Energy Transfer Reports Second Quarter 2021 Results

Rhea-AI Summary

Energy Transfer LP (NYSE:ET) reported strong financial results for Q2 2021, with net income attributable to partners of $626 million, a $273 million increase from the previous year. Adjusted EBITDA rose to $2.62 billion, driven by enhanced earnings across core segments. Distributable Cash Flow also increased to $1.39 billion. Operationally, ET launched its Cushing to Nederland expansion and ramped up volumes at its terminal. The partnership successfully reduced debt by about $1.5 billion, affirming its investment-grade rating. Quarterly distribution was set at $0.1525 per unit.

Positive

• Net income attributable to partners increased by $273 million year-over-year, totaling $626 million.
• Adjusted EBITDA rose to $2.62 billion, up from $2.44 billion in Q2 2020.
• Distributable Cash Flow for Q2 increased to $1.39 billion, driven by higher EBITDA.
• Outstanding debt was reduced by approximately $1.5 billion during the second quarter.
• Investment-grade ratings were affirmed by two credit agencies, outlook revised to stable.
• Quarterly distribution announced at $0.1525 per unit.

Negative

• None.

Energy Transfer LP (NYSE:ET) (“ET” or the “Partnership”) today reported financial results for the quarter ended June 30, 2021.

ET reported net income attributable to partners for the three months ended June 30, 2021 of $626 million, an increase of $273 million compared to the same period the previous year. For the three months ended June 30, 2021, net income per limited partner unit (basic and diluted) was $0.20 per unit.

Adjusted EBITDA for the three months ended June 30, 2021 was $2.62 billion compared to $2.44 billion for the three months ended June 30, 2020. The increase was largely driven by improved earnings from several of the Partnership’s core segments.

Distributable Cash Flow attributable to partners, as adjusted, for the three months ended June 30, 2021 was $1.39 billion compared to $1.27 billion for the three months ended June 30, 2020. The increase in distributable cash flow was primarily due to the higher Adjusted EBITDA.

Key accomplishments and current developments:

Operational

• In June 2021, the Partnership commenced service on its Cushing to Nederland expansion project, which utilizes a crude oil pipeline previously servicing the Permian Basin. The new service provides connectivity to transport crude oil barrels from the Denver-Julesburg Basin and Cushing, Oklahoma to ET’s Nederland, Texas terminal.
• During the second quarter of 2021, the Partnership continued to ramp up volumes at its newly expanded Nederland, Texas terminal. As a result, when combined with Energy Transfer’s Marcus Hook Terminal on the east coast, ET exported more NGLs than any other company worldwide in the months of May and June.
• The Partnership recently commenced work on its Permian Bridge project, which converts existing pipeline assets to connect ET’s natural gas gathering and processing assets in the Delaware Basin with Midland Basin assets.

Strategic

• In May 2021, ET’s acquisition of Enable Midstream Partners, LP (“Enable”), which was announced in February 2021, was approved by a vote of the Enable unitholders. ET and Enable continue to work toward obtaining Hart-Scott-Rodino Act (“HSR”) clearance for the merger. ET continues to expect the transaction to close in the second half of 2021.
• In June 2021, ET’s patented Dual Drive Technologies natural gas compression system was awarded a 2021 GPA Midstream Environmental Excellence Award for its impact on reducing CO2 emissions.
• In July 2021, ET signed a memorandum of understanding with the Republic of Panama to study the feasibility of a proposed Trans-Panama Gateway LPG pipeline and the potential creation of a new strategically located NGL hub.

Financial

• During the second quarter of 2021, the Partnership reduced outstanding debt by approximately $1.5 billion, utilizing cash from operations and proceeds from its recent $900 million Series H preferred unit offering. Year-to-date in 2021, ET has reduced its long-term debt by approximately $5.2 billion.
• In May 2021, two credit rating agencies affirmed ET’s investment grade ratings and revised ET’s outlook from negative to stable.
• As of June 30, 2021, the Partnership’s $6.00 billion revolving credit facilities had an aggregate $5.02 billion of available capacity, and the leverage ratio, as defined by the credit agreement, was 3.14x.
• For the three months ended June 30, 2021, the Partnership invested approximately $355 million on growth capital expenditures.
• In July 2021, ET announced a quarterly distribution of $0.1525 per unit ($0.61 annualized) on ET common units for the quarter ended June 30, 2021.

ET benefits from a portfolio of assets with exceptional product and geographic diversity. The Partnership’s multiple segments generate high-quality, balanced earnings with no single segment contributing more than 30% of the Partnership’s consolidated Adjusted EBITDA for the three months ended June 30, 2021. The vast majority of the Partnership’s segment margins are fee-based and therefore have limited commodity price sensitivity.

Conference Call information:

The Partnership has scheduled a conference call for 3:30 p.m. Central Time, Tuesday, August 3, 2021 to discuss its second quarter 2021 results and provide a partnership update. The conference call will be broadcast live via an internet webcast, which can be accessed through www.energytransfer.com and will also be available for replay on the Partnership’s website for a limited time.

Energy Transfer LP (NYSE: ET) owns and operates one of the largest and most diversified portfolios of energy assets in the United States, with a strategic footprint in all of the major domestic production basins. ET is a publicly traded limited partnership with core operations that include complementary natural gas midstream, intrastate and interstate transportation and storage assets; crude oil, natural gas liquids (“NGL”) and refined product transportation and terminalling assets; NGL fractionation; and various acquisition and marketing assets. ET also owns Lake Charles LNG Company, as well as the general partner interests, the incentive distribution rights and 28.5 million common units of Sunoco LP (NYSE: SUN), and the general partner interests and 46.1 million common units of USA Compression Partners, LP (NYSE: USAC). For more information, visit the Energy Transfer LP website at www.energytransfer.com.

Sunoco LP (NYSE: SUN) is a master limited partnership with core operations that include the distribution of motor fuel to approximately 10,000 convenience stores, independent dealers, commercial customers and distributors located in more than 30 states, as well as refined product transportation and terminalling assets. SUN’s general partner is owned by Energy Transfer LP (NYSE: ET). For more information, visit the Sunoco LP website at www.sunocolp.com.

USA Compression Partners, LP (NYSE: USAC) is a growth-oriented Delaware limited partnership that is one of the nation’s largest independent providers of natural gas compression services in terms of total compression fleet horsepower. USAC partners with a broad customer base composed of producers, processors, gatherers and transporters of natural gas and crude oil. USAC focuses on providing compression services to infrastructure applications primarily in high-volume gathering systems, processing facilities and transportation applications. For more information, visit the USAC website at www.usacompression.com.

Forward-Looking Statements

This news release may include certain statements concerning expectations for the future that are forward-looking statements as defined by federal law. Such forward-looking statements are subject to a variety of known and unknown risks, uncertainties, and other factors that are difficult to predict and many of which are beyond management’s control. An extensive list of factors that can affect future results are discussed in the Partnership’s Annual Report on Form 10-K and other documents filed from time to time with the Securities and Exchange Commission, including the Partnership’s Quarterly Report on Form 10-Q to be filed for the current period. In addition to the risks and uncertainties previously disclosed, the Partnership has also been, or may in the future be, impacted by new or heightened risks related to the COVID-19 pandemic, and we cannot predict the length and ultimate impact of those risks. The Partnership has also been, and may in the future be, impacted by the winter storm in February 2021 and the resolution of related contingencies, including credit losses, disputed purchases and sales, litigation and/or potential legislative action. The Partnership undertakes no obligation to update or revise any forward-looking statement to reflect new information or events.

The information contained in this press release is available on our website at www.energytransfer.com.

 

ENERGY TRANSFER LP AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS
(In millions)
(unaudited)
	June 30, 2021				December 31, 2020
ASSETS
Current assets	$	8,208			$	6,317
Property, plant and equipment, net	74,551				75,107
Investments in unconsolidated affiliates	3,025				3,060
Lease right-of-use assets, net	841				866
Other non-current assets, net	1,664				1,657
Intangible assets, net	5,562				5,746
Goodwill	2,391				2,391
Total assets	$	96,242			$	95,144
LIABILITIES AND EQUITY
Current liabilities (1)	$	8,547			$	5,923
Long-term debt, less current maturities	45,612				51,417
Non-current derivative liabilities	378				237
Non-current operating lease liabilities	812				837
Deferred income taxes	3,618				3,428
Other non-current liabilities	1,224				1,152
Commitments and contingencies
Redeemable noncontrolling interests	776				762
Equity:
Limited Partners:
Preferred Unitholders	5,654				—
Common Unitholders	21,579				18,531
General Partner	(5)				(8)
Accumulated other comprehensive income	26				6
Total partners’ capital	27,254				18,529
Noncontrolling interests	8,021				12,859
Total equity	35,275				31,388
Total liabilities and equity	$	96,242			$	95,144
(1) As of June 30, 2021, current liabilities include $674 million of current maturities of long-term debt. This total includes all of the $650 million of senior notes due in April 2022 from the Bakken Pipeline entities, for which our proportionate ownership is 36.4%.

ENERGY TRANSFER LP AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(In millions, except per unit data)
(unaudited)
	Three Months Ended June 30,								Six Months Ended June 30,
	2021				2020				2021				2020
REVENUES	$	15,101			$	7,338			$	32,096			$	18,965
COSTS AND EXPENSES:
Cost of products sold	11,505				4,117				22,453				12,408
Operating expenses	867				770				1,687				1,649
Depreciation, depletion and amortization	940				936				1,894				1,803
Selling, general and administrative	184				175				385				379
Impairment losses	8				4				11				1,329
Total costs and expenses	13,504				6,002				26,430				17,568
OPERATING INCOME	1,597				1,336				5,666				1,397
OTHER INCOME (EXPENSE):
Interest expense, net of interest capitalized	(566)				(579)				(1,155)				(1,181)
Equity in earnings of unconsolidated affiliates	65				85				120				78
Losses on extinguishments of debt	(1)				—				(8)				(62)
Gains (losses) on interest rate derivatives	(123)				(3)				71				(332)
Other, net	18				(68)				12				(65)
INCOME (LOSS) BEFORE INCOME TAX EXPENSE	990				771				4,706				(165)
Income tax expense	82				99				157				127
NET INCOME (LOSS)	908				672				4,549				(292)
Less: Net income attributable to noncontrolling interests	269				306				610				185
Less: Net income attributable to redeemable noncontrolling interests	13				13				25				25
NET INCOME (LOSS) ATTRIBUTABLE TO PARTNERS	626				353				3,914				(502)
General Partner’s interest in net income (loss)	1				—				4				(1)
Preferred Unitholders’ interest in net income	86				—				86				—
Limited Partners’ interest in net income (loss)	$	539			$	353			$	3,824			$	(501)
NET INCOME (LOSS) PER LIMITED PARTNER UNIT:
Basic	$	0.20			$	0.13			$	1.41			$	(0.19)
Diluted	$	0.20			$	0.13			$	1.41			$	(0.19)
WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING:
Basic	2,704.0				2,694.9				2,703.4				2,693.3
Diluted	2,717.8				2,695.8				2,715.5				2,693.3

ENERGY TRANSFER LP AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION
(Dollars and units in millions)
(unaudited)
	Three Months Ended June 30,								Six Months Ended June 30,
	2021				2020				2021(a)				2020
Reconciliation of net income (loss) to Adjusted EBITDA and Distributable Cash Flow(b):
Net income (loss)	$	908			$	672			$	4,549			$	(292)
Interest expense, net of interest capitalized	566				579				1,155				1,181
Impairment losses	8				4				11				1,329
Income tax expense	82				99				157				127
Depreciation, depletion and amortization	940				936				1,894				1,803
Non-cash compensation expense	27				41				55				63
(Gains) losses on interest rate derivatives	123				3				(71)				332
Unrealized (gains) losses on commodity risk management activities	(47)				48				(93)				(3)
Losses on extinguishments of debt	1				—				8				62
Inventory valuation adjustments (Sunoco LP)	(59)				(90)				(159)				137
Equity in earnings of unconsolidated affiliates	(65)				(85)				(120)				(78)
Adjusted EBITDA related to unconsolidated affiliates	136				157				259				311
Other, net	(4)				74				11				101
Adjusted EBITDA (consolidated)	2,616				2,438				7,656				5,073
Adjusted EBITDA related to unconsolidated affiliates	(136)				(157)				(259)				(311)
Distributable cash flow from unconsolidated affiliates	89				112				165				225
Interest expense, net of interest capitalized	(566)				(579)				(1,155)				(1,181)
Preferred unitholders’ distributions	(99)				(96)				(195)				(185)
Current income tax expense	(15)				(15)				(24)				(1)
Maintenance capital expenditures	(140)				(136)				(216)				(239)
Other, net	17				18				36				40
Distributable Cash Flow (consolidated)	1,766				1,585				6,008				3,421
Distributable Cash Flow attributable to Sunoco LP (100%)	(145)				(122)				(253)				(281)
Distributions from Sunoco LP	42				41				83				82
Distributable Cash Flow attributable to USAC (100%)	(52)				(58)				(105)				(113)
Distributions from USAC	24				24				48				48
Distributable Cash Flow attributable to noncontrolling interests in other non-wholly-owned consolidated subsidiaries	(251)				(209)				(502)				(499)
Distributable Cash Flow attributable to the partners of ET	1,384				1,261				5,279				2,658
Transaction-related adjustments	9				10				28				30
Distributable Cash Flow attributable to the partners of ET, as adjusted	$	1,393			$	1,271			$	5,307			$	2,688
Distributions to partners:
Limited Partners	$	413			$	822			$	825			$	1,644
General Partner	1				1				1				2
Total distributions to be paid to partners	$	414			$	823			$	826			$	1,646
Common Units outstanding – end of period	2,704.6				2,695.6				2,704.6				2,695.6
Distribution coverage ratio	3.36x				1.54x				6.42x				1.63x
(a) Winter Storm Uri, which occurred in February 2021, resulted in one-time impacts to the Partnership’s consolidated net income, Adjusted EBITDA and Distributable Cash Flow. Please see additional discussion of these impacts, as well as the potential impacts to future periods, included in the “Summary Analysis of Quarterly Results by Segment” below.
(b) Adjusted EBITDA, Distributable Cash Flow and distribution coverage ratio are non-GAAP financial measures used by industry analysts, investors, lenders and rating agencies to assess the financial performance and the operating results of ET’s fundamental business activities and should not be considered in isolation or as a substitute for net income, income from operations, cash flows from operating activities or other GAAP measures.

There are material limitations to using measures such as Adjusted EBITDA, Distributable Cash Flow and distribution coverage ratio, including the difficulty associated with using any such measure as the sole measure to compare the results of one company to another, and the inability to analyze certain significant items that directly affect a company’s net income or loss or cash flows. In addition, our calculations of Adjusted EBITDA, Distributable Cash Flow and distribution coverage ratio may not be consistent with similarly titled measures of other companies and should be viewed in conjunction with measurements that are computed in accordance with GAAP, such as operating income, net income and cash flow from operating activities.

Definition of Adjusted EBITDA

We define Adjusted EBITDA as total partnership earnings before interest, taxes, depreciation, depletion, amortization and other non-cash items, such as non-cash compensation expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and other non-operating income or expense items. Inventory adjustments that are excluded from the calculation of Adjusted EBITDA represent only the changes in lower of cost or market reserves on inventory that is carried at last-in, first-out (“LIFO”). These amounts are unrealized valuation adjustments applied to Sunoco LP’s fuel volumes remaining in inventory at the end of the period.

Adjusted EBITDA reflects amounts for unconsolidated affiliates based on the same recognition and measurement methods used to record equity in earnings of unconsolidated affiliates. Adjusted EBITDA related to unconsolidated affiliates excludes the same items with respect to the unconsolidated affiliate as those excluded from the calculation of Adjusted EBITDA, such as interest, taxes, depreciation, depletion, amortization and other non-cash items. Although these amounts are excluded from Adjusted EBITDA related to unconsolidated affiliates, such exclusion should not be understood to imply that we have control over the operations and resulting revenues and expenses of such affiliates. We do not control our unconsolidated affiliates; therefore, we do not control the earnings or cash flows of such affiliates. The use of Adjusted EBITDA or Adjusted EBITDA related to unconsolidated affiliates as an analytical tool should be limited accordingly.

Adjusted EBITDA is used by management to determine our operating performance and, along with other financial and volumetric data, as internal measures for setting annual operating budgets, assessing financial performance of our numerous business locations, as a measure for evaluating targeted businesses for acquisition and as a measurement component of incentive compensation.

Definition of Distributable Cash Flow

We define Distributable Cash Flow as net income, adjusted for certain non-cash items, less distributions to preferred unitholders and maintenance capital expenditures. Non-cash items include depreciation, depletion and amortization, non-cash compensation expense, amortization included in interest expense, gains and losses on disposals of assets, the allowance for equity funds used during construction, unrealized gains and losses on commodity risk management activities, inventory valuation adjustments, non-cash impairment charges, losses on extinguishments of debt and deferred income taxes. For unconsolidated affiliates, Distributable Cash Flow reflects the Partnership’s proportionate share of the investee’s distributable cash flow.

Distributable Cash Flow is used by management to evaluate our overall performance. Our partnership agreement requires us to distribute all available cash, and Distributable Cash Flow is calculated to evaluate our ability to fund distributions through cash generated by our operations.

On a consolidated basis, Distributable Cash Flow includes 100% of the Distributable Cash Flow of ET’s consolidated subsidiaries. However, to the extent that noncontrolling interests exist among our subsidiaries, the Distributable Cash Flow generated by our subsidiaries may not be available to be distributed to our partners. In order to reflect the cash flows available for distributions to our partners, we have reported Distributable Cash Flow attributable to partners, which is calculated by adjusting Distributable Cash Flow (consolidated), as follows:

• For subsidiaries with publicly traded equity interests, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiary, and Distributable Cash Flow attributable to our partners includes distributions to be received by the parent company with respect to the periods presented.
• For consolidated joint ventures or similar entities, where the noncontrolling interest is not publicly traded, Distributable Cash Flow (consolidated) includes 100% of Distributable Cash Flow attributable to such subsidiaries, but Distributable Cash Flow attributable to partners reflects only the amount of Distributable Cash Flow of such subsidiaries that is attributable to our ownership interest.

For Distributable Cash Flow attributable to partners, as adjusted, certain transaction-related adjustments and non-recurring expenses that are included in net income are excluded.

Definition of Distribution Coverage Ratio

Distribution coverage ratio for a period is calculated as Distributable Cash Flow attributable to partners, as adjusted, divided by distributions expected to be paid to the partners of ET in respect of such period.

ENERGY TRANSFER LP AND SUBSIDIARIES
SUMMARY ANALYSIS OF QUARTERLY RESULTS BY SEGMENT
(Tabular dollar amounts in millions)
(unaudited)
	Three Months Ended June 30,
	2021				2020
Segment Adjusted EBITDA:
Intrastate transportation and storage	$	224			$	187
Interstate transportation and storage	331				403
Midstream	477				367
NGL and refined products transportation and services	736				674
Crude oil transportation and services	484				519
Investment in Sunoco LP	201				182
Investment in USAC	100				105
All other	63				1
Total Segment Adjusted EBITDA	$	2,616			$	2,438

In the following analysis of segment operating results, a measure of segment margin is reported for segments with sales revenues. Segment margin is a non-GAAP financial measure and is presented herein to assist in the analysis of segment operating results and particularly to facilitate an understanding of the impacts that changes in sales revenues have on the segment performance measure of Segment Adjusted EBITDA. Segment margin is similar to the GAAP measure of gross margin, except that segment margin excludes charges for depreciation, depletion and amortization. Among the GAAP measures reported by the Partnership, the most directly comparable measure to segment margin is Segment Adjusted EBITDA; a reconciliation of segment margin to Segment Adjusted EBITDA is included in the following tables for each segment where segment margin is presented.

In addition, for certain segments, the sections below include information on the components of segment margin by sales type, which components are included in order to provide additional disaggregated information to facilitate the analysis of segment margin and Segment Adjusted EBITDA. For example, these components include transportation margin, storage margin and other margin. These components of segment margin are calculated consistent with the calculation of segment margin; therefore, these components also exclude charges for depreciation, depletion and amortization.

Intrastate Transportation and Storage

	Three Months Ended June 30,
	2021				2020
Natural gas transported (BBtu/d)	13,205				12,921
Withdrawals from storage natural gas inventory (BBtu)	10,643				(1,910)
Revenues	$	949			$	516
Cost of products sold	664				248
Segment margin	285				268
Unrealized gains on commodity risk management activities	(5)				(33)
Operating expenses, excluding non-cash compensation expense	(55)				(48)
Selling, general and administrative expenses, excluding non-cash compensation expense	(9)				(6)
Adjusted EBITDA related to unconsolidated affiliates	7				6
Other	1				—
Segment Adjusted EBITDA	$	224			$	187

Transported volumes increased primarily due to volume ramp-ups in the Permian.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our intrastate transportation segment increased due to the net effects of the following:

• an increase of $52 million in transportation fees due to revenues related to Winter Storm Uri of $39 million, as well as increased firm transportation volumes from the Permian, partially offset by the expiration of certain contracts on our Regency Intrastate Gas System; and
• an increase of $13 million in retained fuel revenues primarily due to higher gas prices; partially offset by
• a decrease of $11 million in realized natural gas sales and other primarily due to lower optimization volumes with shifts to long-term third-party contracts from the Permian to the Gulf Coast;
• a decrease of $9 million in realized storage margin due to lower storage optimization; and
• an increase of $7 million in operating expenses primarily due to higher cost of fuel consumption from higher gas prices.

Interstate Transportation and Storage

	Three Months Ended June 30,
	2021				2020
Natural gas transported (BBtu/d)	9,735				10,152
Natural gas sold (BBtu/d)	18				17
Revenues	$	407			$	445
Operating expenses, excluding non-cash compensation, amortization and accretion expenses	(143)				(139)
Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses	(21)				(16)
Adjusted EBITDA related to unconsolidated affiliates	89				115
Other	(1)				(2)
Segment Adjusted EBITDA	$	331			$	403

Transported volumes decreased primarily due to foundation shipper contract expirations and a shipper bankruptcy on our Tiger system, as well as lower utilization resulting from unfavorable market conditions on our Panhandle and Trunkline systems, partially offset by increased short-term firm and interruptible utilization on our Rover system.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our interstate transportation and storage segment decreased due to the net impacts of the following:

• a decrease of $38 million in revenues primarily due to a $30 million decline as a result of shipper contract expirations on our Tiger system and a $14 million decline due to a shipper bankruptcy during 2020 also on our Tiger system. These decreases were partially offset by an increase of $6 million from interruptible and short-term firm transportation volumes sold primarily on our Rover system due to increased demand on the system;
• an increase of $4 million in operating expenses primarily due to higher employee costs of $12 million, partially offset by credit losses recorded in 2020 related to a shipper bankruptcy;
• an increase of $5 million in selling, general and administrative expenses primarily due to higher allocated overhead costs and employee costs; and
• a decrease of $26 million in Adjusted EBITDA related to unconsolidated affiliates primarily due to a $19 million decrease from our Fayetteville Express Pipeline joint venture as a result of the expiration of foundation shipper contracts, a $4 million decrease from our Citrus joint venture resulting from higher employee costs and maintenance project costs and a $3 million decrease from our Midcontinent Express Pipeline joint venture as a result of lower revenue due to capacity sold at lower rates.

Midstream

	Three Months Ended June 30,
	2021				2020
Gathered volumes (BBtu/d)	13,112				12,964
NGLs produced (MBbls/d)	665				602
Equity NGLs (MBbls/d)	38				37
Revenues	$	2,199			$	1,018
Cost of products sold	1,509				473
Segment margin	690				545
Operating expenses, excluding non-cash compensation expense	(196)				(166)
Selling, general and administrative expenses, excluding non-cash compensation expense	(27)				(20)
Adjusted EBITDA related to unconsolidated affiliates	8				7
Other	2				1
Segment Adjusted EBITDA	$	477			$	367

Gathered volumes and NGL production increased compared to the same period last year primarily due to increases in the Permian, Ark-La-Tex, South Texas and North Texas regions, partially offset by volume declines in the Northeast and Mid-Continent/Panhandle regions.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our midstream segment increased due to the net impacts of the following:

• an increase of $111 million in non-fee-based margin due to favorable NGL prices of $75 million and natural gas prices of $36 million;
• an increase of $15 million in non-fee-based margin due to increased throughput in the Permian region and the ramp-up of recently completed assets in the Northeast region; and
• an increase of $19 million in fee-based margin due to volume growth in the Permian region; partially offset by
• an increase of $30 million in operating expenses due to increases of $19 million in employee costs, $4 million in outside services, $3 million in allocated overhead costs and $2 million in maintenance project costs; and
• an increase of $7 million in selling, general and administrative expenses due to higher allocated overhead costs.

NGL and Refined Products Transportation and Services

	Three Months Ended June 30,
	2021				2020
NGL transportation volumes (MBbls/d)	1,748				1,401
Refined products transportation volumes (MBbls/d)	510				377
NGL and refined products terminal volumes (MBbls/d)	1,186				746
NGL fractionation volumes (MBbls/d)	833				836
Revenues	$	4,522			$	2,119
Cost of products sold	3,547				1,368
Segment margin	975				751
Unrealized (gains) losses on commodity risk management activities	(46)				78
Operating expenses, excluding non-cash compensation expense	(194)				(154)
Selling, general and administrative expenses, excluding non-cash compensation expense	(27)				(19)
Adjusted EBITDA related to unconsolidated affiliates	28				18
Segment Adjusted EBITDA	$	736			$	674

NGL transportation volumes increased primarily due to the initiation of service on our propane and ethane export pipelines into our Nederland Terminal in the fourth quarter of 2020, higher volumes from the Eagle Ford region and higher volumes on our Mariner East and West pipeline systems.

Refined products transportation volumes increased due to recovery from COVID-19 related demand reduction in the prior period.

NGL and refined products terminal volumes increased primarily due to increased export volumes at our Nederland Terminal due to the initiation of service on our propane and ethane export pipelines in the fourth quarter of 2020, higher throughput volumes on our Mariner East and West pipeline systems and increased throughput at our refined product terminals due to recovery from COVID-19 related demand reduction in the prior period.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our NGL and refined products transportation and services segment increased due to the net impacts of the following:

• an increase of $40 million in transportation margin primarily due to a $27 million increase due to higher export volumes feeding into our Nederland Terminal and a $17 million increase from higher throughput on our Mariner pipeline system;
• an increase of $34 million in terminal services margin primarily due to a $22 million increase in ethane export fees at our Nederland Terminal, a $10 million increase due to higher throughput at our Marcus Hook Terminal, an increase of $9 million in loading fees due to higher LPG export volumes at our Nederland Terminal and a $5 million increase due to higher throughput at our refined product terminals. These increases were partially offset by an $11 million decrease resulting from an expiration of a third-party contract at our Nederland Terminal in the second quarter of 2020;
• an increase of $15 million in storage margin primarily due to a $9 million increase in fees generated from exported volumes, as well as increases related to blending activity due to a more favorable pricing environment and the timing of cavern withdrawals; and
• an increase of $10 million in fractionators and refinery services margin primarily due to a more favorable pricing environment impacting our refinery services business; partially offset by
• an increase of $40 million in operating expenses primarily due to a $19 million increase in utilities cost, a $12 million increase in employee related costs and an $8 million increase in allocated corporate overhead costs; and
• an increase of $8 million in selling, general and administrative expenses primarily due to corporate cost reductions in 2020.

Crude Oil Transportation and Services

	Three Months Ended June 30,
	2021				2020
Crude transportation volumes (MBbls/d)	3,943				3,549
Crude terminals volumes (MBbls/d)	2,532				2,703
Revenues	$	4,420			$	1,814
Cost of products sold	3,764				1,150
Segment margin	656				664
Unrealized losses on commodity risk management activities	3				—
Operating expenses, excluding non-cash compensation expense	(150)				(131)
Selling, general and administrative expenses, excluding non-cash compensation expense	(28)				(26)
Adjusted EBITDA related to unconsolidated affiliates	3				11
Other	—				1
Segment Adjusted EBITDA	$	484			$	519

Crude transportation volumes were higher on our Texas pipeline system and Bakken pipeline, driven by a recovery in crude oil production in these regions as a result of higher crude oil prices as well as a recovery in refinery utilization. Volumes on our Bayou Bridge pipeline were also higher, driven by more favorable crude oil differentials for shippers. Crude Terminal volumes were lower primarily due to reduced export demand.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our crude oil transportation and services segment decreased due to the net impacts of the following:

• a decrease of $5 million in segment margin (excluding unrealized gains and losses on commodity risk management activities) primarily due to a $35 million decrease from our Texas crude pipeline system due to lower average tariff rates, a $17 million decrease (excluding unrealized gains and losses on commodity risk management activities) from our crude oil acquisition and marketing business due primarily to storage trading gains realized in the second quarter of 2020 due to favorable market conditions and a $2 million decrease in throughput at our crude terminals primarily driven by lower export demand; partially offset by a $33 million increase due to higher volumes on our Bakken Pipeline and a $17 million increase due to higher volumes on our Bayou Bridge pipeline;
• an increase of $19 million in operating expenses primarily due to the timing of higher utility expenses resulting from Winter Storm Uri and timing of maintenance projects;
• an increase of $2 million in selling, general and administrative expenses primarily due to higher corporate allocations to the crude segment; and
• a decrease of $8 million in Adjusted EBITDA related to unconsolidated affiliates due to lower volumes on White Cliffs pipeline from lower crude oil production.

Investment in Sunoco LP

	Three Months Ended June 30,
	2021				2020
Revenues	$	4,392			$	2,080
Cost of products sold	4,039				1,722
Segment margin	353				358
Unrealized gains on commodity risk management activities	(2)				—
Operating expenses, excluding non-cash compensation expense	(75)				(72)
Selling, general and administrative expenses, excluding non-cash compensation expense	(24)				(22)
Adjusted EBITDA related to unconsolidated affiliates	2				3
Inventory valuation adjustments	(59)				(90)
Other	6				5
Segment Adjusted EBITDA	$	201			$	182

The Investment in Sunoco LP segment reflects the consolidated results of Sunoco LP.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our investment in Sunoco LP segment increased due to the net impacts of the following:

• an increase in the gross profit on motor fuel sales of $12 million primarily due to a 27.6% increase in gallons sold, partially offset by a 16.6% decrease in gross profit per gallon sold; and
• an increase in non-motor fuel sales of $12 million primarily due to increased credit card transactions, merchandise gross profit and franchise fee income; partially offset by
• an increase in operating expenses and selling, general and administrative expenses primarily due to higher maintenance and advertising costs.

Investment in USAC

	Three Months Ended June 30,
	2021				2020
Revenues	$	156			$	169
Cost of products sold	21				18
Segment margin	135				151
Operating expenses, excluding non-cash compensation expense	(24)				(30)
Selling, general and administrative expenses, excluding non-cash compensation expense	(11)				(16)
Segment Adjusted EBITDA	$	100			$	105

The Investment in USAC segment reflects the consolidated results of USAC.

Segment Adjusted EBITDA. For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our investment in USAC segment decreased due to the net impacts of the following:

• a decrease of $16 million in segment margin primarily due to a decrease in demand for compression services driven by continued capital discipline and optimization of existing compression service requirements by existing customers; partially offset by
• a decrease of $6 million in operating expenses primarily due to sales tax refunds received in the current period; and
• a decrease of $5 million in selling, general and administrative expenses primarily due to a $2 million decrease in the provision for expected credit losses and a $2 million decrease in severance charges related to the departure of an executive.

All Other

	Three Months Ended June 30,
	2021				2020
Revenues	$	576			$	492
Cost of products sold	470				377
Segment margin	106				115
Unrealized losses on commodity risk management activities	3				2
Operating expenses, excluding non-cash compensation expense	(38)				(27)
Selling, general and administrative expenses, excluding non-cash compensation expense	(19)				(22)
Other and eliminations	11				(67)
Segment Adjusted EBITDA	$	63			$	1

For the three months ended June 30, 2021 compared to the same period last year, Segment Adjusted EBITDA related to our all other segment increased primarily due to the net impacts of the following:

• an increase of $8 million from power trading activities;
• an increase of $14 million due to the realization of amounts in excess of book values on previously reserved receivables in our marketing business;
• an increase of $11 million primarily due to higher gas revenue and lower power costs at our compressor equipment business;
• an increase of $7 million due to lower allocated utility expense;
• an increase of $9 million due to lower corporate expenses; and
• an increase of $4 million primarily due to increased service fees and foreign currency fluctuations at Energy Transfer Canada.

   

ENERGY TRANSFER LP AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION ON LIQUIDITY
(In millions)
(unaudited)
The following table is a summary of our revolving credit facilities. We also have other consolidated subsidiaries with revolving credit facilities which are not included in this table.
	Facility Size				Funds Available at June 30, 2021				Maturity Date
Five-Year Revolving Credit Facility	$	5,000			$	4,024			December 1, 2024
364-Day Revolving Credit Facility	1,000				1,000				November 26, 2021
	$	6,000			$	5,024

ENERGY TRANSFER LP AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION ON UNCONSOLIDATED AFFILIATES
(In millions)
(unaudited)
The table below provides information on an aggregated basis for our unconsolidated affiliates, which are accounted for as equity method investments in the Partnership’s financial statements for the periods presented.
	Three Months Ended June 30,
	2021				2020
Equity in earnings (losses) of unconsolidated affiliates:
Citrus	$	42			$	42
FEP	—				18
MEP	(4)				(2)
White Cliffs	1				9
Other	26				18
Total equity in earnings (losses) of unconsolidated affiliates	$	65			$	85
Adjusted EBITDA related to unconsolidated affiliates:
Citrus	$	85			89
FEP	—				19
MEP	5				7
White Cliffs	5				13
Other	41				29
Total Adjusted EBITDA related to unconsolidated affiliates	$	136			$	157
Distributions received from unconsolidated affiliates:
Citrus	$	29			$	58
FEP	—				17
MEP	4				7
White Cliffs	5				10
Other	26				20
Total distributions received from unconsolidated affiliates	$	64			$	112

ENERGY TRANSFER LP AND SUBSIDIARIES
SUPPLEMENTAL INFORMATION ON NON-WHOLLY-OWNED JOINT VENTURE SUBSIDIARIES
(Dollars in millions)
(unaudited)
The table below provides information on an aggregated basis for our non-wholly-owned joint venture subsidiaries, which are reflected on a consolidated basis in our financial statements. The table below excludes Sunoco LP and USAC, our non-wholly-owned subsidiaries that are publicly traded.
	Three Months Ended June 30,
	2021				2020
Adjusted EBITDA of non-wholly-owned subsidiaries (100%) (a)	$	549			$	494
Our proportionate share of Adjusted EBITDA of non-wholly-owned subsidiaries (b)	283				264
Distributable Cash Flow of non-wholly-owned subsidiaries (100%) (c)	$	508			$	456
Our proportionate share of Distributable Cash Flow of non-wholly-owned subsidiaries (d)	257				247

Below is our current ownership percentage of certain non-wholly-owned subsidiaries:
Non-wholly-owned subsidiary:	ET Percentage Ownership (e)
Bakken Pipeline	36.4 %
Bayou Bridge	60.0 %
Maurepas	51.0 %
Ohio River System	75.0 %
Permian Express Partners	87.7 %
Red Bluff Express	70.0 %
Rover	32.6 %
Energy Transfer Canada	51.0 %
Others	various
(a) Adjusted EBITDA of non-wholly-owned subsidiaries reflects the total Adjusted EBITDA of our non-wholly-owned subsidiaries on an aggregated basis. This is the amount of Adjusted EBITDA included in our consolidated non-GAAP measure of Adjusted EBITDA.
(b) Our proportionate share of Adjusted EBITDA of non-wholly-owned subsidiaries reflects the amount of Adjusted EBITDA of such subsidiaries (on an aggregated basis) that is attributable to our ownership interest.
(c) Distributable Cash Flow of non-wholly-owned subsidiaries reflects the total Distributable Cash Flow of our non-wholly-owned subsidiaries on an aggregated basis.
(d) Our proportionate share of Distributable Cash Flow of non-wholly-owned subsidiaries reflects the amount of Distributable Cash Flow of such subsidiaries (on an aggregated basis) that is attributable to our ownership interest. This is the amount of Distributable Cash Flow included in our consolidated non-GAAP measure of Distributable Cash Flow attributable to the partners of ET.
(e) Our ownership reflects the total economic interest held by us and our subsidiaries. In some cases, this percentage comprises ownership interests held in (or by) multiple entities.

 

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FAQ

What was Energy Transfer's net income for the second quarter of 2021?

Energy Transfer reported a net income of $626 million for the second quarter of 2021.

How much did Energy Transfer reduce its debt in Q2 2021?

Energy Transfer reduced its outstanding debt by approximately $1.5 billion during the second quarter of 2021.

What is the quarterly distribution announced by Energy Transfer for Q2 2021?

Energy Transfer announced a quarterly distribution of $0.1525 per unit for the quarter ended June 30, 2021.

When will Energy Transfer discuss its Q2 2021 results?

Energy Transfer has scheduled a conference call for 3:30 p.m. Central Time on August 3, 2021, to discuss its second quarter results.

What was the Adjusted EBITDA reported by Energy Transfer for Q2 2021?

Energy Transfer reported an Adjusted EBITDA of $2.62 billion for the second quarter of 2021.