Energy Transfer LP (NYSE:ET) ("Energy Transfer" or the "Partnership") today reported financial results for the quarter ended March 31, 2022.
Energy Transfer reported net income attributable to partners for the three months ended March 31, 2022 of $1.27 billion. For the three months ended March 31, 2022, net income per limited partner unit (basic) was $0.38 per unit.
Adjusted EBITDA for the three months ended March 31, 2022 was $3.34 billion compared to $5.04 billion for the three months ended March 31, 2021. First quarter 2021 results were favorably impacted by earnings from the historic Winter Storm Uri. Excluding this contribution, Adjusted EBITDA would have increased over the prior period.
Distributable Cash Flow attributable to partners, as adjusted, for the three months ended March 31, 2022 was $2.08 billion compared to $3.91 billion for the three months ended March 31, 2021. The decrease from the prior period was primarily driven by the favorable impact on the first quarter 2021 Adjusted EBITDA from Winter Storm Uri discussed above.
For the first quarter 2022, Energy Transfer had higher transportation volumes across all of its segments and a full quarter contribution from the Enable Midstream assets that were acquired in December 2021.
Key accomplishments and recent developments:
Operational
Strategic
Financial
Energy Transfer 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 25% of the Partnership's consolidated Adjusted EBITDA for the three months ended March 31, 2022. 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/4:30 p.m. Eastern Time on Wednesday, May 4, 2022 to discuss its first quarter 2022 results and provide an update on the Partnership. 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 North America, with a strategic footprint in all of the major U.S. production basins. Energy Transfer 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; and NGL fractionation. Energy Transfer 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 40 U.S. states and territories, 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, including future distribution levels and leverage ratio, 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. 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 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) |
|||||||
|
March 31,
|
|
December 31,
|
||||
ASSETS |
|
|
|
||||
Current assets (1) |
$ |
15,699 |
|
|
$ |
10,537 |
|
|
|
|
|
||||
Property, plant and equipment, net |
|
80,035 |
|
|
|
81,607 |
|
|
|
|
|
||||
Investments in unconsolidated affiliates |
|
2,921 |
|
|
|
2,947 |
|
Lease right-of-use assets, net |
|
830 |
|
|
|
838 |
|
Other non-current assets, net |
|
1,566 |
|
|
|
1,645 |
|
Intangible assets, net |
|
5,608 |
|
|
|
5,856 |
|
Goodwill |
|
2,533 |
|
|
|
2,533 |
|
Total assets |
$ |
109,192 |
|
|
$ |
105,963 |
|
LIABILITIES AND EQUITY |
|
|
|
||||
Current liabilities (1) (2) |
$ |
13,719 |
|
|
$ |
10,835 |
|
|
|
|
|
||||
Long-term debt, less current maturities |
|
48,826 |
|
|
|
49,022 |
|
Non-current derivative liabilities |
|
139 |
|
|
|
193 |
|
Non-current operating lease liabilities |
|
809 |
|
|
|
814 |
|
Deferred income taxes |
|
3,540 |
|
|
|
3,648 |
|
Other non-current liabilities |
|
1,337 |
|
|
|
1,323 |
|
|
|
|
|
||||
Commitments and contingencies |
|
|
|
||||
Redeemable noncontrolling interests |
|
493 |
|
|
|
783 |
|
|
|
|
|
||||
Equity: |
|
|
|
||||
Limited Partners: |
|
|
|
||||
Preferred Unitholders |
|
6,077 |
|
|
|
6,051 |
|
Common Unitholders |
|
25,881 |
|
|
|
25,230 |
|
General Partner |
|
(3 |
) |
|
|
(4 |
) |
Accumulated other comprehensive income |
|
43 |
|
|
|
23 |
|
Total partners' capital |
|
31,998 |
|
|
|
31,300 |
|
Noncontrolling interests |
|
8,331 |
|
|
|
8,045 |
|
Total equity |
|
40,329 |
|
|
|
39,345 |
|
Total liabilities and equity |
$ |
109,192 |
|
|
$ |
105,963 |
|
(1) |
As of March 31, 2022, current assets include $1.68 billion of current assets held for sale and current liabilities include $1.03 billion of current liabilities held for sale, related to the Partnership's pending sale of its interest in Energy Transfer Canada. |
(2) |
As of March 31, 2022, current liabilities include $652 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 proportional ownership is 36.4%. These notes were repaid in April 2022. |
ENERGY TRANSFER LP AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (In millions, except per unit data) (unaudited) |
|||||||
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
REVENUES |
$ |
20,491 |
|
|
$ |
16,995 |
|
COSTS AND EXPENSES: |
|
|
|
||||
Cost of products sold |
|
16,138 |
|
|
|
10,948 |
|
Operating expenses |
|
949 |
|
|
|
820 |
|
Depreciation, depletion and amortization |
|
1,028 |
|
|
|
954 |
|
Selling, general and administrative |
|
230 |
|
|
|
201 |
|
Impairment losses |
|
300 |
|
|
|
3 |
|
Total costs and expenses |
|
18,645 |
|
|
|
12,926 |
|
OPERATING INCOME |
|
1,846 |
|
|
|
4,069 |
|
OTHER INCOME (EXPENSE): |
|
|
|
||||
Interest expense, net of interest capitalized |
|
(559 |
) |
|
|
(589 |
) |
Equity in earnings of unconsolidated affiliates |
|
56 |
|
|
|
55 |
|
Losses on extinguishments of debt |
|
? |
|
|
|
(7 |
) |
Gains on interest rate derivatives |
|
114 |
|
|
|
194 |
|
Other, net |
|
21 |
|
|
|
(6 |
) |
INCOME BEFORE INCOME TAX EXPENSE (BENEFIT) |
|
1,478 |
|
|
|
3,716 |
|
Income tax expense (benefit) |
|
(9 |
) |
|
|
75 |
|
NET INCOME |
|
1,487 |
|
|
|
3,641 |
|
Less: Net income attributable to noncontrolling interests |
|
205 |
|
|
|
341 |
|
Less: Net income attributable to redeemable noncontrolling interests |
|
13 |
|
|
|
12 |
|
NET INCOME ATTRIBUTABLE TO PARTNERS |
|
1,269 |
|
|
|
3,288 |
|
General Partner's interest in net income |
|
1 |
|
|
|
3 |
|
Preferred Unitholders' interest in net income |
|
106 |
|
|
|
? |
|
Limited Partners' interest in net income |
$ |
1,162 |
|
|
$ |
3,285 |
|
NET INCOME PER COMMON UNIT: |
|
|
|
||||
Basic |
$ |
0.38 |
|
|
$ |
1.22 |
|
Diluted |
$ |
0.37 |
|
|
$ |
1.21 |
|
WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING: |
|
|
|
||||
Basic |
|
3,083.5 |
|
|
|
2,702.8 |
|
Diluted |
|
3,100.5 |
|
|
|
2,708.6 |
|
ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION (Dollars and units in millions) (unaudited) |
|||||||
|
Three Months Ended
|
||||||
|
2022 |
|
2021(a) |
||||
Reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow(b): |
|
|
|
||||
Net income |
$ |
1,487 |
|
|
$ |
3,641 |
|
Interest expense, net of interest capitalized |
|
559 |
|
|
|
589 |
|
Impairment losses |
|
300 |
|
|
|
3 |
|
Income tax expense (benefit) |
|
(9 |
) |
|
|
75 |
|
Depreciation, depletion and amortization |
|
1,028 |
|
|
|
954 |
|
Non-cash compensation expense |
|
36 |
|
|
|
28 |
|
Gains on interest rate derivatives |
|
(114 |
) |
|
|
(194 |
) |
Unrealized (gains) losses on commodity risk management activities |
|
45 |
|
|
|
(46 |
) |
Losses on extinguishments of debt |
|
? |
|
|
|
7 |
|
Inventory valuation adjustments (Sunoco LP) |
|
(120 |
) |
|
|
(100 |
) |
Equity in earnings of unconsolidated affiliates |
|
(56 |
) |
|
|
(55 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
125 |
|
|
|
123 |
|
Other, net |
|
59 |
|
|
|
15 |
|
Adjusted EBITDA (consolidated) |
|
3,340 |
|
|
|
5,040 |
|
Adjusted EBITDA related to unconsolidated affiliates |
|
(125 |
) |
|
|
(123 |
) |
Distributable cash flow from unconsolidated affiliates |
|
86 |
|
|
|
76 |
|
Interest expense, net of interest capitalized |
|
(559 |
) |
|
|
(589 |
) |
Preferred unitholders' distributions |
|
(118 |
) |
|
|
(96 |
) |
Current income tax (expense) benefit |
|
41 |
|
|
|
(9 |
) |
Transaction-related income taxes(c) |
|
(42 |
) |
|
|
? |
|
Maintenance capital expenditures |
|
(118 |
) |
|
|
(76 |
) |
Other, net |
|
5 |
|
|
|
19 |
|
Distributable Cash Flow (consolidated) |
|
2,510 |
|
|
|
4,242 |
|
Distributable Cash Flow attributable to Sunoco LP (100%) |
|
(142 |
) |
|
|
(108 |
) |
Distributions from Sunoco LP |
|
41 |
|
|
|
41 |
|
Distributable Cash Flow attributable to USAC (100%) |
|
(50 |
) |
|
|
(53 |
) |
Distributions from USAC |
|
24 |
|
|
|
24 |
|
Distributable Cash Flow attributable to noncontrolling interests in other non-wholly-owned consolidated subsidiaries |
|
(317 |
) |
|
|
(251 |
) |
Distributable Cash Flow attributable to the partners of Energy Transfer |
|
2,066 |
|
|
|
3,895 |
|
Transaction-related adjustments |
|
12 |
|
|
|
19 |
|
Distributable Cash Flow attributable to the partners of Energy Transfer, as adjusted |
$ |
2,078 |
|
|
$ |
3,914 |
|
Distributions to partners: |
|
|
|
||||
Limited Partners |
$ |
617 |
|
|
$ |
412 |
|
General Partner |
|
1 |
|
|
|
? |
|
Total distributions to be paid to partners |
$ |
618 |
|
|
$ |
412 |
|
Common Units outstanding ? end of period |
|
3,084.7 |
|
|
|
2,703.5 |
|
Distribution coverage ratio |
3.36x |
|
9.50x |
(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 Energy Transfer'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 Energy Transfer'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 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 Energy Transfer in respect of such period. |
|
(c) |
For the three months ended March 31, 2022, the amount reflected for transaction-related income taxes was related to an amended return from a previous transaction. |
ENERGY TRANSFER LP AND SUBSIDIARIES SUMMARY ANALYSIS OF QUARTERLY RESULTS BY SEGMENT (Tabular dollar amounts in millions) (unaudited) |
|||||
|
Three Months Ended
|
||||
|
2022 |
|
2021 |
||
Segment Adjusted EBITDA: |
|
|
|
||
Intrastate transportation and storage |
$ |
444 |
|
$ |
2,813 |
Interstate transportation and storage |
|
453 |
|
|
453 |
Midstream |
|
807 |
|
|
288 |
NGL and refined products transportation and services |
|
700 |
|
|
647 |
Crude oil transportation and services |
|
593 |
|
|
510 |
Investment in Sunoco LP |
|
191 |
|
|
157 |
Investment in USAC |
|
98 |
|
|
100 |
All other |
|
54 |
|
|
72 |
Total Segment Adjusted EBITDA |
$ |
3,340 |
|
$ |
5,040 |
The following analysis of segment operating results includes a measure of segment margin. 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
|
||||||
|
2022 |
|
2021 |
||||
Natural gas transported (BBtu/d) |
|
13,973 |
|
|
|
11,221 |
|
Withdrawals from storage natural gas inventory (BBtu) |
|
21,858 |
|
|
|
19,045 |
|
Revenues |
$ |
1,632 |
|
|
$ |
4,900 |
|
Cost of products sold |
|
1,171 |
|
|
|
1,994 |
|
Segment margin |
|
461 |
|
|
|
2,906 |
|
Unrealized (gains) losses on commodity risk management activities |
|
46 |
|
|
|
(12 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(63 |
) |
|
|
(80 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(12 |
) |
|
|
(8 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
6 |
|
|
|
6 |
|
Other |
|
6 |
|
|
|
1 |
|
Segment Adjusted EBITDA |
$ |
444 |
|
|
$ |
2,813 |
|
Transported volumes increased primarily due to the acquisition of the Enable Oklahoma Intrastate Transmission system, as well as increased production in the Permian and Haynesville.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our intrastate transportation segment decreased due to the net impacts of the following:
Interstate Transportation and Storage
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Natural gas transported (BBtu/d) |
|
15,098 |
|
|
|
9,654 |
|
Natural gas sold (BBtu/d) |
|
41 |
|
|
|
21 |
|
Revenues |
$ |
566 |
|
|
$ |
525 |
|
Cost of products sold |
|
19 |
|
|
|
? |
|
Segment margin |
|
547 |
|
|
|
525 |
|
Operating expenses, excluding non-cash compensation, amortization and accretion expenses |
|
(171 |
) |
|
|
(134 |
) |
Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses |
|
(31 |
) |
|
|
(21 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
88 |
|
|
|
85 |
|
Other |
|
20 |
|
|
|
(2 |
) |
Segment Adjusted EBITDA |
$ |
453 |
|
|
$ |
453 |
|
Transported volumes increased primarily due to the impact of the Enable Acquisition, higher utilization on our Tiger system due to increased production in the Haynesville Shale, higher volumes on our Transwestern system and increased short-term firm and interruptible utilization on our Rover system.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our interstate transportation and storage segment was unchanged due to the net impacts of the following:
Midstream
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Gathered volumes (BBtu/d) |
|
17,333 |
|
|
|
12,024 |
|
NGLs produced (MBbls/d) |
|
757 |
|
|
|
534 |
|
Equity NGLs (MBbls/d) |
|
42 |
|
|
|
30 |
|
Revenues |
$ |
3,925 |
|
|
$ |
2,672 |
|
Cost of products sold |
|
2,885 |
|
|
|
2,202 |
|
Segment margin |
|
1,040 |
|
|
|
470 |
|
Unrealized gains on commodity risk management activities |
|
(2 |
) |
|
|
? |
|
Operating expenses, excluding non-cash compensation expense |
|
(234 |
) |
|
|
(164 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(44 |
) |
|
|
(25 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
9 |
|
|
|
7 |
|
Other |
|
38 |
|
|
|
? |
|
Segment Adjusted EBITDA |
$ |
807 |
|
|
$ |
288 |
|
Gathered volumes and NGL production increased compared to the same period last year due to increased production in South Texas, additional gathering capacity from the Permian Bridge Pipeline and new volumes from the Enable Acquisition in December 2021.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our midstream segment increased due to the net impacts of the following:
NGL and Refined Products Transportation and Services
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
NGL transportation volumes (MBbls/d) |
|
1,752 |
|
|
|
1,502 |
|
Refined products transportation volumes (MBbls/d) |
|
496 |
|
|
|
462 |
|
NGL and refined products terminal volumes (MBbls/d) |
|
1,180 |
|
|
|
1,042 |
|
NGL fractionation volumes (MBbls/d) |
|
804 |
|
|
|
726 |
|
Revenues |
$ |
6,277 |
|
|
$ |
3,990 |
|
Cost of products sold |
|
5,356 |
|
|
|
3,141 |
|
Segment margin |
|
921 |
|
|
|
849 |
|
Unrealized gains on commodity risk management activities |
|
(5 |
) |
|
|
(23 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(202 |
) |
|
|
(172 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(35 |
) |
|
|
(28 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
21 |
|
|
|
21 |
|
Segment Adjusted EBITDA |
$ |
700 |
|
|
$ |
647 |
|
NGL transportation volumes increased primarily due to higher volumes from the Permian and Eagle Ford regions and the ramp-up in volumes on our propane and ethane export pipelines into our Nederland Terminal.
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 the ramp-up in volumes on our propane and ethane export pipelines and refined product demand recovery.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 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:
Crude Oil Transportation and Services
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Crude transportation volumes (MBbls/d) |
|
4,216 |
|
|
|
3,537 |
|
Crude terminal volumes (MBbls/d) |
|
2,765 |
|
|
|
2,358 |
|
Revenues |
$ |
5,926 |
|
|
$ |
3,500 |
|
Cost of products sold |
|
5,179 |
|
|
|
2,838 |
|
Segment margin |
|
747 |
|
|
|
662 |
|
Unrealized (gains) losses on commodity risk management activities |
|
11 |
|
|
|
(5 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(137 |
) |
|
|
(122 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(30 |
) |
|
|
(30 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
1 |
|
|
|
5 |
|
Other |
|
1 |
|
|
|
? |
|
Segment Adjusted EBITDA |
$ |
593 |
|
|
$ |
510 |
|
Crude transportation volumes were higher on our Texas pipeline system and Bakken pipeline, driven by the continued recovery in crude oil production in these regions as a result of higher crude oil prices, higher refinery demand, and Winter Storm Uri impacting crude oil production in the prior period. Additionally, volumes benefited from higher demand on our Bayou Bridge pipeline, the initiation of service on our Cushing South pipeline in 2021, and contributions from assets acquired in the Enable Acquisition. Crude terminal volumes were higher due to increased refinery and export activity at our Gulf Coast terminals.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our crude oil transportation and services segment increased due to the net impacts of the following:
Investment in Sunoco LP
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Revenues |
$ |
5,402 |
|
|
$ |
3,471 |
|
Cost of products sold |
|
4,972 |
|
|
|
3,120 |
|
Segment margin |
|
430 |
|
|
|
351 |
|
Unrealized gains on commodity risk management activities |
|
(9 |
) |
|
|
(5 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(97 |
) |
|
|
(76 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(22 |
) |
|
|
(20 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
2 |
|
|
|
2 |
|
Inventory valuation adjustments |
|
(120 |
) |
|
|
(100 |
) |
Other |
|
7 |
|
|
|
5 |
|
Segment Adjusted EBITDA |
$ |
191 |
|
|
$ |
157 |
|
The Investment in Sunoco LP segment reflects the consolidated results of Sunoco LP.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 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:
Investment in USAC
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Revenues |
$ |
163 |
|
|
$ |
158 |
|
Cost of products sold |
|
25 |
|
|
|
21 |
|
Segment margin |
|
138 |
|
|
|
137 |
|
Operating expenses, excluding non-cash compensation expense |
|
(29 |
) |
|
|
(28 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(11 |
) |
|
|
(9 |
) |
Segment Adjusted EBITDA |
$ |
98 |
|
|
$ |
100 |
|
The Investment in USAC segment reflects the consolidated results of USAC.
Segment Adjusted EBITDA. For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our investment in USAC segment decreased primarily due to an increase of $2 million in selling, general and administrative expenses primarily due to higher employee expenses and changes in the provision for credit losses.
All Other
|
Three Months Ended
|
||||||
|
2022 |
|
2021 |
||||
Revenues |
$ |
715 |
|
|
$ |
1,512 |
|
Cost of products sold |
|
614 |
|
|
|
1,342 |
|
Segment margin |
|
101 |
|
|
|
170 |
|
Unrealized (gains) losses on commodity risk management activities |
|
4 |
|
|
|
(1 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(34 |
) |
|
|
(51 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(17 |
) |
|
|
(39 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
? |
|
|
|
(1 |
) |
Other and eliminations |
|
? |
|
|
|
(6 |
) |
Segment Adjusted EBITDA |
$ |
54 |
|
|
$ |
72 |
|
For the three months ended March 31, 2022 compared to the same period last year, Segment Adjusted EBITDA related to our all other segment decreased primarily due to the net impacts of the following:
ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION ON LIQUIDITY (In millions) (unaudited)
The following table summarizes the status of our revolving credit facility. We also have consolidated subsidiaries with revolving credit facilities which are not included in this table. |
|||||||
|
Facility Size |
|
Funds Available at
|
|
Maturity Date |
||
Five-Year Revolving Credit Facility |
$ |
5,000 |
|
$ |
2,024 |
|
April 8, 2027 |
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
|
||||||
|
2022 |
|
2021 |
||||
Equity in earnings (losses) of unconsolidated affiliates: |
|
|
|
||||
Citrus |
$ |
34 |
|
|
$ |
37 |
|
MEP |
|
(4 |
) |
|
|
(3 |
) |
White Cliffs |
|
? |
|
|
|
? |
|
Other |
|
26 |
|
|
|
21 |
|
Total equity in earnings (losses) of unconsolidated affiliates |
$ |
56 |
|
|
$ |
55 |
|
|
|
|
|
||||
Adjusted EBITDA related to unconsolidated affiliates: |
|
|
|
||||
Citrus |
$ |
77 |
|
|
$ |
79 |
|
MEP |
|
5 |
|
|
|
5 |
|
White Cliffs |
|
5 |
|
|
|
5 |
|
Other |
|
38 |
|
|
|
34 |
|
Total Adjusted EBITDA related to unconsolidated affiliates |
$ |
125 |
|
|
$ |
123 |
|
|
|
|
|
||||
Distributions received from unconsolidated affiliates: |
|
|
|
||||
Citrus |
$ |
60 |
|
|
$ |
56 |
|
MEP |
|
4 |
|
|
|
4 |
|
White Cliffs |
|
5 |
|
|
|
15 |
|
Other |
|
21 |
|
|
|
25 |
|
Total distributions received from unconsolidated affiliates |
$ |
90 |
|
|
$ |
100 |
|
ENERGY TRANSFER LP AND SUBSIDIARIES SUPPLEMENTAL INFORMATION ON NON-WHOLLY-OWNED JOINT VENTURE SUBSIDIARIES (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, which are non-wholly-owned subsidiaries that are publicly traded. |
|||||
|
Three Months Ended
|
||||
|
2022 |
|
2021 |
||
Adjusted EBITDA of non-wholly-owned subsidiaries (100%) (a) |
$ |
650 |
|
$ |
540 |
Our proportionate share of Adjusted EBITDA of non-wholly-owned subsidiaries (b) |
|
317 |
|
|
275 |
|
|
|
|
||
Distributable Cash Flow of non-wholly-owned subsidiaries (100%) (c) |
$ |
609 |
|
$ |
504 |
Our proportionate share of Distributable Cash Flow of non-wholly-owned subsidiaries (d) |
|
292 |
|
|
253 |
Below is our ownership percentage of certain non-wholly-owned subsidiaries: |
|
Non-wholly-owned subsidiary: |
Energy Transfer Percentage
|
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 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. |
These press releases may also interest you
|