Enterprise Products Partners (EPD) 10-Q 6 May 16 2016 Q1 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2016	Apr. 29, 2016
Document and Entity Information [Abstract]
Entity Registrant Name	ENTERPRISE PRODUCTS PARTNERS L P
Entity Central Index Key	1,061,219
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		2,081,508,834
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2016

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 160.6	$ 19
Restricted cash	136.9	15.9
Accounts receivable - trade, net of allowance for doubtful accounts of $11.9 at March 31, 2016 and $12.1 at December 31, 2015	2,449.4	2,569.9
Accounts receivable - related parties	1.1	1.2
Inventories	1,232.1	1,038.1
Derivative assets	234.9	258.6
Prepaid and other current assets	377.6	395.6
Total current assets	4,592.6	4,298.3
Property, plant and equipment, net	32,673.3	32,034.7
Investments in unconsolidated affiliates	2,684.1	2,628.5
Intangible assets, net of accumulated amortization of $1,282.1 at March 31, 2016 and $1,235.8 at December 31, 2015	3,990.9	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	51.3	58.3
Total assets	49,737.4	48,802.2
Current liabilities:
Current maturities of debt	835.9	1,863.9
Accounts payable - trade	743.5	860.1
Accounts payable - related parties	37.4	84.1
Accrued product payables	2,690.1	2,484.4
Accrued liability related to EFS Midstream acquisition	996.5	993.2
Accrued interest	193.9	352.1
Other current liabilities	516.1	528.8
Total current liabilities	6,013.4	7,166.6
Long-term debt	21,919.8	20,676.9
Deferred tax liabilities	50.2	46.1
Other long-term liabilities	$ 407.7	$ 411.5
Commitments and contingencies
Limited partners:
Common units (2,055,907,178 units outstanding at March 31, 2016 and 2,012,553,024 units outstanding at December 31, 2015)	$ 21,397.4	$ 20,514.3
Accumulated other comprehensive loss	(268.5)	(219.2)
Total partners' equity	21,128.9	20,295.1
Noncontrolling interests	217.4	206
Total equity	21,346.3	20,501.1
Total liabilities and equity	$ 49,737.4	$ 48,802.2

UNAUDITED CONDENSED CONSOLIDAT3

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Accounts receivable, allowance for doubtful accounts	$ 11.9	$ 12.1
Intangible assets, accumulated amortization	$ 1,282.1	$ 1,235.8
Limited partners:
Capital account, units outstanding (in units)	2,055,907,178	2,012,553,024

UNAUDITED CONDENSED STATEMENTS

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Revenues:
Third parties	$ 4,989.7	$ 7,466.4
Related parties	15.6	6.1
Total revenues	5,005.3	7,472.5
Operating costs and expenses:
Third parties	3,866.3	6,384.3
Related parties	280.6	232.1
Total operating costs and expenses	4,146.9	6,616.4
General and administrative costs:
Third parties	14.3	20.3
Related parties	29.6	29
Total general and administrative costs	43.9	49.3
Total costs and expenses	4,190.8	6,665.7
Equity in income of unconsolidated affiliates	101.1	89.2
Operating income	915.6	896
Other income (expense):
Interest expense	(240.6)	(239.1)
Other, net	3.6	0.5
Total other expense, net	(237)	(238.6)
Income before income taxes	678.6	657.4
Provision for income taxes	(8.4)	(6.8)
Net income	670.2	650.6
Net income attributable to noncontrolling interests	(9)	(14.5)
Net income attributable to limited partners	$ 661.2	$ 636.1
Earnings per unit:
Basic earnings per unit (in dollars per unit)	$ 0.32	$ 0.33
Diluted earnings per unit (in dollars per unit)	$ 0.32	$ 0.32

UNAUDITED CONDENSED STATEMENTS5

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
Net income	$ 670.2	$ 650.6
Commodity derivative instruments:
Changes in fair value of cash flow hedges	(1.2)	30.8
Reclassification of gains to net income	(57.2)	(61.1)
Interest rate derivative instruments:
Reclassification of losses to net income	9.2	8.7
Total cash flow hedges	(49.2)	(21.6)
Other	(0.1)	0
Total other comprehensive loss	(49.3)	(21.6)
Comprehensive income	620.9	629
Comprehensive income attributable to noncontrolling interests	(9)	(14.5)
Comprehensive income attributable to limited partners	$ 611.9	$ 614.5

UNAUDITED CONDENSED STATEMENTS6

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating activities:
Net income	$ 670.2	$ 650.6
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	382.1	367.4
Non-cash asset impairment charges	1.7	33.3
Equity in income of unconsolidated affiliates	(101.1)	(89.2)
Distributions received on earnings from unconsolidated affiliates	106.7	134.4
Net losses (gains) attributable to asset sales	4.9	(0.1)
Deferred income tax expense	4.1	1.5
Changes in fair market value of derivative instruments	20.1	(4.6)
Net effect of changes in operating accounts	(186.4)	(139)
Other operating activities	(2.6)	(0.3)
Net cash flows provided by operating activities	899.7	954
Investing activities:
Capital expenditures	(1,007.2)	(812.8)
Contributions in aid of construction costs	12.2	19.6
Increase in restricted cash	(121)	(28.2)
Investments in unconsolidated affiliates	(70.4)	(68.3)
Distributions received for return of capital from unconsolidated affiliates	9.1	0
Proceeds from asset sales	13.4	0.5
Other investing activities	0	0.1
Cash used in investing activities	(1,163.9)	(889.1)
Financing activities:
Borrowings under debt agreements	20,000.6	9,182.5
Repayments of debt	(19,797.4)	(8,953.2)
Debt issuance costs	0	(0.1)
Cash distributions paid to limited partners	(788.3)	(703.8)
Cash payments made in connection with distribution equivalent rights	(2)	(1.2)
Cash distributions paid to noncontrolling interests	(8.7)	(16.5)
Cash contributions from noncontrolling interests	11.1	4
Net cash proceeds from the issuance of common units	1,011.5	468.4
Other financing activities	(21)	(38.3)
Cash provided by (used in) financing activities	405.8	(58.2)
Net change in cash and cash equivalents	141.6	6.7
Cash and cash equivalents, beginning balance	19	74.4
Cash and cash equivalents, ending balance	$ 160.6	$ 81.1

UNAUDITED CONDENSED STATEMENTS7

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, 2014	$ 19,692.2	$ (241.6)	$ 1,629	$ 18,304.8
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	650.6	0	14.5	636.1
Cash distributions paid to limited partners	(703.8)	0	0	(703.8)
Cash payments made in connection with distribution equivalent rights	(1.2)	0	0	(1.2)
Cash distributions paid to noncontrolling interests	(16.5)	0	(16.5)	0
Cash contributions from noncontrolling interests	4	0	4	0
Common units issued in connection with Step 2 of Oiltanking acquisition	0	0	(1,408.7)	1,408.7
Net cash proceeds from the issuance of common units	468.4	0	0	468.4
Amortization of fair value of equity-based awards	23.3	0	0	23.3
Cash flow hedges	(21.6)	(21.6)	0	0
Other	(37.3)	0	0.1	(37.4)
Balance at Mar. 31, 2015	20,058.1	(263.2)	222.4	20,098.9
Balance at Dec. 31, 2015	20,501.1	(219.2)	206	20,514.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	670.2	0	9	661.2
Cash distributions paid to limited partners	(788.3)	0	0	(788.3)
Cash payments made in connection with distribution equivalent rights	(2)	0	0	(2)
Cash distributions paid to noncontrolling interests	(8.7)	0	(8.7)	0
Cash contributions from noncontrolling interests	11.1	0	11.1	0
Net cash proceeds from the issuance of common units	1,011.5	0	0	1,011.5
Amortization of fair value of equity-based awards	22.3	0	0	22.3
Cash flow hedges	(49.2)	(49.2)	0	0
Other	(21.7)	(0.1)	0	(21.6)
Balance at Mar. 31, 2016	$ 21,346.3	$ (268.5)	$ 217.4	$ 21,397.4

Partnership Operations, Organiz

Partnership Operations, Organization and Basis for Presentation	3 Months Ended
	Mar. 31, 2016
Partnership Operations and Organization [Abstract]
Partnership Operations and Organization	With the exception of per unit amounts, or as noted within the context of each disclosure, the dollar amounts presented in the tabular data within these disclosures are stated in millions of dollars. NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS Unless the context requires otherwise, references to "we," "us," "our," "Enterprise" or "Enterprise Products Partners" are intended to mean the business and operations of Enterprise Products Partners L.P. and its consolidated subsidiaries. References to "EPO" mean Enterprise Products Operating LLC, which is a wholly owned subsidiary of Enterprise, and its consolidated subsidiaries, through which Enterprise Products Partners L.P. conducts its business. Enterprise is managed by its general partner, Enterprise Products Holdings LLC ("Enterprise GP"), which is a wholly owned subsidiary of Dan Duncan LLC, a privately held Texas limited liability company. The membership interests of Dan Duncan LLC are owned by a voting trust, the current trustees ("DD LLC Trustees") of which are: (i) Randa Duncan Williams, who is also a director and Chairman of the Board of Directors (the "Board") of Enterprise GP; (ii) Richard H. Bachmann, who is also a director and Vice Chairman of the Board of Enterprise GP; and (iii) Dr. Ralph S. Cunningham. Ms. Duncan Williams and Mr. Bachmann also currently serve as managers of Dan Duncan LLC along with W. Randall Fowler, who is also a director and President of Enterprise GP. References to "EPCO" mean Enterprise Products Company, a privately held Texas corporation, and its privately held affiliates. A majority of the outstanding voting capital stock of EPCO is owned by a voting trust, the current trustees ("EPCO Trustees") of which are: (i) Ms. Duncan Williams, who serves as Chairman of EPCO; (ii) Dr. Cunningham, who serves as Vice Chairman of EPCO; and (iii) Mr. Bachmann, who serves as the President and Chief Executive Officer of EPCO. Ms. Duncan Williams and Mr. Bachmann also currently serve as directors of EPCO along with Mr. Fowler, who is also the Executive Vice President and Chief Administrative Officer of EPCO. EPCO, together with its privately held affiliates, owned approximately 33.3% of our limited partner interests at March 31, 2016. References to "Oiltanking" and "Oiltanking GP" mean Oiltanking Partners, L.P. and OTLP GP, LLC, the general partner of Oiltanking, respectively. In October 2014, we acquired approximately 65.9% of the limited partner interests of Oiltanking, all of the member interests of Oiltanking GP and the incentive distribution rights ("IDRs") held by Oiltanking GP from Oiltanking Holding Americas, Inc. ("OTA"), a U.S. corporation, as the first step of a two-step acquisition of Oiltanking. In February 2015, we completed the second step of this transaction consisting of the acquisition of the noncontrolling interests in Oiltanking. References to "TEPPCO" mean TEPPCO Partners, L.P. prior to its merger with one of our wholly owned subsidiaries in October 2009. References to "Offshore Business" refer to the Gulf of Mexico operations we sold to Genesis Energy, L.P. ("Genesis") in July 2015. References to "EFS Midstream" mean EFS Midstream LLC, which we acquired in July 2015 from affiliates of Pioneer Natural Resources Company and Reliance Industries Limited. 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 liquid ("NGL") 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 the 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; 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. Our assets currently include approximately 49,000 miles of pipelines; 250 million barrels ("MMBbls") of storage capacity for NGLs, crude oil, petrochemicals and refined products; and 14 billion cubic feet ("Bcf") of natural gas storage capacity. We conduct substantially all of our business through EPO and are owned 100% by our limited partners from an economic perspective. Enterprise GP manages our partnership and owns 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. Like many publicly traded partnerships, we have no employees. All of our management, administrative and operating functions are performed by employees of EPCO pursuant to an administrative services agreement (the "ASA") or by other service providers. See Note 13 for information regarding the ASA and other related party matters. Our historical operations are reported under five business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services, (iv) Petrochemical & Refined Products Services and (v) Offshore Pipelines & Services. On July 24, 2015, we completed the sale of our Offshore Business, which primarily consisted of our Offshore Pipelines & Services segment. Our consolidated financial statements reflect ownership of the Offshore Business through July 24, 2015. See Note 9 for additional information regarding our business segments. As a result of our acquisition of the member interests of EFS Midstream effective July 1, 2015, we began consolidating the financial statements of EFS Midstream as of that date. Effective January 1, 2016, we applied the provisions of Accounting Standard Update ("ASU") 2015-03, Simplifying the Presentation of Debt Issuance Costs

General Accounting and Disclosu

General Accounting and Disclosure Matters	3 Months Ended
	Mar. 31, 2016
General Accounting Matters [Abstract]
General Accounting Matters	Our results of operations for the three months ended March 31, 2016 are not necessarily indicative of results expected for the full year of 2016. 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, 2015 (the "2015 Form 10-K") filed with the SEC on February 26, 2016. 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 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. 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 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 12 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. 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. 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, NGLs, crude oil and refined products. Additional cash may be restricted to maintain our commodity derivative instruments portfolio as prices fluctuate or deposit requirements change. At March 31, 2016 and December 31, 2015, our restricted cash amounts were $136.9 million and $15.9 million, respectively. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories

Inventories	3 Months Ended
	Mar. 31, 2016
Inventories [Abstract]
Inventories	Our inventory amounts by product type were as follows at the dates indicated: March 31, 2016 December 31, 2015 NGLs $ 625.8 $ 639.9 Petrochemicals and refined products 335.7 148.0 Crude oil 248.7 222.1 Natural gas 21.9 28.1 Total $ 1,232.1 $ 1,038.1 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 March 31, 2016 2015 Cost of sales (1) $ 3,208.3 $ 5,678.1 Lower of cost or market adjustments 5.3 3.5 (1) Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. 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

Property, Plant and Equipment	3 Months Ended
	Mar. 31, 2016
Property, Plant and Equipment [Abstract]
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 March 31, 2016 December 31, 2015 Plants, pipelines and facilities (1) 3-45 (5) $ 33,096.3 $ 32,525.0 Underground and other storage facilities (2) 5-40 (6) 3,147.1 3,000.5 Transportation equipment (3) 3-10 161.6 159.9 Marine vessels (4) 15-30 774.0 769.8 Land 262.7 262.7 Construction in progress 4,087.4 3,894.0 Total 41,529.1 40,611.9 Less accumulated depreciation 8,855.8 8,577.2 Property, plant and equipment, net $ 32,673.3 $ 32,034.7 (1) Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; buildings; office furniture and equipment; 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) Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations. (4) Marine vessels include tow boats, barges and related equipment used in our marine transportation business. (5) 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; buildings, 20-40 years; office furniture and equipment, 3-20 years; and laboratory and shop equipment, 5-35 years. (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. The following table summarizes our depreciation expense and capitalized interest amounts for the periods indicated: For the Three Months Ended March 31, 2016 2015 Depreciation expense (1) $ 295.9 $ 291.3 Capitalized interest (2) 42.5 29.6 (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. Asset Retirement Obligations We record asset retirement obligations ("AROs") in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations. Our contractual AROs primarily result from right-of-way agreements associated with our pipeline operations and real estate leases associated with our plant sites. In addition, we record AROs in connection with governmental regulations associated with the abandonment or retirement of above-ground brine storage pits and certain marine vessels. We also record AROs in connection with regulatory requirements associated with the renovation or demolition of certain assets containing hazardous substances such as asbestos. We typically fund our AROs using cash flow from operations. Property, plant and equipment at March 31, 2016 and December 31, 2015 includes $17.5 million and $17.6 million, respectively, of asset retirement costs capitalized as an increase in the associated long-lived asset. The following table presents information regarding our AROs since December 31, 2015: ARO liability balance, December 31, 2015 $ 58.5 Liabilities settled (1.5 ) Revisions in estimated cash flows 1.7 Accretion expense 0.9 ARO liability balance, March 31, 2016 $ 59.6

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	3 Months Ended
	Mar. 31, 2016
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 March 31, 2016 March 31, 2016 December 31, 2015 NGL Pipelines & Services: Venice Energy Service Company, L.L.C. 13.1% $ 25.7 $ 25.9 K/D/S Promix, L.L.C. 50% 38.3 38.3 Baton Rouge Fractionators LLC 32.2% 17.9 18.5 Skelly-Belvieu Pipeline Company, L.L.C. 50% 39.1 39.8 Texas Express Pipeline LLC 35% 338.1 342.0 Texas Express Gathering LLC 45% 36.6 36.8 Front Range Pipeline LLC 33.3% 171.1 171.2 Delaware Basin Gas Processing LLC 50% 73.3 46.2 Crude Oil Pipelines & Services: Seaway Crude Pipeline Company LLC 50% 1,420.0 1,396.0 Eagle Ford Pipeline LLC 50% 389.5 388.8 Eagle Ford Terminals Corpus Christi LLC 50% 39.1 28.6 Natural Gas Pipelines & Services: White River Hub, LLC 50% 22.3 22.5 Petrochemical & Refined Products Services: Baton Rouge Propylene Concentrator, LLC 30% 5.3 5.4 Centennial Pipeline LLC 50% 64.6 65.6 Other Various 3.2 2.9 Total $ 2,684.1 $ 2,628.5 The following table presents our equity in inc ome (loss) of u For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services $ 15.1 $ 11.6 Crude Oil Pipelines & Services 90.1 59.9 Natural Gas Pipelines & Services 1.0 0.9 Petrochemical & Refined Products Services (5.1 ) (3.4 ) Offshore Pipelines & Services -- 20.2 Total $ 101.1 $ 89.2 The following table presents our unamortized excess cost amounts by business segment at the dates indicated: March 31, 2016 December 31, 2015 NGL Pipelines & Services $ 25.0 $ 25.3 Crude Oil Pipelines & Services 19.1 19.3 Petrochemical & Refined Products Services 2.3 2.3 Total $ 46.4 $ 46.9 In total, amortization of excess cost amounts were $0.5 million and $2.6 million for the three months ended March 31, 2016 and 2015, respectively. Summarized Combined Financial Information of Unconsolidated Affiliates Combined results of operations data for the periods indicated for our unconsolidated affiliates are summarized in the following table (all data presented on a 100% basis): For the Three Months Ended March 31, 2016 2015 Income Statement Data: Revenues $ 345.5 $ 349.5 Operating income 213.7 196.6 Net income 215.2 193.4

Intangible Assets and Goodwill

Intangible Assets and Goodwill	3 Months Ended
	Mar. 31, 2016
Intangible Assets and Goodwill [Abstract]
Intangible Assets and Goodwill	Identifiable Intangible Assets The following table summarizes our intangible assets by business segment at the dates indicated: March 31, 2016 December 31, 2015 Gross Value Accumulated Amortization Carrying Value Gross Value Accumulated Amortization Carrying Value NGL Pipelines & Services: Customer relationship intangibles $ 447.4 $ (160.9 ) $ 286.5 $ 447.4 $ (156.9 ) $ 290.5 Contract-based intangibles 283.0 (197.0 ) 86.0 283.0 (193.2 ) 89.8 Segment total 730.4 (357.9 ) 372.5 730.4 (350.1 ) 380.3 Crude Oil Pipelines & Services: Customer relationship intangibles 2,204.4 (52.1 ) 2,152.3 2,204.4 (39.1 ) 2,165.3 Contract-based intangibles 281.4 (83.9 ) 197.5 281.4 (69.2 ) 212.2 Segment total 2,485.8 (136.0 ) 2,349.8 2,485.8 (108.3 ) 2,377.5 Natural Gas Pipelines & Services: Customer relationship intangibles 1,350.3 (372.4 ) 977.9 1,350.3 (366.3 ) 984.0 Contract-based intangibles 464.7 (363.5 ) 101.2 464.7 (361.0 ) 103.7 Segment total 1,815.0 (735.9 ) 1,079.1 1,815.0 (727.3 ) 1,087.7 Petrochemical & Refined Products Services: Customer relationship intangibles 185.5 (39.7 ) 145.8 185.5 (38.3 ) 147.2 Contract-based intangibles 56.3 (12.6 ) 43.7 56.3 (11.8 ) 44.5 Segment total 241.8 (52.3 ) 189.5 241.8 (50.1 ) 191.7 Total intangible assets $ 5,273.0 $ (1,282.1 ) $ 3,990.9 $ 5,273.0 $ (1,235.8 ) $ 4,037.2 The following table presents the amortization expense of our intangible assets by business segment for the periods indicated: For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services $ 7.8 $ 7.5 Crude Oil Pipelines & Services 27.7 16.7 Natural Gas Pipelines & Services 8.6 9.9 Petrochemical & Refined Products Services 2.2 2.4 Offshore Pipelines & Services -- 2.3 Total $ 46.3 $ 38.8 The following table presents our forecast of amortization expense associated with existing intangible assets for the periods indicated: Remainder of 2016 2017 2018 2019 2020 $ 133.3 $ 176.3 $ 171.7 $ 167.1 $ 166.4 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 since December 31, 2015: NGL Pipelines & Services Crude Oil Pipelines & Services Natural Gas Pipelines & Services Petrochemical & Refined Products Services Consolidated Total Balance at December 31, 2015 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2 Balance at March 31, 2016 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2

Debt Obligations

Debt Obligations	3 Months Ended
	Mar. 31, 2016
Debt Obligations [Abstract]
Debt Obligations	The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated: March 31, 2016 December 31, 2015 EPO senior debt obligations: Commercial Paper Notes, variable-rates $ 2,072.0 $ 1,114.1 Senior Notes AA, 3.20% fixed-rate, due February 2016 -- 750.0 364-Day Credit Agreement, variable-rate, due September 2016 -- -- 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 Senior Notes OO, 1.65% fixed-rate, due May 2018 750.0 750.0 Senior Notes N, 6.50% fixed-rate, due January 2019 700.0 700.0 Senior Notes LL, 2.55% fixed-rate, due October 2019 800.0 800.0 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 Multi-Year Revolving Credit Facility, variable-rate, due September 2020 -- -- 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 850.0 850.0 Senior Notes MM, 3.75% fixed-rate, due February 2025 1,150.0 1,150.0 Senior Notes PP, 3.70% fixed-rate, due February 2026 875.0 875.0 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 1,400.0 1,400.0 Senior Notes KK, 5.10% fixed-rate, due February 2045 1,150.0 1,150.0 Senior Notes QQ, 4.90% fixed-rate, due May 2046 875.0 875.0 Senior Notes NN, 4.95% fixed-rate, due October 2054 400.0 400.0 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 21,472.0 21,264.1 EPO Junior Subordinated Notes A, fixed/variable-rate, due August 2066 521.1 521.1 EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 256.4 256.4 EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 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 22,946.4 22,738.5 Other, non-principal amounts (190.7 ) (197.7 ) Less current maturities of debt (835.9 ) (1,863.9 ) Total long-term debt $ 21,919.8 $ 20,676.9 (1) Fixed rate of 8.375% through August 1, 2016 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 3.708%. (2) Fixed rate of 7.000% through September 1, 2017 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 2.778%. (3) Fixed rate of 7.034% through January 15, 2018 (i.e., first call date without a make-whole redemption premium); thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.680%. At December 31, 2015, we reclassified $149.8 million of bond issuance costs, which were previously accounted for as assets on our consolidated balance sheet, to long-term debt in connection with the adoption of ASU 2015-03 (see Note 1). These amounts are a component of "Other, non-principal amounts" in the preceding table. The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at March 31, 2016 for the next five years, and in total thereafter: Scheduled Maturities of Debt Total Remainder of 2016 2017 2018 2019 2020 Thereafter Commercial Paper Notes $ 2,072.0 $ 2,072.0 $ -- $ -- $ -- $ -- $ -- Senior Notes 19,400.0 -- 800.0 1,100.0 1,500.0 1,500.0 14,500.0 Junior Subordinated Notes 1,474.4 -- -- -- -- -- 1,474.4 Total $ 22,946.4 $ 2,072.0 $ 800.0 $ 1,100.0 $ 1,500.0 $ 1,500.0 $ 15,974.4 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 $1.25 Billion of Senior Notes in April 2016 In April 2016, EPO issued $575 million in principal amount of 2.85% senior notes due April 2021 ("Senior Notes RR"), $575 million in principal amount of 3.95% senior notes due February 2027 ("Senior Notes SS") and $100 million in principal amount of 4.90% reopened senior notes due May 2046 ("Senior Notes QQ"). Senior Notes RR, SS and QQ were issued at 99.898%, 99.760% and 95.516% of their principal amounts, respectively. We issued these senior notes using our 2013 Shelf (see Note 8). Net proceeds from the issuance of these senior notes were used as follows: (i) the repayment of amounts then outstanding under EPO's commercial paper program, which included amounts we used to repay $750 million in principal amount of Senior Notes AA that matured in February 2016, and (ii) 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 an indenture 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. Letters of Credit At March 31, 2016, 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 March 31, 2016. 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 three months ended March 31, 2016: Range of Interest Rates Paid Weighted-Average Interest Rate Paid Commercial Paper Notes 0.56% to 1.18% 0.89% Multi-Year Revolving Credit Facility 1.43% to 1.43% 1.43%

Equity and Distributions

Equity and Distributions	3 Months Ended
	Mar. 31, 2016
Equity and Distributions [Abstract]
Equity and Distributions	Partners Equity Partners' equity reflects the limited partner interests (i.e., common units, including restricted common units) that we have outstanding. The following table summarizes changes in the number of our outstanding units from December 31, 2015 to March 31, 2016: Common Units (Unrestricted) Restricted Common Units Total Common Units Number of units outstanding at December 31, 2015 2,010,592,504 1,960,520 2,012,553,024 Common units issued in connection with ATM program 35,396,147 -- 35,396,147 Common units issued in connection with DRIP and EUPP 7,282,006 -- 7,282,006 Common units issued in connection with the vesting of phantom unit awards 1,053,117 -- 1,053,117 Common units issued in connection with the vesting of restricted common unit awards 1,167,578 (1,167,578 ) -- Forfeiture of restricted common unit awards -- (9,350 ) (9,350 ) Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (388,396 ) -- (388,396 ) Other 20,630 -- 20,630 Number of units outstanding at March 31, 2016 2,055,123,586 783,592 2,055,907,178 Universal shelf registration statement We expect to issue additional equity and debt securities to assist us in meeting our future liquidity requirements, including those related to capital spending. 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 (each on a standalone basis) to issue an unlimited amount of equity and debt securities, respectively. See Note 7 for information regarding an offering of senior notes we completed in April 2016 using the 2013 Shelf. The 2013 Shelf will expire in June 2016, at which time we expect to file a replacement universal shelf registration statement. ATM program We have a registration statement on file with the SEC in connection with our "at-the-market" program (or "ATM program"). Pursuant to this 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 three months ended March 31, 2016, we sold 35,396,147 common units under the ATM program for aggregate gross proceeds of $856.5 million. This includes 3,830,256 common units sold in January 2016 to privately held affiliates of EPCO, which generated gross proceeds of $100 million. After taking into account applicable costs, our transactions under the ATM program resulted in aggregate net cash proceeds of $849.0 million during the three months ended March 31, 2016. During the three months ended March 31, 2015, we issued 12,350,761 common units under this program for aggregate gross cash proceeds of $407.8 million, resulting in total net cash proceeds of $404.2 million. During the period April 1, 2016 through April 8, 2016, we sold an additional 25,550,931 common units under the ATM program for aggregate gross proceeds of $594.1 million, resulting in net cash proceeds of $592.0 million. After taking into account the aggregate sales price of common units sold under our ATM program through April 8, 2016, our capacity under the applicable registration statement was reduced to $415.7 million. On April 22, 2016, we filed a registration statement with the SEC that (when declared effective) will replace our existing registration statement with respect to the ATM program and increase the available capacity under the ATM program to allow us to issue up to an aggregate $2.17 billion of additional common units, inclusive of the remaining capacity under such existing registration statement. Distribution reinvestment plan 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 ("DRIP"). The DRIP provides unitholders of record and beneficial owners of our common units a voluntary means by which they can increase the number of our common units they own by reinvesting the quarterly cash distributions they receive from us into the purchase of additional new common units. We issued a total of 7,162,744 common units under our DRIP during the three months ended March 31, 2016, which generated net cash proceeds of $159.8 million. During the three months ended March 31, 2015, we issued 1,869,079 common units under our DRIP, which generated net cash proceeds of $61.7 million. Privately held affiliates of EPCO reinvested $100 million through the DRIP during the three months ended March 31, 2016 (this amount being a component of the net cash proceeds presented). After taking into account the number of common units issued under the DRIP through March 31, 2016, we have the capacity to issue an additional 7,905,254 common units under this plan. We expect to file a new registration statement during the second quarter of 2016 to increase the number of common units available for issuance under the DRIP. Employee unit purchase plan 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 our employee unit purchase plan ("EUPP"). We issued 119,262 common units under our EUPP during the three months ended March 31, 2016, which generated net cash proceeds of $2.7 million. During the three months ended March 31, 2015, we issued 71,753 common units under our EUPP, which generated net cash proceeds of $2.5 million. After taking into account the number of common units issued under the EUPP through March 31, 2016, we may issue an additional 6,653,244 common units under this plan. Noncontrolling Interests Noncontrolling interests represent third party equity ownership interests in our consolidated subsidiaries. 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, 2015 $ 56.6 $ (279.5 ) $ 3.7 $ (219.2 ) Other comprehensive loss before reclassifications (1.2 ) -- (0.1 ) (1.3 ) Amounts reclassified from accumulated other comprehensive loss (income) (57.2 ) 9.2 -- (48.0 ) Total other comprehensive income (loss) (58.4 ) 9.2 (0.1 ) (49.3 ) Balance, March 31, 2016 $ (1.8 ) $ (270.3 ) $ 3.6 $ (268.5 ) Gains (Losses) on Cash Flow Hedges Commodity Derivative Instruments Interest Rate Derivative Instruments Other Total Balance, December 31, 2014 $ 69.9 $ (314.8 ) $ 3.3 $ (241.6 ) Other comprehensive income before reclassifications 30.8 -- -- 30.8 Amounts reclassified from accumulated other comprehensive loss (income) (61.1 ) 8.7 -- (52.4 ) Total other comprehensive income (loss) (30.3 ) 8.7 -- (21.6 ) Balance, March 31, 2015 $ 39.6 $ (306.1 ) $ 3.3 $ (263.2 ) The following table presents reclassifications out of accumulated other comprehensive income (loss) into net income during the periods indicated: For the Three Months Ended March 31, Location 2016 2015 Losses (gains) on cash flow hedges: Interest rate derivatives Interest expense $ 9.2 $ 8.7 Commodity derivatives Revenue (58.8 ) (61.1 ) Commodity derivatives Operating costs and expenses 1.6 -- Total $ (48.0 ) $ (52.4 ) 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 2015: 1st Quarter $ 0.3750 4/30/2015 5/7/2015 2016: 1st Quarter $ 0.3950 4/29/2016 5/6/2016 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 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 to partners during 2015 excluded 35,380,000 Designated Units. The temporary distribution waiver expired in November 2015; therefore, distributions to be paid, if any, during calendar year 2016 will include all common units owned by the privately held affiliates of EPCO.

Business Segments

Business Segments	3 Months Ended
	Mar. 31, 2016
Business Segments [Abstract]
Business Segments	Our historical operations are reported under five business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services, (iv) Petrochemical & Refined Products Services and (v) Offshore Pipelines & 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. Our consolidated financial statements reflect ownership of the Offshore Business through July 24, 2015, which was the closing date of the sales transaction. 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. 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 (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 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 remainder of our consolidated total assets, which consist primarily of working capital assets, are excluded from segment assets since these amounts are not attributable to one specific segment (e.g. cash). The following table presents our measurement of non-GAAP total segment gross operating margin for the periods indicated: For the Three Months Ended March 31, 2016 2015 Revenues $ 5,005.3 $ 7,472.5 Subtract operating costs and expenses (4,146.9 ) (6,616.4 ) Add equity in income of unconsolidated affiliates 101.1 89.2 Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin 358.2 345.3 Add impairment charges not reflected in gross operating margin 1.7 33.3 Add net losses or subtract net gains attributable to asset sales not reflected in gross operating margin 4.9 (0.1 ) Add non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin 7.1 30.7 Subtract subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin (12.9 ) (20.1 ) Total segment gross operating margin $ 1,318.5 $ 1,334.4 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 March 31, 2016 2015 Total segment gross operating margin $ 1,318.5 $ 1,334.4 Adjustments to reconcile total segment gross operating margin to operating income: Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin (358.2 ) (345.3 ) Subtract impairment charges not reflected in gross operating margin (1.7 ) (33.3 ) Add net gains or subtract net losses attributable to asset sales not reflected in gross operating margin (4.9 ) 0.1 Subtract non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin (7.1 ) (30.7 ) Add subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin 12.9 20.1 Subtract general and administrative costs not reflected in gross operating margin (43.9 ) (49.3 ) Operating income 915.6 896.0 Other expense, net (237.0 ) (238.6 ) Income before income taxes $ 678.6 $ 657.4 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 Crude Oil Pipelines & Services Natural Gas Pipelines & Services Petrochemical & Refined Products Services Offshore Pipelines & Services Adjustments and Eliminations Consolidated Total Revenues from third parties: Three months ended March 31, 2016 $ 2,402.0 $ 1,277.5 $ 547.3 $ 762.9 $ -- $ -- $ 4,989.7 Three months ended March 31, 2015 2,674.8 2,677.0 730.9 1,349.1 34.6 -- 7,466.4 Revenues from related parties: Three months ended March 31, 2016 1.8 11.1 2.7 -- -- -- 15.6 Three months ended March 31, 2015 1.5 1.0 3.0 -- 0.6 -- 6.1 Intersegment and intrasegment revenues: Three months ended March 31, 2016 3,174.8 1,499.4 124.7 242.7 -- (5,041.6 ) -- Three months ended March 31, 2015 2,443.1 1,277.1 170.0 285.6 0.4 (4,176.2 ) -- Total revenues: Three months ended March 31, 2016 5,578.6 2,788.0 674.7 1,005.6 -- (5,041.6 ) 5,005.3 Three months ended March 31, 2015 5,119.4 3,955.1 903.9 1,634.7 35.6 (4,176.2 ) 7,472.5 Equity in income (loss) of unconsolidated affiliates: Three months ended March 31, 2016 15.1 90.1 1.0 (5.1 ) -- -- 101.1 Three months ended March 31, 2015 11.6 59.9 0.9 (3.4 ) 20.2 -- 89.2 Gross operating margin: Three months ended March 31, 2016 783.7 202.3 177.7 154.8 -- -- 1,318.5 Three months ended March 31, 2015 695.2 214.0 204.5 174.6 46.1 -- 1,334.4 Property, plant and equipment, net: (see Note 4) At March 31, 2016 12,934.9 3,896.6 8,551.1 3,203.3 -- 4,087.4 32,673.3 At December 31, 2015 12,909.7 3,550.3 8,620.0 3,060.7 -- 3,894.0 32,034.7 Investments in unconsolidated affiliates: (see Note 5) At March 31, 2016 740.1 1,848.6 22.3 73.1 -- -- 2,684.1 At December 31, 2015 718.7 1,813.4 22.5 73.9 -- -- 2,628.5 Intangible assets, net: At March 31, 2016 372.5 2,349.8 1,079.1 189.5 -- -- 3,990.9 At December 31, 2015 380.3 2,377.5 1,087.7 191.7 -- -- 4,037.2 Goodwill: At March 31, 2016 2,651.7 1,841.0 296.3 956.2 -- -- 5,745.2 At December 31, 2015 2,651.7 1,841.0 296.3 956.2 -- -- 5,745.2 Segment assets: At March 31, 2016 16,699.2 9,936.0 9,948.8 4,422.1 -- 4,087.4 45,093.5 At December 31, 2015 16,660.4 9,582.2 10,026.5 4,282.5 -- 3,894.0 44,445.6 The following table presents additional information regarding our consolidated revenues and costs and expenses for the periods indicated: For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services: Sales of NGLs and related products $ 1,943.5 $ 2,242.2 Midstream services 460.3 434.1 Total 2,403.8 2,676.3 Crude Oil Pipelines & Services: Sales of crude oil 1,121.1 2,570.7 Midstream services 167.5 107.3 Total 1,288.6 2,678.0 Natural Gas Pipelines & Services: Sales of natural gas 315.0 476.3 Midstream services 235.0 257.6 Total 550.0 733.9 Petrochemical & Refined Products Services: Sales of petrochemicals and refined products 553.2 1,151.0 Midstream services 209.7 198.1 Total 762.9 1,349.1 Offshore Pipelines & Services: Sales of crude oil -- 1.1 Midstream services -- 34.1 Total -- 35.2 Total consolidated revenues $ 5,005.3 $ 7,472.5 Consolidated costs and expenses Operating costs and expenses: Cost of sales $ 3,208.3 $ 5,678.1 Other operating costs and expenses (1) 573.8 559.8 Depreciation, amortization and accretion 358.2 345.3 Net losses (gains) attributable to asset sales 4.9 (0.1 ) Non-cash asset impairment charges 1.7 33.3 General and administrative costs 43.9 49.3 Total consolidated costs and expenses $ 4,190.8 $ 6,665.7 (1) Represents cost of operating our plants, pipelines and other fixed assets, excluding depreciation, amortization and accretion charges. 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.

Earnings Per Unit

Earnings Per Unit	3 Months Ended
	Mar. 31, 2016
Earnings Per Unit [Abstract]
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 March 31, 2016 2015 BASIC EARNINGS PER UNIT Net income attributable to limited partners $ 661.2 $ 636.1 Undistributed earnings allocated and cash payments on phantom unit awards (1) (3.2 ) (2.2 ) Net income available to common unitholders $ 658.0 $ 633.9 Basic weighted-average number of common units outstanding 2,033.6 1,926.4 Basic earnings per unit $ 0.32 $ 0.33 DILUTED EARNINGS PER UNIT Net income attributable to limited partners $ 661.2 $ 636.1 Diluted weighted-average number of units outstanding: Distribution-bearing common units 2,033.6 1,926.4 Designated Units -- 35.4 Phantom units (1) 6.9 4.5 Incremental option units -- 0.4 Total 2,040.5 1,966.7 Diluted earnings per unit $ 0.32 $ 0.32 (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 our 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.

Equity-based Awards

Equity-based Awards	3 Months Ended
	Mar. 31, 2016
Equity-based Awards [Abstract]
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 March 31, 2016 2015 Equity-classified awards: Phantom unit awards $ 19.4 $ 17.2 Restricted common unit awards 2.2 6.1 Profits interests awards 0.7 -- Liability-classified awards 0.1 0.1 Total $ 22.4 $ 23.4 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 March 31, 2016, 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 35,000,000 at March 31, 2016. This amount will automatically increase under the terms of the 2008 Plan by 5,000,000 common units on January 1, 2017 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 March 31, 2016, a total of 3,245,652 and 17,981,493 additional common units were available for issuance under these plans, respectively. In addition, in February 2016, EPCO formed three limited partnerships (generally referred to as "Employee Partnerships") to serve as incentive arrangements for key employees of EPCO by providing them a "profits interest" in an Employee Partnership. The names of the Employee Partnerships are EPD PubCo Unit I L.P. ("EPD PubCo I"), EPD PubCo Unit II L.P. ("EPD PubCo II") and EPD PrivCo Unit I L.P. ("EPD PrivCo I"). The Employee Partnerships are discussed later in this note. 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 March 31, 2016, 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. The grant date fair value of a phantom unit award is based on the market price per unit of our common units on the date of grant. Compensation expense is recognized based on the grant date fair value, net of an allowance for estimated forfeitures, over the requisite service or vesting period. The following table presents phantom unit award activity for the period indicated: Number of Units Weighted- Average Grant Date Fair Value per Unit Phantom unit awards at December 31, 2015 5,426,949 $ 33.63 Granted (2) 4,467,730 $ 21.86 Vested (1,586,493 ) $ 33.56 Forfeited (41,673 ) $ 31.11 Phantom unit awards at March 31, 2016 8,266,513 $ 27.29 (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 2016 was $97.7 million based on a grant date market price of our common units of $21.86 per unit. An estimated annual forfeiture rate of 3.9% 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 to our 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 phantom unit awards for the periods indicated: For the Three Months Ended March 31, 2016 2015 Cash payments made in connection with DERs $ 2.0 $ 1.2 Total intrinsic value of phantom unit awards that vested during period $ 36.3 $ 26.6 For the EPCO group of companies, the unrecognized compensation cost associated with phantom unit awards was $145.2 million at March 31, 2016, of which our share of the cost is currently estimated to be $133.1 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. 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 fair value of a restricted common unit award is based on the market price per unit of our common units on the date of grant. Compensation expense is recognized based on the grant date fair value, net of an allowance for estimated forfeitures, over the requisite service or vesting period. The following table presents restricted common unit award activity for the period indicated: Number of Units Weighted- Average Grant Date Fair Value per Unit Restricted common units at December 31, 2015 1,960,520 $ 27.88 Vested (1,167,578 ) $ 27.39 Forfeited (9,350 ) $ 28.32 Restricted common units at March 31, 2016 783,592 $ 28.60 (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 to our 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 restricted common unit awards for the periods indicated: For the Three Months Ended March 31, 2016 2015 Cash distributions paid to restricted common unitholders $ 0.8 $ 1.5 Total intrinsic value of restricted common unit awards that vested during period $ 26.8 $ 62.4 For the EPCO group of companies, the unrecognized compensation cost associated with restricted common unit awards was an aggregate $4.7 million at March 31, 2016, of which our share of the cost is currently estimated to be $3.5 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 approximately one year. Unit Option Awards EPCO's long-term incentive plans provide for the issuance of non-qualified incentive options denominated in our common units. All of our unit option awards had been exercised as of December 31, 2015 and no new unit option awards were granted during the three months ended March 31, 2016. In order to fund its unit option award-related obligations, EPCO purchased our common units at fair value 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 three months ended March 31, 2015: Total intrinsic value of unit option awards exercised during period $ 17.4 Cash received from EPCO in connection with the exercise of unit option awards 10.1 Unit option award-related cash reimbursements to EPCO 17.4 Profits Interest Awards On February 22, 2016, EPCO Holdings Inc. ("EPCO Holdings"), a privately held affiliate of EPCO, contributed the following Enterprise common units it owned to the Employee Partnerships: (i) 2,723,052 units to EPD PubCo I, (ii) 2,834,198 units to EPD PubCo II and (iii) 1,111,438 units to EPD PrivCo I. In exchange for these contributions, EPCO Holdings was admitted as the Class A limited partner of each Employee Partnership. Also on the contribution date, certain key EPCO employees were issued Class B limited partner interests (i.e., profits interest awards) and admitted as Class B limited partners of each Employee Partnership, all without any capital contribution by such employees. EPCO serves as the general partner of each Employee Partnership. In general, the Class A limited partner earns a preferred return (the "Class A Preference Return," as described below) on its investment (or "Capital Base") in each Employee Partnership, with any residual cash amounts being paid to the Class B limited partners of such Employee Partnership on a quarterly basis. Upon liquidation of an Employee Partnership, assets having a then current fair market value equal to the Class A limited partner's Capital Base in such Employee Partnership, plus any preferred return for the period in which liquidation occurs, will be distributed to the Class A limited partner. Any remaining assets of such Employee Partnership will be distributed to the Class B limited partners of such Employee Partnership as a residual profits interest, which represents the appreciation in value of the Employee Partnership's assets since the date of EPCO Holdings' contribution to it, as described above. Unless otherwise agreed to by EPCO and a majority in interest of the limited partners of each Employee Partnership, such Employee Partnership will terminate at the earliest to occur of (i) 30 days following its vesting date, (ii) a change of control or (iii) a dissolution of the Employee Partnership. Class B limited partner interests in EPD PubCo I vest four years from February 22, 2016, and Class B limited partner interests in EPD PubCo II and EPD PrivCo I vest five years from that date. Individually, each Class B limited partner interest is subject to forfeiture if the participating employee's employment with EPCO is terminated prior to vesting, with customary exceptions for death, disability and certain retirements. The risk of forfeiture will also lapse upon certain change of control events. Forfeited individual Class B limited partner interests are allocated to the remaining Class B limited partners. The following table summarizes key elements of each Employee Partnership: Employee Partnership Enterprise Common Units owned by Employee Partnership Class A Capital Base Class A Partner Preferred Return Rate Expected Liquidation Date Estimated Grant Date Fair Value of Profits Interest Awards Unrecognized Compensation Cost EPD PubCo I 2,723,052 units $63.5 million 6.6638 % Feb. 2020 $13.2 million $12.7 million EPD PubCo II 2,834,198 units $66.1 million 6.6638 % Feb. 2021 $14.8 million $14.3 million EPD PrivCo I 1,111,438 units $25.9 million 6.6638 % Feb. 2021 $5.8 million $1.2 million (1) Represents the fair market value of the Enterprise common units contributed at the contribution date. (2) For each period, the Class A Preference Return equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by 6.6638% divided by 365 or 366 days, as the case may be during such calendar year, multiplied by the number of days in the applicable period. (3) Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates. (4) Represents our expected share of the unrecognized compensation cost at March 31, 2016. We expect to recognize our share of the unrecognized compensation cost for EPD PubCo I, EPD PubCo II and EPD PrivCo I over a weighted-average period of 3.9 years, 4.9 years and 4.9 years, respectively. The grant date fair value of each Employee Partnership is based on (i) the estimated value (as determined using a Black-Scholes option pricing model) of such Employee Partnership's assets that would be distributed to the Class B limited partners thereof upon liquidation and (ii) the value, based on a discounted cash flow analysis, of the residual quarterly cash amounts that such Class B limited partners are expected to receive over the life of the Employee Partnership. The following table summarizes the assumptions we used in applying a Black-Scholes option pricing model to derive that portion of the estimated grant date fair value of the profits interest awards for each Employee Partnership: Expected Risk-Free Expected Expected Unit Employee Life Interest Distribution Price Partnership of Award Rate Yield Volatility EPD PubCo I 4.0 years 1.09% 6.68% 40% EPD PubCo II 5.0 years 1.25% 6.68% 40% EPD PrivCo I 5.0 years 1.25% 6.68% 40% Compensation expense attributable to the profits interest awards is based on the estimated grant date fair value of each award. A portion of the fair value of these equity-based awards is allocated to us under the ASA as a non-cash expense. We are not responsible for reimbursing EPCO for any expenses of the Employee Partnerships, including the value of any contributions of units made by EPCO Holdings.

Derivative Instruments, Hedging

Derivative Instruments, Hedging Activities and Fair Value Measurements	3 Months Ended
	Mar. 31, 2016
Derivative Instruments, Hedging Activities and Fair Value Measurements [Abstract]
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. This strategy may be used in controlling our overall cost of capital associated with such borrowings. The following table summarizes our portfolio of interest rate swaps at March 31, 2016: Hedged Transaction Number and Type of Derivatives Outstanding Notional Amount Period of Hedge Rate Swap Accounting Treatment Senior Notes OO 10 fixed-to-floating swaps $ 750.0 5/2015 to 5/2018 1.65% to 1.10% Fair value hedge Commodity Hedging Activities The prices of natural gas, NGLs, crude oil, petrochemicals and refined 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 March 31, 2016 (volume measures as noted): Volume (1) Accounting Derivative Purpose Current Long-Term Treatment Derivatives designated as hedging instruments: Natural gas processing: Forecasted natural gas purchases for plant thermal reduction (Bcf) 32.7 n/a Cash flow hedge Forecasted sales of NGLs (MMBbls) (3) 6.5 n/a Cash flow hedge Octane enhancement: Forecasted sales of octane enhancement products (MMBbls) 1.0 n/a Cash flow hedge Natural gas marketing: Forecasted purchases of natural gas for fuel (Bcf) 7.2 n/a Cash flow hedge Natural gas storage inventory management activities (Bcf) 8.9 n/a Fair value hedge NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products (MMBbls) 58.3 0.5 Cash flow hedge Forecasted sales of NGLs and related hydrocarbon products (MMBbls) 66.3 n/a Cash flow hedge Refined products marketing: Forecasted purchases of refined products (MMBbls) 1.8 n/a Cash flow hedge Forecasted sales of refined products (MMBbls) 1.5 n/a Cash flow hedge Refined products inventory management activities (MMBbls) 5.1 n/a Fair value hedge Crude oil marketing: Forecasted purchases of crude oil (MMBbls) 13.1 n/a Cash flow hedge Forecasted sales of crude oil (MMBbls) 20.3 n/a Cash flow hedge Crude oil inventory management activities (MMBbls) 0.2 n/a Fair value hedge Derivatives not designated as hedging instruments: Natural gas risk management activities (Bcf) (4,5) 80.9 7.4 Mark-to-market NGL risk management activities (MMBbls) (5) 4.0 n/a Mark-to-market Crude oil risk management activities (MMBbls) (5) 28.5 2.3 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 2017, December 2016 and March 2019, 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 51.0 Bcf and 2.1 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 March 31, 2016, 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 natural gas processing margins and (iii) hedging the fair value of commodity products held in inventory. § The objective of our anticipated future commodity purchases and sales hedging program is to hedge the margins of certain transportation, storage, blending and operational activities by locking in purchase and sale prices through the use of forward contracts and derivative instruments. § The objective of our natural gas processing hedging program is to hedge an amount of gross margin associated with these activities. We achieve this objective by executing forward fixed-price sales of a portion of our expected equity NGL production using forward contracts and commodity derivative instruments. For certain natural gas processing contracts, the hedging of expected equity NGL production also involves the purchase of natural gas for plant thermal reduction, which is hedged by executing forward fixed-price purchases using forward contracts and derivative instruments. § The objective of our inventory hedging program is to hedge the fair value of commodity products currently held in inventory by locking in the sales price of the inventory through the use of forward contracts and derivative instruments. 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 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 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 Current assets $ 5.2 Current assets $ 3.2 Other current liabilities $ -- Other current liabilities $ -- Interest rate derivatives Other assets 1.6 Other assets -- Other liabilities -- Other liabilities 3.7 Total interest rate derivatives 6.8 3.2 -- 3.7 Commodity derivatives Current assets 153.1 Current assets 253.8 Other current liabilities 220.8 Other current liabilities 137.5 Commodity derivatives Other assets 0.6 Other assets 0.2 Other liabilities 0.3 Other liabilities 1.4 Total commodity derivatives 153.7 254.0 221.1 138.9 Total derivatives designated as hedging instruments $ 160.5 $ 257.2 $ 221.1 $ 142.6 Derivatives not designated as hedging instruments Commodity derivatives Current assets $ 76.6 Current assets $ 1.6 Other current liabilities $ 66.3 Other current liabilities $ 3.1 Commodity derivatives Other assets 0.7 Other assets -- Other liabilities 1.8 Other liabilities 1.0 Total commodity derivatives $ 77.3 $ 1.6 $ 68.1 $ 4.1 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 Financial Instruments Cash Collateral Received Cash Collateral Paid (i) (ii) (iii) = (i) – (ii) (iv) (v) = (iii) + (iv) As of March 31, 2016: Interest rate derivatives $ 6.8 $ -- $ 6.8 $ -- $ -- $ -- $ 6.8 Commodity derivatives 231.0 -- 231.0 (228.9 ) -- -- 2.1 As of December 31, 2015: Interest rate derivatives $ 3.2 $ -- $ 3.2 $ (3.2 ) $ -- $ -- $ -- Commodity derivatives 255.6 -- 255.6 (143.0 ) (40.1 ) (72.2 ) 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 Financial Instruments Cash Collateral Paid (i) (ii) (iii) = (i) – (ii) (iv) (v) = (iii) + (iv) As of March 31, 2016: Commodity derivatives $ 289.2 $ -- $ 289.2 $ (228.9 ) $ (59.0 ) $ 1.3 As of December 31, 2015: Interest rate derivatives $ 3.7 $ -- $ 3.7 $ (3.2 ) $ -- $ 0.5 Commodity derivatives 143.0 -- 143.0 (143.0 ) -- -- 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 these tables, 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 these tables. 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 March 31, 2016 2015 Interest rate derivatives Interest expense $ 6.1 $ -- Commodity derivatives Revenue (19.0 ) 0.7 Total $ (12.9 ) $ 0.7 Derivatives in Fair Value Hedging Relationships Location Gain (Loss) Recognized in Income on Hedged Item For the Three Months Ended March 31, 2016 2015 Interest rate derivatives Interest expense $ (6.2 ) $ -- Commodity derivatives Revenue 28.0 8.6 Total $ 21.8 $ 8.6 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 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 March 31, 2016 2015 Commodity derivatives – Revenue (1) $ 3.3 $ 32.6 Commodity derivatives – Operating costs and expenses (1) (4.5 ) (1.8 ) Total $ (1.2 ) $ 30.8 (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 March 31, 2016 2015 Interest rate derivatives Interest expense $ (9.2 ) $ (8.7 ) Commodity derivatives Revenue 58.8 61.1 Commodity derivatives Operating costs and expenses (1.6 ) -- Total $ 48.0 $ 52.4 Derivatives in Cash Flow Hedging Relationships Location Gain (Loss) Recognized in Income on Derivative (Ineffective Portion) For the Three Months Ended March 31, 2016 2015 Commodity derivatives Revenue $ -- $ 0.3 Over the next twelve months, we expect to reclassify $37.9 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 $1.9 million of net losses attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, $0.6 million as an increase in revenue and $2.5 million as an increase 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 March 31, 2016 2015 Commodity derivatives Revenue $ (1.3 ) $ (0.4 ) Commodity derivatives Operating costs and expenses 0.1 -- Total $ (1.2 ) $ (0.4 ) Fair Value Measurements The following tables set forth, by level within the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated. 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. March 31, 2016 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 $ -- $ 6.8 $ -- $ 6.8 Commodity derivatives 114.8 113.9 2.3 231.0 Total $ 114.8 $ 120.7 $ 2.3 $ 237.8 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 242.9 $ 242.9 Commodity derivatives 126.6 160.9 1.7 289.2 Total $ 126.6 $ 160.9 $ 244.6 $ 532.1 December 31, 2015 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 $ -- $ 3.2 $ -- $ 3.2 Commodity derivatives 109.5 145.2 0.9 255.6 Total $ 109.5 $ 148.4 $ 0.9 $ 258.8 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 245.1 $ 245.1 Interest rate derivatives -- 3.7 -- 3.7 Commodity derivatives 31.3 109.2 2.5 143.0 Total $ 31.3 $ 112.9 $ 247.6 $ 391.8 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 Three Months Ended March 31, Location 2016 2015 Financial liability balance, net, January 1 $ (246.7 ) $ (219.3 ) Total gains (losses) included in: Net income (1) Revenue 0.7 (0.4 ) Net income Other expense, net 2.2 -- Other comprehensive income (loss) Commodity derivative instruments – changes in fair value of cash flow hedges 1.5 (1.5 ) Settlements (0.1 ) (0.5 ) Transfers out of Level 3 0.1 0.1 Financial liability balance, net, March 31 $ (242.3 ) $ (221.6 ) (1) There were $0.6 million of unrealized gains and $1.0 million of unrealized losses included in these amounts for the three months ended March 31, 2016 and 2015, respectively. The following Fair Value Financial Assets Financial Liabilities Valuation Techniques Unobservable Input Range Commodity derivatives – Crude oil $ 1.6 $ 1.4 Discounted cash flow Forward commodity prices $36.30-$43.03/barrel Commodity derivatives – Propane -- 0.3 Discounted cash flow Forward commodity prices $0.91-$0.93/gallon Commodity derivatives – Natural gasoline 0.7 -- Discounted cash flow Forward commodity prices $0.48/gallon Total $ 2.3 $ 1.7 With respect to commodity derivatives, we believe forward commodity prices are the most significant unobservable inputs in determining our Level 3 recurring fair value measurements at March 31, 2016. 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 the periods indicated: For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services $ 0.4 $ 0.8 Crude Oil Pipelines & Services 0.2 7.8 Natural Gas Pipelines & Services -- 20.7 Petrochemical & Refined Products Services 1.1 0.4 Offshore Pipelines & Services -- 3.6 Total $ 1.7 $ 33.3 Impairment charges are a component of "Operating costs and expenses" on our Unaudited Condensed Statements of Consolidated Operations. Our non-cash impairment charges for the three months ended March 31, 2016 include $1.1 million related to other current assets, primarily spare parts and materials. The following table presents categories of long-lived assets, primarily property, plant and equipment, that were subject to non-recurring fair value measurements during the three months ended March 31, 2016: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at March 31, 2016 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 Long-lived assets disposed of other than by sale $ -- $ -- $ -- $ -- $ 0.6 The following table presents categories of long-lived assets, primarily property, plant and equipment, that were subject to non-recurring fair value measurements during the three months ended March 31, 2015: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at March 31, 2015 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 Long-lived assets disposed of other than by sale $ -- $ -- $ -- $ -- $ 33.1 Long-lived assets held for sale 0.6 -- -- 0.6 0.2 Total $ 33.3 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 $20.27 billion and $19.51 billion at March 31, 2016 and December 31, 2015, respectively. The aggregate carrying value of these debt obligations was $20.12 billion and $20.87 billion at March 31, 2016 and December 31, 2015, 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 amounts reported for fixed-rate debt obligations exclude those amounts hedged using fixed-to-floating interest rate swaps. See " Interest Rate Hedging Activities

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	The following table summarizes our related party transactions for the periods indicated: For the Three Months Ended March 31, 2016 2015 Revenues – related parties: Unconsolidated affiliates $ 15.6 $ 6.1 Costs and expenses – related parties: EPCO and its privately held affiliates $ 237.3 $ 221.9 Unconsolidated affiliates 72.9 39.2 Total $ 310.2 $ 261.1 The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated: March 31, 2016 December 31, 2015 Accounts receivable - related parties: Unconsolidated affiliates $ 1.1 $ 1.2 Accounts payable - related parties: EPCO and its privately held affiliates $ 24.3 $ 75.6 Unconsolidated affiliates 13.1 8.5 Total $ 37.4 $ 84.1 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 March 31, 2016, EPCO and its privately held affiliates (including Dan Duncan LLC and certain Duncan family trusts) beneficially owned the following limited partner interests in us: Total Number of Units Percentage of Total Units Outstanding 685,481,428 33.3% Of the total number of units held by EPCO and its privately held affiliates, 118,000,000 have been pledged as security under the credit facilities of certain of the privately held affiliates at March 31, 2016. These credit facilities contain customary and other events of default, including defaults by us and other affiliates of EPCO. An event of default, followed by a foreclosure on the pledged collateral, could ultimately result in a change in ownership of these units and affect the market price of our common units. 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 three months ended March 31, 2016 and 2015, we paid EPCO and its privately held affiliates cash distributions totaling $260.1 million and $231.2 million, respectively. Distributions paid during 2015 excluded 35,380,000 Designated Units (see Note 8). In January 2016, privately held affiliates of EPCO purchased 3,830,256 common units from us under our ATM program, generating gross proceeds of $100 million. In February 2016, privately held affiliates of EPCO reinvested $100 million through our DRIP, resulting in the issuance of an additional 4,481,504 of our common units. See Note 8 for additional information regarding our ATM program and DRIP. 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 related party costs and expenses attributable to the ASA with EPCO for the periods indicated: For the Three Months Ended March 31, 2016 2015 Operating costs and expenses $ 205.4 $ 191.0 General and administrative expenses 27.3 26.6 Total costs and expenses $ 232.7 $ 217.6

Commitments and Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2016
Commitments and Contingencies [Abstract]
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 March 31, 2016 and December 31, 2015, our accruals for litigation contingencies were $2.6 million and $4.6 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%, compounded annually. We do not believe that the verdict or the judgment entered against us is supported by the evidence or the law. We filed our Brief of the Appellant in the Court of Appeals for the Fifth District of Dallas, Texas on March 30, 2015 and ETP filed its Brief of Appellees on June 29, 2015. We filed our Reply Brief of Appellant on September 18, 2015. Oral argument was conducted on April 20, 2016, and the case has now been submitted to the Court of Appeals for its consideration. We intend to vigorously oppose the judgment through the appeals process. As of March 31, 2016, we have not recorded a provision for this matter as management believes payment of damages in this case is not probable. FTC Inquiry regarding Oiltanking Acquisition On February 23, 2015, we received a Civil Investigative Demand and a related Subpoena Duces Tecum Contractual Obligations Scheduled Maturities of Debt We have long-term and short-term payment obligations under debt agreements. See Note 7 for additional information regarding our scheduled future maturities of debt principal. Operating Lease Obligations Consolidated lease and rental expense was $28.5 million and $22.4 million during the three months ended March 31, 2016 and 2015, respectively. Our operating lease commitments at March 31, 2016 did not differ materially from those reported in our 2015 Form 10-K. Purchase Obligations Our consolidated purchase obligations at March 31, 2016 did not differ materially from those reported in our 2015 Form 10-K. Liquidity Option Agreement We entered into a put option agreement (the "Liquidity Option Agreement") with OTA and Marquard & Bahls ("M&B") in connection with the Oiltanking acquisition. Under the Liquidity Option Agreement, we granted M&B the option to sell to us 100% of the issued and outstanding capital stock of OTA at any time within a 90-day period commencing on February 1, 2020. At that time, OTA's only significant asset is expected to be the Enterprise common units it received in Step 1 of the Oiltanking acquisition, to the extent that such common units are not sold by M&B prior to the option exercise date pursuant to a related registration rights agreement. If the Liquidity Option is exercised, we would indirectly acquire any Enterprise common units owned by OTA and assume all future income tax obligations of OTA associated with (i) owning common units encumbered by the entity-level taxes of a U.S. corporation and (ii) OTA's tax liabilities resulting from differences in the book and tax basis of such common units at the time of exercise. The carrying value of the Liquidity Option Agreement, which is a component of "Other long-term liabilities" on our Unaudited Condensed Consolidated Balance Sheet, was $242.9 million and $245.1 million at March 31, 2016 and December 31, 2015, respectively. Results for the three months ended March 31, 2016 reflect a $2.2 million benefit, which is a component of "Other, net" on our Unaudited Condensed Consolidated Statements of Operations, attributable to the Liquidity Option Agreement.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	3 Months Ended
	Mar. 31, 2016
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	The following table presents the net effect of changes in our operating accounts for the periods indicated: For the Three Months Ended March 31, 2016 2015 Decrease (increase) in: Accounts receivable – trade $ 124.6 $ 837.5 Accounts receivable – related parties 0.4 (0.6 ) Inventories (194.3 ) 161.0 Prepaid and other current assets 5.3 (3.2 ) Other assets 1.3 0.5 Increase (decrease) in: Accounts payable – trade (64.8 ) (61.6 ) Accounts payable – related parties (46.7 ) (69.6 ) Accrued product payables 228.7 (768.7 ) Accrued interest (158.2 ) (155.6 ) Other current liabilities (84.4 ) (71.9 ) Other liabilities 1.7 (6.8 ) Net effect of changes in operating accounts $ (186.4 ) $ (139.0 ) We incurred liabilities for construction in progress that had not been paid at March 31, 2016 and December 31, 2015 of $422.8 million and $472.8 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 for the periods indicated: For the Three Months Ended March 31, 2016 2015 Other cash proceeds $ 13.4 $ 0.5 Total $ 13.4 $ 0.5 The following table presents net gains (losses) attributable to asset sales for the periods indicated: For the Three Months Ended March 31, 2016 2015 Ne $ (4.9 ) $ 0.1 Total $ (4.9 ) $ 0.1

Condensed Consolidating Financi

Condensed Consolidating Financial Information	3 Months Ended
	Mar. 31, 2016
Condensed Consolidating Financial Information [Abstract]
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. As the parent company of EPO, Enterprise Products Partners L.P. guarantees substantially all of the debt obligations of EPO. 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. See Note 7 for additional information regarding our consolidated debt obligations. EPO's consolidated subsidiaries have no significant restrictions on their ability to pay distributions or make loans to Enterprise Products Partners L.P. Enterprise Products Partners L.P. Unaudited Condensed Consolidating Balance Sheet March 31, 2016 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 $ 215.6 $ 90.1 $ (8.2 ) $ 297.5 $ -- $ -- $ 297.5 Accounts receivable – trade, net 750.1 1,700.2 (0.9 ) 2,449.4 -- -- 2,449.4 Accounts receivable – related parties 92.1 680.4 (749.0 ) 23.5 -- (22.4 ) 1.1 Inventories 954.3 278.1 (0.3 ) 1,232.1 -- -- 1,232.1 Derivative assets 147.8 87.1 -- 234.9 -- -- 234.9 Prepaid and other current assets 157.1 227.7 (7.9 ) 376.9 0.7 -- 377.6 Total current assets 2,317.0 3,063.6 (766.3 ) 4,614.3 0.7 (22.4 ) 4,592.6 Property, plant and equipment, net 4,141.2 28,530.7 1.4 32,673.3 -- -- 32,673.3 Investments in unconsolidated affiliates 39,020.7 4,146.0 (40,482.6 ) 2,684.1 21,393.6 (21,393.6 ) 2,684.1 Intangible assets, net 715.8 3,289.7 (14.6 ) 3,990.9 -- -- 3,990.9 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 149.2 38.7 (136.9 ) 51.0 0.3 -- 51.3 Total assets $ 46,803.4 $ 44,354.4 $ (41,399.0 ) $ 49,758.8 $ 21,394.6 $ (21,416.0 ) $ 49,737.4 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 835.8 $ 0.1 $ -- $ 835.9 $ -- $ -- $ 835.9 Accounts payable – trade 324.3 427.0 (8.2 ) 743.1 0.4 -- 743.5 Accounts payable – related parties 713.8 87.7 (764.1 ) 37.4 22.4 (22.4 ) 37.4 Accrued product payables 1,257.4 1,434.5 (1.8 ) 2,690.1 -- -- 2,690.1 Accrued liability related to EFS Midstream acquisition -- 996.5 -- 996.5 -- -- 996.5 Accrued interest 193.5 0.4 -- 193.9 -- -- 193.9 Other current liabilities 179.5 344.5 (7.9 ) 516.1 -- -- 516.1 Total current liabilities 3,504.3 3,290.7 (782.0 ) 6,013.0 22.8 (22.4 ) 6,013.4 Long-term debt 21,904.6 15.2 -- 21,919.8 -- -- 21,919.8 Deferred tax liabilities 3.4 44.8 (0.8 ) 47.4 -- 2.8 50.2 Other long-term liabilities 9.5 291.9 (136.6 ) 164.8 242.9 -- 407.7 Commitments and contingencies Equity: Partners' and other owners' equity 21,381.6 40,641.1 (40,655.9 ) 21,366.8 21,128.9 (21,366.8 ) 21,128.9 Noncontrolling interests -- 70.7 176.3 247.0 -- (29.6 ) 217.4 Total equity 21,381.6 40,711.8 (40,479.6 ) 21,613.8 21,128.9 (21,396.4 ) 21,346.3 Total liabilities and equity $ 46,803.4 $ 44,354.4 $ (41,399.0 ) $ 49,758.8 $ 21,394.6 $ (21,416.0 ) $ 49,737.4 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Balance Sheet December 31, 2015 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 $ 14.4 $ 71.1 $ (50.6 ) $ 34.9 $ -- $ -- $ 34.9 Accounts receivable – trade, net 811.3 1,755.8 2.8 2,569.9 -- -- 2,569.9 Accounts receivable – related parties 59.0 795.4 (853.0 ) 1.4 -- (0.2 ) 1.2 Inventories 786.9 251.4 (0.2 ) 1,038.1 -- -- 1,038.1 Derivative assets 150.4 108.2 -- 258.6 -- -- 258.6 Prepaid and other current assets 153.6 249.1 (7.1 ) 395.6 -- -- 395.6 Total current assets 1,975.6 3,231.0 (908.1 ) 4,298.5 -- (0.2 ) 4,298.3 Property, plant and equipment, net 3,859.8 28,173.5 1.4 32,034.7 -- -- 32,034.7 Investments in unconsolidated affiliates 38,655.0 4,067.3 (40,093.8 ) 2,628.5 20,540.2 (20,540.2 ) 2,628.5 Intangible assets, net 721.2 3,330.7 (14.7 ) 4,037.2 -- -- 4,037.2 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 145.1 47.9 (135.2 ) 57.8 0.5 -- 58.3 Total assets $ 45,816.2 $ 44,136.1 $ (41,150.4 ) $ 48,801.9 $ 20,540.7 $ (20,540.4 ) $ 48,802.2 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 1,863.8 $ 0.1 $ -- $ 1,863.9 $ -- $ -- $ 1,863.9 Accounts payable – trade 375.3 535.1 (50.6 ) 859.8 0.3 -- 860.1 Accounts payable – related parties 885.3 62.3 (863.5 ) 84.1 0.2 (0.2 ) 84.1 Accrued product payables 997.7 1,489.3 (2.6 ) 2,484.4 -- -- 2,484.4 Accrued liability related to EFS Midstream acquisition -- 993.2 -- 993.2 -- -- 993.2 Accrued interest 352.0 0.1 -- 352.1 -- -- 352.1 Other current liabilities 178.7 357.1 (7.0 ) 528.8 -- -- 528.8 Total current liabilities 4,652.8 3,437.2 (923.7 ) 7,166.3 0.5 (0.2 ) 7,166.6 Long-term debt 20,661.6 15.3 -- 20,676.9 -- -- 20,676.9 Deferred tax liabilities 3.4 40.8 (0.8 ) 43.4 -- 2.7 46.1 Other long-term liabilities 14.5 286.9 (135.0 ) 166.4 245.1 -- 411.5 Commitments and contingencies Equity: Partners' and other owners' equity 20,483.9 40,297.2 (40,266.8 ) 20,514.3 20,295.1 (20,514.3 ) 20,295.1 Noncontrolling interests -- 58.7 175.9 234.6 -- (28.6 ) 206.0 Total equity 20,483.9 40,355.9 (40,090.9 ) 20,748.9 20,295.1 (20,542.9 ) 20,501.1 Total liabilities and equity $ 45,816.2 $ 44,136.1 $ (41,150.4 ) $ 48,801.9 $ 20,540.7 $ (20,540.4 ) $ 48,802.2 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended March 31, 2016 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 $ 5,361.9 $ 3,282.7 $ (3,639.3 ) $ 5,005.3 $ -- $ -- $ 5,005.3 Costs and expenses: Operating costs and expenses 5,091.2 2,695.1 (3,639.4 ) 4,146.9 -- -- 4,146.9 General and administrative costs 6.0 36.8 -- 42.8 1.1 -- 43.9 Total costs and expenses 5,097.2 2,731.9 (3,639.4 ) 4,189.7 1.1 -- 4,190.8 Equity in income of unconsolidated affiliates 632.7 133.6 (665.2 ) 101.1 660.1 (660.1 ) 101.1 Operating income 897.4 684.4 (665.1 ) 916.7 659.0 (660.1 ) 915.6 Other income (expense): Interest expense (237.1 ) (5.2 ) 1.7 (240.6 ) -- -- (240.6 ) Other, net 1.8 1.3 (1.7 ) 1.4 2.2 -- 3.6 Total other income (expense), net (235.3 ) (3.9 ) -- (239.2 ) 2.2 -- (237.0 ) Income before income taxes 662.1 680.5 (665.1 ) 677.5 661.2 (660.1 ) 678.6 Provision for income taxes (2.9 ) (5.1 ) -- (8.0 ) -- (0.4 ) (8.4 ) Net income 659.2 675.4 (665.1 ) 669.5 661.2 (660.5 ) 670.2 Ne t income at -- (1.3 ) (8.9 ) (10.2 ) -- 1.2 (9.0 ) Net income attributable to entity $ 659.2 $ 674.1 $ (674.0 ) $ 659.3 $ 661.2 $ (659.3 ) $ 661.2 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended March 31, 2015 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 $ 5,579.8 $ 4,825.2 $ (2,932.5 ) $ 7,472.5 $ -- $ -- $ 7,472.5 Costs and expenses: Operating costs and expenses 5,324.1 4,224.9 (2,932.6 ) 6,616.4 -- -- 6,616.4 General and administrative costs 8.4 40.7 -- 49.1 0.2 -- 49.3 Total costs and expenses 5,332.5 4,265.6 (2,932.6 ) 6,665.5 0.2 -- 6,665.7 Equity in income of unconsolidated affiliates 627.7 91.6 (630.1 ) 89.2 636.3 (636.3 ) 89.2 Operating income 875.0 651.2 (630.0 ) 896.2 636.1 (636.3 ) 896.0 Other income (expense): Interest expense (238.3 ) (2.8 ) 2.0 (239.1 ) -- -- (239.1 ) Other, net 2.0 0.5 (2.0 ) 0.5 -- -- 0.5 Total other expense, net (236.3 ) (2.3 ) -- (238.6 ) -- -- (238.6 ) Income before income taxes 638.7 648.9 (630.0 ) 657.6 636.1 (636.3 ) 657.4 Provision for income taxes (3.2 ) (3.1 ) -- (6.3 ) -- (0.5 ) (6.8 ) Net income 635.5 645.8 (630.0 ) 651.3 636.1 (636.8 ) 650.6 Net loss (income) attributable to noncontrolling interests -- 0.3 (16.0 ) (15.7 ) -- 1.2 (14.5 ) Net income attributable to entity $ 635.5 $ 646.1 $ (646.0 ) $ 635.6 $ 636.1 $ (635.6 ) $ 636.1 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended March 31, 2016 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 $ 655.2 $ 630.1 $ (665.0 ) $ 620.3 $ 611.9 $ (611.3 ) $ 620.9 Comprehensive income attrib -- (1.3 ) (8.9 ) (10.2 ) -- 1.2 (9.0 ) Comprehensive income attributable to entity $ 655.2 $ 628.8 $ (673.9 ) $ 610.1 $ 611.9 $ (610.1 ) $ 611.9 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended March 31, 2015 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 $ 621.9 $ 637.8 $ (630.0 ) $ 629.7 $ 614.5 $ (615.2 ) $ 629.0 Comprehensive income attrib -- 0.3 (16.0 ) (15.7 ) -- 1.2 (14.5 ) Comprehensive income attributable to entity $ 621.9 $ 638.1 $ (646.0 ) $ 614.0 $ 614.5 $ (614.0 ) $ 614.5 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Three Months Ended March 31, 2016 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 $ 659.2 $ 675.4 $ (665.1 ) $ 669.5 $ 661.2 $ (660.5 ) $ 670.2 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 42.5 339.7 (0.1 ) 382.1 -- -- 382.1 Equity in income of unconsolidated affiliates (632.7 ) (133.6 ) 665.2 (101.1 ) (660.1 ) 660.1 (101.1 ) Distributions received on earnings from unconsolidated affiliates 247.2 74.2 (214.7 ) 106.7 788.5 (788.5 ) 106.7 Net effect of changes in operating accounts and other operating activities 35.5 (255.3 ) 42.4 (177.4 ) 18.8 0.4 (158.2 ) Net cash flows provided by operating activities 351.7 700.4 (172.3 ) 879.8 808.4 (788.5 ) 899.7 Investing activities: Capital expenditures, net of contributions in aid of construction costs (307.6 ) (687.4 ) -- (995.0 ) -- -- (995.0 ) Proceeds from asset sales 0.1 13.3 -- 13.4 -- -- 13.4 Other investing activities (387.5 ) (55.7 ) 260.9 (182.3 ) (1,008.6 ) 1,008.6 (182.3 ) Cash used in investing activities (695.0 ) (729.8 ) 260.9 (1,163.9 ) (1,008.6 ) 1,008.6 (1,163.9 ) Financing activities: Borrowings under debt agreements 20,000.6 -- -- 20,000.6 -- -- 20,000.6 Repayments of debt (19,797.3 ) (0.1 ) -- (19,797.4 ) -- -- (19,797.4 ) Cash distributions paid to partners (788.5 ) (222.9 ) 222.9 (788.5 ) (788.3 ) 788.5 (788.3 ) Cash payments made in connection with DERs -- -- -- -- (2.0 ) -- (2.0 ) Cash distributions paid to noncontrolling interests -- (0.5 ) (8.2 ) (8.7 ) -- -- (8.7 ) Cash contributions from noncontrolling interests -- 11.1 -- 11.1 -- -- 11.1 Net cash proceeds from issuance of common units -- -- -- -- 1,011.5 -- 1,011.5 Cash contributions from owners 1,008.6 260.9 (260.9 ) 1,008.6 -- (1,008.6 ) -- Other financing activities -- -- -- -- (21.0 ) -- (21.0 ) Cash provided by financing activities 423.4 48.5 (46.2 ) 425.7 200.2 (220.1 ) 405.8 Net change in cash and cash equivalents 80.1 19.1 42.4 141.6 -- -- 141.6 Cash and cash equivalents, January 1 -- 69.6 (50.6 ) 19.0 -- -- 19.0 Cash and cash equivalents, March 31 $ 80.1 $ 88.7 $ (8.2 ) $ 160.6 $ -- $ -- $ 160.6 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Three Months Ended March 31, 2015 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 $ 635.5 $ 645.8 $ (630.0 ) $ 651.3 $ 636.1 $ (636.8 ) $ 650.6 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 32.9 334.6 (0.1 ) 367.4 -- -- 367.4 Equity in income of unconsolidated affiliates (627.7 ) (91.6 ) 630.1 (89.2 ) (636.3 ) 636.3 (89.2 ) Distributions received on earnings from unconsolidated affiliates 633.9 97.5 (597.0 ) 134.4 726.7 (726.7 ) 134.4 Net effect of changes in operating accounts and other operating activities (146.6 ) 13.0 6.9 (126.7 ) 17.0 0.5 (109.2 ) Net cash flows provided by operating activities 528.0 999.3 (590.1 ) 937.2 743.5 (726.7 ) 954.0 Investing activities: Capital expenditures, net of contributions in aid of construction costs (234.2 ) (559.0 ) -- (793.2 ) -- -- (793.2 ) Proceeds from asset sales -- 0.5 -- 0.5 -- -- 0.5 Other investing activities (252.0 ) (24.0 ) 179.6 (96.4 ) (468.4 ) 468.4 (96.4 ) Cash used in investing activities (486.2 ) (582.5 ) 179.6 (889.1 ) (468.4 ) 468.4 (889.1 ) Financing activities: Borrowings under debt agreements 9,182.5 -- -- 9,182.5 -- -- 9,182.5 Repayments of debt (8,953.2 ) -- -- (8,953.2 ) -- -- (8,953.2 ) Cash distributions paid to partners (726.7 ) (613.1 ) 613.1 (726.7 ) (703.8 ) 726.7 (703.8 ) Cash payments made in connection with DERs -- -- -- -- (1.2 ) -- (1.2 ) Cash distributions paid to noncontrolling interests -- (0.4 ) (16.1 ) (16.5 ) -- -- (16.5 ) Cash contributions from noncontrolling interests -- 4.4 (0.4 ) 4.0 -- -- 4.0 Net cash proceeds from issuance of common units -- -- -- -- 468.4 -- 468.4 Cash contributions from owners 468.4 179.2 (179.2 ) 468.4 -- (468.4 ) -- Other financing activities 0.1 -- -- 0.1 (38.5 ) -- (38.4 ) Cash used in financing activities (28.9 ) (429.9 ) 417.4 (41.4 ) (275.1 ) 258.3 (58.2 ) Net change in cash and cash equivalents 12.9 (13.1 ) 6.9 6.7 -- -- 6.7 Cash and cash equivalents, January 1 18.7 70.4 (14.7 ) 74.4 -- -- 74.4 Cash and cash equivalents, March 31 $ 31.6 $ 57.3 $ (7.8 ) $ 81.1 $ -- $ -- $ 81.1

General Accounting and Disclo24

General Accounting and Disclosure Matters (Policies)	3 Months Ended
	Mar. 31, 2016
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 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. 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 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 12 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. 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.
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, NGLs, crude oil and refined products. Additional cash may be restricted to maintain our commodity derivative instruments portfolio as prices fluctuate or deposit requirements change. At March 31, 2016 and December 31, 2015, our restricted cash amounts were $136.9 million and $15.9 million, respectively. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories (Tables)

Inventories (Tables)	3 Months Ended
	Mar. 31, 2016
Inventories [Abstract]
Inventory Amounts by Product Type	Our inventory amounts by product type were as follows at the dates indicated: March 31, 2016 December 31, 2015 NGLs $ 625.8 $ 639.9 Petrochemicals and refined products 335.7 148.0 Crude oil 248.7 222.1 Natural gas 21.9 28.1 Total $ 1,232.1 $ 1,038.1
Cost of Sales and Lower of Cost or Market Adjustments	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 March 31, 2016 2015 Cost of sales (1) $ 3,208.3 $ 5,678.1 Lower of cost or market adjustments 5.3 3.5 (1) Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. 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 (

Property, Plant and Equipment (Tables)	3 Months Ended
	Mar. 31, 2016
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 March 31, 2016 December 31, 2015 Plants, pipelines and facilities (1) 3-45 (5) $ 33,096.3 $ 32,525.0 Underground and other storage facilities (2) 5-40 (6) 3,147.1 3,000.5 Transportation equipment (3) 3-10 161.6 159.9 Marine vessels (4) 15-30 774.0 769.8 Land 262.7 262.7 Construction in progress 4,087.4 3,894.0 Total 41,529.1 40,611.9 Less accumulated depreciation 8,855.8 8,577.2 Property, plant and equipment, net $ 32,673.3 $ 32,034.7 (1) Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; buildings; office furniture and equipment; 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) Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations. (4) Marine vessels include tow boats, barges and related equipment used in our marine transportation business. (5) 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; buildings, 20-40 years; office furniture and equipment, 3-20 years; and laboratory and shop equipment, 5-35 years. (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.
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 March 31, 2016 2015 Depreciation expense (1) $ 295.9 $ 291.3 Capitalized interest (2) 42.5 29.6 (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 AROs since December 31, 2015: ARO liability balance, December 31, 2015 $ 58.5 Liabilities settled (1.5 ) Revisions in estimated cash flows 1.7 Accretion expense 0.9 ARO liability balance, March 31, 2016 $ 59.6

Investments in Unconsolidated27

Investments in Unconsolidated Affiliates (Tables)	3 Months Ended
	Mar. 31, 2016
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 March 31, 2016 March 31, 2016 December 31, 2015 NGL Pipelines & Services: Venice Energy Service Company, L.L.C. 13.1% $ 25.7 $ 25.9 K/D/S Promix, L.L.C. 50% 38.3 38.3 Baton Rouge Fractionators LLC 32.2% 17.9 18.5 Skelly-Belvieu Pipeline Company, L.L.C. 50% 39.1 39.8 Texas Express Pipeline LLC 35% 338.1 342.0 Texas Express Gathering LLC 45% 36.6 36.8 Front Range Pipeline LLC 33.3% 171.1 171.2 Delaware Basin Gas Processing LLC 50% 73.3 46.2 Crude Oil Pipelines & Services: Seaway Crude Pipeline Company LLC 50% 1,420.0 1,396.0 Eagle Ford Pipeline LLC 50% 389.5 388.8 Eagle Ford Terminals Corpus Christi LLC 50% 39.1 28.6 Natural Gas Pipelines & Services: White River Hub, LLC 50% 22.3 22.5 Petrochemical & Refined Products Services: Baton Rouge Propylene Concentrator, LLC 30% 5.3 5.4 Centennial Pipeline LLC 50% 64.6 65.6 Other Various 3.2 2.9 Total $ 2,684.1 $ 2,628.5 The following table presents our equity in inc ome (loss) of u For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services $ 15.1 $ 11.6 Crude Oil Pipelines & Services 90.1 59.9 Natural Gas Pipelines & Services 1.0 0.9 Petrochemical & Refined Products Services (5.1 ) (3.4 ) Offshore Pipelines & Services -- 20.2 Total $ 101.1 $ 89.2 The following table presents our unamortized excess cost amounts by business segment at the dates indicated: March 31, 2016 December 31, 2015 NGL Pipelines & Services $ 25.0 $ 25.3 Crude Oil Pipelines & Services 19.1 19.3 Petrochemical & Refined Products Services 2.3 2.3 Total $ 46.4 $ 46.9 Combined results of operations data for the periods indicated for our unconsolidated affiliates are summarized in the following table (all data presented on a 100% basis): For the Three Months Ended March 31, 2016 2015 Income Statement Data: Revenues $ 345.5 $ 349.5 Operating income 213.7 196.6 Net income 215.2 193.4

Intangible Assets and Goodwill

Intangible Assets and Goodwill (Tables)	3 Months Ended
	Mar. 31, 2016
Intangible Assets and Goodwill [Abstract]
Intangible Assets by Segment	The following table summarizes our intangible assets by business segment at the dates indicated: March 31, 2016 December 31, 2015 Gross Value Accumulated Amortization Carrying Value Gross Value Accumulated Amortization Carrying Value NGL Pipelines & Services: Customer relationship intangibles $ 447.4 $ (160.9 ) $ 286.5 $ 447.4 $ (156.9 ) $ 290.5 Contract-based intangibles 283.0 (197.0 ) 86.0 283.0 (193.2 ) 89.8 Segment total 730.4 (357.9 ) 372.5 730.4 (350.1 ) 380.3 Crude Oil Pipelines & Services: Customer relationship intangibles 2,204.4 (52.1 ) 2,152.3 2,204.4 (39.1 ) 2,165.3 Contract-based intangibles 281.4 (83.9 ) 197.5 281.4 (69.2 ) 212.2 Segment total 2,485.8 (136.0 ) 2,349.8 2,485.8 (108.3 ) 2,377.5 Natural Gas Pipelines & Services: Customer relationship intangibles 1,350.3 (372.4 ) 977.9 1,350.3 (366.3 ) 984.0 Contract-based intangibles 464.7 (363.5 ) 101.2 464.7 (361.0 ) 103.7 Segment total 1,815.0 (735.9 ) 1,079.1 1,815.0 (727.3 ) 1,087.7 Petrochemical & Refined Products Services: Customer relationship intangibles 185.5 (39.7 ) 145.8 185.5 (38.3 ) 147.2 Contract-based intangibles 56.3 (12.6 ) 43.7 56.3 (11.8 ) 44.5 Segment total 241.8 (52.3 ) 189.5 241.8 (50.1 ) 191.7 Total intangible assets $ 5,273.0 $ (1,282.1 ) $ 3,990.9 $ 5,273.0 $ (1,235.8 ) $ 4,037.2
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 March 31, 2016 2015 NGL Pipelines & Services $ 7.8 $ 7.5 Crude Oil Pipelines & Services 27.7 16.7 Natural Gas Pipelines & Services 8.6 9.9 Petrochemical & Refined Products Services 2.2 2.4 Offshore Pipelines & Services -- 2.3 Total $ 46.3 $ 38.8
Forecasted Amortization Expense	The following table presents our forecast of amortization expense associated with existing intangible assets for the periods indicated: Remainder of 2016 2017 2018 2019 2020 $ 133.3 $ 176.3 $ 171.7 $ 167.1 $ 166.4
Changes in Carrying Amount of 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 since December 31, 2015: NGL Pipelines & Services Crude Oil Pipelines & Services Natural Gas Pipelines & Services Petrochemical & Refined Products Services Consolidated Total Balance at December 31, 2015 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2 Balance at March 31, 2016 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2

Debt Obligations (Tables)

Debt Obligations (Tables)	3 Months Ended
	Mar. 31, 2016
Debt Obligations [Abstract]
Consolidated Debt Obligations	The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated: March 31, 2016 December 31, 2015 EPO senior debt obligations: Commercial Paper Notes, variable-rates $ 2,072.0 $ 1,114.1 Senior Notes AA, 3.20% fixed-rate, due February 2016 -- 750.0 364-Day Credit Agreement, variable-rate, due September 2016 -- -- 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 Senior Notes OO, 1.65% fixed-rate, due May 2018 750.0 750.0 Senior Notes N, 6.50% fixed-rate, due January 2019 700.0 700.0 Senior Notes LL, 2.55% fixed-rate, due October 2019 800.0 800.0 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 Multi-Year Revolving Credit Facility, variable-rate, due September 2020 -- -- 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 850.0 850.0 Senior Notes MM, 3.75% fixed-rate, due February 2025 1,150.0 1,150.0 Senior Notes PP, 3.70% fixed-rate, due February 2026 875.0 875.0 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 1,400.0 1,400.0 Senior Notes KK, 5.10% fixed-rate, due February 2045 1,150.0 1,150.0 Senior Notes QQ, 4.90% fixed-rate, due May 2046 875.0 875.0 Senior Notes NN, 4.95% fixed-rate, due October 2054 400.0 400.0 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 21,472.0 21,264.1 EPO Junior Subordinated Notes A, fixed/variable-rate, due August 2066 521.1 521.1 EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 256.4 256.4 EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 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 22,946.4 22,738.5 Other, non-principal amounts (190.7 ) (197.7 ) Less current maturities of debt (835.9 ) (1,863.9 ) Total long-term debt $ 21,919.8 $ 20,676.9 (1) Fixed rate of 8.375% through August 1, 2016 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 3.708%. (2) Fixed rate of 7.000% through September 1, 2017 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 2.778%. (3) Fixed rate of 7.034% through January 15, 2018 (i.e., first call date without a make-whole redemption premium); thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.680%.
Consolidated Debt Maturities	The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at March 31, 2016 for the next five years, and in total thereafter: Scheduled Maturities of Debt Total Remainder of 2016 2017 2018 2019 2020 Thereafter Commercial Paper Notes $ 2,072.0 $ 2,072.0 $ -- $ -- $ -- $ -- $ -- Senior Notes 19,400.0 -- 800.0 1,100.0 1,500.0 1,500.0 14,500.0 Junior Subordinated Notes 1,474.4 -- -- -- -- -- 1,474.4 Total $ 22,946.4 $ 2,072.0 $ 800.0 $ 1,100.0 $ 1,500.0 $ 1,500.0 $ 15,974.4
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 three months ended March 31, 2016: Range of Interest Rates Paid Weighted-Average Interest Rate Paid Commercial Paper Notes 0.56% to 1.18% 0.89% Multi-Year Revolving Credit Facility 1.43% to 1.43% 1.43%

Equity and Distributions (Table

Equity and Distributions (Tables)	3 Months Ended
	Mar. 31, 2016
Equity and Distributions [Abstract]
Summary of Changes in Outstanding Units	Partners Equity Partners' equity reflects the limited partner interests (i.e., common units, including restricted common units) that we have outstanding. The following table summarizes changes in the number of our outstanding units from December 31, 2015 to March 31, 2016: Common Units (Unrestricted) Restricted Common Units Total Common Units Number of units outstanding at December 31, 2015 2,010,592,504 1,960,520 2,012,553,024 Common units issued in connection with ATM program 35,396,147 -- 35,396,147 Common units issued in connection with DRIP and EUPP 7,282,006 -- 7,282,006 Common units issued in connection with the vesting of phantom unit awards 1,053,117 -- 1,053,117 Common units issued in connection with the vesting of restricted common unit awards 1,167,578 (1,167,578 ) -- Forfeiture of restricted common unit awards -- (9,350 ) (9,350 ) Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (388,396 ) -- (388,396 ) Other 20,630 -- 20,630 Number of units outstanding at March 31, 2016 2,055,123,586 783,592 2,055,907,178
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, 2015 $ 56.6 $ (279.5 ) $ 3.7 $ (219.2 ) Other comprehensive loss before reclassifications (1.2 ) -- (0.1 ) (1.3 ) Amounts reclassified from accumulated other comprehensive loss (income) (57.2 ) 9.2 -- (48.0 ) Total other comprehensive income (loss) (58.4 ) 9.2 (0.1 ) (49.3 ) Balance, March 31, 2016 $ (1.8 ) $ (270.3 ) $ 3.6 $ (268.5 ) Gains (Losses) on Cash Flow Hedges Commodity Derivative Instruments Interest Rate Derivative Instruments Other Total Balance, December 31, 2014 $ 69.9 $ (314.8 ) $ 3.3 $ (241.6 ) Other comprehensive income before reclassifications 30.8 -- -- 30.8 Amounts reclassified from accumulated other comprehensive loss (income) (61.1 ) 8.7 -- (52.4 ) Total other comprehensive income (loss) (30.3 ) 8.7 -- (21.6 ) Balance, March 31, 2015 $ 39.6 $ (306.1 ) $ 3.3 $ (263.2 )
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 March 31, Location 2016 2015 Losses (gains) on cash flow hedges: Interest rate derivatives Interest expense $ 9.2 $ 8.7 Commodity derivatives Revenue (58.8 ) (61.1 ) Commodity derivatives Operating costs and expenses 1.6 -- Total $ (48.0 ) $ (52.4 )
Declared Quarterly Cash Distribution Rates	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 2015: 1st Quarter $ 0.3750 4/30/2015 5/7/2015 2016: 1st Quarter $ 0.3950 4/29/2016 5/6/2016

Business Segments (Tables)

Business Segments (Tables)	3 Months Ended
	Mar. 31, 2016
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 March 31, 2016 2015 Revenues $ 5,005.3 $ 7,472.5 Subtract operating costs and expenses (4,146.9 ) (6,616.4 ) Add equity in income of unconsolidated affiliates 101.1 89.2 Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin 358.2 345.3 Add impairment charges not reflected in gross operating margin 1.7 33.3 Add net losses or subtract net gains attributable to asset sales not reflected in gross operating margin 4.9 (0.1 ) Add non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin 7.1 30.7 Subtract subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin (12.9 ) (20.1 ) Total segment gross operating margin $ 1,318.5 $ 1,334.4
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 March 31, 2016 2015 Total segment gross operating margin $ 1,318.5 $ 1,334.4 Adjustments to reconcile total segment gross operating margin to operating income: Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin (358.2 ) (345.3 ) Subtract impairment charges not reflected in gross operating margin (1.7 ) (33.3 ) Add net gains or subtract net losses attributable to asset sales not reflected in gross operating margin (4.9 ) 0.1 Subtract non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin (7.1 ) (30.7 ) Add subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin 12.9 20.1 Subtract general and administrative costs not reflected in gross operating margin (43.9 ) (49.3 ) Operating income 915.6 896.0 Other expense, net (237.0 ) (238.6 ) Income before income taxes $ 678.6 $ 657.4
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 Crude Oil Pipelines & Services Natural Gas Pipelines & Services Petrochemical & Refined Products Services Offshore Pipelines & Services Adjustments and Eliminations Consolidated Total Revenues from third parties: Three months ended March 31, 2016 $ 2,402.0 $ 1,277.5 $ 547.3 $ 762.9 $ -- $ -- $ 4,989.7 Three months ended March 31, 2015 2,674.8 2,677.0 730.9 1,349.1 34.6 -- 7,466.4 Revenues from related parties: Three months ended March 31, 2016 1.8 11.1 2.7 -- -- -- 15.6 Three months ended March 31, 2015 1.5 1.0 3.0 -- 0.6 -- 6.1 Intersegment and intrasegment revenues: Three months ended March 31, 2016 3,174.8 1,499.4 124.7 242.7 -- (5,041.6 ) -- Three months ended March 31, 2015 2,443.1 1,277.1 170.0 285.6 0.4 (4,176.2 ) -- Total revenues: Three months ended March 31, 2016 5,578.6 2,788.0 674.7 1,005.6 -- (5,041.6 ) 5,005.3 Three months ended March 31, 2015 5,119.4 3,955.1 903.9 1,634.7 35.6 (4,176.2 ) 7,472.5 Equity in income (loss) of unconsolidated affiliates: Three months ended March 31, 2016 15.1 90.1 1.0 (5.1 ) -- -- 101.1 Three months ended March 31, 2015 11.6 59.9 0.9 (3.4 ) 20.2 -- 89.2 Gross operating margin: Three months ended March 31, 2016 783.7 202.3 177.7 154.8 -- -- 1,318.5 Three months ended March 31, 2015 695.2 214.0 204.5 174.6 46.1 -- 1,334.4 Property, plant and equipment, net: (see Note 4) At March 31, 2016 12,934.9 3,896.6 8,551.1 3,203.3 -- 4,087.4 32,673.3 At December 31, 2015 12,909.7 3,550.3 8,620.0 3,060.7 -- 3,894.0 32,034.7 Investments in unconsolidated affiliates: (see Note 5) At March 31, 2016 740.1 1,848.6 22.3 73.1 -- -- 2,684.1 At December 31, 2015 718.7 1,813.4 22.5 73.9 -- -- 2,628.5 Intangible assets, net: At March 31, 2016 372.5 2,349.8 1,079.1 189.5 -- -- 3,990.9 At December 31, 2015 380.3 2,377.5 1,087.7 191.7 -- -- 4,037.2 Goodwill: At March 31, 2016 2,651.7 1,841.0 296.3 956.2 -- -- 5,745.2 At December 31, 2015 2,651.7 1,841.0 296.3 956.2 -- -- 5,745.2 Segment assets: At March 31, 2016 16,699.2 9,936.0 9,948.8 4,422.1 -- 4,087.4 45,093.5 At December 31, 2015 16,660.4 9,582.2 10,026.5 4,282.5 -- 3,894.0 44,445.6
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 March 31, 2016 2015 NGL Pipelines & Services: Sales of NGLs and related products $ 1,943.5 $ 2,242.2 Midstream services 460.3 434.1 Total 2,403.8 2,676.3 Crude Oil Pipelines & Services: Sales of crude oil 1,121.1 2,570.7 Midstream services 167.5 107.3 Total 1,288.6 2,678.0 Natural Gas Pipelines & Services: Sales of natural gas 315.0 476.3 Midstream services 235.0 257.6 Total 550.0 733.9 Petrochemical & Refined Products Services: Sales of petrochemicals and refined products 553.2 1,151.0 Midstream services 209.7 198.1 Total 762.9 1,349.1 Offshore Pipelines & Services: Sales of crude oil -- 1.1 Midstream services -- 34.1 Total -- 35.2 Total consolidated revenues $ 5,005.3 $ 7,472.5 Consolidated costs and expenses Operating costs and expenses: Cost of sales $ 3,208.3 $ 5,678.1 Other operating costs and expenses (1) 573.8 559.8 Depreciation, amortization and accretion 358.2 345.3 Net losses (gains) attributable to asset sales 4.9 (0.1 ) Non-cash asset impairment charges 1.7 33.3 General and administrative costs 43.9 49.3 Total consolidated costs and expenses $ 4,190.8 $ 6,665.7 (1) Represents cost of operating our plants, pipelines and other fixed assets, excluding depreciation, amortization and accretion charges.

Earnings Per Unit (Tables)

Earnings Per Unit (Tables)	3 Months Ended
	Mar. 31, 2016
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 March 31, 2016 2015 BASIC EARNINGS PER UNIT Net income attributable to limited partners $ 661.2 $ 636.1 Undistributed earnings allocated and cash payments on phantom unit awards (1) (3.2 ) (2.2 ) Net income available to common unitholders $ 658.0 $ 633.9 Basic weighted-average number of common units outstanding 2,033.6 1,926.4 Basic earnings per unit $ 0.32 $ 0.33 DILUTED EARNINGS PER UNIT Net income attributable to limited partners $ 661.2 $ 636.1 Diluted weighted-average number of units outstanding: Distribution-bearing common units 2,033.6 1,926.4 Designated Units -- 35.4 Phantom units (1) 6.9 4.5 Incremental option units -- 0.4 Total 2,040.5 1,966.7 Diluted earnings per unit $ 0.32 $ 0.32 (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 our 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.

Equity-based Awards (Tables)

Equity-based Awards (Tables)	3 Months Ended
	Mar. 31, 2016
Equity-based Awards [Abstract]
Equity-based Award Expense	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 March 31, 2016 2015 Equity-classified awards: Phantom unit awards $ 19.4 $ 17.2 Restricted common unit awards 2.2 6.1 Profits interests awards 0.7 -- Liability-classified awards 0.1 0.1 Total $ 22.4 $ 23.4
Other Share-based Compensation Plans	The following table presents phantom unit award activity for the period indicated: Number of Units Weighted- Average Grant Date Fair Value per Unit Phantom unit awards at December 31, 2015 5,426,949 $ 33.63 Granted (2) 4,467,730 $ 21.86 Vested (1,586,493 ) $ 33.56 Forfeited (41,673 ) $ 31.11 Phantom unit awards at March 31, 2016 8,266,513 $ 27.29 (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 2016 was $97.7 million based on a grant date market price of our common units of $21.86 per unit. An estimated annual forfeiture rate of 3.9% was applied to these awards. The following table summarizes key elements of each Employee Partnership: Employee Partnership Enterprise Common Units owned by Employee Partnership Class A Capital Base Class A Partner Preferred Return Rate Expected Liquidation Date Estimated Grant Date Fair Value of Profits Interest Awards Unrecognized Compensation Cost EPD PubCo I 2,723,052 units $63.5 million 6.6638 % Feb. 2020 $13.2 million $12.7 million EPD PubCo II 2,834,198 units $66.1 million 6.6638 % Feb. 2021 $14.8 million $14.3 million EPD PrivCo I 1,111,438 units $25.9 million 6.6638 % Feb. 2021 $5.8 million $1.2 million (1) Represents the fair market value of the Enterprise common units contributed at the contribution date. (2) For each period, the Class A Preference Return equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by 6.6638% divided by 365 or 366 days, as the case may be during such calendar year, multiplied by the number of days in the applicable period. (3) Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates. (4) Represents our expected share of the unrecognized compensation cost at March 31, 2016. We expect to recognize our share of the unrecognized compensation cost for EPD PubCo I, EPD PubCo II and EPD PrivCo I over a weighted-average period of 3.9 years, 4.9 years and 4.9 years, respectively. The following table summarizes the assumptions we used in applying a Black-Scholes option pricing model to derive that portion of the estimated grant date fair value of the profits interest awards for each Employee Partnership: Expected Risk-Free Expected Expected Unit Employee Life Interest Distribution Price Partnership of Award Rate Yield Volatility EPD PubCo I 4.0 years 1.09% 6.68% 40% EPD PubCo II 5.0 years 1.25% 6.68% 40% EPD PrivCo I 5.0 years 1.25% 6.68% 40%
Cash Distributions and Total Intrinsic Value of Phantom Unit Awards	The following table presents supplemental information regarding phantom unit awards for the periods indicated: For the Three Months Ended March 31, 2016 2015 Cash payments made in connection with DERs $ 2.0 $ 1.2 Total intrinsic value of phantom unit awards that vested during period $ 36.3 $ 26.6
Restricted Common Unit Awards	The following table presents restricted common unit award activity for the period indicated: Number of Units Weighted- Average Grant Date Fair Value per Unit Restricted common units at December 31, 2015 1,960,520 $ 27.88 Vested (1,167,578 ) $ 27.39 Forfeited (9,350 ) $ 28.32 Restricted common units at March 31, 2016 783,592 $ 28.60 (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 restricted common unit awards for the periods indicated: For the Three Months Ended March 31, 2016 2015 Cash distributions paid to restricted common unitholders $ 0.8 $ 1.5 Total intrinsic value of restricted common unit awards that vested during period $ 26.8 $ 62.4
Supplemental Information Regarding Unit Option Awards	The following table presents supplemental information regarding unit option awards during the three months ended March 31, 2015: Total intrinsic value of unit option awards exercised during period $ 17.4 Cash received from EPCO in connection with the exercise of unit option awards 10.1 Unit option award-related cash reimbursements to EPCO 17.4

Derivative Instruments, Hedgi34

Derivative Instruments, Hedging Activities and Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2016
Derivative Instruments, Hedging Activities and Fair Value Measurements [Abstract]
Hedging Instruments Under the FASB's Derivative and Hedging Guidance	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. This strategy may be used in controlling our overall cost of capital associated with such borrowings. The following table summarizes our portfolio of interest rate swaps at March 31, 2016: Hedged Transaction Number and Type of Derivatives Outstanding Notional Amount Period of Hedge Rate Swap Accounting Treatment Senior Notes OO 10 fixed-to-floating swaps $ 750.0 5/2015 to 5/2018 1.65% to 1.10% Fair value hedge The prices of natural gas, NGLs, crude oil, petrochemicals and refined 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 March 31, 2016 (volume measures as noted): Volume (1) Accounting Derivative Purpose Current Long-Term Treatment Derivatives designated as hedging instruments: Natural gas processing: Forecasted natural gas purchases for plant thermal reduction (Bcf) 32.7 n/a Cash flow hedge Forecasted sales of NGLs (MMBbls) (3) 6.5 n/a Cash flow hedge Octane enhancement: Forecasted sales of octane enhancement products (MMBbls) 1.0 n/a Cash flow hedge Natural gas marketing: Forecasted purchases of natural gas for fuel (Bcf) 7.2 n/a Cash flow hedge Natural gas storage inventory management activities (Bcf) 8.9 n/a Fair value hedge NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products (MMBbls) 58.3 0.5 Cash flow hedge Forecasted sales of NGLs and related hydrocarbon products (MMBbls) 66.3 n/a Cash flow hedge Refined products marketing: Forecasted purchases of refined products (MMBbls) 1.8 n/a Cash flow hedge Forecasted sales of refined products (MMBbls) 1.5 n/a Cash flow hedge Refined products inventory management activities (MMBbls) 5.1 n/a Fair value hedge Crude oil marketing: Forecasted purchases of crude oil (MMBbls) 13.1 n/a Cash flow hedge Forecasted sales of crude oil (MMBbls) 20.3 n/a Cash flow hedge Crude oil inventory management activities (MMBbls) 0.2 n/a Fair value hedge Derivatives not designated as hedging instruments: Natural gas risk management activities (Bcf) (4,5) 80.9 7.4 Mark-to-market NGL risk management activities (MMBbls) (5) 4.0 n/a Mark-to-market Crude oil risk management activities (MMBbls) (5) 28.5 2.3 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 2017, December 2016 and March 2019, 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 51.0 Bcf and 2.1 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 March 31, 2016 December 31, 2015 March 31, 2016 December 31, 2015 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 Current assets $ 5.2 Current assets $ 3.2 Other current liabilities $ -- Other current liabilities $ -- Interest rate derivatives Other assets 1.6 Other assets -- Other liabilities -- Other liabilities 3.7 Total interest rate derivatives 6.8 3.2 -- 3.7 Commodity derivatives Current assets 153.1 Current assets 253.8 Other current liabilities 220.8 Other current liabilities 137.5 Commodity derivatives Other assets 0.6 Other assets 0.2 Other liabilities 0.3 Other liabilities 1.4 Total commodity derivatives 153.7 254.0 221.1 138.9 Total derivatives designated as hedging instruments $ 160.5 $ 257.2 $ 221.1 $ 142.6 Derivatives not designated as hedging instruments Commodity derivatives Current assets $ 76.6 Current assets $ 1.6 Other current liabilities $ 66.3 Other current liabilities $ 3.1 Commodity derivatives Other assets 0.7 Other assets -- Other liabilities 1.8 Other liabilities 1.0 Total commodity derivatives $ 77.3 $ 1.6 $ 68.1 $ 4.1
Offsetting Financial Assets	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 Financial Instruments Cash Collateral Received Cash Collateral Paid (i) (ii) (iii) = (i) – (ii) (iv) (v) = (iii) + (iv) As of March 31, 2016: Interest rate derivatives $ 6.8 $ -- $ 6.8 $ -- $ -- $ -- $ 6.8 Commodity derivatives 231.0 -- 231.0 (228.9 ) -- -- 2.1 As of December 31, 2015: Interest rate derivatives $ 3.2 $ -- $ 3.2 $ (3.2 ) $ -- $ -- $ -- Commodity derivatives 255.6 -- 255.6 (143.0 ) (40.1 ) (72.2 ) 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 Financial Instruments Cash Collateral Paid (i) (ii) (iii) = (i) – (ii) (iv) (v) = (iii) + (iv) As of March 31, 2016: Commodity derivatives $ 289.2 $ -- $ 289.2 $ (228.9 ) $ (59.0 ) $ 1.3 As of December 31, 2015: Interest rate derivatives $ 3.7 $ -- $ 3.7 $ (3.2 ) $ -- $ 0.5 Commodity derivatives 143.0 -- 143.0 (143.0 ) -- --
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 March 31, 2016 2015 Interest rate derivatives Interest expense $ 6.1 $ -- Commodity derivatives Revenue (19.0 ) 0.7 Total $ (12.9 ) $ 0.7 Derivatives in Fair Value Hedging Relationships Location Gain (Loss) Recognized in Income on Hedged Item For the Three Months Ended March 31, 2016 2015 Interest rate derivatives Interest expense $ (6.2 ) $ -- Commodity derivatives Revenue 28.0 8.6 Total $ 21.8 $ 8.6
Derivative Instruments Effects on Statements of Comprehensive Income	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 March 31, 2016 2015 Commodity derivatives – Revenue (1) $ 3.3 $ 32.6 Commodity derivatives – Operating costs and expenses (1) (4.5 ) (1.8 ) Total $ (1.2 ) $ 30.8 (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 March 31, 2016 2015 Interest rate derivatives Interest expense $ (9.2 ) $ (8.7 ) Commodity derivatives Revenue 58.8 61.1 Commodity derivatives Operating costs and expenses (1.6 ) -- Total $ 48.0 $ 52.4
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 March 31, 2016 2015 Commodity derivatives Revenue $ -- $ 0.3
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 March 31, 2016 2015 Commodity derivatives Revenue $ (1.3 ) $ (0.4 ) Commodity derivatives Operating costs and expenses 0.1 -- Total $ (1.2 ) $ (0.4 )
Fair Value Measurements of Financial Assets and Liabilities Measured on a Recurring Basis	The following tables set forth, by level within the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated. 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. March 31, 2016 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 $ -- $ 6.8 $ -- $ 6.8 Commodity derivatives 114.8 113.9 2.3 231.0 Total $ 114.8 $ 120.7 $ 2.3 $ 237.8 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 242.9 $ 242.9 Commodity derivatives 126.6 160.9 1.7 289.2 Total $ 126.6 $ 160.9 $ 244.6 $ 532.1 December 31, 2015 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 $ -- $ 3.2 $ -- $ 3.2 Commodity derivatives 109.5 145.2 0.9 255.6 Total $ 109.5 $ 148.4 $ 0.9 $ 258.8 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 245.1 $ 245.1 Interest rate derivatives -- 3.7 -- 3.7 Commodity derivatives 31.3 109.2 2.5 143.0 Total $ 31.3 $ 112.9 $ 247.6 $ 391.8
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 Three Months Ended March 31, Location 2016 2015 Financial liability balance, net, January 1 $ (246.7 ) $ (219.3 ) Total gains (losses) included in: Net income (1) Revenue 0.7 (0.4 ) Net income Other expense, net 2.2 -- Other comprehensive income (loss) Commodity derivative instruments – changes in fair value of cash flow hedges 1.5 (1.5 ) Settlements (0.1 ) (0.5 ) Transfers out of Level 3 0.1 0.1 Financial liability balance, net, March 31 $ (242.3 ) $ (221.6 ) (1) There were $0.6 million of unrealized gains and $1.0 million of unrealized losses included in these amounts for the three months ended March 31, 2016 and 2015, respectively.
Fair Value Measurements, Valuation Techniques	The following Fair Value Financial Assets Financial Liabilities Valuation Techniques Unobservable Input Range Commodity derivatives – Crude oil $ 1.6 $ 1.4 Discounted cash flow Forward commodity prices $36.30-$43.03/barrel Commodity derivatives – Propane -- 0.3 Discounted cash flow Forward commodity prices $0.91-$0.93/gallon Commodity derivatives – Natural gasoline 0.7 -- Discounted cash flow Forward commodity prices $0.48/gallon Total $ 2.3 $ 1.7
Noncash Impairment Charges by Segment	The following table summarizes our non-cash impairment charges by segment during the periods indicated: For the Three Months Ended March 31, 2016 2015 NGL Pipelines & Services $ 0.4 $ 0.8 Crude Oil Pipelines & Services 0.2 7.8 Natural Gas Pipelines & Services -- 20.7 Petrochemical & Refined Products Services 1.1 0.4 Offshore Pipelines & Services -- 3.6 Total $ 1.7 $ 33.3
Nonrecurring Fair Value Measurements	Our non-cash impairment charges for the three months ended March 31, 2016 include $1.1 million related to other current assets, primarily spare parts and materials. The following table presents categories of long-lived assets, primarily property, plant and equipment, that were subject to non-recurring fair value measurements during the three months ended March 31, 2016: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at March 31, 2016 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 Long-lived assets disposed of other than by sale $ -- $ -- $ -- $ -- $ 0.6 The following table presents categories of long-lived assets, primarily property, plant and equipment, that were subject to non-recurring fair value measurements during the three months ended March 31, 2015: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at March 31, 2015 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 Long-lived assets disposed of other than by sale $ -- $ -- $ -- $ -- $ 33.1 Long-lived assets held for sale 0.6 -- -- 0.6 0.2 Total $ 33.3

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	The following table summarizes our related party transactions for the periods indicated: For the Three Months Ended March 31, 2016 2015 Revenues – related parties: Unconsolidated affiliates $ 15.6 $ 6.1 Costs and expenses – related parties: EPCO and its privately held affiliates $ 237.3 $ 221.9 Unconsolidated affiliates 72.9 39.2 Total $ 310.2 $ 261.1 The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated: March 31, 2016 December 31, 2015 Accounts receivable - related parties: Unconsolidated affiliates $ 1.1 $ 1.2 Accounts payable - related parties: EPCO and its privately held affiliates $ 24.3 $ 75.6 Unconsolidated affiliates 13.1 8.5 Total $ 37.4 $ 84.1 At March 31, 2016, EPCO and its privately held affiliates (including Dan Duncan LLC and certain Duncan family trusts) beneficially owned the following limited partner interests in us: Total Number of Units Percentage of Total Units Outstanding 685,481,428 33.3% 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 related party costs and expenses attributable to the ASA with EPCO for the periods indicated: For the Three Months Ended March 31, 2016 2015 Operating costs and expenses $ 205.4 $ 191.0 General and administrative expenses 27.3 26.6 Total costs and expenses $ 232.7 $ 217.6

Supplemental Cash Flow Inform36

Supplemental Cash Flow Information (Tables)	3 Months Ended
	Mar. 31, 2016
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 Three Months Ended March 31, 2016 2015 Decrease (increase) in: Accounts receivable – trade $ 124.6 $ 837.5 Accounts receivable – related parties 0.4 (0.6 ) Inventories (194.3 ) 161.0 Prepaid and other current assets 5.3 (3.2 ) Other assets 1.3 0.5 Increase (decrease) in: Accounts payable – trade (64.8 ) (61.6 ) Accounts payable – related parties (46.7 ) (69.6 ) Accrued product payables 228.7 (768.7 ) Accrued interest (158.2 ) (155.6 ) Other current liabilities (84.4 ) (71.9 ) Other liabilities 1.7 (6.8 ) Net effect of changes in operating accounts $ (186.4 ) $ (139.0 )
Schedule of Significant Acquisitions and Disposals	The following table presents our cash proceeds from asset sales for the periods indicated: For the Three Months Ended March 31, 2016 2015 Other cash proceeds $ 13.4 $ 0.5 Total $ 13.4 $ 0.5 The following table presents net gains (losses) attributable to asset sales for the periods indicated: For the Three Months Ended March 31, 2016 2015 Ne $ (4.9 ) $ 0.1 Total $ (4.9 ) $ 0.1

Condensed Consolidating Finan37

Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2016
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Balance Sheet	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Balance Sheet March 31, 2016 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 $ 215.6 $ 90.1 $ (8.2 ) $ 297.5 $ -- $ -- $ 297.5 Accounts receivable – trade, net 750.1 1,700.2 (0.9 ) 2,449.4 -- -- 2,449.4 Accounts receivable – related parties 92.1 680.4 (749.0 ) 23.5 -- (22.4 ) 1.1 Inventories 954.3 278.1 (0.3 ) 1,232.1 -- -- 1,232.1 Derivative assets 147.8 87.1 -- 234.9 -- -- 234.9 Prepaid and other current assets 157.1 227.7 (7.9 ) 376.9 0.7 -- 377.6 Total current assets 2,317.0 3,063.6 (766.3 ) 4,614.3 0.7 (22.4 ) 4,592.6 Property, plant and equipment, net 4,141.2 28,530.7 1.4 32,673.3 -- -- 32,673.3 Investments in unconsolidated affiliates 39,020.7 4,146.0 (40,482.6 ) 2,684.1 21,393.6 (21,393.6 ) 2,684.1 Intangible assets, net 715.8 3,289.7 (14.6 ) 3,990.9 -- -- 3,990.9 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 149.2 38.7 (136.9 ) 51.0 0.3 -- 51.3 Total assets $ 46,803.4 $ 44,354.4 $ (41,399.0 ) $ 49,758.8 $ 21,394.6 $ (21,416.0 ) $ 49,737.4 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 835.8 $ 0.1 $ -- $ 835.9 $ -- $ -- $ 835.9 Accounts payable – trade 324.3 427.0 (8.2 ) 743.1 0.4 -- 743.5 Accounts payable – related parties 713.8 87.7 (764.1 ) 37.4 22.4 (22.4 ) 37.4 Accrued product payables 1,257.4 1,434.5 (1.8 ) 2,690.1 -- -- 2,690.1 Accrued liability related to EFS Midstream acquisition -- 996.5 -- 996.5 -- -- 996.5 Accrued interest 193.5 0.4 -- 193.9 -- -- 193.9 Other current liabilities 179.5 344.5 (7.9 ) 516.1 -- -- 516.1 Total current liabilities 3,504.3 3,290.7 (782.0 ) 6,013.0 22.8 (22.4 ) 6,013.4 Long-term debt 21,904.6 15.2 -- 21,919.8 -- -- 21,919.8 Deferred tax liabilities 3.4 44.8 (0.8 ) 47.4 -- 2.8 50.2 Other long-term liabilities 9.5 291.9 (136.6 ) 164.8 242.9 -- 407.7 Commitments and contingencies Equity: Partners' and other owners' equity 21,381.6 40,641.1 (40,655.9 ) 21,366.8 21,128.9 (21,366.8 ) 21,128.9 Noncontrolling interests -- 70.7 176.3 247.0 -- (29.6 ) 217.4 Total equity 21,381.6 40,711.8 (40,479.6 ) 21,613.8 21,128.9 (21,396.4 ) 21,346.3 Total liabilities and equity $ 46,803.4 $ 44,354.4 $ (41,399.0 ) $ 49,758.8 $ 21,394.6 $ (21,416.0 ) $ 49,737.4 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Balance Sheet December 31, 2015 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 $ 14.4 $ 71.1 $ (50.6 ) $ 34.9 $ -- $ -- $ 34.9 Accounts receivable – trade, net 811.3 1,755.8 2.8 2,569.9 -- -- 2,569.9 Accounts receivable – related parties 59.0 795.4 (853.0 ) 1.4 -- (0.2 ) 1.2 Inventories 786.9 251.4 (0.2 ) 1,038.1 -- -- 1,038.1 Derivative assets 150.4 108.2 -- 258.6 -- -- 258.6 Prepaid and other current assets 153.6 249.1 (7.1 ) 395.6 -- -- 395.6 Total current assets 1,975.6 3,231.0 (908.1 ) 4,298.5 -- (0.2 ) 4,298.3 Property, plant and equipment, net 3,859.8 28,173.5 1.4 32,034.7 -- -- 32,034.7 Investments in unconsolidated affiliates 38,655.0 4,067.3 (40,093.8 ) 2,628.5 20,540.2 (20,540.2 ) 2,628.5 Intangible assets, net 721.2 3,330.7 (14.7 ) 4,037.2 -- -- 4,037.2 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 145.1 47.9 (135.2 ) 57.8 0.5 -- 58.3 Total assets $ 45,816.2 $ 44,136.1 $ (41,150.4 ) $ 48,801.9 $ 20,540.7 $ (20,540.4 ) $ 48,802.2 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 1,863.8 $ 0.1 $ -- $ 1,863.9 $ -- $ -- $ 1,863.9 Accounts payable – trade 375.3 535.1 (50.6 ) 859.8 0.3 -- 860.1 Accounts payable – related parties 885.3 62.3 (863.5 ) 84.1 0.2 (0.2 ) 84.1 Accrued product payables 997.7 1,489.3 (2.6 ) 2,484.4 -- -- 2,484.4 Accrued liability related to EFS Midstream acquisition -- 993.2 -- 993.2 -- -- 993.2 Accrued interest 352.0 0.1 -- 352.1 -- -- 352.1 Other current liabilities 178.7 357.1 (7.0 ) 528.8 -- -- 528.8 Total current liabilities 4,652.8 3,437.2 (923.7 ) 7,166.3 0.5 (0.2 ) 7,166.6 Long-term debt 20,661.6 15.3 -- 20,676.9 -- -- 20,676.9 Deferred tax liabilities 3.4 40.8 (0.8 ) 43.4 -- 2.7 46.1 Other long-term liabilities 14.5 286.9 (135.0 ) 166.4 245.1 -- 411.5 Commitments and contingencies Equity: Partners' and other owners' equity 20,483.9 40,297.2 (40,266.8 ) 20,514.3 20,295.1 (20,514.3 ) 20,295.1 Noncontrolling interests -- 58.7 175.9 234.6 -- (28.6 ) 206.0 Total equity 20,483.9 40,355.9 (40,090.9 ) 20,748.9 20,295.1 (20,542.9 ) 20,501.1 Total liabilities and equity $ 45,816.2 $ 44,136.1 $ (41,150.4 ) $ 48,801.9 $ 20,540.7 $ (20,540.4 ) $ 48,802.2
Condensed Consolidating Statement of Operations	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended March 31, 2016 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 $ 5,361.9 $ 3,282.7 $ (3,639.3 ) $ 5,005.3 $ -- $ -- $ 5,005.3 Costs and expenses: Operating costs and expenses 5,091.2 2,695.1 (3,639.4 ) 4,146.9 -- -- 4,146.9 General and administrative costs 6.0 36.8 -- 42.8 1.1 -- 43.9 Total costs and expenses 5,097.2 2,731.9 (3,639.4 ) 4,189.7 1.1 -- 4,190.8 Equity in income of unconsolidated affiliates 632.7 133.6 (665.2 ) 101.1 660.1 (660.1 ) 101.1 Operating income 897.4 684.4 (665.1 ) 916.7 659.0 (660.1 ) 915.6 Other income (expense): Interest expense (237.1 ) (5.2 ) 1.7 (240.6 ) -- -- (240.6 ) Other, net 1.8 1.3 (1.7 ) 1.4 2.2 -- 3.6 Total other income (expense), net (235.3 ) (3.9 ) -- (239.2 ) 2.2 -- (237.0 ) Income before income taxes 662.1 680.5 (665.1 ) 677.5 661.2 (660.1 ) 678.6 Provision for income taxes (2.9 ) (5.1 ) -- (8.0 ) -- (0.4 ) (8.4 ) Net income 659.2 675.4 (665.1 ) 669.5 661.2 (660.5 ) 670.2 Ne t income at -- (1.3 ) (8.9 ) (10.2 ) -- 1.2 (9.0 ) Net income attributable to entity $ 659.2 $ 674.1 $ (674.0 ) $ 659.3 $ 661.2 $ (659.3 ) $ 661.2 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended March 31, 2015 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 $ 5,579.8 $ 4,825.2 $ (2,932.5 ) $ 7,472.5 $ -- $ -- $ 7,472.5 Costs and expenses: Operating costs and expenses 5,324.1 4,224.9 (2,932.6 ) 6,616.4 -- -- 6,616.4 General and administrative costs 8.4 40.7 -- 49.1 0.2 -- 49.3 Total costs and expenses 5,332.5 4,265.6 (2,932.6 ) 6,665.5 0.2 -- 6,665.7 Equity in income of unconsolidated affiliates 627.7 91.6 (630.1 ) 89.2 636.3 (636.3 ) 89.2 Operating income 875.0 651.2 (630.0 ) 896.2 636.1 (636.3 ) 896.0 Other income (expense): Interest expense (238.3 ) (2.8 ) 2.0 (239.1 ) -- -- (239.1 ) Other, net 2.0 0.5 (2.0 ) 0.5 -- -- 0.5 Total other expense, net (236.3 ) (2.3 ) -- (238.6 ) -- -- (238.6 ) Income before income taxes 638.7 648.9 (630.0 ) 657.6 636.1 (636.3 ) 657.4 Provision for income taxes (3.2 ) (3.1 ) -- (6.3 ) -- (0.5 ) (6.8 ) Net income 635.5 645.8 (630.0 ) 651.3 636.1 (636.8 ) 650.6 Net loss (income) attributable to noncontrolling interests -- 0.3 (16.0 ) (15.7 ) -- 1.2 (14.5 ) Net income attributable to entity $ 635.5 $ 646.1 $ (646.0 ) $ 635.6 $ 636.1 $ (635.6 ) $ 636.1
Condensed Consolidating Statement of Comprehensive Income	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended March 31, 2016 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 $ 655.2 $ 630.1 $ (665.0 ) $ 620.3 $ 611.9 $ (611.3 ) $ 620.9 Comprehensive income attrib -- (1.3 ) (8.9 ) (10.2 ) -- 1.2 (9.0 ) Comprehensive income attributable to entity $ 655.2 $ 628.8 $ (673.9 ) $ 610.1 $ 611.9 $ (610.1 ) $ 611.9 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended March 31, 2015 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 $ 621.9 $ 637.8 $ (630.0 ) $ 629.7 $ 614.5 $ (615.2 ) $ 629.0 Comprehensive income attrib -- 0.3 (16.0 ) (15.7 ) -- 1.2 (14.5 ) Comprehensive income attributable to entity $ 621.9 $ 638.1 $ (646.0 ) $ 614.0 $ 614.5 $ (614.0 ) $ 614.5
Condensed Consolidating Statement of Cash Flows	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Three Months Ended March 31, 2016 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 $ 659.2 $ 675.4 $ (665.1 ) $ 669.5 $ 661.2 $ (660.5 ) $ 670.2 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 42.5 339.7 (0.1 ) 382.1 -- -- 382.1 Equity in income of unconsolidated affiliates (632.7 ) (133.6 ) 665.2 (101.1 ) (660.1 ) 660.1 (101.1 ) Distributions received on earnings from unconsolidated affiliates 247.2 74.2 (214.7 ) 106.7 788.5 (788.5 ) 106.7 Net effect of changes in operating accounts and other operating activities 35.5 (255.3 ) 42.4 (177.4 ) 18.8 0.4 (158.2 ) Net cash flows provided by operating activities 351.7 700.4 (172.3 ) 879.8 808.4 (788.5 ) 899.7 Investing activities: Capital expenditures, net of contributions in aid of construction costs (307.6 ) (687.4 ) -- (995.0 ) -- -- (995.0 ) Proceeds from asset sales 0.1 13.3 -- 13.4 -- -- 13.4 Other investing activities (387.5 ) (55.7 ) 260.9 (182.3 ) (1,008.6 ) 1,008.6 (182.3 ) Cash used in investing activities (695.0 ) (729.8 ) 260.9 (1,163.9 ) (1,008.6 ) 1,008.6 (1,163.9 ) Financing activities: Borrowings under debt agreements 20,000.6 -- -- 20,000.6 -- -- 20,000.6 Repayments of debt (19,797.3 ) (0.1 ) -- (19,797.4 ) -- -- (19,797.4 ) Cash distributions paid to partners (788.5 ) (222.9 ) 222.9 (788.5 ) (788.3 ) 788.5 (788.3 ) Cash payments made in connection with DERs -- -- -- -- (2.0 ) -- (2.0 ) Cash distributions paid to noncontrolling interests -- (0.5 ) (8.2 ) (8.7 ) -- -- (8.7 ) Cash contributions from noncontrolling interests -- 11.1 -- 11.1 -- -- 11.1 Net cash proceeds from issuance of common units -- -- -- -- 1,011.5 -- 1,011.5 Cash contributions from owners 1,008.6 260.9 (260.9 ) 1,008.6 -- (1,008.6 ) -- Other financing activities -- -- -- -- (21.0 ) -- (21.0 ) Cash provided by financing activities 423.4 48.5 (46.2 ) 425.7 200.2 (220.1 ) 405.8 Net change in cash and cash equivalents 80.1 19.1 42.4 141.6 -- -- 141.6 Cash and cash equivalents, January 1 -- 69.6 (50.6 ) 19.0 -- -- 19.0 Cash and cash equivalents, March 31 $ 80.1 $ 88.7 $ (8.2 ) $ 160.6 $ -- $ -- $ 160.6 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Three Months Ended March 31, 2015 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 $ 635.5 $ 645.8 $ (630.0 ) $ 651.3 $ 636.1 $ (636.8 ) $ 650.6 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 32.9 334.6 (0.1 ) 367.4 -- -- 367.4 Equity in income of unconsolidated affiliates (627.7 ) (91.6 ) 630.1 (89.2 ) (636.3 ) 636.3 (89.2 ) Distributions received on earnings from unconsolidated affiliates 633.9 97.5 (597.0 ) 134.4 726.7 (726.7 ) 134.4 Net effect of changes in operating accounts and other operating activities (146.6 ) 13.0 6.9 (126.7 ) 17.0 0.5 (109.2 ) Net cash flows provided by operating activities 528.0 999.3 (590.1 ) 937.2 743.5 (726.7 ) 954.0 Investing activities: Capital expenditures, net of contributions in aid of construction costs (234.2 ) (559.0 ) -- (793.2 ) -- -- (793.2 ) Proceeds from asset sales -- 0.5 -- 0.5 -- -- 0.5 Other investing activities (252.0 ) (24.0 ) 179.6 (96.4 ) (468.4 ) 468.4 (96.4 ) Cash used in investing activities (486.2 ) (582.5 ) 179.6 (889.1 ) (468.4 ) 468.4 (889.1 ) Financing activities: Borrowings under debt agreements 9,182.5 -- -- 9,182.5 -- -- 9,182.5 Repayments of debt (8,953.2 ) -- -- (8,953.2 ) -- -- (8,953.2 ) Cash distributions paid to partners (726.7 ) (613.1 ) 613.1 (726.7 ) (703.8 ) 726.7 (703.8 ) Cash payments made in connection with DERs -- -- -- -- (1.2 ) -- (1.2 ) Cash distributions paid to noncontrolling interests -- (0.4 ) (16.1 ) (16.5 ) -- -- (16.5 ) Cash contributions from noncontrolling interests -- 4.4 (0.4 ) 4.0 -- -- 4.0 Net cash proceeds from issuance of common units -- -- -- -- 468.4 -- 468.4 Cash contributions from owners 468.4 179.2 (179.2 ) 468.4 -- (468.4 ) -- Other financing activities 0.1 -- -- 0.1 (38.5 ) -- (38.4 ) Cash used in financing activities (28.9 ) (429.9 ) 417.4 (41.4 ) (275.1 ) 258.3 (58.2 ) Net change in cash and cash equivalents 12.9 (13.1 ) 6.9 6.7 -- -- 6.7 Cash and cash equivalents, January 1 18.7 70.4 (14.7 ) 74.4 -- -- 74.4 Cash and cash equivalents, March 31 $ 31.6 $ 57.3 $ (7.8 ) $ 81.1 $ -- $ -- $ 81.1

Partnership Operations, Organ38

Partnership Operations, Organization and Basis for Presentation (Details) bbl in Millions, $ in Millions, ft³ in Billions	3 Months Ended
	Mar. 31, 2016Segmentmibblft³	Dec. 31, 2015USD ($)	Dec. 31, 2014
Related Party Transaction [Line Items]
Number of miles of pipelines | mi	49,000
Number of barrels of storage capacity | bbl	250
Number of cubic feet of storage capacity | ft³	14
Number of reportable segments | Segment	5
Limited partners ownership interest (in hundredths)	100.00%
Debt Instrument [Line Items]
Unamortized debt issuance costs in current assets		$ 14.7
Unamortized debt issuance costs in other assets		135.1
Total unamortized debt issuance costs		$ 149.8
EPCO and its privately held affiliates [Member]
Related Party Transaction [Line Items]
Percentage of Total Units Outstanding (in hundredths)	33.30%
Oiltanking Partners L.P. [Member]
Business Acquisition [Line Items]
Limited partner interests acquired (in hundredths)			65.90%

General Accounting and Disclo39

General Accounting and Disclosure Matters (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Restricted cash [Abstract]
Restricted cash	$ 136.9	$ 15.9

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Available-for-Sale Inventory by Product Type [Abstract]
NGLs		$ 625.8		$ 639.9
Petrochemicals and refined products		335.7		148
Crude oil		248.7		222.1
Natural gas		21.9		28.1
Total		1,232.1		$ 1,038.1
Summary of cost of sales and lower of cost or market adjustments [Abstract]
Cost of sales	[1]	3,208.3	$ 5,678.1
Lower of cost or market adjustments		$ 5.3	$ 3.5
[1]	Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. Fluctuations in these amounts are primarily due to changes in energy commodity prices and sales volumes associated with our marketing activities.

Property, Plant and Equipment41

Property, Plant and Equipment (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		$ 41,529.1		$ 40,611.9
Less accumulated depreciation		8,855.8		8,577.2
Property, plant and equipment, net		32,673.3		32,034.7
Summary of depreciation expense and capitalized interest [Abstract]
Depreciation expense	[1]	295.9	$ 291.3
Capitalized interest	[2]	42.5	$ 29.6
Asset Retirement Obligations [Roll Forward]
Balance at beginning of period		58.5
Liabilities settled		(1.5)
Revisions in estimated cash flows		1.7
Accretion expense		0.9
Balance at end of period		59.6
Capitalized costs, asset retirement costs		17.5		17.6
Plants, pipelines and facilities [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[3]	$ 33,096.3		32,525
Plants, pipelines and facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[4],[5]	3 years
Plants, pipelines and facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[4],[5]	45 years
Underground and other storage facilities [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[6]	$ 3,147.1		3,000.5
Underground and other storage facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[6],[7]	5 years
Underground and other storage facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[6],[7]	40 years
Transportation equipment [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[8]	$ 161.6		159.9
Transportation equipment [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[8]	3 years
Transportation equipment [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[8]	10 years
Marine vessels [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[9]	$ 774		769.8
Marine vessels [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[9]	15 years
Marine vessels [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[9]	30 years
Land [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		$ 262.7		262.7
Construction in progress [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		$ 4,087.4		$ 3,894
Processing plants [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		20 years
Processing plants [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		35 years
Pipelines and related equipment [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		5 years
Pipelines and related equipment [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		45 years
Terminal facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		10 years
Terminal facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		35 years
Office furniture and equipment [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		3 years
Office furniture and equipment [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		20 years
Buildings [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		20 years
Buildings [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		40 years
Laboratory and shop equipment [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		5 years
Laboratory and shop equipment [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		35 years
Underground storage facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		5 years
Underground storage facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		35 years
Storage tanks [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		10 years
Storage tanks [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		40 years
Water wells [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		5 years
Water wells [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life		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; buildings, 20-40 years; office furniture and equipment, 3-20 years; and laboratory and shop equipment, 5-35 years.
[5]	Plants, pipelines and facilities include processing plants; NGL, natural gas, crude oil and petrochemical and refined products pipelines; terminal loading and unloading facilities; buildings; office furniture and equipment; laboratory and shop equipment and related assets.
[6]	Underground and other storage facilities include underground product storage caverns; above ground storage tanks; water wells and related assets.
[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.
[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.

Investments in Unconsolidated42

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2,684.1		$ 2,628.5
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	101.1	$ 89.2
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	46.4		46.9
Equity method investment amortization of excess cost	0.5	2.6
Equity Method Investment, Summarized Financial Information, Income Statement [Abstract]
Revenues	345.5	349.5
Operating income	213.7	196.6
Net income	215.2	193.4
NGL Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	15.1	11.6
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 25		25.3
NGL Pipelines & Services [Member] | Venice Energy Service Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	13.10%
Investments in unconsolidated affiliates	$ 25.7		25.9
NGL Pipelines & Services [Member] | K/D/S Promix, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 38.3		38.3
NGL Pipelines & Services [Member] | Baton Rouge Fractionators LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	32.20%
Investments in unconsolidated affiliates	$ 17.9		18.5
NGL Pipelines & Services [Member] | Skelly-Belvieu Pipeline Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 39.1		39.8
NGL Pipelines & Services [Member] | Texas Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	35.00%
Investments in unconsolidated affiliates	$ 338.1		342
NGL Pipelines & Services [Member] | Texas Express Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	45.00%
Investments in unconsolidated affiliates	$ 36.6		36.8
NGL Pipelines & Services [Member] | Front Range Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	33.30%
Investments in unconsolidated affiliates	$ 171.1		171.2
NGL Pipelines & Services [Member] | Delaware Basin Gas Processing LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 73.3		46.2
Crude Oil Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	90.1	59.9
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 19.1		19.3
Crude Oil Pipelines & Services [Member] | Seaway Crude Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 1,420		1,396
Crude Oil Pipelines & Services [Member] | Eagle Ford Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 389.5		388.8
Crude Oil Pipelines & Services [Member] | Eagle Ford Terminals Corpus Christi LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 39.1		28.6
Natural Gas Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	$ 1	0.9
Natural Gas Pipelines & Services [Member] | White River Hub, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 22.3		22.5
Petrochemical & Refined Products Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	(5.1)	(3.4)
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 2.3		2.3
Petrochemical & Refined Products Services [Member] | Baton Rouge Propylene Concentrator, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	30.00%
Investments in unconsolidated affiliates	$ 5.3		5.4
Petrochemical & Refined Products Services [Member] | Centennial Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership Interest (in hundredths)	50.00%
Investments in unconsolidated affiliates	$ 64.6		65.6
Petrochemical & Refined Products Services [Member] | Other Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	3.2		$ 2.9
Offshore Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	$ 0	$ 20.2

Intangible Assets and Goodwill,

Intangible Assets and Goodwill, Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Identifiable intangible assets [Abstract]
Gross Value	$ 5,273		$ 5,273
Accumulated Amortization	(1,282.1)		(1,235.8)
Carrying Value	3,990.9		4,037.2
Amortization Expense	46.3	$ 38.8
Forecasted amortization expense [Abstract]
Remainder of 2016	133.3
2,017	176.3
2,018	171.7
2,019	167.1
2,020	166.4
NGL Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	730.4		730.4
Accumulated Amortization	(357.9)		(350.1)
Carrying Value	372.5		380.3
Amortization Expense	7.8	7.5
NGL Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	447.4		447.4
Accumulated Amortization	(160.9)		(156.9)
Carrying Value	286.5		290.5
NGL Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	283		283
Accumulated Amortization	(197)		(193.2)
Carrying Value	86		89.8
Crude Oil Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,485.8		2,485.8
Accumulated Amortization	(136)		(108.3)
Carrying Value	2,349.8		2,377.5
Amortization Expense	27.7	16.7
Crude Oil Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,204.4		2,204.4
Accumulated Amortization	(52.1)		(39.1)
Carrying Value	2,152.3		2,165.3
Crude Oil Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	281.4		281.4
Accumulated Amortization	(83.9)		(69.2)
Carrying Value	197.5		212.2
Natural Gas Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,815		1,815
Accumulated Amortization	(735.9)		(727.3)
Carrying Value	1,079.1		1,087.7
Amortization Expense	8.6	9.9
Natural Gas Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,350.3		1,350.3
Accumulated Amortization	(372.4)		(366.3)
Carrying Value	977.9		984
Natural Gas Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	464.7		464.7
Accumulated Amortization	(363.5)		(361)
Carrying Value	101.2		103.7
Petrochemical & Refined Products Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	241.8		241.8
Accumulated Amortization	(52.3)		(50.1)
Carrying Value	189.5		191.7
Amortization Expense	2.2	2.4
Petrochemical & Refined Products Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	185.5		185.5
Accumulated Amortization	(39.7)		(38.3)
Carrying Value	145.8		147.2
Petrochemical & Refined Products Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	56.3		56.3
Accumulated Amortization	(12.6)		(11.8)
Carrying Value	43.7		$ 44.5
Offshore Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Amortization Expense	$ 0	$ 2.3

Intangible Assets and Goodwil44

Intangible Assets and Goodwill, Goodwill (Details) $ in Millions	Mar. 31, 2016USD ($)
Changes in carrying amount of goodwill [Roll Forward]
Balance at beginning of period	$ 5,745.2
Balance at end of period	5,745.2
NGL Pipelines & Services [Member]
Changes in carrying amount of goodwill [Roll Forward]
Balance at beginning of period	2,651.7
Balance at end of period	2,651.7
Crude Oil Pipelines & Services [Member]
Changes in carrying amount of goodwill [Roll Forward]
Balance at beginning of period	1,841
Balance at end of period	1,841
Natural Gas Pipelines & Services [Member]
Changes in carrying amount of goodwill [Roll Forward]
Balance at beginning of period	296.3
Balance at end of period	296.3
Petrochemical & Refined Products Services [Member]
Changes in carrying amount of goodwill [Roll Forward]
Balance at beginning of period	956.2
Balance at end of period	$ 956.2

Debt Obligations (Details)

Debt Obligations (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended
		Apr. 30, 2016	Mar. 31, 2016	Apr. 13, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Principal Outstanding			$ 22,946.4		$ 22,738.5
Other, non-principal amounts			(190.7)		(197.7)
Less current maturities of debt			(835.9)		(1,863.9)
Total long-term debt			21,919.8		20,676.9
Debt Obligations Terms [Abstract]
Letters of credit outstanding for facilities and motor fuel tax obligations			2.5
Total unamortized debt issuance costs					149.8
Senior Debt Obligations [Member]
Debt Instrument [Line Items]
Principal Outstanding			21,472		21,264.1
Debt Obligations Terms [Abstract]
Aggregate debt principal issued		$ 1,250
Senior Debt Obligations [Member] | Commercial Paper Notes [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 2,072		1,114.1
Debt Obligations Terms [Abstract]
Interest Rate Terms			variable
Information regarding variable interest rates paid [Abstract]
Variable Interest Rates Paid, Minimum (in hundredths)			0.56%
Variable Interest Rates Paid, Maximum (in hundredths)			1.18%
Weighted-Average Interest Rate Paid (in hundredths)			0.89%
Senior Debt Obligations [Member] | EPO Senior Notes AA [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 0		750
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			3.20%
Maturity Date			Feb. 1, 2016
Repayment of debt obligations			$ 750
Senior Debt Obligations [Member] | EPO 364-Day Credit Agreement [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 0		0
Debt Obligations Terms [Abstract]
Interest Rate Terms			variable
Maturity Date			Sep. 14, 2016
Senior Debt Obligations [Member] | EPO Senior Notes L [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 800		800
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.30%
Maturity Date			Sep. 1, 2017
Senior Debt Obligations [Member] | EPO Senior Notes V [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 349.7		349.7
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.65%
Maturity Date			Apr. 15, 2018
Senior Debt Obligations [Member] | EPO Senior Notes OO [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 750		750
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			1.65%
Maturity Date			May 7, 2018
Senior Debt Obligations [Member] | EPO Senior Notes N [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 700		700
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.50%
Maturity Date			Jan. 31, 2019
Senior Debt Obligations [Member] | EPO Senior Notes LL [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 800		800
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			2.55%
Maturity Date			Oct. 15, 2019
Senior Debt Obligations [Member] | EPO Senior Notes Q [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 500		500
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.25%
Maturity Date			Jan. 31, 2020
Senior Debt Obligations [Member] | EPO Senior Notes Y [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,000		1,000
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.20%
Maturity Date			Sep. 1, 2020
Senior Debt Obligations [Member] | EPO Multi-Year Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 0		0
Debt Obligations Terms [Abstract]
Interest Rate Terms			variable
Maturity Date			Sep. 15, 2020
Information regarding variable interest rates paid [Abstract]
Variable Interest Rates Paid, Minimum (in hundredths)			1.43%
Variable Interest Rates Paid, Maximum (in hundredths)			1.43%
Weighted-Average Interest Rate Paid (in hundredths)			1.43%
Senior Debt Obligations [Member] | EPO Senior Notes CC [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 650		650
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.05%
Maturity Date			Feb. 15, 2022
Senior Debt Obligations [Member] | EPO Senior Notes HH [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,250		1,250
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			3.35%
Maturity Date			Mar. 15, 2023
Senior Debt Obligations [Member] | EPO Senior Notes JJ [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 850		850
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			3.90%
Maturity Date			Feb. 15, 2024
Senior Debt Obligations [Member] | EPO Senior Notes MM [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,150		1,150
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			3.75%
Maturity Date			Feb. 15, 2025
Senior Debt Obligations [Member] | EPO Senior Notes PP [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 875		875
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			3.70%
Maturity Date			Feb. 15, 2026
Senior Debt Obligations [Member] | EPO Senior Notes D [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 500		500
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.875%
Maturity Date			Mar. 1, 2033
Senior Debt Obligations [Member] | EPO Senior Notes H [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 350		350
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.65%
Maturity Date			Oct. 15, 2034
Senior Debt Obligations [Member] | EPO Senior Notes J [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 250		250
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.75%
Maturity Date			Mar. 1, 2035
Senior Debt Obligations [Member] | EPO Senior Notes W [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 399.6		399.6
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			7.55%
Maturity Date			Apr. 15, 2038
Senior Debt Obligations [Member] | EPO Senior Notes R [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 600		600
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.125%
Maturity Date			Oct. 15, 2039
Senior Debt Obligations [Member] | EPO Senior Notes Z [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 600		600
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.45%
Maturity Date			Sep. 1, 2040
Senior Debt Obligations [Member] | EPO Senior Notes BB [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 750		750
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.95%
Maturity Date			Feb. 1, 2041
Senior Debt Obligations [Member] | EPO Senior Notes DD [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 600		600
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.70%
Maturity Date			Feb. 15, 2042
Senior Debt Obligations [Member] | EPO Senior Notes EE [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 750		750
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.85%
Maturity Date			Aug. 15, 2042
Senior Debt Obligations [Member] | EPO Senior Notes GG [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,100		1,100
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.45%
Maturity Date			Feb. 15, 2043
Senior Debt Obligations [Member] | EPO Senior Notes II [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,400		1,400
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.85%
Maturity Date			Mar. 15, 2044
Senior Debt Obligations [Member] | EPO Senior Notes KK [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 1,150		1,150
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			5.10%
Maturity Date			Feb. 15, 2045
Senior Debt Obligations [Member] | EPO Senior Notes QQ [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 875		875
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.90%
Maturity Date			May 15, 2046
Aggregate debt principal issued		$ 100
Debt issued as percent of principal amount (in hundredths)		95.516%
Senior Debt Obligations [Member] | EPO Senior Notes NN [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 400		400
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			4.95%
Maturity Date			Oct. 15, 2054
Senior Debt Obligations [Member] | TEPPCO Senior Notes 4 [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 0.3		0.3
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			6.65%
Maturity Date			Apr. 15, 2018
Senior Debt Obligations [Member] | TEPPCO Senior Notes 5 [Member]
Debt Instrument [Line Items]
Principal Outstanding			$ 0.4		0.4
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed
Interest Rate, stated percentage (in hundredths)			7.55%
Maturity Date			Apr. 15, 2038
Senior Debt Obligations [Member] | EPO Senior Notes RR [Member]
Debt Obligations Terms [Abstract]
Interest Rate, stated percentage (in hundredths)				2.85%
Maturity Date		Apr. 21, 2021
Aggregate debt principal issued		$ 575
Debt issued as percent of principal amount (in hundredths)		99.898%
Senior Debt Obligations [Member] | EPO Senior Notes SS [Member]
Debt Obligations Terms [Abstract]
Interest Rate, stated percentage (in hundredths)				3.95%
Maturity Date		Feb. 15, 2027
Aggregate debt principal issued		$ 575
Debt issued as percent of principal amount (in hundredths)		99.76%
Junior Debt Obligations [Member] | EPO Junior Subordinated Notes A [Member]
Debt Instrument [Line Items]
Principal Outstanding	[1]		$ 521.1		521.1
Debt Obligations Terms [Abstract]
Interest Rate Terms	[1]		fixed/variable
Interest Rate, stated percentage (in hundredths)	[1]		8.375%
Maturity Date	[1]		Aug. 31, 2066
Date through which interest rate is fixed			8/1/2016
Variable annual interest rate thereafter, variable rate basis			3-month LIBOR
Variable interest rate (in hundredths)			3.708%
Junior Debt Obligations [Member] | EPO Junior Subordinated Notes C [Member]
Debt Instrument [Line Items]
Principal Outstanding	[2]		$ 256.4		256.4
Debt Obligations Terms [Abstract]
Interest Rate Terms	[2]		fixed/variable
Interest Rate, stated percentage (in hundredths)	[2]		7.00%
Maturity Date	[2]		Jun. 1, 2067
Date through which interest rate is fixed			9/1/2017
Variable annual interest rate thereafter, variable rate basis			3-month LIBOR
Variable interest rate (in hundredths)			2.778%
Junior Debt Obligations [Member] | EPO Junior Subordinated Notes B [Member]
Debt Instrument [Line Items]
Principal Outstanding	[3]		$ 682.7		682.7
Debt Obligations Terms [Abstract]
Interest Rate Terms	[3]		fixed/variable
Interest Rate, stated percentage (in hundredths)	[3]		7.034%
Maturity Date	[3]		Jan. 15, 2068
Date through which interest rate is fixed			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]
Debt Instrument [Line Items]
Principal Outstanding			$ 14.2		$ 14.2
Debt Obligations Terms [Abstract]
Interest Rate Terms			fixed/variable
Maturity Date			Jun. 1, 2067
[1]	Fixed rate of 8.375% through August 1, 2016 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 3.708%.
[2]	Fixed rate of 7.000% through September 1, 2017 (i.e., first call date without a make-whole redemption premium); thereafter, variable rate based on 3-month LIBOR plus 2.778%.
[3]	Fixed rate of 7.034% through January 15, 2018 (i.e., first call date without a make-whole redemption premium); thereafter, the rate will be the greater of 7.034% or a variable rate based on 3-month LIBOR plus 2.680%.

Debt Obligations, Debt Maturiti

Debt Obligations, Debt Maturities (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	$ 2,072
2,017	800
2,018	1,100
2,019	1,500
2,020	1,500
After 2,020	15,974.4
Total	22,946.4	$ 22,738.5
Commercial Paper Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	2,072
2,017	0
2,018	0
2,019	0
2,020	0
After 2,020	0
Total	2,072
Senior Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	0
2,017	800
2,018	1,100
2,019	1,500
2,020	1,500
After 2,020	14,500
Total	19,400
Junior Subordinated Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	0
2,017	0
2,018	0
2,019	0
2,020	0
After 2,020	1,474.4
Total	$ 1,474.4

Equity and Distributions, Summa

Equity and Distributions, Summary of Changes in Outstanding Units (Details)	3 Months Ended
	Mar. 31, 2016shares
Common Units (Unrestricted) [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	2,010,592,504
Common units issued in connection with ATM program (in units)	35,396,147
Common units issued in connection with DRIP and EUPP (in units)	7,282,006
Common units issued in connection with the vesting of phantom unit awards (in units)	1,053,117
Common units issued in connection with the vesting of restricted common unit awards (in units)	1,167,578
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)	(388,396)
Other (in units)	20,630
Ending Balance (in units)	2,055,123,586
Restricted Common Units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	1,960,520
Common units issued in connection with ATM program (in units)	0
Common units issued in connection with DRIP and EUPP (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)	(1,167,578)
Forfeiture of restricted common unit awards (in units)	(9,350)
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)	783,592
Common units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	2,012,553,024
Common units issued in connection with ATM program (in units)	35,396,147
Common units issued in connection with DRIP and EUPP (in units)	7,282,006
Common units issued in connection with the vesting of phantom unit awards (in units)	1,053,117
Common units issued in connection with the vesting of restricted common unit awards (in units)	0
Forfeiture of restricted common unit awards (in units)	(9,350)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (in units)	(388,396)
Other (in units)	20,630
Ending Balance (in units)	2,055,907,178

Equity and Distributions, Issua

Equity and Distributions, Issuances of Equity (Details) - USD ($) $ in Millions	Apr. 08, 2016	Mar. 31, 2016	Mar. 31, 2015	Apr. 22, 2016
Net Cash Proceeds from Sale of Common Units [Abstract]
Net cash proceeds from the issuance of common units		$ 1,011.5	$ 468.4
At-the-Market Registration [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance				$ 2,170
Remaining units available for issuance	$ 415.7
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	25,550,931	35,396,147	12,350,761
Gross proceeds from the sale of common units	$ 594.1	$ 856.5	$ 407.8
Net cash proceeds from the issuance of common units	$ 592	$ 849	$ 404.2
At-the-Market Registration [Member] | EPCO and its privately held affiliates [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)		3,830,256
Gross proceeds from the sale of common units		$ 100
Distribution Reinvestment Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units)		140,000,000
Remaining units available for issuance (in units)		7,905,254
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)		7,162,744	1,869,079
Net cash proceeds from the issuance of common units		$ 159.8	$ 61.7
Distribution Reinvestment Plan [Member] | EPCO and its privately held affiliates [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)		4,481,504
Net cash proceeds from the issuance of common units		$ 100
Employee Unit Purchase Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units)		8,000,000
Remaining units available for issuance (in units)		6,653,244
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)		119,262	71,753
Net cash proceeds from the issuance of common units		$ 2.7	$ 2.5

Equity and Distributions, Accum

Equity and Distributions, Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	$ (219.2)	$ (241.6)
Other comprehensive income (loss) before reclassifications	(1.3)	30.8
Amounts reclassified from accumulated other comprehensive loss (income)	(48)	(52.4)
Total other comprehensive income (loss)	(49.3)	(21.6)
Ending Balance	(268.5)	(263.2)
Interest expense	240.6	239.1
Revenue	(5,005.3)	(7,472.5)
Operating costs and expenses	4,146.9	6,616.4
Total	(670.2)	(650.6)
Gains and Losses on Cash Flow Hedges [Member] | Interest rate derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	(279.5)	(314.8)
Other comprehensive income (loss) before reclassifications	0	0
Amounts reclassified from accumulated other comprehensive loss (income)	9.2	8.7
Total other comprehensive income (loss)	9.2	8.7
Ending Balance	(270.3)	(306.1)
Gains and Losses on Cash Flow Hedges [Member] | Commodity derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	56.6	69.9
Other comprehensive income (loss) before reclassifications	(1.2)	30.8
Amounts reclassified from accumulated other comprehensive loss (income)	(57.2)	(61.1)
Total other comprehensive income (loss)	(58.4)	(30.3)
Ending Balance	(1.8)	39.6
Other [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	3.7	3.3
Other comprehensive income (loss) before reclassifications	(0.1)	0
Amounts reclassified from accumulated other comprehensive loss (income)	0	0
Total other comprehensive income (loss)	(0.1)	0
Ending Balance	3.6	3.3
Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Total	(48)	(52.4)
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	9.2	8.7
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	(58.8)	(61.1)
Operating costs and expenses	$ 1.6	$ 0

Equity and Distributions, Distr

Equity and Distributions, Distributions (Details) - $ / shares	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Distributions to Partners [Abstract]
Number of Designated Units excluded from distributions (in units)			35,380,000
Cash Distribution [Member] | First Quarter 2015 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)		$ 0.3750
Record Date		Apr. 30, 2015
Payment Date		May 7, 2015
Cash Distribution [Member] | First Quarter 2016 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)	$ 0.3950
Record Date	Apr. 29, 2016
Payment Date	May 6, 2016

Business Segments (Details)

Business Segments (Details) $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)Segment	Mar. 31, 2015USD ($)
Business Segments [Abstract]
Number of reportable segments | Segment	5
Segment Gross Operating Margin [Abstract]
Revenues	$ 5,005.3	$ 7,472.5
Subtract operating costs and expenses	(4,146.9)	(6,616.4)
Add equity in income of unconsolidated affiliates	101.1	89.2
Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin	358.2	345.3
Add impairment charges not reflected in gross operating margin	1.7	33.3
Add net losses or subtract net gains attributable to asset sales not reflected in gross operating margin	4.9	(0.1)
Add non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin	7.1	30.7
Subtract subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin	(12.9)	(20.1)
Total segment gross operating margin	1,318.5	1,334.4
Reconciliation of total Segment Gross Operating Margin [Abstract]
Total segment gross operating margin	1,318.5	1,334.4
Adjustments to reconcile total segment gross operating margin to operating income:
Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin	(358.2)	(345.3)
Subtract impairment charges not reflected in gross operating margin	(1.7)	(33.3)
Add net gains or subtract net losses attributable to asset sales not reflected in gross operating margin	(4.9)	0.1
Subtract non-refundable deferred revenues attributable to shipper make-up rights on major new pipeline projects reflected in gross operating margin	(7.1)	(30.7)
Add subsequent recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin	12.9	20.1
Subtract general and administrative costs not reflected in gross operating margin	(43.9)	(49.3)
Operating income	915.6	896
Other expense, net	(237)	(238.6)
Income before income taxes	$ 678.6	$ 657.4

Business Segments, Segment Repo

Business Segments, Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Information by business segment [Abstract]
Revenues from third parties	$ 4,989.7	$ 7,466.4
Revenues from related parties	15.6	6.1
Intersegment and intrasegment revenues	0	0
Total revenues	5,005.3	7,472.5
Equity in income (loss) of unconsolidated affiliates	101.1	89.2
Gross operating margin	1,318.5	1,334.4
Property, plant and equipment, net	32,673.3		$ 32,034.7
Investments in unconsolidated affiliates	2,684.1		2,628.5
Intangible assets, net	3,990.9		4,037.2
Goodwill	5,745.2		5,745.2
Segment assets	45,093.5		44,445.6
NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	2,403.8	2,676.3
Equity in income (loss) of unconsolidated affiliates	15.1	11.6
Intangible assets, net	372.5		380.3
Goodwill	2,651.7		2,651.7
Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	1,288.6	2,678
Equity in income (loss) of unconsolidated affiliates	90.1	59.9
Intangible assets, net	2,349.8		2,377.5
Goodwill	1,841		1,841
Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	550	733.9
Equity in income (loss) of unconsolidated affiliates	1	0.9
Intangible assets, net	1,079.1		1,087.7
Goodwill	296.3		296.3
Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Total revenues	762.9	1,349.1
Equity in income (loss) of unconsolidated affiliates	(5.1)	(3.4)
Intangible assets, net	189.5		191.7
Goodwill	956.2		956.2
Offshore Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	0	35.2
Equity in income (loss) of unconsolidated affiliates	0	20.2
Reportable Business Segments [Member] | NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	2,402	2,674.8
Revenues from related parties	1.8	1.5
Intersegment and intrasegment revenues	3,174.8	2,443.1
Total revenues	5,578.6	5,119.4
Equity in income (loss) of unconsolidated affiliates	15.1	11.6
Gross operating margin	783.7	695.2
Property, plant and equipment, net	12,934.9		12,909.7
Investments in unconsolidated affiliates	740.1		718.7
Intangible assets, net	372.5		380.3
Goodwill	2,651.7		2,651.7
Segment assets	16,699.2		16,660.4
Reportable Business Segments [Member] | Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	1,277.5	2,677
Revenues from related parties	11.1	1
Intersegment and intrasegment revenues	1,499.4	1,277.1
Total revenues	2,788	3,955.1
Equity in income (loss) of unconsolidated affiliates	90.1	59.9
Gross operating margin	202.3	214
Property, plant and equipment, net	3,896.6		3,550.3
Investments in unconsolidated affiliates	1,848.6		1,813.4
Intangible assets, net	2,349.8		2,377.5
Goodwill	1,841		1,841
Segment assets	9,936		9,582.2
Reportable Business Segments [Member] | Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	547.3	730.9
Revenues from related parties	2.7	3
Intersegment and intrasegment revenues	124.7	170
Total revenues	674.7	903.9
Equity in income (loss) of unconsolidated affiliates	1	0.9
Gross operating margin	177.7	204.5
Property, plant and equipment, net	8,551.1		8,620
Investments in unconsolidated affiliates	22.3		22.5
Intangible assets, net	1,079.1		1,087.7
Goodwill	296.3		296.3
Segment assets	9,948.8		10,026.5
Reportable Business Segments [Member] | Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Revenues from third parties	762.9	1,349.1
Revenues from related parties	0	0
Intersegment and intrasegment revenues	242.7	285.6
Total revenues	1,005.6	1,634.7
Equity in income (loss) of unconsolidated affiliates	(5.1)	(3.4)
Gross operating margin	154.8	174.6
Property, plant and equipment, net	3,203.3		3,060.7
Investments in unconsolidated affiliates	73.1		73.9
Intangible assets, net	189.5		191.7
Goodwill	956.2		956.2
Segment assets	4,422.1		4,282.5
Reportable Business Segments [Member] | Offshore Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	0	34.6
Revenues from related parties	0	0.6
Intersegment and intrasegment revenues	0	0.4
Total revenues	0	35.6
Equity in income (loss) of unconsolidated affiliates	0	20.2
Gross operating margin	0	46.1
Property, plant and equipment, net	0		0
Investments in unconsolidated affiliates	0		0
Intangible assets, net	0		0
Goodwill	0		0
Segment assets	0		0
Eliminations [Member]
Information by business segment [Abstract]
Revenues from third parties	0	0
Revenues from related parties	0	0
Intersegment and intrasegment revenues	(5,041.6)	(4,176.2)
Total revenues	(5,041.6)	(4,176.2)
Equity in income (loss) of unconsolidated affiliates	0	0
Gross operating margin	0	$ 0
Adjustments [Member]
Information by business segment [Abstract]
Property, plant and equipment, net	4,087.4		3,894
Investments in unconsolidated affiliates	0		0
Intangible assets, net	0		0
Goodwill	0		0
Segment assets	$ 4,087.4		$ 3,894

Business Segments, Consolidated

Business Segments, Consolidated Revenues and Expenses (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Consolidated Revenues [Abstract]
Total consolidated revenues		$ 5,005.3	$ 7,472.5
Operating costs and expenses:
Cost of sales	[1]	3,208.3	5,678.1
Other operating costs and expenses	[2]	573.8	559.8
Depreciation, amortization and accretion		358.2	345.3
Net losses (gains) attributable to asset sales		4.9	(0.1)
Non-cash asset impairment charges		1.7	33.3
General and administrative costs		43.9	49.3
Total consolidated costs and expenses		4,190.8	6,665.7
NGL Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of NGLs and related products		1,943.5	2,242.2
Midstream services		460.3	434.1
Total consolidated revenues		2,403.8	2,676.3
Crude Oil Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of crude oil		1,121.1	2,570.7
Midstream services		167.5	107.3
Total consolidated revenues		1,288.6	2,678
Natural Gas Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of natural gas		315	476.3
Midstream services		235	257.6
Total consolidated revenues		550	733.9
Petrochemical & Refined Products Services [Member]
Consolidated Revenues [Abstract]
Sales of petrochemicals and refined products		553.2	1,151
Midstream services		209.7	198.1
Total consolidated revenues		762.9	1,349.1
Offshore Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of crude oil		0	1.1
Midstream services		0	34.1
Total consolidated revenues		$ 0	$ 35.2
[1]	Cost of sales is a component of "Operating costs and expenses" as presented on our Unaudited Condensed Statements of Consolidated Operations. 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.

Earnings Per Unit (Details)

Earnings Per Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
BASIC EARNINGS PER UNIT
Net income attributable to limited partners		$ 661.2	$ 636.1
Undistributed earnings allocated and cash payments on phantom unit awards	[1]	(3.2)	(2.2)
Net income available to common unitholders		$ 658	$ 633.9
Basic weighted-average number of common units outstanding (in units)		2,033.6	1,926.4
Basic earnings per unit (in dollars per unit)		$ 0.32	$ 0.33
DILUTED EARNINGS PER UNIT
Net income attributable to limited partners		$ 661.2	$ 636.1
Diluted weighted-average number of units outstanding:
Distribution-bearing common units (in units)		2,033.6	1,926.4
Designated Units (in units)		0	35.4
Phantom units (in units)	[1]	6.9	4.5
Incremental option units (in units)		0	0.4
Total (in units)		2,040.5	1,966.7
Diluted earnings per unit (in dollars per unit)		$ 0.32	$ 0.32
[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 our 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.

Equity-based Awards (Details)

Equity-based Awards (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Equity-based compensation expense [Abstract]
Total compensation expense	$ 22.4	$ 23.4
Equity-classified awards [Member] | Phantom Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	19.4	17.2
Equity-classified awards [Member] | Restricted Common Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	2.2	6.1
Equity-classified awards [Member] | Profits Interests Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	0.7	0
Liability-classified awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	$ 0.1	$ 0.1
Long-Term Incentive Plan (2008) [Member]
Equity-based compensation expense [Abstract]
Maximum number of common units that may be issued as awards (in units)	35,000,000
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)	17,981,493
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
Remaining number of common units available to be issued as awards (in units)	3,245,652

Equity-based Awards, Restricted

Equity-based Awards, Restricted Unit Awards (Details) - Restricted Common Unit Awards [Member] - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
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)		1,960,520
Vested (in units)		(1,167,578)
Forfeited (in units)		(9,350)
End of period (in units)		783,592
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]	$ 27.88
Vested weighted-average grant date fair value per unit (in dollars per unit)	[1]	27.39
Forfeited weighted-average grant date fair value per unit (in dollars per unit)	[1]	28.32
Weighted-average grant date fair value per unit, at end of period (in dollars per unit)	[1]	$ 28.60
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Cash distributions paid to restricted common unitholders		$ 0.8	$ 1.5
Total intrinsic value of our restricted common unit awards that vested during period		26.8	$ 62.4
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 4.7
Recognition period for total unrecognized compensation cost (in years)		10 months 24 days
Enterprise [Member]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 3.5
[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, Phantom Un

Equity-based Awards, Phantom Unit Awards (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Cash payments made in connection with DERs		$ 2	$ 1.2
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)		5,426,949
Granted (in units)	[1]	4,467,730
Vested (in units)		(1,586,493)
Forfeited (in units)		(41,673)
End of period (in units)		8,266,513
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]	$ 33.63
Granted weighted-average grant date fair value per unit (in dollars per unit)	[1],[2]	21.86
Vested weighted-average grant date fair value per unit (in dollars per unit)	[2]	33.56
Forfeited weighted-average grant date fair value per unit (in dollars per unit)	[2]	31.11
Weighted-average grant date fair value per unit, at end of period (in dollars per unit)	[2]	$ 27.29
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Aggregate grant date fair value		$ 97.7
Estimated forfeiture rate (in hundredths)		3.90%
Cash payments made in connection with DERs		$ 2	1.2
Total intrinsic value of phantom unit awards that vested during period		36.3	$ 26.6
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 145.2
Recognition period for total unrecognized compensation cost (in years)		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)		$ 21.86
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)		$ 21.86
Phantom Unit Awards [Member] | Enterprise [Member]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 133.1
[1]	The aggregate grant date fair value of phantom unit awards issued during 2016 was $97.7 million based on a grant date market price of our common units of $21.86 per unit. An estimated annual forfeiture rate of 3.9% 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.

Equity-based Awards, Unit Optio

Equity-based Awards, Unit Option Awards (Details) - Unit Option Awards [Member] $ in Millions	3 Months Ended
	Mar. 31, 2015USD ($)
Options outstanding, weighted-average strike price [Roll Forward]
Total intrinsic value of unit option awards exercised during period	$ 17.4
Cash received from EPCO in connection with the exercise of unit option awards	10.1
Unit option award-related cash reimbursements to EPCO	$ 17.4

Equity-based Awards, Profits In

Equity-based Awards, Profits Interest Awards (Details) - Profits Interests Awards [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)shares
EPD PubCo I [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	30 days
Common units owned by Employee Partnership (in units) | shares	2,723,052
Class A Capital Base	$ 63.5	[1]
Class A Partner Preferred Return Rate (in hundredths)	0.066638	[2]
Expected Liquidation Date	Feb. 1, 2020
Aggregate grant date fair value	$ 13.2	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 12.7	[4]
Recognition period for total unrecognized compensation cost (in years)	3 years 10 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award (in years)	4 years
Risk-Free Interest Rate (in hundredths)	1.09%
Expected Distribution Yield (in hundredths)	6.68%
Expected Unit Price Volatility (in hundredths)	40.00%
EPD PubCo II [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	30 days
Common units owned by Employee Partnership (in units) | shares	2,834,198
Class A Capital Base	$ 66.1	[1]
Class A Partner Preferred Return Rate (in hundredths)	0.066638	[2]
Expected Liquidation Date	Feb. 1, 2021
Aggregate grant date fair value	$ 14.8	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 14.3	[4]
Recognition period for total unrecognized compensation cost (in years)	4 years 10 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award (in years)	5 years
Risk-Free Interest Rate (in hundredths)	1.25%
Expected Distribution Yield (in hundredths)	6.68%
Expected Unit Price Volatility (in hundredths)	40.00%
EPD PrivCo I [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period	30 days
Common units owned by Employee Partnership (in units) | shares	1,111,438
Class A Capital Base	$ 25.9	[1]
Class A Partner Preferred Return Rate (in hundredths)	0.066638	[2]
Expected Liquidation Date	Feb. 1, 2021
Aggregate grant date fair value	$ 5.8	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 1.2	[4]
Recognition period for total unrecognized compensation cost (in years)	4 years 10 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award (in years)	5 years
Risk-Free Interest Rate (in hundredths)	1.25%
Expected Distribution Yield (in hundredths)	6.68%
Expected Unit Price Volatility (in hundredths)	40.00%
[1]	Represents the fair market value of the Enterprise common units contributed at the contribution date.
[2]	For each period, the Class A Preference Return equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by 6.6638% divided by 365 or 366 days, as the case may be during such calendar year, multiplied by the number of days in the applicable period.
[3]	Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates.
[4]	Represents our expected share of the unrecognized compensation cost at March 31, 2016. We expect to recognize our share of the unrecognized compensation cost for EPD PubCo I, EPD PubCo II and EPD PrivCo I over a weighted-average period of 3.9 years, 4.9 years and 4.9 years, respectively.

Derivative Instruments, Hedgi60

Derivative Instruments, Hedging Activities and Fair Value Measurements (Details) bbl in Millions, $ in Millions, ft³ in Billions	3 Months Ended
	Mar. 31, 2016USD ($)Contractbblft³
Interest rate derivatives [Member] | Derivatives in fair value hedging relationships [Member] | EPO Senior Notes OO [Member]
Derivative [Line Items]
Number of Derivatives Outstanding | Contract	10
Type of Derivatives Outstanding	fixed-to-floating swaps
Notional Amount | $	$ 750
Period of Hedge	5/2015 to 5/2018
Rate Swap, fixed rate (in hundredths)	1.65%
Rate Swap, floating rate (in hundredths)	1.10%
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas processing: Forecasted natural gas purchases for plant thermal reduction (PTR) [Member]
Derivative [Line Items]
Current Volume | ft³	32.7	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas processing: Forecasted sales of NGLs [Member]
Derivative [Line Items]
Current Volume	6.5	[1],[2],[3]
Forecasted NGL sales designated as normal sales agreements	0.3
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Octane enhancement: Forecasted sales of octane enhancement products [Member]
Derivative [Line Items]
Current Volume	1	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Natural gas marketing: Forecasted purchases of natural gas for fuel [Member]
Derivative [Line Items]
Current Volume | ft³	7.2	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products [Member]
Derivative [Line Items]
Current Volume	58.3	[1],[2]
Long Term Volume	0.5	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | NGL marketing: Forecasted sales of NGLs and related hydrocarbon products [Member]
Derivative [Line Items]
Current Volume	66.3	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Refined products marketing: Forecasted purchases of refined products [Member]
Derivative [Line Items]
Current Volume	1.8	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Refined products marketing: Forecasted sales of refined products [Member]
Derivative [Line Items]
Current Volume	1.5	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Crude oil marketing: Forecasted purchases of crude oil [Member]
Derivative [Line Items]
Current Volume	13.1	[1],[2]
Commodity derivatives [Member] | Derivatives in cash flow hedging relationships [Member] | Crude oil marketing: Forecasted sales of crude oil [Member]
Derivative [Line Items]
Current Volume	20.3	[1],[2]
Commodity derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Natural gas marketing: Natural gas storage inventory management activities [Member]
Derivative [Line Items]
Current Volume | ft³	8.9	[1],[2]
Commodity derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Refined products marketing: Refined products inventory management activities [Member]
Derivative [Line Items]
Current Volume	5.1	[1],[2]
Commodity derivatives [Member] | Derivatives in fair value hedging relationships [Member] | Crude oil marketing: Crude oil inventory management activities [Member]
Derivative [Line Items]
Current Volume	0.2	[1],[2]
Commodity derivatives [Member] | Derivatives in mark-to-market relationships [Member] | Natural gas risk management activities [Member]
Derivative [Line Items]
Current Volume | ft³	80.9	[1],[2],[4],[5]
Long Term Volume | ft³	7.4	[1],[2],[4],[5]
Current natural gas hedging volumes designated as an index plus or minus a discount | ft³	51
Long-term natural gas hedging volumes designated as an index plus or minus a discount | ft³	2.1
Commodity derivatives [Member] | Derivatives in mark-to-market relationships [Member] | NGL risk management activities [Member]
Derivative [Line Items]
Current Volume	4	[1],[2],[5]
Commodity derivatives [Member] | Derivatives in mark-to-market relationships [Member] | Crude oil risk management activities [Member]
Derivative [Line Items]
Current Volume	28.5	[1],[2],[5]
Long Term Volume	2.3	[1],[2],[5]
[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 2017, December 2016 and March 2019, 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 51.0 Bcf and 2.1 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, Hedgi61

Derivative Instruments, Hedging Activities and Fair Value Measurements, Derivative Fair Value Amounts (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 6.8	$ 3.2
Liability Derivatives		3.7
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	231	255.6
Liability Derivatives	289.2	143
Derivatives designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	160.5	257.2
Liability Derivatives	221.1	142.6
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	6.8	3.2
Liability Derivatives	0	3.7
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	5.2	3.2
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.6	0
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0	0
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0	3.7
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	153.7	254
Liability Derivatives	221.1	138.9
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	153.1	253.8
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.6	0.2
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	220.8	137.5
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.3	1.4
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	77.3	1.6
Liability Derivatives	68.1	4.1
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	76.6	1.6
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.7	0
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Other current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	66.3	3.1
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	$ 1.8	$ 1

Derivative Instruments, Hedgi62

Derivative Instruments, Hedging Activities and Fair Value Measurements, Asset Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 6.8	$ 3.2
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Assets Presented in the Balance Sheet	6.8	3.2
Financial Instruments	0	(3.2)
Cash Collateral Received	0	0
Cash Collateral Paid	0	0
Amounts That Would Have Been Presented On Net Basis	6.8	0
Commodity derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	231	255.6
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Assets Presented in the Balance Sheet	231	255.6
Financial Instruments	(228.9)	(143)
Cash Collateral Received	0	(40.1)
Cash Collateral Paid	0	(72.2)
Amounts That Would Have Been Presented On Net Basis	$ 2.1	$ 0.3

Derivative Instruments, Hedgi63

Derivative Instruments, Hedging Activities and Fair Value Measurements, Liability Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities		$ 3.7
Gross Amounts Offset in the Balance Sheet		0
Amounts of Liabilities Presented in the Balance Sheet		3.7
Financial Instruments		(3.2)
Cash Collateral Paid		0
Amounts That Would Have Been Presented On Net Basis		0.5
Commodity derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 289.2	143
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Liabilities Presented in the Balance Sheet	289.2	143
Financial Instruments	(228.9)	(143)
Cash Collateral Paid	(59)	0
Amounts That Would Have Been Presented On Net Basis	$ 1.3	$ 0

Derivative Instruments, Hedgi64

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
		Mar. 31, 2016	Mar. 31, 2015
Derivatives in fair value hedging relationships [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		$ (12.9)	$ 0.7
Gain (Loss) Recognized in Income on Hedged Item		21.8	8.6
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 Derivative		6.1	0
Gain (Loss) Recognized in Income on Hedged Item		(6.2)	0
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 Derivative		(19)	0.7
Gain (Loss) Recognized in Income on Hedged Item		28	8.6
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)		(1.2)	30.8
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		48	52.4
Derivatives in cash flow hedging relationships [Member] | Interest rate derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Accumulated other comprehensive loss related to interest rate derivative instruments expected to be reclassified to earnings in interest expense over the next twelve months		(37.9)
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)		(9.2)	(8.7)
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		(1.9)
Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to revenue over the next twelve months		0.6
Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to operating costs and expenses over the next twelve months		(2.5)
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]	3.3	32.6
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		58.8	61.1
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)		0	0.3
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]	(4.5)	(1.8)
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		(1.6)	0
Derivatives not designated as hedging instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		(1.2)	(0.4)
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Location - Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		(1.3)	(0.4)
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Location - Operating costs and expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		$ 0.1	$ 0
[1]	The fair value of these derivative instruments will be reclassified to their respective locations on the Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Derivative Instruments, Hedgi65

Derivative Instruments, Hedging Activities and Fair Value Measurements, Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Total gains (losses) included in:
Unrealized gain (loss) recognized as a component of net income related to financial assets and liabilities		$ (20.1)	$ 4.6
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Reconciliation of changes in the fair value of Level 3 financial assets and liabilities [Roll Forward]
Financial liability balance, net, beginning of period		(246.7)	(219.3)
Total gains (losses) included in:
Other comprehensive income		1.5	(1.5)
Settlements		(0.1)	(0.5)
Transfers out of Level 3		0.1	0.1
Financial liability balance, net, end of period		(242.3)	(221.6)
Unrealized gain (loss) recognized as a component of net income related to financial assets and liabilities		0.6	(1)
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Location - Revenue [Member]
Total gains (losses) included in:
Net income	[1]	0.7	(0.4)
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Location - Other Expense [Member]
Total gains (losses) included in:
Net income		2.2	$ 0
Fair Value, Measurements, Recurring [Member] | Fair Value [Member]
Financial assets [Abstract]
Interest rate derivatives		6.8		$ 3.2
Commodity derivatives		231		255.6
Total		237.8		258.8
Financial liabilities [Abstract]
Liquidity Option Agreement		242.9		245.1
Interest rate derivatives				3.7
Commodity derivatives		289.2		143
Total		532.1		391.8
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 1 [Member]
Financial assets [Abstract]
Interest rate derivatives		0		0
Commodity derivatives		114.8		109.5
Total		114.8		109.5
Financial liabilities [Abstract]
Liquidity Option Agreement		0		0
Interest rate derivatives				0
Commodity derivatives		126.6		31.3
Total		126.6		31.3
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 2 [Member]
Financial assets [Abstract]
Interest rate derivatives		6.8		3.2
Commodity derivatives		113.9		145.2
Total		120.7		148.4
Financial liabilities [Abstract]
Liquidity Option Agreement		0		0
Interest rate derivatives				3.7
Commodity derivatives		160.9		109.2
Total		160.9		112.9
Fair Value, Measurements, Recurring [Member] | Fair Value [Member] | Level 3 [Member]
Financial assets [Abstract]
Interest rate derivatives		0		0
Commodity derivatives		2.3		0.9
Total		2.3		0.9
Financial liabilities [Abstract]
Liquidity Option Agreement		242.9		245.1
Interest rate derivatives				0
Commodity derivatives		1.7		2.5
Total		$ 244.6		$ 247.6
[1]	There were $0.6 million of unrealized gains and $1.0 million of unrealized losses included in these amounts for the three months ended March 31, 2016 and 2015, respectively.

Derivative Instruments, Hedgi66

Derivative Instruments, Hedging Activities and Fair Value Measurements, Level 3 Recurring Valuation Techniques (Details) - Fair Value [Member] $ in Millions	3 Months Ended
	Mar. 31, 2016USD ($)$ / bbl$ / gal	Dec. 31, 2015USD ($)
Asset commodity derivatives - Crude oil [Member] | Liability commodity derivatives - Crude oil [Member] | Level 3 [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] | Level 3 [Member] | Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / bbl	36.30
Asset commodity derivatives - Crude oil [Member] | Liability commodity derivatives - Crude oil [Member] | Level 3 [Member] | Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / bbl	43.03
Asset commodity derivatives - Propane [Member] | Liability commodity derivatives - Propane [Member] | Level 3 [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] | Level 3 [Member] | Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / gal	0.91
Asset commodity derivatives - Propane [Member] | Liability commodity derivatives - Propane [Member] | Level 3 [Member] | Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / gal	0.93
Asset commodity derivatives - Natural gasoline [Member] | Liability commodity derivatives - Natural gasoline [Member] | Level 3 [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] | Level 3 [Member] | Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / gal	0.48
Fair Value, Measurements, Recurring [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	$ 231	$ 255.6
Commodity liability derivatives	289.2	143
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	2.3	0.9
Commodity liability derivatives	1.7	$ 2.5
Fair Value, Measurements, Recurring [Member] | Liability commodity derivatives - Crude oil [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	1.4
Fair Value, Measurements, Recurring [Member] | Liability commodity derivatives - Propane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	0.3
Fair Value, Measurements, Recurring [Member] | Liability commodity derivatives - Natural gasoline [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	0
Fair Value, Measurements, Recurring [Member] | Asset commodity derivatives - Crude oil [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	1.6
Fair Value, Measurements, Recurring [Member] | Asset commodity derivatives - Propane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	0
Fair Value, Measurements, Recurring [Member] | Asset commodity derivatives - Natural gasoline [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	$ 0.7

Derivative Instruments, Hedgi67

Derivative Instruments, Hedging Activities and Fair Value Measurements, Nonrecurring Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	$ 1.7	$ 33.3
Impairment of other current assets	1.1
Impairment of long-lived assets disposed of other than by sale	0.6	33.1
Impairment of long-lived assets held for sale		0.2
NGL Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0.4	0.8
Crude Oil Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0.2	7.8
Natural Gas Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0	20.7
Petrochemical & Refined Products Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	1.1	0.4
Offshore Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Non-cash asset impairment charges	0	3.6
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
Fair Value, Measurements, Nonrecurring [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0.6
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
Fair Value, Measurements, Nonrecurring [Member] | Level 1 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0
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
Fair Value, Measurements, Nonrecurring [Member] | Level 2 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		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
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		$ 0.6

Derivative Instruments, Hedgi68

Derivative Instruments, Hedging Activities and Fair Value Measurements, Other Fair Value Measurements (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015
Carrying Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 20,120	$ 20,870
Level 2 [Member] | Fair Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 20,270	$ 19,510

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	Apr. 08, 2016	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Revenues - related parties:
Total revenue - related parties		$ 15.6	$ 6.1
Costs and expenses - related parties:
Total costs and expenses - related parties		310.2	261.1
Accounts receivable - related parties:
Total accounts receivable - related parties		1.1		$ 1.2
Accounts payable - related parties:
Total accounts payable - related parties		37.4		$ 84.1
Related Party Transactions [Abstract]
Operating costs and expenses		280.6	232.1
General and administrative expenses		29.6	29
Relationship with Affiliates [Abstract]
Net cash proceeds from the issuance of common units		$ 1,011.5	$ 468.4
Number of Designated Units excluded from distributions (in units)				35,380,000
At-the-Market Registration [Member]
Relationship with Affiliates [Abstract]
Number of common units issued (in units)	25,550,931	35,396,147	12,350,761
Gross proceeds from the sale of common units	$ 594.1	$ 856.5	$ 407.8
Net cash proceeds from the issuance of common units	$ 592	$ 849	$ 404.2
Distribution Reinvestment Plan [Member]
Relationship with Affiliates [Abstract]
Number of common units issued (in units)		7,162,744	1,869,079
Net cash proceeds from the issuance of common units		$ 159.8	$ 61.7
EPCO and its privately held affiliates [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties		237.3	221.9
Accounts payable - related parties:
Total accounts payable - related parties		24.3		$ 75.6
Distributions:
Total cash distributions		$ 260.1	231.2
Relationship with Affiliates [Abstract]
Total Number of Units (in units)		685,481,428
Percentage of Total Units Outstanding (in hundredths)		33.30%
Number of Designated Units excluded from distributions (in units)				35,380,000
Enterprise common units pledged as security (in units)		118,000,000
EPCO and its privately held affiliates [Member] | At-the-Market Registration [Member]
Relationship with Affiliates [Abstract]
Number of common units issued (in units)		3,830,256
Gross proceeds from the sale of common units		$ 100
EPCO and its privately held affiliates [Member] | Distribution Reinvestment Plan [Member]
Relationship with Affiliates [Abstract]
Number of common units issued (in units)		4,481,504
Net cash proceeds from the issuance of common units		$ 100
EPCO and its privately held affiliates [Member] | Administrative Services Agreement [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties		232.7	217.6
Related Party Transactions [Abstract]
Operating costs and expenses		205.4	191
General and administrative expenses		27.3	26.6
Unconsolidated affiliates [Member]
Revenues - related parties:
Total revenue - related parties		15.6	6.1
Costs and expenses - related parties:
Total costs and expenses - related parties		72.9	$ 39.2
Accounts receivable - related parties:
Total accounts receivable - related parties		1.1		$ 1.2
Accounts payable - related parties:
Total accounts payable - related parties		$ 13.1		$ 8.5

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Operating lease obligations [Abstract]
Lease and rental expense included in costs and expenses	$ 28.5	$ 22.4
Litigation matters [Member]
Loss Contingencies [Line Items]
Litigation accruals on an undiscounted basis	2.6		$ 4.6
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
Prejudgment interest	$ 66.4
Post-judgment interest rate (in hundredths)	5.00%

Commitments and Contingencies,

Commitments and Contingencies, Liquidity Option Agreement (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Dec. 31, 2015
Liquidity Option Agreement [Abstract]
Liquidity Option Agreement	$ 242.9	$ 245.1
Business Acquisition [Line Items]
Change in fair value of Liquidity Option Agreement	$ (2.2)

Supplemental Cash Flow Inform72

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2016	Mar. 31, 2015	Dec. 31, 2015
Decrease (increase) in:
Accounts receivable - trade	$ 124.6	$ 837.5
Accounts receivable - related parties	0.4	(0.6)
Inventories	(194.3)	161
Prepaid and other current assets	5.3	(3.2)
Other assets	1.3	0.5
Increase (decrease) in:
Accounts payable - trade	(64.8)	(61.6)
Accounts payable - related parties	(46.7)	(69.6)
Accrued product payables	228.7	(768.7)
Accrued interest	(158.2)	(155.6)
Other current liabilities	(84.4)	(71.9)
Other liabilities	1.7	(6.8)
Net effect of changes in operating accounts	(186.4)	(139)
Liability for construction in progress expenditures	422.8		$ 472.8
Significant Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	13.4	0.5
Net gains (losses) attributable to asset sales and insurance recoveries	(4.9)	0.1
Other Disposal of Assets [Member]
Significant Disposals [Line Items]
Proceeds from asset sales and insurance recoveries	13.4	0.5
Net gains (losses) attributable to asset sales and insurance recoveries	$ (4.9)	$ 0.1

Condensed Consolidating Finan73

Condensed Consolidating Financial Information, Balance Sheet (Details) - USD ($) $ in Millions	Mar. 31, 2016	Dec. 31, 2015	Mar. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents and restricted cash	$ 297.5	$ 34.9
Accounts receivable - trade, net	2,449.4	2,569.9
Accounts receivable - related parties	1.1	1.2
Inventories	1,232.1	1,038.1
Derivative assets	234.9	258.6
Prepaid and other current assets	377.6	395.6
Total current assets	4,592.6	4,298.3
Property, plant and equipment, net	32,673.3	32,034.7
Investments in unconsolidated affiliates	2,684.1	2,628.5
Intangible assets, net	3,990.9	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	51.3	58.3
Total assets	49,737.4	48,802.2
Current liabilities:
Current maturities of debt	835.9	1,863.9
Accounts payable - trade	743.5	860.1
Accounts payable - related parties	37.4	84.1
Accrued product payables	2,690.1	2,484.4
Accrued liability related to EFS Midstream acquisition	996.5	993.2
Accrued interest	193.9	352.1
Other current liabilities	516.1	528.8
Total current liabilities	6,013.4	7,166.6
Long-term debt	21,919.8	20,676.9
Deferred tax liabilities	50.2	46.1
Other long-term liabilities	$ 407.7	$ 411.5
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ 21,128.9	$ 20,295.1
Noncontrolling interests	217.4	206
Total equity	21,346.3	20,501.1	$ 20,058.1	$ 19,692.2
Total liabilities and equity	49,737.4	48,802.2
Eliminations and Adjustments [Member]
Current assets:
Cash and cash equivalents and restricted cash	0	0
Accounts receivable - trade, net	0	0
Accounts receivable - related parties	(22.4)	(0.2)
Inventories	0	0
Derivative assets	0	0
Prepaid and other current assets	0	0
Total current assets	(22.4)	(0.2)
Property, plant and equipment, net	0	0
Investments in unconsolidated affiliates	(21,393.6)	(20,540.2)
Intangible assets, net	0	0
Goodwill	0	0
Other assets	0	0
Total assets	(21,416)	(20,540.4)
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	0	0
Accounts payable - related parties	(22.4)	(0.2)
Accrued product payables	0	0
Accrued liability related to EFS Midstream acquisition	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	(22.4)	(0.2)
Long-term debt	0	0
Deferred tax liabilities	2.8	2.7
Other long-term liabilities	$ 0	$ 0
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ (21,366.8)	$ (20,514.3)
Noncontrolling interests	(29.6)	(28.6)
Total equity	(21,396.4)	(20,542.9)
Total liabilities and equity	(21,416)	(20,540.4)
Subsidiary Issuer (EPO) [Member]
Current assets:
Cash and cash equivalents and restricted cash	215.6	14.4
Accounts receivable - trade, net	750.1	811.3
Accounts receivable - related parties	92.1	59
Inventories	954.3	786.9
Derivative assets	147.8	150.4
Prepaid and other current assets	157.1	153.6
Total current assets	2,317	1,975.6
Property, plant and equipment, net	4,141.2	3,859.8
Investments in unconsolidated affiliates	39,020.7	38,655
Intangible assets, net	715.8	721.2
Goodwill	459.5	459.5
Other assets	149.2	145.1
Total assets	46,803.4	45,816.2
Current liabilities:
Current maturities of debt	835.8	1,863.8
Accounts payable - trade	324.3	375.3
Accounts payable - related parties	713.8	885.3
Accrued product payables	1,257.4	997.7
Accrued liability related to EFS Midstream acquisition	0	0
Accrued interest	193.5	352
Other current liabilities	179.5	178.7
Total current liabilities	3,504.3	4,652.8
Long-term debt	21,904.6	20,661.6
Deferred tax liabilities	3.4	3.4
Other long-term liabilities	$ 9.5	$ 14.5
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ 21,381.6	$ 20,483.9
Noncontrolling interests	0	0
Total equity	21,381.6	20,483.9
Total liabilities and equity	46,803.4	45,816.2
Other Subsidiaries (Non-guarantor) [Member]
Current assets:
Cash and cash equivalents and restricted cash	90.1	71.1
Accounts receivable - trade, net	1,700.2	1,755.8
Accounts receivable - related parties	680.4	795.4
Inventories	278.1	251.4
Derivative assets	87.1	108.2
Prepaid and other current assets	227.7	249.1
Total current assets	3,063.6	3,231
Property, plant and equipment, net	28,530.7	28,173.5
Investments in unconsolidated affiliates	4,146	4,067.3
Intangible assets, net	3,289.7	3,330.7
Goodwill	5,285.7	5,285.7
Other assets	38.7	47.9
Total assets	44,354.4	44,136.1
Current liabilities:
Current maturities of debt	0.1	0.1
Accounts payable - trade	427	535.1
Accounts payable - related parties	87.7	62.3
Accrued product payables	1,434.5	1,489.3
Accrued liability related to EFS Midstream acquisition	996.5	993.2
Accrued interest	0.4	0.1
Other current liabilities	344.5	357.1
Total current liabilities	3,290.7	3,437.2
Long-term debt	15.2	15.3
Deferred tax liabilities	44.8	40.8
Other long-term liabilities	$ 291.9	$ 286.9
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ 40,641.1	$ 40,297.2
Noncontrolling interests	70.7	58.7
Total equity	40,711.8	40,355.9
Total liabilities and equity	44,354.4	44,136.1
Consolidated EPO and Subsidiaries [Member]
Current assets:
Cash and cash equivalents and restricted cash	297.5	34.9
Accounts receivable - trade, net	2,449.4	2,569.9
Accounts receivable - related parties	23.5	1.4
Inventories	1,232.1	1,038.1
Derivative assets	234.9	258.6
Prepaid and other current assets	376.9	395.6
Total current assets	4,614.3	4,298.5
Property, plant and equipment, net	32,673.3	32,034.7
Investments in unconsolidated affiliates	2,684.1	2,628.5
Intangible assets, net	3,990.9	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	51	57.8
Total assets	49,758.8	48,801.9
Current liabilities:
Current maturities of debt	835.9	1,863.9
Accounts payable - trade	743.1	859.8
Accounts payable - related parties	37.4	84.1
Accrued product payables	2,690.1	2,484.4
Accrued liability related to EFS Midstream acquisition	996.5	993.2
Accrued interest	193.9	352.1
Other current liabilities	516.1	528.8
Total current liabilities	6,013	7,166.3
Long-term debt	21,919.8	20,676.9
Deferred tax liabilities	47.4	43.4
Other long-term liabilities	$ 164.8	$ 166.4
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ 21,366.8	$ 20,514.3
Noncontrolling interests	247	234.6
Total equity	21,613.8	20,748.9
Total liabilities and equity	49,758.8	48,801.9
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Current assets:
Cash and cash equivalents and restricted cash	(8.2)	(50.6)
Accounts receivable - trade, net	(0.9)	2.8
Accounts receivable - related parties	(749)	(853)
Inventories	(0.3)	(0.2)
Derivative assets	0	0
Prepaid and other current assets	(7.9)	(7.1)
Total current assets	(766.3)	(908.1)
Property, plant and equipment, net	1.4	1.4
Investments in unconsolidated affiliates	(40,482.6)	(40,093.8)
Intangible assets, net	(14.6)	(14.7)
Goodwill	0	0
Other assets	(136.9)	(135.2)
Total assets	(41,399)	(41,150.4)
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	(8.2)	(50.6)
Accounts payable - related parties	(764.1)	(863.5)
Accrued product payables	(1.8)	(2.6)
Accrued liability related to EFS Midstream acquisition	0	0
Accrued interest	0	0
Other current liabilities	(7.9)	(7)
Total current liabilities	(782)	(923.7)
Long-term debt	0	0
Deferred tax liabilities	(0.8)	(0.8)
Other long-term liabilities	$ (136.6)	$ (135)
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ (40,655.9)	$ (40,266.8)
Noncontrolling interests	176.3	175.9
Total equity	(40,479.6)	(40,090.9)
Total liabilities and equity	(41,399)	(41,150.4)
Enterprise Products Partners L.P. (Guarantor) [Member]
Current assets:
Cash and cash equivalents and restricted cash	0	0
Accounts receivable - trade, net	0	0
Accounts receivable - related parties	0	0
Inventories	0	0
Derivative assets	0	0
Prepaid and other current assets	0.7	0
Total current assets	0.7	0
Property, plant and equipment, net	0	0
Investments in unconsolidated affiliates	21,393.6	20,540.2
Intangible assets, net	0	0
Goodwill	0	0
Other assets	0.3	0.5
Total assets	21,394.6	20,540.7
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	0.4	0.3
Accounts payable - related parties	22.4	0.2
Accrued product payables	0	0
Accrued liability related to EFS Midstream acquisition	0	0
Accrued interest	0	0
Other current liabilities	0	0
Total current liabilities	22.8	0.5
Long-term debt	0	0
Deferred tax liabilities	0	0
Other long-term liabilities	$ 242.9	$ 245.1
Commitments and contingencies
Equity:
Partners' and other owners' equity	$ 21,128.9	$ 20,295.1
Noncontrolling interests	0	0
Total equity	21,128.9	20,295.1
Total liabilities and equity	$ 21,394.6	$ 20,540.7

Condensed Consolidating Finan74

Condensed Consolidating Financial Information, Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Consolidating Statement of Operations
Revenues	$ 5,005.3	$ 7,472.5
Costs and expenses:
Operating costs and expenses	4,146.9	6,616.4
General and administrative costs	43.9	49.3
Total costs and expenses	4,190.8	6,665.7
Equity in income of unconsolidated affiliates	101.1	89.2
Operating income	915.6	896
Other income (expense):
Interest expense	(240.6)	(239.1)
Other, net	3.6	0.5
Total other income (expense), net	(237)	(238.6)
Income before income taxes	678.6	657.4
Provision for income taxes	(8.4)	(6.8)
Net income	670.2	650.6
Net loss (income) attributable to noncontrolling interests	(9)	(14.5)
Net income attributable to entity	661.2	636.1
Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Operations
Revenues	0	0
Costs and expenses:
Operating costs and expenses	0	0
General and administrative costs	0	0
Total costs and expenses	0	0
Equity in income of unconsolidated affiliates	(660.1)	(636.3)
Operating income	(660.1)	(636.3)
Other income (expense):
Interest expense	0	0
Other, net	0	0
Total other income (expense), net	0	0
Income before income taxes	(660.1)	(636.3)
Provision for income taxes	(0.4)	(0.5)
Net income	(660.5)	(636.8)
Net loss (income) attributable to noncontrolling interests	1.2	1.2
Net income attributable to entity	(659.3)	(635.6)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Operations
Revenues	5,361.9	5,579.8
Costs and expenses:
Operating costs and expenses	5,091.2	5,324.1
General and administrative costs	6	8.4
Total costs and expenses	5,097.2	5,332.5
Equity in income of unconsolidated affiliates	632.7	627.7
Operating income	897.4	875
Other income (expense):
Interest expense	(237.1)	(238.3)
Other, net	1.8	2
Total other income (expense), net	(235.3)	(236.3)
Income before income taxes	662.1	638.7
Provision for income taxes	(2.9)	(3.2)
Net income	659.2	635.5
Net loss (income) attributable to noncontrolling interests	0	0
Net income attributable to entity	659.2	635.5
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Operations
Revenues	3,282.7	4,825.2
Costs and expenses:
Operating costs and expenses	2,695.1	4,224.9
General and administrative costs	36.8	40.7
Total costs and expenses	2,731.9	4,265.6
Equity in income of unconsolidated affiliates	133.6	91.6
Operating income	684.4	651.2
Other income (expense):
Interest expense	(5.2)	(2.8)
Other, net	1.3	0.5
Total other income (expense), net	(3.9)	(2.3)
Income before income taxes	680.5	648.9
Provision for income taxes	(5.1)	(3.1)
Net income	675.4	645.8
Net loss (income) attributable to noncontrolling interests	(1.3)	0.3
Net income attributable to entity	674.1	646.1
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Operations
Revenues	5,005.3	7,472.5
Costs and expenses:
Operating costs and expenses	4,146.9	6,616.4
General and administrative costs	42.8	49.1
Total costs and expenses	4,189.7	6,665.5
Equity in income of unconsolidated affiliates	101.1	89.2
Operating income	916.7	896.2
Other income (expense):
Interest expense	(240.6)	(239.1)
Other, net	1.4	0.5
Total other income (expense), net	(239.2)	(238.6)
Income before income taxes	677.5	657.6
Provision for income taxes	(8)	(6.3)
Net income	669.5	651.3
Net loss (income) attributable to noncontrolling interests	(10.2)	(15.7)
Net income attributable to entity	659.3	635.6
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Operations
Revenues	(3,639.3)	(2,932.5)
Costs and expenses:
Operating costs and expenses	(3,639.4)	(2,932.6)
General and administrative costs	0	0
Total costs and expenses	(3,639.4)	(2,932.6)
Equity in income of unconsolidated affiliates	(665.2)	(630.1)
Operating income	(665.1)	(630)
Other income (expense):
Interest expense	1.7	2
Other, net	(1.7)	(2)
Total other income (expense), net	0	0
Income before income taxes	(665.1)	(630)
Provision for income taxes	0	0
Net income	(665.1)	(630)
Net loss (income) attributable to noncontrolling interests	(8.9)	(16)
Net income attributable to entity	(674)	(646)
Enterprise Products Partners L.P. (Guarantor) [Member]
Condensed Consolidating Statement of Operations
Revenues	0	0
Costs and expenses:
Operating costs and expenses	0	0
General and administrative costs	1.1	0.2
Total costs and expenses	1.1	0.2
Equity in income of unconsolidated affiliates	660.1	636.3
Operating income	659	636.1
Other income (expense):
Interest expense	0	0
Other, net	2.2	0
Total other income (expense), net	2.2	0
Income before income taxes	661.2	636.1
Provision for income taxes	0	0
Net income	661.2	636.1
Net loss (income) attributable to noncontrolling interests	0	0
Net income attributable to entity	$ 661.2	$ 636.1

Condensed Consolidating Finan75

Condensed Consolidating Financial Information, Statement of Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	$ 620.9	$ 629
Comprehensive loss (income) attributable to noncontrolling interests	(9)	(14.5)
Comprehensive income attributable to entity	611.9	614.5
Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(611.3)	(615.2)
Comprehensive loss (income) attributable to noncontrolling interests	1.2	1.2
Comprehensive income attributable to entity	(610.1)	(614)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	655.2	621.9
Comprehensive loss (income) attributable to noncontrolling interests	0	0
Comprehensive income attributable to entity	655.2	621.9
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	630.1	637.8
Comprehensive loss (income) attributable to noncontrolling interests	(1.3)	0.3
Comprehensive income attributable to entity	628.8	638.1
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	620.3	629.7
Comprehensive loss (income) attributable to noncontrolling interests	(10.2)	(15.7)
Comprehensive income attributable to entity	610.1	614
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(665)	(630)
Comprehensive loss (income) attributable to noncontrolling interests	(8.9)	(16)
Comprehensive income attributable to entity	(673.9)	(646)
Enterprise Products Partners L.P. (Guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	611.9	614.5
Comprehensive loss (income) attributable to noncontrolling interests	0	0
Comprehensive income attributable to entity	$ 611.9	$ 614.5

Condensed Consolidating Finan76

Condensed Consolidating Financial Information, Statement of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2016	Mar. 31, 2015
Operating activities:
Net income	$ 670.2	$ 650.6
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	382.1	367.4
Equity in income of unconsolidated affiliates	(101.1)	(89.2)
Distributions received on earnings from unconsolidated affiliates	106.7	134.4
Net effect of changes in operating accounts and other operating activities	(158.2)	(109.2)
Net cash flows provided by operating activities	899.7	954
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(995)	(793.2)
Proceeds from asset sales	13.4	0.5
Other investing activities	(182.3)	(96.4)
Cash used in investing activities	(1,163.9)	(889.1)
Financing activities:
Borrowings under debt agreements	20,000.6	9,182.5
Repayments of debt	(19,797.4)	(8,953.2)
Cash distributions paid to partners	(788.3)	(703.8)
Cash payments made in connection with DERs	(2)	(1.2)
Cash distributions paid to noncontrolling interests	(8.7)	(16.5)
Cash contributions from noncontrolling interests	11.1	4
Net cash proceeds from issuance of common units	1,011.5	468.4
Cash contributions from owners	0	0
Other financing activities	(21)	(38.4)
Cash provided by (used in) financing activities	405.8	(58.2)
Net change in cash and cash equivalents	141.6	6.7
Cash and cash equivalents, beginning balance	19	74.4
Cash and cash equivalents, ending balance	160.6	81.1
Eliminations and Adjustments [Member]
Operating activities:
Net income	(660.5)	(636.8)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	0	0
Equity in income of unconsolidated affiliates	660.1	636.3
Distributions received on earnings from unconsolidated affiliates	(788.5)	(726.7)
Net effect of changes in operating accounts and other operating activities	0.4	0.5
Net cash flows provided by operating activities	(788.5)	(726.7)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other investing activities	1,008.6	468.4
Cash used in investing activities	1,008.6	468.4
Financing activities:
Borrowings under debt agreements	0	0
Repayments of debt	0	0
Cash distributions paid to partners	788.5	726.7
Cash payments made in connection with DERs	0	0
Cash distributions paid to noncontrolling interests	0	0
Cash contributions from noncontrolling interests	0	0
Net cash proceeds from issuance of common units	0	0
Cash contributions from owners	(1,008.6)	(468.4)
Other financing activities	0	0
Cash provided by (used in) financing activities	(220.1)	258.3
Net change in cash and cash equivalents	0	0
Cash and cash equivalents, beginning balance	0	0
Cash and cash equivalents, ending balance	0	0
Subsidiary Issuer (EPO) [Member]
Operating activities:
Net income	659.2	635.5
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	42.5	32.9
Equity in income of unconsolidated affiliates	(632.7)	(627.7)
Distributions received on earnings from unconsolidated affiliates	247.2	633.9
Net effect of changes in operating accounts and other operating activities	35.5	(146.6)
Net cash flows provided by operating activities	351.7	528
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(307.6)	(234.2)
Proceeds from asset sales	0.1	0
Other investing activities	(387.5)	(252)
Cash used in investing activities	(695)	(486.2)
Financing activities:
Borrowings under debt agreements	20,000.6	9,182.5
Repayments of debt	(19,797.3)	(8,953.2)
Cash distributions paid to partners	(788.5)	(726.7)
Cash payments made in connection with DERs	0	0
Cash distributions paid to noncontrolling interests	0	0
Cash contributions from noncontrolling interests	0	0
Net cash proceeds from issuance of common units	0	0
Cash contributions from owners	1,008.6	468.4
Other financing activities	0	0.1
Cash provided by (used in) financing activities	423.4	(28.9)
Net change in cash and cash equivalents	80.1	12.9
Cash and cash equivalents, beginning balance	0	18.7
Cash and cash equivalents, ending balance	80.1	31.6
Other Subsidiaries (Non-guarantor) [Member]
Operating activities:
Net income	675.4	645.8
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	339.7	334.6
Equity in income of unconsolidated affiliates	(133.6)	(91.6)
Distributions received on earnings from unconsolidated affiliates	74.2	97.5
Net effect of changes in operating accounts and other operating activities	(255.3)	13
Net cash flows provided by operating activities	700.4	999.3
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(687.4)	(559)
Proceeds from asset sales	13.3	0.5
Other investing activities	(55.7)	(24)
Cash used in investing activities	(729.8)	(582.5)
Financing activities:
Borrowings under debt agreements	0	0
Repayments of debt	(0.1)	0
Cash distributions paid to partners	(222.9)	(613.1)
Cash payments made in connection with DERs	0	0
Cash distributions paid to noncontrolling interests	(0.5)	(0.4)
Cash contributions from noncontrolling interests	11.1	4.4
Net cash proceeds from issuance of common units	0	0
Cash contributions from owners	260.9	179.2
Other financing activities	0	0
Cash provided by (used in) financing activities	48.5	(429.9)
Net change in cash and cash equivalents	19.1	(13.1)
Cash and cash equivalents, beginning balance	69.6	70.4
Cash and cash equivalents, ending balance	88.7	57.3
Consolidated EPO and Subsidiaries [Member]
Operating activities:
Net income	669.5	651.3
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	382.1	367.4
Equity in income of unconsolidated affiliates	(101.1)	(89.2)
Distributions received on earnings from unconsolidated affiliates	106.7	134.4
Net effect of changes in operating accounts and other operating activities	(177.4)	(126.7)
Net cash flows provided by operating activities	879.8	937.2
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(995)	(793.2)
Proceeds from asset sales	13.4	0.5
Other investing activities	(182.3)	(96.4)
Cash used in investing activities	(1,163.9)	(889.1)
Financing activities:
Borrowings under debt agreements	20,000.6	9,182.5
Repayments of debt	(19,797.4)	(8,953.2)
Cash distributions paid to partners	(788.5)	(726.7)
Cash payments made in connection with DERs	0	0
Cash distributions paid to noncontrolling interests	(8.7)	(16.5)
Cash contributions from noncontrolling interests	11.1	4
Net cash proceeds from issuance of common units	0	0
Cash contributions from owners	1,008.6	468.4
Other financing activities	0	0.1
Cash provided by (used in) financing activities	425.7	(41.4)
Net change in cash and cash equivalents	141.6	6.7
Cash and cash equivalents, beginning balance	19	74.4
Cash and cash equivalents, ending balance	160.6	81.1
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Operating activities:
Net income	(665.1)	(630)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	(0.1)	(0.1)
Equity in income of unconsolidated affiliates	665.2	630.1
Distributions received on earnings from unconsolidated affiliates	(214.7)	(597)
Net effect of changes in operating accounts and other operating activities	42.4	6.9
Net cash flows provided by operating activities	(172.3)	(590.1)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other investing activities	260.9	179.6
Cash used in investing activities	260.9	179.6
Financing activities:
Borrowings under debt agreements	0	0
Repayments of debt	0	0
Cash distributions paid to partners	222.9	613.1
Cash payments made in connection with DERs	0	0
Cash distributions paid to noncontrolling interests	(8.2)	(16.1)
Cash contributions from noncontrolling interests	0	(0.4)
Net cash proceeds from issuance of common units	0	0
Cash contributions from owners	(260.9)	(179.2)
Other financing activities	0	0
Cash provided by (used in) financing activities	(46.2)	417.4
Net change in cash and cash equivalents	42.4	6.9
Cash and cash equivalents, beginning balance	(50.6)	(14.7)
Cash and cash equivalents, ending balance	(8.2)	(7.8)
Enterprise Products Partners L.P. (Guarantor) [Member]
Operating activities:
Net income	661.2	636.1
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	0	0
Equity in income of unconsolidated affiliates	(660.1)	(636.3)
Distributions received on earnings from unconsolidated affiliates	788.5	726.7
Net effect of changes in operating accounts and other operating activities	18.8	17
Net cash flows provided by operating activities	808.4	743.5
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0	0
Proceeds from asset sales	0	0
Other investing activities	(1,008.6)	(468.4)
Cash used in investing activities	(1,008.6)	(468.4)
Financing activities:
Borrowings under debt agreements	0	0
Repayments of debt	0	0
Cash distributions paid to partners	(788.3)	(703.8)
Cash payments made in connection with DERs	(2)	(1.2)
Cash distributions paid to noncontrolling interests	0	0
Cash contributions from noncontrolling interests	0	0
Net cash proceeds from issuance of common units	1,011.5	468.4
Cash contributions from owners	0	0
Other financing activities	(21)	(38.5)
Cash provided by (used in) financing activities	200.2	(275.1)
Net change in cash and cash equivalents	0	0
Cash and cash equivalents, beginning balance	0	0
Cash and cash equivalents, ending balance	$ 0	$ 0