Company Announcements

Energy Transfer Reports Second Quarter 2021 Results

DALLAS--(BUSINESS WIRE)--Aug. 3, 2021-- 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.

 

Energy Transfer
Investor Relations:
Bill Baerg, Brent Ratliff, Lyndsay Hannah, 214-981-0795
or
Media Relations:
Vicki Granado, 214-840-5820

Source: Energy Transfer LP