exhibit99

		2nd Quarter
	$Millions, except per unit	2010		2009 (1)		% Change
	Gross operating margin	$	815	$	622		31.0%
	Operating income	$	548	$	373		46.9%
	Adjusted EBITDA	$	794	$	581		36.7%
	Net income	$	373	$	213		75.1%
	Net income attributable to Enterprise	$	357	$	187		90.9%
	Earnings per unit	$	0.46	$	0.32		43.8%
	Distributable Cash Flow	$	532	$	328		62.2%

(1)	Gross operating margin, operating income, Adjusted EBITDA and net income for the second quarter of 2009 were reduced by $68 million and net income attributable to Enterprise was reduced by $34 million, or $0.07 per unit, for charges related to the termination of the Texas Offshore Port System project.

Affiliates of Enterprise Products Company (formerly known as EPCO, Inc.), a private company owned by the Dan L. Duncan family and the largest unitholder of Enterprise Products Partners, have expressed their willingness to consider investing up to $200 million in 2010 to purchase additional common units from Enterprise Products Partners. They have committed to reinvest $50 million through the partnership’s distribution reinvestment plan for the distribution to be paid on August 5, 2010 which would bring their total purchases of common units in 2010 up to $158 million.

Net income attributable to Enterprise for the second quarter of 2010 was $357 million, or $0.46 per unit on a fully diluted basis, versus $187 million, or $0.32 per unit on a fully diluted basis, for the second quarter of 2009. Net income attributable to Enterprise for the second quarter of 2009 does not include $12 million of net income attributable to the former owners of TEPPCO. Net income attributable to Enterprise for the second quarter of 2009 was reduced by $34 million, or $0.07 per unit, associated with the termination of the Texas Offshore Port System project (“TOPS”). The total charge related to TOPS was $68 million, of which 50 percent was attributable to the former owners of TEPPCO. Our consolidated financial results for periods prior to the TEPPCO merger reflect the combined results of Enterprise and TEPPCO. However, there was no change in net income attributable to Enterprise and earnings per unit for periods prior to completion of the TEPPCO merger since net income attributable to TEPPCO was allocated to noncontrolling interests.

On July 13, 2010, the Board of Directors of Enterprise’s general partner approved an increase in the partnership’s quarterly cash distribution rate with respect to the second quarter of 2010 to $0.575 per unit, representing a 5.5 percent increase over the $0.545 per unit rate that was paid with respect to the second quarter of 2009. Enterprise generated $532 million of distributable cash flow during the second quarter of 2010 compared to $328 million for the second quarter of 2009. Enterprise’s distributable cash flow for the second quarter of 2010 provided 1.3 times coverage of the cash distributions to be paid to limited partners on August 5, 2010. The partnership retained approximately $100 million of distributable cash flow in the second quarter of 2010, which is available to reinvest in growth capital projects, reduce debt, and reduce the potential need to issue additional equity. Since the partnership’s IPO in 1998, Enterprise has generated approximately $8.9 billion of distributable cash flow, of which it has retained approximately $1.4 billion. Distributable cash flow is a non-generally accepted accounting principle (“non-GAAP”) financial measure that is defined and reconciled later in this press release to its most directly comparable U.S. GAAP financial measure, net cash flows provided by operating activities.

“Enterprise reported solid operating and financial results for the second quarter of 2010,” said Michael A. Creel, president and chief executive officer of Enterprise. “During the second quarter of 2010, we continued to see strong volumes across our midstream system which operated at or near record levels. NGL, crude oil, refined products and petrochemical pipeline volumes averaged 4 million barrels per day, while natural gas pipeline volumes were a record 12.7 trillion Btu per day and equity NGL production was a record 125,000 barrels per day. Growth in gross operating margin continued to be supported by improvement in domestic and global economic activity; strong demand for NGLs and propylene by the petrochemical industry driven by the relative value of natural gas and NGLs compared to more costly crude oil derivatives; NGL production growth in the Rockies; and natural gas volume growth from shale plays in Texas and Louisiana.”

“Enterprise has developed a number of opportunities to invest capital at attractive returns to build midstream facilities to support new sources of production as a result of the continued success of drilling programs by producers in the shale and non-conventional resource plays. These projects are principally fee-based and associated with natural gas, NGL and crude oil infrastructure to support production growth in the Haynesville and Eagle Ford Shale plays. During the second quarter, we completed our $1.2 billion acquisition of the State Line and Fairplay natural gas gathering pipelines and treating facilities in the Haynesville and Bossier Shale areas of North Louisiana and East Texas from subsidiaries of M2 Midstream. In June, we completed the expansion of the State Line system that increased its capacity up to 700 million cubic feet per day,” stated Creel.

“In the second quarter, we were successful in raising $553 million of equity and $2 billion of long-term debt to fund the acquisition of the M2 Midstream assets, retire $500 million of maturing debt and provide financial flexibility to fund our growth capital investments. We have also been disciplined in managing Enterprise’s distributable cash flow. For the first six months of 2010, we have increased our cash distributions by 2.7 percent and have retained over $250 million of distributable cash flow to reinvest in the growth of the partnership. At June 30, 2010, we had approximately $500 million of unrestricted cash on the balance sheet, total liquidity of $2.3 billion, and strong credit ratios. We believe we are in a strong position from which to execute our growth plans to increase the value of our partnership,” stated Creel.

Certain of Enterprise’s revenues, operating costs and expenses can fluctuate significantly based on the market prices of natural gas, NGLs and crude oil without necessarily affecting gross operating margin and operating income to the same degree. Revenue for the second quarter of 2010 increased to $7.5 billion from $5.4 billion in the same quarter of 2009 primarily attributable to an increase in sales volumes and energy prices. Gross operating margin was $815 million for the second quarter of 2010 compared to $622 million for the second quarter of 2009. Operating income was $548 million for the second quarter of 2010 versus $373 million for the same quarter of 2009. Adjusted earnings before interest, taxes, depreciation and amortization (“Adjusted EBITDA”) for the second quarter of 2010 was $794 million compared to $581 million for the second quarter of 2009.

Equity NGL production (the NGLs that Enterprise earns as a result of providing processing services) for the second quarter of 2010 increased to a record 125 MBPD compared to 118 MBPD in the second quarter of 2009. This increase in equity NGL production was due to a 12 MBPD increase in volumes from the partnership’s Rocky Mountain plants which was partially offset by decreases from the partnership’s South Texas and Louisiana plants. Fee-based natural gas processing volumes were 3.0 billion cubic feet per day (“Bcfd”) for the second quarter of 2010 compared to 2.7 Bcfd for the second quarter of 2009 primarily reflecting an increase in fee-based processing volumes at plants in South Texas and the Rocky Mountains.

Gross operating margin from Enterprise’s NGL fractionation business was $34 million for the second quarter of 2010 compared to $38 million reported for the same quarter of 2009. This $4 million decrease in gross operating margin was primarily due to a decrease in revenues from the Norco facility, which had benefited from higher realized NGL prices in the second quarter of 2009 due to hedging activities. This business was also adversely impacted by scheduled downtime in June 2010 at the Shoup NGL fractionator in South Texas as a result of construction activities to increase the capacity of this facility. Construction activities at Shoup were completed in June 2010. NGL fractionation volumes for the second quarter of 2010 were 463 MBPD compared to 459 MBPD for the second quarter of 2009. Higher volumes for the Norco and Promix fractionators were offset by an 11 MBPD decrease in volumes for the Shoup plant due to the construction activities.

Onshore Natural Gas Pipelines & Services – Enterprise’s Onshore Natural Gas Pipelines & Services segment reported gross operating margin of $107 million for the second quarter of 2010, a $14 million decrease from the $121 million reported for the second quarter of 2009. Gross operating margin in the second quarter of 2010 includes $12 million of non-cash, mark-to-market losses associated with financial transactions for sales of natural gas in future periods. We expect substantially all of these non-cash, mark-to-market losses to be reversed in future periods upon physical delivery of the natural gas.

The aforementioned increase in gross operating margin was partially offset by an aggregate decrease in gross operating margin of $8 million from the Val Verde, Jonah and San Juan natural gas gathering systems and Enterprise’s natural gas storage business largely due to a 7 percent, or 0.3 TBtud, decrease in transportation volumes on these systems. In addition, the delay in the completion of the Trinity River Basin Lateral pipeline reduced gross operating margin by approximately $9 million for the second quarter of 2010 due to charges incurred for transportation capacity on a downstream pipeline in anticipation of natural gas volumes originating on the Trinity River Basin Lateral pipeline. The pipeline is expected to be in service by the end of July 2010.

Onshore Crude Oil Pipelines & Services – Gross operating margin for the second quarter of 2010 from the partnership’s Onshore Crude Oil Pipelines & Services segment was $26 million compared to $42 million for the second quarter of 2009. This $16 million decrease was due to lower gross operating margin from crude oil marketing activities attributable to lower sales margins. The partnership’s crude oil marketing business had higher sales margins in the second quarter of last year due in part from the settlement of forward sales transactions which benefited from a strong contango market for crude oil. Crude oil volumes decreased to 678 MBPD for the second quarter of 2010 from 750 MBPD for the second quarter of 2009 principally due to lower volumes on the Seaway crude oil pipeline.

Offshore Pipelines & Services – Gross operating margin for the Offshore Pipelines & Services segment was $83 million in the second quarter of 2010 compared to a loss of $1 million in the same quarter of 2009. Gross operating margin for the second quarter of 2010 includes $10 million of proceeds from insurance claims associated with hurricanes in prior years and $4 million of revenues from a tariff rate case settlement on our High Island Offshore System. The second quarter of 2009 includes charges of approximately $68 million associated with the termination of TOPS.

The Independence Hub platform and Trail pipeline reported aggregate gross operating margin of $44 million for the second quarter of 2010 compared to $56 million for the second quarter of 2009. Natural gas volumes on the Independence system decreased to 635 billion British thermal units per day (“BBtud”) for the second quarter of 2010 from 891 BBtud for the second quarter of 2009 due to lower production volumes as the result of depletion and one large well watering out. Workover activities have generally been delayed as the result of the uncertainty caused by the federal offshore drilling moratorium. Total offshore natural gas pipeline volumes were 1.3 TBtud for the second quarter of 2010 compared to 1.5 TBtud for the second quarter of 2009.

Gross operating margin from Enterprise’s offshore crude oil pipeline business increased to $26 million for the second quarter of 2010 from $14 million for the second quarter of 2009, excluding the charges associated with the termination of TOPS. The Shenzi pipeline, which commenced operations in April 2009, accounted for approximately $4 million of this increase. Substantially all of the partnership’s offshore crude oil pipelines reported increases in gross operating margin and volumes. Total offshore oil pipeline volumes were 322 MBPD in the second quarter of 2010 versus 244 MBPD in the same quarter of 2009.

Enterprise’s refined products pipelines and related services business reported gross operating margin of $31 million for the second quarter of 2010 compared to $30 million in the second quarter of 2009. The partnership’s Port Arthur, Texas refined products terminal began full commercial operations in June 2010 and therefore only generated nominal gross operating margin in the second quarter of 2010. Pipeline volumes for the refined products pipeline business declined by 4 percent to 642 MBPD for the second quarter of 2010 compared to 669 MPBD for the second quarter of 2009.

Total debt principal outstanding at June 30, 2010 was approximately $12.6 billion, including $1.5 billion of junior subordinated notes to which the nationally recognized debt rating agencies ascribe partial equity credit. Enterprise’s consolidated debt at June 30, 2010 also included $537 million of debt of Duncan Energy Partners L.P., for which Enterprise does not have the payment obligation. During the second quarter of 2010, Enterprise received total proceeds of $553 million from the issuance of approximately 15.8 million common units through a public offering in April and the partnership’s distribution reinvestment plan in May. Also during the second quarter of 2010, the partnership received aggregate net proceeds of approximately $2.0 billion from the issuance of 5-year, 10-year and 30-year senior notes. At June 30, 2010, Enterprise had liquidity of approximately $2.3 billion, which included availability under Enterprise’s credit facilities and unrestricted cash.

This press release and accompanying schedules include the non-GAAP financial measures of gross operating margin, distributable cash flow and Adjusted EBITDA. The accompanying schedules provide reconciliations of these non-GAAP financial measures to their most directly comparable financial measure calculated and presented in accordance with GAAP. Our non-GAAP financial measures should not be considered as alternatives to GAAP measures such as net income, operating income, net cash flows provided by operating activities or any other measure of liquidity or financial performance calculated and presented in accordance with GAAP. Our non-GAAP financial measures may not be comparable to similarly-titled measures of other companies because they may not calculate such measures in the same manner as we do.

Gross operating margin. We evaluate segment performance based on the non-GAAP financial measure of gross operating margin. Gross operating margin (either in total or by individual segment) is an important performance measure of the core profitability of our operations. This measure forms the basis of our internal financial reporting and is used by management in deciding how to allocate capital resources among business segments. We believe that investors benefit from having access to the same financial measures that management uses in evaluating segment results. The GAAP financial measure most directly comparable to total segment gross operating margin is operating income.

We define total segment gross operating margin as operating income before: (1) depreciation, amortization and accretion expense; (2) non-cash consolidated asset impairment charges; (3) operating lease expenses for which we do not have the payment obligation; (4) gains and losses from asset sales and related transactions; and (5) general and administrative costs. Gross operating margin by segment is calculated by subtracting segment operating costs and expenses (net of the adjustments noted above) from segment revenues, with both segment totals before the elimination of intercompany transactions. In accordance with GAAP, intercompany accounts and transactions are eliminated in consolidation. Gross operating margin is exclusive of other income and expense transactions, provision for income taxes, the cumulative effect of changes in accounting principles and extraordinary charges. Gross operating margin is presented on a 100 percent basis before the allocation of earnings to noncontrolling interests.

We include equity earnings from unconsolidated affiliates in our measurement of segment gross operating margin. Our equity investments with industry partners are a vital component of our business strategy. They are a means by which we conduct our operations to align our interests with those of our customers and/or suppliers. This method of operation also enables us to achieve favorable economies of scale relative to the level of investment and business risk assumed versus what we could accomplish on a standalone basis. Many of these businesses perform supporting or complementary roles to our other business operations.

Distributable cash flow. We define distributable cash flow as net income or loss attributable to Enterprise adjusted for: (1) the addition of depreciation, amortization and accretion expense; (2) the addition of operating lease expenses for which we do not have the payment obligation; (3) the addition of cash distributions received from unconsolidated affiliates less equity earnings from unconsolidated affiliates; (4) the subtraction of sustaining capital expenditures and cash payments to settle asset retirement obligations; (5) the addition of losses or subtraction of gains from asset sales and related transactions; (6) the addition of cash proceeds from asset sales or related transactions; (7) the return of an investment in an unconsolidated affiliate (if any); (8) the addition of losses or subtraction of gains on the monetization of financial instruments recorded in accumulated other comprehensive income (loss), if any, less related amortization of such amounts to earnings; (9) the addition of net income attributable to the noncontrolling interest associated with the public unitholders of Duncan Energy Partners L.P. (“DEP”), less related cash distributions to be paid to such unitholders with respect to the period of calculation; and (10) the addition or subtraction of other miscellaneous non-cash amounts (as applicable) that affect net income or loss for the period.

Management compares the distributable cash flow we generate to the cash distributions we expect to pay our partners. Using this metric, management computes our distribution coverage ratio. Distributable cash flow is an important non-GAAP financial measure for our limited partners since it serves as an indicator of our success in providing a cash return on investment. Specifically, this financial measure indicates to investors whether or not we are generating cash flows at a level that can sustain or support an increase in our quarterly cash distributions. Distributable cash flow is also a quantitative standard used by the investment community with respect to publicly traded partnerships because the value of a partnership unit is in part measured by its yield, which is based on the amount of cash distributions a partnership can pay to a unitholder. The GAAP measure most directly comparable to distributable cash flow is net cash flows provided by operating activities.

Adjusted EBITDA. We define Adjusted EBITDA as net income or loss minus equity in income from unconsolidated affiliates; plus distributions received from unconsolidated affiliates, interest expense, provision for income taxes and depreciation, amortization and accretion expense. Adjusted EBITDA is commonly used as a supplemental financial measure by management and external users of our financial statements, such as investors, commercial banks, research analysts and rating agencies, to assess: (1) the financial performance of our assets without regard to financing methods, capital structures or historical cost basis; (2) the ability of our assets to generate cash sufficient to pay interest and support our indebtedness; and (3) the viability of projects and the overall rates of return on alternative investment opportunities. Since Adjusted EBITDA excludes some, but not all, items that affect net income or loss and because these measures may vary among other companies, the Adjusted EBITDA data presented in this press release may not be comparable to similarly titled measures of other companies. The GAAP measure most directly comparable to Adjusted EBITDA is net cash flows provided by operating activities.

Enterprise Products Partners L.P. is the largest publicly traded energy partnership and a leading North American provider of midstream energy services to producers and consumers of natural gas, NGLs, crude oil, refined products and petrochemicals. The partnership’s assets include: 49,100 miles of onshore and offshore pipelines; approximately 200 million barrels of storage capacity for NGLs, refined products and crude oil; and 27 billion cubic feet of natural gas storage capacity. Services include: natural gas transportation, gathering, processing and storage; NGL fractionation (or separation), transportation, storage, and import and export terminaling; crude oil and refined products storage, transportation and terminaling; offshore production platform; petrochemical transportation and storage; and a marine transportation business that operates primarily on the United States inland and Intracoastal Waterway systems and in the Gulf of Mexico. For additional information visit www.epplp.com. Enterprise Products Partners L.P. is managed by its general partner, Enterprise Products GP LLC, which is wholly owned by Enterprise GP Holdings L.P. (NYSE: EPE). For more information on Enterprise GP Holdings L.P., visit www.enterprisegp.com.

This press release includes forward-looking statements. Except for the historical information contained herein, the matters discussed in this press release are forward-looking statements that involve certain risks and uncertainties, such as the partnership’s expectations regarding future results, capital expenditures, project completions, liquidity and financial market conditions. These risks and uncertainties include, among other things, insufficient cash from operations, adverse market conditions, governmental regulations and other factors discussed in Enterprise’s filings with the U.S. Securities and Exchange Commission. If any of these risks or uncertainties materialize, or should underlying assumptions prove incorrect, actual results or outcomes may vary materially from those expected. The partnership disclaims any intention or obligation to update publicly or reverse such statements, whether as a result of new information, future events or otherwise.

Enterprise Products Partners L.P.										Exhibit A
Condensed Statements of Consolidated Operations – UNAUDITED
($ in millions, except per unit amounts)
	Three Months Ended June 30,						Six Months Ended June 30,
	2010			2009			2010			2009
Revenues	$	7,543.4		$	5,434.3		$	16,087.9		$	10,321.2
Costs and expenses:
Operating costs and expenses		6,974.2			5,024.5			14,946.1			9,401.1
General and administrative costs		37.9			46.1			75.5			81.0
Total costs and expenses		7,012.1			5,070.6			15,021.6			9,482.1
Equity in income of unconsolidated affiliates		16.7			9.6			32.7			17.0
Operating income		548.0			373.3			1,099.0			856.1
Other income (expense):
Interest expense		(168.6	)		(158.5	)		(317.2	)		(311.0	)
Other, net		0.4			0.8			0.5			2.0
Total other expense		(168.2	)		(157.7	)		(316.7	)		(309.0	)
Income before provision for income taxes		379.8			215.6			782.3			547.1
Provision for income taxes		(6.5	)		(3.1	)		(15.2	)		(19.1	)
Net income		373.3			212.5			767.1			528.0
Net income attributable to noncontrolling interests		(16.1	)		(25.9	)		(32.1	)		(116.1	)
Net income attributable to Enterprise Products Partners L.P.	$	357.2		$	186.6		$	735.0		$	411.9

Net income allocated to:
Limited partners	$	294.3		$	147.0		$	611.7		$	333.3
General partner	$	62.9		$	39.6		$	123.3		$	78.6
Per unit data (fully diluted):
Earnings per unit	$	0.46		$	0.32		$	0.96		$	0.73
Average LP units outstanding (in millions)		639.1			458.5			631.3			455.6
Other financial data:
Net cash flows provided by operating activities	$	213.4		$	263.0		$	900.3		$	635.0
Cash used in investing activities	$	1,521.3		$	334.7		$	1,891.8		$	887.3
Cash provided by financing activities	$	1,667.8		$	89.9		$	1,431.2		$	261.5
Distributable cash flow	$	532.0		$	327.5		$	1,112.4		$	670.4
Adjusted EBITDA	$	793.8		$	581.4		$	1,577.2		$	1,279.8
Depreciation, amortization and accretion	$	233.8		$	208.6		$	451.4		$	407.7
Distributions received from unconsolidated affiliates	$	28.6		$	11.1		$	58.8		$	33.5
Total debt principal outstanding at end of period	$	12,627.5		$	12,087.5		$	12,627.5		$	12,087.5
Capital spending:
Capital expenditures, net of contributions in aid of construction costs, for property, plant and equipment	$	393.9		$	316.4		$	738.1		$	823.9
Cash used for business combinations, net of cash acquired		1,218.0			73.7			1,220.2			73.7
Acquisition of intangible assets		--			--			--			1.4
Investments in unconsolidated affiliates		2.5			2.7			10.2			9.8
Total capital spending	$	1,614.4		$	392.8		$	1,968.5		$	908.8

Enterprise Products Partners L.P.										Exhibit B
Condensed Operating Data – UNAUDITED
($ in millions)
	Three Months Ended June 30,						Six Months Ended June 30,
	2010			2009			2010			2009
Gross operating margin by segment:
NGL Pipelines & Services	$	441.0		$	363.8		$	878.3		$	714.7
Onshore Natural Gas Pipelines & Services		106.9			121.2			237.2			283.1
Onshore Crude Oil Pipelines & Services		25.9			42.1			52.6			92.6
Offshore Pipelines & Services		82.8			(1.1	)		163.9			60.2
Petrochemical & Refined Products Services		158.1			96.1			278.1			185.6
Total gross operating margin		814.7			622.1			1,610.1			1,336.2
Adjustments to reconcile non-GAAP gross operating margin to GAAP operating income:
Amounts included in operating costs and expenses:
Depreciation, amortization and accretion		(227.0	)		(200.5	)		(439.4	)		(396.9	)
Non-cash impairment charges		--			(2.3	)		(1.5	)		(2.3	)
Operating lease expenses paid by EPCO		(0.1	)		(0.1	)		(0.3	)		(0.3	)
Gain (loss) from asset sales and related transactions		(1.7	)		0.2			5.6			0.4
General and administrative costs		(37.9	)		(46.1	)		(75.5	)		(81.0	)
Operating income	$	548.0		$	373.3		$	1,099.0		$	856.1

Selected operating data: (1)
NGL Pipelines & Services, net:
NGL transportation volumes (MBPD)		2,194			1,993			2,217			2,057
NGL fractionation volumes (MBPD)		463			459			468			450
Equity NGL production (MBPD)		125			118			124			116
Fee-based natural gas processing (MMcf/d)		2,985			2,714			2,833			2,908
Onshore Natural Gas Pipelines & Services, net:
Natural gas transportation volumes (BBtus/d)		11,418			10,672			11,300			10,506
Onshore Crude Oil Pipelines & Services
Crude oil transportation volumes (MBPD)		678			750			675			698
Offshore Pipelines & Services, net:
Natural gas transportation volumes (BBtus/d)		1,312			1,460			1,359			1,501
Crude oil transportation volumes (MBPD)		322			244			338			219
Platform natural gas processing (MMcf/d)		568			753			600			765
Platform crude oil processing (MBPD)		17			10			18			6
Petrochemical & Refined Products Services, net:
Butane isomerization volumes (MBPD)		99			100			86			95
Propylene fractionation volumes (MBPD)		79			67			79			67
Octane additive production volumes (MBPD)		13			10			12			7
Transportation volumes, primarily refined products and petrochemicals (MBPD)		786			788			795			814
Total, net:
NGL, crude oil, refined products and petrochemical transportation volumes (MBPD)		3,980			3,775			4,025			3,788
Natural gas transportation volumes (BBtus/d)		12,730			12,132			12,659			12,007
Equivalent transportation volumes (MBPD) (2)		7,330			6,968			7,356			6,948

(1) Operating rates are reported on a net basis, taking into account our ownership interests in certain joint ventures, and include volumes for newly constructed assets from the related in-service dates and for recently purchased assets from the related acquisition dates. (2) Reflects equivalent energy volumes where 3.8 MMBtus of natural gas are equivalent to one barrel of NGLs.

Enterprise Products Partners L.P.										Exhibit C
Reconciliation of Unaudited GAAP Financial Measures to Non-GAAP Financial Measures
Distributable Cash Flow
($ in millions)
	Three Months Ended June 30,						Six Months Ended June 30,
	2010			2009 (1)			2010			2009 (1)
Net income attributable to Enterprise Products Partners L.P.	$	357.2		$	186.6		$	735.0		$	411.9
Adjustments to GAAP net income attributable to Enterprise Products Partners L.P. to derive non-GAAP distributable cash flow:
Depreciation, amortization and accretion		233.8			158.8			451.4			312.9
Operating lease expenses paid by EPCO		0.1			0.1			0.3			0.3
Distributions received from unconsolidated affiliates		28.6			15.6			58.8			38.5
Equity in (income) loss of unconsolidated affiliates		(16.7	)		17.6			(32.7	)		4.2
Sustaining capital expenditures		(72.7	)		(33.1	)		(105.3	)		(53.1	)
Cash payments to settle asset retirement obligations		(1.2	)		(8.1	)		(3.2	)		(8.2	)
Loss (gain) from asset sales and related transactions		1.8			(0.2	)		(5.7	)		(0.4	)
Proceeds from asset sales and related transactions		2.4			0.2			24.1			0.5
Monetization of derivative instruments		1.3			--			1.3			--
Amortization of net losses (gains) related to monetization of derivative instruments		1.4			(0.5	)		2.8			(0.9	)
Net income attributable to noncontrolling interest – DEP public unitholders		9.6			6.6			18.3			11.7
Distribution to be paid to DEP public unitholders with respect to period		(10.4	)		(10.0	)		(21.1	)		(16.4	)
Other miscellaneous adjustments to derive distributable cash flow		(3.2	)		(6.1	)		(11.6	)		(30.6	)
Distributable cash flow		532.0			327.5			1,112.4			670.4
Adjustments to non-GAAP distributable cash flow to derive GAAP net cash flows provided by operating activities:
Sustaining capital expenditures		72.7			33.1			105.3			53.1
Cash payments to settle asset retirement obligations		1.2			8.1			3.2			8.2
Proceeds from asset sales and related transactions		(2.4	)		(0.2	)		(24.1	)		(0.5	)
Monetization of derivative instruments		(1.3	)		--			(1.3	)		--
Amortization of net (losses) gains related to monetization of derivative instruments		(1.4	)		0.5			(2.8	)		0.9
Net income attributable to noncontrolling interests		16.1			13.5			32.1			25.5
Net income attributable to noncontrolling interest – DEP public unitholders		(9.6	)		(6.6	)		(18.3	)		(11.7	)
Distribution to be paid to DEP public unitholders with respect to period		10.4			10.0			21.1			16.4
Miscellaneous non-cash and other amounts to reconcile distributable cash flow with net cash flows provided by operating activities		6.3			7.3			9.2			20.6
Net effect of changes in operating accounts		(410.6	)		(173.6	)		(336.5	)		(345.2	)
Net cash flows provided by operating activities	$	213.4		$	219.6		$	900.3		$	437.7

(1) Distributable cash flow for the three and six months ended June 30, 2009 is calculated based on and reconciled to historical results (pre-recast) of Enterprise Products Partners L.P. prior to the TEPPCO Merger.

Enterprise Products Partners L.P.										Exhibit D
Reconciliation of Unaudited GAAP Financial Measures to Non-GAAP Financial Measures
Adjusted EBITDA
($ in millions)
	Three Months Ended June 30,						Six Months Ended June 30,
	2010			2009			2010			2009
Net income	$	373.3		$	212.5		$	767.1		$	528.0
Adjustments to GAAP net income to derive non-GAAP Adjusted EBITDA:
Equity in income of unconsolidated affiliates		(16.7	)		(9.6	)		(32.7	)		(17.0	)
Distributions received from unconsolidated affiliates		28.6			11.1			58.8			33.5
Interest expense (including related amortization)		168.6			158.5			317.2			311.0
Provision for income taxes		6.5			3.1			15.2			19.1
Depreciation, amortization and accretion in costs and expenses		233.5			205.8			451.6			405.2
Adjusted EBITDA		793.8			581.4			1,577.2			1,279.8
Adjustments to non-GAAP Adjusted EBITDA to derive GAAP net cash flows provided by operating activities:
Interest expense		(168.6	)		(158.5	)		(317.2	)		(311.0	)
Provision for income taxes		(6.5	)		(3.1	)		(15.2	)		(19.1	)
Operating lease expenses paid by EPCO		0.1			0.1			0.3			0.3
Loss (gain) from asset sales and related transactions		1.8			(0.2	)		(5.7	)		(0.4	)
Loss on forfeiture of Texas Offshore Port System		--			68.4			--			68.4
Miscellaneous non-cash and other amounts to reconcile Adjusted EBITDA and net cash flows provided by operating activities		3.4			6.6			(2.6	)		(5.5	)
Net effect of changes in operating accounts		(410.6	)		(231.7	)		(336.5	)		(377.5	)
Net cash flows provided by operating activities	$	213.4		$	263.0		$	900.3		$	635.0