Enterprise Products Partners (EPD) 10-Q 4 Nov 16 2016 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2016	Oct. 31, 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		2,104,197,364
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	Q3
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2016

UNAUDITED CONDENSED CONSOLIDATE

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 57.1	$ 19
Restricted cash	277.3	15.9
Accounts receivable - trade, net of allowance for doubtful accounts of $14.0 at September 30, 2016 and $12.1 at December 31, 2015	2,944.1	2,569.9
Accounts receivable - related parties	1.7	1.2
Inventories	1,762.5	1,038.1
Derivative assets	241.4	258.6
Prepaid and other current assets	457.5	395.6
Total current assets	5,741.6	4,298.3
Property, plant and equipment, net	33,119.4	32,034.7
Investments in unconsolidated affiliates	2,687.2	2,628.5
Intangible assets, net of accumulated amortization of $1,365.9 at September 30, 2016 and $1,235.8 at December 31, 2015	3,907.2	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	57.8	58.3
Total assets	51,258.4	48,802.2
Current liabilities:
Current maturities of debt	2,838.1	1,863.9
Accounts payable - trade	453.7	860.1
Accounts payable - related parties	97.7	84.1
Accrued product payables	3,087.5	2,484.4
Accrued liability related to EFS Midstream acquisition	0	993.2
Accrued interest	202.7	352.1
Derivative liabilities	464.2	140.6
Other current liabilities	424.4	388.2
Total current liabilities	7,568.3	7,166.6
Long-term debt	21,121.2	20,676.9
Deferred tax liabilities	51.6	46.1
Other long-term liabilities	478.6	411.5
Commitments and contingencies
Limited partners:
Common units (2,102,796,228 units outstanding at September 30, 2016 and 2,012,553,024 units outstanding at December 31, 2015)	22,127.9	20,514.3
Accumulated other comprehensive loss	(308.7)	(219.2)
Total partners' equity	21,819.2	20,295.1
Noncontrolling interests	219.5	206
Total equity	22,038.7	20,501.1
Total liabilities and equity	$ 51,258.4	$ 48,802.2

UNAUDITED CONDENSED CONSOLIDAT3

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Current assets:
Accounts receivable, allowance for doubtful accounts	$ 14	$ 12.1
Intangible assets, accumulated amortization	$ 1,365.9	$ 1,235.8
Limited partners:
Common units outstanding (in units)	2,102,796,228	2,012,553,024

UNAUDITED CONDENSED STATEMENTS

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Revenues:
Third parties	$ 5,904.7	$ 6,294	$ 16,499	$ 20,845.6
Related parties	15.7	13.9	44.5	27.3
Total revenues	5,920.4	6,307.9	16,543.5	20,872.9
Operating costs and expenses:
Third parties	4,781.2	5,167.9	13,199.4	17,642.6
Related parties	284.5	284.7	835.4	783.9
Total operating costs and expenses	5,065.7	5,452.6	14,034.8	18,426.5
General and administrative costs:
Third parties	15	20.8	35.9	57.9
Related parties	27	28.2	85.1	85.3
Total general and administrative costs	42	49	121	143.2
Total costs and expenses	5,107.7	5,501.6	14,155.8	18,569.7
Equity in income of unconsolidated affiliates	92.3	103.1	269.8	302.5
Operating income	905	909.4	2,657.5	2,605.7
Other income (expense):
Interest expense	(250.9)	(243.7)	(735.6)	(723.2)
Change in fair market value of Liquidity Option Agreement	(6.9)	(4.3)	(28)	(15.8)
Other, net	0.7	1.8	2.5	2.6
Total other expense, net	(257.1)	(246.2)	(761.1)	(736.4)
Income before income taxes	647.9	663.2	1,896.4	1,869.3
Provision for income taxes	(4.8)	(5.5)	(13.1)	(4.4)
Net income	643.1	657.7	1,883.3	1,864.9
Net income attributable to noncontrolling interests	(8.5)	(8.4)	(29)	(28.5)
Net income attributable to limited partners	$ 634.6	$ 649.3	$ 1,854.3	$ 1,836.4
Earnings per unit:
Basic earnings per unit (in dollars per unit)	$ 0.30	$ 0.33	$ 0.89	$ 0.94
Diluted earnings per unit (in dollars per unit)	$ 0.30	$ 0.32	$ 0.89	$ 0.92

UNAUDITED CONDENSED STATEMENTS5

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
Net income	$ 643.1	$ 657.7	$ 1,883.3	$ 1,864.9
Commodity derivative instruments:
Changes in fair value of cash flow hedges	22.7	85.8	(52.2)	112.3
Reclassification of gains to net income	(26.9)	(46.8)	(48.7)	(128.1)
Interest rate derivative instruments:
Changes in fair value of cash flow hedges	(6.9)	0	(16.3)	0
Reclassification of losses to net income	9.4	8.9	27.8	26.3
Total cash flow hedges	(1.7)	47.9	(89.4)	10.5
Other	0	0	(0.1)	0.4
Total other comprehensive income (loss)	(1.7)	47.9	(89.5)	10.9
Comprehensive income	641.4	705.6	1,793.8	1,875.8
Comprehensive income attributable to noncontrolling interests	(8.5)	(8.4)	(29)	(28.5)
Comprehensive income attributable to limited partners	$ 632.9	$ 697.2	$ 1,764.8	$ 1,847.3

UNAUDITED CONDENSED STATEMENTS6

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015
Operating activities:
Net income	$ 1,883.3	$ 1,864.9
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	1,155.3	1,147.7
Asset impairment charges	22	139.1
Loss due to Pascagoula fire	7.1	0
Equity in income of unconsolidated affiliates	(269.8)	(302.5)
Distributions received on earnings from unconsolidated affiliates	281.6	362.4
Net losses (gains) attributable to asset sales	(2.3)	14.7
Gains on early extinguishment of debt	0	(1.4)
Deferred income tax expense (benefit)	5.3	(13.3)
Change in fair market value of derivative instruments	42.1	(7.7)
Change in fair market value of Liquidity Option Agreement	28	15.8
Net effect of changes in operating accounts	(489.7)	(627.9)
Other operating activities	(3.9)	(0.6)
Net cash flows provided by operating activities	2,659	2,591.2
Investing activities:
Capital expenditures	(2,443.9)	(2,630.5)
Contributions in aid of construction costs	34.1	11.4
Increase in restricted cash	(261.4)	(46.2)
Cash used for business combinations, net of cash received	(1,000)	(1,045.1)
Investments in unconsolidated affiliates	(119.9)	(130.7)
Distributions received for return of capital from unconsolidated affiliates	51.9	0
Proceeds from asset sales	43.9	1,537.3
Other investing activities	(0.4)	(4.4)
Cash used in investing activities	(3,695.7)	(2,308.2)
Financing activities:
Borrowings under debt agreements	50,183.8	17,113.7
Repayments of debt	(48,776.5)	(16,139.2)
Debt issuance costs	(10.5)	(23.9)
Cash distributions paid to limited partners	(2,448.3)	(2,185.1)
Cash payments made in connection with distribution equivalent rights	(8.5)	(5.6)
Cash distributions paid to noncontrolling interests	(35.7)	(33.2)
Cash contributions from noncontrolling interests	20.1	37.4
Net cash proceeds from the issuance of common units	2,170.4	1,011.4
Other financing activities	(20)	(52.4)
Cash provided by (used in) financing activities	1,074.8	(276.9)
Net change in cash and cash equivalents	38.1	6.1
Cash and cash equivalents, beginning balance	19	74.4
Cash and cash equivalents, ending balance	$ 57.1	$ 80.5

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	1,864.9	0	28.5	1,836.4
Cash distributions paid to limited partners	(2,185.1)	0	0	(2,185.1)
Cash payments made in connection with distribution equivalent rights	(5.6)	0	0	(5.6)
Cash distributions paid to noncontrolling interests	(33.2)	0	(33.2)	0
Cash contributions from noncontrolling interests	37.4	0	37.4	0
Common units issued in connection with Step 2 of Oiltanking acquisition	0	0	(1,408.7)	1,408.7
Removal of noncontrolling interests in connection with sale of Offshore Business	(62.1)	0	(62.1)	0
Net cash proceeds from the issuance of common units	1,011.4	0	0	1,011.4
Amortization of fair value of equity-based awards	72.9	0	0	72.9
Cash flow hedges	10.5	10.5	0	0
Other	(50.4)	0.4	(0.1)	(50.7)
Balance at Sep. 30, 2015	20,352.9	(230.7)	190.8	20,392.8
Balance at Dec. 31, 2015	20,501.1	(219.2)	206	20,514.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	1,883.3	0	29	1,854.3
Cash distributions paid to limited partners	(2,448.3)	0	0	(2,448.3)
Cash payments made in connection with distribution equivalent rights	(8.5)	0	0	(8.5)
Cash distributions paid to noncontrolling interests	(35.7)	0	(35.7)	0
Cash contributions from noncontrolling interests	20.1	0	20.1	0
Net cash proceeds from the issuance of common units	2,170.4	0	0	2,170.4
Amortization of fair value of equity-based awards	67.7	0	0	67.7
Cash flow hedges	(89.4)	(89.4)	0	0
Other	(22)	(0.1)	0.1	(22)
Balance at Sep. 30, 2016	$ 22,038.7	$ (308.7)	$ 219.5	$ 22,127.9

Partnership Operations, Organiz

Partnership Operations, Organization and Basis for Presentation	9 Months Ended
	Sep. 30, 2016
Partnership Operations and Organization [Abstract]
Partnership Operations and Organization	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 32.6% of our limited partner interests at September 30, 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 (“Pioneer”) and Reliance Industries Limited (“Reliance”). 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	9 Months Ended
	Sep. 30, 2016
General Accounting Matters [Abstract]
General Accounting Matters	Our results of operations for the three and nine months ended September 30, 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, 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 margin requirements change. At September 30, 2016 and December 31, 2015, our restricted cash amounts were $277.3 million and $15.9 million, respectively. The balance at September 30, 2016 consisted of initial margin requirements of $48.9 million and variation margin requirements of $228.4 million. The initial margin requirements will be returned to us as the related derivative instruments are settled. Our variation margin requirements increased by $248.7 million since December 31, 2015 primarily due to higher forward commodity prices for NGLs and related hydrocarbons during 2016 relative to our short financial derivative positions in these products. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories

Inventories	9 Months Ended
	Sep. 30, 2016
Inventories [Abstract]
Inventories	Our inventory amounts by product type were as follows at the dates indicated: September 30, 2016 December 31, 2015 NGLs $ 1,202.4 $ 639.9 Petrochemicals and refined products 230.4 148.0 Crude oil 299.3 222.1 Natural gas 30.4 28.1 Total $ 1,762.5 $ 1,038.1 Our inventories, and associated working capital commitments, have increased significantly since December 31, 2015 primarily due to our marketing groups taking advantage of contango opportunities using our storage assets. We expect to gradually settle these inventory positions (valued at approximately $1 billion) through the first quarter of 2017, with a corresponding decrease in working capital commitments and related debt. Due to fluctuating commodity prices, we recognize lower of cost or market adjustments when the carrying value of our available-for-sale inventories exceeds their net realizable value. The following table presents our total cost of sales amounts and lower of cost or market adjustments for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cost of sales (1) $ 4,088.6 $ 4,419.9 $ 11,135.6 $ 15,355.9 Lower of cost or market adjustments within cost of sales 1.5 2.1 7.6 6.1 (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	9 Months Ended
	Sep. 30, 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 September 30, 2016 December 31, 2015 Plants, pipelines and facilities (1) 3-45 (5) $ 34,752.7 $ 32,525.0 Underground and other storage facilities (2) 5-40 (6) 3,309.2 3,000.5 Transportation equipment (3) 3-10 162.9 159.9 Marine vessels (4) 15-30 792.0 769.8 Land 264.6 262.7 Construction in progress 3,276.4 3,894.0 Total 42,557.8 40,611.9 Less accumulated depreciation 9,438.4 8,577.2 Property, plant and equipment, net $ 33,119.4 $ 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 (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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Depreciation expense (1) $ 309.4 $ 286.2 $ 903.5 $ 870.1 Capitalized interest (2) 38.9 40.3 127.8 105.6 (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. Fire at Pascagoula Facility We acquired the remaining 60% undivided interest in the Pascagoula natural gas processing facility (the “Pascagoula Facility”) for $35.0 million in March 2016 and assumed operatorship of the facility on June 1, 2016. The facility is located in Pascagoula, Mississippi and processes natural gas received from third-party production developments located in the northern Gulf of Mexico. On June 27, 2016, we experienced a fire at the facility, which remains out of service as a result of damage sustained during the fire. Repairs to this location have commenced and the facility is expected to return to commercial service during the fourth quarter of 2016. As a result of this event, we recorded a $7.1 million non-cash loss in the second quarter of 2016 attributable to assets damaged in the fire. In addition, we incurred $7.1 million of expense during the third quarter of 2016 for fire response activities at the Pascagoula Facility. We will capitalize those expenditures we incur to rebuild the facility. Under our current insurance program, the standalone deductible for property damage claims is $55 million. We also have business interruption protection; however, such claims must involve physical damage and have a combined loss value in excess of $55 million and the period of interruption must exceed 60 days. We continue to evaluate the possibility of filing an insurance claim related to this event. 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 September 30, 2016 and December 31, 2015 includes $21.1 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 incurred 4.1 Liabilities settled (2.9 ) Revisions in estimated cash flows 4.0 Accretion expense 2.8 ARO liability balance, September 30, 2016 $ 66.5

Investments in Unconsolidated A

Investments in Unconsolidated Affiliates	9 Months Ended
	Sep. 30, 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 September 30, 2016 September 30, 2016 December 31, 2015 NGL Pipelines & Services: Venice Energy Service Company, L.L.C. 13.1% $ 25.0 $ 25.9 K/D/S Promix, L.L.C. 50% 35.2 38.3 Baton Rouge Fractionators LLC 32.2% 17.1 18.5 Skelly-Belvieu Pipeline Company, L.L.C. 50% 40.0 39.8 Texas Express Pipeline LLC 35% 330.1 342.0 Texas Express Gathering LLC 45% 36.1 36.8 Front Range Pipeline LLC 33.3% 168.0 171.2 Delaware Basin Gas Processing LLC 50% 96.0 46.2 Crude Oil Pipelines & Services: Seaway Crude Pipeline Company LLC 50% 1,405.7 1,396.0 Eagle Ford Pipeline LLC 50% 383.6 388.8 Eagle Ford Terminals Corpus Christi LLC 50% 49.4 28.6 Natural Gas Pipelines & Services: White River Hub, LLC 50% 22.0 22.5 Petrochemical & Refined Products Services: Baton Rouge Propylene Concentrator, LLC 30% 4.6 5.4 Centennial Pipeline LLC 50% 62.7 65.6 Other Various 11.7 2.9 Total investments in unconsolidated affiliates $ 2,687.2 $ 2,628.5 The following table presents our equity in income (loss) of unconsolidated affiliates by business segment for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 15.9 $ 18.9 $ 45.0 $ 43.0 Crude Oil Pipelines & Services 78.4 81.2 234.3 220.5 Natural Gas Pipelines & Services 1.0 0.9 2.9 2.8 Petrochemical & Refined Products Services (3.0 ) (3.3 ) (12.4 ) (10.4 ) Offshore Pipelines & Services -- 5.4 -- 46.6 Total $ 92.3 $ 103.1 $ 269.8 $ 302.5 The following table presents our unamortized excess cost amounts by business segment at the dates indicated: September 30, 2016 December 31, 2015 NGL Pipelines & Services $ 24.4 $ 25.3 Crude Oil Pipelines & Services 18.7 19.3 Petrochemical & Refined Products Services 2.2 2.3 Total $ 45.3 $ 46.9 In total, amortization of excess cost amounts was $0.5 million and $0.6 million for the three months ended September 30, 2016 and 2015, respectively. During the nine months ended September 30, 2016 and 2015, amortization of excess cost amounts was $1.6 million and $4.5 million, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Income Statement Data: Revenues $ 328.9 $ 368.2 $ 991.9 $ 1,121.4 Operating income 193.6 225.4 589.0 662.7 Net income 192.0 223.0 585.5 654.1

Intangible Assets and Goodwill

Intangible Assets and Goodwill	9 Months Ended
	Sep. 30, 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: September 30, 2016 December 31, 2015 Gross Value Accumulated Amortization Carrying Value Gross Value Accumulated Amortization Carrying Value NGL Pipelines & Services: Customer relationship intangibles $ 447.4 $ (168.9 ) $ 278.5 $ 447.4 $ (156.9 ) $ 290.5 Contract-based intangibles 283.5 (204.3 ) 79.2 283.0 (193.2 ) 89.8 Segment total 730.9 (373.2 ) 357.7 730.4 (350.1 ) 380.3 Crude Oil Pipelines & Services: Customer relationship intangibles 2,204.4 (74.2 ) 2,130.2 2,204.4 (39.1 ) 2,165.3 Contract-based intangibles 281.0 (109.3 ) 171.7 281.4 (69.2 ) 212.2 Segment total 2,485.4 (183.5 ) 2,301.9 2,485.8 (108.3 ) 2,377.5 Natural Gas Pipelines & Services: Customer relationship intangibles 1,350.3 (384.1 ) 966.2 1,350.3 (366.3 ) 984.0 Contract-based intangibles 464.7 (368.2 ) 96.5 464.7 (361.0 ) 103.7 Segment total 1,815.0 (752.3 ) 1,062.7 1,815.0 (727.3 ) 1,087.7 Petrochemical & Refined Products Services: Customer relationship intangibles 185.5 (42.5 ) 143.0 185.5 (38.3 ) 147.2 Contract-based intangibles 56.3 (14.4 ) 41.9 56.3 (11.8 ) 44.5 Segment total 241.8 (56.9 ) 184.9 241.8 (50.1 ) 191.7 Total intangible assets $ 5,273.1 $ (1,365.9 ) $ 3,907.2 $ 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 7.6 $ 9.7 $ 23.1 $ 24.9 Crude Oil Pipelines & Services 23.2 29.0 75.6 62.3 Natural Gas Pipelines & Services 8.1 10.7 25.0 30.5 Petrochemical & Refined Products Services 2.3 2.3 6.8 7.0 Offshore Pipelines & Services -- -- -- 4.5 Total $ 41.2 $ 51.7 $ 130.5 $ 129.2 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 $ 44.6 $ 176.4 $ 171.8 $ 167.3 $ 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 the carrying amount of goodwill at the dates indicated: 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 September 30, 2016 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2

Debt Obligations

Debt Obligations	9 Months Ended
	Sep. 30, 2016
Debt Obligations [Abstract]
Debt Obligations	The following table presents our consolidated debt obligations (arranged by company and maturity date) at the dates indicated: September 30, 2016 December 31, 2015 EPO senior debt obligations: Commercial Paper Notes, variable-rates $ 2,038.6 $ 1,114.1 Senior Notes AA, 3.20% fixed-rate, due February 2016 -- 750.0 Senior Notes L, 6.30% fixed-rate, due September 2017 800.0 800.0 364-Day Credit Agreement, variable-rate, due September 2017 -- -- 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 RR, 2.85% fixed-rate, due April 2021 575.0 -- Senior Notes CC, 4.05% fixed-rate, due February 2022 650.0 650.0 Senior Notes HH, 3.35% fixed-rate, due March 2023 1,250.0 1,250.0 Senior Notes JJ, 3.90% fixed-rate, due February 2024 850.0 850.0 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 SS, 3.95% fixed-rate, due February 2027 575.0 -- 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 975.0 875.0 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 22,688.6 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 24,163.0 22,738.5 Other, non-principal amounts (203.7 ) (197.7 ) Less current maturities of debt (2,838.1 ) (1,863.9 ) Total long-term debt $ 21,121.2 $ 20,676.9 (1) Fixed rate of 8.375% was paid through August 1, 2016; thereafter, a variable rate is in effect 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 September 30, 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 $ 2,038.6 $ 2,038.6 $ -- $ -- $ -- $ -- $ -- Senior Notes 20,650.0 -- 800.0 1,100.0 1,500.0 1,500.0 15,750.0 Junior Subordinated Notes 1,474.4 -- -- -- -- -- 1,474.4 Total $ 24,163.0 $ 2,038.6 $ 800.0 $ 1,100.0 $ 1,500.0 $ 1,500.0 $ 17,224.4 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. 364-Day Credit Agreement In September 2016, EPO amended its 364-Day Credit Agreement to extend its maturity date to September 2017. There are currently no principal amounts outstanding under this revolving credit agreement. Under the terms of the 364-Day Credit Agreement, EPO may borrow up to $1.5 billion (which may be increased by up to $200 million to $1.7 billion at EPO’s election, provided certain conditions are met) at a variable interest rate for a term of 364 days, subject to the terms and conditions set forth therein. To the extent that principal amounts are outstanding at the maturity date, EPO may elect to have the entire principal balance then outstanding continued as a non-revolving term loan for a period of one additional year, payable in September 2018. The remaining terms of the 364-Day Credit Agreement, as amended, remain materially the same as those reported for the 364-Day Credit Agreement in our 2015 Form 10-K. Letters of Credit At September 30, 2016, EPO had $67.7 million of letters of credit outstanding primarily related to our commodity hedging activities. Lender Financial Covenants We were in compliance with the financial covenants of our consolidated debt agreements at September 30, 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 nine months ended September 30, 2016: Range of Interest Rates Paid Weighted-Average Interest Rate Paid Commercial Paper Notes 0.56% to 1.18% 0.89% Junior Subordinated Notes A 4.46% 4.46% Multi-Year Revolving Credit Facility 1.43% to 1.43% 1.43%

Equity and Distributions

Equity and Distributions	9 Months Ended
	Sep. 30, 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 September 30, 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 76,113,492 -- 76,113,492 Common units issued in connection with DRIP and EUPP 13,334,558 -- 13,334,558 Common units issued in connection with the vesting of phantom unit awards 1,149,450 -- 1,149,450 Common units issued in connection with the vesting of restricted common unit awards 1,214,178 (1,214,178 ) -- Forfeiture of restricted common unit awards -- (41,774 ) (41,774 ) Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (403,229 ) -- (403,229 ) Other 90,707 -- 90,707 Number of units outstanding at September 30, 2016 2,102,091,660 704,568 2,102,796,228 The net cash proceeds we received from the issuance of common units during the nine months ended September 30, 2016 were used to temporarily reduce principal amounts outstanding under EPO’s commercial paper program and revolving credit facilities and for general company purposes. We expect to issue additional equity and debt securities to assist us in meeting our future liquidity requirements, including those related to capital spending. Universal shelf registration statement On May 12, 2016, we filed with the SEC a new universal shelf registration statement (the “2016 Shelf”), which was immediately effective and replaced our prior universal shelf registration statement filed with the SEC in June 2013 (the “2013 Shelf”). The 2016 Shelf allows (and the prior 2013 Shelf allowed) 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. At-the-Market (“ATM”) program On July 11, 2016, we filed an amended registration statement with the SEC covering the issuance of up to $1.89 billion of our common units in amounts, at prices and on terms to be determined by market conditions and other factors at the time of such offerings. Pursuant to the ATM 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. The new registration statement was declared effective on July 14, 2016 and replaced our prior registration statement with respect to the ATM program. During the nine months ended September 30, 2016, we sold 76,113,492 common units under the ATM program for aggregate gross proceeds of $1.87 billion. 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 $1.85 billion during the nine months ended September 30, 2016. During the nine months ended September 30, 2015, we issued 23,258,453 common units under this program for aggregate gross cash proceeds of $767.1 million, resulting in total net cash proceeds of $759.7 million. This includes 3,225,057 common units sold in March 2015 to a privately held affiliate of EPCO, which generated gross proceeds of $100 million. Following the effectiveness of the new ATM registration statement and after taking into account the aggregate sales price of common units sold under the ATM program through September 30, 2016, we have the capacity to issue additional common units under the ATM program up to an aggregate sales price of $1.75 billion. Distribution reinvestment plan On May 12, 2016, we filed with the SEC a new registration statement in connection with our distribution reinvestment plan (“DRIP”), which was immediately effective and amended a prior registration statement filed in March 2010. The new registration statement increased the aggregate number of our common units authorized for issuance under the DRIP from 140,000,000 to 240,000,000. 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 12,946,724 common units under our DRIP during the nine months ended September 30, 2016, which generated net cash proceeds of $306.2 million. During the nine months ended September 30, 2015, we issued 7,965,318 common units under our DRIP, which generated net cash proceeds of $242.8 million. Privately held affiliates of EPCO reinvested $100 million through the DRIP during the nine months ended September 30, 2016 (this amount being a component of the net cash proceeds presented). After taking into account the new registration statement and the number of common units issued under the DRIP through September 30, 2016, we have the capacity to issue an additional 102,121,274 common units under this plan. 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 387,834 common units under our EUPP during the nine months ended September 30, 2016, which generated net cash proceeds of $9.8 million. During the nine months ended September 30, 2015, we issued 285,997 common units under our EUPP, which generated net cash proceeds of $8.9 million. After taking into account the number of common units issued under the EUPP through September 30, 2016, we may issue an additional 6,384,672 common units under this plan. Noncontrolling Interests Noncontrolling interests represent third party equity ownership interests in our consolidated subsidiaries (e.g., joint venture partners in entities in which we have a controlling ownership interest). 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 (52.2 ) (16.3 ) (0.1 ) (68.6 ) Amounts reclassified from accumulated other comprehe nsive loss (income) (48.7 ) 27.8 -- (20.9 ) Total other comprehensive income (loss) (100.9 ) 11.5 (0.1 ) (89.5 ) Balance, September 30, 2016 $ (44.3 ) $ (268.0 ) $ 3.6 $ (308.7 ) 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 112.3 -- 0.4 112.7 Amounts reclassified from accumulated other comprehensive loss (income) (128.1 ) 26.3 -- (101.8 ) Total other comprehensive income (loss) (15.8 ) 26.3 0.4 10.9 Balance, September 30, 2015 $ 54.1 $ (288.5 ) $ 3.7 $ (230.7 ) The following table presents reclassifications out of accumulated other comprehensive income (loss) into net income during the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, Location 2016 2015 2016 2015 Losses (gains) on cash flow hedges: Interest rate derivatives Interest expense $ 9.4 $ 8.9 $ 27.8 $ 26.3 Commodity derivatives Revenue (23.0 ) (46.8 ) (47.6 ) (128.6 ) Commodity derivatives Operating costs and expenses (3.9 ) -- (1.1 ) 0.5 Total $ (17.5 ) $ (37.9 ) $ (20.9 ) $ (101.8 ) For information regarding our interest rate and commodity derivative instruments, see Note 12. 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 2nd Quarter $ 0.3800 7/31/2015 8/7/2015 3rd Quarter $ 0.3850 10/30/2015 11/6/2015 2016: 1st Quarter $ 0.3950 4/29/2016 5/6/2016 2nd Quarter $ 0.4000 7/29/2016 8/5/2016 3rd Quarter $ 0.4050 10/31/2016 11/7/2016 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 reflected the exclusion of 35,380,000 Designated Units. The temporary distribution waiver expired in November 2015; therefore, distributions paid to partners during calendar year 2016 are payable on all outstanding common units.

Business Segments

Business Segments	9 Months Ended
	Sep. 30, 2016
Business Segments [Abstract]
Business Segments	Note 9. 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. 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. Our business segments are generally organized and managed according to the types of services rendered (or technologies employed) and products produced and/or sold. Financial information regarding these segments is evaluated regularly by our chief operating decision makers in deciding how to allocate resources and in assessing operating and financial performance. 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 our financial measure of gross operating margin. Gross operating margin is an important performance measure of the core profitability of our operations and forms the basis of our internal financial reporting. 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. Gross operating margin represents GAAP operating income exclusive of (i) depreciation, amortization and accretion expenses, (ii) impairment charges, (iii) gains and losses attributable to asset sales, insurance recoveries and related property damage and (iv) general and administrative costs. Gross operating margin includes (i) equity in the earnings of unconsolidated affiliates and (ii) non-refundable deferred transportation revenues relating to the make-up rights of committed shippers on certain pipeline assets. 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. Gross operating margin by segment is calculated by subtracting segment operating costs and expenses from segment revenues, with both segment totals reflecting the adjustments noted above, as applicable, and before the elimination of intercompany transactions. 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. 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). Substantially all of our plants, pipelines and other fixed assets are located in the U.S. The following table presents our measurement of total segment gross operating margin for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Revenues $ 5,920.4 $ 6,307.9 $ 16,543.5 $ 20,872.9 Subtract operating costs and expenses (5,065.7 ) (5,452.6 ) (14,034.8 ) (18,426.5 ) Add equity in income of unconsolidated affiliates 92.3 103.1 269.8 302.5 Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin 367.1 351.1 1,085.6 1,082.0 Add asset impairment charges not reflected in gross operating margin 6.8 26.8 21.6 139.1 Add net losses or subtract net gains attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin (8.9 ) 12.3 4.8 14.7 Add non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin 1.2 3.4 10.1 39.3 Subtract subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin (5.6 ) (10.9 ) (25.1 ) (45.3 ) Total segment gross operating margin $ 1,307.6 $ 1,341.1 $ 3,875.5 $ 3,978.7 The following table presents a reconciliation of total segment gross operating margin to GAAP operating income and further to income before income taxes for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Total segment gross operating margin $ 1,307.6 $ 1,341.1 $ 3,875.5 $ 3,978.7 Adjustments to reconcile total segment gross operating margin to operating income: Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin (367.1 ) (351.1 ) (1,085.6 ) (1,082.0 ) Subtract asset impairment charges not reflected in gross operating margin (6.8 ) (26.8 ) (21.6 ) (139.1 ) Add net gains or subtract net losses attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin 8.9 (12.3 ) (4.8 ) (14.7 ) Subtract non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin (1.2 ) (3.4 ) (10.1 ) (39.3 ) Add subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin 5.6 10.9 25.1 45.3 Subtract general and administrative costs not reflected in gross operating margin (42.0 ) (49.0 ) (121.0 ) (143.2 ) Operating income 905.0 909.4 2,657.5 2,605.7 Other expense, net (257.1 ) (246.2 ) (761.1 ) (736.4 ) Income before income taxes $ 647.9 $ 663.2 $ 1,896.4 $ 1,869.3 Information by business segment, together with reconciliations to our consolidated financial statement totals, is presented in the following table: 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 September 30, 2016 $ 2,414.2 $ 1,712.9 $ 711.3 $ 1,066.3 $ -- $ -- $ 5,904.7 Three months ended September 30, 2015 2,284.6 2,316.4 705.2 980.0 7.8 -- 6,294.0 Nine months ended September 30, 2016 7,328.9 4,641.8 1,792.5 2,735.8 -- -- 16,499.0 Nine months ended September 30, 2015 7,223.2 8,080.4 2,117.5 3,347.6 76.9 -- 20,845.6 Revenues from related parties: Three months ended September 30, 2016 2.7 10.1 2.9 -- -- -- 15.7 Three months ended September 30, 2015 2.2 6.2 4.5 -- 1.0 -- 13.9 Nine months ended September 30, 2016 7.3 29.8 7.4 -- -- -- 44.5 Nine months ended September 30, 2015 6.0 8.6 10.8 -- 1.9 -- 27.3 Intersegment and intrasegment revenues: Three months ended September 30, 2016 4,772.4 2,445.2 201.2 315.4 -- (7,734.2 ) -- Three months ended September 30, 2015 2,461.0 1,142.1 180.2 267.3 0.1 (4,050.7 ) -- Nine months ended September 30, 2016 12,828.0 6,390.3 472.8 865.8 -- (20,556.9 ) -- Nine months ended September 30, 2015 7,685.1 3,958.9 519.7 875.8 0.6 (13,040.1 ) -- Total revenues: Three months ended September 30, 2016 7,189.3 4,168.2 915.4 1,381.7 -- (7,734.2 ) 5,920.4 Three months ended September 30, 2015 4,747.8 3,464.7 889.9 1,247.3 8.9 (4,050.7 ) 6,307.9 Nine months ended September 30, 2016 20,164.2 11,061.9 2,272.7 3,601.6 -- (20,556.9 ) 16,543.5 Nine months ended September 30, 2015 14,914.3 12,047.9 2,648.0 4,223.4 79.4 (13,040.1 ) 20,872.9 Equity in income (loss) of unconsolidated affiliates: Three months ended September 30, 2016 15.9 78.4 1.0 (3.0 ) -- -- 92.3 Three months ended September 30, 2015 18.9 81.2 0.9 (3.3 ) 5.4 -- 103.1 Nine months ended September 30, 2016 45.0 234.3 2.9 (12.4 ) -- -- 269.8 Nine months ended September 30, 2015 43.0 220.5 2.8 (10.4 ) 46.6 -- 302.5 Gross operating margin: Three months ended September 30, 2016 703.5 254.0 178.5 171.6 -- -- 1,307.6 Three months ended September 30, 2015 695.5 254.6 192.4 191.5 7.1 -- 1,341.1 Nine months ended September 30, 2016 2,206.3 633.7 533.6 501.9 -- -- 3,875.5 Nine months ended September 30, 2015 2,041.3 704.2 588.3 547.4 97.5 -- 3,978.7 Property, plant and equipment, net: (see Note 4) At September 30, 2016 14,040.1 4,074.1 8,473.7 3,255.1 -- 3,276.4 33,119.4 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 September 30, 2016 747.5 1,838.7 22.0 79.0 -- -- 2,687.2 At December 31, 2015 718.7 1,813.4 22.5 73.9 -- -- 2,628.5 Intangible assets, net: At September 30, 2016 357.7 2,301.9 1,062.7 184.9 -- -- 3,907.2 At December 31, 2015 380.3 2,377.5 1,087.7 191.7 -- -- 4,037.2 Goodwill: At September 30, 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 September 30, 2016 17,797.0 10,055.7 9,854.7 4,475.2 -- 3,276.4 45,459.0 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services: Sales of NGLs and related products $ 1,959.0 $ 1,844.9 $ 5,962.9 $ 5,936.2 Midstream services 457.9 441.9 1,373.3 1,293.0 Total 2,416.9 2,286.8 7,336.2 7,229.2 Crude Oil Pipelines & Services: Sales of crude oil 1,538.5 2,147.3 4,141.8 7,689.3 Midstream services 184.5 175.3 529.8 399.7 Total 1,723.0 2,322.6 4,671.6 8,089.0 Natural Gas Pipelines & Services: Sales of natural gas 483.7 455.0 1,104.4 1,361.2 Midstream services 230.5 254.7 695.5 767.1 Total 714.2 709.7 1,799.9 2,128.3 Petrochemical & Refined Products Services: Sales of petrochemicals and refined products 871.3 780.5 2,137.9 2,764.2 Midstream services 195.0 199.5 597.9 583.4 Total 1,066.3 980.0 2,735.8 3,347.6 Offshore Pipelines & Services: Sales of crude oil -- 0.4 -- 3.2 Midstream services -- 8.4 -- 75.6 Total -- 8.8 -- 78.8 Total consolidated revenues $ 5,920.4 $ 6,307.9 $ 16,543.5 $ 20,872.9 Consolidated costs and expenses Operating costs and expenses: Cost of sales $ 4,088.6 $ 4,419.9 $ 11,135.6 $ 15,355.9 Other operating costs and expenses (1) 612.1 642.5 1,787.2 1,834.8 Depreciation, amortization and accretion 367.1 351.1 1,085.6 1,082.0 Asset impairment charges 6.8 26.8 21.6 139.1 Loss due to Pascagoula fire -- -- 7.1 -- Ne t losses (8.9 ) 12.3 (2.3 ) 14.7 General and administrative costs 42.0 49.0 121.0 143.2 Total consolidated costs and expenses $ 5,107.7 $ 5,501.6 $ 14,155.8 $ 18,569.7 (1) Represents the cost of operating our plants, pipelines and other fixed assets excluding: depreciation, amortization and accretion charges; asset impairment charges; losses due to property damage events (e.g., the fire at our Pascagoula Facility (see Note 4)); and net losses (or gains) attributable to asset sales. 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	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 BASIC EARNINGS PER UNIT Net income attributable to limited partners $ 634.6 $ 649.3 $ 1,854.3 $ 1,836.4 Undistributed earnings allocated and cash payments on phantom unit awards (1) (3.2 ) (2.2 ) (9.7 ) (6.6 ) Net income available to common unitholders $ 631.4 $ 647.1 $ 1,844.6 $ 1,829.8 Basic weighted-average number of common units outstanding 2,097.5 1,969.3 2,072.2 1,952.3 Basic earnings per unit $ 0.30 $ 0.33 $ 0.89 $ 0.94 DILUTED EARNINGS PER UNIT Net income attributable to limited partners $ 634.6 $ 649.3 $ 1,854.3 $ 1,836.4 Diluted weighted-average number of units outstanding: Distribution-bearing common units 2,097.5 1,969.3 2,072.2 1,952.3 Designated Units -- 35.4 -- 35.4 Phantom units (1) 8.0 5.7 7.6 5.4 Incremental option units -- 0.1 -- 0.2 Total 2,105.5 2,010.5 2,079.8 1,993.3 Diluted earnings per unit $ 0.30 $ 0.32 $ 0.89 $ 0.92 (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	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Equity-classified awards: Phantom unit awards $ 19.9 $ 20.3 $ 58.6 $ 60.2 Restricted common unit awards 0.8 3.1 3.7 13.1 Profits interest awards 1.5 -- 3.8 -- Liability-classified awards 0.1 -- 0.4 0.2 Total $ 22.3 $ 23.4 $ 66.5 $ 73.5 The fair value of equity-classified awards is amortized into earnings over the requisite service or vesting period. Equity-classified awards are expected to result in the issuance of common units upon vesting. Compensation expense for liability-classified awards is recognized over the requisite service or vesting period based on the fair value of the award remeasured at each reporting date. Liability-classified awards are settled in cash upon vesting. At September 30, 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 authorized for issuance under the 2008 Plan was 35,000,000 at September 30, 2016. This authorized 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 September 30, 2016, a total of 3,255,545 and 18,297,995 additional common units were available for issuance under these plans, respectively. In addition, during the first half of 2016, EPCO formed four 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. (“PubCo I”), EPD PubCo Unit II L.P. (“PubCo II”), EPD PubCo Unit III L.P. (“PubCo III”) and EPD PrivCo Unit I L.P. (“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 September 30, 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) 4,486,910 $ 21.88 Vested (1,728,388 ) $ 33.13 Forfeited (364,506 ) $ 28.71 Phantom unit awards at September 30, 2016 7,820,965 $ 27.23 (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 $98.2 million based on grant date market prices of our common units ranging from $21.86 per unit to $27.39 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cash payments made in connection with DERs $ 3.2 $ 2.2 $ 8.5 $ 5.6 Total intrinsic value of phantom unit awards that vested during period 3.0 2.3 40.1 31.0 For the EPCO group of companies, the unrecognized compensation cost associated with phantom unit awards was $99.7 million at September 30, 2016, of which our share of the cost is currently estimated to be $89.9 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 2.0 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 (1,214,178 ) $ 27.45 Forfeited (41,774 ) $ 28.46 Restricted common units at September 30, 2016 704,568 $ 28.58 (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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cash distributions paid to restricted common unitholders $ 0.3 $ 0.8 $ 1.4 $ 3.2 Total intrinsic value of restricted common unit awards that vested during period 0.7 1.5 28.0 66.9 For the EPCO group of companies, the unrecognized compensation cost associated with restricted common unit awards was an aggregate $1.9 million at September 30, 2016, of which our share of the cost is currently estimated to be $1.4 million. We expect to recognize our share of the unrecognized compensation cost for these awards by the end of 2017. 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 nine months ended September 30, 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 periods indicated: For the Three Months Ended September 30, 2015 For the Nine Months Ended September 30, 2015 Total intrinsic value of unit option awards exercised during period $ 0.2 $ 19.8 Cash received from EPCO in connection with the exercise of unit option awards 0.2 11.5 Unit option award-related cash reimbursements to EPCO 0.2 19.8 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 PubCo I, (ii) 2,834,198 units to PubCo II and (iii) 1,111,438 units to PrivCo I. On April 6, 2016, EPCO Holdings contributed 105,000 Enterprise common units it owned to PubCo III. In exchange for these contributions, EPCO Holdings was admitted as the Class A limited partner of each Employee Partnership. Also on the applicable 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. The Class B limited partner interests in each Employee Partnership vest as follows: PubCo I, four years from February 22, 2016; PubCo II and PrivCo I, five years from February 22, 2016; and PubCo III, four years from April 6, 2016. 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 PubCo I 2,723,052 units $63.5 million 6.6638% Feb. 2020 $13.2 million $11.2 million PubCo II 2,834,198 units $66.1 million 6.6638% Feb. 2021 $14.8 million $12.9 million PubCo III 105,000 units $2.5 million 6.5381% Apr. 2020 $0.5 million $0.5 million PrivCo I 1,111,438 units $25.9 million 6.6638% Feb. 2021 $5.8 million $1.1 million (1) Represents fair market value of the Enterprise common units contributed to each Employee Partnership at the applicable contribution date. (2) For each period and Employee Partnership, the Class A Preference Return amount equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by the applicable Class A Partner Preferred Return Rate 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 September 30, 2016. We expect to recognize our share of the unrecognized compensation cost for PubCo I, PubCo II, PubCo III and PrivCo I over a weighted-average period of 3.4 years, 4.4 years, 3.5 years and 4.4 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 PubCo I 4.0 years 0.9% to 1.1% 6.2% to 6.7% 29% to 40% PubCo II 5.0 years 1.1% to 1.3% 6.2% to 6.7% 27% to 40% PubCo III 4.0 years 0.9% to 1.0% 6.2% 29% to 40% PrivCo I 5.0 years 1.1% to 1.3% 6.2% to 6.7% 27% to 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	9 Months Ended
	Sep. 30, 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 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 September 30, 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 1.27% Fair value hedge As a result of lower market interest rates in June and July 2016, we entered into eight 30-year forward-starting swaps associated with anticipated future issuances of debt. At September 30, 2016, our portfolio of forward starting swaps was as follows: Hedged Transaction Number and Type of Derivatives Outstanding Notional Amount Expected Settlement Date Average Rate Locked Accounting Treatment Future long-term debt offering 4 forward starting swaps $ 250.0 9/2017 1.91% Cash flow hedge Future long-term debt offering 4 forward starting swaps $ 275.0 5/2018 2.02% Cash flow hedge As a result of market conditions in October 2016, we elected to terminate the forward starting swaps that were scheduled to settle in September 2017, which resulted in cash gains totaling $6.1 million. As cash flow hedges, gains on these derivative instruments will be reflected as a component of accumulated other comprehensive income and be amortized to earnings (as a decrease in interest expense) over the life of the associated future debt obligations beginning in September 2017. 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 and basis swaps. The following table summarizes our portfolio of commodity derivative instruments outstanding at September 30, 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) 24.4 3.3 Cash flow hedge Forecasted sales of NGLs (MMBbls) 12.1 3.5 Cash flow hedge Octane enhancement: Forecasted purchase of NGLs (MMBbls) 1.3 n/a Cash flow hedge Forecasted sales of octane enhancement products (MMBbls) 1.4 n/a Cash flow hedge Natural gas marketing: Forecasted purchases of natural gas for fuel (Bcf) 3.3 0.5 Cash flow hedge Natural gas storage inventory management activities (Bcf) 8.2 n/a Fair value hedge NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products (MMBbls) 78.2 2.3 Cash flow hedge Forecasted sales of NGLs and related hydrocarbon products (MMBbls) 99.0 7.0 Cash flow hedge Refined products marketing: Forecasted purchases of refined products (MMBbls) 0.3 n/a Cash flow hedge Forecasted sales of refined products (MMBbls) 0.4 n/a Cash flow hedge Refined products inventory management activities (MMBbls) 2.1 n/a Fair value hedge Crude oil marketing: Forecasted purchases of crude oil (MMBbls) 7.4 n/a Cash flow hedge Forecasted sales of crude oil (MMBbls) 11.5 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) (3,4) 98.2 20.9 Mark-to-market NGL risk management activities (MMBbls) (4) 7.2 n/a Mark-to-market Crude oil risk management activities (MMBbls) (4) 28.5 0.9 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, June 2017 and March 2020, respectively. (3) Current and long-term volumes include 25.4 Bcf and 1.8 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. (4) Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets. At September 30, 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 derivative instruments and related contracts.  The objective of our natural gas processing hedging program is to hedge an amount of earnings associated with these activities. We achieve this objective by executing sales contracts for a portion of our expected equity NGL production using derivative instruments and related contracts. 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 using derivative instruments and related contracts.  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 derivative instruments and related contracts. Tabular Presentation of Fair Value Amounts, and Gains and Losses on Derivative Instruments and Related Hedged Items The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated: Asset Derivatives Liability Derivatives September 30, 2016 December 31, 2015 September 30, 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 $ 3.0 Current assets $ 3.2 Current liabilities $ -- Current liabilities $ -- Interest rate derivatives Other assets 0.5 Other assets -- Other liabilities 16.3 Other liabilities 3.7 Total interest rate derivatives 3.5 3.2 16.3 3.7 Commodity derivatives Current assets 202.6 Current assets 253.8 Current liabilities 407.1 Current liabilities 137.5 Commodity derivatives Other assets 5.7 Other assets 0.2 Other liabilities 6.0 Other liabilities 1.4 Total commodity derivatives 208.3 254.0 413.1 138.9 Total derivatives designated as hedging instruments $ 211.8 $ 257.2 $ 429.4 $ 142.6 Derivatives not designated as hedging instruments Commodity derivatives Current assets $ 35.8 Current assets $ 1.6 Current liabilities $ 57.1 Current liabilities $ 3.1 Commodity derivatives Other assets 1.6 Other assets -- Other liabilities 5.2 Other liabilities 1.0 Total commodity derivatives $ 37.4 $ 1.6 $ 62.3 $ 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 September 30, 2016: Interest rate derivatives $ 3.5 $ -- $ 3.5 $ (2.1 ) $ -- $ -- $ 1.4 Commodity derivatives 245.7 -- 245.7 (244.1 ) -- 8.9 10.5 As of December 31, 2015: Interest rate derivatives $ 3.2 $ -- $ 3.2 $ (3.2 ) $ -- $ -- $ -- Commodity derivatives 255.6 -- 255.6 (143.0 ) (72.2 ) (40.1 ) 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 September 30, 2016: Interest rate derivatives $ 16.3 $ -- $ 16.3 $ (2.1 ) $ -- $ 14.2 Commodity derivatives 475.4 -- 475.4 (244.1 ) (231.3 ) -- 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ (3.8 ) $ 5.9 $ 3.5 $ 5.1 Commodity derivatives Revenue (0.4 ) 3.6 (82.4 ) 4.0 Total $ (4.2 ) $ 9.5 $ (78.9 ) $ 9.1 Derivatives in Fair Value Hedging Relationships Location Gain (Loss) Recognized in Income on Hedged Item For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ 3.8 $ (5.7 ) $ (3.7 ) $ (5.2 ) Commodity derivatives Revenue 2.1 (2.5 ) 110.9 7.4 Total $ 5.9 $ (8.2 ) $ 107.2 $ 2.2 For the nine months ended September 30, 2016, the net gain of $28.5 million recognized in income from our commodity derivatives designated as fair value hedges includes $0.8 million of net gains attributable to hedge ineffectiveness. The remaining $27.7 million of net gain recognized during the nine months ended September 30, 2016 was primarily related to prompt-to-forward month price differentials that were excluded from the assessment of hedge effectiveness. Net gains or losses due to ineffectiveness and from those amounts excluded from the assessment of hedge effectiveness were immaterial for all other periods presented. The following tables present the effect of our derivative instruments designated as cash flow hedges on our Unaudited Condensed Statements of Consolidated Operations and Unaudited Condensed Statements of Consolidated Comprehensive Income for the periods indicated: Derivatives in Cash Flow Hedging Relationships Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion) For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives $ (6.9 ) $ -- $ (16.3 ) $ -- Commodity derivatives – Revenue (1) 23.8 87.4 (53.4 ) 113.9 Commodity derivatives – Operating costs and expenses (1) (1.1 ) (1.6 ) 1.2 (1.6 ) Total $ 15.8 $ 85.8 $ (68.5 ) $ 112.3 (1) The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate. Derivatives in Cash Flow Hedging Relationships Location Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion) For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ (9.4 ) $ (8.9 ) $ (27.8 ) $ (26.3 ) Commodity derivatives Revenue 23.0 46.8 47.6 128.6 Commodity derivatives Operating costs and expenses 3.9 -- 1.1 (0.5 ) Total $ 17.5 $ 37.9 $ 20.9 $ 101.8 Derivatives in Cash Flow Hedging Relationships Location Gain (Loss) Recognized in Income on Derivative (Ineffective Portion) For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Commodity derivatives Revenue $ -- $ (3.5 ) $ -- $ (3.1 ) Commodity derivatives Operating costs and expenses (0.3 ) -- (0.3 ) -- Total $ (0.3 ) $ (3.5 ) $ (0.3 ) $ (3.1 ) Over the next twelve months, we expect to reclassify $39.5 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 $43.6 million of net losses attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, $44.0 million as a decrease in revenue and $0.4 million as a decrease in operating costs and expenses. The following table presents the effect of our derivative instruments not designated as hedging instruments on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated: Derivatives Not Designated as Hedging Instruments Location Gain (Loss) Recognized in Income on Derivative For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Commodity derivatives Revenue $ 18.3 $ -- $ (28.3 ) $ 3.9 Commodity derivatives Operating costs and expenses -- (0.3 ) -- -- Total $ 18.3 $ (0.3 ) $ (28.3 ) $ 3.9 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. September 30, 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 $ -- $ 3.5 $ -- $ 3.5 Commodity derivatives 82.2 149.1 14.4 245.7 Total $ 82.2 $ 152.6 $ 14.4 $ 249.2 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 273.1 $ 273.1 Interest rate derivatives -- 16.3 -- 16.3 Commodity derivatives 202.8 256.6 16.0 475.4 Total $ 202.8 $ 272.9 $ 289.1 $ 764.8 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 Nine Months Ended September 30, Location 2016 2015 Financial asset (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 Commodity derivative instruments – changes in fair value of cash flow hedges 1.5 (1.5 ) Settlements Revenue (0.1 ) (0.5 ) Transfers out of Level 3 0.1 0.1 Financial asset (liability) balance, net, March 31 (242.3 ) (221.6 ) Total gains (losses) included in: Net income (1) Revenue -- (0.4 ) Net income Other expense, net (23.3 ) (11.5 ) Other comprehensive income Commodity derivative instruments – changes in fair value of cash flow hedges 2.0 (1.0 ) Settlements Revenue (0.1 ) 0.2 Transfers out of Level 3 -- 1.5 Financial asset (liability) balance, net, June 30 (263.7 ) (232.8 ) Total gains (losses) included in: Net income (1) Revenue 0.2 (0.3 ) Net income Other expense, net (6.9 ) (4.3 ) Other comprehensive income Commodity derivative instruments – changes in fair value of cash flow hedges (4.1 ) (15.5 ) Settlements Revenue (0.2 ) 0.3 Transfers out of Level 3 -- 1.1 Financial asset (liability) balance, net, September 30 $ (274.7 ) $ (251.5 ) (1) There were $0.5 million of unrealized gains included in these amounts for the nine months ended September 30, 2016. There were unrealized losses of $1.1 million included in these amounts for the nine months ended September 30, 2015. The following Fair Value Financial Assets Financial Liabilities Valuation Techniques Unobservable Input Range Commodity derivatives – Crude oil $ 1.4 $ 1.3 Discounted cash flow Forward commodity prices $45.44-$48.89/barrel Commodity derivatives – Propane 5.8 6.5 Discounted cash flow Forward commodity prices $0.49-$0.57/gallon Commodity derivatives – Natural gasoline 2.2 2.1 Discounted cash flow Forward commodity prices $1.06-$1.11/gallon Commodity derivatives – Ethane 3.4 2.6 Discounted cash flow Forward commodity prices $0.23-$0.29/gallon Commodity derivatives – Normal butane 1.6 3.5 Discounted cash flow Forward commodity prices $0.62-$0.73/gallon Total $ 14.4 $ 16.0 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 September 30, 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 Long-lived assets (including intangible assets with finite useful lives and property, plant and equipment) are reviewed for impairment (i.e., subject to nonrecurring fair value measurements) when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated fair values. The following table summarizes our non-cash impairment charges by segment during each of the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 3.8 $ 14.6 $ 6.4 $ 20.6 Crude Oil Pipelines & Services -- -- 0.9 25.9 Natural Gas Pipelines & Services 2.0 -- 11.7 21.5 Petrochemical & Refined Products Services 1.0 12.2 3.0 12.6 Offshore Pipelines & Services -- -- -- 58.5 Total $ 6.8 $ 26.8 $ 22.0 $ 139.1 Impairment charges are primarily a component of “Operating costs and expenses” on our Unaudited Condensed Statements of Consolidated Operations. Our non-cash impairment charges for the nine months ended September 30, 2016 include $1.2 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 nine months ended September 30, 2016: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at September 30, 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 $ -- $ -- $ -- $ -- $ 11.3 Long-lived assets held for sale 1.5 -- 1.5 -- 9.5 Total $ 20.8 The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the nine months ended September 30, 2015: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at September 30, 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 $ 0.4 $ -- $ -- $ 0.4 $ 69.9 Long-lived assets held for sale 34.2 -- -- 34.2 14.2 Long-lived assets disposed of by sale (1) -- -- -- -- 55.0 Total $ 139.1 (1) Primarily represents the impairment charge recorded in connection with the sale of our Offshore Business. 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 $22.5 billion and $19.51 billion at September 30, 2016 and December 31, 2015, respectively. The aggregate carrying value of these debt obligations was $20.85 billion and $20.87 billion at September 30, 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	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Revenues – related parties: Unconsolidated affiliates $ 15.7 $ 13.9 $ 44.5 $ 27.3 Costs and expenses – related parties: EPCO and its privately held affiliates $ 242.3 $ 246.0 $ 721.0 $ 703.9 Unconsolidated affiliates 69.2 66.9 199.5 165.3 Total $ 311.5 $ 312.9 $ 920.5 $ 869.2 The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated: September 30, 2016 December 31, 2015 Accounts receivable - related parties: Unconsolidated affiliates $ 1.7 $ 1.2 Accounts payable - related parties: EPCO and its privately held affiliates $ 81.9 $ 75.6 Unconsolidated affiliates 15.8 8.5 Total $ 97.7 $ 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 September 30, 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 32.6% 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 a privately held affiliate at September 30, 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 nine months ended September 30, 2016 and 2015, we paid EPCO and its privately held affiliates cash distributions totaling $793.6 million and $705.9 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Operating costs and expenses $ 212.9 $ 215.3 $ 628.9 $ 612.2 General and administrative expenses 25.9 26.4 79.5 78.8 Total costs and expenses $ 238.8 $ 241.7 $ 708.4 $ 691.0

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 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 September 30, 2016 and December 31, 2015, our accruals for litigation contingencies were $5.6 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 September 30, 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 from the Federal Trade Commission (“FTC”) requesting specified information relating to the Oiltanking acquisition and our operations. On April 13, 2015, we received a Civil Investigative Demand issued by the Attorney General of the State of Texas requesting copies of the same information and any correspondence with the FTC. In a letter dated August 10, 2016 and published by the FTC on August 19, 2016, the FTC announced, “[u]pon further review of this matter, it now appears that no further action is warranted by the Commission at this time. Accordingly, the investigation has been closed.” Contemporaneously, the Attorney General of the State of Texas closed its investigation of the Oiltanking acquisition. PDH Litigation In July 2013, we executed a contract with Foster Wheeler USA Corporation (“Foster Wheeler”) pursuant to which Foster Wheeler was to serve as the general contractor responsible for the engineering, procurement, construction and installation of our propane dehydrogenation (“PDH”) facility. In November 2014, Foster Wheeler was acquired by an affiliate of AMEC plc to form Amec Foster Wheeler plc, and Foster Wheeler is now known as Amec Foster Wheeler USA Corporation (“AFW”). In December 2015, Enterprise and AFW entered into a transition services agreement under which AFW was partially terminated from the PDH project. In December 2015, Enterprise engaged a second contractor, Optimized Process Designs LLC (“OPD”), to complete the construction and installation of the PDH facility. On September 2, 2016, we terminated AFW for cause and filed a lawsuit in the 151st Judicial Civil District Court of Harris County, Texas against AFW and its parent company, Amec Foster Wheeler plc, asserting claims for breach of contract, breach of warranty, fraudulent inducement, string-along fraud, gross negligence, professional negligence, negligent misrepresentation and attorneys’ fees. This case has yet to be set for trial, and we intend to diligently prosecute these claims and seek all direct, consequential, and exemplary damages to which we may be entitled. 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 $27.0 million and $28.8 million during the three months ended September 30, 2016 and 2015, respectively. For the nine months ended September 30, 2016 and 2015, consolidated lease and rental expense was $81.8 million and $76.4 million, respectively. Our operating lease commitments at September 30, 2016 did not differ materially from those reported in our 2015 Form 10-K. Purchase Obligations Our consolidated purchase obligations at September 30, 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 54,807,352 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 deferred tax liabilities. To the extent that the sum of OTA’s deferred tax liabilities exceeds the then current book value of the Liquidity Option liability, we will recognize expense for the difference. The fair value of the Liquidity Option, at any measurement date, represents the present value of estimated federal and state income tax payments that we believe a market participant would incur on the future taxable income of OTA. We expect that OTA’s taxable income would, in turn, be based on an allocation of our partnership’s taxable income to the common units held by OTA and reflect any tax planning we believe could be employed. Our valuation estimate for the Liquidity Option is based on several inputs that are not observable in the market (i.e., Level 3 inputs). For example, the fair value of the Liquidity Option at September 30, 2016 was estimated at $273.1 million and was based on the following Level 3 inputs:  OTA remains in existence (i.e., is not dissolved and its assets sold) between one and 30 years following exercise of the Liquidity Option, depending on the liquidity preference of its owner. An equal probability that OTA will be dissolved was assigned to each year in the 30-year forecast period;  OTA assumes approximately $2.2 billion of associated long-term debt (30-year maturity) immediately after the Liquidity Option is exercised. For purposes of the valuation at September 30, 2016, we used a market rate commensurate with level of debt and tenure of approximately 4.75%. If the assumption of debt is excluded from the valuation model (and all other inputs are the same), the estimated fair value of the Liquidity Option would increase by $211.1 million at September 30, 2016;  Forecasted annual growth rates of Enterprise’s taxable earnings before interest, taxes, depreciation and amortization ranging from 2% to 15%;  OTA’s ownership interest in Enterprise common units is assumed to be diluted over time in connection with Enterprise’s issuance of equity for general company reasons. For purposes of the valuation at September 30, 2016, we used ownership interests ranging from 1.9% to 2.6%;  A forecasted yield on Enterprise common units of 5.8% to 6.6%;  OTA pays an aggregate federal and state income tax rate of 38% on its taxable income; and  A discount rate of 7.5% based on our weighted-average cost of capital at September 30, 2016. Furthermore, our valuation estimate incorporates probability-weighted scenarios reflecting the likelihood that M&B may elect to divest a portion of the Enterprise common units held by OTA prior to exercise of the option. At September 30, 2016, based on these scenarios, we expect that OTA would own approximately 83% of the 54,807,352 Enterprise common units it received in Step 1 when the option period begins in February 2020. For sensitivity purposes, if OTA owned all of the Enterprise common units it received in Step 1 at the time of exercise (and all other inputs remained the same), the estimated fair value of the Liquidity Option liability would increase by $56.7 million at September 30, 2016. Changes in the fair value of the Liquidity Option are recognized in earnings as a component of other income (expense) on our Unaudited Statements of Consolidated Operations. Results for the three and nine months ended September 30, 2015 include $4.3 million and $15.8 million, respectively, of expense for the Liquidity Option. Results for the three and nine months ended September 30, 2016 include $6.9 million and $28.0 million, respectively, of aggregate non-cash expense attributable to accretion and changes in management estimates regarding inputs to the valuation model.

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	9 Months Ended
	Sep. 30, 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 Nine Months Ended September 30, 2016 2015 Decrease (increase) in: Accounts receivable – trade $ (370.4 ) $ 1,042.5 Accounts receivable – related parties (0.2 ) 1.2 Inventories (701.6 ) (143.2 ) Prepaid and other current assets (71.8 ) (32.7 ) Other assets (1.3 ) 2.1 Increase (decrease) in: Accounts payable – trade (36.8 ) (72.7 ) Accounts payable – related parties 13.6 (38.6 ) Accrued product payables 615.1 (1,248.4 ) Accrued interest (149.5 ) (136.7 ) Other current liabilities 201.1 (13.8 ) Other liabilities 12.1 12.4 Net effect of changes in operating accounts $ (489.7 ) $ (627.9 ) We incurred liabilities for construction in progress that had not been paid at September 30, 2016 and December 31, 2015 of $166.5 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. In July 2015, we purchased EFS Midstream from affiliates of Pioneer and Reliance for approximately $2.1 billion, which was payable in two installments. The initial payment of $1.1 billion was paid at closing on July 8, 2015. The second and final installment of $1.0 billion was paid on July 11, 2016 using a combination of cash on hand and proceeds from the issuance of short-term notes under EPO’s commercial paper program. The following table presents our cash proceeds from asset sales and insurance recoveries for the periods indicated: For the Nine Months Ended September 30, 2016 2015 Sale of Offshore Business $ -- $ 1,528.6 Other cash proceeds 43.9 8.7 Total $ 43.9 $ 1,537.3 The following table presents net gains (losses) attributable to asset sales and insurance recoveries for the periods indicated: For the Nine Months Ended September 30, 2016 2015 Sale of Offshore Business $ -- $ (12.6 ) Ne 2.3 (2.1 ) Total $ 2.3 $ (14.7 )

Condensed Consolidating Financi

Condensed Consolidating Financial Information	9 Months Ended
	Sep. 30, 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 September 30, 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 $ 279.2 $ 59.6 $ (4.4 ) $ 334.4 $ -- $ -- $ 334.4 Accounts receivable – trade, net 1,089.9 1,857.4 (3.2 ) 2,944.1 -- -- 2,944.1 Accounts receivable – related parties 125.8 772.6 (895.0 ) 3.4 -- (1.7 ) 1.7 Inventories 1,426.3 339.5 (3.3 ) 1,762.5 -- -- 1,762.5 Derivative assets 193.2 48.2 -- 241.4 -- -- 241.4 Prepaid and other current assets 268.9 199.9 (11.5 ) 457.3 0.2 -- 457.5 Total current assets 3,383.3 3,277.2 (917.4 ) 5,743.1 0.2 (1.7 ) 5,741.6 Property, plant and equipment, net 4,608.0 28,510.0 1.4 33,119.4 -- -- 33,119.4 Investments in unconsolidated affiliates 40,035.9 4,208.7 (41,557.4 ) 2,687.2 22,093.4 (22,093.4 ) 2,687.2 Intangible assets, net 706.6 3,215.0 (14.4 ) 3,907.2 -- -- 3,907.2 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 194.8 41.4 (178.9 ) 57.3 0.5 -- 57.8 Total assets $ 49,388.1 $ 44,538.0 $ (42,666.7 ) $ 51,259.4 $ 22,094.1 $ (22,095.1 ) $ 51,258.4 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 2,838.0 $ 0.1 $ -- $ 2,838.1 $ -- $ -- $ 2,838.1 Accounts payable – trade 197.8 260.2 (4.4 ) 453.6 0.1 -- 453.7 Accounts payable – related parties 886.0 123.1 (911.4 ) 97.7 1.7 (1.7 ) 97.7 Accrued product payables 1,594.4 1,496.0 (2.9 ) 3,087.5 -- -- 3,087.5 Accrued interest 202.3 0.4 -- 202.7 -- -- 202.7 Derivative liabilities 371.7 92.5 -- 464.2 -- -- 464.2 Other current liabilities 85.3 348.7 (10.3 ) 423.7 -- 0.7 424.4 Total current liabilities 6,175.5 2,321.0 (929.0 ) 7,567.5 1.8 (1.0 ) 7,568.3 Long-term debt 21,106.0 15.2 -- 21,121.2 -- -- 21,121.2 Deferred tax liabilities 3.7 45.7 (0.8 ) 48.6 -- 3.0 51.6 Other long-term liabilities 33.8 351.5 (179.8 ) 205.5 273.1 -- 478.6 Commitments and contingencies Equity: Partners’ and other owners’ equity 22,069.1 41,727.7 (41,729.4 ) 22,067.4 21,819.2 (22,067.4 ) 21,819.2 Noncontrolling interests -- 76.9 172.3 249.2 -- (29.7 ) 219.5 Total equity 22,069.1 41,804.6 (41,557.1 ) 22,316.6 21,819.2 (22,097.1 ) 22,038.7 Total liabilities and equity $ 49,388.1 $ 44,538.0 $ (42,666.7 ) $ 51,259.4 $ 22,094.1 $ (22,095.1 ) $ 51,258.4 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 Derivative liabilities 75.1 65.5 -- 140.6 -- -- 140.6 Other current liabilities 103.6 291.6 (7.0 ) 388.2 -- -- 388.2 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 September 30, 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 $ 7,291.8 $ 3,932.4 $ (5,303.8 ) $ 5,920.4 $ -- $ -- $ 5,920.4 Costs and expenses: Operating costs and expenses 7,099.6 3,270.3 (5,304.2 ) 5,065.7 -- -- 5,065.7 General and administrative costs 6.3 35.0 0.2 41.5 0.5 -- 42.0 Total costs and expenses 7,105.9 3,305.3 (5,304.0 ) 5,107.2 0.5 -- 5,107.7 Equity in income of unconsolidated affiliates 701.6 129.3 (738.6 ) 92.3 642.0 (642.0 ) 92.3 Operating income 887.5 756.4 (738.4 ) 905.5 641.5 (642.0 ) 905.0 Other income (expense): Interest expense (248.8 ) (4.2 ) 2.1 (250.9 ) -- -- (250.9 ) Other, net 2.1 0.7 (2.1 ) 0.7 (6.9 ) -- (6.2 ) Total other expense, net (246.7 ) (3.5 ) -- (250.2 ) (6.9 ) -- (257.1 ) Income before income taxes 640.8 752.9 (738.4 ) 655.3 634.6 (642.0 ) 647.9 Provision for income taxes (2.7 ) (1.6 ) -- (4.3 ) -- (0.5 ) (4.8 ) Net income 638.1 751.3 (738.4 ) 651.0 634.6 (642.5 ) 643.1 Net income attributable to noncontrolling interests -- (1.7 ) (8.1 ) (9.8 ) -- 1.3 (8.5 ) Net income attributable to entity $ 638.1 $ 749.6 $ (746.5 ) $ 641.2 $ 634.6 $ (641.2 ) $ 634.6 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended September 30, 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 $ 4,685.2 $ 4,531.1 $ (2,908.4 ) $ 6,307.9 $ -- $ -- $ 6,307.9 Costs and expenses: Operating costs and expenses 4,506.7 3,854.5 (2,908.6 ) 5,452.6 -- -- 5,452.6 General and administrative costs 11.1 38.3 -- 49.4 (0.4 ) -- 49.0 Total costs and expenses 4,517.8 3,892.8 (2,908.6 ) 5,502.0 (0.4 ) -- 5,501.6 Equity in income of unconsolidated affiliates 725.5 116.5 (738.9 ) 103.1 653.2 (653.2 ) 103.1 Operating income 892.9 754.8 (738.7 ) 909.0 653.6 (653.2 ) 909.4 Other income (expense): Interest expense (239.5 ) (4.2 ) -- (243.7 ) -- -- (243.7 ) Other, net 1.7 0.1 -- 1.8 (4.3 ) -- (2.5 ) Total other expense, net (237.8 ) (4.1 ) -- (241.9 ) (4.3 ) -- (246.2 ) Income before income taxes 655.1 750.7 (738.7 ) 667.1 649.3 (653.2 ) 663.2 Provision for income taxes (3.3 ) (2.2 ) -- (5.5 ) -- -- (5.5 ) Net income 651.8 748.5 (738.7 ) 661.6 649.3 (653.2 ) 657.7 Net income attributable to noncontrolling interests -- -- (9.7 ) (9.7 ) -- 1.3 (8.4 ) Net income attributable to entity $ 651.8 $ 748.5 $ (748.4 ) $ 651.9 $ 649.3 $ (651.9 ) $ 649.3 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Nine Months Ended September 30, 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 $ 19,847.9 $ 11,009.3 $ (14,313.7 ) $ 16,543.5 $ -- $ -- $ 16,543.5 Costs and expenses: Operating costs and expenses 19,192.8 9,156.3 (14,314.3 ) 14,034.8 -- -- 14,034.8 General and administrative costs 16.4 102.3 0.2 118.9 2.1 -- 121.0 Total costs and expenses 19,209.2 9,258.6 (14,314.1 ) 14,153.7 2.1 -- 14,155.8 Equity in income of unconsolidated affiliates 1,971.6 389.3 (2,091.1 ) 269.8 1,884.4 (1,884.4 ) 269.8 Operating income 2,610.3 2,140.0 (2,090.7 ) 2,659.6 1,882.3 (1,884.4 ) 2,657.5 Other income (expense): Interest expense (726.4 ) (14.8 ) 5.6 (735.6 ) -- -- (735.6 ) Other, net 6.0 2.1 (5.6 ) 2.5 (28.0 ) -- (25.5 ) Total other expense, net (720.4 ) (12.7 ) -- (733.1 ) (28.0 ) -- (761.1 ) Income before income taxes 1,889.9 2,127.3 (2,090.7 ) 1,926.5 1,854.3 (1,884.4 ) 1,896.4 Provision for income taxes (5.5 ) (6.2 ) -- (11.7 ) -- (1.4 ) (13.1 ) Net income 1,884.4 2,121.1 (2,090.7 ) 1,914.8 1,854.3 (1,885.8 ) 1,883.3 Net income attributable to noncontrolling interests -- (5.3 ) (27.6 ) (32.9 ) -- 3.9 (29.0 ) Net income attributable to entity $ 1,884.4 $ 2,115.8 $ (2,118.3 ) $ 1,881.9 $ 1,854.3 $ (1,881.9 ) $ 1,854.3 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Nine Months Ended September 30, 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 $ 15,301.0 $ 14,751.0 $ (9,179.1 ) $ 20,872.9 $ -- $ -- $ 20,872.9 Costs and expenses: Operating costs and expenses 14,696.2 12,909.8 (9,179.5 ) 18,426.5 -- -- 18,426.5 General and administrative costs 28.9 113.9 -- 142.8 0.4 -- 143.2 Total costs and expenses 14,725.1 13,023.7 (9,179.5 ) 18,569.3 0.4 -- 18,569.7 Equity in income of unconsolidated affiliates 1,996.4 314.5 (2,008.4 ) 302.5 1,852.6 (1,852.6 ) 302.5 Operating income 2,572.3 2,041.8 (2,008.0 ) 2,606.1 1,852.2 (1,852.6 ) 2,605.7 Other income (expense): Interest expense (717.9 ) (7.3 ) 2.0 (723.2 ) -- -- (723.2 ) Other, net 4.0 0.6 (2.0 ) 2.6 (15.8 ) -- (13.2 ) Total other expense, net (713.9 ) (6.7 ) -- (720.6 ) (15.8 ) -- (736.4 ) Income before income taxes 1,858.4 2,035.1 (2,008.0 ) 1,885.5 1,836.4 (1,852.6 ) 1,869.3 Benefit from (provision for) income taxes (8.9 ) 5.4 -- (3.5 ) -- (0.9 ) (4.4 ) Net income 1,849.5 2,040.5 (2,008.0 ) 1,882.0 1,836.4 (1,853.5 ) 1,864.9 Net loss (income) attributable to noncontrolling interests -- 0.8 (32.9 ) (32.1 ) -- 3.6 (28.5 ) Net income attributable to entity $ 1,849.5 $ 2,041.3 $ (2,040.9 ) $ 1,849.9 $ 1,836.4 $ (1,849.9 ) $ 1,836.4 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended September 30, 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 $ 649.9 $ 738.0 $ (738.6 ) $ 649.3 $ 632.9 $ (640.8 ) $ 641.4 Comprehensive loss (income) attributable to noncontrolling interests -- (1.7 ) (8.1 ) (9.8 ) -- 1.3 (8.5 ) Comprehensive income attributable to entity $ 649.9 $ 736.3 $ (746.7 ) $ 639.5 $ 632.9 $ (639.5 ) $ 632.9 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended September 30, 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 $ 676.0 $ 797.3 $ (763.9 ) $ 709.4 $ 697.2 $ (701.0 ) $ 705.6 Comprehensive income attributable to noncontrolling interests -- -- (9.7 ) (9.7 ) -- 1.3 (8.4 ) Comprehensive income attributable to entity $ 676.0 $ 797.3 $ (773.6 ) $ 699.7 $ 697.2 $ (699.7 ) $ 697.2 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Nine Months Ended September 30, 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 $ 1,824.5 $ 2,091.6 $ (2,090.8 ) $ 1,825.3 $ 1,764.8 $ (1,796.3 ) $ 1,793.8 Comp rehensive loss (income) attrib -- (5.3 ) (27.6 ) (32.9 ) -- 3.9 (29.0 ) Comprehensive income attributable to entity $ 1,824.5 $ 2,086.3 $ (2,118.4 ) $ 1,792.4 $ 1,764.8 $ (1,792.4 ) $ 1,764.8 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Nine Months Ended September 30, 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 $ 1,869.9 $ 2,056.1 $ (2,033.2 ) $ 1,892.8 $ 1,847.3 $ (1,864.3 ) $ 1,875.8 Comprehensive loss (income) attributable to noncontrolling interests -- 0.8 (32.9 ) (32.1 ) -- 3.6 (28.5 ) Comprehensive income attributable to entity $ 1,869.9 $ 2,056.9 $ (2,066.1 ) $ 1,860.7 $ 1,847.3 $ (1,860.7 ) $ 1,847.3 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Nine Months Ended September 30, 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 $ 1,884.4 $ 2,121.1 $ (2,090.7 ) $ 1,914.8 $ 1,854.3 $ (1,885.8 ) $ 1,883.3 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 131.9 1,023.7 (0.3 ) 1,155.3 -- -- 1,155.3 Equity in income of unconsolidated affiliates (1,971.6 ) (389.3 ) 2,091.1 (269.8 ) (1,884.4 ) 1,884.4 (269.8 ) Distributions received on earnings from unconsolidated affiliates 733.1 196.9 (648.4 ) 281.6 2,477.3 (2,477.3 ) 281.6 Net effect of changes in operating accounts and other operating activities 1,281.6 (1,742.7 ) 46.1 (415.0 ) 22.9 0.7 (391.4 ) Net cash flows provided by operating activities 2,059.4 1,209.7 (602.2 ) 2,666.9 2,470.1 (2,478.0 ) 2,659.0 Investing activities: Capital expenditures, net of contributions in aid of construction costs (989.6 ) (1,420.2 ) -- (2,409.8 ) -- -- (2,409.8 ) Cash used for business combinations, net of cash received -- (1,000.0 ) -- (1,000.0 ) -- -- (1,000.0 ) Proceeds from asset sales 27.9 16.0 -- 43.9 -- -- 43.9 Other investing activities (2,177.0 ) (84.2 ) 1,931.4 (329.8 ) (2,161.2 ) 2,161.2 (329.8 ) Cash used in investing activities (3,138.7 ) (2,488.4 ) 1,931.4 (3,695.7 ) (2,161.2 ) 2,161.2 (3,695.7 ) Financing activities: Borrowings under debt agreements 50,183.8 41.4 (41.4 ) 50,183.8 -- -- 50,183.8 Repayments of debt (48,776.4 ) (0.1 ) -- (48,776.5 ) -- -- (48,776.5 ) Cash distributions paid to owners (2,477.3 ) (677.5 ) 677.5 (2,477.3 ) (2,448.3 ) 2,477.3 (2,448.3 ) Cash payments made in connection with DERs -- -- -- -- (8.5 ) -- (8.5 ) Cash distributions paid to noncontrolling interests -- (7.3 ) (29.1 ) (36.4 ) -- 0.7 (35.7 ) Cash contributions from noncontrolling interests -- 20.1 -- 20.1 -- -- 20.1 Net cash proceeds from issuance of common units -- -- -- -- 2,170.4 -- 2,170.4 Cash contributions from owners 2,161.2 1,890.0 (1,890.0 ) 2,161.2 -- (2,161.2 ) -- Other financing activities (8.0 ) -- -- (8.0 ) (22.5 ) -- (30.5 ) Cash provided by financing activities 1,083.3 1,266.6 (1,283.0 ) 1,066.9 (308.9 ) 316.8 1,074.8 Net change in cash and cash equivalents 4.0 (12.1 ) 46.2 38.1 -- -- 38.1 Cash and cash equivalents, January 1 -- 69.6 (50.6 ) 19.0 -- -- 19.0 Cash and cash equivalents, September 30 $ 4.0 $ 57.5 $ (4.4 ) $ 57.1 $ -- $ -- $ 57.1 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Nine Months Ended September 30, 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 $ 1,849.5 $ 2,040.5 $ (2,008.0 ) $ 1,882.0 $ 1,836.4 $ (1,853.5 ) $ 1,864.9 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 106.0 1,042.1 (0.4 ) 1,147.7 -- -- 1,147.7 Equity in income of unconsolidated affiliates (1,996.4 ) (314.5 ) 2,008.4 (302.5 ) (1,852.6 ) 1,852.6 (302.5 ) Distributions received on earnings from unconsolidated affiliates 1,705.4 227.1 (1,570.1 ) 362.4 2,241.1 (2,241.1 ) 362.4 Net effect of changes in operating accounts and other operating activities (52.9 ) (450.6 ) 9.3 (494.2 ) 12.0 0.9 (481.3 ) Net cash flows provided by operating activities 1,611.6 2,544.6 (1,560.8 ) 2,595.4 2,236.9 (2,241.1 ) 2,591.2 Investing activities: Capital expenditures, net of contributions in aid of construction costs (725.5 ) (1,893.6 ) -- (2,619.1 ) -- -- (2,619.1 ) Cash used for business combinations, net of cash received (1,058.4 ) 13.3 -- (1,045.1 ) -- -- (1,045.1 ) Proceeds from asset sales 1,532.1 5.2 -- 1,537.3 -- -- 1,537.3 Other investing activities (1,091.2 ) (43.5 ) 953.4 (181.3 ) (1,005.2 ) 1,005.2 (181.3 ) Cash used in investing activities (1,343.0 ) (1,918.6 ) 953.4 (2,308.2 ) (1,005.2 ) 1,005.2 (2,308.2 ) Financing activities: Borrowings under debt agreements 17,113.7 77.9 (77.9 ) 17,113.7 -- -- 17,113.7 Repayments of debt (16,139.2 ) -- -- (16,139.2 ) -- -- (16,139.2 ) Cash distributions paid to owners (2,241.1 ) (1,602.4 ) 1,602.4 (2,241.1 ) (2,185.1 ) 2,241.1 (2,185.1 ) Cash payments made in connection with DERs -- -- -- -- (5.6 ) -- (5.6 ) Cash distributions paid to noncontrolling interests -- (0.8 ) (32.4 ) (33.2 ) -- -- (33.2 ) Cash contributions from noncontrolling interests -- 37.8 (0.4 ) 37.4 -- -- 37.4 Net cash proceeds from issuance of common units -- -- -- -- 1,011.4 -- 1,011.4 Cash contributions from owners 1,005.2 875.1 (875.1 ) 1,005.2 -- (1,005.2 ) -- Other financing activities (23.9 ) -- -- (23.9 ) (52.4 ) -- (76.3 ) Cash used in financing activities (285.3 ) (612.4 ) 616.6 (281.1 ) (1,231.7 ) 1,235.9 (276.9 ) Net change in cash and cash equivalents (16.7 ) 13.6 9.2 6.1 -- -- 6.1 Cash and cash equivalents, January 1 18.7 70.4 (14.7 ) 74.4 -- -- 74.4 Cash and cash equivalents, September 30 $ 2.0 $ 84.0 $ (5.5 ) $ 80.5 $ -- $ -- $ 80.5

General Accounting and Disclo24

General Accounting and Disclosure Matters (Policies)	9 Months Ended
	Sep. 30, 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, 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	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 margin requirements change. At September 30, 2016 and December 31, 2015, our restricted cash amounts were $277.3 million and $15.9 million, respectively. The balance at September 30, 2016 consisted of initial margin requirements of $48.9 million and variation margin requirements of $228.4 million. The initial margin requirements will be returned to us as the related derivative instruments are settled. Our variation margin requirements increased by $248.7 million since December 31, 2015 primarily due to higher forward commodity prices for NGLs and related hydrocarbons during 2016 relative to our short financial derivative positions in these products. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories (Tables)

Inventories (Tables)	9 Months Ended
	Sep. 30, 2016
Inventories [Abstract]
Inventory Amounts by Product Type	Our inventory amounts by product type were as follows at the dates indicated: September 30, 2016 December 31, 2015 NGLs $ 1,202.4 $ 639.9 Petrochemicals and refined products 230.4 148.0 Crude oil 299.3 222.1 Natural gas 30.4 28.1 Total $ 1,762.5 $ 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cost of sales (1) $ 4,088.6 $ 4,419.9 $ 11,135.6 $ 15,355.9 Lower of cost or market adjustments within cost of sales 1.5 2.1 7.6 6.1 (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)	9 Months Ended
	Sep. 30, 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 September 30, 2016 December 31, 2015 Plants, pipelines and facilities (1) 3-45 (5) $ 34,752.7 $ 32,525.0 Underground and other storage facilities (2) 5-40 (6) 3,309.2 3,000.5 Transportation equipment (3) 3-10 162.9 159.9 Marine vessels (4) 15-30 792.0 769.8 Land 264.6 262.7 Construction in progress 3,276.4 3,894.0 Total 42,557.8 40,611.9 Less accumulated depreciation 9,438.4 8,577.2 Property, plant and equipment, net $ 33,119.4 $ 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 (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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Depreciation expense (1) $ 309.4 $ 286.2 $ 903.5 $ 870.1 Capitalized interest (2) 38.9 40.3 127.8 105.6 (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 incurred 4.1 Liabilities settled (2.9 ) Revisions in estimated cash flows 4.0 Accretion expense 2.8 ARO liability balance, September 30, 2016 $ 66.5

Investments in Unconsolidated27

Investments in Unconsolidated Affiliates (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 2016 September 30, 2016 December 31, 2015 NGL Pipelines & Services: Venice Energy Service Company, L.L.C. 13.1% $ 25.0 $ 25.9 K/D/S Promix, L.L.C. 50% 35.2 38.3 Baton Rouge Fractionators LLC 32.2% 17.1 18.5 Skelly-Belvieu Pipeline Company, L.L.C. 50% 40.0 39.8 Texas Express Pipeline LLC 35% 330.1 342.0 Texas Express Gathering LLC 45% 36.1 36.8 Front Range Pipeline LLC 33.3% 168.0 171.2 Delaware Basin Gas Processing LLC 50% 96.0 46.2 Crude Oil Pipelines & Services: Seaway Crude Pipeline Company LLC 50% 1,405.7 1,396.0 Eagle Ford Pipeline LLC 50% 383.6 388.8 Eagle Ford Terminals Corpus Christi LLC 50% 49.4 28.6 Natural Gas Pipelines & Services: White River Hub, LLC 50% 22.0 22.5 Petrochemical & Refined Products Services: Baton Rouge Propylene Concentrator, LLC 30% 4.6 5.4 Centennial Pipeline LLC 50% 62.7 65.6 Other Various 11.7 2.9 Total investments in unconsolidated affiliates $ 2,687.2 $ 2,628.5 The following table presents our equity in income (loss) of unconsolidated affiliates by business segment for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 15.9 $ 18.9 $ 45.0 $ 43.0 Crude Oil Pipelines & Services 78.4 81.2 234.3 220.5 Natural Gas Pipelines & Services 1.0 0.9 2.9 2.8 Petrochemical & Refined Products Services (3.0 ) (3.3 ) (12.4 ) (10.4 ) Offshore Pipelines & Services -- 5.4 -- 46.6 Total $ 92.3 $ 103.1 $ 269.8 $ 302.5 The following table presents our unamortized excess cost amounts by business segment at the dates indicated: September 30, 2016 December 31, 2015 NGL Pipelines & Services $ 24.4 $ 25.3 Crude Oil Pipelines & Services 18.7 19.3 Petrochemical & Refined Products Services 2.2 2.3 Total $ 45.3 $ 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Income Statement Data: Revenues $ 328.9 $ 368.2 $ 991.9 $ 1,121.4 Operating income 193.6 225.4 589.0 662.7 Net income 192.0 223.0 585.5 654.1

Intangible Assets and Goodwill

Intangible Assets and Goodwill (Tables)	9 Months Ended
	Sep. 30, 2016
Intangible Assets and Goodwill [Abstract]
Intangible Assets by Segment	The following table summarizes our intangible assets by business segment at the dates indicated: September 30, 2016 December 31, 2015 Gross Value Accumulated Amortization Carrying Value Gross Value Accumulated Amortization Carrying Value NGL Pipelines & Services: Customer relationship intangibles $ 447.4 $ (168.9 ) $ 278.5 $ 447.4 $ (156.9 ) $ 290.5 Contract-based intangibles 283.5 (204.3 ) 79.2 283.0 (193.2 ) 89.8 Segment total 730.9 (373.2 ) 357.7 730.4 (350.1 ) 380.3 Crude Oil Pipelines & Services: Customer relationship intangibles 2,204.4 (74.2 ) 2,130.2 2,204.4 (39.1 ) 2,165.3 Contract-based intangibles 281.0 (109.3 ) 171.7 281.4 (69.2 ) 212.2 Segment total 2,485.4 (183.5 ) 2,301.9 2,485.8 (108.3 ) 2,377.5 Natural Gas Pipelines & Services: Customer relationship intangibles 1,350.3 (384.1 ) 966.2 1,350.3 (366.3 ) 984.0 Contract-based intangibles 464.7 (368.2 ) 96.5 464.7 (361.0 ) 103.7 Segment total 1,815.0 (752.3 ) 1,062.7 1,815.0 (727.3 ) 1,087.7 Petrochemical & Refined Products Services: Customer relationship intangibles 185.5 (42.5 ) 143.0 185.5 (38.3 ) 147.2 Contract-based intangibles 56.3 (14.4 ) 41.9 56.3 (11.8 ) 44.5 Segment total 241.8 (56.9 ) 184.9 241.8 (50.1 ) 191.7 Total intangible assets $ 5,273.1 $ (1,365.9 ) $ 3,907.2 $ 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 7.6 $ 9.7 $ 23.1 $ 24.9 Crude Oil Pipelines & Services 23.2 29.0 75.6 62.3 Natural Gas Pipelines & Services 8.1 10.7 25.0 30.5 Petrochemical & Refined Products Services 2.3 2.3 6.8 7.0 Offshore Pipelines & Services -- -- -- 4.5 Total $ 41.2 $ 51.7 $ 130.5 $ 129.2
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 $ 44.6 $ 176.4 $ 171.8 $ 167.3 $ 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 the carrying amount of goodwill at the dates indicated: 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 September 30, 2016 $ 2,651.7 $ 1,841.0 $ 296.3 $ 956.2 $ 5,745.2

Debt Obligations (Tables)

Debt Obligations (Tables)	9 Months Ended
	Sep. 30, 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: September 30, 2016 December 31, 2015 EPO senior debt obligations: Commercial Paper Notes, variable-rates $ 2,038.6 $ 1,114.1 Senior Notes AA, 3.20% fixed-rate, due February 2016 -- 750.0 Senior Notes L, 6.30% fixed-rate, due September 2017 800.0 800.0 364-Day Credit Agreement, variable-rate, due September 2017 -- -- 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 RR, 2.85% fixed-rate, due April 2021 575.0 -- Senior Notes CC, 4.05% fixed-rate, due February 2022 650.0 650.0 Senior Notes HH, 3.35% fixed-rate, due March 2023 1,250.0 1,250.0 Senior Notes JJ, 3.90% fixed-rate, due February 2024 850.0 850.0 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 SS, 3.95% fixed-rate, due February 2027 575.0 -- 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 975.0 875.0 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 22,688.6 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 24,163.0 22,738.5 Other, non-principal amounts (203.7 ) (197.7 ) Less current maturities of debt (2,838.1 ) (1,863.9 ) Total long-term debt $ 21,121.2 $ 20,676.9 (1) Fixed rate of 8.375% was paid through August 1, 2016; thereafter, a variable rate is in effect 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 September 30, 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 $ 2,038.6 $ 2,038.6 $ -- $ -- $ -- $ -- $ -- Senior Notes 20,650.0 -- 800.0 1,100.0 1,500.0 1,500.0 15,750.0 Junior Subordinated Notes 1,474.4 -- -- -- -- -- 1,474.4 Total $ 24,163.0 $ 2,038.6 $ 800.0 $ 1,100.0 $ 1,500.0 $ 1,500.0 $ 17,224.4
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 nine months ended September 30, 2016: Range of Interest Rates Paid Weighted-Average Interest Rate Paid Commercial Paper Notes 0.56% to 1.18% 0.89% Junior Subordinated Notes A 4.46% 4.46% Multi-Year Revolving Credit Facility 1.43% to 1.43% 1.43%

Equity and Distributions (Table

Equity and Distributions (Tables)	9 Months Ended
	Sep. 30, 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 September 30, 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 76,113,492 -- 76,113,492 Common units issued in connection with DRIP and EUPP 13,334,558 -- 13,334,558 Common units issued in connection with the vesting of phantom unit awards 1,149,450 -- 1,149,450 Common units issued in connection with the vesting of restricted common unit awards 1,214,178 (1,214,178 ) -- Forfeiture of restricted common unit awards -- (41,774 ) (41,774 ) Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (403,229 ) -- (403,229 ) Other 90,707 -- 90,707 Number of units outstanding at September 30, 2016 2,102,091,660 704,568 2,102,796,228
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 (52.2 ) (16.3 ) (0.1 ) (68.6 ) Amounts reclassified from accumulated other comprehe nsive loss (income) (48.7 ) 27.8 -- (20.9 ) Total other comprehensive income (loss) (100.9 ) 11.5 (0.1 ) (89.5 ) Balance, September 30, 2016 $ (44.3 ) $ (268.0 ) $ 3.6 $ (308.7 ) 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 112.3 -- 0.4 112.7 Amounts reclassified from accumulated other comprehensive loss (income) (128.1 ) 26.3 -- (101.8 ) Total other comprehensive income (loss) (15.8 ) 26.3 0.4 10.9 Balance, September 30, 2015 $ 54.1 $ (288.5 ) $ 3.7 $ (230.7 )
Reclassification out of Accumulated Other Comprehensive Income (Loss)	The following table presents reclassifications out of accumulated other comprehensive income (loss) into net income during the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, Location 2016 2015 2016 2015 Losses (gains) on cash flow hedges: Interest rate derivatives Interest expense $ 9.4 $ 8.9 $ 27.8 $ 26.3 Commodity derivatives Revenue (23.0 ) (46.8 ) (47.6 ) (128.6 ) Commodity derivatives Operating costs and expenses (3.9 ) -- (1.1 ) 0.5 Total $ (17.5 ) $ (37.9 ) $ (20.9 ) $ (101.8 )
Declared Quarterly Cash Distribution Rates	The following table presents Enterprise’s declared quarterly cash distribution rates per common unit with respect to the quarter indicated: Distribution Per Common Unit Record Date Payment Date 2015: 1st Quarter $ 0.3750 4/30/2015 5/7/2015 2nd Quarter $ 0.3800 7/31/2015 8/7/2015 3rd Quarter $ 0.3850 10/30/2015 11/6/2015 2016: 1st Quarter $ 0.3950 4/29/2016 5/6/2016 2nd Quarter $ 0.4000 7/29/2016 8/5/2016 3rd Quarter $ 0.4050 10/31/2016 11/7/2016

Business Segments (Tables)

Business Segments (Tables)	9 Months Ended
	Sep. 30, 2016
Business Segments [Abstract]
Measurement of Total Segment Gross Operating Margin	The following table presents our measurement of total segment gross operating margin for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Revenues $ 5,920.4 $ 6,307.9 $ 16,543.5 $ 20,872.9 Subtract operating costs and expenses (5,065.7 ) (5,452.6 ) (14,034.8 ) (18,426.5 ) Add equity in income of unconsolidated affiliates 92.3 103.1 269.8 302.5 Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin 367.1 351.1 1,085.6 1,082.0 Add asset impairment charges not reflected in gross operating margin 6.8 26.8 21.6 139.1 Add net losses or subtract net gains attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin (8.9 ) 12.3 4.8 14.7 Add non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin 1.2 3.4 10.1 39.3 Subtract subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin (5.6 ) (10.9 ) (25.1 ) (45.3 ) Total segment gross operating margin $ 1,307.6 $ 1,341.1 $ 3,875.5 $ 3,978.7
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 GAAP operating income and further to income before income taxes for the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Total segment gross operating margin $ 1,307.6 $ 1,341.1 $ 3,875.5 $ 3,978.7 Adjustments to reconcile total segment gross operating margin to operating income: Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin (367.1 ) (351.1 ) (1,085.6 ) (1,082.0 ) Subtract asset impairment charges not reflected in gross operating margin (6.8 ) (26.8 ) (21.6 ) (139.1 ) Add net gains or subtract net losses attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin 8.9 (12.3 ) (4.8 ) (14.7 ) Subtract non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin (1.2 ) (3.4 ) (10.1 ) (39.3 ) Add subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin 5.6 10.9 25.1 45.3 Subtract general and administrative costs not reflected in gross operating margin (42.0 ) (49.0 ) (121.0 ) (143.2 ) Operating income 905.0 909.4 2,657.5 2,605.7 Other expense, net (257.1 ) (246.2 ) (761.1 ) (736.4 ) Income before income taxes $ 647.9 $ 663.2 $ 1,896.4 $ 1,869.3
Information by Business Segments	Information by business segment, together with reconciliations to our consolidated financial statement totals, is presented in the following table: 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 September 30, 2016 $ 2,414.2 $ 1,712.9 $ 711.3 $ 1,066.3 $ -- $ -- $ 5,904.7 Three months ended September 30, 2015 2,284.6 2,316.4 705.2 980.0 7.8 -- 6,294.0 Nine months ended September 30, 2016 7,328.9 4,641.8 1,792.5 2,735.8 -- -- 16,499.0 Nine months ended September 30, 2015 7,223.2 8,080.4 2,117.5 3,347.6 76.9 -- 20,845.6 Revenues from related parties: Three months ended September 30, 2016 2.7 10.1 2.9 -- -- -- 15.7 Three months ended September 30, 2015 2.2 6.2 4.5 -- 1.0 -- 13.9 Nine months ended September 30, 2016 7.3 29.8 7.4 -- -- -- 44.5 Nine months ended September 30, 2015 6.0 8.6 10.8 -- 1.9 -- 27.3 Intersegment and intrasegment revenues: Three months ended September 30, 2016 4,772.4 2,445.2 201.2 315.4 -- (7,734.2 ) -- Three months ended September 30, 2015 2,461.0 1,142.1 180.2 267.3 0.1 (4,050.7 ) -- Nine months ended September 30, 2016 12,828.0 6,390.3 472.8 865.8 -- (20,556.9 ) -- Nine months ended September 30, 2015 7,685.1 3,958.9 519.7 875.8 0.6 (13,040.1 ) -- Total revenues: Three months ended September 30, 2016 7,189.3 4,168.2 915.4 1,381.7 -- (7,734.2 ) 5,920.4 Three months ended September 30, 2015 4,747.8 3,464.7 889.9 1,247.3 8.9 (4,050.7 ) 6,307.9 Nine months ended September 30, 2016 20,164.2 11,061.9 2,272.7 3,601.6 -- (20,556.9 ) 16,543.5 Nine months ended September 30, 2015 14,914.3 12,047.9 2,648.0 4,223.4 79.4 (13,040.1 ) 20,872.9 Equity in income (loss) of unconsolidated affiliates: Three months ended September 30, 2016 15.9 78.4 1.0 (3.0 ) -- -- 92.3 Three months ended September 30, 2015 18.9 81.2 0.9 (3.3 ) 5.4 -- 103.1 Nine months ended September 30, 2016 45.0 234.3 2.9 (12.4 ) -- -- 269.8 Nine months ended September 30, 2015 43.0 220.5 2.8 (10.4 ) 46.6 -- 302.5 Gross operating margin: Three months ended September 30, 2016 703.5 254.0 178.5 171.6 -- -- 1,307.6 Three months ended September 30, 2015 695.5 254.6 192.4 191.5 7.1 -- 1,341.1 Nine months ended September 30, 2016 2,206.3 633.7 533.6 501.9 -- -- 3,875.5 Nine months ended September 30, 2015 2,041.3 704.2 588.3 547.4 97.5 -- 3,978.7 Property, plant and equipment, net: (see Note 4) At September 30, 2016 14,040.1 4,074.1 8,473.7 3,255.1 -- 3,276.4 33,119.4 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 September 30, 2016 747.5 1,838.7 22.0 79.0 -- -- 2,687.2 At December 31, 2015 718.7 1,813.4 22.5 73.9 -- -- 2,628.5 Intangible assets, net: At September 30, 2016 357.7 2,301.9 1,062.7 184.9 -- -- 3,907.2 At December 31, 2015 380.3 2,377.5 1,087.7 191.7 -- -- 4,037.2 Goodwill: At September 30, 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 September 30, 2016 17,797.0 10,055.7 9,854.7 4,475.2 -- 3,276.4 45,459.0 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services: Sales of NGLs and related products $ 1,959.0 $ 1,844.9 $ 5,962.9 $ 5,936.2 Midstream services 457.9 441.9 1,373.3 1,293.0 Total 2,416.9 2,286.8 7,336.2 7,229.2 Crude Oil Pipelines & Services: Sales of crude oil 1,538.5 2,147.3 4,141.8 7,689.3 Midstream services 184.5 175.3 529.8 399.7 Total 1,723.0 2,322.6 4,671.6 8,089.0 Natural Gas Pipelines & Services: Sales of natural gas 483.7 455.0 1,104.4 1,361.2 Midstream services 230.5 254.7 695.5 767.1 Total 714.2 709.7 1,799.9 2,128.3 Petrochemical & Refined Products Services: Sales of petrochemicals and refined products 871.3 780.5 2,137.9 2,764.2 Midstream services 195.0 199.5 597.9 583.4 Total 1,066.3 980.0 2,735.8 3,347.6 Offshore Pipelines & Services: Sales of crude oil -- 0.4 -- 3.2 Midstream services -- 8.4 -- 75.6 Total -- 8.8 -- 78.8 Total consolidated revenues $ 5,920.4 $ 6,307.9 $ 16,543.5 $ 20,872.9 Consolidated costs and expenses Operating costs and expenses: Cost of sales $ 4,088.6 $ 4,419.9 $ 11,135.6 $ 15,355.9 Other operating costs and expenses (1) 612.1 642.5 1,787.2 1,834.8 Depreciation, amortization and accretion 367.1 351.1 1,085.6 1,082.0 Asset impairment charges 6.8 26.8 21.6 139.1 Loss due to Pascagoula fire -- -- 7.1 -- Ne t losses (8.9 ) 12.3 (2.3 ) 14.7 General and administrative costs 42.0 49.0 121.0 143.2 Total consolidated costs and expenses $ 5,107.7 $ 5,501.6 $ 14,155.8 $ 18,569.7 (1) Represents the cost of operating our plants, pipelines and other fixed assets excluding: depreciation, amortization and accretion charges; asset impairment charges; losses due to property damage events (e.g., the fire at our Pascagoula Facility (see Note 4)); and net losses (or gains) attributable to asset sales.

Earnings Per Unit (Tables)

Earnings Per Unit (Tables)	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 BASIC EARNINGS PER UNIT Net income attributable to limited partners $ 634.6 $ 649.3 $ 1,854.3 $ 1,836.4 Undistributed earnings allocated and cash payments on phantom unit awards (1) (3.2 ) (2.2 ) (9.7 ) (6.6 ) Net income available to common unitholders $ 631.4 $ 647.1 $ 1,844.6 $ 1,829.8 Basic weighted-average number of common units outstanding 2,097.5 1,969.3 2,072.2 1,952.3 Basic earnings per unit $ 0.30 $ 0.33 $ 0.89 $ 0.94 DILUTED EARNINGS PER UNIT Net income attributable to limited partners $ 634.6 $ 649.3 $ 1,854.3 $ 1,836.4 Diluted weighted-average number of units outstanding: Distribution-bearing common units 2,097.5 1,969.3 2,072.2 1,952.3 Designated Units -- 35.4 -- 35.4 Phantom units (1) 8.0 5.7 7.6 5.4 Incremental option units -- 0.1 -- 0.2 Total 2,105.5 2,010.5 2,079.8 1,993.3 Diluted earnings per unit $ 0.30 $ 0.32 $ 0.89 $ 0.92 (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)	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Equity-classified awards: Phantom unit awards $ 19.9 $ 20.3 $ 58.6 $ 60.2 Restricted common unit awards 0.8 3.1 3.7 13.1 Profits interest awards 1.5 -- 3.8 -- Liability-classified awards 0.1 -- 0.4 0.2 Total $ 22.3 $ 23.4 $ 66.5 $ 73.5
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) 4,486,910 $ 21.88 Vested (1,728,388 ) $ 33.13 Forfeited (364,506 ) $ 28.71 Phantom unit awards at September 30, 2016 7,820,965 $ 27.23 (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 $98.2 million based on grant date market prices of our common units ranging from $21.86 per unit to $27.39 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 PubCo I 2,723,052 units $63.5 million 6.6638% Feb. 2020 $13.2 million $11.2 million PubCo II 2,834,198 units $66.1 million 6.6638% Feb. 2021 $14.8 million $12.9 million PubCo III 105,000 units $2.5 million 6.5381% Apr. 2020 $0.5 million $0.5 million PrivCo I 1,111,438 units $25.9 million 6.6638% Feb. 2021 $5.8 million $1.1 million (1) Represents fair market value of the Enterprise common units contributed to each Employee Partnership at the applicable contribution date. (2) For each period and Employee Partnership, the Class A Preference Return amount equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by the applicable Class A Partner Preferred Return Rate 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 September 30, 2016. We expect to recognize our share of the unrecognized compensation cost for PubCo I, PubCo II, PubCo III and PrivCo I over a weighted-average period of 3.4 years, 4.4 years, 3.5 years and 4.4 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 PubCo I 4.0 years 0.9% to 1.1% 6.2% to 6.7% 29% to 40% PubCo II 5.0 years 1.1% to 1.3% 6.2% to 6.7% 27% to 40% PubCo III 4.0 years 0.9% to 1.0% 6.2% 29% to 40% PrivCo I 5.0 years 1.1% to 1.3% 6.2% to 6.7% 27% to 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cash payments made in connection with DERs $ 3.2 $ 2.2 $ 8.5 $ 5.6 Total intrinsic value of phantom unit awards that vested during period 3.0 2.3 40.1 31.0
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 (1,214,178 ) $ 27.45 Forfeited (41,774 ) $ 28.46 Restricted common units at September 30, 2016 704,568 $ 28.58 (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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Cash distributions paid to restricted common unitholders $ 0.3 $ 0.8 $ 1.4 $ 3.2 Total intrinsic value of restricted common unit awards that vested during period 0.7 1.5 28.0 66.9
Supplemental Information Regarding Unit Option Awards	The following table presents supplemental information regarding unit option awards during the periods indicated: For the Three Months Ended September 30, 2015 For the Nine Months Ended September 30, 2015 Total intrinsic value of unit option awards exercised during period $ 0.2 $ 19.8 Cash received from EPCO in connection with the exercise of unit option awards 0.2 11.5 Unit option award-related cash reimbursements to EPCO 0.2 19.8

Derivative Instruments, Hedgi34

Derivative Instruments, Hedging Activities and Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2016
Derivative Instruments, Hedging Activities and Fair Value Measurements [Abstract]
Hedging Instruments Under the FASB's Derivative and Hedging Guidance	The following table summarizes our portfolio of interest rate swaps at September 30, 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 1.27% Fair value hedge As a result of lower market interest rates in June and July 2016, we entered into eight 30-year forward-starting swaps associated with anticipated future issuances of debt. At September 30, 2016, our portfolio of forward starting swaps was as follows: Hedged Transaction Number and Type of Derivatives Outstanding Notional Amount Expected Settlement Date Average Rate Locked Accounting Treatment Future long-term debt offering 4 forward starting swaps $ 250.0 9/2017 1.91% Cash flow hedge Future long-term debt offering 4 forward starting swaps $ 275.0 5/2018 2.02% Cash flow 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 and basis swaps. The following table summarizes our portfolio of commodity derivative instruments outstanding at September 30, 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) 24.4 3.3 Cash flow hedge Forecasted sales of NGLs (MMBbls) 12.1 3.5 Cash flow hedge Octane enhancement: Forecasted purchase of NGLs (MMBbls) 1.3 n/a Cash flow hedge Forecasted sales of octane enhancement products (MMBbls) 1.4 n/a Cash flow hedge Natural gas marketing: Forecasted purchases of natural gas for fuel (Bcf) 3.3 0.5 Cash flow hedge Natural gas storage inventory management activities (Bcf) 8.2 n/a Fair value hedge NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products (MMBbls) 78.2 2.3 Cash flow hedge Forecasted sales of NGLs and related hydrocarbon products (MMBbls) 99.0 7.0 Cash flow hedge Refined products marketing: Forecasted purchases of refined products (MMBbls) 0.3 n/a Cash flow hedge Forecasted sales of refined products (MMBbls) 0.4 n/a Cash flow hedge Refined products inventory management activities (MMBbls) 2.1 n/a Fair value hedge Crude oil marketing: Forecasted purchases of crude oil (MMBbls) 7.4 n/a Cash flow hedge Forecasted sales of crude oil (MMBbls) 11.5 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) (3,4) 98.2 20.9 Mark-to-market NGL risk management activities (MMBbls) (4) 7.2 n/a Mark-to-market Crude oil risk management activities (MMBbls) (4) 28.5 0.9 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, June 2017 and March 2020, respectively. (3) Current and long-term volumes include 25.4 Bcf and 1.8 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. (4) Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.
Derivative Assets and Liabilities Balance Sheet	The following table provides a balance sheet overview of our derivative assets and liabilities at the dates indicated: Asset Derivatives Liability Derivatives September 30, 2016 December 31, 2015 September 30, 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 $ 3.0 Current assets $ 3.2 Current liabilities $ -- Current liabilities $ -- Interest rate derivatives Other assets 0.5 Other assets -- Other liabilities 16.3 Other liabilities 3.7 Total interest rate derivatives 3.5 3.2 16.3 3.7 Commodity derivatives Current assets 202.6 Current assets 253.8 Current liabilities 407.1 Current liabilities 137.5 Commodity derivatives Other assets 5.7 Other assets 0.2 Other liabilities 6.0 Other liabilities 1.4 Total commodity derivatives 208.3 254.0 413.1 138.9 Total derivatives designated as hedging instruments $ 211.8 $ 257.2 $ 429.4 $ 142.6 Derivatives not designated as hedging instruments Commodity derivatives Current assets $ 35.8 Current assets $ 1.6 Current liabilities $ 57.1 Current liabilities $ 3.1 Commodity derivatives Other assets 1.6 Other assets -- Other liabilities 5.2 Other liabilities 1.0 Total commodity derivatives $ 37.4 $ 1.6 $ 62.3 $ 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 September 30, 2016: Interest rate derivatives $ 3.5 $ -- $ 3.5 $ (2.1 ) $ -- $ -- $ 1.4 Commodity derivatives 245.7 -- 245.7 (244.1 ) -- 8.9 10.5 As of December 31, 2015: Interest rate derivatives $ 3.2 $ -- $ 3.2 $ (3.2 ) $ -- $ -- $ -- Commodity derivatives 255.6 -- 255.6 (143.0 ) (72.2 ) (40.1 ) 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 September 30, 2016: Interest rate derivatives $ 16.3 $ -- $ 16.3 $ (2.1 ) $ -- $ 14.2 Commodity derivatives 475.4 -- 475.4 (244.1 ) (231.3 ) -- 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ (3.8 ) $ 5.9 $ 3.5 $ 5.1 Commodity derivatives Revenue (0.4 ) 3.6 (82.4 ) 4.0 Total $ (4.2 ) $ 9.5 $ (78.9 ) $ 9.1 Derivatives in Fair Value Hedging Relationships Location Gain (Loss) Recognized in Income on Hedged Item For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ 3.8 $ (5.7 ) $ (3.7 ) $ (5.2 ) Commodity derivatives Revenue 2.1 (2.5 ) 110.9 7.4 Total $ 5.9 $ (8.2 ) $ 107.2 $ 2.2
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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives $ (6.9 ) $ -- $ (16.3 ) $ -- Commodity derivatives – Revenue (1) 23.8 87.4 (53.4 ) 113.9 Commodity derivatives – Operating costs and expenses (1) (1.1 ) (1.6 ) 1.2 (1.6 ) Total $ 15.8 $ 85.8 $ (68.5 ) $ 112.3 (1) The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.
Gain/(Loss) Reclassified from Accumulated Other Comprehensive Income/(Loss) to Income (Effective Portion)	Derivatives in Cash Flow Hedging Relationships Location Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion) For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Interest rate derivatives Interest expense $ (9.4 ) $ (8.9 ) $ (27.8 ) $ (26.3 ) Commodity derivatives Revenue 23.0 46.8 47.6 128.6 Commodity derivatives Operating costs and expenses 3.9 -- 1.1 (0.5 ) Total $ 17.5 $ 37.9 $ 20.9 $ 101.8
Gain/(Loss) Recognized in Income on Derivative (Ineffective Portion)	Derivatives in Cash Flow Hedging Relationships Location Gain (Loss) Recognized in Income on Derivative (Ineffective Portion) For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Commodity derivatives Revenue $ -- $ (3.5 ) $ -- $ (3.1 ) Commodity derivatives Operating costs and expenses (0.3 ) -- (0.3 ) -- Total $ (0.3 ) $ (3.5 ) $ (0.3 ) $ (3.1 )
Gain/(Loss) Recognized in Income on Derivative	The following table presents the effect of our derivative instruments not designated as hedging instruments on our Unaudited Condensed Statements of Consolidated Operations for the periods indicated: Derivatives Not Designated as Hedging Instruments Location Gain (Loss) Recognized in Income on Derivative For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Commodity derivatives Revenue $ 18.3 $ -- $ (28.3 ) $ 3.9 Commodity derivatives Operating costs and expenses -- (0.3 ) -- -- Total $ 18.3 $ (0.3 ) $ (28.3 ) $ 3.9
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. September 30, 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 $ -- $ 3.5 $ -- $ 3.5 Commodity derivatives 82.2 149.1 14.4 245.7 Total $ 82.2 $ 152.6 $ 14.4 $ 249.2 Financial liabilities: Liquidity Option Agreement $ -- $ -- $ 273.1 $ 273.1 Interest rate derivatives -- 16.3 -- 16.3 Commodity derivatives 202.8 256.6 16.0 475.4 Total $ 202.8 $ 272.9 $ 289.1 $ 764.8 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 Nine Months Ended September 30, Location 2016 2015 Financial asset (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 Commodity derivative instruments – changes in fair value of cash flow hedges 1.5 (1.5 ) Settlements Revenue (0.1 ) (0.5 ) Transfers out of Level 3 0.1 0.1 Financial asset (liability) balance, net, March 31 (242.3 ) (221.6 ) Total gains (losses) included in: Net income (1) Revenue -- (0.4 ) Net income Other expense, net (23.3 ) (11.5 ) Other comprehensive income Commodity derivative instruments – changes in fair value of cash flow hedges 2.0 (1.0 ) Settlements Revenue (0.1 ) 0.2 Transfers out of Level 3 -- 1.5 Financial asset (liability) balance, net, June 30 (263.7 ) (232.8 ) Total gains (losses) included in: Net income (1) Revenue 0.2 (0.3 ) Net income Other expense, net (6.9 ) (4.3 ) Other comprehensive income Commodity derivative instruments – changes in fair value of cash flow hedges (4.1 ) (15.5 ) Settlements Revenue (0.2 ) 0.3 Transfers out of Level 3 -- 1.1 Financial asset (liability) balance, net, September 30 $ (274.7 ) $ (251.5 ) (1) There were $0.5 million of unrealized gains included in these amounts for the nine months ended September 30, 2016. There were unrealized losses of $1.1 million included in these amounts for the nine months ended September 30, 2015.
Fair Value Measurements, Valuation Techniques	The following Fair Value Financial Assets Financial Liabilities Valuation Techniques Unobservable Input Range Commodity derivatives – Crude oil $ 1.4 $ 1.3 Discounted cash flow Forward commodity prices $45.44-$48.89/barrel Commodity derivatives – Propane 5.8 6.5 Discounted cash flow Forward commodity prices $0.49-$0.57/gallon Commodity derivatives – Natural gasoline 2.2 2.1 Discounted cash flow Forward commodity prices $1.06-$1.11/gallon Commodity derivatives – Ethane 3.4 2.6 Discounted cash flow Forward commodity prices $0.23-$0.29/gallon Commodity derivatives – Normal butane 1.6 3.5 Discounted cash flow Forward commodity prices $0.62-$0.73/gallon Total $ 14.4 $ 16.0
Noncash Impairment Charges by Segment	Long-lived assets (including intangible assets with finite useful lives and property, plant and equipment) are reviewed for impairment (i.e., subject to nonrecurring fair value measurements) when events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Long-lived assets with carrying values that are not expected to be recovered through future cash flows are written-down to their estimated fair values. The following table summarizes our non-cash impairment charges by segment during each of the periods indicated: For the Three Months Ended September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 NGL Pipelines & Services $ 3.8 $ 14.6 $ 6.4 $ 20.6 Crude Oil Pipelines & Services -- -- 0.9 25.9 Natural Gas Pipelines & Services 2.0 -- 11.7 21.5 Petrochemical & Refined Products Services 1.0 12.2 3.0 12.6 Offshore Pipelines & Services -- -- -- 58.5 Total $ 6.8 $ 26.8 $ 22.0 $ 139.1
Nonrecurring Fair Value Measurements	Our non-cash impairment charges for the nine months ended September 30, 2016 include $1.2 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 nine months ended September 30, 2016: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at September 30, 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 $ -- $ -- $ -- $ -- $ 11.3 Long-lived assets held for sale 1.5 -- 1.5 -- 9.5 Total $ 20.8 The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the nine months ended September 30, 2015: Fair Value Measurements at the End of the Reporting Period Using Carrying Value at September 30, 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 $ 0.4 $ -- $ -- $ 0.4 $ 69.9 Long-lived assets held for sale 34.2 -- -- 34.2 14.2 Long-lived assets disposed of by sale (1) -- -- -- -- 55.0 Total $ 139.1 (1) Primarily represents the impairment charge recorded in connection with the sale of our Offshore Business.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Revenues – related parties: Unconsolidated affiliates $ 15.7 $ 13.9 $ 44.5 $ 27.3 Costs and expenses – related parties: EPCO and its privately held affiliates $ 242.3 $ 246.0 $ 721.0 $ 703.9 Unconsolidated affiliates 69.2 66.9 199.5 165.3 Total $ 311.5 $ 312.9 $ 920.5 $ 869.2 The following table summarizes our related party accounts receivable and accounts payable balances at the dates indicated: September 30, 2016 December 31, 2015 Accounts receivable - related parties: Unconsolidated affiliates $ 1.7 $ 1.2 Accounts payable - related parties: EPCO and its privately held affiliates $ 81.9 $ 75.6 Unconsolidated affiliates 15.8 8.5 Total $ 97.7 $ 84.1 At September 30, 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 32.6% 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 September 30, For the Nine Months Ended September 30, 2016 2015 2016 2015 Operating costs and expenses $ 212.9 $ 215.3 $ 628.9 $ 612.2 General and administrative expenses 25.9 26.4 79.5 78.8 Total costs and expenses $ 238.8 $ 241.7 $ 708.4 $ 691.0

Supplemental Cash Flow Inform36

Supplemental Cash Flow Information (Tables)	9 Months Ended
	Sep. 30, 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 Nine Months Ended September 30, 2016 2015 Decrease (increase) in: Accounts receivable – trade $ (370.4 ) $ 1,042.5 Accounts receivable – related parties (0.2 ) 1.2 Inventories (701.6 ) (143.2 ) Prepaid and other current assets (71.8 ) (32.7 ) Other assets (1.3 ) 2.1 Increase (decrease) in: Accounts payable – trade (36.8 ) (72.7 ) Accounts payable – related parties 13.6 (38.6 ) Accrued product payables 615.1 (1,248.4 ) Accrued interest (149.5 ) (136.7 ) Other current liabilities 201.1 (13.8 ) Other liabilities 12.1 12.4 Net effect of changes in operating accounts $ (489.7 ) $ (627.9 )
Schedule of Significant Acquisitions and Disposals	The following table presents our cash proceeds from asset sales and insurance recoveries for the periods indicated: For the Nine Months Ended September 30, 2016 2015 Sale of Offshore Business $ -- $ 1,528.6 Other cash proceeds 43.9 8.7 Total $ 43.9 $ 1,537.3 The following table presents net gains (losses) attributable to asset sales and insurance recoveries for the periods indicated: For the Nine Months Ended September 30, 2016 2015 Sale of Offshore Business $ -- $ (12.6 ) Ne 2.3 (2.1 ) Total $ 2.3 $ (14.7 )

Condensed Consolidating Finan37

Condensed Consolidating Financial Information (Tables)	9 Months Ended
	Sep. 30, 2016
Condensed Consolidating Financial Information [Abstract]
Condensed Consolidating Balance Sheet	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Balance Sheet September 30, 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 $ 279.2 $ 59.6 $ (4.4 ) $ 334.4 $ -- $ -- $ 334.4 Accounts receivable – trade, net 1,089.9 1,857.4 (3.2 ) 2,944.1 -- -- 2,944.1 Accounts receivable – related parties 125.8 772.6 (895.0 ) 3.4 -- (1.7 ) 1.7 Inventories 1,426.3 339.5 (3.3 ) 1,762.5 -- -- 1,762.5 Derivative assets 193.2 48.2 -- 241.4 -- -- 241.4 Prepaid and other current assets 268.9 199.9 (11.5 ) 457.3 0.2 -- 457.5 Total current assets 3,383.3 3,277.2 (917.4 ) 5,743.1 0.2 (1.7 ) 5,741.6 Property, plant and equipment, net 4,608.0 28,510.0 1.4 33,119.4 -- -- 33,119.4 Investments in unconsolidated affiliates 40,035.9 4,208.7 (41,557.4 ) 2,687.2 22,093.4 (22,093.4 ) 2,687.2 Intangible assets, net 706.6 3,215.0 (14.4 ) 3,907.2 -- -- 3,907.2 Goodwill 459.5 5,285.7 -- 5,745.2 -- -- 5,745.2 Other assets 194.8 41.4 (178.9 ) 57.3 0.5 -- 57.8 Total assets $ 49,388.1 $ 44,538.0 $ (42,666.7 ) $ 51,259.4 $ 22,094.1 $ (22,095.1 ) $ 51,258.4 LIABILITIES AND EQUITY Current liabilities: Current maturities of debt $ 2,838.0 $ 0.1 $ -- $ 2,838.1 $ -- $ -- $ 2,838.1 Accounts payable – trade 197.8 260.2 (4.4 ) 453.6 0.1 -- 453.7 Accounts payable – related parties 886.0 123.1 (911.4 ) 97.7 1.7 (1.7 ) 97.7 Accrued product payables 1,594.4 1,496.0 (2.9 ) 3,087.5 -- -- 3,087.5 Accrued interest 202.3 0.4 -- 202.7 -- -- 202.7 Derivative liabilities 371.7 92.5 -- 464.2 -- -- 464.2 Other current liabilities 85.3 348.7 (10.3 ) 423.7 -- 0.7 424.4 Total current liabilities 6,175.5 2,321.0 (929.0 ) 7,567.5 1.8 (1.0 ) 7,568.3 Long-term debt 21,106.0 15.2 -- 21,121.2 -- -- 21,121.2 Deferred tax liabilities 3.7 45.7 (0.8 ) 48.6 -- 3.0 51.6 Other long-term liabilities 33.8 351.5 (179.8 ) 205.5 273.1 -- 478.6 Commitments and contingencies Equity: Partners’ and other owners’ equity 22,069.1 41,727.7 (41,729.4 ) 22,067.4 21,819.2 (22,067.4 ) 21,819.2 Noncontrolling interests -- 76.9 172.3 249.2 -- (29.7 ) 219.5 Total equity 22,069.1 41,804.6 (41,557.1 ) 22,316.6 21,819.2 (22,097.1 ) 22,038.7 Total liabilities and equity $ 49,388.1 $ 44,538.0 $ (42,666.7 ) $ 51,259.4 $ 22,094.1 $ (22,095.1 ) $ 51,258.4 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 Derivative liabilities 75.1 65.5 -- 140.6 -- -- 140.6 Other current liabilities 103.6 291.6 (7.0 ) 388.2 -- -- 388.2 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 September 30, 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 $ 7,291.8 $ 3,932.4 $ (5,303.8 ) $ 5,920.4 $ -- $ -- $ 5,920.4 Costs and expenses: Operating costs and expenses 7,099.6 3,270.3 (5,304.2 ) 5,065.7 -- -- 5,065.7 General and administrative costs 6.3 35.0 0.2 41.5 0.5 -- 42.0 Total costs and expenses 7,105.9 3,305.3 (5,304.0 ) 5,107.2 0.5 -- 5,107.7 Equity in income of unconsolidated affiliates 701.6 129.3 (738.6 ) 92.3 642.0 (642.0 ) 92.3 Operating income 887.5 756.4 (738.4 ) 905.5 641.5 (642.0 ) 905.0 Other income (expense): Interest expense (248.8 ) (4.2 ) 2.1 (250.9 ) -- -- (250.9 ) Other, net 2.1 0.7 (2.1 ) 0.7 (6.9 ) -- (6.2 ) Total other expense, net (246.7 ) (3.5 ) -- (250.2 ) (6.9 ) -- (257.1 ) Income before income taxes 640.8 752.9 (738.4 ) 655.3 634.6 (642.0 ) 647.9 Provision for income taxes (2.7 ) (1.6 ) -- (4.3 ) -- (0.5 ) (4.8 ) Net income 638.1 751.3 (738.4 ) 651.0 634.6 (642.5 ) 643.1 Net income attributable to noncontrolling interests -- (1.7 ) (8.1 ) (9.8 ) -- 1.3 (8.5 ) Net income attributable to entity $ 638.1 $ 749.6 $ (746.5 ) $ 641.2 $ 634.6 $ (641.2 ) $ 634.6 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Three Months Ended September 30, 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 $ 4,685.2 $ 4,531.1 $ (2,908.4 ) $ 6,307.9 $ -- $ -- $ 6,307.9 Costs and expenses: Operating costs and expenses 4,506.7 3,854.5 (2,908.6 ) 5,452.6 -- -- 5,452.6 General and administrative costs 11.1 38.3 -- 49.4 (0.4 ) -- 49.0 Total costs and expenses 4,517.8 3,892.8 (2,908.6 ) 5,502.0 (0.4 ) -- 5,501.6 Equity in income of unconsolidated affiliates 725.5 116.5 (738.9 ) 103.1 653.2 (653.2 ) 103.1 Operating income 892.9 754.8 (738.7 ) 909.0 653.6 (653.2 ) 909.4 Other income (expense): Interest expense (239.5 ) (4.2 ) -- (243.7 ) -- -- (243.7 ) Other, net 1.7 0.1 -- 1.8 (4.3 ) -- (2.5 ) Total other expense, net (237.8 ) (4.1 ) -- (241.9 ) (4.3 ) -- (246.2 ) Income before income taxes 655.1 750.7 (738.7 ) 667.1 649.3 (653.2 ) 663.2 Provision for income taxes (3.3 ) (2.2 ) -- (5.5 ) -- -- (5.5 ) Net income 651.8 748.5 (738.7 ) 661.6 649.3 (653.2 ) 657.7 Net income attributable to noncontrolling interests -- -- (9.7 ) (9.7 ) -- 1.3 (8.4 ) Net income attributable to entity $ 651.8 $ 748.5 $ (748.4 ) $ 651.9 $ 649.3 $ (651.9 ) $ 649.3 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Nine Months Ended September 30, 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 $ 19,847.9 $ 11,009.3 $ (14,313.7 ) $ 16,543.5 $ -- $ -- $ 16,543.5 Costs and expenses: Operating costs and expenses 19,192.8 9,156.3 (14,314.3 ) 14,034.8 -- -- 14,034.8 General and administrative costs 16.4 102.3 0.2 118.9 2.1 -- 121.0 Total costs and expenses 19,209.2 9,258.6 (14,314.1 ) 14,153.7 2.1 -- 14,155.8 Equity in income of unconsolidated affiliates 1,971.6 389.3 (2,091.1 ) 269.8 1,884.4 (1,884.4 ) 269.8 Operating income 2,610.3 2,140.0 (2,090.7 ) 2,659.6 1,882.3 (1,884.4 ) 2,657.5 Other income (expense): Interest expense (726.4 ) (14.8 ) 5.6 (735.6 ) -- -- (735.6 ) Other, net 6.0 2.1 (5.6 ) 2.5 (28.0 ) -- (25.5 ) Total other expense, net (720.4 ) (12.7 ) -- (733.1 ) (28.0 ) -- (761.1 ) Income before income taxes 1,889.9 2,127.3 (2,090.7 ) 1,926.5 1,854.3 (1,884.4 ) 1,896.4 Provision for income taxes (5.5 ) (6.2 ) -- (11.7 ) -- (1.4 ) (13.1 ) Net income 1,884.4 2,121.1 (2,090.7 ) 1,914.8 1,854.3 (1,885.8 ) 1,883.3 Net income attributable to noncontrolling interests -- (5.3 ) (27.6 ) (32.9 ) -- 3.9 (29.0 ) Net income attributable to entity $ 1,884.4 $ 2,115.8 $ (2,118.3 ) $ 1,881.9 $ 1,854.3 $ (1,881.9 ) $ 1,854.3 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Operations For the Nine Months Ended September 30, 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 $ 15,301.0 $ 14,751.0 $ (9,179.1 ) $ 20,872.9 $ -- $ -- $ 20,872.9 Costs and expenses: Operating costs and expenses 14,696.2 12,909.8 (9,179.5 ) 18,426.5 -- -- 18,426.5 General and administrative costs 28.9 113.9 -- 142.8 0.4 -- 143.2 Total costs and expenses 14,725.1 13,023.7 (9,179.5 ) 18,569.3 0.4 -- 18,569.7 Equity in income of unconsolidated affiliates 1,996.4 314.5 (2,008.4 ) 302.5 1,852.6 (1,852.6 ) 302.5 Operating income 2,572.3 2,041.8 (2,008.0 ) 2,606.1 1,852.2 (1,852.6 ) 2,605.7 Other income (expense): Interest expense (717.9 ) (7.3 ) 2.0 (723.2 ) -- -- (723.2 ) Other, net 4.0 0.6 (2.0 ) 2.6 (15.8 ) -- (13.2 ) Total other expense, net (713.9 ) (6.7 ) -- (720.6 ) (15.8 ) -- (736.4 ) Income before income taxes 1,858.4 2,035.1 (2,008.0 ) 1,885.5 1,836.4 (1,852.6 ) 1,869.3 Benefit from (provision for) income taxes (8.9 ) 5.4 -- (3.5 ) -- (0.9 ) (4.4 ) Net income 1,849.5 2,040.5 (2,008.0 ) 1,882.0 1,836.4 (1,853.5 ) 1,864.9 Net loss (income) attributable to noncontrolling interests -- 0.8 (32.9 ) (32.1 ) -- 3.6 (28.5 ) Net income attributable to entity $ 1,849.5 $ 2,041.3 $ (2,040.9 ) $ 1,849.9 $ 1,836.4 $ (1,849.9 ) $ 1,836.4
Condensed Consolidating Statement of Comprehensive Income	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended September 30, 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 $ 649.9 $ 738.0 $ (738.6 ) $ 649.3 $ 632.9 $ (640.8 ) $ 641.4 Comprehensive loss (income) attributable to noncontrolling interests -- (1.7 ) (8.1 ) (9.8 ) -- 1.3 (8.5 ) Comprehensive income attributable to entity $ 649.9 $ 736.3 $ (746.7 ) $ 639.5 $ 632.9 $ (639.5 ) $ 632.9 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Three Months Ended September 30, 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 $ 676.0 $ 797.3 $ (763.9 ) $ 709.4 $ 697.2 $ (701.0 ) $ 705.6 Comprehensive income attributable to noncontrolling interests -- -- (9.7 ) (9.7 ) -- 1.3 (8.4 ) Comprehensive income attributable to entity $ 676.0 $ 797.3 $ (773.6 ) $ 699.7 $ 697.2 $ (699.7 ) $ 697.2 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Nine Months Ended September 30, 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 $ 1,824.5 $ 2,091.6 $ (2,090.8 ) $ 1,825.3 $ 1,764.8 $ (1,796.3 ) $ 1,793.8 Comp rehensive loss (income) attrib -- (5.3 ) (27.6 ) (32.9 ) -- 3.9 (29.0 ) Comprehensive income attributable to entity $ 1,824.5 $ 2,086.3 $ (2,118.4 ) $ 1,792.4 $ 1,764.8 $ (1,792.4 ) $ 1,764.8 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Comprehensive Income For the Nine Months Ended September 30, 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 $ 1,869.9 $ 2,056.1 $ (2,033.2 ) $ 1,892.8 $ 1,847.3 $ (1,864.3 ) $ 1,875.8 Comprehensive loss (income) attributable to noncontrolling interests -- 0.8 (32.9 ) (32.1 ) -- 3.6 (28.5 ) Comprehensive income attributable to entity $ 1,869.9 $ 2,056.9 $ (2,066.1 ) $ 1,860.7 $ 1,847.3 $ (1,860.7 ) $ 1,847.3
Condensed Consolidating Statement of Cash Flows	Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Nine Months Ended September 30, 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 $ 1,884.4 $ 2,121.1 $ (2,090.7 ) $ 1,914.8 $ 1,854.3 $ (1,885.8 ) $ 1,883.3 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 131.9 1,023.7 (0.3 ) 1,155.3 -- -- 1,155.3 Equity in income of unconsolidated affiliates (1,971.6 ) (389.3 ) 2,091.1 (269.8 ) (1,884.4 ) 1,884.4 (269.8 ) Distributions received on earnings from unconsolidated affiliates 733.1 196.9 (648.4 ) 281.6 2,477.3 (2,477.3 ) 281.6 Net effect of changes in operating accounts and other operating activities 1,281.6 (1,742.7 ) 46.1 (415.0 ) 22.9 0.7 (391.4 ) Net cash flows provided by operating activities 2,059.4 1,209.7 (602.2 ) 2,666.9 2,470.1 (2,478.0 ) 2,659.0 Investing activities: Capital expenditures, net of contributions in aid of construction costs (989.6 ) (1,420.2 ) -- (2,409.8 ) -- -- (2,409.8 ) Cash used for business combinations, net of cash received -- (1,000.0 ) -- (1,000.0 ) -- -- (1,000.0 ) Proceeds from asset sales 27.9 16.0 -- 43.9 -- -- 43.9 Other investing activities (2,177.0 ) (84.2 ) 1,931.4 (329.8 ) (2,161.2 ) 2,161.2 (329.8 ) Cash used in investing activities (3,138.7 ) (2,488.4 ) 1,931.4 (3,695.7 ) (2,161.2 ) 2,161.2 (3,695.7 ) Financing activities: Borrowings under debt agreements 50,183.8 41.4 (41.4 ) 50,183.8 -- -- 50,183.8 Repayments of debt (48,776.4 ) (0.1 ) -- (48,776.5 ) -- -- (48,776.5 ) Cash distributions paid to owners (2,477.3 ) (677.5 ) 677.5 (2,477.3 ) (2,448.3 ) 2,477.3 (2,448.3 ) Cash payments made in connection with DERs -- -- -- -- (8.5 ) -- (8.5 ) Cash distributions paid to noncontrolling interests -- (7.3 ) (29.1 ) (36.4 ) -- 0.7 (35.7 ) Cash contributions from noncontrolling interests -- 20.1 -- 20.1 -- -- 20.1 Net cash proceeds from issuance of common units -- -- -- -- 2,170.4 -- 2,170.4 Cash contributions from owners 2,161.2 1,890.0 (1,890.0 ) 2,161.2 -- (2,161.2 ) -- Other financing activities (8.0 ) -- -- (8.0 ) (22.5 ) -- (30.5 ) Cash provided by financing activities 1,083.3 1,266.6 (1,283.0 ) 1,066.9 (308.9 ) 316.8 1,074.8 Net change in cash and cash equivalents 4.0 (12.1 ) 46.2 38.1 -- -- 38.1 Cash and cash equivalents, January 1 -- 69.6 (50.6 ) 19.0 -- -- 19.0 Cash and cash equivalents, September 30 $ 4.0 $ 57.5 $ (4.4 ) $ 57.1 $ -- $ -- $ 57.1 Enterprise Products Partners L.P. Unaudited Condensed Consolidating Statement of Cash Flows For the Nine Months Ended September 30, 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 $ 1,849.5 $ 2,040.5 $ (2,008.0 ) $ 1,882.0 $ 1,836.4 $ (1,853.5 ) $ 1,864.9 Reconciliation of net income to net cash flows provided by operating activities: Depreciation, amortization and accretion 106.0 1,042.1 (0.4 ) 1,147.7 -- -- 1,147.7 Equity in income of unconsolidated affiliates (1,996.4 ) (314.5 ) 2,008.4 (302.5 ) (1,852.6 ) 1,852.6 (302.5 ) Distributions received on earnings from unconsolidated affiliates 1,705.4 227.1 (1,570.1 ) 362.4 2,241.1 (2,241.1 ) 362.4 Net effect of changes in operating accounts and other operating activities (52.9 ) (450.6 ) 9.3 (494.2 ) 12.0 0.9 (481.3 ) Net cash flows provided by operating activities 1,611.6 2,544.6 (1,560.8 ) 2,595.4 2,236.9 (2,241.1 ) 2,591.2 Investing activities: Capital expenditures, net of contributions in aid of construction costs (725.5 ) (1,893.6 ) -- (2,619.1 ) -- -- (2,619.1 ) Cash used for business combinations, net of cash received (1,058.4 ) 13.3 -- (1,045.1 ) -- -- (1,045.1 ) Proceeds from asset sales 1,532.1 5.2 -- 1,537.3 -- -- 1,537.3 Other investing activities (1,091.2 ) (43.5 ) 953.4 (181.3 ) (1,005.2 ) 1,005.2 (181.3 ) Cash used in investing activities (1,343.0 ) (1,918.6 ) 953.4 (2,308.2 ) (1,005.2 ) 1,005.2 (2,308.2 ) Financing activities: Borrowings under debt agreements 17,113.7 77.9 (77.9 ) 17,113.7 -- -- 17,113.7 Repayments of debt (16,139.2 ) -- -- (16,139.2 ) -- -- (16,139.2 ) Cash distributions paid to owners (2,241.1 ) (1,602.4 ) 1,602.4 (2,241.1 ) (2,185.1 ) 2,241.1 (2,185.1 ) Cash payments made in connection with DERs -- -- -- -- (5.6 ) -- (5.6 ) Cash distributions paid to noncontrolling interests -- (0.8 ) (32.4 ) (33.2 ) -- -- (33.2 ) Cash contributions from noncontrolling interests -- 37.8 (0.4 ) 37.4 -- -- 37.4 Net cash proceeds from issuance of common units -- -- -- -- 1,011.4 -- 1,011.4 Cash contributions from owners 1,005.2 875.1 (875.1 ) 1,005.2 -- (1,005.2 ) -- Other financing activities (23.9 ) -- -- (23.9 ) (52.4 ) -- (76.3 ) Cash used in financing activities (285.3 ) (612.4 ) 616.6 (281.1 ) (1,231.7 ) 1,235.9 (276.9 ) Net change in cash and cash equivalents (16.7 ) 13.6 9.2 6.1 -- -- 6.1 Cash and cash equivalents, January 1 18.7 70.4 (14.7 ) 74.4 -- -- 74.4 Cash and cash equivalents, September 30 $ 2.0 $ 84.0 $ (5.5 ) $ 80.5 $ -- $ -- $ 80.5

Partnership Operations, Organ38

Partnership Operations, Organization and Basis for Presentation (Details) bbl in Millions, $ in Millions	9 Months Ended
	Sep. 30, 2016SegmentmibblBcf	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 | Bcf	14
Number of reportable segments | Segment	5
Limited partners ownership interest	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	32.60%
Oiltanking Partners L.P. [Member]
Business Acquisition [Line Items]
Limited partner interests acquired			65.90%

General Accounting and Disclo39

General Accounting and Disclosure Matters (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 277.3		$ 15.9
Increase in restricted cash	261.4	$ 46.2
Initial Margin Requirement [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	48.9
Variation Margin Requirement [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	228.4
Increase in restricted cash	$ 248.7

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Available-for-Sale Inventory by Product Type [Abstract]
NGLs		$ 1,202.4		$ 1,202.4		$ 639.9
Petrochemicals and refined products		230.4		230.4		148
Crude oil		299.3		299.3		222.1
Natural gas		30.4		30.4		28.1
Total		1,762.5		1,762.5		$ 1,038.1
Inventory held for certain market opportunities		1,000		1,000
Summary of cost of sales and lower of cost or market adjustments [Abstract]
Cost of sales	[1]	4,088.6	$ 4,419.9	11,135.6	$ 15,355.9
Lower of cost or market adjustments within cost of sales		$ 1.5	$ 2.1	$ 7.6	$ 6.1
[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		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		$ 42,557.8		$ 42,557.8		$ 40,611.9
Less accumulated depreciation		9,438.4		9,438.4		8,577.2
Property, plant and equipment, net		33,119.4		33,119.4		32,034.7
Summary of depreciation expense and capitalized interest [Abstract]
Depreciation expense	[1]	309.4	$ 286.2	903.5	$ 870.1
Capitalized interest	[2]	38.9	$ 40.3	127.8	$ 105.6
Asset Retirement Obligations [Roll Forward]
Balance at beginning of period				58.5
Liabilities incurred				4.1
Liabilities settled				(2.9)
Revisions in estimated cash flows				4
Accretion expense				2.8
Balance at end of period		66.5		66.5
Capitalized costs, asset retirement costs		21.1		21.1		17.6
Plants, pipelines and facilities [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[3]	34,752.7		$ 34,752.7		32,525
Plants, pipelines and facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[3],[4]			3 years
Plants, pipelines and facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[3],[4]			45 years
Underground and other storage facilities [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[5]	3,309.2		$ 3,309.2		3,000.5
Underground and other storage facilities [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[5],[6]			5 years
Underground and other storage facilities [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[5],[6]			40 years
Transportation equipment [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[7]	162.9		$ 162.9		159.9
Transportation equipment [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[7]			3 years
Transportation equipment [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[7]			10 years
Marine vessels [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross	[8]	792		$ 792		769.8
Marine vessels [Member] | Minimum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[8]			15 years
Marine vessels [Member] | Maximum [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Estimated useful life	[8]			30 years
Land [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		264.6		$ 264.6		262.7
Construction in progress [Member]
Property, plant and equipment and accumulated depreciation [Abstract]
Property, plant and equipment, gross		$ 3,276.4		$ 3,276.4		$ 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; buildings; office furniture and equipment; 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]	Underground and other storage facilities include underground product storage caverns; above ground storage tanks; water wells and related assets.
[6]	In general, the estimated useful lives of assets within this category are: underground storage facilities, 5-35 years; storage tanks, 10-40 years; and water wells, 5-35 years.
[7]	Transportation equipment includes tractor-trailer tank trucks and other vehicles and similar assets used in our operations.
[8]	Marine vessels include tow boats, barges and related equipment used in our marine transportation business.

Property, Plant and Equipment,

Property, Plant and Equipment, Other (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Property, Plant and Equipment [Line Items]
Capital expenditures			$ 2,443.9	$ 2,630.5
Loss due to Pascagoula fire	$ 0	$ 0	7.1	$ 0
Insurance Matters [Abstract]
Insurance deductible per incident	55		$ 55
Minimum business interruption period			60 days
Pascagoula Natural Gas Processing Facility [Member]
Property, Plant and Equipment [Line Items]
Undivided ownership interest acquired			60.00%
Capital expenditures			$ 35
Loss due to Pascagoula fire			7.1
Fire response expenses	$ 7.1		$ 7.1

Investments in Unconsolidated43

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2,687.2		$ 2,687.2		$ 2,628.5
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	92.3	$ 103.1	269.8	$ 302.5
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	45.3		45.3		46.9
Equity method investment amortization of excess cost	0.5	0.6	1.6	4.5
Income Statement Data:
Revenues	328.9	368.2	991.9	1,121.4
Operating income	193.6	225.4	589	662.7
Net income	192	223	585.5	654.1
NGL Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	15.9	18.9	45	43
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 24.4		$ 24.4		25.3
NGL Pipelines & Services [Member] | Venice Energy Service Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	13.10%		13.10%
Investments in unconsolidated affiliates	$ 25		$ 25		25.9
NGL Pipelines & Services [Member] | K/D/S Promix, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 35.2		$ 35.2		38.3
NGL Pipelines & Services [Member] | Baton Rouge Fractionators LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	32.20%		32.20%
Investments in unconsolidated affiliates	$ 17.1		$ 17.1		18.5
NGL Pipelines & Services [Member] | Skelly-Belvieu Pipeline Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 40		$ 40		39.8
NGL Pipelines & Services [Member] | Texas Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	35.00%		35.00%
Investments in unconsolidated affiliates	$ 330.1		$ 330.1		342
NGL Pipelines & Services [Member] | Texas Express Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	45.00%		45.00%
Investments in unconsolidated affiliates	$ 36.1		$ 36.1		36.8
NGL Pipelines & Services [Member] | Front Range Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	33.30%		33.30%
Investments in unconsolidated affiliates	$ 168		$ 168		171.2
NGL Pipelines & Services [Member] | Delaware Basin Gas Processing LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 96		$ 96		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	78.4	81.2	234.3	220.5
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 18.7		$ 18.7		19.3
Crude Oil Pipelines & Services [Member] | Seaway Crude Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 1,405.7		$ 1,405.7		1,396
Crude Oil Pipelines & Services [Member] | Eagle Ford Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 383.6		$ 383.6		388.8
Crude Oil Pipelines & Services [Member] | Eagle Ford Terminals Corpus Christi LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 49.4		$ 49.4		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	$ 2.9	2.8
Natural Gas Pipelines & Services [Member] | White River Hub, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 22		$ 22		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	(3)	(3.3)	(12.4)	(10.4)
Unamortized excess cost amounts by business segment [Abstract]
Unamortized excess cost amounts	$ 2.2		$ 2.2		2.3
Petrochemical & Refined Products Services [Member] | Baton Rouge Propylene Concentrator, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	30.00%		30.00%
Investments in unconsolidated affiliates	$ 4.6		$ 4.6		5.4
Petrochemical & Refined Products Services [Member] | Centennial Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%		50.00%
Investments in unconsolidated affiliates	$ 62.7		$ 62.7		65.6
Petrochemical & Refined Products Services [Member] | Other Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	11.7		11.7		$ 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	$ 5.4	$ 0	$ 46.6

Intangible Assets and Goodwill,

Intangible Assets and Goodwill, Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Identifiable intangible assets [Abstract]
Gross Value	$ 5,273.1		$ 5,273.1		$ 5,273
Accumulated Amortization	(1,365.9)		(1,365.9)		(1,235.8)
Carrying Value	3,907.2		3,907.2		4,037.2
Amortization Expense	41.2	$ 51.7	130.5	$ 129.2
Forecasted amortization expense [Abstract]
Remainder of 2016	44.6		44.6
2,017	176.4		176.4
2,018	171.8		171.8
2,019	167.3		167.3
2,020	166.4		166.4
NGL Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	730.9		730.9		730.4
Accumulated Amortization	(373.2)		(373.2)		(350.1)
Carrying Value	357.7		357.7		380.3
Amortization Expense	7.6	9.7	23.1	24.9
NGL Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	447.4		447.4		447.4
Accumulated Amortization	(168.9)		(168.9)		(156.9)
Carrying Value	278.5		278.5		290.5
NGL Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	283.5		283.5		283
Accumulated Amortization	(204.3)		(204.3)		(193.2)
Carrying Value	79.2		79.2		89.8
Crude Oil Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,485.4		2,485.4		2,485.8
Accumulated Amortization	(183.5)		(183.5)		(108.3)
Carrying Value	2,301.9		2,301.9		2,377.5
Amortization Expense	23.2	29	75.6	62.3
Crude Oil Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,204.4		2,204.4		2,204.4
Accumulated Amortization	(74.2)		(74.2)		(39.1)
Carrying Value	2,130.2		2,130.2		2,165.3
Crude Oil Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	281		281		281.4
Accumulated Amortization	(109.3)		(109.3)		(69.2)
Carrying Value	171.7		171.7		212.2
Natural Gas Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,815		1,815		1,815
Accumulated Amortization	(752.3)		(752.3)		(727.3)
Carrying Value	1,062.7		1,062.7		1,087.7
Amortization Expense	8.1	10.7	25	30.5
Natural Gas Pipelines & Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,350.3		1,350.3		1,350.3
Accumulated Amortization	(384.1)		(384.1)		(366.3)
Carrying Value	966.2		966.2		984
Natural Gas Pipelines & Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	464.7		464.7		464.7
Accumulated Amortization	(368.2)		(368.2)		(361)
Carrying Value	96.5		96.5		103.7
Petrochemical & Refined Products Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	241.8		241.8		241.8
Accumulated Amortization	(56.9)		(56.9)		(50.1)
Carrying Value	184.9		184.9		191.7
Amortization Expense	2.3	2.3	6.8	7
Petrochemical & Refined Products Services [Member] | Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	185.5		185.5		185.5
Accumulated Amortization	(42.5)		(42.5)		(38.3)
Carrying Value	143		143		147.2
Petrochemical & Refined Products Services [Member] | Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	56.3		56.3		56.3
Accumulated Amortization	(14.4)		(14.4)		(11.8)
Carrying Value	41.9		41.9		$ 44.5
Offshore Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Amortization Expense	$ 0	$ 0	$ 0	$ 4.5

Intangible Assets and Goodwil45

Intangible Assets and Goodwill, Goodwill (Details) $ in Millions	Sep. 30, 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		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Debt Instrument [Line Items]
Principal outstanding		$ 24,163		$ 22,738.5
Other, non-principal amounts		(203.7)		(197.7)
Less current maturities of debt		(2,838.1)		(1,863.9)
Total long-term debt		21,121.2		20,676.9
Debt Obligations Terms [Abstract]
Repayment of debt obligations		48,776.5	$ 16,139.2
Letters of credit outstanding		67.7
Total unamortized debt issuance costs				149.8
Senior Debt Obligations [Member]
Debt Instrument [Line Items]
Principal outstanding		22,688.6		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		$ 2,038.6		1,114.1
Debt Obligations Terms [Abstract]
Interest rate terms		variable
Information regarding variable interest rates paid [Abstract]
Weighted-average interest rate paid		0.89%
Senior Debt Obligations [Member] | Commercial Paper Notes [Member] | Minimum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		0.56%
Senior Debt Obligations [Member] | Commercial Paper Notes [Member] | Maximum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		1.18%
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		3.20%
Maturity date		Feb. 1, 2016
Repayment of debt obligations		$ 750
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		6.30%
Maturity date		Sep. 1, 2017
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, 2017
Maximum borrowing capacity		$ 1,500
Maximum bank commitments increase		200
Total maximum borrowing capacity		1,700
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		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		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		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		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		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		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]
Weighted-average interest rate paid		1.43%
Senior Debt Obligations [Member] | EPO Multi-Year Revolving Credit Facility [Member] | Minimum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		1.43%
Senior Debt Obligations [Member] | EPO Multi-Year Revolving Credit Facility [Member] | Maximum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		1.43%
Senior Debt Obligations [Member] | EPO Senior Notes RR [Member]
Debt Instrument [Line Items]
Principal outstanding		$ 575		0
Debt Obligations Terms [Abstract]
Interest rate terms		fixed
Interest rate, stated percentage		2.85%
Maturity date		Apr. 15, 2021
Aggregate debt principal issued		$ 575
Debt issued as percent of principal amount		99.898%
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		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		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		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		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		3.70%
Maturity date		Feb. 15, 2026
Senior Debt Obligations [Member] | EPO Senior Notes SS [Member]
Debt Instrument [Line Items]
Principal outstanding		$ 575		0
Debt Obligations Terms [Abstract]
Interest rate terms		fixed
Interest rate, stated percentage		3.95%
Maturity date		Feb. 15, 2027
Aggregate debt principal issued		$ 575
Debt issued as percent of principal amount		99.76%
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		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		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		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		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		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		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		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		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		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		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		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		5.10%
Maturity date		Feb. 15, 2045
Senior Debt Obligations [Member] | EPO Senior Notes QQ [Member]
Debt Instrument [Line Items]
Principal outstanding		$ 975		875
Debt Obligations Terms [Abstract]
Interest rate terms		fixed
Interest rate, stated percentage		4.90%
Maturity date		May 15, 2046
Aggregate debt principal issued		$ 100
Debt issued as percent of principal amount		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		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		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		7.55%
Maturity date		Apr. 15, 2038
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		8.375%
Maturity date	[1]	Aug. 31, 2066
Variable annual interest rate thereafter, variable rate basis		3-month LIBOR
Variable interest rate		3.708%
Information regarding variable interest rates paid [Abstract]
Weighted-average interest rate paid		4.46%
Junior Debt Obligations [Member] | EPO Junior Subordinated Notes A [Member] | Minimum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		4.46%
Junior Debt Obligations [Member] | EPO Junior Subordinated Notes A [Member] | Maximum [Member]
Information regarding variable interest rates paid [Abstract]
Variable interest rates paid		4.46%
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		7.00%
Maturity date	[2]	Jun. 1, 2067
Variable annual interest rate thereafter, variable rate basis		3-month LIBOR
Variable interest rate		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		7.034%
Maturity date	[3]	Jan. 15, 2068
Variable annual interest rate thereafter, variable rate basis		3-month LIBOR
Variable interest rate		2.68%
Minimum variable annual interest rate		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% was paid through August 1, 2016; thereafter, a variable rate is in effect 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	Sep. 30, 2016	Dec. 31, 2015
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	$ 2,038.6
2,017	800
2,018	1,100
2,019	1,500
2,020	1,500
After 2,020	17,224.4
Total	24,163	$ 22,738.5
Commercial Paper Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2016	2,038.6
2,017	0
2,018	0
2,019	0
2,020	0
After 2,020	0
Total	2,038.6
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	15,750
Total	20,650
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)	9 Months Ended
	Sep. 30, 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)	76,113,492
Common units issued in connection with DRIP and EUPP (in units)	13,334,558
Common units issued in connection with the vesting of phantom unit awards (in units)	1,149,450
Common units issued in connection with the vesting of restricted common unit awards (in units)	1,214,178
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)	(403,229)
Other (in units)	90,707
Ending Balance (in units)	2,102,091,660
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)	(1,214,178)
Forfeiture of restricted common unit awards (in units)	(41,774)
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)	704,568
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)	76,113,492
Common units issued in connection with DRIP and EUPP (in units)	13,334,558
Common units issued in connection with the vesting of phantom unit awards (in units)	1,149,450
Common units issued in connection with the vesting of restricted common unit awards (in units)	0
Forfeiture of restricted common unit awards (in units)	(41,774)
Acquisition and cancellation of treasury units in connection with the vesting of equity-based awards (in units)	(403,229)
Other (in units)	90,707
Ending Balance (in units)	2,102,796,228

Equity and Distributions, Issua

Equity and Distributions, Issuances of Equity (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Mar. 31, 2016
Net Cash Proceeds from Sale of Common Units [Abstract]
Net cash proceeds from the issuance of common units	$ 2,170.4	$ 1,011.4
At-the-Market Registration [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance	1,890
Remaining units available for issuance	$ 1,750
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	76,113,492	23,258,453
Gross proceeds from the sale of common units	$ 1,870	$ 767.1
Net cash proceeds from the issuance of common units	$ 1,850	$ 759.7
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	3,225,057
Gross proceeds from the sale of common units	$ 100	$ 100
Distribution Reinvestment Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units)	240,000,000		140,000,000
Remaining units available for issuance (in units)	102,121,274
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	12,946,724	7,965,318
Net cash proceeds from the issuance of common units	$ 306.2	$ 242.8
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)	6,384,672
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	387,834	285,997
Net cash proceeds from the issuance of common units	$ 9.8	$ 8.9

Equity and Distributions, Accum

Equity and Distributions, Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			$ (219.2)	$ (241.6)
Other comprehensive income (loss) before reclassifications			(68.6)	112.7
Amounts reclassified from accumulated other comprehensive loss (income)			(20.9)	(101.8)
Total other comprehensive income (loss)	$ (1.7)	$ 47.9	(89.5)	10.9
Ending Balance	(308.7)	(230.7)	(308.7)	(230.7)
Interest expense	250.9	243.7	735.6	723.2
Revenue	(5,920.4)	(6,307.9)	(16,543.5)	(20,872.9)
Operating costs and expenses	5,065.7	5,452.6	14,034.8	18,426.5
Total	(643.1)	(657.7)	(1,883.3)	(1,864.9)
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			(16.3)	0
Amounts reclassified from accumulated other comprehensive loss (income)			27.8	26.3
Total other comprehensive income (loss)			11.5	26.3
Ending Balance	(268)	(288.5)	(268)	(288.5)
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			(52.2)	112.3
Amounts reclassified from accumulated other comprehensive loss (income)			(48.7)	(128.1)
Total other comprehensive income (loss)			(100.9)	(15.8)
Ending Balance	(44.3)	54.1	(44.3)	54.1
Other [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance			3.7	3.3
Other comprehensive income (loss) before reclassifications			(0.1)	0.4
Amounts reclassified from accumulated other comprehensive loss (income)			0	0
Total other comprehensive income (loss)			(0.1)	0.4
Ending Balance	3.6	3.7	3.6	3.7
Reclassification out of Accumulated Other Comprehensive Income [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Total	(17.5)	(37.9)	(20.9)	(101.8)
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	9.4	8.9	27.8	26.3
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	(23)	(46.8)	(47.6)	(128.6)
Operating costs and expenses	$ (3.9)	$ 0	$ (1.1)	$ 0.5

Equity and Distributions, Distr

Equity and Distributions, Distributions (Details) - $ / shares	9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 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] | Second Quarter 2015 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)		$ 0.3800
Record Date		Jul. 31, 2015
Payment Date		Aug. 7, 2015
Cash Distribution [Member] | Third Quarter 2015 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)		$ 0.3850
Record Date		Oct. 30, 2015
Payment Date		Nov. 6, 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
Cash Distribution [Member] | Second Quarter 2016 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)	$ 0.4000
Record Date	Jul. 29, 2016
Payment Date	Aug. 5, 2016
Cash Distribution [Member] | Third Quarter 2016 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)	$ 0.4050
Record Date	Oct. 31, 2016
Payment Date	Nov. 7, 2016

Business Segments (Details)

Business Segments (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2016USD ($)Segment	Sep. 30, 2015USD ($)
Business Segments [Abstract]
Number of reportable segments | Segment			5
Segment Gross Operating Margin [Abstract]
Revenues	$ 5,920.4	$ 6,307.9	$ 16,543.5	$ 20,872.9
Subtract operating costs and expenses	(5,065.7)	(5,452.6)	(14,034.8)	(18,426.5)
Add equity in income of unconsolidated affiliates	92.3	103.1	269.8	302.5
Add depreciation, amortization and accretion expense amounts not reflected in gross operating margin	367.1	351.1	1,085.6	1,082
Add asset impairment charges not reflected in gross operating margin	6.8	26.8	21.6	139.1
Add net losses or subtract net gains attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin	(8.9)	12.3	4.8	14.7
Add non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin	1.2	3.4	10.1	39.3
Subtract subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin	(5.6)	(10.9)	(25.1)	(45.3)
Total segment gross operating margin	1,307.6	1,341.1	3,875.5	3,978.7
Reconciliation of total Segment Gross Operating Margin [Abstract]
Total segment gross operating margin	1,307.6	1,341.1	3,875.5	3,978.7
Adjustments to reconcile total segment gross operating margin to operating income:
Subtract depreciation, amortization and accretion expense amounts not reflected in gross operating margin	(367.1)	(351.1)	(1,085.6)	(1,082)
Subtract asset impairment charges not reflected in gross operating margin	(6.8)	(26.8)	(21.6)	(139.1)
Add net gains or subtract net losses attributable to asset sales, insurance recoveries and related property damage not reflected in gross operating margin	8.9	(12.3)	(4.8)	(14.7)
Subtract non-refundable payments attributable to shipper make-up rights on new pipeline projects reflected in gross operating margin	(1.2)	(3.4)	(10.1)	(39.3)
Add subsequent revenue recognition of deferred revenues attributable to make-up rights not reflected in gross operating margin	5.6	10.9	25.1	45.3
Subtract general and administrative costs not reflected in gross operating margin	(42)	(49)	(121)	(143.2)
Operating income	905	909.4	2,657.5	2,605.7
Other expense, net	(257.1)	(246.2)	(761.1)	(736.4)
Income before income taxes	$ 647.9	$ 663.2	$ 1,896.4	$ 1,869.3

Business Segments, Segment Repo

Business Segments, Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Information by business segment [Abstract]
Revenues from third parties	$ 5,904.7	$ 6,294	$ 16,499	$ 20,845.6
Revenues from related parties	15.7	13.9	44.5	27.3
Intersegment and intrasegment revenues	0	0	0	0
Total revenues	5,920.4	6,307.9	16,543.5	20,872.9
Equity in income (loss) of unconsolidated affiliates	92.3	103.1	269.8	302.5
Gross operating margin	1,307.6	1,341.1	3,875.5	3,978.7
Property, plant and equipment, net	33,119.4		33,119.4		$ 32,034.7
Investments in unconsolidated affiliates	2,687.2		2,687.2		2,628.5
Intangible assets, net	3,907.2		3,907.2		4,037.2
Goodwill	5,745.2		5,745.2		5,745.2
Segment assets	45,459		45,459		44,445.6
NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	2,416.9	2,286.8	7,336.2	7,229.2
Equity in income (loss) of unconsolidated affiliates	15.9	18.9	45	43
Intangible assets, net	357.7		357.7		380.3
Goodwill	2,651.7		2,651.7		2,651.7
Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	1,723	2,322.6	4,671.6	8,089
Equity in income (loss) of unconsolidated affiliates	78.4	81.2	234.3	220.5
Intangible assets, net	2,301.9		2,301.9		2,377.5
Goodwill	1,841		1,841		1,841
Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	714.2	709.7	1,799.9	2,128.3
Equity in income (loss) of unconsolidated affiliates	1	0.9	2.9	2.8
Intangible assets, net	1,062.7		1,062.7		1,087.7
Goodwill	296.3		296.3		296.3
Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Total revenues	1,066.3	980	2,735.8	3,347.6
Equity in income (loss) of unconsolidated affiliates	(3)	(3.3)	(12.4)	(10.4)
Intangible assets, net	184.9		184.9		191.7
Goodwill	956.2		956.2		956.2
Offshore Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	0	8.8	0	78.8
Equity in income (loss) of unconsolidated affiliates	0	5.4	0	46.6
Reportable Business Segments [Member] | NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	2,414.2	2,284.6	7,328.9	7,223.2
Revenues from related parties	2.7	2.2	7.3	6
Intersegment and intrasegment revenues	4,772.4	2,461	12,828	7,685.1
Total revenues	7,189.3	4,747.8	20,164.2	14,914.3
Equity in income (loss) of unconsolidated affiliates	15.9	18.9	45	43
Gross operating margin	703.5	695.5	2,206.3	2,041.3
Property, plant and equipment, net	14,040.1		14,040.1		12,909.7
Investments in unconsolidated affiliates	747.5		747.5		718.7
Intangible assets, net	357.7		357.7		380.3
Goodwill	2,651.7		2,651.7		2,651.7
Segment assets	17,797		17,797		16,660.4
Reportable Business Segments [Member] | Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	1,712.9	2,316.4	4,641.8	8,080.4
Revenues from related parties	10.1	6.2	29.8	8.6
Intersegment and intrasegment revenues	2,445.2	1,142.1	6,390.3	3,958.9
Total revenues	4,168.2	3,464.7	11,061.9	12,047.9
Equity in income (loss) of unconsolidated affiliates	78.4	81.2	234.3	220.5
Gross operating margin	254	254.6	633.7	704.2
Property, plant and equipment, net	4,074.1		4,074.1		3,550.3
Investments in unconsolidated affiliates	1,838.7		1,838.7		1,813.4
Intangible assets, net	2,301.9		2,301.9		2,377.5
Goodwill	1,841		1,841		1,841
Segment assets	10,055.7		10,055.7		9,582.2
Reportable Business Segments [Member] | Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	711.3	705.2	1,792.5	2,117.5
Revenues from related parties	2.9	4.5	7.4	10.8
Intersegment and intrasegment revenues	201.2	180.2	472.8	519.7
Total revenues	915.4	889.9	2,272.7	2,648
Equity in income (loss) of unconsolidated affiliates	1	0.9	2.9	2.8
Gross operating margin	178.5	192.4	533.6	588.3
Property, plant and equipment, net	8,473.7		8,473.7		8,620
Investments in unconsolidated affiliates	22		22		22.5
Intangible assets, net	1,062.7		1,062.7		1,087.7
Goodwill	296.3		296.3		296.3
Segment assets	9,854.7		9,854.7		10,026.5
Reportable Business Segments [Member] | Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Revenues from third parties	1,066.3	980	2,735.8	3,347.6
Revenues from related parties	0	0	0	0
Intersegment and intrasegment revenues	315.4	267.3	865.8	875.8
Total revenues	1,381.7	1,247.3	3,601.6	4,223.4
Equity in income (loss) of unconsolidated affiliates	(3)	(3.3)	(12.4)	(10.4)
Gross operating margin	171.6	191.5	501.9	547.4
Property, plant and equipment, net	3,255.1		3,255.1		3,060.7
Investments in unconsolidated affiliates	79		79		73.9
Intangible assets, net	184.9		184.9		191.7
Goodwill	956.2		956.2		956.2
Segment assets	4,475.2		4,475.2		4,282.5
Reportable Business Segments [Member] | Offshore Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	0	7.8	0	76.9
Revenues from related parties	0	1	0	1.9
Intersegment and intrasegment revenues	0	0.1	0	0.6
Total revenues	0	8.9	0	79.4
Equity in income (loss) of unconsolidated affiliates	0	5.4	0	46.6
Gross operating margin	0	7.1	0	97.5
Property, plant and equipment, net	0		0		0
Investments in unconsolidated affiliates	0		0		0
Intangible assets, net	0		0		0
Goodwill	0		0		0
Segment assets	0		0		0
Eliminations [Member]
Information by business segment [Abstract]
Revenues from third parties	0	0	0	0
Revenues from related parties	0	0	0	0
Intersegment and intrasegment revenues	(7,734.2)	(4,050.7)	(20,556.9)	(13,040.1)
Total revenues	(7,734.2)	(4,050.7)	(20,556.9)	(13,040.1)
Equity in income (loss) of unconsolidated affiliates	0	0	0	0
Gross operating margin	0	$ 0	0	$ 0
Adjustments [Member]
Information by business segment [Abstract]
Property, plant and equipment, net	3,276.4		3,276.4		3,894
Investments in unconsolidated affiliates	0		0		0
Intangible assets, net	0		0		0
Goodwill	0		0		0
Segment assets	$ 3,276.4		$ 3,276.4		$ 3,894

Business Segments, Consolidated

Business Segments, Consolidated Revenues and Expenses (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Consolidated Revenues [Abstract]
Total consolidated revenues		$ 5,920.4	$ 6,307.9	$ 16,543.5	$ 20,872.9
Operating costs and expenses:
Cost of sales	[1]	4,088.6	4,419.9	11,135.6	15,355.9
Other operating costs and expenses	[2]	612.1	642.5	1,787.2	1,834.8
Depreciation, amortization and accretion		367.1	351.1	1,085.6	1,082
Asset impairment charges		6.8	26.8	21.6	139.1
Loss due to Pascagoula fire		0	0	7.1	0
Net losses (gains) attributable to asset sales		(8.9)	12.3	(2.3)	14.7
General and administrative costs		42	49	121	143.2
Total consolidated costs and expenses		5,107.7	5,501.6	14,155.8	18,569.7
NGL Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of NGLs and related products		1,959	1,844.9	5,962.9	5,936.2
Midstream services		457.9	441.9	1,373.3	1,293
Total consolidated revenues		2,416.9	2,286.8	7,336.2	7,229.2
Crude Oil Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of crude oil		1,538.5	2,147.3	4,141.8	7,689.3
Midstream services		184.5	175.3	529.8	399.7
Total consolidated revenues		1,723	2,322.6	4,671.6	8,089
Natural Gas Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of natural gas		483.7	455	1,104.4	1,361.2
Midstream services		230.5	254.7	695.5	767.1
Total consolidated revenues		714.2	709.7	1,799.9	2,128.3
Petrochemical & Refined Products Services [Member]
Consolidated Revenues [Abstract]
Sales of petrochemicals and refined products		871.3	780.5	2,137.9	2,764.2
Midstream services		195	199.5	597.9	583.4
Total consolidated revenues		1,066.3	980	2,735.8	3,347.6
Offshore Pipelines & Services [Member]
Consolidated Revenues [Abstract]
Sales of crude oil		0	0.4	0	3.2
Midstream services		0	8.4	0	75.6
Total consolidated revenues		$ 0	$ 8.8	$ 0	$ 78.8
[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 the cost of operating our plants, pipelines and other fixed assets excluding: depreciation, amortization and accretion charges; asset impairment charges; losses due to property damage events (e.g., the fire at our Pascagoula Facility (see Note 4)); and net losses (or gains) attributable to asset sales.

Earnings Per Unit (Details)

Earnings Per Unit (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
BASIC EARNINGS PER UNIT
Net income attributable to limited partners		$ 634.6	$ 649.3	$ 1,854.3	$ 1,836.4
Undistributed earnings allocated and cash payments on phantom unit awards	[1]	(3.2)	(2.2)	(9.7)	(6.6)
Net income available to common unitholders		$ 631.4	$ 647.1	$ 1,844.6	$ 1,829.8
Basic weighted-average number of common units outstanding (in units)		2,097.5	1,969.3	2,072.2	1,952.3
Basic earnings per unit (in dollars per unit)		$ 0.30	$ 0.33	$ 0.89	$ 0.94
DILUTED EARNINGS PER UNIT
Net income attributable to limited partners		$ 634.6	$ 649.3	$ 1,854.3	$ 1,836.4
Diluted weighted-average number of units outstanding:
Distribution-bearing common units (in units)		2,097.5	1,969.3	2,072.2	1,952.3
Designated Units (in units)		0	35.4	0	35.4
Phantom units (in units)	[1]	8	5.7	7.6	5.4
Incremental option units (in units)		0	0.1	0	0.2
Total (in units)		2,105.5	2,010.5	2,079.8	1,993.3
Diluted earnings per unit (in dollars per unit)		$ 0.30	$ 0.32	$ 0.89	$ 0.92
[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		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Equity-based compensation expense [Abstract]
Total compensation expense	$ 22.3	$ 23.4	$ 66.5	$ 73.5
Phantom Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	19.9	20.3	58.6	60.2
Restricted Common Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	0.8	3.1	3.7	13.1
Profits Interest Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	1.5	0	3.8	0
Liability-classified awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	$ 0.1	$ 0	$ 0.4	$ 0.2
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		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)	18,297,995		18,297,995
Long Term Incentive Plan (1998) [Member]
Equity-based compensation expense [Abstract]
Maximum number of common units that may be issued as awards (in units)	14,000,000		14,000,000
Remaining number of common units available to be issued as awards (in units)	3,255,545		3,255,545

Equity-Based Awards, Phantom Un

Equity-Based Awards, Phantom Unit Awards (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Cash payments made in connection with DERs				$ 8.5	$ 5.6
Phantom Unit Awards [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate of phantom unit awards		25.00%		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]			4,486,910
Vested (in units)				(1,728,388)
Forfeited (in units)				(364,506)
End of period (in units)		7,820,965		7,820,965
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]			21.88
Vested weighted-average grant date fair value per unit (in dollars per unit)	[2]			33.13
Forfeited weighted-average grant date fair value per unit (in dollars per unit)	[2]			28.71
Weighted-average grant date fair value per unit, at end of period (in dollars per unit)	[2]	$ 27.23		$ 27.23
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Aggregate grant date fair value				$ 98.2
Estimated forfeiture rate				3.90%
Cash payments made in connection with DERs		$ 3.2	$ 2.2	$ 8.5	5.6
Total intrinsic value of phantom unit awards that vested during period		3	$ 2.3	40.1	$ 31
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		99.7		$ 99.7
Recognition period for total unrecognized compensation cost				2 years
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)				$ 27.39
Phantom Unit Awards [Member] | Enterprise [Member]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 89.9		$ 89.9
[1]	The aggregate grant date fair value of phantom unit awards issued during 2016 was $98.2 million based on grant date market prices of our common units ranging from $21.86 per unit to $27.39 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, Restricted

Equity-Based Awards, Restricted Unit Awards (Details) - Restricted Common Unit Awards [Member] - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting rate of restricted common unit awards		25.00%		25.00%
Summary of awards activity, equity instruments other than options [Roll Forward]
Beginning of period (in units)				1,960,520
Vested (in units)				(1,214,178)
Forfeited (in units)				(41,774)
End of period (in units)		704,568		704,568
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]			27.45
Forfeited weighted-average grant date fair value per unit (in dollars per unit)	[1]			28.46
Weighted-average grant date fair value per unit, at end of period (in dollars per unit)	[1]	$ 28.58		$ 28.58
Summary of awards activity, equity instruments other than options, additional disclosures [Abstract]
Cash distributions paid to restricted common unitholders		$ 0.3	$ 0.8	$ 1.4	$ 3.2
Total intrinsic value of our restricted common unit awards that vested during period		0.7	$ 1.5	28	$ 66.9
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		1.9		1.9
Enterprise [Member]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost		$ 1.4		$ 1.4
[1]	Determined by dividing the aggregate grant date fair value of awards (before an allowance for forfeitures) by the number of awards issued.

Equity-Based Awards, Unit Optio

Equity-Based Awards, Unit Option Awards (Details) - Unit Option Awards [Member] - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015
Options outstanding, weighted-average strike price [Roll Forward]
Total intrinsic value of unit option awards exercised during period	$ 0.2	$ 19.8
Cash received from EPCO in connection with the exercise of unit option awards	0.2	11.5
Unit option award-related cash reimbursements to EPCO	$ 0.2	$ 19.8

Equity-Based Awards, Profits In

Equity-Based Awards, Profits Interest Awards (Details) - Profits Interest Awards [Member] $ in Millions	9 Months Ended
	Sep. 30, 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	6.6638%	[2]
Expected liquidation date	Feb. 1, 2020
Estimated grant date fair value of profits interest awards	$ 13.2	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 11.2	[4]
Recognition period for total unrecognized compensation cost	3 years 4 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award	4 years
EPD PubCo I [Member] | Minimum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	0.90%
Expected Distribution Yield	6.20%
Expected Unit Price Volatility	29.00%
EPD PubCo I [Member] | Maximum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.10%
Expected Distribution Yield	6.70%
Expected Unit Price Volatility	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	6.6638%	[2]
Expected liquidation date	Feb. 1, 2021
Estimated grant date fair value of profits interest awards	$ 14.8	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 12.9	[4]
Recognition period for total unrecognized compensation cost	4 years 4 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award	5 years
EPD PubCo II [Member] | Minimum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.10%
Expected Distribution Yield	6.20%
Expected Unit Price Volatility	27.00%
EPD PubCo II [Member] | Maximum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.30%
Expected Distribution Yield	6.70%
Expected Unit Price Volatility	40.00%
EPD PubCo III [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	105,000
Class A capital base	$ 2.5	[1]
Class A partner preferred return rate	6.5381%	[2]
Expected liquidation date	Apr. 1, 2020
Estimated grant date fair value of profits interest awards	$ 0.5	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 0.5	[4]
Recognition period for total unrecognized compensation cost	3 years 6 months
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award	4 years
Expected Distribution Yield	6.20%
EPD PubCo III [Member] | Minimum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	0.90%
Expected Unit Price Volatility	29.00%
EPD PubCo III [Member] | Maximum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.00%
Expected Unit Price Volatility	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	6.6638%	[2]
Expected liquidation date	Feb. 1, 2021
Estimated grant date fair value of profits interest awards	$ 5.8	[3]
Unrecognized Compensation Expense [Abstract]
Unrecognized compensation cost	$ 1.1	[4]
Recognition period for total unrecognized compensation cost	4 years 4 months 24 days
Estimated Grant Date Fair Value Assumptions [Abstract]
Expected Life of Award	5 years
EPD PrivCo I [Member] | Minimum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.10%
Expected Distribution Yield	6.20%
Expected Unit Price Volatility	27.00%
EPD PrivCo I [Member] | Maximum [Member]
Estimated Grant Date Fair Value Assumptions [Abstract]
Risk-Free Interest Rate	1.30%
Expected Distribution Yield	6.70%
Expected Unit Price Volatility	40.00%
[1]	Represents fair market value of the Enterprise common units contributed to each Employee Partnership at the applicable contribution date.
[2]	For each period and Employee Partnership, the Class A Preference Return amount equals the Class A Capital Base, after adjusting for certain retained cash distributions and other amounts as defined in the underlying agreements, multiplied by the applicable Class A Partner Preferred Return Rate 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 September 30, 2016. We expect to recognize our share of the unrecognized compensation cost for PubCo I, PubCo II, PubCo III and PrivCo I over a weighted-average period of 3.4 years, 4.4 years, 3.5 years and 4.4 years, respectively.

Derivative Instruments, Hedgi61

Derivative Instruments, Hedging Activities and Fair Value Measurements (Details) bbl in Millions, $ in Millions		1 Months Ended	9 Months Ended
		Oct. 31, 2016USD ($)	Sep. 30, 2016USD ($)ContractbblBcf
Interest Rate Swaps Hedging Senior Notes OO [Member] | Derivatives in fair value hedging relationships [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			1.65%
Rate Swap, floating rate			1.27%
Forward Starting Swaps A [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Number of Derivatives Outstanding | Contract			4
Type of Derivatives Outstanding			forward starting swaps
Notional Amount | $			$ 250
Expected Termination Date			Sep. 1, 2017
Average Rate Locked			1.91%
Life of associated future debt (in years)			30 years
Forward Starting Swaps B [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Number of Derivatives Outstanding | Contract			4
Type of Derivatives Outstanding			forward starting swaps
Notional Amount | $			$ 275
Expected Termination Date			May 1, 2018
Average Rate Locked			2.02%
Life of associated future debt (in years)			30 years
Unrealized gain on cash flow hedging instruments | $		$ 6.1
Designated as Hedging Instrument [Member] | Natural gas processing: Forecasted natural gas purchases for plant thermal reduction (PTR) [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume | Bcf	[1],[2]		24.4
Long Term Volume | Bcf	[1],[2]		3.3
Designated as Hedging Instrument [Member] | Natural gas processing: Forecasted sales of NGLs [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		12.1
Long Term Volume	[1],[2]		3.5
Designated as Hedging Instrument [Member] | Octane enhancement: Forecasted purchases of NGLs [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		1.3
Designated as Hedging Instrument [Member] | Octane enhancement: Forecasted sales of octane enhancement products [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		1.4
Designated as Hedging Instrument [Member] | Natural gas marketing: Forecasted purchases of natural gas for fuel [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume | Bcf	[1],[2]		3.3
Long Term Volume | Bcf	[1],[2]		0.5
Designated as Hedging Instrument [Member] | Natural gas marketing: Natural gas storage inventory management activities [Member] | Derivatives in fair value hedging relationships [Member]
Derivative [Line Items]
Current Volume | Bcf	[1],[2]		8.2
Designated as Hedging Instrument [Member] | NGL marketing: Forecasted purchases of NGLs and related hydrocarbon products [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		78.2
Long Term Volume	[1],[2]		2.3
Designated as Hedging Instrument [Member] | NGL marketing: Forecasted sales of NGLs and related hydrocarbon products [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		99
Long Term Volume	[1],[2]		7
Designated as Hedging Instrument [Member] | Refined products marketing: Forecasted purchases of refined products [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		0.3
Designated as Hedging Instrument [Member] | Refined products marketing: Forecasted sales of refined products [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		0.4
Designated as Hedging Instrument [Member] | Refined products marketing: Refined products inventory management activities [Member] | Derivatives in fair value hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		2.1
Designated as Hedging Instrument [Member] | Crude oil marketing: Forecasted purchases of crude oil [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		7.4
Designated as Hedging Instrument [Member] | Crude oil marketing: Forecasted sales of crude oil [Member] | Derivatives in cash flow hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		11.5
Designated as Hedging Instrument [Member] | Crude oil marketing: Crude oil inventory management activities [Member] | Derivatives in fair value hedging relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2]		0.2
Not Designated as Hedging Instrument [Member] | Natural gas risk management activities [Member] | Derivatives in mark-to-market relationships [Member]
Derivative [Line Items]
Current Volume | Bcf	[1],[2],[3],[4]		98.2
Long Term Volume | Bcf	[1],[2],[3],[4]		20.9
Current natural gas hedging volumes designated as an index plus or minus a discount | Bcf			25.4
Long-term natural gas hedging volumes designated as an index plus or minus a discount | Bcf			1.8
Not Designated as Hedging Instrument [Member] | NGL risk management activities [Member] | Derivatives in mark-to-market relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2],[4]		7.2
Not Designated as Hedging Instrument [Member] | Crude oil risk management activities [Member] | Derivatives in mark-to-market relationships [Member]
Derivative [Line Items]
Current Volume	[1],[2],[4]		28.5
Long Term Volume	[1],[2],[4]		0.9
[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, June 2017 and March 2020, 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]	Current and long-term volumes include 25.4 Bcf and 1.8 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.
[4]	Reflects the use of derivative instruments to manage risks associated with transportation, processing and storage assets.

Derivative Instruments, Hedgi62

Derivative Instruments, Hedging Activities and Fair Value Measurements, Derivative Fair Value Amounts (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 3.5	$ 3.2
Liability Derivatives	16.3	3.7
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	245.7	255.6
Liability Derivatives	475.4	143
Derivatives designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	211.8	257.2
Liability Derivatives	429.4	142.6
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	3.5	3.2
Liability Derivatives	16.3	3.7
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	3	3.2
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.5	0
Derivatives designated as hedging instruments [Member] | Interest rate derivatives [Member] | 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	16.3	3.7
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	208.3	254
Liability Derivatives	413.1	138.9
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	202.6	253.8
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	5.7	0.2
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	407.1	137.5
Derivatives designated as hedging instruments [Member] | Commodity derivatives [Member] | Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	6	1.4
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	37.4	1.6
Liability Derivatives	62.3	4.1
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	35.8	1.6
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.6	0
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	57.1	3.1
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	$ 5.2	$ 1

Derivative Instruments, Hedgi63

Derivative Instruments, Hedging Activities and Fair Value Measurements, Asset Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 3.5	$ 3.2
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Assets Presented in the Balance Sheet	3.5	3.2
Financial Instruments	(2.1)	(3.2)
Cash Collateral Received	0	0
Cash Collateral Paid	0	0
Amounts That Would Have Been Presented On Net Basis	1.4	0
Commodity derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	245.7	255.6
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Assets Presented in the Balance Sheet	245.7	255.6
Financial Instruments	(244.1)	(143)
Cash Collateral Received	0	(72.2)
Cash Collateral Paid	8.9	(40.1)
Amounts That Would Have Been Presented On Net Basis	$ 10.5	$ 0.3

Derivative Instruments, Hedgi64

Derivative Instruments, Hedging Activities and Fair Value Measurements, Liability Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Interest rate derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 16.3	$ 3.7
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Liabilities Presented in the Balance Sheet	16.3	3.7
Financial Instruments	(2.1)	(3.2)
Cash Collateral Paid	0	0
Amounts That Would Have Been Presented On Net Basis	14.2	0.5
Commodity derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	475.4	143
Gross Amounts Offset in the Balance Sheet	0	0
Amounts of Liabilities Presented in the Balance Sheet	475.4	143
Financial Instruments	(244.1)	(143)
Cash Collateral Paid	(231.3)	0
Amounts That Would Have Been Presented On Net Basis	$ 0	$ 0

Derivative Instruments, Hedgi65

Derivative Instruments, Hedging Activities and Fair Value Measurements, Gains and Losses on Derivative Instruments and Related Hedged Items (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Derivatives in fair value hedging relationships [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		$ (4.2)	$ 9.5	$ (78.9)	$ 9.1
Gain (Loss) Recognized in Income on Hedged Item		5.9	(8.2)	107.2	2.2
Derivatives in fair value hedging relationships [Member] | Interest rate derivatives [Member] | Interest expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		(3.8)	5.9	3.5	5.1
Gain (Loss) Recognized in Income on Hedged Item		3.8	(5.7)	(3.7)	(5.2)
Derivatives in fair value hedging relationships [Member] | Commodity derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) on Fair Value Hedge Ineffectiveness				0.8
Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness				27.7
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)				28.5
Derivatives in fair value hedging relationships [Member] | Commodity derivatives [Member] | Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		(0.4)	3.6	(82.4)	4
Gain (Loss) Recognized in Income on Hedged Item		2.1	(2.5)	110.9	7.4
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)		15.8	85.8	(68.5)	112.3
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		17.5	37.9	20.9	101.8
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)		(0.3)	(3.5)	(0.3)	(3.1)
Derivatives in cash flow hedging relationships [Member] | Interest rate derivatives [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)		(6.9)	0	(16.3)	0
Accumulated other comprehensive loss related to interest rate derivative instruments expected to be reclassified to earnings in interest expense over the next twelve months		(39.5)		(39.5)
Derivatives in cash flow hedging relationships [Member] | Interest rate derivatives [Member] | Interest expense [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		(9.4)	(8.9)	(27.8)	(26.3)
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		(43.6)		(43.6)
Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to revenue over the next twelve months		(44)		(44)
Accumulated other comprehensive income (loss) related to commodity derivative instruments expected to be reclassified to operating costs and expenses over the next twelve months		0.4		0.4
Derivatives in cash flow hedging relationships [Member] | Commodity derivatives [Member] | Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)	[1]	23.8	87.4	(53.4)	113.9
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		23	46.8	47.6	128.6
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)		0	(3.5)	0	(3.1)
Derivatives in cash flow hedging relationships [Member] | Commodity derivatives [Member] | 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]	(1.1)	(1.6)	1.2	(1.6)
Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)		3.9	0	1.1	(0.5)
Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)		(0.3)	0	(0.3)	0
Derivatives not designated as hedging instruments [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		18.3	(0.3)	(28.3)	3.9
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Revenue [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		18.3	0	(28.3)	3.9
Derivatives not designated as hedging instruments [Member] | Commodity derivatives [Member] | Operating costs and expenses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in Income on Derivative		$ 0	$ (0.3)	$ 0	$ 0
[1]	The fair value of these derivative instruments will be reclassified to their respective locations on the Unaudited Condensed Statement of Consolidated Operations upon settlement of the underlying derivative transactions, as appropriate.

Derivative Instruments, Hedgi66

Derivative Instruments, Hedging Activities and Fair Value Measurements, Recurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended						9 Months Ended
		Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Sep. 30, 2016	Sep. 30, 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								$ (42.1)	$ 7.7
Fair Value, Measurements, Recurring [Member]
Financial assets [Abstract]
Interest rate derivatives		$ 3.5						3.5		$ 3.2
Commodity derivatives		245.7						245.7		255.6
Total		249.2						249.2		258.8
Financial liabilities [Abstract]
Liquidity Option Agreement		273.1						273.1		245.1
Interest rate derivatives		16.3						16.3		3.7
Commodity derivatives		475.4						475.4		143
Total		764.8						764.8		391.8
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Financial assets [Abstract]
Interest rate derivatives		0						0		0
Commodity derivatives		82.2						82.2		109.5
Total		82.2						82.2		109.5
Financial liabilities [Abstract]
Liquidity Option Agreement		0						0		0
Interest rate derivatives		0						0		0
Commodity derivatives		202.8						202.8		31.3
Total		202.8						202.8		31.3
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Financial assets [Abstract]
Interest rate derivatives		3.5						3.5		3.2
Commodity derivatives		149.1						149.1		145.2
Total		152.6						152.6		148.4
Financial liabilities [Abstract]
Liquidity Option Agreement		0						0		0
Interest rate derivatives		16.3						16.3		3.7
Commodity derivatives		256.6						256.6		109.2
Total		272.9						272.9		112.9
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Financial assets [Abstract]
Interest rate derivatives		0						0		0
Commodity derivatives		14.4						14.4		0.9
Total		14.4						14.4		0.9
Financial liabilities [Abstract]
Liquidity Option Agreement		273.1						273.1		245.1
Interest rate derivatives		0						0		0
Commodity derivatives		16						16		2.5
Total		289.1						289.1		$ 247.6
Reconciliation of changes in the fair value of Level 3 financial assets and liabilities [Roll Forward]
Financial liability balance, net, beginning of period		(263.7)	$ (242.3)	$ (246.7)	$ (232.8)	$ (221.6)	$ (219.3)	(246.7)	(219.3)
Total gains (losses) included in:
Transfers out of Level 3		0	0	0.1	1.1	1.5	0.1
Financial liability balance, net, end of period		(274.7)	(263.7)	(242.3)	(251.5)	(232.8)	(221.6)	(274.7)	(251.5)
Unrealized gain (loss) recognized as a component of net income related to financial assets and liabilities								$ 0.5	$ (1.1)
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Revenue [Member]
Total gains (losses) included in:
Net income	[1]	0.2	0	0.7	(0.3)	(0.4)	(0.4)
Settlements		(0.2)	(0.1)	(0.1)	0.3	0.2	(0.5)
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Other Expense [Member]
Total gains (losses) included in:
Net income		(6.9)	(23.3)	2.2	(4.3)	(11.5)	0
Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Other Comprehensive Income (Loss) [Member]
Total gains (losses) included in:
Other comprehensive income		$ (4.1)	$ 2	$ 1.5	$ (15.5)	$ (1)	$ (1.5)
[1]	There were $0.5 million of unrealized gains included in these amounts for the nine months ended September 30, 2016. There were unrealized losses of $1.1 million included in these amounts for the nine months ended September 30, 2015.

Derivative Instruments, Hedgi67

Derivative Instruments, Hedging Activities and Fair Value Measurements, Level 3 Recurring Valuation Techniques (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)$ / gal$ / bbl	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	45.44
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	48.89
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	0.49
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	0.57
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] | Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, forward commodity price (in dollars per unit) | $ / gal	1.06
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	1.11
Asset Commodity derivatives - Ethane [Member] | Liability Commodity Derivatives - Ethane [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 - Ethane [Member] | Liability Commodity Derivatives - Ethane [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	0.23
Asset Commodity derivatives - Ethane [Member] | Liability Commodity Derivatives - Ethane [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	0.29
Asset commodity derivatives - Normal butane [Member] | Liability commodity derivatives - Normal butane [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 - Normal butane [Member] | Liability commodity derivatives - Normal butane [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	0.62
Asset commodity derivatives - Normal butane [Member] | Liability commodity derivatives - Normal butane [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	0.73
Fair Value, Measurements, Recurring [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	$ 245.7	$ 255.6
Commodity liability derivatives	475.4	143
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	14.4	0.9
Commodity liability derivatives	16	$ 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	1.3
Fair Value, Measurements, Recurring [Member] | Liability commodity derivatives - Propane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	6.5
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	2.1
Fair Value, Measurements, Recurring [Member] | Liability Commodity Derivatives - Ethane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	2.6
Fair Value, Measurements, Recurring [Member] | Liability commodity derivatives - Normal butane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity liability derivatives	3.5
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	1.4
Fair Value, Measurements, Recurring [Member] | Asset commodity derivatives - Propane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	5.8
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	2.2
Fair Value, Measurements, Recurring [Member] | Asset Commodity derivatives - Ethane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	3.4
Fair Value, Measurements, Recurring [Member] | Asset commodity derivatives - Normal butane [Member] | Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	$ 1.6

Derivative Instruments, Hedgi68

Derivative Instruments, Hedging Activities and Fair Value Measurements, Nonrecurring Fair Value Measurements (Details) - USD ($) $ in Millions		3 Months Ended		9 Months Ended
		Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Asset Impairment Charges [Abstract]
Asset impairment charges		$ 6.8	$ 26.8	$ 22	$ 139.1
Impairment of other current assets				1.2
Impairment of long-lived assets disposed of other than by sale				11.3	69.9
Impairment of long-lived assets held for sale				9.5	14.2
Impairment of long-lived assets disposed of by sale	[1]				55
Impairment of long-lived assets				20.8	139.1
NGL Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Asset impairment charges		3.8	14.6	6.4	20.6
Crude Oil Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Asset impairment charges		0	0	0.9	25.9
Natural Gas Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Asset impairment charges		2	0	11.7	21.5
Petrochemical & Refined Products Services [Member]
Asset Impairment Charges [Abstract]
Asset impairment charges		1	12.2	3	12.6
Offshore Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Asset impairment charges		0	0	0	58.5
Fair Value, Measurements, Nonrecurring [Member] | Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0	0.4	0	0.4
Fair Value, Measurements, Nonrecurring [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		1.5	34.2	1.5	34.2
Fair Value, Measurements, Nonrecurring [Member] | Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value			0		0
Fair Value, Measurements, Nonrecurring [Member] | Level 1 [Member] | Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0	0	0	0
Fair Value, Measurements, Nonrecurring [Member] | Level 1 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0	0	0	0
Fair Value, Measurements, Nonrecurring [Member] | Level 1 [Member] | Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value			0		0
Fair Value, Measurements, Nonrecurring [Member] | Level 2 [Member] | Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		0	0	0	0
Fair Value, Measurements, Nonrecurring [Member] | Level 2 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		1.5	0	1.5	0
Fair Value, Measurements, Nonrecurring [Member] | Level 2 [Member] | Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value			0		0
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	0.4	0	0.4
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Long-lived Assets Held For Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value		$ 0	34.2	$ 0	34.2
Fair Value, Measurements, Nonrecurring [Member] | Level 3 [Member] | Long-lived Assets Disposed of By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value			$ 0		$ 0
[1]	Primarily represents the impairment charge recorded in connection with the sale of our Offshore Business.

Derivative Instruments, Hedgi69

Derivative Instruments, Hedging Activities and Fair Value Measurements, Other Fair Value Measurements (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015
Carrying Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 20,850	$ 20,870
Level 2 [Member] | Fair Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 22,500	$ 19,510

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Revenues - related parties:
Total revenue - related parties	$ 15.7	$ 13.9	$ 44.5	$ 27.3
Costs and expenses - related parties:
Total costs and expenses - related parties	311.5	312.9	920.5	869.2
Accounts receivable - related parties:
Total accounts receivable - related parties	1.7		1.7		$ 1.2
Accounts payable - related parties:
Total accounts payable - related parties	97.7		97.7		$ 84.1
Related Party Transactions [Abstract]
Operating costs and expenses	284.5	284.7	835.4	783.9
General and administrative expenses	27	28.2	85.1	85.3
Relationship with Affiliates [Abstract]
Net cash proceeds from the issuance of common units			$ 2,170.4	$ 1,011.4
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)			76,113,492	23,258,453
Gross proceeds from the sale of common units			$ 1,870	$ 767.1
Net cash proceeds from the issuance of common units			$ 1,850	$ 759.7
Distribution Reinvestment Plan [Member]
Relationship with Affiliates [Abstract]
Number of common units issued (in units)			12,946,724	7,965,318
Net cash proceeds from the issuance of common units			$ 306.2	$ 242.8
EPCO and its privately held affiliates [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties	242.3	246	721	703.9
Accounts payable - related parties:
Total accounts payable - related parties	$ 81.9		81.9		$ 75.6
Distributions:
Total cash distributions			$ 793.6	$ 705.9
Relationship with Affiliates [Abstract]
Total Number of Units (in units)	685,481,428		685,481,428
Percentage of Total Units Outstanding	32.60%		32.60%
Number of Designated Units excluded from distributions (in units)					35,380,000
Enterprise common units pledged as security (in units)	118,000,000		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	3,225,057
Gross proceeds from the sale of common units			$ 100	$ 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	$ 238.8	241.7	708.4	691
Related Party Transactions [Abstract]
Operating costs and expenses	212.9	215.3	628.9	612.2
General and administrative expenses	25.9	26.4	79.5	78.8
Unconsolidated affiliates [Member]
Revenues - related parties:
Total revenue - related parties	15.7	13.9	44.5	27.3
Costs and expenses - related parties:
Total costs and expenses - related parties	69.2	$ 66.9	199.5	$ 165.3
Accounts receivable - related parties:
Total accounts receivable - related parties	1.7		1.7		$ 1.2
Accounts payable - related parties:
Total accounts payable - related parties	$ 15.8		$ 15.8		$ 8.5

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Operating lease obligations [Abstract]
Lease and rental expense included in costs and expenses	$ 27	$ 28.8	$ 81.8	$ 76.4
Litigation matters [Member]
Loss Contingencies [Line Items]
Litigation accruals on an undiscounted basis	$ 5.6		5.6		$ 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			5.00%

Commitments and Contingencies,

Commitments and Contingencies, Liquidity Option Agreement (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Number of units held by limited partner	54,807,352		54,807,352
Liquidity Option Agreement [Abstract]
Liquidity Option Agreement	$ 273.1		$ 273.1		$ 245.1
Change in fair value of Liquidity Option Agreement	6.9	$ 4.3	28	$ 15.8
Liquidity Option Agreement [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, Assumed long-term debt			$ 2,200
Fair value inputs, Interest rate on assumed debt of OTA following option exercise			4.75%
Increase in fair value of liquidity option agreement excluding assumption of debt	211.1		$ 211.1
Fair value inputs, Life of debt assumed after Liquidity option is exercised			30 years
Fair value inputs, federal and state tax rate			38.00%
Cash flow projections discount rate			7.50%
Fair value inputs, weighted-average expected ownership percentage of contributed units at beginning of option period			83.00%
Increase in fair value of liquidity option agreement assuming retention of all units	$ 56.7		$ 56.7
Liquidity Option Agreement [Abstract]
Other Commitments, Description			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.
Liquidity Option Agreement [Member] | Maximum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, Expected life of OTA following option exercise			30 years
Fair value inputs, Estimated growth rates in Enterprise earnings before interest, taxes, depreciation and amortization			15.00%
Fair value inputs, OTA ownership interest in Enterprise common units			2.60%
Fair value inputs, Forecasted yield on Enterprise common units			6.60%
Liquidity Option Agreement [Member] | Minimum [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Fair value inputs, Expected life of OTA following option exercise			1 year
Fair value inputs, Estimated growth rates in Enterprise earnings before interest, taxes, depreciation and amortization			2.00%
Fair value inputs, OTA ownership interest in Enterprise common units			1.90%
Fair value inputs, Forecasted yield on Enterprise common units			5.80%

Supplemental Cash Flow Inform73

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	1 Months Ended		9 Months Ended		12 Months Ended
	Jul. 31, 2016	Jul. 31, 2015	Sep. 30, 2016	Sep. 30, 2015	Dec. 31, 2015
Decrease (increase) in:
Accounts receivable - trade			$ (370.4)	$ 1,042.5
Accounts receivable - related parties			(0.2)	1.2
Inventories			(701.6)	(143.2)
Prepaid and other current assets			(71.8)	(32.7)
Other assets			(1.3)	2.1
Increase (decrease) in:
Accounts payable - trade			(36.8)	(72.7)
Accounts payable - related parties			13.6	(38.6)
Accrued product payables			615.1	(1,248.4)
Accrued interest			(149.5)	(136.7)
Other current liabilities			201.1	(13.8)
Other liabilities			12.1	12.4
Net effect of changes in operating accounts			(489.7)	(627.9)
Liability for construction in progress expenditures			166.5		$ 472.8
Business Acquisition [Line Items]
Cash used for business combinations			1,000	1,045.1
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries			43.9	1,537.3
Net gains (losses) attributable to asset sales			2.3	(14.7)
Offshore Business [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries			0	1,528.6
Net gains (losses) attributable to asset sales			0	(12.6)
Other Disposal of Assets [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from asset sales and insurance recoveries			43.9	8.7
Net gains (losses) attributable to asset sales			$ 2.3	$ (2.1)
Eagle Ford Midstream Assets [Member]
Business Acquisition [Line Items]
Total purchase price of business combination		$ 2,100
Cash used for business combinations	$ 1,000	$ 1,100

Condensed Consolidating Finan74

Condensed Consolidating Financial Information, Balance Sheet (Details) - USD ($) $ in Millions	Sep. 30, 2016	Dec. 31, 2015	Sep. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents and restricted cash	$ 334.4	$ 34.9
Accounts receivable - trade, net	2,944.1	2,569.9
Accounts receivable - related parties	1.7	1.2
Inventories	1,762.5	1,038.1
Derivative assets	241.4	258.6
Prepaid and other current assets	457.5	395.6
Total current assets	5,741.6	4,298.3
Property, plant and equipment, net	33,119.4	32,034.7
Investments in unconsolidated affiliates	2,687.2	2,628.5
Intangible assets, net	3,907.2	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	57.8	58.3
Total assets	51,258.4	48,802.2
Current liabilities:
Current maturities of debt	2,838.1	1,863.9
Accounts payable - trade	453.7	860.1
Accounts payable - related parties	97.7	84.1
Accrued product payables	3,087.5	2,484.4
Accrued liability related to EFS Midstream acquisition	0	993.2
Accrued interest	202.7	352.1
Derivative liabilities	464.2	140.6
Other current liabilities	424.4	388.2
Total current liabilities	7,568.3	7,166.6
Long-term debt	21,121.2	20,676.9
Deferred tax liabilities	51.6	46.1
Other long-term liabilities	478.6	411.5
Commitments and contingencies
Equity:
Partners' and other owners' equity	21,819.2	20,295.1
Noncontrolling interests	219.5	206
Total equity	22,038.7	20,501.1	$ 20,352.9	$ 19,692.2
Total liabilities and equity	51,258.4	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	(1.7)	(0.2)
Inventories	0	0
Derivative assets	0	0
Prepaid and other current assets	0	0
Total current assets	(1.7)	(0.2)
Property, plant and equipment, net	0	0
Investments in unconsolidated affiliates	(22,093.4)	(20,540.2)
Intangible assets, net	0	0
Goodwill	0	0
Other assets	0	0
Total assets	(22,095.1)	(20,540.4)
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	0	0
Accounts payable - related parties	(1.7)	(0.2)
Accrued product payables	0	0
Accrued liability related to EFS Midstream acquisition		0
Accrued interest	0	0
Derivative liabilities	0	0
Other current liabilities	0.7	0
Total current liabilities	(1)	(0.2)
Long-term debt	0	0
Deferred tax liabilities	3	2.7
Other long-term liabilities	0	0
Commitments and contingencies
Equity:
Partners' and other owners' equity	(22,067.4)	(20,514.3)
Noncontrolling interests	(29.7)	(28.6)
Total equity	(22,097.1)	(20,542.9)
Total liabilities and equity	(22,095.1)	(20,540.4)
Subsidiary Issuer (EPO) [Member]
Current assets:
Cash and cash equivalents and restricted cash	279.2	14.4
Accounts receivable - trade, net	1,089.9	811.3
Accounts receivable - related parties	125.8	59
Inventories	1,426.3	786.9
Derivative assets	193.2	150.4
Prepaid and other current assets	268.9	153.6
Total current assets	3,383.3	1,975.6
Property, plant and equipment, net	4,608	3,859.8
Investments in unconsolidated affiliates	40,035.9	38,655
Intangible assets, net	706.6	721.2
Goodwill	459.5	459.5
Other assets	194.8	145.1
Total assets	49,388.1	45,816.2
Current liabilities:
Current maturities of debt	2,838	1,863.8
Accounts payable - trade	197.8	375.3
Accounts payable - related parties	886	885.3
Accrued product payables	1,594.4	997.7
Accrued liability related to EFS Midstream acquisition		0
Accrued interest	202.3	352
Derivative liabilities	371.7	75.1
Other current liabilities	85.3	103.6
Total current liabilities	6,175.5	4,652.8
Long-term debt	21,106	20,661.6
Deferred tax liabilities	3.7	3.4
Other long-term liabilities	33.8	14.5
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,069.1	20,483.9
Noncontrolling interests	0	0
Total equity	22,069.1	20,483.9
Total liabilities and equity	49,388.1	45,816.2
Other Subsidiaries (Non-guarantor) [Member]
Current assets:
Cash and cash equivalents and restricted cash	59.6	71.1
Accounts receivable - trade, net	1,857.4	1,755.8
Accounts receivable - related parties	772.6	795.4
Inventories	339.5	251.4
Derivative assets	48.2	108.2
Prepaid and other current assets	199.9	249.1
Total current assets	3,277.2	3,231
Property, plant and equipment, net	28,510	28,173.5
Investments in unconsolidated affiliates	4,208.7	4,067.3
Intangible assets, net	3,215	3,330.7
Goodwill	5,285.7	5,285.7
Other assets	41.4	47.9
Total assets	44,538	44,136.1
Current liabilities:
Current maturities of debt	0.1	0.1
Accounts payable - trade	260.2	535.1
Accounts payable - related parties	123.1	62.3
Accrued product payables	1,496	1,489.3
Accrued liability related to EFS Midstream acquisition		993.2
Accrued interest	0.4	0.1
Derivative liabilities	92.5	65.5
Other current liabilities	348.7	291.6
Total current liabilities	2,321	3,437.2
Long-term debt	15.2	15.3
Deferred tax liabilities	45.7	40.8
Other long-term liabilities	351.5	286.9
Commitments and contingencies
Equity:
Partners' and other owners' equity	41,727.7	40,297.2
Noncontrolling interests	76.9	58.7
Total equity	41,804.6	40,355.9
Total liabilities and equity	44,538	44,136.1
Consolidated EPO and Subsidiaries [Member]
Current assets:
Cash and cash equivalents and restricted cash	334.4	34.9
Accounts receivable - trade, net	2,944.1	2,569.9
Accounts receivable - related parties	3.4	1.4
Inventories	1,762.5	1,038.1
Derivative assets	241.4	258.6
Prepaid and other current assets	457.3	395.6
Total current assets	5,743.1	4,298.5
Property, plant and equipment, net	33,119.4	32,034.7
Investments in unconsolidated affiliates	2,687.2	2,628.5
Intangible assets, net	3,907.2	4,037.2
Goodwill	5,745.2	5,745.2
Other assets	57.3	57.8
Total assets	51,259.4	48,801.9
Current liabilities:
Current maturities of debt	2,838.1	1,863.9
Accounts payable - trade	453.6	859.8
Accounts payable - related parties	97.7	84.1
Accrued product payables	3,087.5	2,484.4
Accrued liability related to EFS Midstream acquisition		993.2
Accrued interest	202.7	352.1
Derivative liabilities	464.2	140.6
Other current liabilities	423.7	388.2
Total current liabilities	7,567.5	7,166.3
Long-term debt	21,121.2	20,676.9
Deferred tax liabilities	48.6	43.4
Other long-term liabilities	205.5	166.4
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,067.4	20,514.3
Noncontrolling interests	249.2	234.6
Total equity	22,316.6	20,748.9
Total liabilities and equity	51,259.4	48,801.9
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Current assets:
Cash and cash equivalents and restricted cash	(4.4)	(50.6)
Accounts receivable - trade, net	(3.2)	2.8
Accounts receivable - related parties	(895)	(853)
Inventories	(3.3)	(0.2)
Derivative assets	0	0
Prepaid and other current assets	(11.5)	(7.1)
Total current assets	(917.4)	(908.1)
Property, plant and equipment, net	1.4	1.4
Investments in unconsolidated affiliates	(41,557.4)	(40,093.8)
Intangible assets, net	(14.4)	(14.7)
Goodwill	0	0
Other assets	(178.9)	(135.2)
Total assets	(42,666.7)	(41,150.4)
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	(4.4)	(50.6)
Accounts payable - related parties	(911.4)	(863.5)
Accrued product payables	(2.9)	(2.6)
Accrued liability related to EFS Midstream acquisition		0
Accrued interest	0	0
Derivative liabilities	0	0
Other current liabilities	(10.3)	(7)
Total current liabilities	(929)	(923.7)
Long-term debt	0	0
Deferred tax liabilities	(0.8)	(0.8)
Other long-term liabilities	(179.8)	(135)
Commitments and contingencies
Equity:
Partners' and other owners' equity	(41,729.4)	(40,266.8)
Noncontrolling interests	172.3	175.9
Total equity	(41,557.1)	(40,090.9)
Total liabilities and equity	(42,666.7)	(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	0.2	0
Total current assets	0.2	0
Property, plant and equipment, net	0	0
Investments in unconsolidated affiliates	22,093.4	20,540.2
Intangible assets, net	0	0
Goodwill	0	0
Other assets	0.5	0.5
Total assets	22,094.1	20,540.7
Current liabilities:
Current maturities of debt	0	0
Accounts payable - trade	0.1	0.3
Accounts payable - related parties	1.7	0.2
Accrued product payables	0	0
Accrued liability related to EFS Midstream acquisition		0
Accrued interest	0	0
Derivative liabilities	0	0
Other current liabilities	0	0
Total current liabilities	1.8	0.5
Long-term debt	0	0
Deferred tax liabilities	0	0
Other long-term liabilities	273.1	245.1
Commitments and contingencies
Equity:
Partners' and other owners' equity	21,819.2	20,295.1
Noncontrolling interests	0	0
Total equity	21,819.2	20,295.1
Total liabilities and equity	$ 22,094.1	$ 20,540.7

Condensed Consolidating Finan75

Condensed Consolidating Financial Information, Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Consolidating Statement of Operations
Revenues	$ 5,920.4	$ 6,307.9	$ 16,543.5	$ 20,872.9
Costs and expenses:
Operating costs and expenses	5,065.7	5,452.6	14,034.8	18,426.5
General and administrative costs	42	49	121	143.2
Total costs and expenses	5,107.7	5,501.6	14,155.8	18,569.7
Equity in income of unconsolidated affiliates	92.3	103.1	269.8	302.5
Operating income	905	909.4	2,657.5	2,605.7
Other income (expense):
Interest expense	(250.9)	(243.7)	(735.6)	(723.2)
Other, net	(6.2)	(2.5)	(25.5)	(13.2)
Total other expense, net	(257.1)	(246.2)	(761.1)	(736.4)
Income before income taxes	647.9	663.2	1,896.4	1,869.3
Benefit from (provision for) income taxes	(4.8)	(5.5)	(13.1)	(4.4)
Net income	643.1	657.7	1,883.3	1,864.9
Net loss (income) attributable to noncontrolling interests	(8.5)	(8.4)	(29)	(28.5)
Net income attributable to limited partners	634.6	649.3	1,854.3	1,836.4
Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Operations
Revenues	0	0	0	0
Costs and expenses:
Operating costs and expenses	0	0	0	0
General and administrative costs	0	0	0	0
Total costs and expenses	0	0	0	0
Equity in income of unconsolidated affiliates	(642)	(653.2)	(1,884.4)	(1,852.6)
Operating income	(642)	(653.2)	(1,884.4)	(1,852.6)
Other income (expense):
Interest expense	0	0	0	0
Other, net	0	0	0	0
Total other expense, net	0	0	0	0
Income before income taxes	(642)	(653.2)	(1,884.4)	(1,852.6)
Benefit from (provision for) income taxes	(0.5)	0	(1.4)	(0.9)
Net income	(642.5)	(653.2)	(1,885.8)	(1,853.5)
Net loss (income) attributable to noncontrolling interests	1.3	1.3	3.9	3.6
Net income attributable to limited partners	(641.2)	(651.9)	(1,881.9)	(1,849.9)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Operations
Revenues	7,291.8	4,685.2	19,847.9	15,301
Costs and expenses:
Operating costs and expenses	7,099.6	4,506.7	19,192.8	14,696.2
General and administrative costs	6.3	11.1	16.4	28.9
Total costs and expenses	7,105.9	4,517.8	19,209.2	14,725.1
Equity in income of unconsolidated affiliates	701.6	725.5	1,971.6	1,996.4
Operating income	887.5	892.9	2,610.3	2,572.3
Other income (expense):
Interest expense	(248.8)	(239.5)	(726.4)	(717.9)
Other, net	2.1	1.7	6	4
Total other expense, net	(246.7)	(237.8)	(720.4)	(713.9)
Income before income taxes	640.8	655.1	1,889.9	1,858.4
Benefit from (provision for) income taxes	(2.7)	(3.3)	(5.5)	(8.9)
Net income	638.1	651.8	1,884.4	1,849.5
Net loss (income) attributable to noncontrolling interests	0	0	0	0
Net income attributable to limited partners	638.1	651.8	1,884.4	1,849.5
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Operations
Revenues	3,932.4	4,531.1	11,009.3	14,751
Costs and expenses:
Operating costs and expenses	3,270.3	3,854.5	9,156.3	12,909.8
General and administrative costs	35	38.3	102.3	113.9
Total costs and expenses	3,305.3	3,892.8	9,258.6	13,023.7
Equity in income of unconsolidated affiliates	129.3	116.5	389.3	314.5
Operating income	756.4	754.8	2,140	2,041.8
Other income (expense):
Interest expense	(4.2)	(4.2)	(14.8)	(7.3)
Other, net	0.7	0.1	2.1	0.6
Total other expense, net	(3.5)	(4.1)	(12.7)	(6.7)
Income before income taxes	752.9	750.7	2,127.3	2,035.1
Benefit from (provision for) income taxes	(1.6)	(2.2)	(6.2)	5.4
Net income	751.3	748.5	2,121.1	2,040.5
Net loss (income) attributable to noncontrolling interests	(1.7)	0	(5.3)	0.8
Net income attributable to limited partners	749.6	748.5	2,115.8	2,041.3
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Operations
Revenues	5,920.4	6,307.9	16,543.5	20,872.9
Costs and expenses:
Operating costs and expenses	5,065.7	5,452.6	14,034.8	18,426.5
General and administrative costs	41.5	49.4	118.9	142.8
Total costs and expenses	5,107.2	5,502	14,153.7	18,569.3
Equity in income of unconsolidated affiliates	92.3	103.1	269.8	302.5
Operating income	905.5	909	2,659.6	2,606.1
Other income (expense):
Interest expense	(250.9)	(243.7)	(735.6)	(723.2)
Other, net	0.7	1.8	2.5	2.6
Total other expense, net	(250.2)	(241.9)	(733.1)	(720.6)
Income before income taxes	655.3	667.1	1,926.5	1,885.5
Benefit from (provision for) income taxes	(4.3)	(5.5)	(11.7)	(3.5)
Net income	651	661.6	1,914.8	1,882
Net loss (income) attributable to noncontrolling interests	(9.8)	(9.7)	(32.9)	(32.1)
Net income attributable to limited partners	641.2	651.9	1,881.9	1,849.9
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Operations
Revenues	(5,303.8)	(2,908.4)	(14,313.7)	(9,179.1)
Costs and expenses:
Operating costs and expenses	(5,304.2)	(2,908.6)	(14,314.3)	(9,179.5)
General and administrative costs	0.2	0	0.2	0
Total costs and expenses	(5,304)	(2,908.6)	(14,314.1)	(9,179.5)
Equity in income of unconsolidated affiliates	(738.6)	(738.9)	(2,091.1)	(2,008.4)
Operating income	(738.4)	(738.7)	(2,090.7)	(2,008)
Other income (expense):
Interest expense	2.1	0	5.6	2
Other, net	(2.1)	0	(5.6)	(2)
Total other expense, net	0	0	0	0
Income before income taxes	(738.4)	(738.7)	(2,090.7)	(2,008)
Benefit from (provision for) income taxes	0	0	0	0
Net income	(738.4)	(738.7)	(2,090.7)	(2,008)
Net loss (income) attributable to noncontrolling interests	(8.1)	(9.7)	(27.6)	(32.9)
Net income attributable to limited partners	(746.5)	(748.4)	(2,118.3)	(2,040.9)
Enterprise Products Partners L.P. (Guarantor) [Member]
Condensed Consolidating Statement of Operations
Revenues	0	0	0	0
Costs and expenses:
Operating costs and expenses	0	0	0	0
General and administrative costs	0.5	(0.4)	2.1	0.4
Total costs and expenses	0.5	(0.4)	2.1	0.4
Equity in income of unconsolidated affiliates	642	653.2	1,884.4	1,852.6
Operating income	641.5	653.6	1,882.3	1,852.2
Other income (expense):
Interest expense	0	0	0	0
Other, net	(6.9)	(4.3)	(28)	(15.8)
Total other expense, net	(6.9)	(4.3)	(28)	(15.8)
Income before income taxes	634.6	649.3	1,854.3	1,836.4
Benefit from (provision for) income taxes	0	0	0	0
Net income	634.6	649.3	1,854.3	1,836.4
Net loss (income) attributable to noncontrolling interests	0	0	0	0
Net income attributable to limited partners	$ 634.6	$ 649.3	$ 1,854.3	$ 1,836.4

Condensed Consolidating Finan76

Condensed Consolidating Financial Information, Statement of Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	$ 641.4	$ 705.6	$ 1,793.8	$ 1,875.8
Comprehensive loss (income) attributable to noncontrolling interests	(8.5)	(8.4)	(29)	(28.5)
Comprehensive income attributable to entity	632.9	697.2	1,764.8	1,847.3
Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(640.8)	(701)	(1,796.3)	(1,864.3)
Comprehensive loss (income) attributable to noncontrolling interests	1.3	1.3	3.9	3.6
Comprehensive income attributable to entity	(639.5)	(699.7)	(1,792.4)	(1,860.7)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	649.9	676	1,824.5	1,869.9
Comprehensive loss (income) attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to entity	649.9	676	1,824.5	1,869.9
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	738	797.3	2,091.6	2,056.1
Comprehensive loss (income) attributable to noncontrolling interests	(1.7)	0	(5.3)	0.8
Comprehensive income attributable to entity	736.3	797.3	2,086.3	2,056.9
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	649.3	709.4	1,825.3	1,892.8
Comprehensive loss (income) attributable to noncontrolling interests	(9.8)	(9.7)	(32.9)	(32.1)
Comprehensive income attributable to entity	639.5	699.7	1,792.4	1,860.7
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(738.6)	(763.9)	(2,090.8)	(2,033.2)
Comprehensive loss (income) attributable to noncontrolling interests	(8.1)	(9.7)	(27.6)	(32.9)
Comprehensive income attributable to entity	(746.7)	(773.6)	(2,118.4)	(2,066.1)
Enterprise Products Partners L.P. (Guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	632.9	697.2	1,764.8	1,847.3
Comprehensive loss (income) attributable to noncontrolling interests	0	0	0	0
Comprehensive income attributable to entity	$ 632.9	$ 697.2	$ 1,764.8	$ 1,847.3

Condensed Consolidating Finan77

Condensed Consolidating Financial Information, Statement of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2016	Sep. 30, 2015	Sep. 30, 2016	Sep. 30, 2015
Operating activities:
Net income	$ 643.1	$ 657.7	$ 1,883.3	$ 1,864.9
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			1,155.3	1,147.7
Equity in income of unconsolidated affiliates	(92.3)	(103.1)	(269.8)	(302.5)
Distributions received on earnings from unconsolidated affiliates			281.6	362.4
Net effect of changes in operating accounts and other operating activities			(391.4)	(481.3)
Net cash flows provided by operating activities			2,659	2,591.2
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			(2,409.8)	(2,619.1)
Cash used for business combinations, net of cash received			(1,000)	(1,045.1)
Proceeds from asset sales			43.9	1,537.3
Other investing activities			(329.8)	(181.3)
Cash used in investing activities			(3,695.7)	(2,308.2)
Financing activities:
Borrowings under debt agreements			50,183.8	17,113.7
Repayments of debt			(48,776.5)	(16,139.2)
Cash distributions paid to owners			(2,448.3)	(2,185.1)
Cash payments made in connection with DERs			(8.5)	(5.6)
Cash distributions paid to noncontrolling interests			(35.7)	(33.2)
Cash contributions from noncontrolling interests			20.1	37.4
Net cash proceeds from issuance of common units			2,170.4	1,011.4
Cash contributions from owners			0	0
Other financing activities			(30.5)	(76.3)
Cash provided by (used in) financing activities			1,074.8	(276.9)
Net change in cash and cash equivalents			38.1	6.1
Cash and cash equivalents, beginning balance			19	74.4
Cash and cash equivalents, ending balance	57.1	80.5	57.1	80.5
Eliminations and Adjustments [Member]
Operating activities:
Net income	(642.5)	(653.2)	(1,885.8)	(1,853.5)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			0	0
Equity in income of unconsolidated affiliates	642	653.2	1,884.4	1,852.6
Distributions received on earnings from unconsolidated affiliates			(2,477.3)	(2,241.1)
Net effect of changes in operating accounts and other operating activities			0.7	0.9
Net cash flows provided by operating activities			(2,478)	(2,241.1)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			0	0
Cash used for business combinations, net of cash received			0	0
Proceeds from asset sales			0	0
Other investing activities			2,161.2	1,005.2
Cash used in investing activities			2,161.2	1,005.2
Financing activities:
Borrowings under debt agreements			0	0
Repayments of debt			0	0
Cash distributions paid to owners			2,477.3	2,241.1
Cash payments made in connection with DERs			0	0
Cash distributions paid to noncontrolling interests			0.7	0
Cash contributions from noncontrolling interests			0	0
Net cash proceeds from issuance of common units			0	0
Cash contributions from owners			(2,161.2)	(1,005.2)
Other financing activities			0	0
Cash provided by (used in) financing activities			316.8	1,235.9
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	0	0
Subsidiary Issuer (EPO) [Member]
Operating activities:
Net income	638.1	651.8	1,884.4	1,849.5
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			131.9	106
Equity in income of unconsolidated affiliates	(701.6)	(725.5)	(1,971.6)	(1,996.4)
Distributions received on earnings from unconsolidated affiliates			733.1	1,705.4
Net effect of changes in operating accounts and other operating activities			1,281.6	(52.9)
Net cash flows provided by operating activities			2,059.4	1,611.6
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			(989.6)	(725.5)
Cash used for business combinations, net of cash received			0	(1,058.4)
Proceeds from asset sales			27.9	1,532.1
Other investing activities			(2,177)	(1,091.2)
Cash used in investing activities			(3,138.7)	(1,343)
Financing activities:
Borrowings under debt agreements			50,183.8	17,113.7
Repayments of debt			(48,776.4)	(16,139.2)
Cash distributions paid to owners			(2,477.3)	(2,241.1)
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			2,161.2	1,005.2
Other financing activities			(8)	(23.9)
Cash provided by (used in) financing activities			1,083.3	(285.3)
Net change in cash and cash equivalents			4	(16.7)
Cash and cash equivalents, beginning balance			0	18.7
Cash and cash equivalents, ending balance	4	2	4	2
Other Subsidiaries (Non-guarantor) [Member]
Operating activities:
Net income	751.3	748.5	2,121.1	2,040.5
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			1,023.7	1,042.1
Equity in income of unconsolidated affiliates	(129.3)	(116.5)	(389.3)	(314.5)
Distributions received on earnings from unconsolidated affiliates			196.9	227.1
Net effect of changes in operating accounts and other operating activities			(1,742.7)	(450.6)
Net cash flows provided by operating activities			1,209.7	2,544.6
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			(1,420.2)	(1,893.6)
Cash used for business combinations, net of cash received			(1,000)	13.3
Proceeds from asset sales			16	5.2
Other investing activities			(84.2)	(43.5)
Cash used in investing activities			(2,488.4)	(1,918.6)
Financing activities:
Borrowings under debt agreements			41.4	77.9
Repayments of debt			(0.1)	0
Cash distributions paid to owners			(677.5)	(1,602.4)
Cash payments made in connection with DERs			0	0
Cash distributions paid to noncontrolling interests			(7.3)	(0.8)
Cash contributions from noncontrolling interests			20.1	37.8
Net cash proceeds from issuance of common units			0	0
Cash contributions from owners			1,890	875.1
Other financing activities			0	0
Cash provided by (used in) financing activities			1,266.6	(612.4)
Net change in cash and cash equivalents			(12.1)	13.6
Cash and cash equivalents, beginning balance			69.6	70.4
Cash and cash equivalents, ending balance	57.5	84	57.5	84
Consolidated EPO and Subsidiaries [Member]
Operating activities:
Net income	651	661.6	1,914.8	1,882
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			1,155.3	1,147.7
Equity in income of unconsolidated affiliates	(92.3)	(103.1)	(269.8)	(302.5)
Distributions received on earnings from unconsolidated affiliates			281.6	362.4
Net effect of changes in operating accounts and other operating activities			(415)	(494.2)
Net cash flows provided by operating activities			2,666.9	2,595.4
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			(2,409.8)	(2,619.1)
Cash used for business combinations, net of cash received			(1,000)	(1,045.1)
Proceeds from asset sales			43.9	1,537.3
Other investing activities			(329.8)	(181.3)
Cash used in investing activities			(3,695.7)	(2,308.2)
Financing activities:
Borrowings under debt agreements			50,183.8	17,113.7
Repayments of debt			(48,776.5)	(16,139.2)
Cash distributions paid to owners			(2,477.3)	(2,241.1)
Cash payments made in connection with DERs			0	0
Cash distributions paid to noncontrolling interests			(36.4)	(33.2)
Cash contributions from noncontrolling interests			20.1	37.4
Net cash proceeds from issuance of common units			0	0
Cash contributions from owners			2,161.2	1,005.2
Other financing activities			(8)	(23.9)
Cash provided by (used in) financing activities			1,066.9	(281.1)
Net change in cash and cash equivalents			38.1	6.1
Cash and cash equivalents, beginning balance			19	74.4
Cash and cash equivalents, ending balance	57.1	80.5	57.1	80.5
Consolidated EPO and Subsidiaries [Member] | Eliminations and Adjustments [Member]
Operating activities:
Net income	(738.4)	(738.7)	(2,090.7)	(2,008)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			(0.3)	(0.4)
Equity in income of unconsolidated affiliates	738.6	738.9	2,091.1	2,008.4
Distributions received on earnings from unconsolidated affiliates			(648.4)	(1,570.1)
Net effect of changes in operating accounts and other operating activities			46.1	9.3
Net cash flows provided by operating activities			(602.2)	(1,560.8)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			0	0
Cash used for business combinations, net of cash received			0	0
Proceeds from asset sales			0	0
Other investing activities			1,931.4	953.4
Cash used in investing activities			1,931.4	953.4
Financing activities:
Borrowings under debt agreements			(41.4)	(77.9)
Repayments of debt			0	0
Cash distributions paid to owners			677.5	1,602.4
Cash payments made in connection with DERs			0	0
Cash distributions paid to noncontrolling interests			(29.1)	(32.4)
Cash contributions from noncontrolling interests			0	(0.4)
Net cash proceeds from issuance of common units			0	0
Cash contributions from owners			(1,890)	(875.1)
Other financing activities			0	0
Cash provided by (used in) financing activities			(1,283)	616.6
Net change in cash and cash equivalents			46.2	9.2
Cash and cash equivalents, beginning balance			(50.6)	(14.7)
Cash and cash equivalents, ending balance	(4.4)	(5.5)	(4.4)	(5.5)
Enterprise Products Partners L.P. (Guarantor) [Member]
Operating activities:
Net income	634.6	649.3	1,854.3	1,836.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion			0	0
Equity in income of unconsolidated affiliates	(642)	(653.2)	(1,884.4)	(1,852.6)
Distributions received on earnings from unconsolidated affiliates			2,477.3	2,241.1
Net effect of changes in operating accounts and other operating activities			22.9	12
Net cash flows provided by operating activities			2,470.1	2,236.9
Investing activities:
Capital expenditures, net of contributions in aid of construction costs			0	0
Cash used for business combinations, net of cash received			0	0
Proceeds from asset sales			0	0
Other investing activities			(2,161.2)	(1,005.2)
Cash used in investing activities			(2,161.2)	(1,005.2)
Financing activities:
Borrowings under debt agreements			0	0
Repayments of debt			0	0
Cash distributions paid to owners			(2,448.3)	(2,185.1)
Cash payments made in connection with DERs			(8.5)	(5.6)
Cash distributions paid to noncontrolling interests			0	0
Cash contributions from noncontrolling interests			0	0
Net cash proceeds from issuance of common units			2,170.4	1,011.4
Cash contributions from owners			0	0
Other financing activities			(22.5)	(52.4)
Cash provided by (used in) financing activities			(308.9)	(1,231.7)
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	$ 0	$ 0