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Document and Entity Information - shares	3 Months Ended
Document and Entity Information - shares	Mar. 31, 2017	Apr. 28, 2017
Document and Entity Information [Abstract]
Entity Registrant Name	ENTERPRISE PRODUCTS PARTNERS L P
Entity Central Index Key	0001061219
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		2,141,588,793
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2017

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 62.4	$ 63.1
Restricted cash	44.7	354.5
Accounts receivable - trade, net of allowance for doubtful accounts of $12.3 at March 31, 2017 and $11.3 at December 31, 2016	3,152.8	3,329.5
Accounts receivable - related parties	1.6	1.1
Inventories	1,922.0	1,770.5
Derivative assets	40.4	541.4
Prepaid and other current assets	417.6	468.1
Total current assets	5,641.5	6,528.2
Property, plant and equipment, net	33,556.1	33,292.5
Investments in unconsolidated affiliates	2,671.4	2,677.3
Intangible assets, net of accumulated amortization of $1,444.1 at March 31, 2017 and $1,403.1 at December 31, 2016	3,823.1	3,864.1
Goodwill	5,745.2	5,745.2
Other assets	92.2	86.7
Total assets	51,529.5	52,194.0
Current liabilities:
Current maturities of debt	2,300.0	2,576.8
Accounts payable - trade	526.1	397.7
Accounts payable - related parties	50.1	105.1
Accrued product payables	3,618.2	3,613.7
Accrued interest	202.8	340.8
Derivative liabilities	43.8	737.7
Other current liabilities	307.0	478.7
Total current liabilities	7,048.0	8,250.5
Long-term debt	21,123.0	21,120.9
Deferred tax liabilities	52.6	52.7
Other long-term liabilities	505.9	503.9
Commitments and contingencies
Limited partners:
Common units (2,136,371,658 units outstanding at March 31, 2017 and 2,117,588,414 units outstanding at December 31, 2016)	22,695.5	22,327.0
Accumulated other comprehensive loss	(116.2)	(280.0)
Total partners' equity	22,579.3	22,047.0
Noncontrolling interests	220.7	219.0
Total equity	22,800.0	22,266.0
Total liabilities and equity	$ 51,529.5	$ 52,194.0

UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Current assets:
Accounts receivable, allowance for doubtful accounts	$ 12.3	$ 11.3
Intangible assets, accumulated amortization	$ 1,444.1	$ 1,403.1
Limited partners:
Common units outstanding (in units)	2,136,371,658	2,117,588,414

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Revenues:
Third parties	$ 7,309.6	$ 4,989.7
Related parties	10.8	15.6
Total revenues	7,320.4	5,005.3
Operating costs and expenses:
Third parties	6,081.6	3,866.3
Related parties	251.6	280.6
Total operating costs and expenses	6,333.2	4,146.9
General and administrative costs:
Third parties	20.7	14.3
Related parties	29.7	29.6
Total general and administrative costs	50.4	43.9
Total costs and expenses	6,383.6	4,190.8
Equity in income of unconsolidated affiliates	94.8	101.1
Operating income	1,031.6	915.6
Other income (expense):
Interest expense	(249.3)	(240.6)
Other, net	(5.3)	3.6
Total other expense, net	(254.6)	(237.0)
Income before income taxes	777.0	678.6
Provision for income taxes	(6.0)	(8.4)
Net income	771.0	670.2
Net income attributable to noncontrolling interests	(10.3)	(9.0)
Net income attributable to limited partners	$ 760.7	$ 661.2
Earnings per unit:
Basic earnings per unit (in dollars per unit)	$ 0.36	$ 0.32
Diluted earnings per unit (in dollars per unit)	$ 0.36	$ 0.32

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
STATEMENTS OF UNAUDITED CONSOLIDATED COMPREHENSIVE INCOME
Net income	$ 771.0	$ 670.2
Commodity derivative instruments:
Changes in fair value of cash flow hedges	144.8	(1.2)
Reclassification of losses (gains) to net income	7.1	(57.2)
Interest rate derivative instruments:
Changes in fair value of cash flow hedges	2.4	0.0
Reclassification of losses to net income	9.6	9.2
Total cash flow hedges	163.9	(49.2)
Other	(0.1)	(0.1)
Total other comprehensive income (loss)	163.8	(49.3)
Comprehensive income	934.8	620.9
Comprehensive income attributable to noncontrolling interests	(10.3)	(9.0)
Comprehensive income attributable to limited partners	$ 924.5	$ 611.9

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating activities:
Net income	$ 771.0	$ 670.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	402.3	382.1
Asset impairment and related charges	11.2	1.7
Equity in income of unconsolidated affiliates	(94.8)	(101.1)
Distributions received on earnings from unconsolidated affiliates	90.5	106.7
Net losses (gains) attributable to asset sales	(0.3)	4.9
Deferred income tax expense	0.1	4.1
Change in fair market value of derivative instruments	(20.3)	20.1
Change in fair market value of Liquidity Option Agreement	5.5	(2.2)
Net effect of changes in operating accounts	(288.8)	(186.4)
Other operating activities	(0.8)	(0.4)
Net cash flows provided by operating activities	875.6	899.7
Investing activities:
Capital expenditures	(446.0)	(1,007.2)
Contributions in aid of construction costs	15.6	12.2
Decrease (increase) in restricted cash	309.8	(121.0)
Cash used for pending business combination	(16.0)	0.0
Investments in unconsolidated affiliates	(13.7)	(70.4)
Distributions received for return of capital from unconsolidated affiliates	12.0	9.1
Proceeds from asset sales	2.0	13.4
Other investing activities	2.1	0.0
Cash used in investing activities	(134.2)	(1,163.9)
Financing activities:
Borrowings under debt agreements	17,575.1	20,000.6
Repayments of debt	(17,856.5)	(19,797.4)
Cash distributions paid to limited partners	(869.0)	(788.3)
Cash payments made in connection with distribution equivalent rights	(3.2)	(2.0)
Cash distributions paid to noncontrolling interests	(10.1)	(8.7)
Cash contributions from noncontrolling interests	0.2	11.1
Net cash proceeds from the issuance of common units	448.8	1,011.5
Other financing activities	(27.4)	(21.0)
Cash provided by (used in) financing activities	(742.1)	405.8
Net change in cash and cash equivalents	(0.7)	141.6
Cash and cash equivalents, beginning balance	63.1	19.0
Cash and cash equivalents, ending balance	$ 62.4	$ 160.6

UNAUDITED CONDENSED STATEMENTS OF CONSOLIDATED EQUITY - USD ($) $ in Millions	Total	Accumulated Other Comprehensive Income (Loss) [Member]	Noncontrolling Interests [Member]	Limited Partners [Member]
Balance at Dec. 31, 2015	$ 20,501.1	$ (219.2)	$ 206.0	$ 20,514.3
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	670.2	0.0	9.0	661.2
Cash distributions paid to limited partners	(788.3)	0.0	0.0	(788.3)
Cash payments made in connection with distribution equivalent rights	(2.0)	0.0	0.0	(2.0)
Cash distributions paid to noncontrolling interests	(8.7)	0.0	(8.7)	0.0
Cash contributions from noncontrolling interests	11.1	0.0	11.1	0.0
Net cash proceeds from the issuance of common units	1,011.5	0.0	0.0	1,011.5
Amortization of fair value of equity-based awards	22.3	0.0	0.0	22.3
Cash flow hedges	(49.2)	(49.2)	0.0	0.0
Other	(21.7)	(0.1)	0.0	(21.6)
Balance at Mar. 31, 2016	21,346.3	(268.5)	217.4	21,397.4
Balance at Dec. 31, 2016	22,266.0	(280.0)	219.0	22,327.0
Increase (Decrease) in Partners' Capital [Roll Forward]
Net income	771.0	0.0	10.3	760.7
Cash distributions paid to limited partners	(869.0)	0.0	0.0	(869.0)
Cash payments made in connection with distribution equivalent rights	(3.2)	0.0	0.0	(3.2)
Cash distributions paid to noncontrolling interests	(10.1)	0.0	(10.1)	0.0
Cash contributions from noncontrolling interests	0.2	0.0	0.2	0.0
Net cash proceeds from the issuance of common units	448.8	0.0	0.0	448.8
Common units issued in connection with employee compensation	33.7	0.0	0.0	33.7
Amortization of fair value of equity-based awards	24.8	0.0	0.0	24.8
Cash flow hedges	163.9	163.9	0.0	0.0
Other	(26.1)	(0.1)	1.3	(27.3)
Balance at Mar. 31, 2017	$ 22,800.0	$ (116.2)	$ 220.7	$ 22,695.5

Partnership Operations, Organization and Basis for Presentation	3 Months Ended
	Mar. 31, 2017
Partnership Operations and Organization [Abstract]
Partnership Operations and Organization	With the exception of per unit amounts, or as noted within the context of each disclosure, the dollar amounts presented in the tabular data within these disclosures are stated in millions of dollars. KEY REFERENCES USED IN THESE 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% of our limited partner interests at March 31, 2017. References to "Oiltanking acquisition" mean the two-step acquisition of Oiltanking Partners, L.P. and its general partner that was completed in February 2015. References to "TEPPCO" mean TEPPCO Partners, L.P. prior to its merger with one of our wholly owned subsidiaries in October 2009. Note 1. Partnership Operations, Organization and Basis of Presentation We are a publicly traded Delaware limited partnership, the common units of which are listed on the New York Stock Exchange ("NYSE") under the ticker symbol "EPD." We were formed in April 1998 to own and operate certain natural gas liquids ("NGLs") related businesses of EPCO and are a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, petrochemicals and refined products. Our integrated midstream energy asset network links producers of natural gas, NGLs and crude oil from some of the largest supply basins in the United States ("U.S."), Canada and 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 export and import terminals (including those used to export liquefied petroleum gases, or "LPG," and ethane); crude oil gathering, transportation, storage, and export and import terminals; petrochemical and refined products transportation, storage, export and import 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 50,000 miles of pipelines; 260 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 operations are reported under four business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services and (iv) Petrochemical & Refined Products Services. See Note 9 for information regarding our business segments.

General Accounting and Disclosure Matters	3 Months Ended
General Accounting and Disclosure Matters	Mar. 31, 2017
General Accounting Matters [Abstract]
General Accounting Matters	Note 2. General Accounting and Disclosure Matters Our results of operations for the three months ended March 31, 2017 are not necessarily indicative of results expected for the full year of 2017. 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, 2016 (the "2016 Form 10-K") filed with the SEC on February 24, 2017. 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. Recent Accounting Developments Revenue Recognition. In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Codification 606, Revenues from Contracts with Customers ("ASC 606"). The new accounting standard, along with its related amendments, replaces the current rules-based U.S. GAAP governing revenue recognition with a principles-based approach. We plan to adopt the new standard on January 1, 2018 using the modified retrospective approach, which requires us to apply the new revenue standard to (i) all new revenue contracts entered into after January 1, 2018 and (ii) all existing revenue contracts as of January 1, 2018 through a cumulative adjustment to equity. In accordance with this approach, our consolidated revenues for periods prior to January 1, 2018 will not be revised. The core principle in the new guidance is that a company should recognize revenue in a manner that fairly depicts the transfer of goods or services to customers in amounts that reflect the consideration the company expects to receive for those goods or services. In order to apply this core principle, companies will apply the following five steps in determining the amount of revenues to recognize: (i) identify the contract; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when (or as) the performance obligation is satisfied. Each of these steps involves management's judgment and an analysis of the contract's material terms and conditions. Our implementation activities related to ASC 606 are ongoing. For the vast majority of our businesses, we do not anticipate that there will be material differences in the amount or timing of revenues recognized following the new standard's adoption date. However, we continue to evaluate the guidance under ASC 606 applicable to natural gas processing agreements where non-cash consideration is received for services rendered (e.g., equity NGL volumes received under percent of liquids, keepwhole and similar arrangements). Although total consolidated revenues may not be materially impacted by the new guidance, we do anticipate significant changes to our disclosures based on the additional requirements prescribed by ASC 606. These new disclosures include information regarding the significant judgments used in evaluating when and how revenue is (or will be) recognized and data related to contract assets and liabilities. Additionally, we are currently evaluating our business processes, systems and controls to ensure the accuracy and timeliness of the recognition and disclosure requirements under the new revenue guidance. Leases. In February 2016, the FASB issued ASC 842, Leases ("ASC 842"), which requires substantially all leases (with the exception of leases with a term of one year or less) to be recorded on the balance sheet using a method referred to as the right-of-use ("ROU") asset approach. We plan to adopt the new standard on January 1, 2019 using the modified retrospective method described within ASC 842. The new standard introduces two lease accounting models, which result in a lease being classified as either a "finance" or "operating" lease on the basis of whether the lessee effectively obtains control of the underlying asset during the lease term. A lease would be classified as a finance lease if it meets one of five classification criteria, four of which are generally consistent with current lease accounting guidance. By default, a lease that does not meet the criteria to be classified as a finance lease will be deemed an operating lease. Regardless of classification, the initial measurement of both lease types will result in the balance sheet recognition of a ROU asset representing a company's right to use the underlying asset for a specified period of time and a corresponding lease liability. The lease liability will be recognized at the present value of the future lease payments, and the ROU asset will equal the lease liability adjusted for any prepaid rent, lease incentives provided by the lessor, and any indirect costs. The subsequent measurement of each type of lease varies. Leases classified as a finance lease will be accounted for using the effective interest method. Under this approach, a lessee will amortize the ROU asset (generally on a straight-line basis in a manner similar to depreciation) and the discount on the lease liability (as a component of interest expense). Leases classified as an operating lease will result in the recognition of a single lease expense amount that is recorded on a straight-line basis (or another systematic basis, if more appropriate). We have started the process of reviewing our lease agreements in light of the new guidance. Although we are in the early stages of our ASC 842 implementation project, we anticipate that this new lease guidance will cause significant changes to the way leases are recorded, presented and disclosed in our consolidated financial statements. 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 March 31, 2017 and December 31, 2016, our restricted cash amounts were $44.7 million and $354.5 million, respectively. The balance of restricted cash decreased since December 31, 2016 primarily due to the settlement of derivative instruments related to contango positions during the first quarter of 2017. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories

3 Months Ended

Mar. 31, 2017

Inventories [Abstract]

Inventories

Note 3. Inventories

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

	March 31, 2017		December 31, 2016
NGLs	$	1,107.5	$	1,156.1
Petrochemicals and refined products		474.2		220.7
Crude oil		319.5		360.0
Natural gas		20.8		33.7
Total	$	1,922.0	$	1,770.5

Inventories of petrochemicals and refined products increased since December 31, 2016 primarily due to our marketing group acquiring additional volumes during the first quarter of 2017 to take advantage of contango opportunities using our storage assets. These contango positions are expected to settle during the second quarter of 2017. Inventories of our other products decreased since December 31, 2016 primarily due to the settlement of contango positions in these products during the first quarter of 2017.

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 net realizable value adjustments for the periods indicated:

	For the Three Months Ended March 31,
	2017		2016
Cost of sales (1)	$	5,335.7	$	3,208.3
Lower of cost or net realizable value adjustments within cost of sales		3.4		5.3

(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

3 Months Ended

Mar. 31, 2017

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Note 4. Property, Plant and Equipment

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

	Estimated Useful Life in Years	March 31, 2017		December 31, 2016
Plants, pipelines and facilities (1)	3-45 (5)	$	35,382.6	$	35,124.6
Underground and other storage facilities (2)	5-40 (6)		3,352.8		3,326.9
Transportation equipment (3)	3-10		169.2		165.8
Marine vessels (4)	15-30		801.2		800.7
Land			265.1		264.6
Construction in progress			3,565.8		3,320.7
Total			43,536.7		43,003.3
Less accumulated depreciation			9,980.6		9,710.8
Property, plant and equipment, net		$	33,556.1	$	33,292.5

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

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

	For the Three Months Ended March 31,
	2017		2016
Depreciation expense (1)	$	317.5	$	295.9
Capitalized interest (2)		39.6		42.5

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

Asset Retirement Obligations

We record asset retirement obligations ("AROs") in connection with legal requirements to perform specified retirement activities under contractual arrangements and/or governmental regulations. Our contractual AROs primarily result from right-of-way agreements associated with our pipeline operations and real estate leases associated with our plant sites. In addition, we record AROs in connection with governmental regulations associated with the abandonment or retirement of above-ground brine storage pits and certain marine vessels. We also record AROs in connection with regulatory requirements associated with the renovation or demolition of certain assets containing hazardous substances such as asbestos. We typically fund our AROs using cash flow from operations.

Property, plant and equipment at March 31, 2017 and December 31, 2016 includes $44.2 million and $44.9 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 January 1, 2017:

ARO liability balance, January 1, 2017	$	85.4
Liabilities settled		(1.0	)
Accretion expense		1.3
ARO liability balance, March 31, 2017	$	85.7

Azure Acquisition

In March 2017, we announced the execution of a definitive agreement to acquire the midstream business and assets of Azure Midstream Partners, L.P. and its operating subsidiaries ("Azure"). The purchase agreement was the result of Azure's bankruptcy auction proceedings, which we won with a bid price of $189 million. The sale was approved by the U.S. Bankruptcy Court for the Southern District of Texas on March 15, 2017.

Azure's assets, which are located in East Texas and North Louisiana, include over 960 miles of natural gas gathering pipelines, three natural gas processing facilities with an aggregate processing capacity of approximately 210 million cubic feet per day, and two NGL pipelines with throughput capacities of 10 thousand barrels per day each. The Azure assets serve production from the Haynesville Shale and Bossier, Cotton Valley and Travis Peak formations.

The transaction closed in April 2017 after receiving final regulatory approvals and the satisfaction of other closing conditions. Under terms of the definitive agreement, we paid a deposit of $16.0 million in March 2017, which was applied to the purchase price of $189 million at closing. The deposit is presented on our Unaudited Condensed Statement of Consolidated Cash Flows under the Investing Activities section as "Cash used for pending business combination." The remainder of the accounting for the Azure acquisition, including development of the purchase price allocation, will take place during the second quarter of 2017 when the necessary information is obtained.

Investments in Unconsolidated Affiliates

3 Months Ended

Mar. 31, 2017

Investments in Unconsolidated Affiliates [Abstract]

Investments in Unconsolidated Affiliates

Note 5. Investments in Unconsolidated Affiliates

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

	Ownership Interest at March 31, 2017	March 31, 2017		December 31, 2016
NGL Pipelines & Services:
Venice Energy Service Company, L.L.C.	13.1%	$	24.7	$	24.8
K/D/S Promix, L.L.C.	50%		34.1		33.7
Baton Rouge Fractionators LLC	32.2%		17.5		17.3
Skelly-Belvieu Pipeline Company, L.L.C.	50%		38.7		38.9
Texas Express Pipeline LLC	35%		330.3		331.9
Texas Express Gathering LLC	45%		36.0		35.8
Front Range Pipeline LLC	33.3%		167.4		165.4
Delaware Basin Gas Processing LLC	50%		109.4		102.6
Crude Oil Pipelines & Services:
Seaway Crude Pipeline Company LLC	50%		1,386.5		1,393.8
Eagle Ford Pipeline LLC	50%		383.7		377.9
Eagle Ford Terminals Corpus Christi LLC	50%		57.8		52.9
Natural Gas Pipelines & Services:
White River Hub, LLC	50%		21.5		21.7
Petrochemical & Refined Products Services:
Centennial Pipeline LLC	50%		58.8		62.3
Other	Various		5.0		18.3
Total		$	2,671.4	$	2,677.3

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

	For the Three Months Ended March 31,
	2017			2016
NGL Pipelines & Services	$	15.5		$	15.1
Crude Oil Pipelines & Services		81.2			90.1
Natural Gas Pipelines & Services		1.0			1.0
Petrochemical & Refined Products Services		(2.9	)		(5.1	)
Total	$	94.8		$	101.1

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

	March 31, 2017		December 31, 2016
NGL Pipelines & Services	$	23.8	$	24.1
Crude Oil Pipelines & Services		18.8		19.0
Petrochemical & Refined Products Services		1.9		2.1
Total	$	44.5	$	45.2

In total, amortization of excess cost amounts was $0.5 million for each of the three months ended March 31, 2017 and 2016.

Summarized Combined Financial Information of Unconsolidated Affiliates

Combined results of operations data for the periods indicated for our unconsolidated affiliates are summarized in the following table (all data presented on a 100% basis):

	For the Three Months Ended March 31,
	2017		2016
Income Statement Data:
Revenues	$	343.2	$	345.5
Operating income		203.7		213.7
Net income		202.9		215.2

Intangible Assets and Goodwill

3 Months Ended

Mar. 31, 2017

Intangible Assets and Goodwill [Abstract]

Intangible Assets and Goodwill

Note 6. Intangible Assets and Goodwill

Identifiable Intangible Assets

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

	March 31, 2017							December 31, 2016
	Gross Value		Accumulated Amortization			Carrying Value		Gross Value		Accumulated Amortization			Carrying Value
NGL Pipelines & Services:
Customer relationship intangibles	$	447.4	$	(176.4	)	$	271.0	$	447.4	$	(172.7	)	$	274.7
Contract-based intangibles		279.9		(208.0	)		71.9		279.9		(204.4	)		75.5
Segment total		727.3		(384.4	)		342.9		727.3		(377.1	)		350.2
Crude Oil Pipelines & Services:
Customer relationship intangibles		2,204.4		(95.2	)		2,109.2		2,204.4		(84.5	)		2,119.9
Contract-based intangibles		281.0		(134.3	)		146.7		281.0		(121.9	)		159.1
Segment total		2,485.4		(229.5	)		2,255.9		2,485.4		(206.4	)		2,279.0
Natural Gas Pipelines & Services:
Customer relationship intangibles		1,350.3		(396.0	)		954.3		1,350.3		(390.0	)		960.3
Contract-based intangibles		464.7		(372.7	)		92.0		464.7		(370.5	)		94.2
Segment total		1,815.0		(768.7	)		1,046.3		1,815.0		(760.5	)		1,054.5
Petrochemical & Refined Products Services:
Customer relationship intangibles		185.5		(45.5	)		140.0		185.5		(43.9	)		141.6
Contract-based intangibles		54.0		(16.0	)		38.0		54.0		(15.2	)		38.8
Segment total		239.5		(61.5	)		178.0		239.5		(59.1	)		180.4
Total intangible assets	$	5,267.2	$	(1,444.1	)	$	3,823.1	$	5,267.2	$	(1,403.1	)	$	3,864.1

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

	For the Three Months Ended March 31,
	2017		2016
NGL Pipelines & Services	$	7.3	$	7.8
Crude Oil Pipelines & Services		23.1		27.7
Natural Gas Pipelines & Services		8.2		8.6
Petrochemical & Refined Products Services		2.4		2.2
Total	$	41.0	$	46.3

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

Remainder of 2017				2018				2019				2020				2021
$	121.1			$	163.8			$	157.7			$	152.8			$	163.2

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, 2016	$	2,651.7	$	1,841.0	$	296.3	$	956.2	$	5,745.2
Balance at March 31, 2017	$	2,651.7	$	1,841.0	$	296.3	$	956.2	$	5,745.2

- Definition

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

+ References + Details

Debt Obligations

3 Months Ended

Mar. 31, 2017

Debt Obligations [Abstract]

Debt Obligations

Note 7. Debt Obligations

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

	March 31, 2017			December 31, 2016
EPO senior debt obligations:
Commercial Paper Notes, variable-rates	$	1,500.4		$	1,777.2
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			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			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			975.0
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		22,150.4			22,427.2
EPO Junior Subordinated Notes A, variable-rate, due August 2066 (1)		521.1			521.1
EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 (2)		256.4			256.4
EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 (3)		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		23,624.8			23,901.6
Other, non-principal amounts		(201.8	)		(203.9	)
Less current maturities of debt		(2,300.0	)		(2,576.8	)
Total long-term debt	$	21,123.0		$	21,120.9

(1)Variable rate is reset quarterly and 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, a variable rate reset quarterly and 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 reset quarterly and based on 3-month LIBOR plus 2.680%.

The following table presents the range of interest rates and weighted-average interest rates paid on our consolidated variable-rate debt during the three months ended March 31, 2017:

	Range of Interest Rates Paid	Weighted-Average Interest Rate Paid
Commercial Paper Notes	0.90% to 1.33%	1.10%
EPO Junior Subordinated Notes A	4.59% to 4.74%	4.69%

The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at March 31, 2017 for the next five years, and in total thereafter:

			Scheduled Maturities of Debt
	Total		Remainder of 2017		2018		2019		2020		2021		Thereafter
Commercial Paper Notes	$	1,500.4	$	1,500.4	$	--	$	--	$	--	$	--	$	--
Senior Notes		20,650.0		800.0		1,100.0		1,500.0		1,500.0		575.0		15,175.0
Junior Subordinated Notes		1,474.4		--		--		--		--		--		1,474.4
Total	$	23,624.8	$	2,300.4	$	1,100.0	$	1,500.0	$	1,500.0	$	575.0	$	16,649.4

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.

Letters of Credit

At March 31, 2017, EPO had $66.4 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 March 31, 2017.

Equity and Distributions

3 Months Ended

Mar. 31, 2017

Equity and Distributions [Abstract]

Equity and Distributions

Note 8. Equity and Distributions

Partners' Equity

Partners' equity reflects the various classes of limited partner interests (i.e., common units, including restricted common units) outstanding. The following table summarizes changes in the number of our outstanding units from January 1, 2017 to March 31, 2017:

	Common Units (Unrestricted)			Restricted Common Units			Total Common Units
Number of units outstanding at January 1, 2017		2,116,906,120			682,294			2,117,588,414
Common units issued in connection with ATM program		12,865,371			--			12,865,371
Common units issued in connection with DRIP and EUPP		3,440,559			--			3,440,559
Common units issued in connection with the vesting of phantom unit awards		2,234,067			--			2,234,067
Common units issued in connection with the vesting of restricted common unit awards		665,920			(665,920	)		--
Forfeiture of restricted common unit awards		--			(1,250	)		(1,250	)
Cancellation of treasury units acquired in connection with the vesting of equity-based awards		(946,291	)		--			(946,291	)
Common units issued in connection with employee compensation		1,176,103			--			1,176,103
Other		14,685			--			14,685
Number of units outstanding at March 31, 2017		2,136,356,534			15,124			2,136,371,658

The net cash proceeds we received from the issuance of common units during the three months ended March 31, 2017 were used to temporarily reduce 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. We have a universal shelf registration statement (the "2016 Shelf") on file with the SEC. The 2016 Shelf allows Enterprise Products Partners L.P. and EPO (each on a standalone basis) to issue an unlimited amount of equity and debt securities, respectively.

At-the-Market ("ATM") program. We have a registration statement on file 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 in connection with our ATM program. Pursuant to this program, we may sell common units under an equity distribution agreement between Enterprise Products Partners L.P. and certain broker-dealers from time-to-time by means of ordinary brokers' transactions through the NYSE at market prices, in block transactions or as otherwise agreed to with the broker-dealer parties to the agreement.

During the three months ended March 31, 2017, we sold 12,865,371 common units under the ATM program for aggregate gross proceeds of $359.7 million. After taking into account applicable costs, our transactions under the ATM program resulted in aggregate net cash proceeds of $356.0 million during the three months ended March 31, 2017. During the three months ended March 31, 2016, we issued 35,396,147 common units under this program for aggregate gross cash proceeds of $856.5 million, resulting in total net cash proceeds of $849.0 million. This includes 3,830,256 common units sold in January 2016 to a privately held affiliate of EPCO, which generated gross proceeds of $100 million. After taking into account the aggregate sales price of common units sold under the ATM program through March 31, 2017, we have the capacity to issue additional common units under the ATM program up to an aggregate sales price of $1.08 billion.

Distribution reinvestment plan. We also have registration statements on file with the SEC collectively authorizing the issuance of up to 240,000,000 of our common units in connection with a distribution reinvestment plan ("DRIP"). The DRIP provides unitholders of record and beneficial owners of our common units a voluntary means by which they can increase the number of our common units they own by reinvesting the quarterly cash distributions they receive from us into the purchase of additional new common units.

We issued a total of 3,325,798 common units under our DRIP during the three months ended March 31, 2017, which generated net cash proceeds of $89.6 million. During the three months ended March 31, 2016, we issued 7,162,744 common units under our DRIP, which generated net cash proceeds of $159.8 million. Privately held affiliates of EPCO reinvested $100 million through the DRIP during the three months ended March 31, 2016 (this amount being a component of the net cash proceeds presented).

After taking into account the number of common units issued under the DRIP through March 31, 2017, we have the capacity to issue an additional 95,932,697 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 114,761 common units under our EUPP during the three months ended March 31, 2017, which generated net cash proceeds of $3.2 million. During the three months ended March 31, 2016, we issued 119,262 common units under our EUPP, which generated net cash proceeds of $2.7 million. After taking into account the number of common units issued under the EUPP through March 31, 2017, we may issue an additional 6,150,714 common units under this plan.

Common units issued in connection with employee compensation. In February 2017, the dollar value of the discretionary employee bonus payments with respect to the year ended December 31, 2016 (less any retirement plan deductions and withholding taxes) was remitted through the issuance of an equivalent value of newly issued Enterprise common units. The compensation expense associated with this issuance of common units was recognized during the year ended December 31, 2016.

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 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, January 1, 2017	$	(83.8	)	$	(199.8	)	$	3.6		$	(280.0	)
Other comprehensive income (loss) before reclassifications		144.8			2.4			(0.1	)		147.1
Amounts reclassified from accumulated other comprehensive loss (income)		7.1			9.6			--			16.7
Total other comprehensive income (loss)		151.9			12.0			(0.1	)		163.8
Balance, March 31, 2017	$	68.1		$	(187.8	)	$	3.5		$	(116.2	)

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other			Total
Balance, January 1, 2016	$	56.6		$	(279.5	)	$	3.7		$	(219.2	)
Other comprehensive loss before reclassifications		(1.2	)		--			(0.1	)		(1.3	)
Amounts reclassified from accumulated other comprehensive loss (income)		(57.2	)		9.2			--			(48.0	)
Total other comprehensive income (loss)		(58.4	)		9.2			(0.1	)		(49.3	)
Balance, March 31, 2016	$	(1.8	)	$	(270.3	)	$	3.6		$	(268.5	)

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

		For the Three Months Ended March 31,
	Location	2017			2016
Losses (gains) on cash flow hedges:
Interest rate derivatives	Interest expense	$	9.6		$	9.2
Commodity derivatives	Revenue		7.5			(58.8	)
Commodity derivatives	Operating costs and expenses		(0.4	)		1.6
Total		$	16.7		$	(48.0	)

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
2016
1st Quarter	$	0.3950	4/29/2016	5/6/2016
2017
1st Quarter	$	0.4150	4/28/2017	5/8/2017

- Definition

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

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 310
-SubTopic 10
-Section S99
-Paragraph 4
-Subparagraph (SAB Topic 4.E)
-URI http://asc.fasb.org/extlink&oid=27010918&loc=d3e74567-122707

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

Reference 3: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
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-Subparagraph (SX 210.5-02(29))
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Reference 4: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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-URI http://asc.fasb.org/extlink&oid=6928386&loc=d3e21488-112644

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 235
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.4-08(e))
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Reference 6: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
-SubTopic 10
-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02(31))
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 7: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section S99
-Paragraph 4
-Subparagraph (SAB Topic 4.C)
-URI http://asc.fasb.org/extlink&oid=27012166&loc=d3e187143-122770

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 210
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-Section S99
-Paragraph 1
-Subparagraph (SX 210.5-02(30))
-URI http://asc.fasb.org/extlink&oid=6877327&loc=d3e13212-122682

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 505
-SubTopic 10
-Section 50
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+ Details

Business Segments

3 Months Ended

Mar. 31, 2017

Business Segments [Abstract]

Business Segments

Note 9. Business Segments

Our operations are reported under four business segments: (i) NGL Pipelines & Services, (ii) Crude Oil Pipelines & Services, (iii) Natural Gas Pipelines & Services and (iv) Petrochemical & Refined Products Services.

Our business segments are generally organized and managed according to the types of services rendered (or technologies employed) and products produced and/or sold. 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 Gross Operating Margin

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. 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.

The following table presents our measurement of total segment gross operating margin for the periods presented. The GAAP financial measure most directly comparable to total segment gross operating margin is operating income.

	For the Three Months Ended March 31,
	2017			2016
Income before income taxes	$	777.0		$	678.6
Add total other expense, net		254.6			237.0
Operating income		1,031.6			915.6
Adjustments to reconcile operating income to total gross operating margin:
Add depreciation, amortization and accretion expense in operating costs and expenses		376.2			358.2
Add asset impairment and related charges in operating costs and expenses		11.2			1.7
Add net losses and subtract net gains attributable to asset sales in operating costs and expenses		(0.3	)		4.9
Add general and administrative costs		50.4			43.9
Adjustments for make-up rights on certain new pipeline projects:
Add non-refundable payments received from shippers attributable to make-up rights (1)		13.3			7.1
Subtract the subsequent recognition of revenues attributable to make-up rights (2)		(9.1	)		(12.9	)
Total segment gross operating margin	$	1,473.3		$	1,318.5

(1)Since make-up rights entail a future performance obligation by the pipeline to the shipper, these receipts are recorded as deferred revenue for GAAP purposes; however, these receipts are included in gross operating margin in the period of receipt since they are nonrefundable to the shipper. (2)As deferred revenues attributable to make-up rights are subsequently recognized as revenue under GAAP, gross operating margin must be adjusted to remove such amounts to prevent duplication since the associated non-refundable payments were previously included in gross operating margin.

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 in the preceding table, as applicable, and before the elimination of intercompany transactions. The following table presents gross operating margin by segment for the periods indicated:

	For the Three Months Ended March 31,
	2017		2016
Gross operating margin by segment:
NGL Pipelines & Services	$	856.0	$	783.7
Crude Oil Pipelines & Services		264.6		202.3
Natural Gas Pipelines & Services		170.9		177.7
Petrochemical & Refined Products Services		181.8		154.8
Total segment gross operating margin	$	1,473.3	$	1,318.5

Summarized Segment Financial Information

Information by business segment, together with reconciliations to amounts presented on our Unaudited Condensed Statements of Consolidated Operations, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Crude Oil Pipelines & Services		Natural Gas Pipelines & Services		Petrochemical & Refined Products Services			Adjustments and Eliminations			Consolidated Total
Revenues from third parties:
Three months ended March 31, 2017	$	3,343.0	$	1,802.6	$	757.8	$	1,406.2		$	--		$	7,309.6
Three months ended March 31, 2016		2,402.0		1,277.5		547.3		762.9			--			4,989.7
Revenues from related parties:
Three months ended March 31, 2017		2.8		4.6		3.4		--			--			10.8
Three months ended March 31, 2016		1.8		11.1		2.7		--			--			15.6
Intersegment and intrasegment revenues:
Three months ended March 31, 2017		8,874.8		3,474.0		194.5		414.7			(12,958.0	)		--
Three months ended March 31, 2016		3,174.8		1,499.4		124.7		242.7			(5,041.6	)		--
Total revenues:
Three months ended March 31, 2017		12,220.6		5,281.2		955.7		1,820.9			(12,958.0	)		7,320.4
Three months ended March 31, 2016		5,578.6		2,788.0		674.7		1,005.6			(5,041.6	)		5,005.3
Equity in income (loss) of unconsolidated affiliates:
Three months ended March 31, 2017		15.5		81.2		1.0		(2.9	)		--			94.8
Three months ended March 31, 2016		15.1		90.1		1.0		(5.1	)		--			101.1

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.

Information by business segment, together with reconciliations to our Unaudited Condensed Consolidated Balance Sheet totals, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Crude Oil Pipelines & Services		Natural Gas Pipelines & Services		Petrochemical & Refined Products Services		Adjustments and Eliminations		Consolidated Total
Property, plant and equipment, net: (see Note 4)
At March 31, 2017	$	14,003.1	$	4,346.9	$	8,355.6	$	3,284.7	$	3,565.8	$	33,556.1
At December 31, 2016		14,091.5		4,216.1		8,403.0		3,261.2		3,320.7		33,292.5
Investments in unconsolidated affiliates: (see Note 5)
At March 31, 2017		758.1		1,828.0		21.5		63.8		--		2,671.4
At December 31, 2016		750.4		1,824.6		21.7		80.6		--		2,677.3
Intangible assets, net: (see Note 6)
At March 31, 2017		342.9		2,255.9		1,046.3		178.0		--		3,823.1
At December 31, 2016		350.2		2,279.0		1,054.5		180.4		--		3,864.1
Goodwill: (see Note 6)
At March 31, 2017		2,651.7		1,841.0		296.3		956.2		--		5,745.2
At December 31, 2016		2,651.7		1,841.0		296.3		956.2		--		5,745.2
Segment assets:
At March 31, 2017		17,755.8		10,271.8		9,719.7		4,482.7		3,565.8		45,795.8
At December 31, 2016		17,843.8		10,160.7		9,775.5		4,478.4		3,320.7		45,579.1

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).

Other Revenue and Expense Information

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

	For the Three Months Ended March 31,
	2017			2016
NGL Pipelines & Services:
Sales of NGLs and related products	$	2,887.2		$	1,943.5
Midstream services		458.6			460.3
Total		3,345.8			2,403.8
Crude Oil Pipelines & Services:
Sales of crude oil		1,618.6			1,121.1
Midstream services		188.6			167.5
Total		1,807.2			1,288.6
Natural Gas Pipelines & Services:
Sales of natural gas		544.0			315.0
Midstream services		217.2			235.0
Total		761.2			550.0
Petrochemical & Refined Products Services:
Sales of petrochemicals and refined products		1,211.1			553.2
Midstream services		195.1			209.7
Total		1,406.2			762.9
Total consolidated revenues	$	7,320.4		$	5,005.3

Consolidated costs and expenses
Operating costs and expenses:
Cost of sales	$	5,335.7		$	3,208.3
Other operating costs and expenses (1)		610.4			573.8
Depreciation, amortization and accretion		376.2			358.2
Impairment and related charges		11.2			1.7
Net losses (gains) attributable to asset sales		(0.3	)		4.9
General and administrative costs		50.4			43.9
Total consolidated costs and expenses	$	6,383.6		$	4,190.8

(1)Represents the cost of operating our plants, pipelines and other fixed assets excluding: depreciation, amortization and accretion charges; asset impairment and related charges; 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.

- Definition

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

+ References

Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
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Reference 2: http://www.xbrl.org/2003/role/presentationRef
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+ Details

Earnings Per Unit

3 Months Ended

Mar. 31, 2017

Earnings Per Unit [Abstract]

Earnings Per Unit

Note 10. Earnings Per Unit

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

	For the Three Months Ended March 31,
	2017			2016
BASIC EARNINGS PER UNIT
Net income attributable to limited partners	$	760.7		$	661.2
Undistributed earnings allocated and cash payments on phantom unit awards (1)		(4.0	)		(3.2	)
Net income available to common unitholders	$	756.7		$	658.0

Basic weighted-average number of common units outstanding		2,126.2			2,033.6

Basic earnings per unit	$	0.36		$	0.32

DILUTED EARNINGS PER UNIT
Net income attributable to limited partners	$	760.7		$	661.2

Diluted weighted-average number of units outstanding:
Distribution-bearing common units		2,126.2			2,033.6
Phantom units (1)		8.7			6.9
Total		2,134.9			2,040.5

Diluted earnings per unit	$	0.36		$	0.32

(1) Each phantom unit award includes a distribution equivalent right ("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

3 Months Ended

Mar. 31, 2017

Equity-based Awards [Abstract]

Equity-based Awards

Note 11. Equity-Based Awards

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

	For the Three Months Ended March 31,
	2017		2016
Equity-classified awards:
Phantom unit awards	$	22.8	$	19.4
Restricted common unit awards		0.5		2.2
Profits interest awards		1.5		0.7
Liability-classified awards		0.2		0.1
Total	$	25.0	$	22.4

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

At March 31, 2017, all of the outstanding phantom unit awards were granted under EPCO's 2008 Enterprise Products Long-Term Incentive Plan (Third Amendment and Restatement) ("2008 Plan"). The maximum number of common units authorized for issuance under the 2008 Plan was 40,000,000 at March 31, 2017. This amount will automatically increase under the terms of the 2008 Plan by 5,000,000 common units on January 1, 2018 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 2008 Plan through March 31, 2017, a total of 18,863,972 additional common units were available for issuance under this plan.

EPCO serves as the general partner of four limited partnerships that were formed in 2016 (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").

At March 31, 2017, a small number of restricted common unit awards remained outstanding under the Enterprise Products 1998 Long-Term Incentive Plan ("1998 Plan"). The 1998 Plan is effectively closed and no new awards have been granted under this plan since 2014.

Phantom Unit Awards

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

At March 31, 2017, 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 (1)
Phantom unit awards at January 1, 2017		7,767,501		$	27.20
Granted (2)		4,203,510		$	28.87
Vested		(2,238,568	)	$	28.33
Forfeited		(41,684	)	$	28.19
Phantom unit awards at March 31, 2017		9,690,759		$	27.66

(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 2017 was $121.4 million based on a grant date market price of our common units of $28.87 per unit. An estimated annual forfeiture rate of 3.8% was applied to these awards.

The 2008 Plan provides for the issuance of DERs in connection with phantom unit awards. A DER entitles the participant to nonforfeitable cash payments equal to the product of the number of phantom unit awards outstanding for the participant and the cash distribution per common unit paid to our common unitholders. Cash payments made in connection with DERs are charged to partners' equity when the phantom unit award is expected to result in the issuance of common units; otherwise, such amounts are expensed.

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

	For the Three Months Ended March 31,
	2017		2016
Cash payments made in connection with DERs	$	3.2	$	2.0
Total intrinsic value of phantom unit awards that vested during period		63.2		36.3

For the EPCO group of companies, the unrecognized compensation cost associated with phantom unit awards was $166.1 million at March 31, 2017, of which our share of the cost is currently estimated to be $145.8 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 2.3 years.

Profits Interest Awards

In 2016, EPCO Holdings Inc. ("EPCO Holdings"), a privately held affiliate of EPCO, contributed a portion of the Enterprise common units it owned to each of the Employee Partnerships. 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.

The following table summarizes key elements of each Employee Partnership:

Employee Partnership	Enterprise Common Units owned by Employee Partnership	Class A Capital Base (1)	Class A Preference Return (2)		Expected Liquidation Date	Estimated Grant Date Fair Value of Profits Interest Awards (3)	Unrecognized Compensation Cost (4)

PubCo I	2,723,052 units	$63.7 million	$	0.39	Feb. 2020	$13.2 million	$9.6 million
PubCo II	2,834,198 units	$66.3 million	$	0.39	Feb. 2021	$14.7 million	$11.5 million
PubCo III	105,000 units	$2.5 million	$	0.39	Apr. 2020	$0.6 million	$0.4 million
PrivCo I	1,111,438 units	$26.0 million	$	0.39	Feb. 2021	$5.8 million	$1.0 million

(1)Represents fair market value of the Enterprise common units contributed to each Employee Partnership at the applicable contribution date. (2)Each quarter, the Class A limited partner in each Employee Partnership is paid a cash distribution equal to the product of (i) the number of common units owned by the Employee Partnership and (ii) the Class A Preference Return of $0.39 per unit (subject to equitable adjustment in order to reflect any equity split, equity distribution or dividend, reverse split, combination, reclassification, recapitalization or other similar event affecting such common units). To the extent that the Employee Partnership has cash remaining after making this quarterly payment to the Class A limited partner, the residual cash is distributed to the Class B limited partners on a quarterly basis. (3)Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates. (4)Represents our expected share of the unrecognized compensation cost at March 31, 2017. 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 2.9 years, 3.9 years, 3.0 years and 3.9 years, respectively.

The grant date fair value of each Employee Partnership is based on (i) the estimated value (as determined using a Black-Scholes option pricing model) of such Employee Partnership's assets that would be distributed to the Class B limited partners thereof upon liquidation and (ii) the value, based on a discounted cash flow analysis, of the residual quarterly cash amounts that such Class B limited partners are expected to receive over the life of the Employee Partnership.

The following table summarizes the assumptions we used in applying a Black-Scholes option pricing model to derive that portion of the estimated grant date fair value of the profits interest awards for each Employee Partnership:

	Expected	Risk-Free	Expected	Expected Unit
Employee	Life	Interest	Distribution	Price
Partnership	of Award	Rate	Yield	Volatility
PubCo I	4.0 years	0.9% to 1.1%	6.2% to 6.8%	29% to 40%
PubCo II	5.0 years	1.1% to 1.6%	6.1% to 6.8%	27% to 40%
PubCo III	4.0 years	1.0% to 1.4%	6.1% to 6.2%	31% to 40%
PrivCo I	5.0 years	1.2% to 1.6%	6.1% to 6.7%	28% 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.

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 (1)
Restricted common units at January 1, 2017		682,294		$	28.61
Vested		(665,920	)	$	28.56
Forfeited		(1,250	)	$	31.07
Restricted common units at March 31, 2017		15,124		$	30.74

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

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

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

	For the Three Months Ended March 31,
	2017			2016
Cash distributions paid to restricted common unitholders		$	0.3		$	0.8
Total intrinsic value of restricted common unit awards that vested during period			18.5			26.8

We expect to recognize our share of the unrecognized compensation cost for these awards by the end of 2017.

- Definition

The entire disclosure for compensation-related costs for equity-based compensation, which may include disclosure of policies, compensation plan details, allocation of equity compensation, incentive distributions, equity-based arrangements to obtain goods and services, deferred compensation arrangements, employee stock ownership plan details and employee stock purchase plan details.

+ References + Details

Derivative Instruments, Hedging Activities and Fair Value Measurements

3 Months Ended

Mar. 31, 2017

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

Derivative Instruments, Hedging Activities and Fair Value Measurements

Note 12. Derivative Instruments, Hedging Activities and Fair Value Measurements

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

Interest Rate Hedging Activities

We may utilize interest rate swaps, forward starting swaps and similar derivative instruments to manage our exposure to changes in interest rates charged on borrowings under certain consolidated debt agreements. This strategy may be used in controlling our overall cost of capital associated with such borrowings.

The following table summarizes our portfolio of interest rate swaps at March 31, 2017:

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 1.51%	Fair value hedge

The following table summarizes our portfolio of forward starting swaps at March 31, 2017:

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		$	275.0		5/2018	2.02%	Cash flow hedge

Commodity Hedging Activities

The prices of natural gas, NGLs, crude oil, petrochemicals and refined products are subject to fluctuations in response to changes in supply and demand, market conditions and a variety of additional factors that are beyond our control. In order to manage such price risks, we enter into commodity derivative instruments such as physical forward contracts, futures contracts, fixed-for-float swaps and basis swaps.

At March 31, 2017, 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 fixed-price sales 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.

The following table summarizes our portfolio of commodity derivative instruments outstanding at March 31, 2017 (volume measures as noted):

	Volume (1)		Accounting
Derivative Purpose	Current (2)	Long-Term (2)	Treatment
Derivatives designated as hedging instruments:
Natural gas processing:
Forecasted natural gas purchases for plant thermal reduction (Bcf)	14.9	n/a	Cash flow hedge
Forecasted sales of NGLs (MMBbls)	3.5	n/a	Cash flow hedge
Octane enhancement:
Forecasted purchases of NGLs (MMBbls)	0.5	n/a	Cash flow hedge
Forecasted sales of octane enhancement products (MMBbls)	0.8	n/a	Cash flow hedge
Natural gas marketing:
Forecasted purchases of natural gas for fuel (Bcf)	4.5	n/a	Cash flow hedge
Natural gas storage inventory management activities (Bcf)	4.5	n/a	Fair value hedge
NGL marketing:
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)	82.3	n/a	Cash flow hedge
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)	93.4	n/a	Cash flow hedge
Refined products marketing:
Forecasted purchases of refined products (MMBbls)	0.2	n/a	Cash flow hedge
Forecasted sales of refined products (MMBbls)	0.4	n/a	Cash flow hedge
Refined products inventory management activities (MMBbls)	5.4	n/a	Fair value hedge
Crude oil marketing:
Forecasted purchases of crude oil (MMBbls)	12.5	n/a	Cash flow hedge
Forecasted sales of crude oil (MMBbls)	21.2	n/a	Cash flow hedge
Derivatives not designated as hedging instruments:
Natural gas risk management activities (Bcf) (3,4)	188.6	21.7	Mark-to-market
NGL risk management activities (MMBbls) (4)	16.1	n/a	Mark-to-market
Refined products risk management activities (MMBbls) (4)	0.2	n/a	Mark-to-market
Crude oil risk management activities (MMBbls) (4)	25.2	10.4	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, September 2017 and March 2020, respectively. (3) Current and long-term volumes include 55.3 Bcf and 10.5 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.

On January 3, 2017, the Chicago Mercantile Exchange ("CME") modified its exchange rules to recharacterize daily variation margin amounts as "final settlement" values. The modified rule ("CME Rule 814") impacts derivative financial instruments traded on exchanges administered by the CME, including the New York Mercantile Exchange. As a result of this rule change, we began reporting the affected derivative instruments on a net basis on our balance sheet during the first quarter of 2017. The netting process results in the elimination of derivative assets, derivative liabilities and associated restricted cash and related amounts with each other as if the underlying derivative instruments had settled on the balance sheet date. Historically through December 31, 2016, we reported such derivatives on a gross basis (i.e., not netted).

Derivative transactions cleared on exchanges other than the CME (e.g., the Intercontinental Exchange or ICE) continue to be reported on a gross basis.

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

Derivative Instruments and Related Hedged Items

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

	Asset Derivatives						Liability Derivatives
	March 31, 2017			December 31, 2016			March 31, 2017			December 31, 2016
	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	$	0.7	Current assets	$	0.3	Current liabilities	$	1.7	Current liabilities	$	0.2
Interest rate derivatives	Other assets		38.6	Other assets		36.2	Other liabilities		0.3	Other liabilities		0.9
Total interest rate derivatives			39.3			36.5			2.0			1.1
Commodity derivatives	Current assets		34.1	Current assets		499.2	Current liabilities		30.0	Current liabilities		662.0
Commodity derivatives	Other assets		--	Other assets		--	Other liabilities		--	Other liabilities		--
Total commodity derivatives			34.1			499.2			30.0			662.0
Total derivatives designated as hedging instruments		$	73.4		$	535.7		$	32.0		$	663.1

Derivatives not designated as hedging instruments
Commodity derivatives	Current assets	$	5.6	Current assets	$	41.9	Current liabilities	$	12.1	Current liabilities	$	75.6
Commodity derivatives	Other assets		1.5	Other assets		0.3	Other liabilities		2.4	Other liabilities		1.8
Total commodity derivatives		$	7.1		$	42.2		$	14.5		$	77.4

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

	Offsetting of Financial Assets and Derivative Assets
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received		Cash Collateral Paid		Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of March 31, 2017:
Interest rate derivatives		$	39.3		$	--		$	39.3		$	(0.6	)	$	--	$	--		$	38.7
Commodity derivatives			41.2			--			41.2			(38.0	)		--		--			3.2
As of December 31, 2016:
Interest rate derivatives		$	36.5		$	--		$	36.5		$	(0.2	)	$	--	$	--		$	36.3
Commodity derivatives			541.4			--			541.4			(526.8	)		--		--			14.6

	Offsetting of Financial Liabilities and Derivative Liabilities
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet										Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received			Cash Collateral Paid			Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)										(v) = (iii) + (iv)
As of March 31, 2017:
Interest rate derivatives		$	2.0		$	--		$	2.0		$	(0.6	)	$	--		$	--			$	1.4
Commodity derivatives			44.5			--			44.5			(38.0	)		(3.2	)		--				3.3
As of December 31, 2016:
Interest rate derivatives		$	1.1		$	--		$	1.1		$	(0.2	)	$	--		$	--			$	0.9
Commodity derivatives			739.4			--			739.4			(526.8	)		--			(212.4	)			0.2

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

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

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	(0.9	)	$	6.1
Commodity derivatives	Revenue		18.8			(19.0	)
Total		$	17.9		$	(12.9	)

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Hedged Item
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	0.9		$	(6.2	)
Commodity derivatives	Revenue		(12.4	)		28.0
Total		$	(11.5	)	$	21.8

For the three months ended March 31, 2017, the net gain of $6.4 million recognized in income from our commodity derivatives designated as fair value hedges includes $0.6 million of net losses attributable to hedge ineffectiveness. The remaining $7.0 million of net gain recognized during the three months ended March 31, 2017 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 March 31,
	2017			2016
Interest rate derivatives	$	2.4		$	--
Commodity derivatives – Revenue (1)		147.6			3.3
Commodity derivatives – Operating costs and expenses (1)		(2.8	)		(4.5	)
Total	$	147.2		$	(1.2	)

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

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	(9.6	)	$	(9.2	)
Commodity derivatives	Revenue		(7.5	)		58.8
Commodity derivatives	Operating costs and expenses		0.4			(1.6	)
Total		$	(16.7	)	$	48.0

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)
		For the Three Months Ended March 31,
		2017			2016
Commodity derivatives	Operating costs and expenses	$	(1.0	)	$	--

Over the next twelve months, we expect to reclassify $41.4 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 $68.0 million of gains attributable to commodity derivative instruments from accumulated other comprehensive income to earnings, $67.5 million as an increase in revenue and $0.5 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 March 31,
		2017		2016
Commodity derivatives	Revenue	$	15.7	$	(1.3	)
Commodity derivatives	Operating costs and expenses		4.5		0.1
Total		$	20.2	$	(1.2	)

Fair Value Measurements

The following tables set forth, by level within the Level 1, 2 and 3 fair value hierarchy, the carrying values of our financial assets and liabilities at the dates indicated. These assets and liabilities are measured on a recurring basis and are classified based on the lowest level of input used to estimate their fair value. Our assessment of the relative significance of such inputs requires judgment.

The values for commodity derivatives at March 31, 2017 are presented before and after the application of CME Rule 814, which deems that financial instruments cleared by the CME are settled daily in connection with variation margin payments. As a result of this new exchange rule, CME-related derivatives are considered to have no fair value at the balance sheet date for financial reporting purposes; however, the derivatives remain outstanding and subject to future commodity price fluctuations until they are settled in accordance with their contractual terms.

	March 31, 2017 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	$	--		$	39.3		$	--	$	39.3
Commodity derivatives:
Value before application of CME Rule 814		57.6			174.3			1.5		233.4
Impact of CME Rule 814 change		(57.6	)		(134.6	)		--		(192.2	)
Total commodity derivatives		--			39.7			1.5		41.2
Total financial assets	$	--		$	79.0		$	1.5	$	80.5

Financial liabilities:
Liquidity Option Agreement	$	--		$	--		$	275.1	$	275.1
Interest rate derivatives		--			2.0			--		2.0
Commodity derivatives:
Value before application of CME Rule 814		35.4			172.9			0.8		209.1
Impact of CME Rule 814 change		(35.4	)		(129.2	)		--		(164.6	)
Total commodity derivatives		--			43.7			0.8		44.5
Total financial liabilities	$	--		$	45.7		$	275.9	$	321.6

	December 31, 2016 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	36.5	$	--	$	36.5
Commodity derivatives		84.5		455.2		1.7		541.4
Total financial assets	$	84.5	$	491.7	$	1.7	$	577.9

Financial liabilities:
Liquidity Option Agreement	$	--	$	--	$	269.6	$	269.6
Interest rate derivatives		--		1.1		--		1.1
Commodity derivatives		136.8		602.3		0.3		739.4
Total financial liabilities	$	136.8	$	603.4	$	269.9	$	1,010.1

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

		For the Three Months Ended March 31,
	Location	2017			2016
Financial liability balance, net, January 1		$	(268.2	)	$	(246.7	)
Total gains (losses) included in:
Net income (1)	Revenue		0.7			0.7
Net income	Other expense, net		(5.5	)		2.2
Other comprehensive income (loss)	Commodity derivative instruments – changes in fair value of cash flow hedges		--			1.5
Settlements	Revenue		(1.4	)		(0.1	)
Transfers out of Level 3			--			0.1
Financial liability balance, net, March 31		$	(274.4	)	$	(242.3	)

(1)There were unrealized losses of $0.6 million and unrealized gains of $0.6 million included in these amounts for the three months ended March 31, 2017 and 2016, respectively.

The following table provides quantitative information regarding our recurring Level 3 fair value measurements for commodity derivatives at March 31, 2017:

	Fair Value
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	1.5	$	0.8	Discounted cash flow	Forward commodity prices	$48.68-$51.93/barrel

With respect to commodity derivatives, we believe forward commodity prices are the most significant unobservable inputs in determining our Level 3 recurring fair value measurements at March 31, 2017. In general, changes in the price of the underlying commodity increases or decreases the fair value of a commodity derivative depending on whether the derivative was purchased or sold. We generally expect changes in the fair value of our derivative instruments to be offset by corresponding changes in the fair value of our hedged exposures.

Nonrecurring Fair Value Measurements

The following table summarizes our non-cash asset impairment charges for long-lived assets by segment during each of the periods indicated:

	For the Three Months Ended March 31,
	2017		2016
NGL Pipelines & Services	$	0.2	$	0.3
Crude Oil Pipelines & Services		--		0.2
Natural Gas Pipelines & Services		0.2		--
Petrochemical & Refined Products Services		--		0.1
Total	$	0.4	$	0.6

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

The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the three months ended March 31, 2017:

			Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at March 31, 2017		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

Total asset impairment and related charges during the three months ended March 31, 2017 were $11.2 million, which consisted of $0.4 million of impairment charges attributable to long-lived assets and $10.8 million of impairment charges attributable to the write-down of spare parts classified as current assets.

The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the three months ended March 31, 2016:

				Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at March 31, 2016			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Non-Cash Impairment Loss
Long-lived assets disposed of other than by sale		$	--		$	--		$	--		$	--		$	0.6

Total asset impairment and related charges during the three months ended March 31, 2016 were $1.7 million, which consisted of $0.6 million of impairment charges attributable to long-lived assets and $1.1 million of impairment charges attributable to the write-down of spare parts classified as current assets.

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 $21.98 billion and $21.95 billion at March 31, 2017 and December 31, 2016, respectively. The aggregate carrying value of these debt obligations was $20.85 billion at March 31, 2017 and December 31, 2016. 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" within this Note 12 for additional information. The carrying values of our variable-rate long-term debt obligations approximate their fair values since the associated interest rates are market-based. We do not have any long-term investments in debt or equity securities recorded at fair value.

Related Party Transactions

3 Months Ended

Mar. 31, 2017

Related Party Transactions

Note 13. Related Party Transactions

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

	For the Three Months Ended March 31,
	2017		2016
Revenues – related parties:
Unconsolidated affiliates	$	10.8	$	15.6
Costs and expenses – related parties:
EPCO and its privately held affiliates	$	243.1	$	237.3
Unconsolidated affiliates		38.2		72.9
Total	$	281.3	$	310.2

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

	March 31, 2017		December 31, 2016
Accounts receivable - related parties:
Unconsolidated affiliates	$	1.6	$	1.1

Accounts payable - related parties:
EPCO and its privately held affiliates	$	39.2	$	88.9
Unconsolidated affiliates		10.9		16.2
Total	$	50.1	$	105.1

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

Relationship with EPCO and Affiliates

We have an extensive and ongoing relationship with EPCO and its privately held affiliates (including Enterprise GP, our general partner), which are not a part of our consolidated group of companies.

At March 31, 2017, 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%

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 March 31, 2017. These credit facilities contain customary and other events of default, including defaults by us and other affiliates of EPCO. An event of default, followed by a foreclosure on the pledged collateral, could ultimately result in a change in ownership of these units and affect the market price of our common units.

We and Enterprise GP are both separate legal entities apart from each other and apart from EPCO and its other affiliates, with assets and liabilities that are also separate from those of EPCO and its other affiliates. EPCO and its privately held affiliates depend on the cash distributions they receive from us and other investments to fund their other activities and to meet their debt obligations. During the three months ended March 31, 2017 and 2016, we paid EPCO and its privately held affiliates cash distributions totaling $275.2 million and $260.1 million, respectively.

We have no employees. All of our operating functions and general and administrative support services are provided by employees of EPCO pursuant to the ASA or by other service providers. The following table presents our related party costs and expenses attributable to the ASA with EPCO for the periods indicated:

	For the Three Months Ended March 31,
	2017		2016
Operating costs and expenses	$	211.6	$	205.4
General and administrative expenses		26.8		27.3
Total costs and expenses	$	238.4	$	232.7

Commitments and Contingencies

3 Months Ended

Mar. 31, 2017

Commitments and Contingencies [Abstract]

Commitments and Contingencies

Note 14. Commitments and Contingencies

Litigation

As part of our normal business activities, we may be named as defendants in legal proceedings, including those arising from regulatory and environmental matters. Although we are insured against various risks to the extent we believe it is prudent, there is no assurance that the nature and amount of such insurance will be adequate, in every case, to fully indemnify us against losses arising from future legal proceedings. We will vigorously defend the partnership in litigation matters.

Management has regular quarterly litigation reviews, including updates from legal counsel, to assess the possible need for accounting recognition and disclosure of these contingencies. We accrue an undiscounted liability for those contingencies where the loss is probable and the amount can be reasonably estimated. If a range of probable loss amounts can be reasonably estimated and no amount within the range is a better estimate than any other amount, then the minimum amount in the range is accrued.

We do not record a contingent liability when the likelihood of loss is probable but the amount cannot be reasonably estimated or when the likelihood of loss is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is reasonably possible and the impact would be material to our consolidated financial statements, we disclose the nature of the contingency and, where feasible, an estimate of the possible loss or range of loss. Based on a consideration of all relevant known facts and circumstances, we do not believe that the ultimate outcome of any currently pending litigation directed against us will have a material impact on our consolidated financial statements either individually at the claim level or in the aggregate.

At March 31, 2017 and December 31, 2016, our accruals for litigation contingencies were $0.3 million and were recorded in our Unaudited Condensed Consolidated Balance Sheets as a component of "Other current liabilities." Our evaluation of litigation contingencies is based on the facts and circumstances of each case and predicting the outcome of these matters involves uncertainties. In the event the assumptions we use to evaluate these matters change in future periods or new information becomes available, we may be required to record additional accruals. In an effort to mitigate expenses associated with litigation, we may settle legal proceedings out of court.

ETP Matter. In connection with a proposed pipeline project, we and Energy Transfer Partners, L.P. ("ETP") signed a non-binding letter of intent in April 2011 that disclaimed any partnership or joint venture related to such project absent executed definitive documents and board approvals of the respective companies. Definitive agreements were never executed and board approval was never obtained for the potential pipeline project. In August 2011, the proposed pipeline project was cancelled due to a lack of customer support.

In September 2011, ETP filed suit against us and a third party in connection with the cancelled project alleging, among other things, that we and ETP had formed a "partnership." The case was tried in the District Court of Dallas County, Texas, 298th Judicial District. While we firmly believe, and argued during our defense, that no agreement was ever executed forming a legal joint venture or partnership between the parties, the jury found that the actions of the two companies, nevertheless, constituted a legal partnership. As a result, the jury found that ETP was wrongfully excluded from a subsequent pipeline project involving a third party, and awarded ETP $319.4 million in actual damages on March 4, 2014. On July 29, 2014, the court entered judgment against us in an aggregate amount of $535.8 million, which includes (i) $319.4 million as the amount of actual damages awarded by the jury, (ii) an additional $150.0 million in disgorgement for the alleged benefit we received due to a breach of fiduciary duties by us against ETP and (iii) prejudgment interest in the amount of $66.4 million. The court also awarded post-judgment interest on such aggregate amount, to accrue at a rate of 5%, compounded annually.

We do not believe that the verdict or the judgment entered against us is supported by the evidence or the law. We filed our Brief of the Appellant in the Court of Appeals for the Fifth District of Dallas, Texas on March 30, 2015 and ETP filed its Brief of Appellees on June 29, 2015. We filed our Reply Brief of Appellant on September 18, 2015. Oral argument was conducted on April 20, 2016, and the case has now been submitted to the Court of Appeals for its consideration. We intend to vigorously oppose the judgment through the appeals process. As of March 31, 2017, we have not recorded a provision for this matter as management believes payment of damages in this case is not probable.

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, 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. 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 $26.2 million and $28.5 million during the three months ended March 31, 2017 and 2016, respectively. Our operating lease commitments at March 31, 2017 did not differ materially from those reported in our 2016 Form 10-K.

Purchase Obligations. Our consolidated purchase obligations at March 31, 2017 did not differ materially from those reported in our 2016 Form 10-K.

Liquidity Option Agreement

We entered into a put option agreement (the "Liquidity Option Agreement" or "Liquidity Option") with Oiltanking Holding Americas, Inc. ("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. 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 carrying value of the Liquidity Option Agreement, which is a component of "Other long-term liabilities" on our Unaudited Condensed Consolidated Balance Sheet, was $275.1 million and $269.6 million at March 31, 2017 and December 31, 2016, respectively. 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 at March 31, 2017 is based on several inputs that are not observable in the market (i.e., Level 3 inputs) such as the following:

	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 March 31, 2017, we used a market rate commensurate with level of debt and tenure of approximately 4.85%. If the assumption of debt is excluded from the valuation model at March 31, 2017 (and all other inputs remained the same), the estimated fair value of the Liquidity Option would have increased by $229.1 million and resulted in the recognition of an equal amount of expense at the time of change;

	Forecasted annual growth rates of Enterprise's taxable earnings before interest, taxes, depreciation and amortization ranging from 0.1% to 13.6%;

	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 March 31, 2017, we used ownership interests ranging from 1.9% to 2.5%;

	OTA pays an aggregate federal and state income tax rate of 38% on its taxable income; and

	A discount rate of 7.7% based on our weighted-average cost of capital at March 31, 2017.

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 March 31, 2017, based on these scenarios, we expect that OTA would own approximately 85% of the 54,807,352 Enterprise common units it received in Step 1 when the option period begins in February 2020. If our valuation estimate had assumed that 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 at March 31, 2017 would have increased by $47.1 million.

Changes in the fair value of the Liquidity Option are recognized in earnings as a component of other income (expense) on our Unaudited Condensed Statements of Consolidated Operations. Results for the three months ended March 31, 2017 and 2016 include $5.5 million of expense and $2.2 million of benefit, respectively, of aggregate non-cash adjustments attributable to accretion and changes in management estimates regarding inputs to the valuation model.

Supplemental Cash Flow Information

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Information [Abstract]

Supplemental Cash Flow Information

Note 15. Supplemental Cash Flow Information

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

	For the Three Months Ended March 31,
	2017			2016
Decrease (increase) in:
Accounts receivable – trade	$	110.1		$	124.6
Accounts receivable – related parties		(0.6	)		0.4
Inventories		(71.9	)		(194.3	)
Prepaid and other current assets		249.0			5.3
Other assets		(2.2	)		1.3
Increase (decrease) in:
Accounts payable – trade		6.5			(64.8	)
Accounts payable – related parties		(21.1	)		(46.7	)
Accrued product payables		(16.8	)		228.7
Accrued interest		(137.9	)		(158.2	)
Other current liabilities		(400.2	)		(84.4	)
Other liabilities		(3.7	)		1.7
Net effect of changes in operating accounts	$	(288.8	)	$	(186.4	)

We incurred liabilities for construction in progress that had not been paid at March 31, 2017 and December 31, 2016 of $240.9 million and $124.3 million, respectively. Such amounts are not included under the caption "Capital expenditures" on the Unaudited Condensed Statements of Consolidated Cash Flows.

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

Condensed Consolidating Financial Information

3 Months Ended

Mar. 31, 2017

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Financial Information

Note 16. Condensed Consolidating Financial Information

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

EPO has issued publicly traded debt securities. As the parent company of EPO, Enterprise Products Partners L.P. guarantees substantially all of the debt obligations of EPO. If EPO were to default on any of its guaranteed debt, Enterprise Products Partners L.P. would be responsible for full and unconditional repayment of that obligation. See Note 7 for additional information regarding our consolidated debt obligations.

EPO's consolidated subsidiaries have no significant restrictions on their ability to pay distributions or make loans to Enterprise Products Partners L.P.

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

March 31, 2017

	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	$	45.0	$	67.9	$	(5.8	)	$	107.1	$	--	$	--		$	107.1
Accounts receivable – trade, net		1,231.3		1,922.2		(0.7	)		3,152.8		--		--			3,152.8
Accounts receivable – related parties		101.5		818.8		(918.7	)		1.6		6.6		(6.6	)		1.6
Inventories		1,548.3		374.1		(0.4	)		1,922.0		--		--			1,922.0
Derivative assets		37.1		3.3		--			40.4		--		--			40.4
Prepaid and other current assets		212.5		220.0		(14.9	)		417.6		--		--			417.6
Total current assets		3,175.7		3,406.3		(940.5	)		5,641.5		6.6		(6.6	)		5,641.5
Property, plant and equipment, net		4,972.2		28,582.3		1.6			33,556.1		--		--			33,556.1
Investments in unconsolidated affiliates		40,079.6		4,186.7		(41,594.9	)		2,671.4		22,847.6		(22,847.6	)		2,671.4
Intangible assets, net		696.0		3,141.3		(14.2	)		3,823.1		--		--			3,823.1
Goodwill		459.5		5,285.7		--			5,745.2		--		--			5,745.2
Other assets		228.1		42.8		(179.2	)		91.7		0.5		--			92.2
Total assets	$	49,611.1	$	44,645.1	$	(42,727.2	)	$	51,529.0	$	22,854.7	$	(22,854.2	)	$	51,529.5

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	2,299.9	$	0.1	$	--		$	2,300.0	$	--	$	--		$	2,300.0
Accounts payable – trade		221.5		310.2		(5.8	)		525.9		0.2		--			526.1
Accounts payable – related parties		894.4		98.3		(936.1	)		56.6		0.1		(6.6	)		50.1
Accrued product payables		1,980.4		1,638.9		(1.1	)		3,618.2		--		--			3,618.2
Accrued interest		202.5		0.3		--			202.8		--		--			202.8
Derivative liabilities		34.5		9.3		--			43.8		--		--			43.8
Other current liabilities		53.4		264.1		(11.0	)		306.5		--		0.5			307.0
Total current liabilities		5,686.6		2,321.2		(954.0	)		7,053.8		0.3		(6.1	)		7,048.0
Long-term debt		21,107.9		15.1		--			21,123.0		--		--			21,123.0
Deferred tax liabilities		4.4		45.0		(0.5	)		48.9		--		3.7			52.6
Other long-term liabilities		11.6		400.6		(181.4	)		230.8		275.1		--			505.9
Commitments and contingencies
Equity:
Partners' and other owners' equity		22,800.6		41,785.8		(41,764.2	)		22,822.2		22,579.3		(22,822.2	)		22,579.3
Noncontrolling interests		--		77.4		172.9			250.3		--		(29.6	)		220.7
Total equity		22,800.6		41,863.2		(41,591.3	)		23,072.5		22,579.3		(22,851.8	)		22,800.0
Total liabilities and equity	$	49,611.1	$	44,645.1	$	(42,727.2	)	$	51,529.0	$	22,854.7	$	(22,854.2	)	$	51,529.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

December 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	366.2	$	58.9	$	(7.5	)	$	417.6	$	--	$	--		$	417.6
Accounts receivable – trade, net		1,499.4		1,830.3		(0.2	)		3,329.5		--		--			3,329.5
Accounts receivable – related parties		131.5		961.4		(1,090.7	)		2.2		--		(1.1	)		1.1
Inventories		1,357.5		413.5		(0.5	)		1,770.5		--		--			1,770.5
Derivative assets		464.8		76.6		--			541.4		--		--			541.4
Prepaid and other current assets		290.7		191.1		(13.7	)		468.1		--		--			468.1
Total current assets		4,110.1		3,531.8		(1,112.6	)		6,529.3		--		(1.1	)		6,528.2
Property, plant and equipment, net		4,796.5		28,495.7		0.3			33,292.5		--		--			33,292.5
Investments in unconsolidated affiliates		39,995.5		4,227.9		(41,546.1	)		2,677.3		22,317.1		(22,317.1	)		2,677.3
Intangible assets, net		700.2		3,178.2		(14.3	)		3,864.1		--		--			3,864.1
Goodwill		459.5		5,285.7		--			5,745.2		--		--			5,745.2
Other assets		222.6		41.0		(177.5	)		86.1		0.6		--			86.7
Total assets	$	50,284.4	$	44,760.3	$	(42,850.2	)	$	52,194.5	$	22,317.7	$	(22,318.2	)	$	52,194.0

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	2,576.7	$	0.1	$	--		$	2,576.8	$	--	$	--		$	2,576.8
Accounts payable – trade		133.1		272.1		(7.5	)		397.7		--		--			397.7
Accounts payable – related parties		1,071.5		139.6		(1,106.0	)		105.1		1.1		(1.1	)		105.1
Accrued product payables		1,944.5		1,670.3		(1.1	)		3,613.7		--		--			3,613.7
Accrued interest		340.7		0.1		--			340.8		--		--			340.8
Derivative liabilities		590.3		147.4		--			737.7		--		--			737.7
Other current liabilities		173.5		316.5		(12.0	)		478.0		--		0.7			478.7
Total current liabilities		6,830.3		2,546.1		(1,126.6	)		8,249.8		1.1		(0.4	)		8,250.5
Long-term debt		21,105.7		15.2		--			21,120.9		--		--			21,120.9
Deferred tax liabilities		5.0		45.1		(1.1	)		49.0		--		3.7			52.7
Other long-term liabilities		13.5		400.6		(179.8	)		234.3		269.6		--			503.9
Commitments and contingencies
Equity:
Partners' and other owners' equity		22,329.9		41,675.3		(41,713.4	)		22,291.8		22,047.0		(22,291.8	)		22,047.0
Noncontrolling interests		--		78.0		170.7			248.7		--		(29.7	)		219.0
Total equity		22,329.9		41,753.3		(41,542.7	)		22,540.5		22,047.0		(22,321.5	)		22,266.0
Total liabilities and equity	$	50,284.4	$	44,760.3	$	(42,850.2	)	$	52,194.5	$	22,317.7	$	(22,318.2	)	$	52,194.0

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended March 31, 2017

	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	$	12,532.8		$	4,308.2		$	(9,520.6	)	$	7,320.4		$	--		$	--		$	7,320.4
Costs and expenses:
Operating costs and expenses		12,239.0			3,615.0			(9,520.8	)		6,333.2			--			--			6,333.2
General and administrative costs		7.4			42.7			(0.2	)		49.9			0.5			--			50.4
Total costs and expenses		12,246.4			3,657.7			(9,521.0	)		6,383.1			0.5			--			6,383.6
Equity in income of unconsolidated affiliates		728.8			133.4			(767.4	)		94.8			766.7			(766.7	)		94.8
Operating income		1,015.2			783.9			(767.0	)		1,032.1			766.2			(766.7	)		1,031.6
Other income (expense):
Interest expense		(248.8	)		(2.7	)		2.2			(249.3	)		--			--			(249.3	)
Other, net		2.2			0.2			(2.2	)		0.2			(5.5	)		--			(5.3	)
Total other expense, net		(246.6	)		(2.5	)		--			(249.1	)		(5.5	)		--			(254.6	)
Income before income taxes		768.6			781.4			(767.0	)		783.0			760.7			(766.7	)		777.0
Provision for income taxes		(2.9	)		(2.6	)		--			(5.5	)		--			(0.5	)		(6.0	)
Net income		765.7			778.8			(767.0	)		777.5			760.7			(767.2	)		771.0
Net income attributable to noncontrolling interests		--			(1.7	)		(9.9	)		(11.6	)		--			1.3			(10.3	)
Net income attributable to entity	$	765.7		$	777.1		$	(776.9	)	$	765.9		$	760.7		$	(765.9	)	$	760.7

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	5,361.9		$	3,282.7		$	(3,639.3	)	$	5,005.3		$	--	$	--		$	5,005.3
Costs and expenses:
Operating costs and expenses		5,091.2			2,695.1			(3,639.4	)		4,146.9			--		--			4,146.9
General and administrative costs		6.0			36.8			--			42.8			1.1		--			43.9
Total costs and expenses		5,097.2			2,731.9			(3,639.4	)		4,189.7			1.1		--			4,190.8
Equity in income of unconsolidated affiliates		632.7			133.6			(665.2	)		101.1			660.1		(660.1	)		101.1
Operating income		897.4			684.4			(665.1	)		916.7			659.0		(660.1	)		915.6
Other income (expense):
Interest expense		(237.1	)		(5.2	)		1.7			(240.6	)		--		--			(240.6	)
Other, net		1.8			1.3			(1.7	)		1.4			2.2		--			3.6
Total other income (expense), net		(235.3	)		(3.9	)		--			(239.2	)		2.2		--			(237.0	)
Income before income taxes		662.1			680.5			(665.1	)		677.5			661.2		(660.1	)		678.6
Provision for income taxes		(2.9	)		(5.1	)		--			(8.0	)		--		(0.4	)		(8.4	)
Net income		659.2			675.4			(665.1	)		669.5			661.2		(660.5	)		670.2
Net income attributable to noncontrolling interests		--			(1.3	)		(8.9	)		(10.2	)		--		1.2			(9.0	)
Net income attributable to entity	$	659.2		$	674.1		$	(674.0	)	$	659.3		$	661.2	$	(659.3	)	$	661.2

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended March 31, 2017

	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	$	870.1	$	838.3		$	(767.0	)	$	941.4		$	924.5	$	(931.1	)	$	934.8
Comprehensive income attributable to noncontrolling interests		--		(1.7	)		(9.9	)		(11.6	)		--		1.3			(10.3	)
Comprehensive income attributable to entity	$	870.1	$	836.6		$	(776.9	)	$	929.8		$	924.5	$	(929.8	)	$	924.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Comprehensive income	$	655.2	$	630.1		$	(665.0	)	$	620.3		$	611.9	$	(611.3	)	$	620.9
Comprehensive income attributable to noncontrolling interests		--		(1.3	)		(8.9	)		(10.2	)		--		1.2			(9.0	)
Comprehensive income attributable to entity	$	655.2	$	628.8		$	(673.9	)	$	610.1		$	611.9	$	(610.1	)	$	611.9

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Three Months Ended March 31, 2017

	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	$	765.7		$	778.8		$	(767.0	)	$	777.5		$	760.7		$	(767.2	)	$	771.0
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		51.3			351.1			(0.1	)		402.3			--			--			402.3
Equity in income of unconsolidated affiliates		(728.8	)		(133.4	)		767.4			(94.8	)		(766.7	)		766.7			(94.8	)
Distributions received on earnings from unconsolidated affiliates		255.4			62.4			(227.3	)		90.5			870.5			(870.5	)		90.5
Net effect of changes in operating accounts and other operating activities		631.0			(958.0	)		1.4			(325.6	)		31.9			0.3			(293.4	)
Net cash flows provided by operating activities		974.6			100.9			(225.6	)		849.9			896.4			(870.7	)		875.6
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(125.5	)		(304.9	)		--			(430.4	)		--			--			(430.4	)
Cash used for pending business combination		--			(16.0	)		--			(16.0	)		--			--			(16.0	)
Proceeds from asset sales		1.2			0.8			--			2.0			--			--			2.0
Other investing activities		(155.9	)		4.5			461.6			310.2			(445.6	)		445.6			310.2
Cash used in investing activities		(280.2	)		(315.6	)		461.6			(134.2	)		(445.6	)		445.6			(134.2	)
Financing activities:
Borrowings under debt agreements		17,575.1			--			--			17,575.1			--			--			17,575.1
Repayments of debt		(17,856.4	)		(0.1	)		--			(17,856.5	)		--			--			(17,856.5	)
Cash distributions paid to owners		(870.5	)		(242.6	)		242.6			(870.5	)		(869.0	)		870.5			(869.0	)
Cash payments made in connection with DERs		--			--			--			--			(3.2	)		--			(3.2	)
Cash distributions paid to noncontrolling interests		--			(2.5	)		(7.8	)		(10.3	)		--			0.2			(10.1	)
Cash contributions from noncontrolling interests		--			0.1			0.1			0.2			--			--			0.2
Net cash proceeds from issuance of common units		--			--			--			--			448.8			--			448.8
Cash contributions from owners		445.6			469.2			(469.2	)		445.6			--			(445.6	)		--
Other financing activities		--			--			--			--			(27.4	)		--			(27.4	)
Cash provided by (used in) financing activities		(706.2	)		224.1			(234.3	)		(716.4	)		(450.8	)		425.1			(742.1	)
Net change in cash and cash equivalents		(11.8	)		9.4			1.7			(0.7	)		--			--			(0.7	)
Cash and cash equivalents, January 1		13.4			57.2			(7.5	)		63.1			--			--			63.1
Cash and cash equivalents, March 31	$	1.6		$	66.6		$	(5.8	)	$	62.4		$	--		$	--		$	62.4

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	659.2		$	675.4		$	(665.1	)	$	669.5		$	661.2		$	(660.5	)	$	670.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		42.5			339.7			(0.1	)		382.1			--			--			382.1
Equity in income of unconsolidated affiliates		(632.7	)		(133.6	)		665.2			(101.1	)		(660.1	)		660.1			(101.1	)
Distributions received on earnings from unconsolidated affiliates		247.2			74.2			(214.7	)		106.7			788.5			(788.5	)		106.7
Net effect of changes in operating accounts and other operating activities		35.5			(255.3	)		42.4			(177.4	)		18.8			0.4			(158.2	)
Net cash flows provided by operating activities		351.7			700.4			(172.3	)		879.8			808.4			(788.5	)		899.7
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(307.6	)		(687.4	)		--			(995.0	)		--			--			(995.0	)
Proceeds from asset sales		0.1			13.3			--			13.4			--			--			13.4
Other investing activities		(387.5	)		(55.7	)		260.9			(182.3	)		(1,008.6	)		1,008.6			(182.3	)
Cash used in investing activities		(695.0	)		(729.8	)		260.9			(1,163.9	)		(1,008.6	)		1,008.6			(1,163.9	)
Financing activities:
Borrowings under debt agreements		20,000.6			--			--			20,000.6			--			--			20,000.6
Repayments of debt		(19,797.3	)		(0.1	)		--			(19,797.4	)		--			--			(19,797.4	)
Cash distributions paid to owners		(788.5	)		(222.9	)		222.9			(788.5	)		(788.3	)		788.5			(788.3	)
Cash payments made in connection with DERs		--			--			--			--			(2.0	)		--			(2.0	)
Cash distributions paid to noncontrolling interests		--			(0.5	)		(8.2	)		(8.7	)		--			--			(8.7	)
Cash contributions from noncontrolling interests		--			11.1			--			11.1			--			--			11.1
Net cash proceeds from issuance of common units		--			--			--			--			1,011.5			--			1,011.5
Cash contributions from owners		1,008.6			260.9			(260.9	)		1,008.6			--			(1,008.6	)		--
Other financing activities		--			--			--			--			(21.0	)		--			(21.0	)
Cash provided by financing activities		423.4			48.5			(46.2	)		425.7			200.2			(220.1	)		405.8
Net change in cash and cash equivalents		80.1			19.1			42.4			141.6			--			--			141.6
Cash and cash equivalents, January 1		--			69.6			(50.6	)		19.0			--			--			19.0
Cash and cash equivalents, March 31	$	80.1		$	88.7		$	(8.2	)	$	160.6		$	--		$	--		$	160.6

General Accounting and Disclosure Matters (Policies)	3 Months Ended
General Accounting and Disclosure Matters (Policies)	Mar. 31, 2017
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 March 31, 2017 and December 31, 2016, our restricted cash amounts were $44.7 million and $354.5 million, respectively. The balance of restricted cash decreased since December 31, 2016 primarily due to the settlement of derivative instruments related to contango positions during the first quarter of 2017. See Note 12 for information regarding our derivative instruments and hedging activities.

Inventories (Tables)

3 Months Ended

Mar. 31, 2017

Inventories [Abstract]

Inventory Amounts by Product Type

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

	March 31, 2017		December 31, 2016
NGLs	$	1,107.5	$	1,156.1
Petrochemicals and refined products		474.2		220.7
Crude oil		319.5		360.0
Natural gas		20.8		33.7
Total	$	1,922.0	$	1,770.5

Cost of Sales and Lower of Cost or Market Adjustments

	For the Three Months Ended March 31,
	2017		2016
Cost of sales (1)	$	5,335.7	$	3,208.3
Lower of cost or net realizable value adjustments within cost of sales		3.4		5.3

(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 (Tables)

3 Months Ended

Mar. 31, 2017

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment and Accumulated Depreciation

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

	Estimated Useful Life in Years	March 31, 2017		December 31, 2016
Plants, pipelines and facilities (1)	3-45 (5)	$	35,382.6	$	35,124.6
Underground and other storage facilities (2)	5-40 (6)		3,352.8		3,326.9
Transportation equipment (3)	3-10		169.2		165.8
Marine vessels (4)	15-30		801.2		800.7
Land			265.1		264.6
Construction in progress			3,565.8		3,320.7
Total			43,536.7		43,003.3
Less accumulated depreciation			9,980.6		9,710.8
Property, plant and equipment, net		$	33,556.1	$	33,292.5

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

Depreciation Expense and Capitalized Interest

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

	For the Three Months Ended March 31,
	2017		2016
Depreciation expense (1)	$	317.5	$	295.9
Capitalized interest (2)		39.6		42.5

(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 January 1, 2017:

ARO liability balance, January 1, 2017	$	85.4
Liabilities settled		(1.0	)
Accretion expense		1.3
ARO liability balance, March 31, 2017	$	85.7

Investments in Unconsolidated Affiliates (Tables)

3 Months Ended

Mar. 31, 2017

Investments in Unconsolidated Affiliates [Abstract]

Investments in Unconsolidated Affiliates

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

	Ownership Interest at March 31, 2017	March 31, 2017		December 31, 2016
NGL Pipelines & Services:
Venice Energy Service Company, L.L.C.	13.1%	$	24.7	$	24.8
K/D/S Promix, L.L.C.	50%		34.1		33.7
Baton Rouge Fractionators LLC	32.2%		17.5		17.3
Skelly-Belvieu Pipeline Company, L.L.C.	50%		38.7		38.9
Texas Express Pipeline LLC	35%		330.3		331.9
Texas Express Gathering LLC	45%		36.0		35.8
Front Range Pipeline LLC	33.3%		167.4		165.4
Delaware Basin Gas Processing LLC	50%		109.4		102.6
Crude Oil Pipelines & Services:
Seaway Crude Pipeline Company LLC	50%		1,386.5		1,393.8
Eagle Ford Pipeline LLC	50%		383.7		377.9
Eagle Ford Terminals Corpus Christi LLC	50%		57.8		52.9
Natural Gas Pipelines & Services:
White River Hub, LLC	50%		21.5		21.7
Petrochemical & Refined Products Services:
Centennial Pipeline LLC	50%		58.8		62.3
Other	Various		5.0		18.3
Total		$	2,671.4	$	2,677.3

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

	For the Three Months Ended March 31,
	2017			2016
NGL Pipelines & Services	$	15.5		$	15.1
Crude Oil Pipelines & Services		81.2			90.1
Natural Gas Pipelines & Services		1.0			1.0
Petrochemical & Refined Products Services		(2.9	)		(5.1	)
Total	$	94.8		$	101.1

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

	March 31, 2017		December 31, 2016
NGL Pipelines & Services	$	23.8	$	24.1
Crude Oil Pipelines & Services		18.8		19.0
Petrochemical & Refined Products Services		1.9		2.1
Total	$	44.5	$	45.2

Combined results of operations data for the periods indicated for our unconsolidated affiliates are summarized in the following table (all data presented on a 100% basis):

	For the Three Months Ended March 31,
	2017		2016
Income Statement Data:
Revenues	$	343.2	$	345.5
Operating income		203.7		213.7
Net income		202.9		215.2

Intangible Assets and Goodwill (Tables)

3 Months Ended

Mar. 31, 2017

Intangible Assets and Goodwill [Abstract]

Intangible Assets by Segment

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

	March 31, 2017							December 31, 2016
	Gross Value		Accumulated Amortization			Carrying Value		Gross Value		Accumulated Amortization			Carrying Value
NGL Pipelines & Services:
Customer relationship intangibles	$	447.4	$	(176.4	)	$	271.0	$	447.4	$	(172.7	)	$	274.7
Contract-based intangibles		279.9		(208.0	)		71.9		279.9		(204.4	)		75.5
Segment total		727.3		(384.4	)		342.9		727.3		(377.1	)		350.2
Crude Oil Pipelines & Services:
Customer relationship intangibles		2,204.4		(95.2	)		2,109.2		2,204.4		(84.5	)		2,119.9
Contract-based intangibles		281.0		(134.3	)		146.7		281.0		(121.9	)		159.1
Segment total		2,485.4		(229.5	)		2,255.9		2,485.4		(206.4	)		2,279.0
Natural Gas Pipelines & Services:
Customer relationship intangibles		1,350.3		(396.0	)		954.3		1,350.3		(390.0	)		960.3
Contract-based intangibles		464.7		(372.7	)		92.0		464.7		(370.5	)		94.2
Segment total		1,815.0		(768.7	)		1,046.3		1,815.0		(760.5	)		1,054.5
Petrochemical & Refined Products Services:
Customer relationship intangibles		185.5		(45.5	)		140.0		185.5		(43.9	)		141.6
Contract-based intangibles		54.0		(16.0	)		38.0		54.0		(15.2	)		38.8
Segment total		239.5		(61.5	)		178.0		239.5		(59.1	)		180.4
Total intangible assets	$	5,267.2	$	(1,444.1	)	$	3,823.1	$	5,267.2	$	(1,403.1	)	$	3,864.1

Amortization Expense of Intangible Assets by Segment

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

	For the Three Months Ended March 31,
	2017		2016
NGL Pipelines & Services	$	7.3	$	7.8
Crude Oil Pipelines & Services		23.1		27.7
Natural Gas Pipelines & Services		8.2		8.6
Petrochemical & Refined Products Services		2.4		2.2
Total	$	41.0	$	46.3

Forecasted Amortization Expense

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

Remainder of 2017				2018				2019				2020				2021
$	121.1			$	163.8			$	157.7			$	152.8			$	163.2

Changes in Carrying Amount of Goodwill

	NGL Pipelines & Services		Crude Oil Pipelines & Services		Natural Gas Pipelines & Services		Petrochemical & Refined Products Services		Consolidated Total
Balance at December 31, 2016	$	2,651.7	$	1,841.0	$	296.3	$	956.2	$	5,745.2
Balance at March 31, 2017	$	2,651.7	$	1,841.0	$	296.3	$	956.2	$	5,745.2

Debt Obligations (Tables)

3 Months Ended

Mar. 31, 2017

Debt Obligations [Abstract]

Consolidated Debt Obligations

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

	March 31, 2017			December 31, 2016
EPO senior debt obligations:
Commercial Paper Notes, variable-rates	$	1,500.4		$	1,777.2
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			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			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			975.0
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		22,150.4			22,427.2
EPO Junior Subordinated Notes A, variable-rate, due August 2066 (1)		521.1			521.1
EPO Junior Subordinated Notes C, fixed/variable-rate, due June 2067 (2)		256.4			256.4
EPO Junior Subordinated Notes B, fixed/variable-rate, due January 2068 (3)		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		23,624.8			23,901.6
Other, non-principal amounts		(201.8	)		(203.9	)
Less current maturities of debt		(2,300.0	)		(2,576.8	)
Total long-term debt	$	21,123.0		$	21,120.9

(1)Variable rate is reset quarterly and 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, a variable rate reset quarterly and 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 reset quarterly and based on 3-month LIBOR plus 2.680%.

Consolidated Debt Maturities

The following table presents contractually scheduled maturities of our consolidated debt obligations outstanding at March 31, 2017 for the next five years, and in total thereafter:

			Scheduled Maturities of Debt
	Total		Remainder of 2017		2018		2019		2020		2021		Thereafter
Commercial Paper Notes	$	1,500.4	$	1,500.4	$	--	$	--	$	--	$	--	$	--
Senior Notes		20,650.0		800.0		1,100.0		1,500.0		1,500.0		575.0		15,175.0
Junior Subordinated Notes		1,474.4		--		--		--		--		--		1,474.4
Total	$	23,624.8	$	2,300.4	$	1,100.0	$	1,500.0	$	1,500.0	$	575.0	$	16,649.4

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

The following table presents the range of interest rates and weighted-average interest rates paid on our consolidated variable-rate debt during the three months ended March 31, 2017:

	Range of Interest Rates Paid	Weighted-Average Interest Rate Paid
Commercial Paper Notes	0.90% to 1.33%	1.10%
EPO Junior Subordinated Notes A	4.59% to 4.74%	4.69%

- Definition

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

+ References

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

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

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

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

Reference 5: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 55
-Paragraph 8
-URI http://asc.fasb.org/extlink&oid=64930739&loc=d3e28878-108400

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

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

Reference 8: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 1A
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28541-108399

Reference 9: http://www.xbrl.org/2003/role/presentationRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 835
-SubTopic 30
-Section 45
-Paragraph 2
-URI http://asc.fasb.org/extlink&oid=64930785&loc=d3e28551-108399

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

+ Details

Equity and Distributions (Tables)

3 Months Ended

Mar. 31, 2017

Equity and Distributions [Abstract]

Summary of Changes in Outstanding Units

Partners' Equity

	Common Units (Unrestricted)			Restricted Common Units			Total Common Units
Number of units outstanding at January 1, 2017		2,116,906,120			682,294			2,117,588,414
Common units issued in connection with ATM program		12,865,371			--			12,865,371
Common units issued in connection with DRIP and EUPP		3,440,559			--			3,440,559
Common units issued in connection with the vesting of phantom unit awards		2,234,067			--			2,234,067
Common units issued in connection with the vesting of restricted common unit awards		665,920			(665,920	)		--
Forfeiture of restricted common unit awards		--			(1,250	)		(1,250	)
Cancellation of treasury units acquired in connection with the vesting of equity-based awards		(946,291	)		--			(946,291	)
Common units issued in connection with employee compensation		1,176,103			--			1,176,103
Other		14,685			--			14,685
Number of units outstanding at March 31, 2017		2,136,356,534			15,124			2,136,371,658

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, January 1, 2017	$	(83.8	)	$	(199.8	)	$	3.6		$	(280.0	)
Other comprehensive income (loss) before reclassifications		144.8			2.4			(0.1	)		147.1
Amounts reclassified from accumulated other comprehensive loss (income)		7.1			9.6			--			16.7
Total other comprehensive income (loss)		151.9			12.0			(0.1	)		163.8
Balance, March 31, 2017	$	68.1		$	(187.8	)	$	3.5		$	(116.2	)

	Gains (Losses) on Cash Flow Hedges
	Commodity Derivative Instruments			Interest Rate Derivative Instruments			Other			Total
Balance, January 1, 2016	$	56.6		$	(279.5	)	$	3.7		$	(219.2	)
Other comprehensive loss before reclassifications		(1.2	)		--			(0.1	)		(1.3	)
Amounts reclassified from accumulated other comprehensive loss (income)		(57.2	)		9.2			--			(48.0	)
Total other comprehensive income (loss)		(58.4	)		9.2			(0.1	)		(49.3	)
Balance, March 31, 2016	$	(1.8	)	$	(270.3	)	$	3.6		$	(268.5	)

Reclassification out of Accumulated Other Comprehensive Income (Loss)

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

		For the Three Months Ended March 31,
	Location	2017			2016
Losses (gains) on cash flow hedges:
Interest rate derivatives	Interest expense	$	9.6		$	9.2
Commodity derivatives	Revenue		7.5			(58.8	)
Commodity derivatives	Operating costs and expenses		(0.4	)		1.6
Total		$	16.7		$	(48.0	)

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
2016
1st Quarter	$	0.3950	4/29/2016	5/6/2016
2017
1st Quarter	$	0.4150	4/28/2017	5/8/2017

Business Segments (Tables)

3 Months Ended

Mar. 31, 2017

Business Segments [Abstract]

Measurement of Total Segment Gross Operating Margin

	For the Three Months Ended March 31,
	2017			2016
Income before income taxes	$	777.0		$	678.6
Add total other expense, net		254.6			237.0
Operating income		1,031.6			915.6
Adjustments to reconcile operating income to total gross operating margin:
Add depreciation, amortization and accretion expense in operating costs and expenses		376.2			358.2
Add asset impairment and related charges in operating costs and expenses		11.2			1.7
Add net losses and subtract net gains attributable to asset sales in operating costs and expenses		(0.3	)		4.9
Add general and administrative costs		50.4			43.9
Adjustments for make-up rights on certain new pipeline projects:
Add non-refundable payments received from shippers attributable to make-up rights (1)		13.3			7.1
Subtract the subsequent recognition of revenues attributable to make-up rights (2)		(9.1	)		(12.9	)
Total segment gross operating margin	$	1,473.3		$	1,318.5

(1)Since make-up rights entail a future performance obligation by the pipeline to the shipper, these receipts are recorded as deferred revenue for GAAP purposes; however, these receipts are included in gross operating margin in the period of receipt since they are nonrefundable to the shipper. (2)As deferred revenues attributable to make-up rights are subsequently recognized as revenue under GAAP, gross operating margin must be adjusted to remove such amounts to prevent duplication since the associated non-refundable payments were previously included in gross operating margin.

	For the Three Months Ended March 31,
	2017		2016
Gross operating margin by segment:
NGL Pipelines & Services	$	856.0	$	783.7
Crude Oil Pipelines & Services		264.6		202.3
Natural Gas Pipelines & Services		170.9		177.7
Petrochemical & Refined Products Services		181.8		154.8
Total segment gross operating margin	$	1,473.3	$	1,318.5

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

Summarized Segment Financial Information

Information by business segment, together with reconciliations to amounts presented on our Unaudited Condensed Statements of Consolidated Operations, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Crude Oil Pipelines & Services		Natural Gas Pipelines & Services		Petrochemical & Refined Products Services			Adjustments and Eliminations			Consolidated Total
Revenues from third parties:
Three months ended March 31, 2017	$	3,343.0	$	1,802.6	$	757.8	$	1,406.2		$	--		$	7,309.6
Three months ended March 31, 2016		2,402.0		1,277.5		547.3		762.9			--			4,989.7
Revenues from related parties:
Three months ended March 31, 2017		2.8		4.6		3.4		--			--			10.8
Three months ended March 31, 2016		1.8		11.1		2.7		--			--			15.6
Intersegment and intrasegment revenues:
Three months ended March 31, 2017		8,874.8		3,474.0		194.5		414.7			(12,958.0	)		--
Three months ended March 31, 2016		3,174.8		1,499.4		124.7		242.7			(5,041.6	)		--
Total revenues:
Three months ended March 31, 2017		12,220.6		5,281.2		955.7		1,820.9			(12,958.0	)		7,320.4
Three months ended March 31, 2016		5,578.6		2,788.0		674.7		1,005.6			(5,041.6	)		5,005.3
Equity in income (loss) of unconsolidated affiliates:
Three months ended March 31, 2017		15.5		81.2		1.0		(2.9	)		--			94.8
Three months ended March 31, 2016		15.1		90.1		1.0		(5.1	)		--			101.1

Information by Business Segments

Information by business segment, together with reconciliations to our Unaudited Condensed Consolidated Balance Sheet totals, is presented in the following table:

	Reportable Business Segments
	NGL Pipelines & Services		Crude Oil Pipelines & Services		Natural Gas Pipelines & Services		Petrochemical & Refined Products Services		Adjustments and Eliminations		Consolidated Total
Property, plant and equipment, net: (see Note 4)
At March 31, 2017	$	14,003.1	$	4,346.9	$	8,355.6	$	3,284.7	$	3,565.8	$	33,556.1
At December 31, 2016		14,091.5		4,216.1		8,403.0		3,261.2		3,320.7		33,292.5
Investments in unconsolidated affiliates: (see Note 5)
At March 31, 2017		758.1		1,828.0		21.5		63.8		--		2,671.4
At December 31, 2016		750.4		1,824.6		21.7		80.6		--		2,677.3
Intangible assets, net: (see Note 6)
At March 31, 2017		342.9		2,255.9		1,046.3		178.0		--		3,823.1
At December 31, 2016		350.2		2,279.0		1,054.5		180.4		--		3,864.1
Goodwill: (see Note 6)
At March 31, 2017		2,651.7		1,841.0		296.3		956.2		--		5,745.2
At December 31, 2016		2,651.7		1,841.0		296.3		956.2		--		5,745.2
Segment assets:
At March 31, 2017		17,755.8		10,271.8		9,719.7		4,482.7		3,565.8		45,795.8
At December 31, 2016		17,843.8		10,160.7		9,775.5		4,478.4		3,320.7		45,579.1

Consolidated Revenues and Expenses

Other Revenue and Expense Information

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

	For the Three Months Ended March 31,
	2017			2016
NGL Pipelines & Services:
Sales of NGLs and related products	$	2,887.2		$	1,943.5
Midstream services		458.6			460.3
Total		3,345.8			2,403.8
Crude Oil Pipelines & Services:
Sales of crude oil		1,618.6			1,121.1
Midstream services		188.6			167.5
Total		1,807.2			1,288.6
Natural Gas Pipelines & Services:
Sales of natural gas		544.0			315.0
Midstream services		217.2			235.0
Total		761.2			550.0
Petrochemical & Refined Products Services:
Sales of petrochemicals and refined products		1,211.1			553.2
Midstream services		195.1			209.7
Total		1,406.2			762.9
Total consolidated revenues	$	7,320.4		$	5,005.3

Consolidated costs and expenses
Operating costs and expenses:
Cost of sales	$	5,335.7		$	3,208.3
Other operating costs and expenses (1)		610.4			573.8
Depreciation, amortization and accretion		376.2			358.2
Impairment and related charges		11.2			1.7
Net losses (gains) attributable to asset sales		(0.3	)		4.9
General and administrative costs		50.4			43.9
Total consolidated costs and expenses	$	6,383.6		$	4,190.8

(1)Represents the cost of operating our plants, pipelines and other fixed assets excluding: depreciation, amortization and accretion charges; asset impairment and related charges; and net losses (or gains) attributable to asset sales.

Earnings Per Unit (Tables)

3 Months Ended

Mar. 31, 2017

Earnings Per Unit [Abstract]

Basic and Diluted Earnings Per Unit

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

	For the Three Months Ended March 31,
	2017			2016
BASIC EARNINGS PER UNIT
Net income attributable to limited partners	$	760.7		$	661.2
Undistributed earnings allocated and cash payments on phantom unit awards (1)		(4.0	)		(3.2	)
Net income available to common unitholders	$	756.7		$	658.0

Basic weighted-average number of common units outstanding		2,126.2			2,033.6

Basic earnings per unit	$	0.36		$	0.32

DILUTED EARNINGS PER UNIT
Net income attributable to limited partners	$	760.7		$	661.2

Diluted weighted-average number of units outstanding:
Distribution-bearing common units		2,126.2			2,033.6
Phantom units (1)		8.7			6.9
Total		2,134.9			2,040.5

Diluted earnings per unit	$	0.36		$	0.32

(1) Each phantom unit award includes a distribution equivalent right ("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)

3 Months Ended

Mar. 31, 2017

Equity-based Awards [Abstract]

Equity-based Award Expense

	For the Three Months Ended March 31,
	2017		2016
Equity-classified awards:
Phantom unit awards	$	22.8	$	19.4
Restricted common unit awards		0.5		2.2
Profits interest awards		1.5		0.7
Liability-classified awards		0.2		0.1
Total	$	25.0	$	22.4

Other Share-based Compensation Plans

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

	Number of Units			Weighted- Average Grant Date Fair Value per Unit (1)
Phantom unit awards at January 1, 2017		7,767,501		$	27.20
Granted (2)		4,203,510		$	28.87
Vested		(2,238,568	)	$	28.33
Forfeited		(41,684	)	$	28.19
Phantom unit awards at March 31, 2017		9,690,759		$	27.66

(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 2017 was $121.4 million based on a grant date market price of our common units of $28.87 per unit. An estimated annual forfeiture rate of 3.8% 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 (1)	Class A Preference Return (2)		Expected Liquidation Date	Estimated Grant Date Fair Value of Profits Interest Awards (3)	Unrecognized Compensation Cost (4)

PubCo I	2,723,052 units	$63.7 million	$	0.39	Feb. 2020	$13.2 million	$9.6 million
PubCo II	2,834,198 units	$66.3 million	$	0.39	Feb. 2021	$14.7 million	$11.5 million
PubCo III	105,000 units	$2.5 million	$	0.39	Apr. 2020	$0.6 million	$0.4 million
PrivCo I	1,111,438 units	$26.0 million	$	0.39	Feb. 2021	$5.8 million	$1.0 million

(1)Represents fair market value of the Enterprise common units contributed to each Employee Partnership at the applicable contribution date. (2)Each quarter, the Class A limited partner in each Employee Partnership is paid a cash distribution equal to the product of (i) the number of common units owned by the Employee Partnership and (ii) the Class A Preference Return of $0.39 per unit (subject to equitable adjustment in order to reflect any equity split, equity distribution or dividend, reverse split, combination, reclassification, recapitalization or other similar event affecting such common units). To the extent that the Employee Partnership has cash remaining after making this quarterly payment to the Class A limited partner, the residual cash is distributed to the Class B limited partners on a quarterly basis. (3)Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates. (4)Represents our expected share of the unrecognized compensation cost at March 31, 2017. 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 2.9 years, 3.9 years, 3.0 years and 3.9 years, respectively.

	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 6.8%	29% to 40%
PubCo II	5.0 years	1.1% to 1.6%	6.1% to 6.8%	27% to 40%
PubCo III	4.0 years	1.0% to 1.4%	6.1% to 6.2%	31% to 40%
PrivCo I	5.0 years	1.2% to 1.6%	6.1% to 6.7%	28% 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 March 31,
	2017		2016
Cash payments made in connection with DERs	$	3.2	$	2.0
Total intrinsic value of phantom unit awards that vested during period		63.2		36.3

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 (1)
Restricted common units at January 1, 2017		682,294		$	28.61
Vested		(665,920	)	$	28.56
Forfeited		(1,250	)	$	31.07
Restricted common units at March 31, 2017		15,124		$	30.74

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

Cash Distributions and Total Intrinsic Value of Restricted Common Unit Awards

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

	For the Three Months Ended March 31,
	2017			2016
Cash distributions paid to restricted common unitholders		$	0.3		$	0.8
Total intrinsic value of restricted common unit awards that vested during period			18.5			26.8

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

3 Months Ended

Mar. 31, 2017

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 March 31, 2017:

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 1.51%	Fair value hedge

The following table summarizes our portfolio of forward starting swaps at March 31, 2017:

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		$	275.0		5/2018	2.02%	Cash flow hedge

The following table summarizes our portfolio of commodity derivative instruments outstanding at March 31, 2017 (volume measures as noted):

	Volume (1)		Accounting
Derivative Purpose	Current (2)	Long-Term (2)	Treatment
Derivatives designated as hedging instruments:
Natural gas processing:
Forecasted natural gas purchases for plant thermal reduction (Bcf)	14.9	n/a	Cash flow hedge
Forecasted sales of NGLs (MMBbls)	3.5	n/a	Cash flow hedge
Octane enhancement:
Forecasted purchases of NGLs (MMBbls)	0.5	n/a	Cash flow hedge
Forecasted sales of octane enhancement products (MMBbls)	0.8	n/a	Cash flow hedge
Natural gas marketing:
Forecasted purchases of natural gas for fuel (Bcf)	4.5	n/a	Cash flow hedge
Natural gas storage inventory management activities (Bcf)	4.5	n/a	Fair value hedge
NGL marketing:
Forecasted purchases of NGLs and related hydrocarbon products (MMBbls)	82.3	n/a	Cash flow hedge
Forecasted sales of NGLs and related hydrocarbon products (MMBbls)	93.4	n/a	Cash flow hedge
Refined products marketing:
Forecasted purchases of refined products (MMBbls)	0.2	n/a	Cash flow hedge
Forecasted sales of refined products (MMBbls)	0.4	n/a	Cash flow hedge
Refined products inventory management activities (MMBbls)	5.4	n/a	Fair value hedge
Crude oil marketing:
Forecasted purchases of crude oil (MMBbls)	12.5	n/a	Cash flow hedge
Forecasted sales of crude oil (MMBbls)	21.2	n/a	Cash flow hedge
Derivatives not designated as hedging instruments:
Natural gas risk management activities (Bcf) (3,4)	188.6	21.7	Mark-to-market
NGL risk management activities (MMBbls) (4)	16.1	n/a	Mark-to-market
Refined products risk management activities (MMBbls) (4)	0.2	n/a	Mark-to-market
Crude oil risk management activities (MMBbls) (4)	25.2	10.4	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, September 2017 and March 2020, respectively. (3) Current and long-term volumes include 55.3 Bcf and 10.5 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
	March 31, 2017			December 31, 2016			March 31, 2017			December 31, 2016
	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	$	0.7	Current assets	$	0.3	Current liabilities	$	1.7	Current liabilities	$	0.2
Interest rate derivatives	Other assets		38.6	Other assets		36.2	Other liabilities		0.3	Other liabilities		0.9
Total interest rate derivatives			39.3			36.5			2.0			1.1
Commodity derivatives	Current assets		34.1	Current assets		499.2	Current liabilities		30.0	Current liabilities		662.0
Commodity derivatives	Other assets		--	Other assets		--	Other liabilities		--	Other liabilities		--
Total commodity derivatives			34.1			499.2			30.0			662.0
Total derivatives designated as hedging instruments		$	73.4		$	535.7		$	32.0		$	663.1

Derivatives not designated as hedging instruments
Commodity derivatives	Current assets	$	5.6	Current assets	$	41.9	Current liabilities	$	12.1	Current liabilities	$	75.6
Commodity derivatives	Other assets		1.5	Other assets		0.3	Other liabilities		2.4	Other liabilities		1.8
Total commodity derivatives		$	7.1		$	42.2		$	14.5		$	77.4

Offsetting Financial Assets

	Offsetting of Financial Assets and Derivative Assets
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet								Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet			Amounts of Assets Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received		Cash Collateral Paid		Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)								(v) = (iii) + (iv)
As of March 31, 2017:
Interest rate derivatives		$	39.3		$	--		$	39.3		$	(0.6	)	$	--	$	--		$	38.7
Commodity derivatives			41.2			--			41.2			(38.0	)		--		--			3.2
As of December 31, 2016:
Interest rate derivatives		$	36.5		$	--		$	36.5		$	(0.2	)	$	--	$	--		$	36.3
Commodity derivatives			541.4			--			541.4			(526.8	)		--		--			14.6

Offsetting Financial Liabilities

	Offsetting of Financial Liabilities and Derivative Liabilities
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Gross Amounts Not Offset in the Balance Sheet										Amounts That Would Have Been Presented On Net Basis
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet			Amounts of Liabilities Presented in the Balance Sheet			Financial Instruments				Cash Collateral Received			Cash Collateral Paid			Amounts That Would Have Been Presented On Net Basis
	(i)			(ii)			(iii) = (i) – (ii)			(iv)										(v) = (iii) + (iv)
As of March 31, 2017:
Interest rate derivatives		$	2.0		$	--		$	2.0		$	(0.6	)	$	--		$	--			$	1.4
Commodity derivatives			44.5			--			44.5			(38.0	)		(3.2	)		--				3.3
As of December 31, 2016:
Interest rate derivatives		$	1.1		$	--		$	1.1		$	(0.2	)	$	--		$	--			$	0.9
Commodity derivatives			739.4			--			739.4			(526.8	)		--			(212.4	)			0.2

Derivative Instruments Effects on Statements of Operations

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

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	(0.9	)	$	6.1
Commodity derivatives	Revenue		18.8			(19.0	)
Total		$	17.9		$	(12.9	)

Derivatives in Fair Value Hedging Relationships	Location	Gain (Loss) Recognized in Income on Hedged Item
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	0.9		$	(6.2	)
Commodity derivatives	Revenue		(12.4	)		28.0
Total		$	(11.5	)	$	21.8

Derivative Instruments Effects on Statements of Comprehensive Income

Derivatives in Cash Flow Hedging Relationships	Change in Value Recognized in Other Comprehensive Income (Loss) on Derivative (Effective Portion)
	For the Three Months Ended March 31,
	2017			2016
Interest rate derivatives	$	2.4		$	--
Commodity derivatives – Revenue (1)		147.6			3.3
Commodity derivatives – Operating costs and expenses (1)		(2.8	)		(4.5	)
Total	$	147.2		$	(1.2	)

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

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

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Reclassified from Accumulated Other Comprehensive Income (Loss) to Income (Effective Portion)
		For the Three Months Ended March 31,
		2017			2016
Interest rate derivatives	Interest expense	$	(9.6	)	$	(9.2	)
Commodity derivatives	Revenue		(7.5	)		58.8
Commodity derivatives	Operating costs and expenses		0.4			(1.6	)
Total		$	(16.7	)	$	48.0

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

Derivatives in Cash Flow Hedging Relationships	Location	Gain (Loss) Recognized in Income on Derivative (Ineffective Portion)
		For the Three Months Ended March 31,
		2017			2016
Commodity derivatives	Operating costs and expenses	$	(1.0	)	$	--

Gain/(Loss) Recognized in Income on Derivative

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

Derivatives Not Designated as Hedging Instruments	Location	Gain (Loss) Recognized in Income on Derivative
		For the Three Months Ended March 31,
		2017		2016
Commodity derivatives	Revenue	$	15.7	$	(1.3	)
Commodity derivatives	Operating costs and expenses		4.5		0.1
Total		$	20.2	$	(1.2	)

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

	March 31, 2017 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	$	--		$	39.3		$	--	$	39.3
Commodity derivatives:
Value before application of CME Rule 814		57.6			174.3			1.5		233.4
Impact of CME Rule 814 change		(57.6	)		(134.6	)		--		(192.2	)
Total commodity derivatives		--			39.7			1.5		41.2
Total financial assets	$	--		$	79.0		$	1.5	$	80.5

Financial liabilities:
Liquidity Option Agreement	$	--		$	--		$	275.1	$	275.1
Interest rate derivatives		--			2.0			--		2.0
Commodity derivatives:
Value before application of CME Rule 814		35.4			172.9			0.8		209.1
Impact of CME Rule 814 change		(35.4	)		(129.2	)		--		(164.6	)
Total commodity derivatives		--			43.7			0.8		44.5
Total financial liabilities	$	--		$	45.7		$	275.9	$	321.6

	December 31, 2016 Fair Value Measurements Using
	Quoted Prices in Active Markets for Identical Assets and Liabilities (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Total
Financial assets:
Interest rate derivatives	$	--	$	36.5	$	--	$	36.5
Commodity derivatives		84.5		455.2		1.7		541.4
Total financial assets	$	84.5	$	491.7	$	1.7	$	577.9

Financial liabilities:
Liquidity Option Agreement	$	--	$	--	$	269.6	$	269.6
Interest rate derivatives		--		1.1		--		1.1
Commodity derivatives		136.8		602.3		0.3		739.4
Total financial liabilities	$	136.8	$	603.4	$	269.9	$	1,010.1

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

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

		For the Three Months Ended March 31,
	Location	2017			2016
Financial liability balance, net, January 1		$	(268.2	)	$	(246.7	)
Total gains (losses) included in:
Net income (1)	Revenue		0.7			0.7
Net income	Other expense, net		(5.5	)		2.2
Other comprehensive income (loss)	Commodity derivative instruments – changes in fair value of cash flow hedges		--			1.5
Settlements	Revenue		(1.4	)		(0.1	)
Transfers out of Level 3			--			0.1
Financial liability balance, net, March 31		$	(274.4	)	$	(242.3	)

(1)There were unrealized losses of $0.6 million and unrealized gains of $0.6 million included in these amounts for the three months ended March 31, 2017 and 2016, respectively.

Fair Value Measurements, Valuation Techniques

The following table provides quantitative information regarding our recurring Level 3 fair value measurements for commodity derivatives at March 31, 2017:

	Fair Value
	Financial Assets		Financial Liabilities		Valuation Techniques	Unobservable Input	Range
Commodity derivatives – Crude oil	$	1.5	$	0.8	Discounted cash flow	Forward commodity prices	$48.68-$51.93/barrel

Asset Impairment Charges by Segment

The following table summarizes our non-cash asset impairment charges for long-lived assets by segment during each of the periods indicated:

	For the Three Months Ended March 31,
	2017		2016
NGL Pipelines & Services	$	0.2	$	0.3
Crude Oil Pipelines & Services		--		0.2
Natural Gas Pipelines & Services		0.2		--
Petrochemical & Refined Products Services		--		0.1
Total	$	0.4	$	0.6

Nonrecurring Fair Value Measurements

The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the three months ended March 31, 2017:

			Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at March 31, 2017		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

The following table presents categories of long-lived assets that were subject to non-recurring fair value measurements during the three months ended March 31, 2016:

				Fair Value Measurements at the End of the Reporting Period Using
	Carrying Value at March 31, 2016			Quoted Prices in Active Markets for Identical Assets (Level 1)			Significant Other Observable Inputs (Level 2)			Significant Unobservable Inputs (Level 3)			Total Non-Cash Impairment Loss
Long-lived assets disposed of other than by sale		$	--		$	--		$	--		$	--		$	0.6

Related Party Transactions (Tables)

3 Months Ended

Mar. 31, 2017

Related Party Transactions

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

	For the Three Months Ended March 31,
	2017		2016
Revenues – related parties:
Unconsolidated affiliates	$	10.8	$	15.6
Costs and expenses – related parties:
EPCO and its privately held affiliates	$	243.1	$	237.3
Unconsolidated affiliates		38.2		72.9
Total	$	281.3	$	310.2

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

	March 31, 2017		December 31, 2016
Accounts receivable - related parties:
Unconsolidated affiliates	$	1.6	$	1.1

Accounts payable - related parties:
EPCO and its privately held affiliates	$	39.2	$	88.9
Unconsolidated affiliates		10.9		16.2
Total	$	50.1	$	105.1

At March 31, 2017, 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%

	For the Three Months Ended March 31,
	2017		2016
Operating costs and expenses	$	211.6	$	205.4
General and administrative expenses		26.8		27.3
Total costs and expenses	$	238.4	$	232.7

Supplemental Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2017

Supplemental Cash Flow Information [Abstract]

Net Effect of Changes in Operating Assets and Liabilities

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

	For the Three Months Ended March 31,
	2017			2016
Decrease (increase) in:
Accounts receivable – trade	$	110.1		$	124.6
Accounts receivable – related parties		(0.6	)		0.4
Inventories		(71.9	)		(194.3	)
Prepaid and other current assets		249.0			5.3
Other assets		(2.2	)		1.3
Increase (decrease) in:
Accounts payable – trade		6.5			(64.8	)
Accounts payable – related parties		(21.1	)		(46.7	)
Accrued product payables		(16.8	)		228.7
Accrued interest		(137.9	)		(158.2	)
Other current liabilities		(400.2	)		(84.4	)
Other liabilities		(3.7	)		1.7
Net effect of changes in operating accounts	$	(288.8	)	$	(186.4	)

Condensed Consolidating Financial Information (Tables)

3 Months Ended

Mar. 31, 2017

Condensed Consolidating Financial Information [Abstract]

Condensed Consolidating Balance Sheet

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

March 31, 2017

	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	$	45.0	$	67.9	$	(5.8	)	$	107.1	$	--	$	--		$	107.1
Accounts receivable – trade, net		1,231.3		1,922.2		(0.7	)		3,152.8		--		--			3,152.8
Accounts receivable – related parties		101.5		818.8		(918.7	)		1.6		6.6		(6.6	)		1.6
Inventories		1,548.3		374.1		(0.4	)		1,922.0		--		--			1,922.0
Derivative assets		37.1		3.3		--			40.4		--		--			40.4
Prepaid and other current assets		212.5		220.0		(14.9	)		417.6		--		--			417.6
Total current assets		3,175.7		3,406.3		(940.5	)		5,641.5		6.6		(6.6	)		5,641.5
Property, plant and equipment, net		4,972.2		28,582.3		1.6			33,556.1		--		--			33,556.1
Investments in unconsolidated affiliates		40,079.6		4,186.7		(41,594.9	)		2,671.4		22,847.6		(22,847.6	)		2,671.4
Intangible assets, net		696.0		3,141.3		(14.2	)		3,823.1		--		--			3,823.1
Goodwill		459.5		5,285.7		--			5,745.2		--		--			5,745.2
Other assets		228.1		42.8		(179.2	)		91.7		0.5		--			92.2
Total assets	$	49,611.1	$	44,645.1	$	(42,727.2	)	$	51,529.0	$	22,854.7	$	(22,854.2	)	$	51,529.5

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	2,299.9	$	0.1	$	--		$	2,300.0	$	--	$	--		$	2,300.0
Accounts payable – trade		221.5		310.2		(5.8	)		525.9		0.2		--			526.1
Accounts payable – related parties		894.4		98.3		(936.1	)		56.6		0.1		(6.6	)		50.1
Accrued product payables		1,980.4		1,638.9		(1.1	)		3,618.2		--		--			3,618.2
Accrued interest		202.5		0.3		--			202.8		--		--			202.8
Derivative liabilities		34.5		9.3		--			43.8		--		--			43.8
Other current liabilities		53.4		264.1		(11.0	)		306.5		--		0.5			307.0
Total current liabilities		5,686.6		2,321.2		(954.0	)		7,053.8		0.3		(6.1	)		7,048.0
Long-term debt		21,107.9		15.1		--			21,123.0		--		--			21,123.0
Deferred tax liabilities		4.4		45.0		(0.5	)		48.9		--		3.7			52.6
Other long-term liabilities		11.6		400.6		(181.4	)		230.8		275.1		--			505.9
Commitments and contingencies
Equity:
Partners' and other owners' equity		22,800.6		41,785.8		(41,764.2	)		22,822.2		22,579.3		(22,822.2	)		22,579.3
Noncontrolling interests		--		77.4		172.9			250.3		--		(29.6	)		220.7
Total equity		22,800.6		41,863.2		(41,591.3	)		23,072.5		22,579.3		(22,851.8	)		22,800.0
Total liabilities and equity	$	49,611.1	$	44,645.1	$	(42,727.2	)	$	51,529.0	$	22,854.7	$	(22,854.2	)	$	51,529.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Balance Sheet

December 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)		EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries		Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
ASSETS
Current assets:
Cash and cash equivalents and restricted cash	$	366.2	$	58.9	$	(7.5	)	$	417.6	$	--	$	--		$	417.6
Accounts receivable – trade, net		1,499.4		1,830.3		(0.2	)		3,329.5		--		--			3,329.5
Accounts receivable – related parties		131.5		961.4		(1,090.7	)		2.2		--		(1.1	)		1.1
Inventories		1,357.5		413.5		(0.5	)		1,770.5		--		--			1,770.5
Derivative assets		464.8		76.6		--			541.4		--		--			541.4
Prepaid and other current assets		290.7		191.1		(13.7	)		468.1		--		--			468.1
Total current assets		4,110.1		3,531.8		(1,112.6	)		6,529.3		--		(1.1	)		6,528.2
Property, plant and equipment, net		4,796.5		28,495.7		0.3			33,292.5		--		--			33,292.5
Investments in unconsolidated affiliates		39,995.5		4,227.9		(41,546.1	)		2,677.3		22,317.1		(22,317.1	)		2,677.3
Intangible assets, net		700.2		3,178.2		(14.3	)		3,864.1		--		--			3,864.1
Goodwill		459.5		5,285.7		--			5,745.2		--		--			5,745.2
Other assets		222.6		41.0		(177.5	)		86.1		0.6		--			86.7
Total assets	$	50,284.4	$	44,760.3	$	(42,850.2	)	$	52,194.5	$	22,317.7	$	(22,318.2	)	$	52,194.0

LIABILITIES AND EQUITY
Current liabilities:
Current maturities of debt	$	2,576.7	$	0.1	$	--		$	2,576.8	$	--	$	--		$	2,576.8
Accounts payable – trade		133.1		272.1		(7.5	)		397.7		--		--			397.7
Accounts payable – related parties		1,071.5		139.6		(1,106.0	)		105.1		1.1		(1.1	)		105.1
Accrued product payables		1,944.5		1,670.3		(1.1	)		3,613.7		--		--			3,613.7
Accrued interest		340.7		0.1		--			340.8		--		--			340.8
Derivative liabilities		590.3		147.4		--			737.7		--		--			737.7
Other current liabilities		173.5		316.5		(12.0	)		478.0		--		0.7			478.7
Total current liabilities		6,830.3		2,546.1		(1,126.6	)		8,249.8		1.1		(0.4	)		8,250.5
Long-term debt		21,105.7		15.2		--			21,120.9		--		--			21,120.9
Deferred tax liabilities		5.0		45.1		(1.1	)		49.0		--		3.7			52.7
Other long-term liabilities		13.5		400.6		(179.8	)		234.3		269.6		--			503.9
Commitments and contingencies
Equity:
Partners' and other owners' equity		22,329.9		41,675.3		(41,713.4	)		22,291.8		22,047.0		(22,291.8	)		22,047.0
Noncontrolling interests		--		78.0		170.7			248.7		--		(29.7	)		219.0
Total equity		22,329.9		41,753.3		(41,542.7	)		22,540.5		22,047.0		(22,321.5	)		22,266.0
Total liabilities and equity	$	50,284.4	$	44,760.3	$	(42,850.2	)	$	52,194.5	$	22,317.7	$	(22,318.2	)	$	52,194.0

Condensed Consolidating Statement of Operations

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended March 31, 2017

	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	$	12,532.8		$	4,308.2		$	(9,520.6	)	$	7,320.4		$	--		$	--		$	7,320.4
Costs and expenses:
Operating costs and expenses		12,239.0			3,615.0			(9,520.8	)		6,333.2			--			--			6,333.2
General and administrative costs		7.4			42.7			(0.2	)		49.9			0.5			--			50.4
Total costs and expenses		12,246.4			3,657.7			(9,521.0	)		6,383.1			0.5			--			6,383.6
Equity in income of unconsolidated affiliates		728.8			133.4			(767.4	)		94.8			766.7			(766.7	)		94.8
Operating income		1,015.2			783.9			(767.0	)		1,032.1			766.2			(766.7	)		1,031.6
Other income (expense):
Interest expense		(248.8	)		(2.7	)		2.2			(249.3	)		--			--			(249.3	)
Other, net		2.2			0.2			(2.2	)		0.2			(5.5	)		--			(5.3	)
Total other expense, net		(246.6	)		(2.5	)		--			(249.1	)		(5.5	)		--			(254.6	)
Income before income taxes		768.6			781.4			(767.0	)		783.0			760.7			(766.7	)		777.0
Provision for income taxes		(2.9	)		(2.6	)		--			(5.5	)		--			(0.5	)		(6.0	)
Net income		765.7			778.8			(767.0	)		777.5			760.7			(767.2	)		771.0
Net income attributable to noncontrolling interests		--			(1.7	)		(9.9	)		(11.6	)		--			1.3			(10.3	)
Net income attributable to entity	$	765.7		$	777.1		$	(776.9	)	$	765.9		$	760.7		$	(765.9	)	$	760.7

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Operations

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Revenues	$	5,361.9		$	3,282.7		$	(3,639.3	)	$	5,005.3		$	--	$	--		$	5,005.3
Costs and expenses:
Operating costs and expenses		5,091.2			2,695.1			(3,639.4	)		4,146.9			--		--			4,146.9
General and administrative costs		6.0			36.8			--			42.8			1.1		--			43.9
Total costs and expenses		5,097.2			2,731.9			(3,639.4	)		4,189.7			1.1		--			4,190.8
Equity in income of unconsolidated affiliates		632.7			133.6			(665.2	)		101.1			660.1		(660.1	)		101.1
Operating income		897.4			684.4			(665.1	)		916.7			659.0		(660.1	)		915.6
Other income (expense):
Interest expense		(237.1	)		(5.2	)		1.7			(240.6	)		--		--			(240.6	)
Other, net		1.8			1.3			(1.7	)		1.4			2.2		--			3.6
Total other income (expense), net		(235.3	)		(3.9	)		--			(239.2	)		2.2		--			(237.0	)
Income before income taxes		662.1			680.5			(665.1	)		677.5			661.2		(660.1	)		678.6
Provision for income taxes		(2.9	)		(5.1	)		--			(8.0	)		--		(0.4	)		(8.4	)
Net income		659.2			675.4			(665.1	)		669.5			661.2		(660.5	)		670.2
Net income attributable to noncontrolling interests		--			(1.3	)		(8.9	)		(10.2	)		--		1.2			(9.0	)
Net income attributable to entity	$	659.2		$	674.1		$	(674.0	)	$	659.3		$	661.2	$	(659.3	)	$	661.2

Condensed Consolidating Statement of Comprehensive Income

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended March 31, 2017

	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	$	870.1	$	838.3		$	(767.0	)	$	941.4		$	924.5	$	(931.1	)	$	934.8
Comprehensive income attributable to noncontrolling interests		--		(1.7	)		(9.9	)		(11.6	)		--		1.3			(10.3	)
Comprehensive income attributable to entity	$	870.1	$	836.6		$	(776.9	)	$	929.8		$	924.5	$	(929.8	)	$	924.5

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Comprehensive Income

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)		Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)		Eliminations and Adjustments			Consolidated Total
Comprehensive income	$	655.2	$	630.1		$	(665.0	)	$	620.3		$	611.9	$	(611.3	)	$	620.9
Comprehensive income attributable to noncontrolling interests		--		(1.3	)		(8.9	)		(10.2	)		--		1.2			(9.0	)
Comprehensive income attributable to entity	$	655.2	$	628.8		$	(673.9	)	$	610.1		$	611.9	$	(610.1	)	$	611.9

Condensed Consolidating Statement of Cash Flows

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Three Months Ended March 31, 2017

	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	$	765.7		$	778.8		$	(767.0	)	$	777.5		$	760.7		$	(767.2	)	$	771.0
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		51.3			351.1			(0.1	)		402.3			--			--			402.3
Equity in income of unconsolidated affiliates		(728.8	)		(133.4	)		767.4			(94.8	)		(766.7	)		766.7			(94.8	)
Distributions received on earnings from unconsolidated affiliates		255.4			62.4			(227.3	)		90.5			870.5			(870.5	)		90.5
Net effect of changes in operating accounts and other operating activities		631.0			(958.0	)		1.4			(325.6	)		31.9			0.3			(293.4	)
Net cash flows provided by operating activities		974.6			100.9			(225.6	)		849.9			896.4			(870.7	)		875.6
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(125.5	)		(304.9	)		--			(430.4	)		--			--			(430.4	)
Cash used for pending business combination		--			(16.0	)		--			(16.0	)		--			--			(16.0	)
Proceeds from asset sales		1.2			0.8			--			2.0			--			--			2.0
Other investing activities		(155.9	)		4.5			461.6			310.2			(445.6	)		445.6			310.2
Cash used in investing activities		(280.2	)		(315.6	)		461.6			(134.2	)		(445.6	)		445.6			(134.2	)
Financing activities:
Borrowings under debt agreements		17,575.1			--			--			17,575.1			--			--			17,575.1
Repayments of debt		(17,856.4	)		(0.1	)		--			(17,856.5	)		--			--			(17,856.5	)
Cash distributions paid to owners		(870.5	)		(242.6	)		242.6			(870.5	)		(869.0	)		870.5			(869.0	)
Cash payments made in connection with DERs		--			--			--			--			(3.2	)		--			(3.2	)
Cash distributions paid to noncontrolling interests		--			(2.5	)		(7.8	)		(10.3	)		--			0.2			(10.1	)
Cash contributions from noncontrolling interests		--			0.1			0.1			0.2			--			--			0.2
Net cash proceeds from issuance of common units		--			--			--			--			448.8			--			448.8
Cash contributions from owners		445.6			469.2			(469.2	)		445.6			--			(445.6	)		--
Other financing activities		--			--			--			--			(27.4	)		--			(27.4	)
Cash provided by (used in) financing activities		(706.2	)		224.1			(234.3	)		(716.4	)		(450.8	)		425.1			(742.1	)
Net change in cash and cash equivalents		(11.8	)		9.4			1.7			(0.7	)		--			--			(0.7	)
Cash and cash equivalents, January 1		13.4			57.2			(7.5	)		63.1			--			--			63.1
Cash and cash equivalents, March 31	$	1.6		$	66.6		$	(5.8	)	$	62.4		$	--		$	--		$	62.4

Enterprise Products Partners L.P.

Unaudited Condensed Consolidating Statement of Cash Flows

For the Three Months Ended March 31, 2016

	EPO and Subsidiaries
	Subsidiary Issuer (EPO)			Other Subsidiaries (Non- guarantor)			EPO and Subsidiaries Eliminations and Adjustments			Consolidated EPO and Subsidiaries			Enterprise Products Partners L.P. (Guarantor)			Eliminations and Adjustments			Consolidated Total
Operating activities:
Net income	$	659.2		$	675.4		$	(665.1	)	$	669.5		$	661.2		$	(660.5	)	$	670.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion		42.5			339.7			(0.1	)		382.1			--			--			382.1
Equity in income of unconsolidated affiliates		(632.7	)		(133.6	)		665.2			(101.1	)		(660.1	)		660.1			(101.1	)
Distributions received on earnings from unconsolidated affiliates		247.2			74.2			(214.7	)		106.7			788.5			(788.5	)		106.7
Net effect of changes in operating accounts and other operating activities		35.5			(255.3	)		42.4			(177.4	)		18.8			0.4			(158.2	)
Net cash flows provided by operating activities		351.7			700.4			(172.3	)		879.8			808.4			(788.5	)		899.7
Investing activities:
Capital expenditures, net of contributions in aid of construction costs		(307.6	)		(687.4	)		--			(995.0	)		--			--			(995.0	)
Proceeds from asset sales		0.1			13.3			--			13.4			--			--			13.4
Other investing activities		(387.5	)		(55.7	)		260.9			(182.3	)		(1,008.6	)		1,008.6			(182.3	)
Cash used in investing activities		(695.0	)		(729.8	)		260.9			(1,163.9	)		(1,008.6	)		1,008.6			(1,163.9	)
Financing activities:
Borrowings under debt agreements		20,000.6			--			--			20,000.6			--			--			20,000.6
Repayments of debt		(19,797.3	)		(0.1	)		--			(19,797.4	)		--			--			(19,797.4	)
Cash distributions paid to owners		(788.5	)		(222.9	)		222.9			(788.5	)		(788.3	)		788.5			(788.3	)
Cash payments made in connection with DERs		--			--			--			--			(2.0	)		--			(2.0	)
Cash distributions paid to noncontrolling interests		--			(0.5	)		(8.2	)		(8.7	)		--			--			(8.7	)
Cash contributions from noncontrolling interests		--			11.1			--			11.1			--			--			11.1
Net cash proceeds from issuance of common units		--			--			--			--			1,011.5			--			1,011.5
Cash contributions from owners		1,008.6			260.9			(260.9	)		1,008.6			--			(1,008.6	)		--
Other financing activities		--			--			--			--			(21.0	)		--			(21.0	)
Cash provided by financing activities		423.4			48.5			(46.2	)		425.7			200.2			(220.1	)		405.8
Net change in cash and cash equivalents		80.1			19.1			42.4			141.6			--			--			141.6
Cash and cash equivalents, January 1		--			69.6			(50.6	)		19.0			--			--			19.0
Cash and cash equivalents, March 31	$	80.1		$	88.7		$	(8.2	)	$	160.6		$	--		$	--		$	160.6

Partnership Operations, Organization and Basis for Presentation (Details) bbl in Millions	3 Months Ended
	Mar. 31, 2017 Segment mi bbl Bcf
Related Party Transaction [Line Items]
Number of miles of pipelines \| mi	50,000
Number of barrels of storage capacity \| bbl	260
Number of cubic feet of storage capacity \| Bcf	14
Number of reportable segments \| Segment	4
Limited partners ownership interest	100.00%
EPCO and its privately held affiliates [Member]
Related Party Transaction [Line Items]
Percentage of Total Units Outstanding	32.00%

General Accounting and Disclosure Matters (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted cash	$ 44.7	$ 354.5

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Dec. 31, 2016

Inventory by Product Type [Abstract]

NGLs

$ 1,107.5

$ 1,156.1

Petrochemicals and refined products

474.2

220.7

Crude oil

319.5

360.0

Natural gas

20.8

33.7

Total

1,922.0

$ 1,770.5

Summary of cost of sales and lower of cost or net realizable value adjustments [Abstract]

Cost of sales

^[1]

5,335.7

$ 3,208.3

Lower of cost or net realizable value adjustments within cost of sales

$ 3.4

$ 5.3

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Dec. 31, 2016

Property, plant and equipment and accumulated depreciation [Abstract]

Property, plant and equipment, gross

$ 43,536.7

$ 43,003.3

Less accumulated depreciation

9,980.6

9,710.8

Property, plant and equipment, net

33,556.1

33,292.5

Summary of depreciation expense and capitalized interest [Abstract]

Depreciation expense

^[1]

317.5

$ 295.9

Capitalized interest

^[2]

39.6

$ 42.5

Asset Retirement Obligations [Roll Forward]

Balance at beginning of period

85.4

Liabilities settled

(1.0)

Accretion expense

1.3

Balance at end of period

85.7

Capitalized costs, asset retirement costs

44.2

44.9

Plants, pipelines and facilities [Member]

Property, plant and equipment and accumulated depreciation [Abstract]

Property, plant and equipment, gross

^[3]

$ 35,382.6

35,124.6

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]

$ 3,352.8

3,326.9

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]

$ 169.2

165.8

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]

$ 801.2

800.7

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

$ 265.1

264.6

Construction in progress [Member]

Property, plant and equipment and accumulated depreciation [Abstract]

Property, plant and equipment, gross

$ 3,565.8

$ 3,320.7

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, Other (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2017	Mar. 31, 2017	Mar. 31, 2016
Business Acquisition [Line Items]
Cash used for pending business combination		$ 16.0	$ 0.0
Azure Midstream Partners, L.P. [Member]
Business Acquisition [Line Items]
Business combination, description		Azure’s assets, which are located in East Texas and North Louisiana, include over 960 miles of natural gas gathering pipelines, three natural gas processing facilities with an aggregate processing capacity of approximately 210 million cubic feet per day, and two NGL pipelines with throughput capacities of 10 thousand barrels per day each. The Azure assets serve production from the Haynesville Shale and Bossier, Cotton Valley and Travis Peak formations.
Cash used for pending business combination		$ 16.0
Total consideration for acquisition	$ 189.0

Investments in Unconsolidated Affiliates (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 2,671.4		$ 2,677.3
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	94.8	$ 101.1
Unamortized excess cost amounts by business segment:
Unamortized excess cost amounts	44.5		45.2
Equity method investment amortization of excess cost	0.5	0.5
Income Statement Data:
Revenues	343.2	345.5
Operating income	203.7	213.7
Net income	202.9	215.2
NGL Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	15.5	15.1
Unamortized excess cost amounts by business segment:
Unamortized excess cost amounts	$ 23.8		24.1
NGL Pipelines & Services [Member] \| Venice Energy Service Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	13.10%
Investments in unconsolidated affiliates	$ 24.7		24.8
NGL Pipelines & Services [Member] \| K/D/S Promix, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 34.1		33.7
NGL Pipelines & Services [Member] \| Baton Rouge Fractionators LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	32.20%
Investments in unconsolidated affiliates	$ 17.5		17.3
NGL Pipelines & Services [Member] \| Skelly-Belvieu Pipeline Company, L.L.C. [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 38.7		38.9
NGL Pipelines & Services [Member] \| Texas Express Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	35.00%
Investments in unconsolidated affiliates	$ 330.3		331.9
NGL Pipelines & Services [Member] \| Texas Express Gathering LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	45.00%
Investments in unconsolidated affiliates	$ 36.0		35.8
NGL Pipelines & Services [Member] \| Front Range Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	33.30%
Investments in unconsolidated affiliates	$ 167.4		165.4
NGL Pipelines & Services [Member] \| Delaware Basin Gas Processing LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 109.4		102.6
Crude Oil Pipelines & Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	81.2	90.1
Unamortized excess cost amounts by business segment:
Unamortized excess cost amounts	$ 18.8		19.0
Crude Oil Pipelines & Services [Member] \| Seaway Crude Pipeline Company LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 1,386.5		1,393.8
Crude Oil Pipelines & Services [Member] \| Eagle Ford Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 383.7		377.9
Crude Oil Pipelines & Services [Member] \| Eagle Ford Terminals Corpus Christi LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 57.8		52.9
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	1.0
Natural Gas Pipelines & Services [Member] \| White River Hub, LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 21.5		21.7
Petrochemical & Refined Products Services [Member]
Equity in income (loss) of unconsolidated affiliates by business segment [Abstract]
Equity in income (loss) of unconsolidated affiliates	(2.9)	$ (5.1)
Unamortized excess cost amounts by business segment:
Unamortized excess cost amounts	$ 1.9		2.1
Petrochemical & Refined Products Services [Member] \| Centennial Pipeline LLC [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest	50.00%
Investments in unconsolidated affiliates	$ 58.8		62.3
Petrochemical & Refined Products Services [Member] \| Other Unconsolidated Affiliates [Member]
Schedule of Equity Method Investments [Line Items]
Investments in unconsolidated affiliates	$ 5.0		$ 18.3

Intangible Assets and Goodwill, Intangible Assets (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Identifiable intangible assets [Abstract]
Gross Value	$ 5,267.2		$ 5,267.2
Accumulated Amortization	(1,444.1)		(1,403.1)
Carrying Value	3,823.1		3,864.1
Amortization expense	41.0	$ 46.3
Forecasted amortization expense [Abstract]
Remainder of 2017	121.1
2018	163.8
2019	157.7
2020	152.8
2021	163.2
NGL Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	727.3		727.3
Accumulated Amortization	(384.4)		(377.1)
Carrying Value	342.9		350.2
Amortization expense	7.3	7.8
NGL Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	447.4		447.4
Accumulated Amortization	(176.4)		(172.7)
Carrying Value	271.0		274.7
NGL Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	279.9		279.9
Accumulated Amortization	(208.0)		(204.4)
Carrying Value	71.9		75.5
Crude Oil Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,485.4		2,485.4
Accumulated Amortization	(229.5)		(206.4)
Carrying Value	2,255.9		2,279.0
Amortization expense	23.1	27.7
Crude Oil Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	2,204.4		2,204.4
Accumulated Amortization	(95.2)		(84.5)
Carrying Value	2,109.2		2,119.9
Crude Oil Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	281.0		281.0
Accumulated Amortization	(134.3)		(121.9)
Carrying Value	146.7		159.1
Natural Gas Pipelines & Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,815.0		1,815.0
Accumulated Amortization	(768.7)		(760.5)
Carrying Value	1,046.3		1,054.5
Amortization expense	8.2	8.6
Natural Gas Pipelines & Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	1,350.3		1,350.3
Accumulated Amortization	(396.0)		(390.0)
Carrying Value	954.3		960.3
Natural Gas Pipelines & Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	464.7		464.7
Accumulated Amortization	(372.7)		(370.5)
Carrying Value	92.0		94.2
Petrochemical & Refined Products Services [Member]
Identifiable intangible assets [Abstract]
Gross Value	239.5		239.5
Accumulated Amortization	(61.5)		(59.1)
Carrying Value	178.0		180.4
Amortization expense	2.4	$ 2.2
Petrochemical & Refined Products Services [Member] \| Customer relationship intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	185.5		185.5
Accumulated Amortization	(45.5)		(43.9)
Carrying Value	140.0		141.6
Petrochemical & Refined Products Services [Member] \| Contract-based intangibles [Member]
Identifiable intangible assets [Abstract]
Gross Value	54.0		54.0
Accumulated Amortization	(16.0)		(15.2)
Carrying Value	$ 38.0		$ 38.8

Intangible Assets and Goodwill, Goodwill (Details) $ in Millions	Mar. 31, 2017 USD ($)
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	1,841.0
Balance at end of period	1,841.0
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) - USD ($)
$ in Millions

3 Months Ended

Mar. 31, 2017

Dec. 31, 2016

Debt Instrument [Line Items]

Principal outstanding

$ 23,624.8

$ 23,901.6

Other, non-principal amounts

(201.8)

(203.9)

Less current maturities of debt

(2,300.0)

(2,576.8)

Total long-term debt

21,123.0

21,120.9

Debt Obligations Terms:

Letters of credit outstanding

66.4

Senior Debt Obligations [Member]

Debt Instrument [Line Items]

Principal outstanding

22,150.4

22,427.2

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

Debt Instrument [Line Items]

Principal outstanding

$ 1,500.4

1,777.2

Debt Obligations Terms:

Interest rate terms

variable

Information regarding variable interest rates paid:

Weighted-average interest rate paid

1.10%

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

Information regarding variable interest rates paid:

Variable interest rates paid

0.90%

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

Information regarding variable interest rates paid:

Variable interest rates paid

1.33%

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

Debt Instrument [Line Items]

Principal outstanding

$ 800.0

800.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

6.30%

Maturity date

Sep. 01, 2017

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

Debt Instrument [Line Items]

Principal outstanding

$ 0.0

0.0

Debt Obligations Terms:

Interest rate terms

variable

Maturity date

Sep. 14, 2017

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

Debt Instrument [Line Items]

Principal outstanding

$ 349.7

349.7

Debt Obligations Terms:

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

$ 750.0

750.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

1.65%

Maturity date

May 07, 2018

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

Debt Instrument [Line Items]

Principal outstanding

$ 700.0

700.0

Debt Obligations Terms:

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

$ 800.0

800.0

Debt Obligations Terms:

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

$ 500.0

500.0

Debt Obligations Terms:

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

$ 1,000.0

1,000.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

5.20%

Maturity date

Sep. 01, 2020

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

Debt Instrument [Line Items]

Principal outstanding

$ 0.0

0.0

Debt Obligations Terms:

Interest rate terms

variable

Maturity date

Sep. 15, 2020

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

Debt Instrument [Line Items]

Principal outstanding

$ 575.0

575.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

2.85%

Maturity date

Apr. 15, 2021

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

Debt Instrument [Line Items]

Principal outstanding

$ 650.0

650.0

Debt Obligations Terms:

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

$ 1,250.0

1,250.0

Debt Obligations Terms:

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

$ 850.0

850.0

Debt Obligations Terms:

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

$ 1,150.0

1,150.0

Debt Obligations Terms:

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

$ 875.0

875.0

Debt Obligations Terms:

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

575.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

3.95%

Maturity date

Feb. 15, 2027

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

Debt Instrument [Line Items]

Principal outstanding

$ 500.0

500.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

6.875%

Maturity date

Mar. 01, 2033

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

Debt Instrument [Line Items]

Principal outstanding

$ 350.0

350.0

Debt Obligations Terms:

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

$ 250.0

250.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

5.75%

Maturity date

Mar. 01, 2035

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

Debt Instrument [Line Items]

Principal outstanding

$ 399.6

399.6

Debt Obligations Terms:

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

$ 600.0

600.0

Debt Obligations Terms:

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

$ 600.0

600.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

6.45%

Maturity date

Sep. 01, 2040

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

Debt Instrument [Line Items]

Principal outstanding

$ 750.0

750.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

5.95%

Maturity date

Feb. 01, 2041

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

Debt Instrument [Line Items]

Principal outstanding

$ 600.0

600.0

Debt Obligations Terms:

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

$ 750.0

750.0

Debt Obligations Terms:

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

$ 1,100.0

1,100.0

Debt Obligations Terms:

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

$ 1,400.0

1,400.0

Debt Obligations Terms:

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

$ 1,150.0

1,150.0

Debt Obligations Terms:

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

$ 975.0

975.0

Debt Obligations Terms:

Interest rate terms

fixed

Interest rate, stated percentage

4.90%

Maturity date

May 15, 2046

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

Debt Instrument [Line Items]

Principal outstanding

$ 400.0

400.0

Debt Obligations Terms:

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:

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:

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:

Interest rate terms

^[1]

variable

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:

Weighted-average interest rate paid

4.69%

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

Information regarding variable interest rates paid:

Variable interest rates paid

4.59%

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

Information regarding variable interest rates paid:

Variable interest rates paid

4.74%

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

Debt Instrument [Line Items]

Principal outstanding

^[2]

$ 256.4

256.4

Debt Obligations Terms:

Interest rate terms

^[2]

fixed/variable

Interest rate, stated percentage

7.00%

Maturity date

^[2]

Jun. 01, 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:

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

Debt Obligations Terms:

Interest rate terms

fixed/variable

Maturity date

Jun. 01, 2067

[1]	Variable rate is reset quarterly and 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 Maturities (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Scheduled Maturities of Debt [Abstract]
Remainder of 2017	$ 2,300.4
2018	1,100.0
2019	1,500.0
2020	1,500.0
2021	575.0
After 2021	16,649.4
Total	23,624.8	$ 23,901.6
Commercial Paper Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2017	1,500.4
2018	0.0
2019	0.0
2020	0.0
2021	0.0
After 2021	0.0
Total	1,500.4
Senior Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2017	800.0
2018	1,100.0
2019	1,500.0
2020	1,500.0
2021	575.0
After 2021	15,175.0
Total	20,650.0
Junior Subordinated Notes [Member]
Scheduled Maturities of Debt [Abstract]
Remainder of 2017	0.0
2018	0.0
2019	0.0
2020	0.0
2021	0.0
After 2021	1,474.4
Total	$ 1,474.4

Equity and Distributions, Summary of Changes in Outstanding Units (Details)	3 Months Ended
	Mar. 31, 2017 shares
Common Units (Unrestricted) [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	2,116,906,120
Common units issued in connection with ATM program (in units)	12,865,371
Common units issued in connection with DRIP and EUPP (in units)	3,440,559
Common units issued in connection with the vesting of phantom unit awards (in units)	2,234,067
Common units issued in connection with the vesting of restricted common unit awards (in units)	665,920
Forfeiture of restricted common unit awards (in units)	0
Cancellation of treasury units acquired in connection with the vesting of equity-based awards (in units)	(946,291)
Common units issued in connection with employee compensation (in units)	1,176,103
Other (in units)	14,685
Ending Balance (in units)	2,136,356,534
Restricted Common Units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	682,294
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)	(665,920)
Forfeiture of restricted common unit awards (in units)	(1,250)
Cancellation of treasury units acquired in connection with the vesting of equity-based awards (in units)	0
Common units issued in connection with employee compensation (in units)	0
Other (in units)	0
Ending Balance (in units)	15,124
Common Units [Member]
Summary of changes in outstanding units [Roll Forward]
Beginning Balance (in units)	2,117,588,414
Common units issued in connection with ATM program (in units)	12,865,371
Common units issued in connection with DRIP and EUPP (in units)	3,440,559
Common units issued in connection with the vesting of phantom unit awards (in units)	2,234,067
Common units issued in connection with the vesting of restricted common unit awards (in units)	0
Forfeiture of restricted common unit awards (in units)	(1,250)
Cancellation of treasury units acquired in connection with the vesting of equity-based awards (in units)	(946,291)
Common units issued in connection with employee compensation (in units)	1,176,103
Other (in units)	14,685
Ending Balance (in units)	2,136,371,658

Equity and Distributions, Issuances of Equity (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Net Cash Proceeds from Sale of Common Units [Abstract]
Net cash proceeds from the issuance of common units	$ 448.8	$ 1,011.5
At-the-Market Registration [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance	1,890.0
Remaining units available for issuance	$ 1,080.0
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	12,865,371	35,396,147
Gross proceeds from the sale of common units	$ 359.7	$ 856.5
Net cash proceeds from the issuance of common units	$ 356.0	$ 849.0
At-the-Market Registration [Member] \| EPCO and its privately held affiliates [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)		3,830,256
Gross proceeds from the sale of common units		$ 100.0
Distribution Reinvestment Plan [Member]
Registration Statements and Equity Offerings [Line Items]
Maximum common units authorized for issuance (in units)		240,000,000
Remaining units available for issuance (in units)	95,932,697
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	3,325,798	7,162,744
Net cash proceeds from the issuance of common units	$ 89.6	$ 159.8
Distribution Reinvestment Plan [Member] \| EPCO and its privately held affiliates [Member]
Net Cash Proceeds from Sale of Common Units [Abstract]
Net cash proceeds from the issuance of common units		$ 100.0
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)	6,150,714
Net Cash Proceeds from Sale of Common Units [Abstract]
Number of common units issued (in units)	114,761	119,262
Net cash proceeds from the issuance of common units	$ 3.2	$ 2.7

Equity and Distributions, Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	$ (280.0)	$ (219.2)
Other comprehensive income (loss) before reclassifications	147.1	(1.3)
Amounts reclassified from accumulated other comprehensive loss (income)	16.7	(48.0)
Total other comprehensive income (loss)	163.8	(49.3)
Ending Balance	(116.2)	(268.5)
Interest expense	249.3	240.6
Revenue	(7,320.4)	(5,005.3)
Operating costs and expenses	6,333.2	4,146.9
Total	(771.0)	(670.2)
Gains and Losses on Cash Flow Hedges [Member] \| Interest Rate Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	(199.8)	(279.5)
Other comprehensive income (loss) before reclassifications	2.4	0.0
Amounts reclassified from accumulated other comprehensive loss (income)	9.6	9.2
Total other comprehensive income (loss)	12.0	9.2
Ending Balance	(187.8)	(270.3)
Gains and Losses on Cash Flow Hedges [Member] \| Commodity Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	(83.8)	56.6
Other comprehensive income (loss) before reclassifications	144.8	(1.2)
Amounts reclassified from accumulated other comprehensive loss (income)	7.1	(57.2)
Total other comprehensive income (loss)	151.9	(58.4)
Ending Balance	68.1	(1.8)
Other [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Beginning Balance	3.6	3.7
Other comprehensive income (loss) before reclassifications	(0.1)	(0.1)
Amounts reclassified from accumulated other comprehensive loss (income)	0.0	0.0
Total other comprehensive income (loss)	(0.1)	(0.1)
Ending Balance	3.5	3.6
Reclassification out of Accumulated Other Comprehensive Income (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Total	16.7	(48.0)
Reclassification out of Accumulated Other Comprehensive Income (Loss) [Member] \| Gains and Losses on Cash Flow Hedges [Member] \| Interest Rate Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Interest expense	9.6	9.2
Reclassification out of Accumulated Other Comprehensive Income (Loss) [Member] \| Gains and Losses on Cash Flow Hedges [Member] \| Commodity Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Abstract]
Revenue	7.5	(58.8)
Operating costs and expenses	$ (0.4)	$ 1.6

Equity and Distributions, Distributions (Details) - Cash Distribution [Member] - $ / shares	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
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 06, 2016
First Quarter 2017 Distribution [Member]
Distributions to Partners [Abstract]
Distribution Per Common Unit (in dollars per unit)	$ 0.4150
Record Date	Apr. 28, 2017
Payment Date	May 08, 2017

Business Segments (Details)
$ in Millions

3 Months Ended

Mar. 31, 2017

USD ($)

Segment

Mar. 31, 2016

USD ($)

Business Segments [Abstract]

Number of reportable segments | Segment

Segment Gross Operating Margin [Abstract]

Income before income taxes

$ 777.0

$ 678.6

Add total other expense, net

254.6

237.0

Operating income

1,031.6

915.6

Adjustments to reconcile operating income to total gross operating margin:

Add depreciation, amortization and accretion expense in operating costs and expenses

376.2

358.2

Add asset impairment and related charges in operating costs and expenses

11.2

1.7

Add net losses or subtract net gains attributable to asset sales in operating costs and expenses

(0.3)

4.9

Add general and administrative costs

50.4

43.9

Adjustments for make-up rights on certain new pipeline projects:

Add non-refundable payments received from shippers attributable to make-up rights

^[1]

13.3

7.1

Subtract the subsequent recognition of revenues attributable to make-up rights

^[2]

(9.1)

(12.9)

Total segment gross operating margin

$ 1,473.3

$ 1,318.5

[1]	Since make-up rights entail a future performance obligation by the pipeline to the shipper, these receipts are recorded as deferred revenue for GAAP purposes; however, these receipts are included in gross operating margin in the period of receipt since they are nonrefundable to the shipper.
[2]	As deferred revenues attributable to make-up rights are subsequently recognized as revenue under GAAP, gross operating margin must be adjusted to remove such amounts to prevent duplication since the associated non-refundable payments were previously included in gross operating margin.

Business Segments, Segment Reporting Information (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Information by business segment [Abstract]
Revenues from third parties	$ 7,309.6	$ 4,989.7
Revenues from related parties	10.8	15.6
Intersegment and intrasegment revenues	0.0	0.0
Total revenues	7,320.4	5,005.3
Equity in income (loss) of unconsolidated affiliates	94.8	101.1
Total segment gross operating margin	1,473.3	1,318.5
Property, plant and equipment, net	33,556.1		$ 33,292.5
Investments in unconsolidated affiliates	2,671.4		2,677.3
Intangible assets, net	3,823.1		3,864.1
Goodwill	5,745.2		5,745.2
Segment assets	45,795.8		45,579.1
NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	3,345.8	2,403.8
Equity in income (loss) of unconsolidated affiliates	15.5	15.1
Intangible assets, net	342.9		350.2
Goodwill	2,651.7		2,651.7
Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	1,807.2	1,288.6
Equity in income (loss) of unconsolidated affiliates	81.2	90.1
Intangible assets, net	2,255.9		2,279.0
Goodwill	1,841.0		1,841.0
Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Total revenues	761.2	550.0
Equity in income (loss) of unconsolidated affiliates	1.0	1.0
Intangible assets, net	1,046.3		1,054.5
Goodwill	296.3		296.3
Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Total revenues	1,406.2	762.9
Equity in income (loss) of unconsolidated affiliates	(2.9)	(5.1)
Intangible assets, net	178.0		180.4
Goodwill	956.2		956.2
Reportable Business Segments [Member] \| NGL Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	3,343.0	2,402.0
Revenues from related parties	2.8	1.8
Intersegment and intrasegment revenues	8,874.8	3,174.8
Total revenues	12,220.6	5,578.6
Equity in income (loss) of unconsolidated affiliates	15.5	15.1
Total segment gross operating margin	856.0	783.7
Property, plant and equipment, net	14,003.1		14,091.5
Investments in unconsolidated affiliates	758.1		750.4
Intangible assets, net	342.9		350.2
Goodwill	2,651.7		2,651.7
Segment assets	17,755.8		17,843.8
Reportable Business Segments [Member] \| Crude Oil Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	1,802.6	1,277.5
Revenues from related parties	4.6	11.1
Intersegment and intrasegment revenues	3,474.0	1,499.4
Total revenues	5,281.2	2,788.0
Equity in income (loss) of unconsolidated affiliates	81.2	90.1
Total segment gross operating margin	264.6	202.3
Property, plant and equipment, net	4,346.9		4,216.1
Investments in unconsolidated affiliates	1,828.0		1,824.6
Intangible assets, net	2,255.9		2,279.0
Goodwill	1,841.0		1,841.0
Segment assets	10,271.8		10,160.7
Reportable Business Segments [Member] \| Natural Gas Pipelines & Services [Member]
Information by business segment [Abstract]
Revenues from third parties	757.8	547.3
Revenues from related parties	3.4	2.7
Intersegment and intrasegment revenues	194.5	124.7
Total revenues	955.7	674.7
Equity in income (loss) of unconsolidated affiliates	1.0	1.0
Total segment gross operating margin	170.9	177.7
Property, plant and equipment, net	8,355.6		8,403.0
Investments in unconsolidated affiliates	21.5		21.7
Intangible assets, net	1,046.3		1,054.5
Goodwill	296.3		296.3
Segment assets	9,719.7		9,775.5
Reportable Business Segments [Member] \| Petrochemical & Refined Products Services [Member]
Information by business segment [Abstract]
Revenues from third parties	1,406.2	762.9
Revenues from related parties	0.0	0.0
Intersegment and intrasegment revenues	414.7	242.7
Total revenues	1,820.9	1,005.6
Equity in income (loss) of unconsolidated affiliates	(2.9)	(5.1)
Total segment gross operating margin	181.8	154.8
Property, plant and equipment, net	3,284.7		3,261.2
Investments in unconsolidated affiliates	63.8		80.6
Intangible assets, net	178.0		180.4
Goodwill	956.2		956.2
Segment assets	4,482.7		4,478.4
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	(12,958.0)	(5,041.6)
Total revenues	(12,958.0)	(5,041.6)
Equity in income (loss) of unconsolidated affiliates	0.0	$ 0.0
Adjustments [Member]
Information by business segment [Abstract]
Property, plant and equipment, net	3,565.8		3,320.7
Investments in unconsolidated affiliates	0.0		0.0
Intangible assets, net	0.0		0.0
Goodwill	0.0		0.0
Segment assets	$ 3,565.8		$ 3,320.7

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Consolidated Revenues [Abstract]

Total consolidated revenues

$ 7,320.4

$ 5,005.3

Operating costs and expenses:

Cost of sales

^[1]

5,335.7

3,208.3

Other operating costs and expenses

^[2]

610.4

573.8

Depreciation, amortization and accretion

376.2

358.2

Impairment and related charges

11.2

1.7

Net losses (gains) attributable to asset sales

(0.3)

4.9

General and administrative costs

50.4

43.9

Total consolidated costs and expenses

6,383.6

4,190.8

NGL Pipelines & Services [Member]

Consolidated Revenues [Abstract]

Sales of NGLs and related products

2,887.2

1,943.5

Midstream services

458.6

460.3

Total consolidated revenues

3,345.8

2,403.8

Crude Oil Pipelines & Services [Member]

Consolidated Revenues [Abstract]

Sales of crude oil

1,618.6

1,121.1

Midstream services

188.6

167.5

Total consolidated revenues

1,807.2

1,288.6

Natural Gas Pipelines & Services [Member]

Consolidated Revenues [Abstract]

Sales of natural gas

544.0

315.0

Midstream services

217.2

235.0

Total consolidated revenues

761.2

550.0

Petrochemical & Refined Products Services [Member]

Consolidated Revenues [Abstract]

Sales of petrochemicals and refined products

1,211.1

553.2

Midstream services

195.1

209.7

Total consolidated revenues

$ 1,406.2

$ 762.9

[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 and related charges; and net losses (or gains) attributable to asset sales.

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

BASIC EARNINGS PER UNIT

Net income attributable to limited partners

$ 760.7

$ 661.2

Undistributed earnings allocated and cash payments on phantom unit awards

^[1]

(4.0)

(3.2)

Net income available to common unitholders

$ 756.7

$ 658.0

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

2,126.2

2,033.6

Basic earnings per unit (in dollars per unit)

$ 0.36

$ 0.32

DILUTED EARNINGS PER UNIT

Net income attributable to limited partners

$ 760.7

$ 661.2

Diluted weighted-average number of units outstanding:

Distribution-bearing common units (in units)

2,126.2

2,033.6

Phantom units (in units)

^[1]

8.7

6.9

Total (in units)

2,134.9

2,040.5

Diluted earnings per unit (in dollars per unit)

$ 0.36

$ 0.32

[1]

Each phantom unit award includes a distribution equivalent right ("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) - USD ($) $ in Millions	3 Months Ended
Equity-Based Awards (Details) - USD ($) $ in Millions	Mar. 31, 2017	Mar. 31, 2016
Equity-based compensation expense [Abstract]
Total compensation expense	$ 25.0	$ 22.4
Phantom Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	22.8	19.4
Restricted Common Unit Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	0.5	2.2
Profits Interest Awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	1.5	0.7
Liability-classified awards [Member]
Equity-based compensation expense [Abstract]
Total compensation expense	$ 0.2	$ 0.1
Long-Term Incentive Plan (2008) [Member]
Equity-based compensation expense [Abstract]
Maximum number of common units that may be issued as awards (in units)	40,000,000
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)	18,863,972

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

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

Cash payments made in connection with DERs

$ 3.2

$ 2.0

Phantom Unit Awards [Member]

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

Vesting rate of phantom unit awards

25.00%

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

Beginning of period (in units)

7,767,501

Granted (in units)

^[1]

4,203,510

Vested (in units)

(2,238,568)

Forfeited (in units)

(41,684)

End of period (in units)

9,690,759

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]

$ 27.20

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

^[1],[2]

28.87

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

^[2]

28.33

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

^[2]

28.19

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

^[2]

$ 27.66

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

Aggregate grant date fair value

$ 121.4

Estimated forfeiture rate

3.80%

Cash payments made in connection with DERs

$ 3.2

2.0

Total intrinsic value of phantom unit awards that vested during period

63.2

$ 36.3

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 166.1

Recognition period for total unrecognized compensation cost

2 years 3 months 18 days

Phantom Unit Awards [Member] | Minimum [Member]

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

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

$ 28.87

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)

$ 28.87

Phantom Unit Awards [Member] | Enterprise [Member]

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 145.8

[1]	The aggregate grant date fair value of phantom unit awards issued during 2017 was $121.4 million based on a grant date market price of our common units of $28.87 per unit. An estimated annual forfeiture rate of 3.8% 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 Unit Awards (Details) - Restricted Common Unit Awards [Member] - USD ($)
$ / shares in Units, $ in Millions

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

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

Vesting rate of restricted common unit awards

25.00%

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

Beginning of period (in units)

682,294

Vested (in units)

(665,920)

Forfeited (in units)

(1,250)

End of period (in units)

15,124

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]

$ 28.61

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

^[1]

28.56

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

^[1]

31.07

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

^[1]

$ 30.74

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

Cash distributions paid to restricted common unitholders

$ 0.3

$ 0.8

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

$ 18.5

$ 26.8

[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, Profits Interest Awards (Details) - Profits Interest Awards [Member]
$ / shares in Units, $ in Millions

3 Months Ended

Mar. 31, 2017

USD ($)

$ / shares

EPD PubCo I [Member]

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

Common units owned by Employee Partnership (in units) | shares

2,723,052

Class A capital base

$ 63.7

^[1]

Class A partner preference return | $ / shares

$ 0.39

^[2]

Expected liquidation date

Feb. 01, 2020

Estimated grant date fair value of profits interest awards

$ 13.2

^[3]

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 9.6

^[4]

Recognition period for total unrecognized compensation cost

2 years 10 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

6.80%

Expected Unit Price Volatility

40.00%

EPD PubCo II [Member]

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

Common units owned by Employee Partnership (in units) | shares

2,834,198

Class A capital base

$ 66.3

^[1]

Class A partner preference return | $ / shares

$ 0.39

^[2]

Expected liquidation date

Feb. 01, 2021

Estimated grant date fair value of profits interest awards

$ 14.7

^[3]

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 11.5

^[4]

Recognition period for total unrecognized compensation cost

3 years 10 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

6.10%

Expected Unit Price Volatility

27.00%

EPD PubCo II [Member] | Maximum [Member]

Estimated Grant Date Fair Value Assumptions [Abstract]

Risk-Free Interest Rate

1.60%

Expected Distribution Yield

6.80%

Expected Unit Price Volatility

40.00%

EPD PubCo III [Member]

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

Common units owned by Employee Partnership (in units) | shares

105,000

Class A capital base

$ 2.5

^[1]

Class A partner preference return | $ / shares

$ 0.39

^[2]

Expected liquidation date

Apr. 01, 2020

Estimated grant date fair value of profits interest awards

$ 0.6

^[3]

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 0.4

^[4]

Recognition period for total unrecognized compensation cost

3 years

Estimated Grant Date Fair Value Assumptions [Abstract]

Expected Life of Award

4 years

EPD PubCo III [Member] | Minimum [Member]

Estimated Grant Date Fair Value Assumptions [Abstract]

Risk-Free Interest Rate

1.00%

Expected Distribution Yield

6.10%

Expected Unit Price Volatility

31.00%

EPD PubCo III [Member] | Maximum [Member]

Estimated Grant Date Fair Value Assumptions [Abstract]

Risk-Free Interest Rate

1.40%

Expected Distribution Yield

6.20%

Expected Unit Price Volatility

40.00%

EPD PrivCo I [Member]

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

Common units owned by Employee Partnership (in units) | shares

1,111,438

Class A capital base

$ 26.0

^[1]

Class A partner preference return | $ / shares

$ 0.39

^[2]

Expected liquidation date

Feb. 01, 2021

Estimated grant date fair value of profits interest awards

$ 5.8

^[3]

Unrecognized Compensation Expense [Abstract]

Unrecognized compensation cost

$ 1.0

^[4]

Recognition period for total unrecognized compensation cost

3 years 10 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

1.20%

Expected Distribution Yield

6.10%

Expected Unit Price Volatility

28.00%

EPD PrivCo I [Member] | Maximum [Member]

Estimated Grant Date Fair Value Assumptions [Abstract]

Risk-Free Interest Rate

1.60%

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]	Each quarter, the Class A limited partner in each Employee Partnership is paid a cash distribution equal to the product of (i) the number of common units owned by the Employee Partnership and (ii) the Class A Preference Return of $0.39 per unit (subject to equitable adjustment in order to reflect any equity split, equity distribution or dividend, reverse split, combination, reclassification, recapitalization or other similar event affecting such common units). To the extent that the Employee Partnership has cash remaining after making this quarterly payment to the Class A limited partner, the residual cash is distributed to the Class B limited partners on a quarterly basis.
[3]	Represents the total grant date fair value of the profits interest awards irrespective of how such costs will be allocated between us and EPCO and its privately held affiliates.
[4]	Represents our expected share of the unrecognized compensation cost at March 31, 2017. 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 2.9 years, 3.9 years, 3.0 years and 3.9 years, respectively.

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

3 Months Ended

Mar. 31, 2017

USD ($)

Contract

bbl

Bcf

Interest Rate Swaps Hedging Senior Notes OO [Member] | Derivatives in fair value hedging relationships [Member]

Derivative [Line Items]

Number of Derivatives Outstanding | Contract

Type of Derivatives Outstanding

fixed-to-floating swaps

Notional Amount | $

$ 750.0

Period of Hedge

5/2015 to 5/2018

Rate Swap, fixed rate

1.65%

Rate Swap, floating rate

1.51%

Forward Starting Swaps B [Member] | Derivatives in cash flow hedging relationships [Member]

Derivative [Line Items]

Number of Derivatives Outstanding | Contract

Type of Derivatives Outstanding

forward starting swaps

Notional Amount | $

$ 275.0

Expected Termination Date

May 01, 2018

Average Rate Locked

2.02%

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

14.9

^[1],[2]

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

3.5

^[1],[2]

Designated as Hedging Instrument [Member] | Octane enhancement: Forecasted purchases of NGLs [Member] | Derivatives in cash flow hedging relationships [Member]

Derivative [Line Items]

Current Volume

0.5

^[1],[2]

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

0.8

^[1],[2]

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

4.5

^[1],[2]

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

4.5

^[1],[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

82.3

^[1],[2]

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

93.4

^[1],[2]

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

0.2

^[1],[2]

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

0.4

^[1],[2]

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

5.4

^[1],[2]

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

12.5

^[1],[2]

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

21.2

^[1],[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

188.6

^{[1],[2],[3],[4]}

Long Term Volume | Bcf

21.7

^{[1],[2],[3],[4]}

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

55.3

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

10.5

Not Designated as Hedging Instrument [Member] | Refined products risk management activities [Member] | Derivatives in mark-to-market relationships [Member]

Derivative [Line Items]

Current Volume

0.2

^[1],[2],[4]

Not Designated as Hedging Instrument [Member] | NGL risk management activities [Member] | Derivatives in mark-to-market relationships [Member]

Derivative [Line Items]

Current Volume

16.1

^[1],[2],[4]

Not Designated as Hedging Instrument [Member] | Crude oil risk management activities [Member] | Derivatives in mark-to-market relationships [Member]

Derivative [Line Items]

Current Volume

25.2

^[1],[2],[4]

Long Term Volume

10.4

^[1],[2],[4]

[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, September 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 55.3 Bcf and 10.5 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, Hedging Activities and Fair Value Measurements, Derivative Fair Value Amounts (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	$ 39.3	$ 36.5
Liability Derivatives	2.0	1.1
Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	41.2	541.4
Liability Derivatives	44.5	739.4
Derivatives designated as hedging instruments [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	73.4	535.7
Liability Derivatives	32.0	663.1
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	39.3	36.5
Liability Derivatives	2.0	1.1
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.7	0.3
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	38.6	36.2
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	1.7	0.2
Derivatives designated as hedging instruments [Member] \| Interest rate derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.3	0.9
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	34.1	499.2
Liability Derivatives	30.0	662.0
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	34.1	499.2
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	0.0	0.0
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	30.0	662.0
Derivatives designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	0.0	0.0
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	7.1	42.2
Liability Derivatives	14.5	77.4
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Current assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	5.6	41.9
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other assets [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives	1.5	0.3
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Current liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	12.1	75.6
Derivatives not designated as hedging instruments [Member] \| Commodity derivatives [Member] \| Other liabilities [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	$ 2.4	$ 1.8

Derivative Instruments, Hedging Activities and Fair Value Measurements, Asset Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Interest rate derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	$ 39.3	$ 36.5
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Assets Presented in the Balance Sheet	39.3	36.5
Financial Instruments	(0.6)	(0.2)
Cash Collateral Received	0.0	0.0
Cash Collateral Paid	0.0	0.0
Amounts That Would Have Been Presented On Net Basis	38.7	36.3
Commodity Derivatives [Member]
Offsetting Assets [Line Items]
Gross Amounts of Recognized Assets	41.2	541.4
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Assets Presented in the Balance Sheet	41.2	541.4
Financial Instruments	(38.0)	(526.8)
Cash Collateral Received	0.0	0.0
Cash Collateral Paid	0.0	0.0
Amounts That Would Have Been Presented On Net Basis	$ 3.2	$ 14.6

Derivative Instruments, Hedging Activities and Fair Value Measurements, Liability Balance Sheet Offsetting (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Interest rate derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	$ 2.0	$ 1.1
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Liabilities Presented in the Balance Sheet	2.0	1.1
Financial Instruments	(0.6)	(0.2)
Cash Collateral Received	0.0	0.0
Cash Collateral Paid	0.0	0.0
Amounts That Would Have Been Presented On Net Basis	1.4	0.9
Commodity Derivatives [Member]
Offsetting Liabilities [Line Items]
Gross Amounts of Recognized Liabilities	44.5	739.4
Gross Amounts Offset in the Balance Sheet	0.0	0.0
Amounts of Liabilities Presented in the Balance Sheet	44.5	739.4
Financial Instruments	(38.0)	(526.8)
Cash Collateral Received	(3.2)	0.0
Cash Collateral Paid	0.0	(212.4)
Amounts That Would Have Been Presented On Net Basis	$ 3.3	$ 0.2

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Derivatives in fair value hedging relationships [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Recognized in Income on Derivative

$ 17.9

$ (12.9)

Gain (Loss) Recognized in Income on Hedged Item

(11.5)

21.8

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

(0.9)

6.1

Gain (Loss) Recognized in Income on Hedged Item

0.9

(6.2)

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

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) on Fair Value Hedge Ineffectiveness

(0.6)

Gain (Loss) from Components Excluded from Assessment of Fair Value Hedge Effectiveness

7.0

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

6.4

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

18.8

(19.0)

Gain (Loss) Recognized in Income on Hedged Item

(12.4)

28.0

Derivatives in cash flow hedging relationships [Member]

Derivative Instruments, Gain (Loss) [Line Items]

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

147.2

(1.2)

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

(16.7)

48.0

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

Derivative Instruments, Gain (Loss) [Line Items]

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

2.4

0.0

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

(41.4)

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)

(9.6)

(9.2)

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

68.0

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

67.5

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

0.5

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]

147.6

3.3

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

(7.5)

58.8

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]

(2.8)

(4.5)

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

0.4

(1.6)

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

(1.0)

0.0

Derivatives not designated as hedging instruments [Member]

Derivative Instruments, Gain (Loss) [Line Items]

Gain (Loss) Recognized in Income on Derivative

20.2

(1.2)

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

15.7

(1.3)

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

$ 4.5

$ 0.1

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

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

3 Months Ended

Mar. 31, 2017

Mar. 31, 2016

Dec. 31, 2016

Total gains (losses) included in:

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

$ 20.3

$ (20.1)

Fair Value, Measurements, Recurring [Member]

Financial assets [Abstract]

Interest rate derivatives

39.3

$ 36.5

Commodity derivatives:

Value before application of CME Rule 814

233.4

Impact of CME Rule 814 change

(192.2)

Total commodity derivatives

41.2

541.4

Total

80.5

577.9

Financial liabilities [Abstract]

Liquidity option agreement

275.1

269.6

Interest rate derivatives

2.0

1.1

Commodity derivatives:

Value before application of CME Rule 814

209.1

Impact of CME Rule 814 change

(164.6)

Total commodity derivatives

44.5

739.4

Total

321.6

1,010.1

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

Financial assets [Abstract]

Interest rate derivatives

0.0

Commodity derivatives:

Value before application of CME Rule 814

57.6

Impact of CME Rule 814 change

(57.6)

Total commodity derivatives

0.0

84.5

Total

0.0

84.5

Financial liabilities [Abstract]

Liquidity option agreement

0.0

Interest rate derivatives

0.0

Commodity derivatives:

Value before application of CME Rule 814

35.4

Impact of CME Rule 814 change

(35.4)

Total commodity derivatives

0.0

136.8

Total

0.0

136.8

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

Financial assets [Abstract]

Interest rate derivatives

39.3

36.5

Commodity derivatives:

Value before application of CME Rule 814

174.3

Impact of CME Rule 814 change

(134.6)

Total commodity derivatives

39.7

455.2

Total

79.0

491.7

Financial liabilities [Abstract]

Liquidity option agreement

0.0

Interest rate derivatives

2.0

1.1

Commodity derivatives:

Value before application of CME Rule 814

172.9

Impact of CME Rule 814 change

(129.2)

Total commodity derivatives

43.7

602.3

Total

45.7

603.4

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

Financial assets [Abstract]

Interest rate derivatives

0.0

Commodity derivatives:

Value before application of CME Rule 814

1.5

Impact of CME Rule 814 change

0.0

Total commodity derivatives

1.5

1.7

Total

1.5

1.7

Financial liabilities [Abstract]

Liquidity option agreement

275.1

269.6

Interest rate derivatives

0.0

Commodity derivatives:

Value before application of CME Rule 814

0.8

Impact of CME Rule 814 change

0.0

Total commodity derivatives

0.8

0.3

Total

275.9

$ 269.9

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

Financial liability balance, net, beginning of period

(268.2)

(246.7)

Total gains (losses) included in:

Transfers out of Level 3

0.0

0.1

Financial liability balance, net, end of period

(274.4)

(242.3)

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

(0.6)

0.6

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

Total gains (losses) included in:

Net income

^[1]

0.7

Settlements

(1.4)

(0.1)

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

Total gains (losses) included in:

Net income

(5.5)

2.2

Fair Value, Measurements, Recurring [Member] | Level 3 [Member] | Other Comprehensive Income (Loss) [Member]

Total gains (losses) included in:

Other comprehensive income

$ 0.0

$ 1.5

[1]	There were unrealized losses of $0.6 million and unrealized gains of $0.6 million included in these amounts for the three months ended March 31, 2017 and 2016, respectively.

Derivative Instruments, Hedging Activities and Fair Value Measurements, Level 3 Recurring Valuation Techniques (Details) $ in Millions	3 Months Ended
	Mar. 31, 2017 USD ($) $ / bbl	Dec. 31, 2016 USD ($)
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	48.68
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	51.93
Fair Value, Measurements, Recurring [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	$ 41.2	$ 541.4
Commodity liability derivatives	44.5	739.4
Fair Value, Measurements, Recurring [Member] \| Level 3 [Member]
Fair Value Measurements, Recurring, Valuation Techniques [Line Items]
Commodity asset derivatives	1.5	1.7
Commodity liability derivatives	0.8	$ 0.3
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	0.8
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	$ 1.5

Derivative Instruments, Hedging Activities and Fair Value Measurements, Nonrecurring Fair Value Measurements (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Asset Impairment Charges [Abstract]
Asset impairment and related charges	$ 11.2	$ 1.7
Impairment of other current assets	10.8	1.1
Impairment of long-lived assets disposed of other than by sale	0.4	0.6
Impairment of long-lived assets	0.4	0.6
NGL Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Impairment of long-lived assets	0.2	0.3
Crude Oil Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Impairment of long-lived assets	0.0	0.2
Natural Gas Pipelines & Services [Member]
Asset Impairment Charges [Abstract]
Impairment of long-lived assets	0.2	0.0
Petrochemical & Refined Products Services [Member]
Asset Impairment Charges [Abstract]
Impairment of long-lived assets	0.0	0.1
Fair Value, Measurements, Nonrecurring [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	0.0	0.0
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 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 3 [Member] \| Long-lived Assets Disposed of Other Than By Sale [Member]
Assets, Fair Value Disclosure [Abstract]
Assets, fair value	$ 0.0	$ 0.0

Derivative Instruments, Hedging Activities and Fair Value Measurements, Other Fair Value Measurements (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016
Carrying Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 20,850	$ 20,850
Level 2 [Member] \| Fair Value [Member]
Financial Liabilities: [Abstract]
Fixed Rate Debt Principal Amount Fair Value Disclosure	$ 21,980	$ 21,950

Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Revenues - related parties:
Total revenue - related parties	$ 10,800	$ 15,600
Costs and expenses - related parties:
Total costs and expenses - related parties	281,300	310,200
Accounts receivable - related parties:
Total accounts receivable - related parties	1,600		$ 1,100
Accounts payable - related parties:
Total accounts payable - related parties	50,100		105,100
Related Party Transactions [Abstract]
Operating costs and expenses	251,600	280,600
General and administrative expenses	29,700	29,600
EPCO and its privately held affiliates [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties	243,100	237,300
Accounts payable - related parties:
Total accounts payable - related parties	39,200		88,900
Distributions:
Total cash distributions	$ 275,200	260,100
Relationship with Affiliates [Abstract]
Total Number of Units (in units)	685,481,428
Percentage of Total Units Outstanding	32.00%
Enterprise common units pledged as security (in units)	118,000,000
EPCO and its privately held affiliates [Member] \| Administrative Services Agreement [Member]
Costs and expenses - related parties:
Total costs and expenses - related parties	$ 238,400	232,700
Related Party Transactions [Abstract]
Operating costs and expenses	211,600	205,400
General and administrative expenses	26,800	27,300
Unconsolidated affiliates [Member]
Revenues - related parties:
Total revenue - related parties	10,800	15,600
Costs and expenses - related parties:
Total costs and expenses - related parties	38,200	$ 72,900
Accounts receivable - related parties:
Total accounts receivable - related parties	1,600		1,100
Accounts payable - related parties:
Total accounts payable - related parties	$ 10,900		$ 16,200

Commitments and Contingencies (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Operating lease obligations:
Lease and rental expense included in costs and expenses	$ 26.2	$ 28.5
Litigation matters [Member]
Loss Contingencies [Line Items]
Litigation accruals on an undiscounted basis	0.3		$ 0.3
Litigation matters [Member] \| ETP Lawsuit [Member]
Loss Contingencies [Line Items]
Loss contingency, damages awarded	319.4
Loss contingency, total damages sought	535.8
Loss contingency, disgorgement damages sought	150.0
Prejudgment interest	$ 66.4
Post-judgment interest rate	5.00%

Commitments and Contingencies, Liquidity Option Agreement (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Liquidity Option Agreement [Abstract]
Liquidity option agreement	$ 275.1		$ 269.6
Change in fair value of Liquidity Option Agreement	$ 5.5	$ (2.2)
Percentage of capital stock we agreed to purchase under liquidity option agreement	100.00%
Liquidity Option exercise period	90 days
Number of units held by limited partner	54,807,352
Liquidity Option Agreement [Member]
Liquidity Option Agreement [Abstract]
Fair value inputs, Assumed long-term debt	$ 2,200.0
Fair value inputs, Interest rate on assumed debt of OTA following option exercise	4.85%
Increase in fair value of liquidity option agreement excluding assumption of debt	$ 229.1
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	7.70%
Fair value inputs, weighted-average expected ownership percentage of contributed units at beginning of option period	85.00%
Increase in fair value of liquidity option agreement assuming retention of all units	$ 47.1
Liquidity Option Agreement [Member] \| Maximum [Member]
Liquidity Option Agreement [Abstract]
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	13.60%
Fair value inputs, OTA ownership interest in Enterprise common units	2.50%
Liquidity Option Agreement [Member] \| Minimum [Member]
Liquidity Option Agreement [Abstract]
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	0.10%
Fair value inputs, OTA ownership interest in Enterprise common units	1.90%

Supplemental Cash Flow Information (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Decrease (increase) in:
Accounts receivable - trade	$ 110.1	$ 124.6
Accounts receivable - related parties	(0.6)	0.4
Inventories	(71.9)	(194.3)
Prepaid and other current assets	249.0	5.3
Other assets	(2.2)	1.3
Increase (decrease) in:
Accounts payable - trade	6.5	(64.8)
Accounts payable - related parties	(21.1)	(46.7)
Accrued product payables	(16.8)	228.7
Accrued interest	(137.9)	(158.2)
Other current liabilities	(400.2)	(84.4)
Other liabilities	(3.7)	1.7
Net effect of changes in operating accounts	(288.8)	$ (186.4)
Liability for construction in progress expenditures	$ 240.9		$ 124.3

Condensed Consolidating Financial Information, Balance Sheet (Details) - USD ($) $ in Millions	Mar. 31, 2017	Dec. 31, 2016	Mar. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents and restricted cash	$ 107.1	$ 417.6
Accounts receivable - trade, net	3,152.8	3,329.5
Accounts receivable - related parties	1.6	1.1
Inventories	1,922.0	1,770.5
Derivative assets	40.4	541.4
Prepaid and other current assets	417.6	468.1
Total current assets	5,641.5	6,528.2
Property, plant and equipment, net	33,556.1	33,292.5
Investments in unconsolidated affiliates	2,671.4	2,677.3
Intangible assets, net	3,823.1	3,864.1
Goodwill	5,745.2	5,745.2
Other assets	92.2	86.7
Total assets	51,529.5	52,194.0
Current liabilities:
Current maturities of debt	2,300.0	2,576.8
Accounts payable - trade	526.1	397.7
Accounts payable - related parties	50.1	105.1
Accrued product payables	3,618.2	3,613.7
Accrued interest	202.8	340.8
Derivative liabilities	43.8	737.7
Other current liabilities	307.0	478.7
Total current liabilities	7,048.0	8,250.5
Long-term debt	21,123.0	21,120.9
Deferred tax liabilities	52.6	52.7
Other long-term liabilities	505.9	503.9
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,579.3	22,047.0
Noncontrolling interests	220.7	219.0
Total equity	22,800.0	22,266.0	$ 21,346.3	$ 20,501.1
Total liabilities and equity	51,529.5	52,194.0
Eliminations and Adjustments [Member]
Current assets:
Cash and cash equivalents and restricted cash	0.0	0.0
Accounts receivable - trade, net	0.0	0.0
Accounts receivable - related parties	(6.6)	(1.1)
Inventories	0.0	0.0
Derivative assets	0.0	0.0
Prepaid and other current assets	0.0	0.0
Total current assets	(6.6)	(1.1)
Property, plant and equipment, net	0.0	0.0
Investments in unconsolidated affiliates	(22,847.6)	(22,317.1)
Intangible assets, net	0.0	0.0
Goodwill	0.0	0.0
Other assets	0.0	0.0
Total assets	(22,854.2)	(22,318.2)
Current liabilities:
Current maturities of debt	0.0	0.0
Accounts payable - trade	0.0	0.0
Accounts payable - related parties	(6.6)	(1.1)
Accrued product payables	0.0	0.0
Accrued interest	0.0	0.0
Derivative liabilities	0.0	0.0
Other current liabilities	0.5	0.7
Total current liabilities	(6.1)	(0.4)
Long-term debt	0.0	0.0
Deferred tax liabilities	3.7	3.7
Other long-term liabilities	0.0	0.0
Commitments and contingencies
Equity:
Partners' and other owners' equity	(22,822.2)	(22,291.8)
Noncontrolling interests	(29.6)	(29.7)
Total equity	(22,851.8)	(22,321.5)
Total liabilities and equity	(22,854.2)	(22,318.2)
Subsidiary Issuer (EPO) [Member]
Current assets:
Cash and cash equivalents and restricted cash	45.0	366.2
Accounts receivable - trade, net	1,231.3	1,499.4
Accounts receivable - related parties	101.5	131.5
Inventories	1,548.3	1,357.5
Derivative assets	37.1	464.8
Prepaid and other current assets	212.5	290.7
Total current assets	3,175.7	4,110.1
Property, plant and equipment, net	4,972.2	4,796.5
Investments in unconsolidated affiliates	40,079.6	39,995.5
Intangible assets, net	696.0	700.2
Goodwill	459.5	459.5
Other assets	228.1	222.6
Total assets	49,611.1	50,284.4
Current liabilities:
Current maturities of debt	2,299.9	2,576.7
Accounts payable - trade	221.5	133.1
Accounts payable - related parties	894.4	1,071.5
Accrued product payables	1,980.4	1,944.5
Accrued interest	202.5	340.7
Derivative liabilities	34.5	590.3
Other current liabilities	53.4	173.5
Total current liabilities	5,686.6	6,830.3
Long-term debt	21,107.9	21,105.7
Deferred tax liabilities	4.4	5.0
Other long-term liabilities	11.6	13.5
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,800.6	22,329.9
Noncontrolling interests	0.0	0.0
Total equity	22,800.6	22,329.9
Total liabilities and equity	49,611.1	50,284.4
Other Subsidiaries (Non-guarantor) [Member]
Current assets:
Cash and cash equivalents and restricted cash	67.9	58.9
Accounts receivable - trade, net	1,922.2	1,830.3
Accounts receivable - related parties	818.8	961.4
Inventories	374.1	413.5
Derivative assets	3.3	76.6
Prepaid and other current assets	220.0	191.1
Total current assets	3,406.3	3,531.8
Property, plant and equipment, net	28,582.3	28,495.7
Investments in unconsolidated affiliates	4,186.7	4,227.9
Intangible assets, net	3,141.3	3,178.2
Goodwill	5,285.7	5,285.7
Other assets	42.8	41.0
Total assets	44,645.1	44,760.3
Current liabilities:
Current maturities of debt	0.1	0.1
Accounts payable - trade	310.2	272.1
Accounts payable - related parties	98.3	139.6
Accrued product payables	1,638.9	1,670.3
Accrued interest	0.3	0.1
Derivative liabilities	9.3	147.4
Other current liabilities	264.1	316.5
Total current liabilities	2,321.2	2,546.1
Long-term debt	15.1	15.2
Deferred tax liabilities	45.0	45.1
Other long-term liabilities	400.6	400.6
Commitments and contingencies
Equity:
Partners' and other owners' equity	41,785.8	41,675.3
Noncontrolling interests	77.4	78.0
Total equity	41,863.2	41,753.3
Total liabilities and equity	44,645.1	44,760.3
Consolidated EPO and Subsidiaries [Member]
Current assets:
Cash and cash equivalents and restricted cash	107.1	417.6
Accounts receivable - trade, net	3,152.8	3,329.5
Accounts receivable - related parties	1.6	2.2
Inventories	1,922.0	1,770.5
Derivative assets	40.4	541.4
Prepaid and other current assets	417.6	468.1
Total current assets	5,641.5	6,529.3
Property, plant and equipment, net	33,556.1	33,292.5
Investments in unconsolidated affiliates	2,671.4	2,677.3
Intangible assets, net	3,823.1	3,864.1
Goodwill	5,745.2	5,745.2
Other assets	91.7	86.1
Total assets	51,529.0	52,194.5
Current liabilities:
Current maturities of debt	2,300.0	2,576.8
Accounts payable - trade	525.9	397.7
Accounts payable - related parties	56.6	105.1
Accrued product payables	3,618.2	3,613.7
Accrued interest	202.8	340.8
Derivative liabilities	43.8	737.7
Other current liabilities	306.5	478.0
Total current liabilities	7,053.8	8,249.8
Long-term debt	21,123.0	21,120.9
Deferred tax liabilities	48.9	49.0
Other long-term liabilities	230.8	234.3
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,822.2	22,291.8
Noncontrolling interests	250.3	248.7
Total equity	23,072.5	22,540.5
Total liabilities and equity	51,529.0	52,194.5
Consolidated EPO and Subsidiaries [Member] \| Eliminations and Adjustments [Member]
Current assets:
Cash and cash equivalents and restricted cash	(5.8)	(7.5)
Accounts receivable - trade, net	(0.7)	(0.2)
Accounts receivable - related parties	(918.7)	(1,090.7)
Inventories	(0.4)	(0.5)
Derivative assets	0.0	0.0
Prepaid and other current assets	(14.9)	(13.7)
Total current assets	(940.5)	(1,112.6)
Property, plant and equipment, net	1.6	0.3
Investments in unconsolidated affiliates	(41,594.9)	(41,546.1)
Intangible assets, net	(14.2)	(14.3)
Goodwill	0.0	0.0
Other assets	(179.2)	(177.5)
Total assets	(42,727.2)	(42,850.2)
Current liabilities:
Current maturities of debt	0.0	0.0
Accounts payable - trade	(5.8)	(7.5)
Accounts payable - related parties	(936.1)	(1,106.0)
Accrued product payables	(1.1)	(1.1)
Accrued interest	0.0	0.0
Derivative liabilities	0.0	0.0
Other current liabilities	(11.0)	(12.0)
Total current liabilities	(954.0)	(1,126.6)
Long-term debt	0.0	0.0
Deferred tax liabilities	(0.5)	(1.1)
Other long-term liabilities	(181.4)	(179.8)
Commitments and contingencies
Equity:
Partners' and other owners' equity	(41,764.2)	(41,713.4)
Noncontrolling interests	172.9	170.7
Total equity	(41,591.3)	(41,542.7)
Total liabilities and equity	(42,727.2)	(42,850.2)
Enterprise Products Partners L.P. (Guarantor) [Member]
Current assets:
Cash and cash equivalents and restricted cash	0.0	0.0
Accounts receivable - trade, net	0.0	0.0
Accounts receivable - related parties	6.6	0.0
Inventories	0.0	0.0
Derivative assets	0.0	0.0
Prepaid and other current assets	0.0	0.0
Total current assets	6.6	0.0
Property, plant and equipment, net	0.0	0.0
Investments in unconsolidated affiliates	22,847.6	22,317.1
Intangible assets, net	0.0	0.0
Goodwill	0.0	0.0
Other assets	0.5	0.6
Total assets	22,854.7	22,317.7
Current liabilities:
Current maturities of debt	0.0	0.0
Accounts payable - trade	0.2	0.0
Accounts payable - related parties	0.1	1.1
Accrued product payables	0.0	0.0
Accrued interest	0.0	0.0
Derivative liabilities	0.0	0.0
Other current liabilities	0.0	0.0
Total current liabilities	0.3	1.1
Long-term debt	0.0	0.0
Deferred tax liabilities	0.0	0.0
Other long-term liabilities	275.1	269.6
Commitments and contingencies
Equity:
Partners' and other owners' equity	22,579.3	22,047.0
Noncontrolling interests	0.0	0.0
Total equity	22,579.3	22,047.0
Total liabilities and equity	$ 22,854.7	$ 22,317.7

Condensed Consolidating Financial Information, Statement of Operations (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Condensed Consolidating Statement of Operations
Revenues	$ 7,320.4	$ 5,005.3
Costs and expenses:
Operating costs and expenses	6,333.2	4,146.9
General and administrative costs	50.4	43.9
Total costs and expenses	6,383.6	4,190.8
Equity in income of unconsolidated affiliates	94.8	101.1
Operating income	1,031.6	915.6
Other income (expense):
Interest expense	(249.3)	(240.6)
Other, net	(5.3)	3.6
Total other expense, net	(254.6)	(237.0)
Income before income taxes	777.0	678.6
Provision for income taxes	(6.0)	(8.4)
Net income	771.0	670.2
Net income attributable to noncontrolling interests	(10.3)	(9.0)
Net income attributable to limited partners	760.7	661.2
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	(766.7)	(660.1)
Operating income	(766.7)	(660.1)
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	(766.7)	(660.1)
Provision for income taxes	(0.5)	(0.4)
Net income	(767.2)	(660.5)
Net income attributable to noncontrolling interests	1.3	1.2
Net income attributable to limited partners	(765.9)	(659.3)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Operations
Revenues	12,532.8	5,361.9
Costs and expenses:
Operating costs and expenses	12,239.0	5,091.2
General and administrative costs	7.4	6.0
Total costs and expenses	12,246.4	5,097.2
Equity in income of unconsolidated affiliates	728.8	632.7
Operating income	1,015.2	897.4
Other income (expense):
Interest expense	(248.8)	(237.1)
Other, net	2.2	1.8
Total other expense, net	(246.6)	(235.3)
Income before income taxes	768.6	662.1
Provision for income taxes	(2.9)	(2.9)
Net income	765.7	659.2
Net income attributable to noncontrolling interests	0.0	0.0
Net income attributable to limited partners	765.7	659.2
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Operations
Revenues	4,308.2	3,282.7
Costs and expenses:
Operating costs and expenses	3,615.0	2,695.1
General and administrative costs	42.7	36.8
Total costs and expenses	3,657.7	2,731.9
Equity in income of unconsolidated affiliates	133.4	133.6
Operating income	783.9	684.4
Other income (expense):
Interest expense	(2.7)	(5.2)
Other, net	0.2	1.3
Total other expense, net	(2.5)	(3.9)
Income before income taxes	781.4	680.5
Provision for income taxes	(2.6)	(5.1)
Net income	778.8	675.4
Net income attributable to noncontrolling interests	(1.7)	(1.3)
Net income attributable to limited partners	777.1	674.1
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Operations
Revenues	7,320.4	5,005.3
Costs and expenses:
Operating costs and expenses	6,333.2	4,146.9
General and administrative costs	49.9	42.8
Total costs and expenses	6,383.1	4,189.7
Equity in income of unconsolidated affiliates	94.8	101.1
Operating income	1,032.1	916.7
Other income (expense):
Interest expense	(249.3)	(240.6)
Other, net	0.2	1.4
Total other expense, net	(249.1)	(239.2)
Income before income taxes	783.0	677.5
Provision for income taxes	(5.5)	(8.0)
Net income	777.5	669.5
Net income attributable to noncontrolling interests	(11.6)	(10.2)
Net income attributable to limited partners	765.9	659.3
Consolidated EPO and Subsidiaries [Member] \| Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Operations
Revenues	(9,520.6)	(3,639.3)
Costs and expenses:
Operating costs and expenses	(9,520.8)	(3,639.4)
General and administrative costs	(0.2)	0.0
Total costs and expenses	(9,521.0)	(3,639.4)
Equity in income of unconsolidated affiliates	(767.4)	(665.2)
Operating income	(767.0)	(665.1)
Other income (expense):
Interest expense	2.2	1.7
Other, net	(2.2)	(1.7)
Total other expense, net	0.0	0.0
Income before income taxes	(767.0)	(665.1)
Provision for income taxes	0.0	0.0
Net income	(767.0)	(665.1)
Net income attributable to noncontrolling interests	(9.9)	(8.9)
Net income attributable to limited partners	(776.9)	(674.0)
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	1.1
Total costs and expenses	0.5	1.1
Equity in income of unconsolidated affiliates	766.7	660.1
Operating income	766.2	659.0
Other income (expense):
Interest expense	0.0	0.0
Other, net	(5.5)	2.2
Total other expense, net	(5.5)	2.2
Income before income taxes	760.7	661.2
Provision for income taxes	0.0	0.0
Net income	760.7	661.2
Net income attributable to noncontrolling interests	0.0	0.0
Net income attributable to limited partners	$ 760.7	$ 661.2

Condensed Consolidating Financial Information, Statement of Comprehensive Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	$ 934.8	$ 620.9
Comprehensive loss (income) attributable to noncontrolling interests	(10.3)	(9.0)
Comprehensive income attributable to entity	924.5	611.9
Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(931.1)	(611.3)
Comprehensive loss (income) attributable to noncontrolling interests	1.3	1.2
Comprehensive income attributable to entity	(929.8)	(610.1)
Subsidiary Issuer (EPO) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	870.1	655.2
Comprehensive loss (income) attributable to noncontrolling interests	0.0	0.0
Comprehensive income attributable to entity	870.1	655.2
Other Subsidiaries (Non-guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	838.3	630.1
Comprehensive loss (income) attributable to noncontrolling interests	(1.7)	(1.3)
Comprehensive income attributable to entity	836.6	628.8
Consolidated EPO and Subsidiaries [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	941.4	620.3
Comprehensive loss (income) attributable to noncontrolling interests	(11.6)	(10.2)
Comprehensive income attributable to entity	929.8	610.1
Consolidated EPO and Subsidiaries [Member] \| Eliminations and Adjustments [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	(767.0)	(665.0)
Comprehensive loss (income) attributable to noncontrolling interests	(9.9)	(8.9)
Comprehensive income attributable to entity	(776.9)	(673.9)
Enterprise Products Partners L.P. (Guarantor) [Member]
Condensed Consolidating Statement of Comprehensive Income
Comprehensive income	924.5	611.9
Comprehensive loss (income) attributable to noncontrolling interests	0.0	0.0
Comprehensive income attributable to entity	$ 924.5	$ 611.9

Condensed Consolidating Financial Information, Statement of Cash Flows (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating activities:
Net income	$ 771.0	$ 670.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	402.3	382.1
Equity in income of unconsolidated affiliates	(94.8)	(101.1)
Distributions received on earnings from unconsolidated affiliates	90.5	106.7
Net effect of changes in operating accounts and other operating activities	(293.4)	(158.2)
Net cash flows provided by operating activities	875.6	899.7
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(430.4)	(995.0)
Cash used for business combinations, net of cash received	(16.0)	0.0
Proceeds from asset sales	2.0	13.4
Other investing activities	310.2	(182.3)
Cash used in investing activities	(134.2)	(1,163.9)
Financing activities:
Borrowings under debt agreements	17,575.1	20,000.6
Repayments of debt	(17,856.5)	(19,797.4)
Cash distributions paid to owners	(869.0)	(788.3)
Cash payments made in connection with DERs	(3.2)	(2.0)
Cash distributions paid to noncontrolling interests	(10.1)	(8.7)
Cash contributions from noncontrolling interests	0.2	11.1
Net cash proceeds from issuance of common units	448.8	1,011.5
Cash contributions from owners	0.0	0.0
Other financing activities	(27.4)	(21.0)
Cash provided by (used in) financing activities	(742.1)	405.8
Net change in cash and cash equivalents	(0.7)	141.6
Cash and cash equivalents, beginning balance	63.1	19.0
Cash and cash equivalents, ending balance	62.4	160.6
Eliminations and Adjustments [Member]
Operating activities:
Net income	(767.2)	(660.5)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	0.0	0.0
Equity in income of unconsolidated affiliates	766.7	660.1
Distributions received on earnings from unconsolidated affiliates	(870.5)	(788.5)
Net effect of changes in operating accounts and other operating activities	0.3	0.4
Net cash flows provided by operating activities	(870.7)	(788.5)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0.0	0.0
Cash used for business combinations, net of cash received	0.0
Proceeds from asset sales	0.0	0.0
Other investing activities	445.6	1,008.6
Cash used in investing activities	445.6	1,008.6
Financing activities:
Borrowings under debt agreements	0.0	0.0
Repayments of debt	0.0	0.0
Cash distributions paid to owners	870.5	788.5
Cash payments made in connection with DERs	0.0	0.0
Cash distributions paid to noncontrolling interests	0.2	0.0
Cash contributions from noncontrolling interests	0.0	0.0
Net cash proceeds from issuance of common units	0.0	0.0
Cash contributions from owners	(445.6)	(1,008.6)
Other financing activities	0.0	0.0
Cash provided by (used in) financing activities	425.1	(220.1)
Net change in cash and cash equivalents	0.0	0.0
Cash and cash equivalents, beginning balance	0.0	0.0
Cash and cash equivalents, ending balance	0.0	0.0
Subsidiary Issuer (EPO) [Member]
Operating activities:
Net income	765.7	659.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	51.3	42.5
Equity in income of unconsolidated affiliates	(728.8)	(632.7)
Distributions received on earnings from unconsolidated affiliates	255.4	247.2
Net effect of changes in operating accounts and other operating activities	631.0	35.5
Net cash flows provided by operating activities	974.6	351.7
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(125.5)	(307.6)
Cash used for business combinations, net of cash received	0.0
Proceeds from asset sales	1.2	0.1
Other investing activities	(155.9)	(387.5)
Cash used in investing activities	(280.2)	(695.0)
Financing activities:
Borrowings under debt agreements	17,575.1	20,000.6
Repayments of debt	(17,856.4)	(19,797.3)
Cash distributions paid to owners	(870.5)	(788.5)
Cash payments made in connection with DERs	0.0	0.0
Cash distributions paid to noncontrolling interests	0.0	0.0
Cash contributions from noncontrolling interests	0.0	0.0
Net cash proceeds from issuance of common units	0.0	0.0
Cash contributions from owners	445.6	1,008.6
Other financing activities	0.0	0.0
Cash provided by (used in) financing activities	(706.2)	423.4
Net change in cash and cash equivalents	(11.8)	80.1
Cash and cash equivalents, beginning balance	13.4	0.0
Cash and cash equivalents, ending balance	1.6	80.1
Other Subsidiaries (Non-guarantor) [Member]
Operating activities:
Net income	778.8	675.4
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	351.1	339.7
Equity in income of unconsolidated affiliates	(133.4)	(133.6)
Distributions received on earnings from unconsolidated affiliates	62.4	74.2
Net effect of changes in operating accounts and other operating activities	(958.0)	(255.3)
Net cash flows provided by operating activities	100.9	700.4
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(304.9)	(687.4)
Cash used for business combinations, net of cash received	(16.0)
Proceeds from asset sales	0.8	13.3
Other investing activities	4.5	(55.7)
Cash used in investing activities	(315.6)	(729.8)
Financing activities:
Borrowings under debt agreements	0.0	0.0
Repayments of debt	(0.1)	(0.1)
Cash distributions paid to owners	(242.6)	(222.9)
Cash payments made in connection with DERs	0.0	0.0
Cash distributions paid to noncontrolling interests	(2.5)	(0.5)
Cash contributions from noncontrolling interests	0.1	11.1
Net cash proceeds from issuance of common units	0.0	0.0
Cash contributions from owners	469.2	260.9
Other financing activities	0.0	0.0
Cash provided by (used in) financing activities	224.1	48.5
Net change in cash and cash equivalents	9.4	19.1
Cash and cash equivalents, beginning balance	57.2	69.6
Cash and cash equivalents, ending balance	66.6	88.7
Consolidated EPO and Subsidiaries [Member]
Operating activities:
Net income	777.5	669.5
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	402.3	382.1
Equity in income of unconsolidated affiliates	(94.8)	(101.1)
Distributions received on earnings from unconsolidated affiliates	90.5	106.7
Net effect of changes in operating accounts and other operating activities	(325.6)	(177.4)
Net cash flows provided by operating activities	849.9	879.8
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	(430.4)	(995.0)
Cash used for business combinations, net of cash received	(16.0)
Proceeds from asset sales	2.0	13.4
Other investing activities	310.2	(182.3)
Cash used in investing activities	(134.2)	(1,163.9)
Financing activities:
Borrowings under debt agreements	17,575.1	20,000.6
Repayments of debt	(17,856.5)	(19,797.4)
Cash distributions paid to owners	(870.5)	(788.5)
Cash payments made in connection with DERs	0.0	0.0
Cash distributions paid to noncontrolling interests	(10.3)	(8.7)
Cash contributions from noncontrolling interests	0.2	11.1
Net cash proceeds from issuance of common units	0.0	0.0
Cash contributions from owners	445.6	1,008.6
Other financing activities	0.0	0.0
Cash provided by (used in) financing activities	(716.4)	425.7
Net change in cash and cash equivalents	(0.7)	141.6
Cash and cash equivalents, beginning balance	63.1	19.0
Cash and cash equivalents, ending balance	62.4	160.6
Consolidated EPO and Subsidiaries [Member] \| Eliminations and Adjustments [Member]
Operating activities:
Net income	(767.0)	(665.1)
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	(0.1)	(0.1)
Equity in income of unconsolidated affiliates	767.4	665.2
Distributions received on earnings from unconsolidated affiliates	(227.3)	(214.7)
Net effect of changes in operating accounts and other operating activities	1.4	42.4
Net cash flows provided by operating activities	(225.6)	(172.3)
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0.0	0.0
Cash used for business combinations, net of cash received	0.0
Proceeds from asset sales	0.0	0.0
Other investing activities	461.6	260.9
Cash used in investing activities	461.6	260.9
Financing activities:
Borrowings under debt agreements	0.0	0.0
Repayments of debt	0.0	0.0
Cash distributions paid to owners	242.6	222.9
Cash payments made in connection with DERs	0.0	0.0
Cash distributions paid to noncontrolling interests	(7.8)	(8.2)
Cash contributions from noncontrolling interests	0.1	0.0
Net cash proceeds from issuance of common units	0.0	0.0
Cash contributions from owners	(469.2)	(260.9)
Other financing activities	0.0	0.0
Cash provided by (used in) financing activities	(234.3)	(46.2)
Net change in cash and cash equivalents	1.7	42.4
Cash and cash equivalents, beginning balance	(7.5)	(50.6)
Cash and cash equivalents, ending balance	(5.8)	(8.2)
Enterprise Products Partners L.P. (Guarantor) [Member]
Operating activities:
Net income	760.7	661.2
Reconciliation of net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	0.0	0.0
Equity in income of unconsolidated affiliates	(766.7)	(660.1)
Distributions received on earnings from unconsolidated affiliates	870.5	788.5
Net effect of changes in operating accounts and other operating activities	31.9	18.8
Net cash flows provided by operating activities	896.4	808.4
Investing activities:
Capital expenditures, net of contributions in aid of construction costs	0.0	0.0
Cash used for business combinations, net of cash received	0.0
Proceeds from asset sales	0.0	0.0
Other investing activities	(445.6)	(1,008.6)
Cash used in investing activities	(445.6)	(1,008.6)
Financing activities:
Borrowings under debt agreements	0.0	0.0
Repayments of debt	0.0	0.0
Cash distributions paid to owners	(869.0)	(788.3)
Cash payments made in connection with DERs	(3.2)	(2.0)
Cash distributions paid to noncontrolling interests	0.0	0.0
Cash contributions from noncontrolling interests	0.0	0.0
Net cash proceeds from issuance of common units	448.8	1,011.5
Cash contributions from owners	0.0	0.0
Other financing activities	(27.4)	(21.0)
Cash provided by (used in) financing activities	(450.8)	200.2
Net change in cash and cash equivalents	0.0	0.0
Cash and cash equivalents, beginning balance	0.0	0.0
Cash and cash equivalents, ending balance	$ 0.0	$ 0.0