Energy Transfer Reports Third Quarter 2024 Results
Energy Transfer reported net income attributable to partners for the three months ended
Adjusted EBITDA for the three months ended
Distributable Cash Flow attributable to partners, as adjusted, for the three months ended
Growth capital expenditures in the third quarter of 2024 were
Operational Highlights
-
With the addition of new organic growth projects and acquisitions, volumes on Energy Transfer’s assets continued to increase during the third quarter of 2024.
- Crude oil transportation volumes were up 25%, setting a new Partnership record.
- Crude oil exports were up 49%.
- Midstream gathered volumes and produced volumes were up 6% and 26%, respectively, setting new Partnership records.
- NGL fractionation volumes were up 12%, setting a new Partnership record.
- NGL transportation volumes were up 4%, setting a new Partnership record.
-
The Partnership recently completed a 50 MMcf/d expansion to the Orla East processing plant in the
Permian Basin . -
The Partnership also recently completed construction of a 30-mile crude oil pipeline that allows Energy Transfer to transport approximately 100,000 Bbls/d of crude oil from its terminals in
Midland, Texas toCushing, Oklahoma . -
Energy Transfer recently approved construction of its ninth fractionator at
Mont Belvieu , which will have a capacity of 165,000 Bbls/d. Frac IX is expected to be in service in the fourth quarter of 2026 and will increase the Partnership’s total fractionation capacity atMont Belvieu to more than 1.3 million Bbls/d.
Strategic Highlights
-
In
July 2024 , Energy Transfer completed the acquisition ofWTG Midstream Holdings LLC (“WTG Midstream”), which added approximately 6,000 miles of complementary gas gathering pipelines and extended Energy Transfer’s network in theMidland Basin . The transaction also added nine gas processing plants with a total capacity of approximately 1.5 Bcf/d, and an additional 200 MMcf/d processing plant is currently under construction. -
In
July 2024 , Energy Transfer and formed a joint venture combining their respective crude oil and produced water gathering assets in theSunoco LP Permian Basin . Energy Transfer serves as the operator of the joint venture. -
With forecasts suggesting that natural gas fueled power demand will increase significantly in the future, Energy Transfer is seeing increasing opportunities to provide natural gas to power plants and data centers spread across its natural gas footprint, from
Arizona toFlorida and fromTexas toMichigan .
Financial Highlights
-
In
October 2024 , Energy Transfer announced a cash distribution of$0.3225 per common unit ($1.29 annualized) for the quarter endedSeptember 30, 2024 . -
As of
September 30, 2024 , the Partnership’s revolving credit facility had$3.34 billion available for future borrowings.
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 one-third of the Partnership’s consolidated Adjusted EBITDA for the three months ended
Conference call information:
The Partnership has scheduled a conference call for
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
The information contained in this press release is available on our website at www.energytransfer.com.
|
|||||||
|
2024 |
|
2023 |
||||
ASSETS |
|||||||
Current assets |
$ |
13,336 |
|
|
$ |
12,433 |
|
|
|
|
|
||||
Property, plant and equipment, net |
|
95,012 |
|
|
|
85,351 |
|
|
|
|
|
||||
Investments in unconsolidated affiliates |
|
3,268 |
|
|
|
3,097 |
|
Lease right-of-use assets, net |
|
836 |
|
|
|
826 |
|
Other non-current assets, net |
|
1,965 |
|
|
|
1,733 |
|
Intangible assets, net |
|
6,102 |
|
|
|
6,239 |
|
|
|
3,910 |
|
|
|
4,019 |
|
Total assets |
$ |
124,429 |
|
|
$ |
113,698 |
|
LIABILITIES AND EQUITY |
|||||||
Current liabilities |
$ |
12,371 |
|
|
$ |
11,277 |
|
|
|
|
|
||||
Long-term debt, less current maturities |
|
58,995 |
|
|
|
51,380 |
|
Non-current derivative liabilities |
|
— |
|
|
|
4 |
|
Non-current operating lease liabilities |
|
742 |
|
|
|
778 |
|
Deferred income taxes |
|
4,110 |
|
|
|
3,931 |
|
Other non-current liabilities |
|
1,613 |
|
|
|
1,611 |
|
|
|
|
|
||||
Commitments and contingencies |
|
|
|
||||
Redeemable noncontrolling interests |
|
418 |
|
|
|
778 |
|
|
|
|
|
||||
Equity: |
|
|
|
||||
Limited Partners: |
|
|
|
||||
Preferred Unitholders |
|
3,892 |
|
|
|
6,459 |
|
Common Unitholders |
|
31,308 |
|
|
|
30,197 |
|
|
|
(2 |
) |
|
|
(2 |
) |
Accumulated other comprehensive income |
|
42 |
|
|
|
28 |
|
Total partners’ capital |
|
35,240 |
|
|
|
36,682 |
|
Noncontrolling interests |
|
10,940 |
|
|
|
7,257 |
|
Total equity |
|
46,180 |
|
|
|
43,939 |
|
Total liabilities and equity |
$ |
124,429 |
|
|
$ |
113,698 |
|
|
|||||||||||||||
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
REVENUES |
$ |
20,772 |
|
|
$ |
20,739 |
|
|
$ |
63,130 |
|
|
$ |
58,054 |
|
COSTS AND EXPENSES: |
|
|
|
|
|
|
|
||||||||
Cost of products sold |
|
15,612 |
|
|
|
16,059 |
|
|
|
47,818 |
|
|
|
44,761 |
|
Operating expenses |
|
1,358 |
|
|
|
1,105 |
|
|
|
3,723 |
|
|
|
3,224 |
|
Depreciation, depletion and amortization |
|
1,324 |
|
|
|
1,107 |
|
|
|
3,791 |
|
|
|
3,227 |
|
Selling, general and administrative |
|
297 |
|
|
|
234 |
|
|
|
889 |
|
|
|
700 |
|
Impairment losses |
|
— |
|
|
|
1 |
|
|
|
50 |
|
|
|
12 |
|
Total costs and expenses |
|
18,591 |
|
|
|
18,506 |
|
|
|
56,271 |
|
|
|
51,924 |
|
OPERATING INCOME |
|
2,181 |
|
|
|
2,233 |
|
|
|
6,859 |
|
|
|
6,130 |
|
OTHER INCOME (EXPENSE): |
|
|
|
|
|
|
|
||||||||
Interest expense, net of interest capitalized |
|
(828 |
) |
|
|
(632 |
) |
|
|
(2,318 |
) |
|
|
(1,892 |
) |
Equity in earnings of unconsolidated affiliates |
|
102 |
|
|
|
103 |
|
|
|
285 |
|
|
|
286 |
|
Loss on extinguishment of debt |
|
— |
|
|
|
— |
|
|
|
(11 |
) |
|
|
— |
|
Gain (loss) on interest rate derivatives |
|
(6 |
) |
|
|
32 |
|
|
|
6 |
|
|
|
47 |
|
Non-operating litigation-related loss |
|
— |
|
|
|
(625 |
) |
|
|
— |
|
|
|
(625 |
) |
Gain on sale of Sunoco LP West Texas assets |
|
— |
|
|
|
— |
|
|
|
598 |
|
|
|
— |
|
Other, net |
|
74 |
|
|
|
13 |
|
|
|
104 |
|
|
|
37 |
|
INCOME BEFORE INCOME TAX EXPENSE |
|
1,523 |
|
|
|
1,124 |
|
|
|
5,523 |
|
|
|
3,983 |
|
Income tax expense |
|
89 |
|
|
|
77 |
|
|
|
405 |
|
|
|
256 |
|
NET INCOME |
|
1,434 |
|
|
|
1,047 |
|
|
|
5,118 |
|
|
|
3,727 |
|
Less: Net income attributable to noncontrolling interests |
|
238 |
|
|
|
451 |
|
|
|
1,337 |
|
|
|
1,080 |
|
Less: Net income attributable to redeemable noncontrolling interests |
|
13 |
|
|
|
12 |
|
|
|
44 |
|
|
|
39 |
|
NET INCOME ATTRIBUTABLE TO PARTNERS |
|
1,183 |
|
|
|
584 |
|
|
|
3,737 |
|
|
|
2,608 |
|
General Partner’s interest in net income |
|
1 |
|
|
|
— |
|
|
|
3 |
|
|
|
2 |
|
Preferred Unitholders’ interest in net income |
|
67 |
|
|
|
118 |
|
|
|
294 |
|
|
|
340 |
|
Loss on redemption of preferred units |
|
— |
|
|
|
— |
|
|
|
54 |
|
|
|
— |
|
Common Unitholders’ interest in net income |
$ |
1,115 |
|
|
$ |
466 |
|
|
$ |
3,386 |
|
|
$ |
2,266 |
|
NET INCOME PER COMMON UNIT: |
|
|
|
|
|
|
|
||||||||
Basic |
$ |
0.33 |
|
|
$ |
0.15 |
|
|
$ |
1.00 |
|
|
$ |
0.73 |
|
Diluted |
$ |
0.32 |
|
|
$ |
0.15 |
|
|
$ |
0.99 |
|
|
$ |
0.72 |
|
WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING: |
|
|
|
|
|
|
|
||||||||
Basic |
|
3,415.2 |
|
|
|
3,144.0 |
|
|
|
3,384.9 |
|
|
|
3,122.3 |
|
Diluted |
|
3,441.2 |
|
|
|
3,167.7 |
|
|
|
3,410.7 |
|
|
|
3,145.9 |
|
|
|||||||||||||||
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
|
2024 |
|
|
|
2023 |
|
|
|
2024 |
|
|
|
2023 |
|
Reconciliation of net income to Adjusted EBITDA and Distributable Cash Flow(a): |
|
|
|
|
|
|
|
||||||||
Net income |
$ |
1,434 |
|
|
$ |
1,047 |
|
|
$ |
5,118 |
|
|
$ |
3,727 |
|
Interest expense, net of interest capitalized |
|
828 |
|
|
|
632 |
|
|
|
2,318 |
|
|
|
1,892 |
|
Impairment losses |
|
— |
|
|
|
1 |
|
|
|
50 |
|
|
|
12 |
|
Income tax expense |
|
89 |
|
|
|
77 |
|
|
|
405 |
|
|
|
256 |
|
Depreciation, depletion and amortization |
|
1,324 |
|
|
|
1,107 |
|
|
|
3,791 |
|
|
|
3,227 |
|
Non-cash compensation expense |
|
37 |
|
|
|
35 |
|
|
|
113 |
|
|
|
99 |
|
(Gain) loss on interest rate derivatives |
|
6 |
|
|
|
(32 |
) |
|
|
(6 |
) |
|
|
(47 |
) |
Unrealized (gain) loss on commodity risk management activities |
|
(53 |
) |
|
|
107 |
|
|
|
50 |
|
|
|
182 |
|
Loss on extinguishment of debt |
|
— |
|
|
|
— |
|
|
|
11 |
|
|
|
— |
|
Inventory valuation adjustments ( |
|
197 |
|
|
|
(141 |
) |
|
|
99 |
|
|
|
(113 |
) |
Equity in earnings of unconsolidated affiliates |
|
(102 |
) |
|
|
(103 |
) |
|
|
(285 |
) |
|
|
(286 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
181 |
|
|
|
182 |
|
|
|
522 |
|
|
|
514 |
|
Non-operating litigation-related loss(b) |
|
— |
|
|
|
625 |
|
|
|
— |
|
|
|
625 |
|
Gain on sale of Sunoco LP West Texas assets |
|
— |
|
|
|
— |
|
|
|
(598 |
) |
|
|
— |
|
Other, net |
|
18 |
|
|
|
4 |
|
|
|
11 |
|
|
|
8 |
|
Adjusted EBITDA (consolidated) |
|
3,959 |
|
|
|
3,541 |
|
|
|
11,599 |
|
|
|
10,096 |
|
Adjusted EBITDA related to unconsolidated affiliates(c) |
|
(181 |
) |
|
|
(182 |
) |
|
|
(522 |
) |
|
|
(514 |
) |
Distributable cash flow from unconsolidated affiliates(c) |
|
127 |
|
|
|
131 |
|
|
|
373 |
|
|
|
364 |
|
Interest expense, net of interest capitalized |
|
(828 |
) |
|
|
(632 |
) |
|
|
(2,318 |
) |
|
|
(1,892 |
) |
Preferred unitholders’ distributions |
|
(72 |
) |
|
|
(129 |
) |
|
|
(290 |
) |
|
|
(376 |
) |
Current income tax expense |
|
20 |
|
|
|
(25 |
) |
|
|
(241 |
) |
|
|
(69 |
) |
Transaction-related income taxes(d) |
|
(18 |
) |
|
|
— |
|
|
|
181 |
|
|
|
— |
|
Maintenance capital expenditures |
|
(392 |
) |
|
|
(202 |
) |
|
|
(785 |
) |
|
|
(601 |
) |
Other, net |
|
16 |
|
|
|
11 |
|
|
|
72 |
|
|
|
21 |
|
Distributable Cash Flow (consolidated) |
|
2,631 |
|
|
|
2,513 |
|
|
|
8,069 |
|
|
|
7,029 |
|
Distributable Cash Flow attributable to |
|
(290 |
) |
|
|
(181 |
) |
|
|
(647 |
) |
|
|
(514 |
) |
Distributions from |
|
60 |
|
|
|
43 |
|
|
|
182 |
|
|
|
130 |
|
Distributable Cash Flow attributable to USAC (100%) |
|
(87 |
) |
|
|
(71 |
) |
|
|
(259 |
) |
|
|
(201 |
) |
Distributions from USAC |
|
25 |
|
|
|
25 |
|
|
|
73 |
|
|
|
73 |
|
Distributable Cash Flow attributable to noncontrolling interests in other non-wholly owned consolidated subsidiaries |
|
(364 |
) |
|
|
(345 |
) |
|
|
(1,052 |
) |
|
|
(983 |
) |
Distributable Cash Flow attributable to the partners of Energy Transfer |
|
1,975 |
|
|
|
1,984 |
|
|
|
6,366 |
|
|
|
5,534 |
|
Transaction-related adjustments |
|
15 |
|
|
|
2 |
|
|
|
19 |
|
|
|
14 |
|
Distributable Cash Flow attributable to the partners of Energy Transfer, as adjusted |
$ |
1,990 |
|
|
$ |
1,986 |
|
|
$ |
6,385 |
|
|
$ |
5,548 |
|
Distributions to partners: |
|
|
|
|
|
|
|
||||||||
Limited Partners |
$ |
1,104 |
|
|
$ |
983 |
|
|
$ |
3,269 |
|
|
$ |
2,923 |
|
|
|
1 |
|
|
|
1 |
|
|
|
3 |
|
|
|
3 |
|
Total distributions to be paid to partners |
$ |
1,105 |
|
|
$ |
984 |
|
|
$ |
3,272 |
|
|
$ |
2,926 |
|
Common Units outstanding – end of period |
|
3,423.7 |
|
|
|
3,145.1 |
|
|
|
3,423.7 |
|
|
|
3,145.1 |
|
(a) |
Adjusted EBITDA and Distributable Cash Flow 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 and Distributable Cash Flow, including the difficulty associated with using either 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 and Distributable Cash Flow may not be consistent with similarly titled measures of other companies and should be viewed in conjunction with measures that are computed in accordance with GAAP, such as operating income, net income and cash flows 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 valuation 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 investees’ 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. |
|
(b) |
Non-operating litigation-related loss recognized in the three and nine months ended |
(c) |
These amounts exclude Sunoco LP’s Adjusted EBITDA and distributable cash flow related to its investment in the Permian joint venture, which amounts are eliminated in the Energy Transfer consolidation. |
(d) |
For the three and nine months ended |
|
|||||||
|
Three Months Ended
|
||||||
|
2024 |
|
2023 |
||||
Segment Adjusted EBITDA: |
|
|
|
||||
Intrastate transportation and storage |
$ |
329 |
|
|
$ |
244 |
|
Interstate transportation and storage |
|
460 |
|
|
|
491 |
|
Midstream |
|
816 |
|
|
|
631 |
|
NGL and refined products transportation and services |
|
1,012 |
|
|
|
1,076 |
|
Crude oil transportation and services |
|
768 |
|
|
|
706 |
|
Investment in |
|
456 |
|
|
|
257 |
|
Investment in USAC |
|
146 |
|
|
|
130 |
|
All other |
|
(28 |
) |
|
|
6 |
|
Adjusted EBITDA (consolidated) |
$ |
3,959 |
|
|
$ |
3,541 |
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. |
Intrastate Transportation and Storage |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Natural gas transported (BBtu/d) |
|
13,214 |
|
|
|
15,123 |
|
Withdrawals from storage natural gas inventory (BBtu) |
|
2,325 |
|
|
|
— |
|
Revenues |
$ |
678 |
|
|
$ |
973 |
|
Cost of products sold |
|
272 |
|
|
|
664 |
|
Segment margin |
|
406 |
|
|
|
309 |
|
Unrealized (gains) losses on commodity risk management activities |
|
(11 |
) |
|
|
14 |
|
Operating expenses, excluding non-cash compensation expense |
|
(61 |
) |
|
|
(71 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(11 |
) |
|
|
(13 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
6 |
|
|
|
6 |
|
Other |
|
— |
|
|
|
(1 |
) |
Segment Adjusted EBITDA |
$ |
329 |
|
|
$ |
244 |
|
Transported volumes of gas on our |
Segment Adjusted EBITDA. For the three months ended |
|
Interstate Transportation and Storage |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Natural gas transported (BBtu/d) |
|
16,616 |
|
|
|
16,237 |
|
Natural gas sold (BBtu/d) |
|
39 |
|
|
|
40 |
|
Revenues |
$ |
575 |
|
|
$ |
571 |
|
Cost of products sold |
|
3 |
|
|
|
2 |
|
Segment margin |
|
572 |
|
|
|
569 |
|
Operating expenses, excluding non-cash compensation, amortization, accretion and other non-cash expenses |
|
(203 |
) |
|
|
(178 |
) |
Selling, general and administrative expenses, excluding non-cash compensation, amortization and accretion expenses |
|
(34 |
) |
|
|
(30 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
125 |
|
|
|
129 |
|
Other |
|
— |
|
|
|
1 |
|
Segment Adjusted EBITDA |
$ |
460 |
|
|
$ |
491 |
|
Transported volumes increased primarily due to more capacity sold and higher utilization on our |
Segment Adjusted EBITDA. For the three months ended |
|
Midstream |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Gathered volumes (BBtu/d) |
|
21,027 |
|
|
|
19,825 |
|
NGLs produced (MBbls/d) |
|
1,094 |
|
|
|
869 |
|
Equity NGLs (MBbls/d) |
|
65 |
|
|
|
42 |
|
Revenues |
$ |
2,758 |
|
|
$ |
2,777 |
|
Cost of products sold |
|
1,551 |
|
|
|
1,808 |
|
Segment margin |
|
1,207 |
|
|
|
969 |
|
Operating expenses, excluding non-cash compensation expense |
|
(411 |
) |
|
|
(294 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(57 |
) |
|
|
(50 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
6 |
|
|
|
5 |
|
Other |
|
71 |
|
|
|
1 |
|
Segment Adjusted EBITDA |
$ |
816 |
|
|
$ |
631 |
|
Gathered volumes increased primarily due to recently acquired assets and higher volumes in the Permian region. NGL production increased primarily due to recently acquired assets and increased Permian plant utilization. |
Segment Adjusted EBITDA. For the three months ended |
|
NGL and Refined Products Transportation and Services |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
NGL transportation volumes (MBbls/d) |
|
2,237 |
|
|
|
2,161 |
|
Refined products transportation volumes (MBbls/d) |
|
574 |
|
|
|
551 |
|
NGL and refined products terminal volumes (MBbls/d) |
|
1,505 |
|
|
|
1,475 |
|
NGL fractionation volumes (MBbls/d) |
|
1,152 |
|
|
|
1,029 |
|
Revenues |
$ |
5,853 |
|
|
$ |
5,260 |
|
Cost of products sold |
|
4,527 |
|
|
|
4,034 |
|
Segment margin |
|
1,326 |
|
|
|
1,226 |
|
Unrealized (gains) losses on commodity risk management activities |
|
(64 |
) |
|
|
84 |
|
Operating expenses, excluding non-cash compensation expense |
|
(243 |
) |
|
|
(235 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(42 |
) |
|
|
(33 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
35 |
|
|
|
34 |
|
Segment Adjusted EBITDA |
$ |
1,012 |
|
|
$ |
1,076 |
|
NGL transportation volumes increased primarily due to higher volumes from the Permian region, on our |
The increase in transportation volumes and the commissioning of our eighth fractionator in |
Segment Adjusted EBITDA. For the three months ended |
|
Crude Oil Transportation and Services |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Crude oil transportation volumes (MBbls/d) |
|
7,025 |
|
|
|
5,640 |
|
Crude oil terminal volumes (MBbls/d) |
|
3,533 |
|
|
|
3,548 |
|
Revenues |
$ |
7,309 |
|
|
$ |
7,289 |
|
Cost of products sold |
|
6,297 |
|
|
|
6,392 |
|
Segment margin |
|
1,012 |
|
|
|
897 |
|
Unrealized losses on commodity risk management activities |
|
20 |
|
|
|
14 |
|
Operating expenses, excluding non-cash compensation expense |
|
(231 |
) |
|
|
(183 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(39 |
) |
|
|
(29 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
6 |
|
|
|
6 |
|
Other |
|
— |
|
|
|
1 |
|
Segment Adjusted EBITDA |
$ |
768 |
|
|
$ |
706 |
|
Crude oil transportation volumes were higher due to continued growth on our gathering systems and contributions from recently acquired assets. Crude terminal volumes were lower due to lower refinery-driven throughput at our |
Segment Adjusted EBITDA. For the three months ended |
|
Investment in |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Revenues |
$ |
5,751 |
|
|
$ |
6,320 |
|
Cost of products sold |
|
5,327 |
|
|
|
5,793 |
|
Segment margin |
|
424 |
|
|
|
527 |
|
Unrealized (gains) losses on commodity risk management activities |
|
1 |
|
|
|
(1 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(168 |
) |
|
|
(110 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(52 |
) |
|
|
(28 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
47 |
|
|
|
2 |
|
Inventory fair value adjustments |
|
197 |
|
|
|
(141 |
) |
Other, net |
|
7 |
|
|
|
8 |
|
Segment Adjusted EBITDA |
$ |
456 |
|
|
$ |
257 |
|
The Investment in |
Segment Adjusted EBITDA. For the three months ended |
|
Investment in USAC |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Revenues |
$ |
240 |
|
|
$ |
217 |
|
Cost of products sold |
|
38 |
|
|
|
35 |
|
Segment margin |
|
202 |
|
|
|
182 |
|
Operating expenses, excluding non-cash compensation expense |
|
(43 |
) |
|
|
(39 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(13 |
) |
|
|
(13 |
) |
Segment Adjusted EBITDA |
$ |
146 |
|
|
$ |
130 |
|
The Investment in USAC segment reflects the consolidated results of USAC. |
Segment Adjusted EBITDA. For the three months ended |
|
All Other |
|||||||
|
Three Months Ended
|
||||||
|
|
2024 |
|
|
|
2023 |
|
Revenues |
$ |
379 |
|
|
$ |
444 |
|
Cost of products sold |
|
369 |
|
|
|
457 |
|
Segment margin |
|
10 |
|
|
|
(13 |
) |
Unrealized (gains) losses on commodity risk management activities |
|
1 |
|
|
|
(4 |
) |
Operating expenses, excluding non-cash compensation expense |
|
(20 |
) |
|
|
(8 |
) |
Selling, general and administrative expenses, excluding non-cash compensation expense |
|
(23 |
) |
|
|
(13 |
) |
Adjusted EBITDA related to unconsolidated affiliates |
|
2 |
|
|
|
2 |
|
Other and eliminations |
|
2 |
|
|
|
42 |
|
Segment Adjusted EBITDA |
$ |
(28 |
) |
|
$ |
6 |
|
Segment Adjusted EBITDA. For the three months ended |
|
|
|||||
The table below provides information on 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 |
|
|
|
|
|
|
|||||
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
|
||||
|
2024 |
|
2023 |
||
Equity in earnings of unconsolidated affiliates: |
|
|
|
||
Citrus |
$ |
41 |
|
$ |
39 |
MEP |
|
16 |
|
|
21 |
White Cliffs |
|
4 |
|
|
2 |
Explorer |
|
11 |
|
|
10 |
SESH |
|
12 |
|
|
8 |
Other |
|
18 |
|
|
23 |
Total equity in earnings of unconsolidated affiliates |
$ |
102 |
|
$ |
103 |
|
|
|
|
||
Adjusted EBITDA related to unconsolidated affiliates: |
|
|
|
||
Citrus |
$ |
89 |
|
$ |
86 |
MEP |
|
25 |
|
|
30 |
White Cliffs |
|
9 |
|
|
7 |
Explorer |
|
17 |
|
|
16 |
SESH |
|
13 |
|
|
12 |
Other |
|
28 |
|
|
31 |
Total Adjusted EBITDA related to unconsolidated affiliates |
$ |
181 |
|
$ |
182 |
|
|
|
|
||
Distributions received from unconsolidated affiliates: |
|
|
|
||
Citrus |
$ |
— |
|
$ |
53 |
MEP |
|
16 |
|
|
25 |
White Cliffs |
|
9 |
|
|
7 |
Explorer |
|
11 |
|
|
10 |
SESH |
|
15 |
|
|
8 |
Other |
|
20 |
|
|
19 |
Total distributions received from unconsolidated affiliates |
$ |
71 |
|
$ |
122 |
|
|||||
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 |
|||||
|
Three Months Ended
|
||||
|
2024 |
|
2023 |
||
Adjusted EBITDA of non-wholly owned subsidiaries (100%) (a) |
$ |
764 |
|
$ |
679 |
Our proportionate share of Adjusted EBITDA of non-wholly owned subsidiaries (b) |
|
400 |
|
|
326 |
|
|
|
|
||
Distributable Cash Flow of non-wholly owned subsidiaries (100%) (c) |
$ |
745 |
|
$ |
653 |
Our proportionate share of Distributable Cash Flow of non-wholly owned subsidiaries (d) |
|
381 |
|
|
308 |
Below is our ownership percentage of certain non-wholly owned subsidiaries: |
|
Non-wholly owned subsidiary: |
Energy Transfer Percentage Ownership (e) |
Bakken Pipeline |
36.4 % |
|
60.0 % |
|
51.0 % |
Ohio River System |
75.0 % |
|
87.7 % |
Red Bluff Express |
70.0 % |
Rover |
32.6 % |
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 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 included in our consolidated non-GAAP measure of Distributable Cash Flow attributable to the partners of Energy Transfer. |
(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. |
View source version on businesswire.com: https://www.businesswire.com/news/home/20241106197626/en/
Energy Transfer
Investor Relations:
or
Media Relations:
Source: