Enterprise Products Partners (EPD) 10-Q 6 Aug 09 2009 Q2 Quarterly report Financial data

1000 - CONDENSED CONSOLIDATED B

1000 - CONDENSED CONSOLIDATED BALANCE SHEETS (USD $)
In Millions	Jun. 30, 2009	Dec. 31, 2008
Current assets:
Cash and cash equivalents	$65	35.4
Restricted cash	184.4	203.8
Accounts and notes receivable - trade, net of allowance for doubtful accounts	1232.2	1185.5
Accounts receivable - related parties	47.4	61.6
Inventories (See Note 5)	965.8	362.8
Derivative assets (see Note 4)	229.3	202.8
Prepaid and other current assets	144.8	111.8
Total current assets	2868.9	2163.7
Property, plant and equipment, net	13,582	13154.8
Investments in unconsolidated affiliates	901.4	949.5
Intangible assets, net of accumulated amortization	813.5	855.4
Goodwill	706.9	706.9
Deferred tax asset	1.1	0.4
Other assets	148.7	126.8
Total assets	19022.5	17957.5
Current liabilities:
Accounts payable - trade	278.2	300.5
Accounts payable - related parties	96	39.6
Accrued product payables	1526.2	1142.4
Other accrued expenses	32.3	48.8
Accrued interest payable	169.4	151.9
Current maturities of long-term debt	181.4	0
Derivative liabilities (see Note 4)	337	287.2
Other current liabilities	191.1	252.7
Total current liabilities	2811.6	2223.1
Long-term debt:
Senior debt obligations - principal	7950.1	7813.4
Junior subordinated notes - principal	1232.7	1232.7
Other	41.5	62.3
Total long-term debt	9224.3	9108.4
Deferred tax liabilities	68.8	66.1
Other long-term liabilities	98.9	81.3
Limited Partners:
Common units	6278.7	6036.9
Restricted common units	32.1	26.2
General partner	128.6	123.6
Accumulated other comprehensive loss	-130.9	-97.2
Total Enterprise Products Partners L.P. partners' equity	6308.5	6089.5
Noncontrolling interest	510.4	389.1
Total equity	6818.9	6478.6
Total liabilities and equity	19022.5	17957.5

1001 - Parenthetical Data For C

1001 - Parenthetical Data For Condensed Consolidated Balance Sheets (USD $)
In Millions, except Share data	Jun. 30, 2009	Dec. 31, 2008
Current assets:
Allowance for doubtful accounts	14.7	15.1
Accumulated amortization	$472	429.9
Limited Partners:
Common units outstanding	457,313,797	439,354,731
Restricted common units outstanding	2,935,450	2,080,600

2000 - CONDENSED STATEMENTS OF

2000 - CONDENSED STATEMENTS OF CONSOLIDATED OPERATIONS (USD $)
In Millions, except Per Share data	3 Months Ended Jun. 30, 2009	3 Months Ended Jun. 30, 2008	6 Months Ended Jun. 30, 2009	6 Months Ended Jun. 30, 2008
Revenues:
Third parties revenues	3382.8	6116.9	6561.4	11500.7
Related parties revenues	125.1	222.8	369.6	523.5
Total revenues (see Note 11)	3507.9	6339.7	6,931	12024.2
Operating costs and expenses:
Third parties operating costs and expenses	-2925.3	-5824.7	-5756.9	-10959.3
Related parties operating costs and expenses	-208.9	-135.3	-418.6	-311.9
Total operating costs and expenses	-3134.2	(5,960)	-6175.5	-11271.2
General and administrative costs:
Third parties general and administrative costs	-11.2	-10.5	-16.4	(14)
Related parties general and administrative costs	-16.6	-13.5	-34.4	-31.2
Total general and administrative costs	-27.8	(24)	-50.8	-45.2
Total costs and expenses	3,162	5,984	6226.3	11316.4
Equity in earnings of unconsolidated affiliates	-17.6	18.6	-4.2	33.2
Operating income	328.3	374.3	700.5	741
Other income (expense):
Interest expense	-126.2	-95.8	-246.6	-187.7
Interest income	0.6	1	1.2	2.6
Other, net	-0.4	-0.3	-0.3	(1)
Total other expense, net	(126)	-95.1	-245.7	-186.1
Income before provision for income taxes	202.3	279.2	454.8	554.9
Provision for income taxes	-2.2	-6.9	-17.4	-10.6
Net income	200.1	272.3	437.4	544.3
Net income attributable to noncontrolling interest	-13.5	(9)	-25.5	-21.4
Net income attributable to Enterprise Products Partners L.P.	186.6	263.3	411.9	522.9
Net income allocated to:
Limited partners	147	227.7	333.3	452.9
General partner	39.6	35.6	78.6	$70
Basic and diluted earnings per unit (see Note 13)	0.32	0.52	0.73	1.03

3000 - CONDENSED STATEMENTS OF

3000 - CONDENSED STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (USD $)
In Millions	3 Months Ended Jun. 30, 2009	3 Months Ended Jun. 30, 2008	6 Months Ended Jun. 30, 2009	6 Months Ended Jun. 30, 2008
Unaudited Condensed Statements Of Consolidated Comprehensive Income
Net income	200.1	272.3	437.4	544.3
Cash flow hedges:
Commodity derivative instrument gains (losses) during period	-76.6	31.1	-138.6	119.9
Reclassification adjustment for (gains) losses included in net income related to commodity derivative instruments	66.3	-16.9	98.5	-12.7
Interest rate derivative instrument gains (losses) during period	15.8	4.2	15.1	-21.8
Reclassification adjustment for (gains) losses included in net income related to interest rate derivative instruments	1.1	-0.8	2	-2.4
Foreign currency derivative gains (losses)	0.1	-0.1	-10.5	-1.3
Total cash flow hedges	6.7	17.5	-33.5	81.7
Foreign currency translation adjustment	1	0.5	0.6	0.1
Change in funded status of pension and postretirement plans, net of tax	0	0	0	-0.3
Total other comprehensive income (loss)	7.7	18	-32.9	81.5
Comprehensive Income	207.8	290.3	404.5	625.8
Comprehensive income attributable to noncontrolling interest	-13.7	-12.5	-26.3	-21.1
Comprehensive income attributable to Enterprise Products Partners L.P.	194.1	277.8	378.2	604.7

4000 - CONDENSED STATEMENTS OF

4000 - CONDENSED STATEMENTS OF CONSOLIDATED CASH FLOWS (USD $)
In Millions	6 Months Ended Jun. 30, 2009	6 Months Ended Jun. 30, 2008
Operating activities:
Net income	437.4	544.3
Adjustments to reconcile net income to net cash flows provided by operating activities:
Depreciation, amortization and accretion	312.9	274.3
Equity in Earnings of Unconsolidated Affiliates	4.2	-33.2
Distributions received from unconsolidated affiliates	38.5	56
Operating lease expense paid by EPCO, Inc.	0.3	1
Gain from asset sales and related transactions	-0.4	-0.8
Deferred income tax expense	1.8	2.5
Changes in fair market value of derivative instruments	-11.7	9.6
Effect of pension settlement recognition	-0.1	-0.1
Net effect of changes in operating accounts (see Note 16)	-345.2	-156.9
Net cash flows provided by operating activities	437.7	696.7
Investing activities:
Capital Expenditures	(640)	-1091.2
Contributions in aid of construction costs	10.3	17.8
Decrease in restricted cash	19.4	71
Cash Used for Business Combinations	23.7	0
Acquisition of intangible assets	0	5.1
Investments in unconsolidated affiliates	-12.5	(25)
Other proceeds from investing activities	4.3	0.5
Cash used in investing activities	-642.2	(1,032)
Financing activities:
Borrowings under debt agreements	2785.1	3914.7
Repayments of debt	-2471.2	(3,063)
Debt issuance costs	-5.4	-8.6
Distributions paid to partners	-566.4	(509)
Distributions paid to noncontrolling interest (See Note 10)	-27.8	-29.1
Net proceeds from issuance of common units	398.8	38
Monetization of interest rate derivative instruments	0	-22.1
Acquisition of Treasury Units	0	-0.7
Contributions from noncontrolling interest (See Note 10)	123.2	0
Cash provided by financing activities	236.3	320.2
Effect of exchange rate changes on cash	-2.2	0.1
Net change in cash and cash equivalents	31.8	-15.1
Cash and cash equivalents, January 1	35.4	39.7
Cash and Cash Equivalents, June 30	$65	24.7

5000 - CONDENSED STATEMENTS OF

5000 - CONDENSED STATEMENTS OF CONSOLIDATED EQUITY (USD $)
In Millions	6 Months Ended Jun. 30, 2009	6 Months Ended Jun. 30, 2008
Partners' Capital, Beginning Balance	6478.6	6562.1
Net income	437.4	544.3
Operating lease expense paid by EPCO, Inc.	0.3	1
Cash distributions paid to partners	-566.1	-508.5
Unit option reimbursements to EPCO, Inc.	-0.3	-0.5
Distributions paid to noncontrolling interest (See Note 10)	27.8	29.1
Net proceeds from issuance of common units	398.6	37.4
Proceeds from exercise of unit options	0.2	0.6
Amortization of equity awards	8.1	5.4
Cash flow hedges	-33.5	81.7
Change in funded status of pension and postretirement plans		-0.3
Contributions from noncontrolling interest (see Note 10)	122.8
Foreign currency translation adjustment	0.6	0.1
Acquisition of Treasury Units	0	-0.7
Partners' Capital, Ending Balance	6818.9	6693.5
Limited Partner [Member]
Partners' Capital, Beginning Balance	6063.1	5992.9
Net income	333.3	452.9
Operating lease expense paid by EPCO, Inc.	0.3	1
Cash distributions paid to partners	-484.4	-438.8
Unit option reimbursements to EPCO, Inc.	-0.3	-0.5
Distributions paid to noncontrolling interest (see Note 10)	0	0
Net proceeds from issuance of common units	390.6	36.7
Proceeds from exercise of unit options	0.2	0.6
Amortization of equity awards	8	5.3
Cash flow hedges	0	0
Change in funded status of pension and postretirement plans		0
Contributions from noncontrolling interest (see Note 10)	0
Foreign currency translation adjustment	0	0
Acquisition of Treasury Units		-0.7
Partners' Capital, Ending Balance	6310.8	6049.4
General Partner [Member]
Partners' Capital, Beginning Balance	123.6	122.3
Net income	78.6	70
Operating lease expense paid by EPCO, Inc.	0	0
Cash distributions paid to partners	-81.7	-69.7
Unit option reimbursements to EPCO, Inc.	0	0
Distributions paid to noncontrolling interest (see Note 10)	0	0
Net proceeds from issuance of common units	8	0.7
Proceeds from exercise of unit options	0	0
Amortization of equity awards	0.1	0.1
Cash flow hedges	0	0
Change in funded status of pension and postretirement plans		0
Contributions from noncontrolling interest (see Note 10)	0
Foreign currency translation adjustment	0	0
Acquisition of Treasury Units		0
Partners' Capital, Ending Balance	128.6	123.4
Accumulated Other Comprehensive Income [Member]
Partners' Capital, Beginning Balance	-97.2	19.1
Net income	0	0
Operating lease expense paid by EPCO, Inc.	0	0
Cash distributions paid to partners	0	0
Unit option reimbursements to EPCO, Inc.	0	0
Distributions paid to noncontrolling interest (see Note 10)	0	0
Net proceeds from issuance of common units	0	0
Proceeds from exercise of unit options	0	0
Amortization of equity awards	0	0
Cash flow hedges	-34.3	81.9
Change in funded status of pension and postretirement plans		-0.3
Contributions from noncontrolling interest (see Note 10)	0
Foreign currency translation adjustment	0.6	0.1
Acquisition of Treasury Units		0
Partners' Capital, Ending Balance	-130.9	100.8
Noncontrolling Interest [Member]
Partners' Capital, Beginning Balance	389.1	427.8
Net income	25.5	21.4
Operating lease expense paid by EPCO, Inc.	0	0
Cash distributions paid to partners	0	0
Unit option reimbursements to EPCO, Inc.	0	0
Distributions paid to noncontrolling interest (see Note 10)	-27.8	-29.1
Net proceeds from issuance of common units	0	0
Proceeds from exercise of unit options	0	0
Amortization of equity awards	0	0
Cash flow hedges	0.8	-0.2
Change in funded status of pension and postretirement plans		0
Contributions from noncontrolling interest (see Note 10)	122.8
Foreign currency translation adjustment	0	0
Acquisition of Treasury Units		0
Partners' Capital, Ending Balance	510.4	419.9

6000 - Partnership Organization

6000 - Partnership Organization
	6 Months Ended Jun. 30, 2009 USD / shares
Partnership Organization
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	Note 1.Partnership Organization Partnership Organization Enterprise Products Partners L.P. is 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.Unless the context requires otherwise, references to we, us, our or Enterprise Products Partners are intended to mean the business and operations of Enterprise Products Partners L.P. and its consolidated subsidiaries. We were formed in April 1998 to own and operate certain natural gas liquids (NGLs) related businesses of EPCO, Inc. (EPCO).We conduct substantially all of our business through our wholly owned subsidiary, Enterprise Products Operating LLC (EPO).We are owned 98% by our limited partners and 2% by Enterprise Products GP, LLC (our general partner, referred to as EPGP).EPGP is owned 100% by Enterprise GP Holdings L.P. (Enterprise GP Holdings), a publicly traded limited partnership, the units of which are listed on the NYSE under the ticker symbol EPE.The general partner of Enterprise GP Holdings is EPE Holdings, LLC (EPE Holdings), a wholly owned subsidiary of Dan Duncan LLC, all of the membership interests of which are owned by Dan L. Duncan.We, EPGP, Enterprise GP Holdings, EPE Holdings and Dan Duncan LLC are affiliates and under the common control of Dan L. Duncan, the Group Co-Chairman and controlling shareholder of EPCO. References to TEPPCO mean TEPPCO Partners, L.P., a publicly traded limited partnership, the common units of which are listed on the NYSE under the ticker symbol TPP.References to TEPPCO GP refer to Texas Eastern Products Pipeline Company, LLC, which is the general partner of TEPPCO and is wholly owned by Enterprise GP Holdings.On June 28, 2009, we and TEPPCO (including TEPPCO GP) entered into definitive agreements to merge.See Note 12 for additional information regarding the merger agreements. References to Energy Transfer Equity mean the business and operations of Energy Transfer Equity, L.P. and its consolidated subsidiaries.References to LE GP mean LE GP, LLC, which is the general partner of Energy Transfer Equity.Enterprise GP Holdings owns a noncontrolling interest in both LE GP and Energy Transfer Equity.Enterprise GP Holdings accounts for its investments in LE GP and Energy Transfer Equity using the equity method of accounting. References to Employee Partnerships mean EPE Unit L.P., EPE Unit II, L.P., EPE Unit III, L.P., Enterprise Unit L.P. and EPCO Unit L.P.,collectively, all of which are privately-held affiliates of EPCO. For financial reporting purposes, we consolidate the financial statements of Duncan Energy Partners L.P. (Duncan Energy Partners) with those of our own and reflect its operations in our business segments.We control Duncan Energy Partners through our ownership of its general partner, DEP Holdings, LLC (DEP GP).Also, due to common control of the entities by Dan L. Duncan, the initial consolidated balance sheet of Duncan Energy Partners reflects our historical carrying basis in each of the subsidiaries contributed to Duncan Energy Partners.Public ownership of Duncan Energy Partners net assets and earnings are presented as a

6001 - General Accounting Matte

6001 - General Accounting Matters
	6 Months Ended Jun. 30, 2009 USD / shares
General Accounting Matters
General Accounting Matters [Text Block]	Note 2.General Accounting Matters Estimates Preparing our financial statements in conformity with GAAP requires management to make estimates and assumptions that affect amounts presented in the financial statements (e.g. assets, liabilities, revenues and expenses) and disclosures about contingent assets and liabilities.Our actual results could differ from these estimates.On an ongoing basis, management reviews its estimates based on currently available information.Changes in facts and circumstances may result in revised estimates. Fair Value Information Cash and cash equivalents, accounts receivable, accounts payable and accrued expenses, and other current liabilities are carried at amounts which reasonably approximate their fair values due to their short-term nature.The estimated fair values of our fixed rate debt are based on quoted market prices for such debt or debt of similar terms and maturities.The carrying amounts of our variable rate debt obligations reasonably approximate their fair values due to their variable interest rates.See Note 4 for fair value information associated with our derivative instruments.The following table presents the estimated fair values of our financial instruments at the dates indicated: June 30, 2009 December 31, 2008 Carrying Fair Carrying Fair Financial Instruments Value Value Value Value Financial assets: Cash and cash equivalents, including restricted cash $ 249.4 $ 249.4 $ 239.2 $ 239.2 Accounts receivable 1,279.6 1,279.6 1,247.1 1,247.1 Financial liabilities: Accounts payable and accrued expenses 2,102.1 2,102.1 1,683.2 1,683.2 Other current liabilities 191.1 191.1 252.7 252.7 Fixed-rate debt (principal amount) 7,986.7 7,760.9 7,704.3 6,639.0 Variable-rate debt 1,377.5 1,377.5 1,341.8 1,341.8 Recent Accounting Developments The following information summarizes recently issued accounting guidance since those reported in our Recast Form 8-K that will or may affect our future financial statements. In April 2009, the Financial Accounting Standards Board (FASB) issued new guidance in the form of FASB Staff Positions (FSPs) in an effort to clarify certain fair value accounting rules. FSP FAS 157-4 (ASC 820), Determining Fair Value When the Volume and Level of Activity for the Asset or Liability Have Significantly Decreased and Identifying Transactions That Are Not Orderly, establishes a process to determine whether a market is not active and a transaction is not distressed. FSP FAS 157-4 states that companies should look at several factors and use judgment to ascertain if a formerly active market has become inactive. When estimating fair value, FSP FAS 157-4 requires companies to place more weight on observable transactions determined to be orderly and less weight on transactions for which there is insufficient information to determine whether the transaction is orderly (entities do not have to incur undue cost and effort in making this dete

6003 - Accounting for Equity Aw

6003 - Accounting for Equity Awards
	6 Months Ended Jun. 30, 2009 USD / shares
Accounting for Equity Awards
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	Note 3.Accounting for Equity Awards We account for equity awards in accordance with SFAS 123(R) (ASC 505 and 718), Share-Based Payment.Such awards were not material to our consolidated financial position, results of operations or cash flows for all periods presented.The amount of equity-based compensation allocable to our businesses was $5.3 million and $3.5 million for the three months ended June 30, 2009 and 2008, respectively.For the six months ended June 30, 2009 and 2008, the amount of equity-based compensation allocable to our businesses was $8.2 million and $6.3 million, respectively. Certain key employees of EPCO participate in long-term incentive compensation plans managed by EPCO.The compensation expense we record related to equity awards is based on an allocation of the total cost of such incentive plans to EPCO.We record our pro rata share of such costs based on the percentage of time each employee spends on our consolidated business activities. EPCO 1998 Long-Term Incentive Plan The EPCO 1998 Long-Term Incentive Plan (EPCO 1998 Plan) provides for the issuance of up to 7,000,000 of our common units.After giving effect to the issuance or forfeiture of option awards and restricted unit awards through June 30, 2009, a total of 301,600 additional common units could be issued under the EPCO 1998 Plan. Unit option awards.The following table presents option activity under the EPCO 1998 Plan for the periods indicated: Weighted- Weighted- Average Average Remaining Aggregate Number of Strike Price Contractual Intrinsic Units (dollars/unit) Term (in years) Value (1) Outstanding at December 31, 2008 2,168,500 $ 26.32 Granted (2) 30,000 20.08 Exercised (25,000 ) 13.16 Forfeited (365,000 ) 26.38 Outstanding at June 30, 2009 1,808,500 26.39 4.8 $ 1.5 Options exercisable at June 30, 2009 403,500 21.33 3.9 $ 1.5 (1) Aggregate intrinsic value reflects fully vested unit options at June 30, 2009. (2) Aggregate grant date fair value of these unit options issued during 2009 was $0.2 million based on the following assumptions: (i) a grant date market price of our common units of $20.08 per unit; (ii) expected life of options of 5.0 years; (iii) risk-free interest rate of 1.81%; (iv) expected distribution yield on our common units of 10%; and (v) expected unit price volatility on our common units of 72.76%. The total intrinsic value of option awards exercised during the three months ended June 30, 2009 and 2008 was $0.2 million and $0.4 million, respectively.For the six months ended June 30, 2009 and 2008, the total intrinsic value of option awards exercised was $0.3 million and $0.5 million, respectively.At June 30, 2009, the estimated total unrecognized compensation cost related to nonvested unit option awards granted under the EPCO 1998 Plan was $1.3 million.We will recognize our share of these costs in accordance with the E

6005 - Derivative Instruments a

6005 - Derivative Instruments and Hedging Activities
	6 Months Ended Jun. 30, 2009 USD / shares
Derivative Instruments and Hedging Activities
Derivative Instruments and Hedging Activities Disclosure [Text Block]	Note 4.Derivative Instruments and Hedging Activities In the course of our normal business operations, we are exposed to certain risks, including changes in interest rates, commodity prices and, to a limited extent, foreign exchange rates.In order to manage risks associated with certain identifiable and anticipated transactions, we use derivative instruments.Derivatives are financial instruments whose fair value is determined by changes in a specified benchmark such as interest rates, commodity prices or currency values.Typical derivative instruments include futures, forward contracts, swaps and other instruments with similar characteristics.Substantially all of our derivatives are used for non-trading activities. SFAS 133 (ASC 815), Accounting for Derivative Instruments and Hedging Activities, requires companies to recognize derivative instruments at fair value as either assets or liabilities on the balance sheet.While the standard requires that all derivatives be reported at fair value on the balance sheet, changes in fair value of the derivative instruments will be reported in different ways depending on the nature and effectiveness of the hedging activities to which they are related.After meeting specified conditions, a qualified derivative may be specifically designated as a total or partial hedge of: Changes in the fair value of a recognized asset or liability, or an unrecognized firm commitment - In a fair value hedge, all gains and losses (of both the derivative instrument and the hedged item) are recognized in income during the period of change. Variable cash flows of a forecasted transaction - In a cash flow hedge, the effective portion of the hedge is reported in other comprehensive income and is reclassified into earnings when the forecasted transaction affects earnings. Foreign currency exposure, such as through an unrecognized firm commitment. An effective hedge is one in which the change in fair value of a derivative instrument can be expected to offset 80% to 125% of changes in the fair value of a hedged item at inception and throughout the life of the hedging relationship.The effective portion of a hedge is the amount by which the derivative instrument exactly offsets the change in fair value of the hedged item during the reporting period.Conversely, ineffectiveness represents the change in the fair value of the derivative instrument that does not exactly offset the change in the fair value of the hedged item.Any ineffectiveness associated with a hedge is recognized in earnings immediately.Ineffectiveness can be caused by, among other things, changes in the timing of forecasted transactions or a mismatch of terms between the derivative instrument and the hedged item. On January 1, 2009, we adopted the disclosure requirements of SFAS 161 (ASC 815), Disclosures About Derivative Financial Instruments and Hedging Activities.SFAS 161 requires enhanced qualitative and quantitative disclosure requirements regarding derivative instruments.This footnote reflects the new disclosure standard. Interest Rate Derivative Instruments We utilize interest rate swaps, treasury locks and similar derivative instruments t

6006 - Inventories

6006 - Inventories
	6 Months Ended Jun. 30, 2009 USD / shares
Inventories
Inventory Disclosure [Text Block]	Note 5.Inventories Our inventory amounts were as follows at the dates indicated: June 30, December 31, 2009 2008 Working inventory (1) $ 438.8 $ 200.4 Forward sales inventory (2) 527.0 162.4 Total inventory $ 965.8 $ 362.8 (1) Working inventory is comprised of inventories of natural gas, NGLs and certain petrochemical products that are either available-for-sale or used in providing services. (2) Forward sales inventory consists of identified NGL and natural gas volumes dedicated to the fulfillment of forward sales contracts.As a result of energy market conditions, we significantly increased our physical inventory purchases and related forward physical sales commitments during 2009.Of the $527.0 million in forward sales inventory at June 30, 2009, approximately $432.0 million relates to forward sales NGL volumes.In general, the significant increase in volumes dedicated to forward physical sales contracts improves the overall utilization and profitability of our fee-based assets.The cash invested in forward sales NGL inventories is expected to be recovered within the next twelve months, with approximately $163.4 million realized by December 31, 2009. Our inventory values reflect payments for product purchases, freight charges associated with such purchase volumes, terminal and storage fees, vessel inspection costs, demurrage charges and other related costs.We value our inventories at the lower of average cost or market. Operating costs and expenses, as presented on our Unaudited Condensed Statements of Consolidated Operations, include cost of sales amounts related to the sale of inventories.Our costs of sales amounts were $2.70 billion and $5.51 billion for the three months ended June 30, 2009 and 2008, respectively.For the six months ended June 30, 2009 and 2008, our costs of sales amounts were $5.33billion and $10.41 billion, respectively.The decrease in cost of sales period-to-period is primarily due to lower energy commodity prices associated with our marketing activities. Due to fluctuating commodity prices, we recognize lower of average cost or market (LCM) adjustments when the carrying value of our available-for-sale inventories exceed their net realizable value.These non-cash charges are a component of cost of sales in the period they are recognized, and reflected in operating costs and expenses as presented on our Unaudited Condensed Statements of Consolidated Operations.For the three months ended June 30, 2009 and 2008, we recognized LCM adjustments of $0.3 million and $0.7 million, respectively.We recognized LCM adjustments of $6.0 million and $4.8 million for the six months ended June 30, 2009 and 2008, respectively.

6007 - Property, Plant and Equi

6007 - Property, Plant and Equipment
	6 Months Ended Jun. 30, 2009 USD / shares
Property, Plant and Equipment
Property, Plant and Equipment Disclosure [Text Block]	Note 6.Property, Plant and Equipment Our property, plant and equipment values and accumulated depreciation balances were as follows at the dates indicated: Estimated Useful Life June 30, December 31, in Years 2009 2008 Plants and pipelines (1) 3-45 (5) $ 13,863.8 $ 12,296.3 Underground and other storage facilities (2) 5-35 (6) 930.8 900.7 Platforms and facilities (3) 20-31 637.5 634.8 Transportation equipment (4) 3-10 39.3 38.7 Land 59.0 54.6 Construction in progress 669.8 1,604.7 Total 16,200.2 15,529.8 Less accumulated depreciation 2,618.2 2,375.0 Property, plant and equipment, net $ 13,582.0 $ 13,154.8 (1) Plants and pipelines include processing plants; NGL, petrochemical, oil and natural gas pipelines; terminal loading and unloading facilities; office furniture and equipment; buildings; laboratory and shop equipment; and related assets. (2) Underground and other storage facilities include underground product storage caverns; storage tanks; water wells; and related assets. (3) Platforms and facilities include offshore platforms and related facilities and other associated assets. (4) Transportation equipment includes vehicles and similar assets used in our operations. (5) In general, the estimated useful lives of major components of this category are as follows:processing plants, 20-35 years; pipelines, 18-45 years (with some equipment at 5 years); terminal facilities, 10-35 years; office furniture and equipment, 3-20 years; buildings, 20-35 years; and laboratory and shop equipment, 5-35 years. (6) In general, the estimated useful lives of major components of this category are as follows:underground storage facilities, 20-35 years (with some components at 5 years); storage tanks, 10-35 years; and water wells, 25-35 years (with some components at 5 years). The following table summarizes our depreciation expense and capitalized interest amounts for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Depreciation expense (1) $ 130.5 $ 114.0 $ 255.5 $ 223.8 Capitalized interest (2) 5.6 17.6 17.7 35.7 (1) Depreciation expense is a component of costs and expenses as presented in our Unaudited Condensed Statements of Consolidated Operations. (2) Capitalized interest increases the carrying value of the associated asset and reduces interest expense during the period it is recorded. In May 2009, we acquired certain rail and truck terminal facilities located in Mont Belvieu, Texas from Martin Midstream Partners L.P. (Martin).Cash consideration paid for this business combination was $23.7 million, all of which was recorded as additions to property, plant and equipment. On a pro forma consolidated basis, our revenues, costs and expenses, operating income, net income and earnings per unit amounts wo

6008 - Investments in Unconsoli

6008 - Investments in Unconsolidated Affiliates
	6 Months Ended Jun. 30, 2009 USD / shares
Investments in Unconsolidated Affiliates
Equity Method Investments Disclosure [Text Block]	Note 7.Investments in Unconsolidated Affiliates We own interests in a number of related businesses that are accounted for using the equity method of accounting.Our investments in unconsolidated affiliates are grouped according to the business segment to which they relate.See Note 11 for a general discussion of our business segments.The following table shows our investments in unconsolidated affiliates at the dates indicated. Ownership Percentage at June 30, June 30, December 31, 2009 2009 2008 NGL Pipelines Services: Venice Energy Service Company, L.L.C. 13.1% $ 31.6 $ 37.7 K/D/S Promix, L.L.C. (Promix) 50% 47.8 46.4 Baton Rouge Fractionators LLC 32.2% 23.3 24.1 Skelly-Belvieu Pipeline Company, L.L.C. (Skelly-Belvieu) 49% 37.0 36.0 Onshore Natural Gas Pipelines Services: Jonah Gas Gathering Company (Jonah) 19.4% 250.4 258.1 Evangeline (1) 49.5% 5.0 4.5 White River Hub, LLC 50% 27.2 21.4 Offshore Pipelines Services: Poseidon Oil Pipeline, L.L.C. (Poseidon) 36% 59.8 60.2 Cameron Highway Oil Pipeline Company (Cameron Highway) 50% 246.7 250.8 Deepwater Gateway, L.L.C. 50% 102.9 104.8 Neptune Pipeline Company, L.L.C. (Neptune) 25.7% 54.5 52.7 Nemo Gathering Company, LLC 33.9% -- 0.4 Texas Offshore Port System(TOPS) (2) -- -- 35.9 Petrochemical Services: Baton Rouge Propylene Concentrator, LLC 30% 11.7 12.6 La Porte (3) 50% 3.5 3.9 Total $ 901.4 $ 949.5 (1) Refers to our ownership interests in Evangeline Gas Pipeline Company, L.P. and Evangeline Gas Corp., collectively. (2) In April 2009, we elected to dissociate from this partnership and forfeit our investment (see discussion below). (3) Refers to our ownership interests in La Porte Pipeline Company, L.P. and La Porte GP, LLC, collectively. Our investments in Promix, La Porte, Neptune, Poseidon, Cameron Highway, Jonah and Skelly-Belvieu include excess cost amounts totaling $55.4 million and $56.6 million at June 30, 2009 and December 31, 2008, respectively, all of which are attributable to the fair value of the underlying tangible assets of these entities exceeding their book carrying values at the time of our acquisition of interests in these entities.To the extent that we attribute all or a portion of an excess cost amount to higher fair values, we amortize such excess cost as a reduction in equity earnings in a manner similar to depreciation.To the extent we attribute an excess cost amount to goodwill, we do not amortize this amount, but it is subject to evaluation for impairment.Amortization of excess cost amounts was $0.7 million and $0.5 million for the three months ended June 30, 2009 and 2008, respectively.For the six months ended June 30, 2009 and 2008, amortization of such amounts was $1.2 million and $1.0 million, respectively.

6009 - Intangible Assets and Go

6009 - Intangible Assets and Goodwill
	6 Months Ended Jun. 30, 2009 USD / shares
Intangible Assets and Goodwill
Goodwill and Intangible Assets Disclosure [Text Block]	Note 8.Intangible Assets and Goodwill Identifiable Intangible Assets The following table summarizes our intangible assets by segment at the dates indicated: June 30, 2009 December 31, 2008 Gross Accum. Carrying Gross Accum. Carrying Value Amort. Value Value Amort. Value NGL Pipelines Services: Customer relationship intangibles $ 237.4 $ (77.9 ) $ 159.5 $ 237.4 $ (68.7 ) $ 168.7 Contract-based intangibles 299.9 (126.8 ) 173.1 299.7 (117.4 ) 182.3 Subtotal 537.3 (204.7 ) 332.6 537.1 (186.1 ) 351.0 Onshore Natural Gas Pipelines Services: Customer relationship intangibles 372.0 (113.9 ) 258.1 372.0 (103.2 ) 268.8 Contract-based intangibles 101.3 (40.9 ) 60.4 101.3 (36.6 ) 64.7 Subtotal 473.3 (154.8 ) 318.5 473.3 (139.8 ) 333.5 Offshore Pipelines Services: Customer relationship intangibles 205.8 (98.2 ) 107.6 205.8 (90.7 ) 115.1 Contract-based intangibles 1.2 (0.2 ) 1.0 1.2 (0.1 ) 1.1 Subtotal 207.0 (98.4 ) 108.6 207.0 (90.8 ) 116.2 Petrochemical Services: Customer relationship intangibles 53.0 (11.2 ) 41.8 53.0 (10.5 ) 42.5 Contract-based intangibles 14.9 (2.9 ) 12.0 14.9 (2.7 ) 12.2 Subtotal 67.9 (14.1 ) 53.8 67.9 (13.2 ) 54.7 Total $ 1,285.5 $ (472.0 ) $ 813.5 $ 1,285.3 $ (429.9 ) $ 855.4 The following table presents the amortization expense of our intangible assets by business segment for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 NGL Pipelines Services $ 9.3 $ 9.8 $ 18.6 $ 19.9 Onshore Natural Gas Pipelines Services 7.4 7.6 15.0 15.4 Offshore Pipelines Services 3.7 4.3 7.6 8.7 Petrochemical Services 0.5 0.5 0.9 1.0 Total $ 20.9 $ 22.2 $ 42.1 $ 45.0 Based on information currently available, we estimate that amortization expense will approximate $40.7 million for the last six months of 2009, $77.8 million for 2010, $72.0 million for 2011, $62.3 million for 2012 and $56.4 million for 2013. Goodwill The following table summarizes our goodwill amounts by business segment at the dates indicated: June 30, December 31, 2009 2008 NGL Pipelines Services $ 269.0 $ 269.0 Onshore Natural Gas Pipelines Services 282.1 282.1 Offshore Pipelines Services 82.1 82.1 Petrochemical Services 73.7 73.7 Total $ 706.9 $ 706.9

6010 - Debt Obligations

6010 - Debt Obligations
	6 Months Ended Jun. 30, 2009 USD / shares
Debt Obligations
Debt Disclosure [Text Block]	Note 9.Debt Obligations Our consolidated debt obligations consisted of the following at the dates indicated: June 30, December 31, 2009 2008 EPO senior debt obligations: Multi-Year Revolving Credit Facility, variable rate, due November 2012 $ 853.2 $ 800.0 Pascagoula MBFC Loan, 8.70% fixed-rate, due March 2010 (1) 54.0 54.0 Petal GO Zone Bonds, variable rate, due August 2037 57.5 57.5 Yen Term Loan, 4.93% fixed-rate, due March 2009 (2) -- 217.6 Senior Notes B, 7.50% fixed-rate, due February 2011 450.0 450.0 Senior Notes C, 6.375% fixed-rate, due February 2013 350.0 350.0 Senior Notes D, 6.875% fixed-rate, due March 2033 500.0 500.0 Senior Notes F, 4.625% fixed-rate, due October 2009 (1) 500.0 500.0 Senior Notes G, 5.60% fixed-rate, due October 2014 650.0 650.0 Senior Notes H, 6.65% fixed-rate, due October 2034 350.0 350.0 Senior Notes I, 5.00% fixed-rate, due March 2015 250.0 250.0 Senior Notes J, 5.75% fixed-rate, due March 2035 250.0 250.0 Senior Notes K, 4.950% fixed-rate, due June 2010 (1) 500.0 500.0 Senior Notes L, 6.30% fixed-rate, due September 2017 800.0 800.0 Senior Notes M, 5.65% fixed-rate, due April 2013 400.0 400.0 Senior Notes N, 6.50% fixed-rate, due January 2019 700.0 700.0 Senior Notes O, 9.75% fixed-rate, due January 2014 500.0 500.0 Senior Notes P, 4.60% fixed-rate, due August 2012 500.0 -- Duncan Energy Partners debt obligations: DEP Revolving Credit Facility, variable rate, due February 2011 184.5 202.0 DEP Term Loan, variable rate, due December 2011 282.3 282.3 Total principal amount of senior debt obligations 8,131.5 7,813.4 EPO Junior Subordinated Notes A, fixed/variable rate, due August 2066 550.0 550.0 EPO Junior Subordinated Notes B, fixed/variable rate, due January 2068 682.7 682.7 Total principal amount of senior and junior debt obligations 9,364.2 9,046.1 Other, non-principal amounts: Change in fair value of debt-related derivative instruments 34.1 51.9 Unamortized discounts, net of premiums (7.3 ) (7.3 ) Unamortized deferred net gains related to terminated interest rate swaps 14.7 17.7 Total other, non-principal amounts 41.5 62.3 Total debt obligations 9,405.7 9,108.4 Less current maturities of debt (181.4 ) -- Total long-term debt $ 9,224.3 $ 9,108.4 Letters of credit outstanding $ 111.7 $ 1.0 (1) In accordance with SFAS 6 (ASC 470), Classification of Short-Term Obligations Expected to be Refinanced, long-term and current maturities of debt reflect the classification of such obligations at June 30, 2009 after taking into consideration EPOs ability to use available borrowing capacity under its Multi-Year Revolving Credit Facility. (2) The Yen Term Loan matured on March 30, 2009. Parent-Subsidiary G

6011 - Equity and Distributions

6011 - Equity and Distributions
	6 Months Ended Jun. 30, 2009 USD / shares
Equity and Distributions
Stockholders' Equity Note Disclosure [Text Block]	Note 10.Equity and Distributions Our common units represent limited partner interests, which give the holders thereof the right to participate in distributions and to exercise the other rights or privileges available to them under ourFifth Amended and Restated Agreement of Limited Partnership (together with all amendments thereto, the Partnership Agreement).We are managed by our general partner, EPGP. Equity Offerings and Registration Statements We have a universal shelf registration statement on file with the SEC that allows us to issue an unlimited amount of debt and equity securities.In January 2009, we sold 10,590,000 common units (including an over-allotment of 990,000 common units) to the public at an offering price of $22.20 per unit under this universal shelf registration statement.In June 2009, EPO sold $500.0 million in principal amount of Senior Notes P under this universal shelf registration statement. We also have a registration statement on file with the SEC authorizing the issuance of up to 40,000,000 common units in connection with our distribution reinvestment plan (DRIP).A total of 28,719,027 common units have been issued under this registration statement through June 30, 2009. In addition, we have a registration statement on file related to our employee unit purchase plan (EUPP), under which we can issue up to 1,200,000 common units.A total of 754,159 common units have been issued to employees under this plan through June 30, 2009. The following table reflects the number of common units issued and the net proceeds received from underwritten and other common unit offerings completed during the six months ended June 30, 2009: Net Proceeds from Sale of Common Units Number of Contributed Contributed by Total Common Units by Limited General Net Issued Partners Partner Proceeds January underwritten offering 10,590,000 $ 225.6 $ 4.6 $ 230.2 February DRIP and EUPP 3,679,163 78.9 1.6 80.5 May DRIP and EUPP 3,671,679 86.1 1.8 87.9 Total 2009 17,940,842 $ 390.6 $ 8.0 $ 398.6 Net proceeds from the issuance of common units during 2009 have been used to temporarily reduce borrowings under EPOs Multi-Year Revolving Credit Facility and for general partnership purposes. Summary of Changes in Outstanding Units The following table summarizes changes in our outstanding units since December 31, 2008: Restricted Common Common Treasury Units Units Units Balance, December 31, 2008 439,354,731 2,080,600 -- Common units issued in connection with underwritten offering 10,590,000 -- -- Common units issued in connection with DRIP and EUPP 7,350,842 -- -- Common units issued in connection with equity awards 7,500 -- -- Restricted units issued -- 1,011,350 -- Forfeiture of restricted units -- (144,000 ) -- Conversion of restricted units to common units 12,500 (12,500 ) --

6012 - Business Segments

6012 - Business Segments
	6 Months Ended Jun. 30, 2009 USD / shares
Business Segments
Segment Reporting Disclosure [Text Block]	Note 11.Business Segments We have four reportable business segments: NGL Pipelines Services, Onshore Natural Gas Pipelines Services, Offshore Pipelines Services and Petrochemical Services.Our business segments are generally organized and managed according to the type of services rendered (or technologies employed) and products produced and/or sold. The following table shows our measurement of total segment gross operating margin for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Revenues (1) $ 3,507.9 $ 6,339.7 $ 6,931.0 $ 12,024.2 Less: Operating costs and expenses (1) (3,134.2 ) (5,960.0 ) (6,175.5 ) (11,271.2 ) Add: Equity in income (loss) of unconsolidated affiliates (1) (17.6 ) 18.6 (4.2 ) 33.2 Depreciation, amortization and accretion in operating costs and expenses (2) 153.2 136.3 306.7 270.2 Operating lease expense paid by EPCO (2) 0.1 0.5 0.3 1.0 Gain from asset sales and related transactions in operating costs and expenses (2) (0.2 ) (0.7 ) (0.4 ) (0.8 ) Total segment gross operating margin $ 509.2 $ 534.4 $ 1,057.9 $ 1,056.6 (1) These amounts are taken from our Unaudited Condensed Statements of Consolidated Operations. (2) These non-cash expenses are taken from the operating activities section of our Unaudited Condensed Statements of Consolidated Cash Flows. A reconciliation of our total segment gross operating margin to operating income and income before provision for income taxes follows: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Total segment gross operating margin $ 509.2 $ 534.4 $ 1,057.9 $ 1,056.6 Adjustments to reconcile total segment gross operating margin to operating income: Depreciation, amortization and accretion in operating costs and expenses (153.2 ) (136.3 ) (306.7 ) (270.2 ) Operating lease expense paid by EPCO (0.1 ) (0.5 ) (0.3 ) (1.0 ) Gain from asset sales and related transactions in operating costs and expenses 0.2 0.7 0.4 0.8 General and administrative costs (27.8 ) (24.0 ) (50.8 ) (45.2 ) Operating income 328.3 374.3 700.5 741.0 Other expense, net (126.0 ) (95.1 ) (245.7 ) (186.1 ) Income before provision for income taxes $ 202.3 $ 279.2 $ 454.8 $ 554.9 Information by segment, together with reconciliations to our consolidated totals, is presented in the following table: Reportable Segments Onshore NGL Natural Gas Offshore Adjustments Pipelines Pipelines Pipelines Petrochemical and Consolidated Services Services Services Serv

6013 - Related Party Transactio

6013 - Related Party Transactions
	6 Months Ended Jun. 30, 2009 USD / shares
Related Party Transactions
Related Party Transactions Disclosure [Text Block]	Note 12.Related Party Transactions The following table summarizes our related party transactions for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Revenues from consolidated operations: EPCO and affiliates $ 32.7 $ 26.3 $ 57.8 $ 44.7 Energy Transfer Equity and subsidiaries 49.2 90.3 212.0 313.4 Unconsolidated affiliates 43.2 106.2 99.8 165.4 Total $ 125.1 $ 222.8 $ 369.6 $ 523.5 Cost of sales: EPCO and affiliates $ 15.2 $ 9.8 $ 43.6 $ 25.6 Energy Transfer Equity and subsidiaries 95.9 23.3 185.9 68.8 Unconsolidated affiliates 11.4 23.9 24.5 52.2 Total $ 122.5 $ 57.0 $ 254.0 $ 146.6 Operating costs and expenses: EPCO and affiliates $ 87.0 $ 75.0 $ 166.5 $ 160.9 Energy Transfer Equity and subsidiaries 1.9 5.8 3.3 9.1 Unconsolidated affiliates (2.5 ) (2.5 ) (5.2 ) (4.7 ) Total $ 86.4 $ 78.3 $ 164.6 $ 165.3 General and administrative expenses: EPCO and affiliates $ 16.6 $ 13.5 $ 34.4 $ 31.2 Other expense: EPCO and affiliates $ -- $ -- $ -- $ 0.3 The following table summarizes our related party receivable and payable amounts at the dates indicated: June 30, December 31, 2009 2008 Accounts receivable - related parties: EPCO and affiliates $ 36.9 $ 26.6 Energy Transfer Equity and subsidiaries 5.4 35.0 Unconsolidated affiliates 5.1 -- Total $ 47.4 $ 61.6 Accounts payable - related parties: EPCO and affiliates $ 63.3 $ 39.4 Energy Transfer Equity and subsidiaries 28.9 0.2 Unconsolidated affiliates 3.8 -- Total $ 96.0 $ 39.6 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. Significant Relationships and Agreements with EPCO and affiliates We have an extensive and ongoing relationship with EPCO and its affiliates, which include the following significant entities that are not a part of our consolidated group of companies: EPCO and its privately-held affiliates; EPGP, our general partner; Enterprise GP Holdings, which owns and controls our general partner; TEPPCO and its general partner, which are owned and/or controlled by Enterprise GP Holdings; and the Employee Partnerships. We also have an ongoing relationship with Duncan Energy Partners, the financial statements of which are consolidated with our own financial statements.Our transactions with Duncan Energy Partners are eliminated in consolidation.A description of our relationship with Duncan

6015 - Earnings Per Unit

6015 - Earnings Per Unit
	6 Months Ended Jun. 30, 2009 USD / shares
Earnings Per Unit
Earnings Per Share [Text Block]	Note 13.Earnings Per Unit The following table presents the net income available to EPGP for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Net income attributable to Enterprise Products Partners L.P. $ 186.6 $ 263.3 $ 411.9 $ 522.9 Less incentive earnings allocations to EPGP (36.6 ) (31.0 ) (71.8 ) (60.8 ) Net income available after incentive earnings allocation 150.0 232.3 340.1 462.1 Multiplied by EPGP ownership interest 2.0 % 2.0 % 2.0 % 2.0 % Standard earnings allocation to EPGP $ 3.0 $ 4.6 $ 6.8 $ 9.2 Incentive earnings allocation to EPGP $ 36.6 $ 31.0 $ 71.8 $ 60.8 Standard earnings allocation to EPGP 3.0 4.6 6.8 9.2 Net income available to EPGP 39.6 35.6 78.6 70.0 Adjustment for EITF 07-4 (1) 1.4 1.1 2.8 2.2 Net income available to EPGP for EPU purposes $ 41.0 $ 36.7 $ 81.4 $ 72.2 (1) For purposes of computing basic and diluted earnings per unit, we apply the provisions of EITF 07-4. The following table presents our calculation of basic and diluted earnings per unit for the periods indicated: For the Three Month For the Six Month Ended June 30, Ended June 30, 2009 2008 2009 2008 BASIC EARNINGS PER UNIT Numerator Net income attributable to Enterprise Products Partners L.P. $ 186.6 $ 263.3 $ 411.9 $ 522.9 Net income available to EPGP for EPU purposes (41.0 ) (36.7 ) (81.4 ) (72.2 ) Net income available to limited partners $ 145.6 $ 226.6 $ 330.5 $ 450.7 Denominator Weighted average common units 455.8 434.6 453.3 434.3 Weighted average time-vested restricted units 2.6 1.9 2.2 1.8 Total 458.4 436.5 455.5 436.1 Basic earnings per unit Net income per unit before EPGP earnings allocation $ 0.41 $ 0.60 $ 0.91 $ 1.20 Net income available to EPGP (0.09 ) (0.08 ) (0.18 ) (0.17 ) Net income available to limited partners $ 0.32 $ 0.52 $ 0.73 $ 1.03 DILUTED EARNINGS PER UNIT Numerator Net income attributable to Enterprise Products Partners L.P. $ 186.6 $ 263.3 $ 411.9 $ 522.9 Net income available to EPGP for EPU purposes (41.0 ) (36.7 ) (81.4 ) (72.2 ) Net income available to limited partners $ 145.6 $ 226.6 $ 330.5 $ 450.7 Denominator Weighted average common units 455.8 434.6 453.3 434.3 Weighted average time-vested restricted units 2.6 1.9 2.2 1.8 Incremental option units 0.1 0.3

6016 - Commitments and Continge

6016 - Commitments and Contingencies
	6 Months Ended Jun. 30, 2009 USD / shares
Commitments and Contingencies
Commitments and Contingencies Disclosure [Text Block]	Note 14.Commitments and Contingencies Litigation On occasion, we or our unconsolidated affiliates are named as a defendant in litigation and legal proceedings, including 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 indemnify us against liabilities arising from future legal proceedings.We are unaware of any litigation, pending or threatened, that we believe is reasonably likely to have a significant adverse effect on our financial position, results of operations or cash flows. We evaluate our ongoing litigation based upon a combination of litigation and settlement alternatives.These reviews are updated as the facts and combinations of the cases develop or change.Assessing and predicting the outcome of these matters involves substantial uncertainties.In the event that the assumptions we used to evaluate these matters change in future periods or new information becomes available, we may be required to record a liability for an adverse outcome.In an effort to mitigate potential adverse consequences of litigation, we could also seek to settle legal proceedings brought against us.We have not recorded any significant reserves for any litigation in our financial statements. On September 18, 2006, Peter Brinckerhoff, a purported unitholder of TEPPCO, filed a complaint in the Court of Chancery of the State of Delaware (the Delaware Court), in his individual capacity, as a putative class action on behalf of other unitholders of TEPPCO and derivatively on behalf of TEPPCO, concerning, among other things, certain transactions involving TEPPCO and us or our affiliates. Mr. Brinckerhoff filed an amended complaint on July 12, 2007.The amended complaint names as defendants (i) TEPPCO, certain of its current and former directors, and certain of its affiliates, (ii) us and certain of our affiliates, (iii) EPCO, and (iv) Dan L. Duncan. The amended complaint alleges, among other things, that the defendants caused TEPPCO to enter into specified transactions that were unfair to TEPPCO or otherwise unfairly favored us or our affiliates over TEPPCO.These transactions are alleged to include: (i) the joint venture to further expand the Jonah system entered into by TEPPCO and us in August2006; (ii) the sale by TEPPCO of its Pioneer natural gas processing plant and certain gas processing rights to us in March2006; and (iii) certain amendments to TEPPCOs partnership agreement, including a reduction in the maximum tier of TEPPCOs incentive distribution rights in exchange for TEPPCO units.The amended complaint seeks (i)rescission of the amendments to TEPPCOs partnership agreement, (ii)damages for profits and special benefits allegedly obtained by defendants as a result of the alleged wrongdoings in the amended complaint, and (iii)an award to plaintiff of the costs of the action, including fees and expenses of his attorneys and experts. By its Opinion and Order dated November 25, 2008, the Delaware Court dismissed Mr. Brinckerhoffs individual and putative class action claims with

6017 - Significant Risks and Un

6017 - Significant Risks and Uncertainties
	6 Months Ended Jun. 30, 2009 USD / shares
Significant Risks and Uncertainties
Concentration Risk Disclosure [Text Block]	Note 15.Significant Risks and Uncertainties Insurance Matters EPCO completed its annual insurance renewal process during the second quarter of 2009. In light of recent hurricane and other weather-related events, the renewal of policies for weather-related risks resulted in significant increases in premiums and certain deductibles, as well as changes in the scope of coverage. EPCOs deductible for onshore physical damage from windstorms increased from $10.0 million per storm to $25.0 million per storm.EPCOs onshore program currently provides $150.0 million per occurrence for named windstorm events compared to $175.0 million per occurrence in the prior year.With respect to offshore assets, the windstorm deductible increased significantly from $10.0 million per storm (with a one-time aggregate deductible of $15.0 million) to $75.0 million per storm.EPCOs offshore program currently provides $100.0 million in the aggregate compared to $175.0 million in the aggregate for the prior year.For non-windstorm events, EPCOs deductible for both onshore and offshore physical damage remained at $5.0 million per occurrence. For certain of our major offshore assets, our producer customers have agreed to provide a specified level of physical damage insurance for named windstorms.For example, the producers associated with our Independence Hub and Marco Polo platforms have agreed to cover windstorm generated physical damage costs up to $250.0 million for each platform. Business interruption coverage in connection with a windstorm event remained unchanged for onshore assets, but was eliminated for offshore assets.Onshore assets covered by business interruption insurance must be out-of-service in excess of 60 days before any losses from business interruption will be covered.Furthermore, pursuant to the current policy, we will now absorb 50% of the first $50.0 million of any loss in excess of deductible amounts for our onshore assets. In the third quarter of 2008, certain of our onshore and offshore facilities located along the Gulf Coast of Texas and Louisiana were damaged by Hurricanes Gustav and Ike.The disruptions in hydrocarbon production caused by these storms resulted in decreased volumes for some of our pipeline systems, natural gas processing plants, NGL fractionators and offshore platforms, which, in turn, caused a decrease in gross operating margin from these operations.As a result of our allocated share of EPCOs insurance deductibles for windstorm coverage, we expensed a combined cumulative total of $47.4 million of repair costs for property damage in connection with these two storms through June 30, 2009.We continue to file property damage claims in connection with the damage caused by these storms.The insurance carriers have notified us that they expect to pay us an initial $25.0 million in business interruption proceeds during the third quarter of 2009 in connection with these storms.We recognize business interruption proceeds as income when they are received in cash. The following table summarizes proceeds we received during the periods indicated from business interruption and property damage insurance claims with respect to certa

6018 - Supplemental Cash Flow I

6018 - Supplemental Cash Flow Information
	6 Months Ended Jun. 30, 2009 USD / shares
Supplemental Cash Flow Information
Cash Flow, Supplemental Disclosures [Text Block]	Note 16.Supplemental Cash Flow Information The following table provides information regarding the net effect of changes in our operating assets and liabilities for the periods indicated: For the Six Months Ended June 30, 2009 2008 Decrease (increase) in: Accounts and notes receivable trade $ (47.1 ) $ (590.8 ) Accounts receivable related parties 27.8 26.0 Inventories (616.3 ) (109.9 ) Prepaid and other current assets (32.6 ) (41.5 ) Other assets (29.0 ) (5.0 ) Increase (decrease) in: Accounts payable trade (21.6 ) 30.6 Accounts payable related parties 57.2 37.3 Accrued product payables 387.7 475.9 Accrued interest payable 19.9 8.5 Other accrued expenses (16.4 ) 17.2 Other current liabilities (71.0 ) (1.9 ) Other liabilities (3.8 ) (3.3 ) Net effect of changes in operating accounts $ (345.2 ) $ (156.9 )

6019 - Condensed Financial Info

6019 - Condensed Financial Information of EPO
	6 Months Ended Jun. 30, 2009 USD / shares
Condensed Financial Information of EPO
Condensed Financial Information of EPO [Text Block]	Note 17.Condensed Consolidated Financial Information of EPO EPO conducts substantially all of our business.Currently, we have no independent operations and no material assets outside those of EPO.EPO consolidates the financial statements of Duncan Energy Partners with its own financial statements. Enterprise Products Partners L.P. guarantees the debt obligations of EPO, with the exception of Duncan Energy Partners debt obligations.If EPO were to default on any of its guaranteed debt, Enterprise Products Partners L.P. would be responsible for full repayment of that obligation.See Note 9 for additional information regarding our consolidated debt obligations. The reconciling items between our consolidated financial statements and those of EPO are insignificant.The following table presents condensed consolidated balance sheet data for EPO at the dates indicated: June 30, December 31, 2009 2008 ASSETS Current assets $ 2,867.6 $ 2,175.6 Property, plant and equipment, net 13,582.0 13,154.8 Investments in unconsolidated affiliates, net 901.4 949.5 Intangible assets, net 813.5 855.4 Goodwill 706.9 706.9 Other assets 149.1 126.6 Total $ 19,020.5 $ 17,968.8 LIABILITIES AND EQUITY Current liabilities $ 2,807.4 $ 2,222.7 Long-term debt 9,224.3 9,108.4 Other long-term liabilities 167.8 147.3 Equity 6,821.0 6,490.4 Total $ 19,020.5 $ 17,968.8 Total EPO debt obligations guaranteed byEnterprise Products Partners L.P. $ 8,897.4 $ 8,561.8 The following table presents condensed consolidated statements of operations data for EPO for the periods indicated: For the Three Months For the Six Months Ended June 30, Ended June 30, 2009 2008 2009 2008 Revenues $ 3,507.9 $ 6,339.7 $ 6,931.0 $ 12,024.2 Costs and expenses 3,157.5 5,983.3 6,219.8 11,315.1 Equity in income (loss) of unconsolidated affiliates (17.6 ) 18.6 (4.2 ) 33.2 Operating income 332.8 375.0 707.0 742.3 Other expense (126.1 ) (95.1 ) (245.7 ) (186.2 ) Income before provision for income taxes 206.7 279.9 461.3 556.1 Provision for income taxes (2.2 ) (6.9 ) (17.4 ) (10.6 ) Net income 204.5 273.0 443.9 545.5 Net income attributable to the noncontrolling interest (13.6 ) (9.0 ) (25.7 ) (21.4 ) Net income attributable to EPO $ 190.9 $ 264.0 $ 418.2 $ 524.1

6020 - Subsequent Events

6020 - Subsequent Events
	6 Months Ended Jun. 30, 2009 USD / shares
Subsequent Events
Schedule of Subsequent Events [Text Block]	Note 18.Subsequent Events Loan Agreement with TEPPCO On August 5, 2009, EPO entered into a Loan Agreement with TEPPCO under which EPO agreed to make an unsecured revolving loan to TEPPCO in an aggregate maximum outstanding principal amount not to exceed $100.0 million.Borrowings under the Loan Agreement mature on the earliest to occur of (i) the consummation of our proposed merger with TEPPCO, (ii) the termination of the related merger agreement in accordance with the provisions thereof, (iii) December 31, 2009, (iv) the date upon which the maturity of the loan is otherwise accelerated upon an event of default, and (v) the date upon which EPOs commitment to make the loan is terminated by TEPPCO pursuant to the Loan Agreement.Borrowings under the Loan Agreement will bear interest at a floating rate equivalent to the one-month LIBOR Rate (as defined in the Loan Agreement) plus 2%.Interest is payable monthly. The Loan Agreement provides that amounts borrowed are non-recourse to TEPPCO GP and TEPPCOs limited partners.The Loan Agreement contains customary events of default, including (i) nonpayment of principal when due or nonpayment of interest or other amounts within three business days of when due, (ii) bankruptcy or insolvency with respect to TEPPCO, (iii) a change of control, or (iv) an event of default under TEPPCOs revolving credit facility.Any amounts due by TEPPCO under the Loan Agreement will be unconditionally and irrevocably guaranteed by each TEPPCO subsidiary that guarantees TEPPCOs obligations under its revolving credit facility.EPOs obligation to fund any borrowings under the Loan Agreement is subject to specified conditions, including the condition that, on and as of the applicable date of funding, no additional amounts are available to TEPPCO pursuant to TEPPCOs revolving credit facility (either as borrowings or under any letters of credit). The execution of the Loan Agreement was unanimously approved by the ACG Committees of EPGP and TEPPCO GP. Settlement Agreement On August 5, 2009, the parties to the Merger Action and the Derivative Action described in Note 14 entered into the Settlement Agreement contemplated by the Memorandum of Understanding.Pursuant to the Settlement Agreement, the board of directors of TEPPCO GP will recommend to TEPPCOs unitholders that they approve the adoption of the merger agreement governing TEPPCOs proposed merger with a subsidiary of ours and take all necessary steps to seek unitholder approval for the merger as soon as practicable.Pursuant to the Settlement Agreement, approval of the merger will require, in addition to votes required under TEPPCOs partnership agreement, that the actual votes cast in favor of the proposal by holders of TEPPCOs outstanding units, excluding those held by defendants to the Derivative Action, exceed the actual votes cast against the proposal by those holders.The Settlement Agreement further provides that the Derivative Action was considered by TEPPCOs Special Committee to be a significant TEPPCO benefit for which fair value was obtained in the merger consideration. The Settlement Agreement is subject to customary conditions, including Delaware Co

Document Information

Document Information
	6 Months Ended Jun. 30, 2009 USD / shares
Document Information [Line Items]
Document Type	10-Q
Document Period End Date	2009-06-30
Amendment Flag	false

Entity Information

Entity Information (USD $)
	6 Months Ended Jun. 30, 2009
Entity Information [Line Items]
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	460,249,247