[2]

4.6

^[2]

1.1

(0.2)

^[2]

(0.6)

^[2]

Other comprehensive income (loss)

(2.5)

(0.9)

Settlements

0.1

(1.8)

(0.1)

0.1

0.6

1.5

Financial asset (liability) balance, net, end of period

(0.7)

$ 2.6

^[1]

$ 7.7

0.1

$ (0.2)

^[1]

$ (0.6)

(0.7)

0.1

Unrealized gain (loss) recognized as a component of net income related to financial assets and liabilities

(0.8)

$ 1.1

(1.3)

$ 2.4

Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 1 [Member]

0.0

$ 0.0

14.4

17.2

14.4

17.2

0.0

8.2

30.8

Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 2 [Member]

8.2

30.8

19.4

32.6

24.4

20.2

43.8

52.8

0.0

7.8

10.2

23.6

Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 3 [Member]

10.2

31.4

0.0

2.9

3.9

2.9

3.9

0.0

3.6

0.7

Fair Value, Measurements, Recurring [Member] | Carrying Value [Member]

3.6

0.7

19.4

32.6

41.7

41.3

61.1

73.9

0.0

7.8

22.0

55.1

Available-for-Sale Inventory by Product Type [Abstract]

$ 22.0

$ 62.9

[1]	There were no transfers into or out of Level 3 during the three or nine months ended September 30, 2014 and 2013.
[2]	There were $0.8 million and $1.3 million of unrealized losses included in these amounts for the three and nine months ended September 30, 2014, respectively. There were unrealized gains of $1.1 million and $2.4 million included in these amounts for the three and nine months ended September 30, 2013, respectively.

Derivative Instruments, Hedging Activities and Fair Value Measurements, Level 3 Recurring Valuation Techniques (Details) - Level 3 [Member] $ in Millions	9 Months Ended
	Sep. 30, 2014 USD ($) $ / gal $ / MMBTU $ / bbl
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Asset commodity derivatives	$ 2.9
Liability commodity derivatives	3.6
Liability commodity derivatives - Crude oil [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Liability commodity derivatives	0.9
Liability commodity derivatives - Propane [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Liability commodity derivatives	0.1
Liability commodity derivatives - Natural gasoline [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Liability commodity derivatives	2.5
Liability commodity derivatives - Natural gas [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Liability commodity derivatives	0.1
Asset commodity derivatives - Crude oil [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Asset commodity derivatives	$ 2.6
Asset commodity derivatives - Crude oil [Member] \| Liability commodity derivatives - Crude oil [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair Value Measurements, Valuation Techniques	Discounted cash flow
Input description	Forward commodity prices
Asset commodity derivatives - Crude oil [Member] \| Liability commodity derivatives - Crude oil [Member] \| Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / bbl	70.32
Asset commodity derivatives - Crude oil [Member] \| Liability commodity derivatives - Crude oil [Member] \| Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / bbl	91.82
Asset commodity derivatives - Propane [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Asset commodity derivatives	$ 0.0
Asset commodity derivatives - Propane [Member] \| Liability commodity derivatives - Propane [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair Value Measurements, Valuation Techniques	Discounted cash flow
Input description	Forward commodity prices
Asset commodity derivatives - Propane [Member] \| Liability commodity derivatives - Propane [Member] \| Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / gal	1.02
Asset commodity derivatives - Propane [Member] \| Liability commodity derivatives - Propane [Member] \| Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / gal	1.05
Asset commodity derivatives - Natural gasoline [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Asset commodity derivatives	$ 0.1
Asset commodity derivatives - Natural gasoline [Member] \| Liability commodity derivatives - Natural gasoline [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair Value Measurements, Valuation Techniques	Discounted cash flow
Input description	Forward commodity prices
Asset commodity derivatives - Natural gasoline [Member] \| Liability commodity derivatives - Natural gasoline [Member] \| Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / gal	1.84
Asset commodity derivatives - Natural gasoline [Member] \| Liability commodity derivatives - Natural gasoline [Member] \| Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / gal	1.94
Assets commodity derivatives - Natural gas [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Asset commodity derivatives	$ 0.2
Assets commodity derivatives - Natural gas [Member] \| Liability commodity derivatives - Natural gas [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair Value Measurements, Valuation Techniques	Discounted cash flow
Input description	Forward commodity prices
Assets commodity derivatives - Natural gas [Member] \| Liability commodity derivatives - Natural gas [Member] \| Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / MMBTU	3.72
Assets commodity derivatives - Natural gas [Member] \| Liability commodity derivatives - Natural gas [Member] \| Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) \| $ / MMBTU	4.54

Derivative Instruments, Hedging Activities and Fair Value Measurements, Nonrecurring Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	$ 5.7	$ 15.2	$ 18.2	$ 53.3
Impairment of long-lived assets disposed of other than by sale			11.7	43.3
Impairment of long-lived assets held and used				4.2
Impairment of long-lived assets to be disposed of by sale			6.5	5.8
NGL Pipelines and Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	1.2	0.3	6.6	10.0
Onshore Natural Gas Pipelines and Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0.4	0.0	0.7	0.0
Onshore Crude Oil Pipelines and Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0.4	0.0	2.2	16.6
Offshore Pipelines And Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0.0	13.2	0.0	13.2
Petrochemical and Refined Products Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	3.7	1.7	8.7	13.5
Fair Value, Measurements, Nonrecurring [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0	0.0	0.0
Fair Value, Measurements, Nonrecurring [Member] \| Long-lived Assets Held and Used [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		6.1		6.1
Fair Value, Measurements, Nonrecurring [Member] \| Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	1.1	11.7	1.1	11.7
Fair Value, Measurements, Nonrecurring [Member] \| Level 1 [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0	0.0	0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 1 [Member] \| Long-lived Assets Held and Used [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0.0		0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 1 [Member] \| Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	11.7	0.0	11.7
Fair Value, Measurements, Nonrecurring [Member] \| Level 2 [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0	0.0	0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 2 [Member] \| Long-lived Assets Held and Used [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0.0		0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 2 [Member] \| Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0	0.0	0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 3 [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0	0.0	0.0
Fair Value, Measurements, Nonrecurring [Member] \| Level 3 [Member] \| Long-lived Assets Held and Used [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		6.1		6.1
Fair Value, Measurements, Nonrecurring [Member] \| Level 3 [Member] \| Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	$ 1.1	$ 0.0	$ 1.1	$ 0.0

Derivative Instruments, Hedging Activities and Fair Value Measurements, Other Fair Value Measurements (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Carrying Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 18,380	$ 16,880
Level 2 [Member] \| Fair Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 20,100	$ 17,930

Inventories (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

NGLs

$ 973.4

$ 593.8

Petrochemicals and refined products

338.7

395.1

Crude oil

238.8

42.6

Natural gas

38.6

61.6

Total

1,589.5

$ 1,093.1

Summary of cost of sales and lower of cost or market adjustments [Abstract]

Cost of sales

^[1]

10,455.1

$ 10,371.3

32,213.1

$ 29,522.1

Lower of cost or market adjustments

$ 6.7

$ 4.5

$ 14.6

$ 14.9

[1]

Cost of sales is a component of “Operating costs and expenses” as presented on our Unaudited Condensed Statements of Consolidated Operations. Period-to-period fluctuations in these amounts are primarily due to changes in energy commodity prices and sales volumes associated with our marketing activities.

Property, Plant and Equipment (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

Property, plant and equipment and accumulated depreciation [Abstract]

Less accumulated depreciation

$ 35,836.3

$ 34,017.6

7,873.0

7,071.0

Summary of depreciation expense and capitalized interest [Abstract]

27,963.3

26,946.6

Depreciation expense

^[1]

283.2

$ 253.4

822.1

$ 749.6

Capitalized interest

^[2]

17.2

$ 27.8

53.4

$ 95.1

Asset Retirement Obligations [Roll Forward]

Revisions in estimated cash flows

90.2

Liabilities incurred

0.1

Liabilities settled

(2.3)

2.7

Accretion expense

4.5

Capitalized costs, asset retirement costs

95.2

31.8

37.4

Forecasted accretion expense [Abstract]

1.6

6.3

6.5

7.0

7.5

Plants, pipelines and facilities [Member]

Property, plant and equipment and accumulated depreciation [Abstract]

Plants, pipelines and facilities [Member] | Minimum [Member]

^[3]

30,096.7

$ 30,096.7

27,540.4

Property, plant and equipment and accumulated depreciation [Abstract]

Plants, pipelines and facilities [Member] | Maximum [Member]

^[3],[4]

3 years

Property, plant and equipment and accumulated depreciation [Abstract]

Underground and other storage facilities [Member]

^[3],[4]

45 years

Property, plant and equipment and accumulated depreciation [Abstract]

Underground and other storage facilities [Member] | Minimum [Member]

^[5]

2,164.9

$ 2,164.9

2,101.8

Property, plant and equipment and accumulated depreciation [Abstract]

Underground and other storage facilities [Member] | Maximum [Member]

^[5],[6]

5 years

Property, plant and equipment and accumulated depreciation [Abstract]

Platforms and facilities [Member]

^[5],[6]

40 years

Property, plant and equipment and accumulated depreciation [Abstract]

Platforms and facilities [Member] | Minimum [Member]

^[7]

659.7

$ 659.7

659.6

Property, plant and equipment and accumulated depreciation [Abstract]

Platforms and facilities [Member] | Maximum [Member]

^[7]

20 years

Property, plant and equipment and accumulated depreciation [Abstract]

Transportation equipment [Member]

^[7]

31 years

Property, plant and equipment and accumulated depreciation [Abstract]

Transportation equipment [Member] | Minimum [Member]

^[8]

142.0

$ 142.0

138.9

Property, plant and equipment and accumulated depreciation [Abstract]

Transportation equipment [Member] | Maximum [Member]

^[8]

3 years

Property, plant and equipment and accumulated depreciation [Abstract]

Property, plant and equipment and accumulated depreciation [Abstract]

^[8]

10 years

Marine vessels [Member]

Marine vessels [Member] | Minimum [Member]

^[9]

782.3

$ 782.3

744.8

Property, plant and equipment and accumulated depreciation [Abstract]

Marine vessels [Member] | Maximum [Member]

^[9]

15 years

Property, plant and equipment and accumulated depreciation [Abstract]

Property, plant and equipment and accumulated depreciation [Abstract]

^[9]

30 years

Land [Member]

Construction in progress [Member]

185.0

$ 185.0

176.6

Property, plant and equipment and accumulated depreciation [Abstract]

Processing plants [Member] | Minimum [Member]

$ 1,805.7

$ 2,655.5

Property, plant and equipment and accumulated depreciation [Abstract]

Processing plants [Member] | Maximum [Member]

20 years

Property, plant and equipment and accumulated depreciation [Abstract]

Pipelines and related equipment [Member] | Minimum [Member]

35 years

Property, plant and equipment and accumulated depreciation [Abstract]

Pipelines and related equipment [Member] | Maximum [Member]

5 years

Property, plant and equipment and accumulated depreciation [Abstract]

Terminal facilities [Member] | Minimum [Member]

45 years

Property, plant and equipment and accumulated depreciation [Abstract]

Terminal facilities [Member] | Maximum [Member]

10 years

Property, plant and equipment and accumulated depreciation [Abstract]

Office furniture and equipment [Member] | Minimum [Member]

35 years

Property, plant and equipment and accumulated depreciation [Abstract]

Office furniture and equipment [Member] | Maximum [Member]

3 years

Property, plant and equipment and accumulated depreciation [Abstract]

Buildings [Member] | Minimum [Member]

20 years

Property, plant and equipment and accumulated depreciation [Abstract]

Buildings [Member] | Maximum [Member]

20 years

Property, plant and equipment and accumulated depreciation [Abstract]

Laboratory and shop equipment [Member] | Minimum [Member]

40 years

Property, plant and equipment and accumulated depreciation [Abstract]

Laboratory and shop equipment [Member] | Maximum [Member]

5 years

Property, plant and equipment and accumulated depreciation [Abstract]

Underground storage facilities [Member] | Minimum [Member]

35 years

Property, plant and equipment and accumulated depreciation [Abstract]

Underground storage facilities [Member] | Maximum [Member]

5 years

Property, plant and equipment and accumulated depreciation [Abstract]

Storage tanks [Member] | Minimum [Member]

35 years

Property, plant and equipment and accumulated depreciation [Abstract]

Storage tanks [Member] | Maximum [Member]

10 years

Property, plant and equipment and accumulated depreciation [Abstract]

Water wells [Member] | Minimum [Member]

40 years

Property, plant and equipment and accumulated depreciation [Abstract]

Water wells [Member] | Maximum [Member]

5 years

Property, plant and equipment and accumulated depreciation [Abstract]

Changes in carrying amount of goodwill [Roll Forward]

35 years

[1]	Depreciation expense is a component of “Costs and expenses” as presented on our Unaudited Condensed Statements of Consolidated Operations.
[2]	We capitalize interest costs incurred on funds used to construct property, plant and equipment while the asset is in its construction phase. The capitalized interest is recorded as part of the asset to which it relates and is amortized over the asset’s estimated useful life as a component of depreciation expense. When capitalized interest is recorded, it reduces interest expense from what it would be otherwise.
[3]	Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; office furniture and equipment; buildings; laboratory and shop equipment and related assets.
[4]	In general, the estimated useful lives of major assets within this category are: processing plants, 20-35 years; pipelines and related equipment, 5-45 years; terminal facilities, 10-35 years; office furniture and equipment, 3-20 years; buildings, 20-40 years; and laboratory and shop equipment, 5-35 years.
[5]	Underground and other storage facilities include underground product storage caverns; above ground storage tanks; water wells and related assets.
[6]	In general, the estimated useful lives of assets within this category are: underground storage facilities, 5-35 years; storage tanks, 10-40 years; and water wells, 5-35 years.
[7]	Platforms and facilities include offshore platforms and related facilities and other associated assets located in the Gulf of Mexico.
[8]	Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations.
[9]	Marine vessels include tow boats, barges and related equipment used in our marine transportation business.

Property, Plant and Equipment, Significant Sales (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Significant Acquisitions and Disposals [Line Items]
Proceeds from disposal of assets	$ 121.5	$ 256.3
Gains attributable to disposal of assets	99.0	68.4
Seminole Pipeline segment [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from disposal of assets	0.0	86.9
Gains attributable to disposal of assets	0.0	52.5
Lubrication oil and specialty chemical distribution assets [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from disposal of assets	$ 0.0	35.3
Gains attributable to disposal of assets		$ 6.7

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2,938.3		$ 2,938.3		$ 2,437.1
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	72.3	$ 44.0	179.1	$ 126.1
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	55.8		55.8		58.1
Equity method investment amortization of excess cost	0.7	0.8	2.3	2.5
NGL Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	11.7	4.1	19.2	11.8
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	26.8		26.8		27.7
Equity method investment amortization of excess cost	$ 0.2	0.3	$ 0.9	0.9
NGL Pipelines & Services [Member] \| Venice Energy Service Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	13.10%		13.10%
Investments in unconsolidated affiliates	$ 26.9		$ 26.9		27.6
NGL Pipelines & Services [Member] \| K/D/S Promix, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 46.1		$ 46.1		45.4
NGL Pipelines & Services [Member] \| Baton Rouge Fractionators LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	32.20%		32.20%
Investments in unconsolidated affiliates	$ 19.1		$ 19.1		19.5
NGL Pipelines & Services [Member] \| Skelly-Belvieu Pipeline Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 39.7		$ 39.7		40.8
NGL Pipelines & Services [Member] \| Texas Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	35.00%		35.00%
Investments in unconsolidated affiliates	$ 348.4		$ 348.4		339.9
NGL Pipelines & Services [Member] \| Texas Express Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	45.00%		45.00%
Investments in unconsolidated affiliates	$ 37.8		$ 37.8		37.8
NGL Pipelines & Services [Member] \| Front Range Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	33.30%		33.30%
Investments in unconsolidated affiliates	$ 167.8		$ 167.8		134.5
Onshore Natural Gas Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	$ 0.9	1.0	$ 2.7	2.9
Onshore Natural Gas Pipelines & Services [Member] \| White River Hub, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 23.5		$ 23.5		24.2
Onshore Crude Oil Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	46.8	34.3	131.7	101.0
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	17.3		17.3		17.8
Equity method investment amortization of excess cost	$ 0.2	0.1	$ 0.5	0.5
Onshore Crude Oil Pipelines & Services [Member] \| Seaway Crude Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 1,372.2		$ 1,372.2		940.7
Onshore Crude Oil Pipelines & Services [Member] \| Eagle Ford Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 279.5		$ 279.5		224.5
Offshore Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	17.1	9.8	35.8	24.9
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	9.2		9.2		10.0
Equity method investment amortization of excess cost	$ 0.3	0.3	$ 0.8	1.0
Offshore Pipelines & Services [Member] \| Poseidon Oil Pipeline Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	36.00%		36.00%
Investments in unconsolidated affiliates	$ 34.3		$ 34.3		41.7
Offshore Pipelines & Services [Member] \| Cameron Highway Oil Pipeline Company [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 204.2		$ 204.2		207.7
Offshore Pipelines & Services [Member] \| Deepwater Gateway LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 81.1		$ 81.1		84.5
Offshore Pipelines & Services [Member] \| Neptune Pipeline Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	25.70%		25.70%
Investments in unconsolidated affiliates	$ 35.4		$ 35.4		38.7
Offshore Pipelines & Services [Member] \| Southeast Keathley Canyon Pipeline Company, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 147.4		$ 147.4		159.2
Petrochemical & Refined Products Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income of unconsolidated affiliates	(4.2)	(5.2)	(10.3)	(14.5)
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	2.5		2.5		2.6
Equity method investment amortization of excess cost	$ 0.0	$ 0.1	$ 0.1	$ 0.1
Petrochemical & Refined Products Services [Member] \| Baton Rouge Propylene Concentrator, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	30.00%		30.00%
Investments in unconsolidated affiliates	$ 6.7		$ 6.7		7.6
Petrochemical & Refined Products Services [Member] \| Centennial Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%		50.00%
Investments in unconsolidated affiliates	$ 65.6		$ 65.6		60.1
Petrochemical & Refined Products Services [Member] \| Other Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2.6		$ 2.6		$ 2.7

Intangible Assets and Goodwill, Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Identifiable intangible assets [Abstract]
Gross Value	$ 2,599.5		$ 2,599.5		$ 2,612.2
Accumulated Amortization	(1,208.4)		(1,208.4)		(1,150.0)
Carrying Value	1,391.1		1,391.1		1,462.2
Amortization Expense	23.5	$ 26.6	72.7	$ 80.2
Forecasted amortization expense [Abstract]
Remainder of 2014	22.2		22.2
2015	86.0		86.0
2016	81.6		81.6
2017	86.1		86.1
2018	89.5		89.5
NGL Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	618.7		618.7		622.1
Accumulated Amortization	(354.1)		(354.1)		(336.9)
Carrying Value	264.6		264.6		285.2
Amortization Expense	8.1	8.6	25.4	27.7
NGL Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	340.8		340.8		340.8
Accumulated Amortization	(179.0)		(179.0)		(165.7)
Carrying Value	161.8		161.8		175.1
NGL Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	277.9		277.9		281.3
Accumulated Amortization	(175.1)		(175.1)		(171.2)
Carrying Value	102.8		102.8		110.1
Onshore Natural Gas Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,629.6		1,629.6		1,629.7
Accumulated Amortization	(646.0)		(646.0)		(611.9)
Carrying Value	983.6		983.6		1,017.8
Amortization Expense	11.1	13.3	34.2	38.0
Onshore Natural Gas Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,163.6		1,163.6		1,163.6
Accumulated Amortization	(302.3)		(302.3)		(281.2)
Carrying Value	861.3		861.3		882.4
Onshore Natural Gas Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	466.0		466.0		466.1
Accumulated Amortization	(343.7)		(343.7)		(330.7)
Carrying Value	122.3		122.3		135.4
Onshore Crude Oil Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	10.0		10.0		11.1
Accumulated Amortization	(6.4)		(6.4)		(6.6)
Carrying Value	3.6		3.6		4.5
Amortization Expense	0.3	0.3	0.9	1.0
Onshore Crude Oil Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	9.6		9.6		10.7
Accumulated Amortization	(6.1)		(6.1)		(6.3)
Carrying Value	3.5		3.5		4.4
Onshore Crude Oil Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	0.4		0.4		0.4
Accumulated Amortization	(0.3)		(0.3)		(0.3)
Carrying Value	0.1		0.1		0.1
Offshore Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	197.0		197.0		205.1
Accumulated Amortization	(153.1)		(153.1)		(150.4)
Carrying Value	43.9		43.9		54.7
Amortization Expense	2.5	2.9	7.6	8.8
Offshore Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	195.8		195.8		203.9
Accumulated Amortization	(152.6)		(152.6)		(150.0)
Carrying Value	43.2		43.2		53.9
Offshore Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	1.2		1.2		1.2
Accumulated Amortization	(0.5)		(0.5)		(0.4)
Carrying Value	0.7		0.7		0.8
Petrochemical & Refined Products Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	144.2		144.2		144.2
Accumulated Amortization	(48.8)		(48.8)		(44.2)
Carrying Value	95.4		95.4		100.0
Amortization Expense	1.5	$ 1.5	4.6	$ 4.7
Petrochemical & Refined Products Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	104.3		104.3		104.3
Accumulated Amortization	(42.1)		(42.1)		(38.2)
Carrying Value	62.2		62.2		66.1
Petrochemical & Refined Products Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	39.9		39.9		39.9
Accumulated Amortization	(6.7)		(6.7)		(6.0)
Carrying Value	$ 33.2		$ 33.2		$ 33.9

Intangible Assets and Goodwill, Goodwill (Details) - USD ($)
$ in Millions

9 Months Ended

Sep. 30, 2014

Dec. 31, 2013

^[1]

$ 2,080.0

0.0

(0.1)

Accumulated impairment charges

^[1]

2,079.9

1.3

$ 1.3

Fixed assets transferred

$ 73.7

NGL Pipelines & Services [Member]

Changes in carrying amount of goodwill [Roll Forward]

341.2

520.0

0.0

Onshore Natural Gas Pipelines & Services [Member]

861.2

Changes in carrying amount of goodwill [Roll Forward]

296.3

0.0

0.0

Onshore Crude Oil Pipelines & Services [Member]

296.3

Changes in carrying amount of goodwill [Roll Forward]

305.1

0.0

0.0

Offshore Pipelines & Services [Member]

305.1

Changes in carrying amount of goodwill [Roll Forward]

82.1

0.0

(0.1)

Petrochemical & Refined Products Services [Member]

82.0

Changes in carrying amount of goodwill [Roll Forward]

1,055.3

(520.0)

0.0

$ 535.3

[1]	The total carrying amount of goodwill at September 30, 2014 and December 31, 2013 is net of $1.3 million of accumulated impairment charges. No goodwill impairment charges were recorded during the nine months ended September 30, 2014.

Debt Obligations (Details) - USD ($)
$ in Millions

1 Months Ended

9 Months Ended

Oct. 31, 2014

Jan. 31, 2014

Sep. 30, 2014

Sep. 30, 2013

Oct. 14, 2014

Oct. 02, 2014

May 01, 2014

Feb. 28, 2014

Dec. 31, 2013

Other, non-principal amounts

$ 19,672.7

$ 17,357.7

(26.3)

(6.2)

Less current maturities of debt

^[1]

(1,939.9)

(1,125.0)

Total long-term debt

17,706.5

16,226.5

Net borrowings under debt agreements

7,167.5

$ 10,139.2

Letters of credit outstanding for facilities and motor fuel tax obligations

2.5

EPO $1.5 Billion 364-Day Credit Agreement [Member]

Senior Debt Obligations [Member]

$ 1,500.0

Senior Debt Obligations [Member] | Commercial Paper Notes [Member]

18,140.0

15,825.0

$ 1,290.0

^[2]

475.0

Senior Debt Obligations [Member] | Commercial Paper Notes [Member] | Minimum [Member]

fixed

Senior Debt Obligations [Member] | Commercial Paper Notes [Member] | Maximum [Member]

0.22%

Senior Debt Obligations [Member] | EPO Senior Notes O [Member]

0.29%

$ 0.0

500.0

fixed

9.75%

Repayment of senior notes

Jan. 31, 2014

$ 500.0

Senior Debt Obligations [Member] | EPO 364 Day Credit Agreement [Member]

Senior Debt Obligations [Member] | EPO Senior Notes G [Member]

$ 1,000.0

$ 650.0

650.0

fixed

5.60%

Repayment of senior notes

Oct. 15, 2014

$ 650.0

Senior Debt Obligations [Member] | EPO Senior Notes I [Member]

$ 250.0

250.0

fixed

5.00%

Senior Debt Obligations [Member] | EPO Senior Notes X [Member]

Mar. 01, 2015

$ 400.0

400.0

fixed

3.70%

Senior Debt Obligations [Member] | EPO Senior Notes FF [Member]

Jun. 01, 2015

$ 650.0

650.0

fixed

1.25%

Senior Debt Obligations [Member] | EPO $1.5 Billion 364-Day Credit Agreement [Member]

Aug. 13, 2015

$ 0.0

$ 1,500.0

0.0

variable

Sep. 29, 2015

Maximum bank commitments increase

$ 1,500.0

200.0

Senior Debt Obligations [Member] | EPO Senior Notes AA [Member]

$ 750.0

750.0

fixed

3.20%

Senior Debt Obligations [Member] | EPO Senior Notes L [Member]

Feb. 01, 2016

$ 800.0

800.0

fixed

6.30%

Senior Debt Obligations [Member] | EPO Senior Notes V [Member]

Sep. 01, 2017

$ 349.7

349.7

fixed

6.65%

Senior Debt Obligations [Member] | EPO $3.5 Billion Multi-Year Revolving Credit Facility [Member]

Apr. 15, 2018

$ 0.0

0.0

variable

Jun. 19, 2018

Information regarding variable interest rates paid [Abstract]

$ 3,500.0

Variable Interest Rates Paid, Minimum (in hundredths)

1.13%

Variable Interest Rates Paid, Maximum (in hundredths)

1.14%

Weighted-Average Interest Rate Paid (in hundredths)

1.13%

Senior Debt Obligations [Member] | EPO Senior Notes N [Member]

$ 700.0

700.0

fixed

6.50%

Senior Debt Obligations [Member] | EPO Senior Notes Q [Member]

Jan. 31, 2019

$ 500.0

500.0

fixed

5.25%

Senior Debt Obligations [Member] | EPO Senior Notes Y [Member]

Jan. 31, 2020

$ 1,000.0

1,000.0

fixed

5.20%

Senior Debt Obligations [Member] | EPO Senior Notes CC [Member]

Sep. 01, 2020

$ 650.0

650.0

fixed

4.05%

Senior Debt Obligations [Member] | EPO Senior Notes HH [Member]

Feb. 15, 2022

$ 1,250.0

1,250.0

fixed

3.35%

Senior Debt Obligations [Member] | EPO Senior Notes JJ [Member]

Mar. 15, 2023

$ 850.0

0.0

fixed

3.90%

Aggregate debt principal issued

Feb. 15, 2024

$ 850.0

Debt issued as percent of principal amount (in hundredths)

99.811%

Senior Debt Obligations [Member] | EPO Senior Notes D [Member]

$ 500.0

500.0

fixed

6.875%

Senior Debt Obligations [Member] | EPO Senior Notes H [Member]

Mar. 01, 2033

$ 350.0

350.0

fixed

6.65%

Senior Debt Obligations [Member] | EPO Senior Notes J [Member]

Oct. 15, 2034

$ 250.0

250.0

fixed

5.75%

Senior Debt Obligations [Member] | EPO Senior Notes W [Member]

Mar. 01, 2035

$ 399.6

399.6

fixed

7.55%

Senior Debt Obligations [Member] | EPO Senior Notes R [Member]

Apr. 15, 2038

$ 600.0

600.0

fixed

6.125%

Senior Debt Obligations [Member] | EPO Senior Notes Z [Member]

Oct. 15, 2039

$ 600.0

600.0

fixed

6.45%

Senior Debt Obligations [Member] | EPO Senior Notes BB [Member]

Sep. 01, 2040

$ 750.0

750.0

fixed

5.95%

Senior Debt Obligations [Member] | EPO Senior Notes DD [Member]

Feb. 01, 2041

$ 600.0

600.0

fixed

5.70%

Senior Debt Obligations [Member] | EPO Senior Notes EE [Member]

Feb. 15, 2042

$ 750.0

750.0

fixed

4.85%

Senior Debt Obligations [Member] | EPO Senior Notes GG [Member]

Aug. 15, 2042

$ 1,100.0

1,100.0

fixed

4.45%

Senior Debt Obligations [Member] | EPO Senior Notes II [Member]

Feb. 15, 2043

$ 1,000.0

1,000.0

fixed

4.85%

Senior Debt Obligations [Member] | EPO Senior Notes KK [Member]

Mar. 15, 2044

$ 1,150.0

0.0

fixed

5.10%

Aggregate debt principal issued

Feb. 15, 2045

$ 1,150.0

Debt issued as percent of principal amount (in hundredths)

99.845%

Senior Debt Obligations [Member] | TEPPCO Senior Notes 4 [Member]

$ 0.3

0.3

fixed

6.65%

Senior Debt Obligations [Member] | TEPPCO Senior Notes 5 [Member]

Apr. 15, 2018

$ 0.4

0.4

fixed

7.55%

Senior Debt Obligations [Member] | EPO Senior Notes LL, MM, NN and II [Member]

Apr. 15, 2038

Aggregate debt principal issued

$ 2,750.0

Net borrowings under debt agreements

$ 2,730.0

Junior Debt Obligations [Member] | EPO Junior Subordinated Notes A [Member]

^[3]

$ 550.0

550.0

^[3]

fixed/variable

^[3]

8.375%

Date through which interest rate is fixed

^[3]

Aug. 31, 2066

8/1/2016

Variable annual interest rate thereafter, variable rate basis

3-month LIBOR

Variable interest rate (in hundredths)

3.7075%

Junior Debt Obligations [Member] | EPO Junior Subordinated Notes C [Member]

^[4]

$ 285.8

285.8

^[4]

fixed/variable

^[4]

7.00%

Date through which interest rate is fixed

^[4]

Jun. 01, 2067

9/1/2017

Variable annual interest rate thereafter, variable rate basis

3-month LIBOR

Variable interest rate (in hundredths)

2.7775%

Junior Debt Obligations [Member] | EPO Junior Subordinated Notes B [Member]

^[5]

$ 682.7

682.7

^[5]

fixed/variable

^[5]

7.034%

Date through which interest rate is fixed

^[5]

Jan. 15, 2068

1/15/2018

Variable annual interest rate thereafter, variable rate basis

3-month LIBOR

Variable interest rate (in hundredths)

2.68%

Minimum variable annual interest rate (in hundredths)

7.034%

Junior Debt Obligations [Member] | TEPPCO Junior Subordinated Notes [Member]

$ 14.2

^[4]

fixed/variable

^[4]

Jun. 01, 2067

[1]	We expect to refinance the current maturities of our debt obligations at or prior to their maturity. Long-term and current maturities of debt reflect the classification of such obligations at September 30, 2014 after taking into consideration the long-term refinancing of Senior Notes G and $650 million of Commercial Paper Notes using proceeds from the issuance of senior notes in October 2014 (see Note 18).
[2]	Principal amounts outstanding at September 30, 2014 have fixed rates ranging from 0.22% and 0.29% and are due in October 2014.
[3]	Fixed rate of 8.375% through August 1, 2016; thereafter, variable rate based on 3-month LIBOR plus 3.7075%.
[4]	Fixed rate of 7.0% through September 1, 2017; thereafter, variable rate based on 3-month LIBOR plus 2.7775%.
[5]	Fixed rate of 7.034% through January 15, 2018; thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.68%.

Debt Obligations, Debt Maturities (Details) - USD ($) $ in Millions	Sep. 30, 2014	Dec. 31, 2013
Scheduled Maturities of Debt [Abstract]
Remainder of 2014	$ 1,940.0
2015	1,300.0
2016	750.0
2017	800.0
2018	350.0
After 2018	14,532.7
Total	19,672.7	$ 17,357.7
Commercial Paper Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2014	1,290.0
2015	0.0
2016	0.0
2017	0.0
2018	0.0
After 2018	0.0
Total	1,290.0
Senior Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2014	650.0
2015	1,300.0
2016	750.0
2017	800.0
2018	350.0
After 2018	13,000.0
Total	16,850.0
Junior Subordinated Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2014	0.0
2015	0.0
2016	0.0
2017	0.0
2018	0.0
After 2018	1,532.7
Total	$ 1,532.7

Equity and Distributions, Summary of Changes in Outstanding Units (Details)	9 Months Ended
	Sep. 30, 2014 shares
Common Units (Unrestricted) [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	1,864,148,802
Common units issued in connection with at-the-market program (in units)	1,590,334
Common units issued in connection with DRIP and EUPP (in units)	7,355,904
Common units issued in connection with the vesting and exercise of unit options (in units)	1,014,108
Common units issued in connection with the vesting of phantom unit awards (in units)	20,842
Common units issued in connection with the vesting of restricted common unit awards (in units)	2,586,398
Forfeiture of restricted common unit awards (in units)	0
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (in units)	(878,017)
Other (in units)	17,202
Ending Balance (in units)	1,875,855,573
Restricted Common Units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	7,221,214
Common units issued in connection with at-the-market program (in units)	0
Common units issued in connection with DRIP and EUPP (in units)	0
Common units issued in connection with the vesting and exercise of unit options (in units)	0
Common units issued in connection with the vesting of phantom unit awards (in units)	0
Common units issued in connection with the vesting of restricted common unit awards (in units)	(2,586,398)
Forfeiture of restricted common unit awards (in units)	(267,200)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (in units)	0
Other (in units)	0
Ending Balance (in units)	4,367,616
Common units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	1,871,370,016
Common units issued in connection with at-the-market program (in units)	1,590,334
Common units issued in connection with DRIP and EUPP (in units)	7,355,904
Common units issued in connection with the vesting and exercise of unit options (in units)	1,014,108
Common units issued in connection with the vesting of phantom unit awards (in units)	20,842
Common units issued in connection with the vesting of restricted common unit awards (in units)	0
Forfeiture of restricted common unit awards (in units)	(267,200)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (in units)	(878,017)
Other (in units)	17,202
Ending Balance (in units)	1,880,223,189

Equity and Distributions, Issuances of Equity (Details) $ in Millions		1 Months Ended	9 Months Ended
	Nov. 07, 2014 USD ($)	Oct. 31, 2014 USD ($) shares	Sep. 30, 2014 USD ($) shares	Sep. 30, 2013 USD ($) shares
Registration Statements and Equity Offerings [Line Items]
Common units issued in connection with acquisition of Oiltanking (in units) \| shares		54,807,352
Net Cash Proceeds from Sale of Common Units [Abstract]
Net cash proceeds from the issuance of common units			$ 304.9	$ 1,134.7
Unit split conversion ratio			2
Distribution Reinvestment Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units) \| shares			140,000,000
Remaining units available for issuance (in units) \| shares			29,812,978
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units) \| shares			7,148,778	7,298,646
Net cash proceeds from the issuance of common units			$ 240.0	$ 206.0
Distribution Reinvestment Plan [Member] \| EPCO and affiliates [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units) \| shares			2,232,872
Net cash proceeds from the issuance of common units	$ 25.0		$ 75.0
Employee Unit Purchase Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units) \| shares			8,000,000
Remaining units available for issuance (in units) \| shares			7,219,762
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units) \| shares			207,126	221,662
Net cash proceeds from the issuance of common units			$ 7.4	$ 6.6
Shelf Registration 2013 [Member]
Registration Statements and Equity Offerings [Line Items]
Senior notes issued under universal shelf registration		$ 2,750.0	2,000.0
2013 At-the-Market Registration [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance			1,250.0
Remaining units available for issuance			$ 1,190.0
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units) \| shares			1,590,334
Gross proceeds from the sale of common units			$ 58.3
Net cash proceeds from the issuance of common units			$ 57.7
2012 At-the-Market Registration [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units) \| shares				14,569,614
Gross proceeds from the sale of common units				$ 439.6
Net cash proceeds from the issuance of common units				$ 435.5

Equity and Distributions, Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			$ (359.0)	$ (370.4)
Other comprehensive income before reclassifications			16.1	(15.0)
Amounts reclassified from accumulated other comprehensive loss			36.8	36.1
Total other comprehensive income (loss)	$ 48.1	$ 13.7	52.9	21.1
Ending Balance	(306.1)	(349.3)	(306.1)	(349.3)
Interest expense	229.8	208.3	679.6	604.4
Revenue	(12,330.2)	(12,093.3)	(37,760.9)	(34,625.7)
Operating costs and expenses	11,414.8	11,273.5	34,934.4	32,061.1
Total	(699.2)	(592.8)	(2,152.4)	(1,901.4)
Gains and Losses on Cash Flow Hedges [Member] \| Interest rate derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			(347.2)	(383.0)
Other comprehensive income before reclassifications			0.0	6.7
Amounts reclassified from accumulated other comprehensive loss			23.9	21.4
Total other comprehensive income (loss)			23.9	28.1
Ending Balance	(323.3)	(354.9)	(323.3)	(354.9)
Gains and Losses on Cash Flow Hedges [Member] \| Commodity derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			(14.7)	10.1
Other comprehensive income before reclassifications			16.1	(22.1)
Amounts reclassified from accumulated other comprehensive loss			12.9	14.7
Total other comprehensive income (loss)			29.0	(7.4)
Ending Balance	14.3	2.7	14.3	2.7
Other [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			2.9	2.5
Other comprehensive income before reclassifications			0.0	0.4
Amounts reclassified from accumulated other comprehensive loss			0.0	0.0
Total other comprehensive income (loss)			0.0	0.4
Ending Balance	2.9	2.9	2.9	2.9
Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Total	(10.0)	22.3	36.8	36.1
Reclassification out of Accumulated Other Comprehensive Income [Member] \| Gains and Losses on Cash Flow Hedges [Member] \| Interest rate derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Interest expense	8.0	7.7	23.9	21.4
Reclassification out of Accumulated Other Comprehensive Income [Member] \| Gains and Losses on Cash Flow Hedges [Member] \| Commodity derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Revenue	(17.8)	14.6	14.5	15.1
Operating costs and expenses	$ (0.2)	$ 0.0	$ (1.6)	$ (0.4)

Equity and Distributions, Distributions (Details) - $ / shares	3 Months Ended						9 Months Ended
	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Sep. 30, 2014
Distributions to Partners [Abstract]
Number of Designated Units to be excluded from distributions during 2014							45,120,000
Number of Designated Units to be excluded from distributions during 2015	35,380,000						35,380,000
Cash Distribution [Member] \| First Quarter 2014 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)			$ 0.3550
Record Date							Apr. 30, 2014
Payment Date							May 07, 2014
Cash Distribution [Member] \| Second Quarter 2014 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)		$ 0.3600
Record Date							Jul. 31, 2014
Payment Date							Aug. 07, 2014
Cash Distribution [Member] \| Third Quarter 2014 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)	$ 0.3650
Record Date							Oct. 31, 2014
Payment Date							Nov. 07, 2014
Cash Distribution [Member] \| First Quarter 2013 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)						$ 0.3350
Record Date							Apr. 30, 2013
Payment Date							May 07, 2013
Cash Distribution [Member] \| Second Quarter 2013 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)					$ 0.3400
Record Date							Jul. 31, 2013
Payment Date							Aug. 07, 2013
Cash Distribution [Member] \| Third Quarter 2013 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)				$ 0.3450
Record Date							Oct. 31, 2013
Payment Date							Nov. 07, 2013

Business Segments (Details) $ in Millions	3 Months Ended		9 Months Ended
Business Segments (Details) $ in Millions	Sep. 30, 2014 USD ($)	Sep. 30, 2013 USD ($)	Sep. 30, 2014 USD ($) Segment	Sep. 30, 2013 USD ($)
Business Segments [Abstract]
Number of reportable segments \| Segment			5
Segment Gross Operating Margin [Abstract]
Revenues	$ 12,330.2	$ 12,093.3	$ 37,760.9	$ 34,625.7
Subtract operating costs and expenses	(11,414.8)	(11,273.5)	(34,934.4)	(32,061.1)
Add equity in income of unconsolidated affiliates	72.3	44.0	179.1	126.1
Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin	322.7	285.2	936.5	851.7
Add impairment charges not reflected in gross operating margin	5.7	15.2	18.2	53.3
Subtract net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin	(2.6)	(10.2)	(99.0)	(68.4)
Add non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin	21.6	0.0	66.8	0.0
Total segment gross operating margin	1,335.1	1,154.0	3,928.1	3,527.3
Reconciliation of total Segment Gross Operating Margin [Abstract]
Total segment gross operating margin	1,335.1	1,154.0	3,928.1	3,527.3
Adjustments to reconcile total segment gross operating margin to operating income:
Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin	(322.7)	(285.2)	(936.5)	(851.7)
Subtract impairment charges not reflected in gross operating margin	(5.7)	(15.2)	(18.2)	(53.3)
Add net gains attributable to asset sales and insurance recoveries not reflected in gross operating margin (see Note 16)	2.6	10.2	99.0	68.4
Subtract non-refundable deferred revenues attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin	(21.6)	0.0	(66.8)	0.0
Subtract general and administrative costs not reflected in gross operating margin	(50.0)	(43.9)	(150.9)	(138.9)
Operating income	937.7	819.9	2,854.7	2,551.8
Other expense, net	(230.8)	(207.7)	(679.8)	(604.2)
Income before income taxes	$ 706.9	$ 612.2	$ 2,174.9	$ 1,947.6

Business Segments, Segment Reporting Information (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

Dec. 31, 2013

$ 12,319.2

$ 12,085.6

$ 37,697.1

$ 34,605.4

11.0

7.7

63.8

20.3

0.0

Equity in income (loss) of unconsolidated affiliates

12,330.2

12,093.3

37,760.9

34,625.7

72.3

44.0

179.1

126.1

1,335.1

1,154.0

3,928.1

3,527.3

Investments in unconsolidated affiliates (see Note 7)

27,963.3

$ 26,946.6

2,938.3

2,437.1

1,391.1

1,462.2

^[1]

2,079.9

2,080.0

NGL Pipelines and Services [Member]

34,372.6

32,925.9

Equity in income (loss) of unconsolidated affiliates

11.7

4.1

19.2

11.8

264.6

285.2

Onshore Natural Gas Pipelines and Services [Member]

861.2

341.2

Equity in income (loss) of unconsolidated affiliates

0.9

1.0

2.7

2.9

983.6

1,017.8

Onshore Crude Oil Pipelines and Services [Member]

296.3

Equity in income (loss) of unconsolidated affiliates

46.8

34.3

131.7

101.0

3.6

4.5

Offshore Pipelines And Services [Member]

305.1

Equity in income (loss) of unconsolidated affiliates

17.1

9.8

35.8

24.9

43.9

54.7

Petrochemical and Refined Products Services [Member]

82.0

82.1

Equity in income (loss) of unconsolidated affiliates

(4.2)

(5.2)

(10.3)

(14.5)

95.4

100.0

Reportable Business Segments [Member] | NGL Pipelines and Services [Member]

535.3

1,055.3

4,024.0

4,230.6

13,217.2

11,686.0

2.7

0.1

10.2

0.6

3,603.8

2,542.3

10,789.7

7,631.7

Equity in income (loss) of unconsolidated affiliates

7,630.5

6,773.0

24,017.1

19,318.3

11.7

4.1

19.2

11.8

711.5

639.6

2,172.4

1,777.0

Investments in unconsolidated affiliates (see Note 7)

11,768.9

9,957.8

685.8

645.5

264.6

285.2

861.2

341.2

Reportable Business Segments [Member] | Onshore Natural Gas Pipelines and Services [Member]

13,580.5

11,229.7

1,026.5

831.4

3,261.0

2,658.6

5.4

4.1

16.5

12.1

231.0

215.6

835.8

726.7

Equity in income (loss) of unconsolidated affiliates

1,262.9

1,051.1

4,113.3

3,397.4

0.9

1.0

2.7

2.9

195.4

213.4

618.8

601.9

Investments in unconsolidated affiliates (see Note 7)

8,834.7

8,917.3

23.5

24.2

983.6

1,017.8

296.3

Reportable Business Segments [Member] | Onshore Crude Oil Pipelines and Services [Member]

10,138.1

10,255.6

5,435.6

5,435.4

16,236.6

15,358.1

1.5

2.1

31.1

2.1

2,529.5

3,591.3

10,714.5

8,333.0

Equity in income (loss) of unconsolidated affiliates

7,966.6

9,028.8

26,982.2

23,693.2

46.8

34.3

131.7

101.0

190.8

146.0

534.5

579.6

Investments in unconsolidated affiliates (see Note 7)

1,540.6

1,479.9

1,651.7

1,165.2

3.6

4.5

305.1

Reportable Business Segments [Member] | Offshore Pipelines And Services [Member]

3,501.0

2,954.7

41.1

38.2

112.4

118.0

1.4

6.0

5.5

1.2

1.8

4.8

8.0

Equity in income (loss) of unconsolidated affiliates

43.7

41.4

123.2

131.5

17.1

9.8

35.8

24.9

47.1

37.9

120.0

118.1

Investments in unconsolidated affiliates (see Note 7)

1,168.2

1,223.7

502.4

531.8

43.9

54.7

82.0

82.1

Reportable Business Segments [Member] | Petrochemical and Refined Products Services [Member]

1,796.5

1,892.3

1,792.0

1,550.0

4,869.9

4,784.7

0.0

452.2

384.4

1,317.6

1,200.7

Equity in income (loss) of unconsolidated affiliates

2,244.2

1,934.4

6,187.5

5,985.4

(4.2)

(5.2)

(10.3)

(14.5)

190.3

117.1

482.4

450.7

Investments in unconsolidated affiliates (see Note 7)

2,845.2

2,712.4

74.9

70.4

95.4

100.0

535.3

1,055.3

3,550.8

3,938.1

Eliminations [Member]

0.0

0.0

(6,817.7)

(6,735.4)

(23,662.4)

(17,900.1)

Equity in income (loss) of unconsolidated affiliates

(6,817.7)

(6,735.4)

(23,662.4)

(17,900.1)

0.0

0.0

$ 0.0

0.0

$ 0.0

Adjustments [Member]

Investments in unconsolidated affiliates (see Note 7)

1,805.7

2,655.5

0.0

0.0

0.0

$ 1,805.7

$ 2,655.5

[1]	The total carrying amount of goodwill at September 30, 2014 and December 31, 2013 is net of $1.3 million of accumulated impairment charges. No goodwill impairment charges were recorded during the nine months ended September 30, 2014.

Business Segments, Consolidated Revenues and Expenses (Details) - USD ($)
$ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

$ 12,330.2

$ 12,093.3

$ 37,760.9

$ 34,625.7

Other operating costs and expenses

Cost of sales

^[1]

10,455.1

10,371.3

32,213.1

29,522.1

^[2]

633.9

612.0

1,865.6

1,702.4

Depreciation, amortization and accretion

322.7

285.2

936.5

851.7

Net gains attributable to asset sales and insurance recoveries

(2.6)

(10.2)

(99.0)

(68.4)

General and administrative costs

5.7

15.2

18.2

53.3

50.0

43.9

150.9

138.9

Total consolidated costs and expenses

11,464.8

11,317.4

35,085.3

32,200.0

NGL Pipelines and Services [Member]

Onshore Natural Gas Pipelines and Services [Member]

1.2

0.3

6.6

10.0

Onshore Crude Oil Pipelines and Services [Member]

0.4

0.0

0.7

0.0

Offshore Pipelines And Services [Member]

0.4

0.0

2.2

16.6

Petrochemical and Refined Products Services [Member]

0.0

13.2

0.0

13.2

Reportable Business Segments [Member] | NGL Pipelines and Services [Member]

3.7

1.7

8.7

13.5

Sales of NGLs and related products

3,603.4

3,929.8

12,029.8

10,831.3

423.3

300.9

1,197.6

855.3

Reportable Business Segments [Member] | Onshore Natural Gas Pipelines and Services [Member]

4,026.7

4,230.7

13,227.4

11,686.6

Sales of natural gas

775.5

590.7

2,515.7

1,954.1

256.4

244.8

761.8

716.6

Reportable Business Segments [Member] | Onshore Crude Oil Pipelines and Services [Member]

1,031.9

835.5

3,277.5

2,670.7

Sales of crude oil

5,348.2

5,359.7

16,003.5

15,159.9

88.9

77.8

264.2

200.3

Reportable Business Segments [Member] | Offshore Pipelines And Services [Member]

5,437.1

5,437.5

16,267.7

15,360.2

Sales of natural gas

0.0

0.1

0.2

0.3

Sales of crude oil

2.5

1.5

7.5

3.7

40.0

38.0

110.7

119.5

Reportable Business Segments [Member] | Petrochemical and Refined Products Services [Member]

42.5

39.6

118.4

123.5

Sales of petrochemicals and refined products

1,605.4

1,390.1

4,338.2

4,271.5

186.6

159.9

531.7

513.2

Net income attributable to limited partners

$ 1,792.0

$ 1,550.0

$ 4,869.9

$ 4,784.7

[1]	Cost of sales is a component of “Operating costs and expenses” as presented on our Unaudited Condensed Statements of Consolidated Operations. Period-to-period fluctuations in these amounts are primarily due to changes in energy commodity prices and sales volumes associated with our marketing activities.
[2]	Represents cost of operating our plants, pipelines and other fixed assets, excluding depreciation, amortization and accretion charges.

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Revenues - related parties:
Total revenue - related parties	$ 11.0	$ 7.7	$ 63.8	$ 20.3
Costs and expenses - related parties:
Total costs and expenses - related parties	248.6	244.7	826.4	740.9
Accounts receivable - related parties:
Total accounts receivable - related parties	2.6		2.6		$ 6.8
Accounts payable - related parties:
Total accounts payable - related parties	122.6		122.6		150.5
Related Party Transactions [Abstract]
Operating costs and expenses	216.7	218.2	735.5	656.6
General and administrative expenses	31.9	26.5	90.9	84.3
EPCO and affiliates [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties	212.8	218.8	688.0	654.4
Accounts payable - related parties:
Total accounts payable - related parties	102.3		102.3		116.3
Distributions:
Total cash distributions			652.8	601.2
Related Party Transactions [Abstract]
Operating costs and expenses	179.1	190.5	591.7	564.7
General and administrative expenses	$ 33.7	28.3	$ 96.3	89.7
Relationship with Affiliates [Abstract]
Number of Units (in units)	683,993,630		683,993,630
Percentage of Total Units Outstanding (in hundredths)	36.40%		36.40%
Unconsolidated affiliates [Member]
Revenues - related parties:
Total revenue - related parties	$ 11.0	7.7	$ 63.8	20.3
Costs and expenses - related parties:
Total costs and expenses - related parties	35.8	$ 25.9	138.4	$ 86.5
Accounts receivable - related parties:
Total accounts receivable - related parties	2.6		2.6		6.8
Accounts payable - related parties:
Total accounts payable - related parties	$ 20.3		$ 20.3		$ 34.2

Earnings Per Unit (Details) - USD ($)
$ / shares in Units, shares in Millions, $ in Millions

3 Months Ended

9 Months Ended

Sep. 30, 2014

Sep. 30, 2013

Sep. 30, 2014

Sep. 30, 2013

BASIC EARNINGS PER UNIT

$ 691.1

$ 592.0

$ 2,127.6

$ 1,898.0

Undistributed earnings allocated and cash payments on phantom unit awards

^[1]

(1.3)

0.0

(4.0)

0.0

Net income available to common unitholders

$ 689.8

$ 592.0

$ 2,123.6

$ 1,898.0

Basic weighted-average number of common units outstanding (in units)

1,834.2

1,792.6

1,831.1

1,778.2

Basic earnings per unit (in dollars per unit)

$ 0.38

$ 0.33

$ 1.16

$ 1.07

DILUTED EARNINGS PER UNIT

Net income attributable to limited partners

$ 691.1

$ 592.0

$ 2,127.6

$ 1,898.0

Diluted weighted-average number of units outstanding:

Distribution-bearing common units (in units)

1,834.2

1,792.6

1,831.1

1,778.2

Designated Units (in units)

45.1

47.4

45.1

47.4

Class B units (in units)

^[2]

0.0

3.8

0.0

7.2

Phantom units (in units)

^[1]

3.4

0.0

2.8

0.0

Incremental option units (in units)

0.7

2.2

1.0

2.4

Total (in units)

1,883.4

1,846.0

1,880.0

1,835.2

Diluted earnings per unit (in dollars per unit)

$ 0.37

$ 0.32

$ 1.13

$ 1.03

[1]

Each phantom unit award includes a DER, which entitles the recipient to receive cash payments equal to the product of the number of phantom unit awards and the cash distribution per unit paid to Enterprise’s common unitholders. Cash payments made in connection with DERs are nonforfeitable. As a result, the phantom units are considered participating securities for purposes of computing basic earnings per unit. Phantom unit awards were first issued in February 2014.

[2]

The Class B units automatically converted into an equal number of distribution-bearing common units in August 2013.

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Operating lease obligations [Abstract]
Lease and rental expense included in costs and expenses	$ 23.5	$ 19.6	$ 69.2	$ 64.9
Litigation matters [Member]
Loss Contingencies [Line Items]
Litigation accruals on an undiscounted basis	2.5		2.5		$ 3.7
Litigation matters [Member] \| ETP Lawsuit [Member]
Loss Contingencies [Line Items]
Loss contingency, damages awarded			319.4
Loss contingency, total damages sought			535.8
Loss contingency, disgorgement damages sought			150.0
Prejudgment interest			$ 66.4
Post-judgment interest rate (in hundredths)			5.00%
New Lease Agreements [Member]
Contractual obligation [Line Items]
Total lease commitments over the next five years	39.0		$ 39.0
Total lease commitments	$ 150.0		$ 150.0

Insurance Matters (Details) - February 2011 West Storage Incident [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Loss Contingencies [Line Items]
Proceeds from property damage insurance recoveries	$ 95.0	$ 8.8
Gains related to property damage proceeds	$ 95.0	$ 8.8

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	9 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Dec. 31, 2013
Decrease (increase) in:
Accounts receivable - trade	$ 153.6	$ (1,130.0)
Accounts receivable - related parties	4.0	(9.6)
Inventories	(536.9)	(674.2)
Prepaid and other current assets	(44.5)	(31.5)
Other assets	20.0	3.2
Increase (decrease) in:
Accounts payable - trade	(14.2)	114.3
Accounts payable - related parties	(27.7)	(30.4)
Accrued product payables	(13.1)	1,358.1
Accrued interest	(131.7)	(132.6)
Other current liabilities	143.5	29.3
Other liabilities	11.2	(10.5)
Net effect of changes in operating accounts	(435.8)	(513.9)
Liability for construction in progress expenditures	264.9		$ 205.3
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	121.5	256.3
Net gains (losses) attributable to asset sales and insurance recoveries	99.0	68.4
Seminole Pipeline segment [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	0.0	86.9
Net gains (losses) attributable to asset sales and insurance recoveries	0.0	52.5
Chemical Trucking Assets [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	0.0	29.5
Lubrication oil and specialty chemical distribution assets [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	0.0	35.3
Net gains (losses) attributable to asset sales and insurance recoveries		6.7
West Storage Facilities [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	95.0	8.8
Net gains (losses) attributable to asset sales and insurance recoveries	95.0	8.8
Other Disposal of Assets [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	19.1	30.8
Net gains (losses) attributable to asset sales and insurance recoveries	4.0	7.1
Pipeline Line Fill [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	$ 7.4	$ 65.0

Condensed Consolidating Financial Information, Balance Sheet (Details) - USD ($)
$ in Millions

Sep. 30, 2014

Dec. 31, 2013

Sep. 30, 2013

Dec. 31, 2012

$ 1,068.2

$ 122.5

5,320.8

5,475.5

2.6

6.8

1,589.5

1,093.1

384.4

325.5

8,365.5

7,023.4

27,963.3

26,946.6

2,938.3

2,437.1

1,391.1

1,462.2

^[1]

2,079.9

2,080.0

167.4

189.4

42,905.5

40,138.7

^[2]

1,939.9

1,125.0

728.0

723.7

122.6

150.5

5,564.6

5,608.7

172.5

304.3

444.2

326.5

8,971.8

8,238.7

17,706.5

16,226.5

63.2

60.8

182.1

172.3

Equity:

15,757.5

15,214.8

224.4

225.6

15,981.9

15,440.4

$ 14,682.2

$ 13,296.0

Eliminations and Adjustments [Member]

42,905.5

40,138.7

0.0

0.0

(0.5)

(0.2)

0.0

0.7

0.0

0.2

(0.2)

0.0

(15,758.0)

(15,214.5)

0.0

0.0

0.0

(15,757.8)

(15,214.7)

0.0

0.0

(0.5)

(0.2)

0.0

0.0

0.0

(1.5)

(0.5)

(1.7)

0.0

3.5

2.9

0.0

Equity:

(15,733.7)

(15,189.9)

(27.1)

(26.0)

(15,760.8)

(15,215.9)

Subsidiary Issuer (EPO) [Member]

(15,757.8)

(15,214.7)

1,019.7

93.9

1,625.8

1,986.8

104.0

384.7

1,244.3

948.5

167.7

140.9

4,161.5

3,554.8

2,360.6

1,945.0

32,198.8

30,819.9

80.2

76.9

458.8

458.9

124.5

123.5

39,384.4

36,979.0

1,939.9

1,125.0

304.5

103.0

1,472.6

1,541.8

2,003.7

2,388.6

172.2

304.2

63.1

92.3

5,956.0

5,554.9

17,691.6

16,211.6

4.3

10.4

11.8

Equity:

15,722.1

15,196.4

0.0

15,722.1

15,196.4

Other Subsidiaries (Non-guarantor) [Member]

39,384.4

36,979.0

52.1

49.5

3,700.7

3,491.1

1,380.9

1,348.1

346.2

145.4

226.2

191.4

5,706.1

5,225.5

25,601.2

24,999.7

3,452.0

2,921.2

1,326.2

1,385.3

1,621.1

44.7

67.2

37,751.3

36,220.0

0.0

426.9

641.6

146.0

333.8

3,568.1

3,224.5

0.3

0.1

392.4

242.4

4,533.7

4,442.4

14.9

57.3

55.0

172.2

160.5

Equity:

32,903.7

31,475.9

69.5

71.3

32,973.2

31,547.2

Consolidated EPO and Subsidiaries [Member]

37,751.3

36,220.0

1,068.2

122.5

5,320.8

5,475.5

3.1

6.8

1,589.5

1,093.1

383.6

325.5

8,365.2

7,023.4

27,963.3

26,946.6

2,938.3

2,437.1

1,391.1

1,462.2

2,079.9

2,080.0

167.3

189.3

42,905.1

40,138.6

1,939.9

1,125.0

727.8

723.7

122.6

150.7

5,564.6

5,608.7

172.5

304.3

444.2

328.0

8,971.6

8,240.4

17,706.5

16,226.5

59.7

57.9

182.1

172.3

Equity:

15,733.7

15,189.9

251.5

251.6

15,985.2

15,441.5

Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]

42,905.1

40,138.6

(3.6)

(20.9)

(5.7)

(2.4)

(1,481.8)

(1,726.0)

(1.0)

(0.8)

(10.3)

(6.8)

(1,502.4)

(1,756.9)

1.5

1.9

(32,712.5)

(31,304.0)

(15.3)

0.0

0.0

(1.9)

(1.4)

(34,230.6)

(33,060.4)

0.0

(3.6)

(20.9)

(1,496.0)

(1,724.9)

(7.2)

(4.4)

0.0

(11.3)

(6.7)

(1,518.1)

(1,756.9)

0.0

(1.9)

(1.4)

(0.5)

0.0

Equity:

(32,892.1)

(31,482.4)

182.0

180.3

(32,710.1)

(31,302.1)

Enterprise Products Partners L.P. (Guarantor) [Member]

(34,230.6)

(33,060.4)

0.0

0.0

0.0

0.2

0.0

0.1

0.0

0.1

0.2

0.0

15,758.0

15,214.5

0.0

0.0

0.1

15,758.2

15,214.8

0.0

0.2

0.0

0.5

0.0

0.0

0.0

0.0

0.7

0.0

0.0

0.0

0.0

Equity:

15,757.5

15,214.8

0.0

15,757.5

15,214.8