Enable Midstream Announces Third Quarter 2020 Financial and Operating Results
Enable Midstream Partners reported a net loss of $164 million for Q3 2020, a significant decline from the $132 million net income in Q3 2019. This loss mainly stemmed from a $225 million non-cash impairment on investments. Net cash from operations decreased by $32 million, with Adjusted EBITDA down to $229 million. The partnership declared a quarterly cash distribution of $0.16525 per unit, maintaining consistency from previous quarters. Despite challenges, the firm has contracted nearly 1.45 million Dth/d of firm transportation capacity with a strong distribution coverage ratio of 2.04x.
- Distribution coverage ratio of 2.04x, indicating strong cash flow relative to distributions.
- Nearly 1.45 million Dth/d of firm transportation capacity contracted, ensuring stable cash flow.
- Maintained quarterly cash distribution of $0.16525 per unit, consistent with previous quarters.
- Net loss of $164 million for Q3 2020, a decrease of $296 million from a profit in Q3 2019.
- Adjusted EBITDA decreased by $66 million compared to Q3 2019, indicating operational challenges.
- Natural gas gathered volumes decreased by 9% and processed volumes by 17% compared to Q3 2019.
OKLAHOMA CITY--(BUSINESS WIRE)--Enable Midstream Partners, LP (NYSE: ENBL) today announced financial and operating results for third quarter 2020.
Net loss attributable to limited partners was
For third quarter 2020, DCF exceeded declared distributions to common unitholders by
For additional information regarding the non-GAAP financial measures Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio, please see “Non-GAAP Financial Measures.”
MANAGEMENT PERSPECTIVE
“We continue to focus on what we can control, optimizing our capital deployment, providing safe and reliable operations and implementing cost reductions while directing excess cash flow to reducing debt,” said Rod Sailor, president and CEO. “I am very proud of our employees for providing a high level of service during these challenging times.
“In addition, we continue to deliver on other important initiatives such as our recently released inaugural sustainability report. Sustainable business practices are deeply embedded across our business, and this report provides our stakeholders with a transparent view of our progress and initiatives.”
BUSINESS HIGHLIGHTS
Enable’s inaugural sustainability report marks an important step in the partnership’s sustainability journey. The report focuses on environmental, social and governance issues and is aligned with the voluntary Sustainability Accounting Standards Board (SASB) reporting standards for midstream companies, allowing for better comparisons of Enable’s sustainability performance. The report is available on the partnership’s website at https://enablemidstream.com/sustainability.
As of Sept. 1, 2020, all wells that were shut-in due to depressed commodity prices have been brought back online, and Enable has not experienced any noticeable production performance degradation from these wells. As of Oct. 28, 2020, there were six rigs across Enable’s footprint that were drilling wells expected to be connected to Enable’s gathering systems. Three of those rigs were in the Anadarko Basin, and three were in the Ark-La-Tex Basin.
Enable remains focused on contracting firm, fee-based transportation capacity. Through Sept. 30, 2020, Enable has contracted nearly 1,450,000 Dth/d of firm transportation capacity at an average volume-weighted contract life of over five years. During third quarter 2020, Enable contracted or extended approximately 190,000 Dth/d of firm transportation capacity.
On Oct. 29, 2020, FERC issued an Environmental Assessment for the Gulf Run Pipeline project. The deadline for other federal agencies to provide authorization for the project is Jan. 27, 2021. Backed by a 20-year commitment for 1.1 billion cubic feet per day (Bcf/d) from cornerstone shipper Golden Pass LNG, the project is proceeding on schedule and is expected to be placed into service in late 2022, subject to FERC approval. While the currently filed project scope provides for capacity in excess of Golden Pass’s firm commitment, Enable continues to review the scope in light of current contracting levels, commercial dialogue and construction costs.
Underpinned by a firm, five-year commitment, Enable Gas Transmission, LLC’s MASS project is designed to deliver gas from the Anadarko and Arkoma Basins to delivery points with access to emerging Gulf Coast markets and growing demand markets in the Southeast. Project construction recently began following the receipt of all regulatory approvals, and the project is expected to be placed into service during second quarter 2021.
QUARTERLY DISTRIBUTIONS
On Nov. 3, 2020, the board of directors of Enable’s general partner declared a quarterly cash distribution of
The board declared a quarterly cash distribution of
KEY OPERATING STATISTICS
Natural gas gathered volumes were 4.07 trillion British thermal units per day (TBtu/d) for third quarter 2020, a decrease of
Natural gas processed volumes were 2.06 TBtu/d for third quarter 2020, a decrease of
Crude oil and condensate gathered volumes were 138.02 thousand barrels per day (MBbl/d) for third quarter 2020, an increase of
Transported natural gas volumes were 4.78 TBtu/d for third quarter 2020, a decrease of
Interstate transportation firm contracted capacity was 5.73 Bcf/d for third quarter 2020, a decrease of
Intrastate transportation average deliveries were 1.74 TBtu/d for third quarter 2020, a decrease of
THIRD QUARTER FINANCIAL PERFORMANCE
Revenues were
Gathering and processing segment revenues were
- a decrease in natural gas gathering revenues due to lower gathered volumes, inclusive of continued producer shut-ins in the Anadarko Basin that ended during the third quarter, lower shortfall fees associated with the expiration of certain minimum volume commitment contracts in the Ark-La-Tex Basin and lower revenue associated with the third quarter 2019 amendment of certain minimum volume commitment contracts in the Arkoma Basin,
- a decrease in changes in the fair value of natural gas, condensate and NGL derivatives,
- a decrease in revenues from natural gas sales due to lower sales volumes, partially offset by higher average sales prices,
- a decrease in processing service revenues due to lower processed volumes under fee-based arrangements, partially offset by higher consideration received from percent-of-proceeds, percent-of-liquids and keep-whole processing arrangements due to an increase in retained volumes at higher average market prices as well as an increase in the recognition of certain annual minimum processing fees,
- a decrease in realized gains on natural gas, condensate and NGL derivatives and
- a decrease in intercompany management fees.
These decreases were partially offset by:
- an increase in revenues from natural gas liquids (NGL) sales primarily due to an increase in the average realized sales price from higher average market prices for all NGL products other than natural gasoline and higher recoveries of ethane in the Anadarko Basin, partially offset by lower sales in the Arkoma and Ark-La-Tex Basin primarily due to lower processed volumes and
- an increase in crude oil, condensate and produced water gathering revenues primarily due to an increase in gathered crude oil volumes in the Anadarko Basin, partially offset by a decrease in gathered crude oil volumes in the Williston Basin.
Transportation and storage segment revenues were
- a decrease in revenues from natural gas sales primarily due to lower sales volumes, partially offset by higher average sales prices,
- a decrease in volume-dependent transportation and storage revenues due to lower off-system intrastate transportation rates and lower transported volumes due to decreased production activity in the Anadarko Basin,
- a decrease in revenues from NGL sales due to lower average sales prices and lower volumes and
- a decrease in firm transportation and storage services due to lower interstate contracted capacity, partially offset by higher recognized rates subsequent to the settlement of the MRT rate case.
These decreases were partially offset by realized gains on natural gas derivatives.
Gross margin was
Gathering and processing segment gross margin was
- a decrease in natural gas gathering fees due to lower gathered volumes, inclusive of continued producer shut-ins in the Anadarko Basin that ended during the third quarter, lower shortfall fees associated with the expiration of certain minimum volume commitment contracts in the Ark-La-Tex Basin and lower revenue associated with the third quarter 2019 amendment of certain minimum volume commitment contracts in the Arkoma Basin,
- a decrease in revenues from natural gas sales due to lower sales volumes, partially offset by higher average sales prices,
- a decrease in changes in the fair value of natural gas, condensate and NGL derivatives,
- a decrease in realized gains on natural gas, condensate and NGL derivatives and
- a decrease in processing service revenues.
These decreases were partially offset by:
- an increase in revenues from NGL sales due to higher average sales prices for all NGL products other than natural gasoline and
- an increase in crude oil, condensate and produced water gathering revenues primarily due to an increase in gathered crude oil volumes in the Anadarko Basin, partially offset by a decrease in gathered crude oil volumes in the Williston Basin.
Transportation and storage segment gross margin was
- a decrease in volume-dependent transportation and storage revenues due to lower off-system intrastate transportation rates and lower transported volumes due to decreased production activity in the Anadarko Basin,
- a decrease in firm transportation and storage services due to lower interstate contracted capacity, partially offset by higher recognized rates subsequent to the settlement of the MRT rate case and
- a decrease due to incremental lower of cost or net realizable value adjustments related to natural gas storage inventories.
These decreases were partially offset by an increase in system management activities and an increase in realized gains on natural gas derivatives.
Operation and maintenance and general and administrative expenses were
Depreciation and amortization expense was
Interest expense was
Capital expenditures were
2020 OUTLOOK
As compared to the 2020 outlook presented in its first quarter 2020 financial results press release dated May 6, 2020, Enable anticipates performing below the projected range for net income attributable to common units due to the non-cash impairment of equity method affiliates in third quarter 2020 and in the upper half of the projected ranges for Adjusted EBITDA and DCF. Excluding the third quarter 2020 non-cash impairment of equity method affiliates, Enable would have anticipated performing in the upper half of the first quarter’s anticipated range for net income attributable to common units.
EARNINGS CONFERENCE CALL AND WEBCAST
A conference call discussing third quarter results is scheduled today at 10 a.m. EST (9 a.m. CST). The toll-free dial-in number to access the conference call is 833-968-1938, and the international dial-in number is 778-560-2726. The conference call ID is 8109667. Investors may also listen to the call via Enable’s website at https://investors.enablemidstream.com. Replays of the conference call will be available on Enable’s website.
AVAILABLE INFORMATION
Enable files annual, quarterly and other reports and other information with the U.S. Securities and Exchange Commission (SEC). Enable’s SEC filings are also available at the SEC’s website at https://www.sec.gov which contains information regarding issuers that file electronically with the SEC. Information about Enable may also be obtained at the offices of the NYSE, 20 Broad Street, New York, New York 10005, or on Enable’s website at https://enablemidstream.com. On the Investor Relations section of Enable’s website, https://investors.enablemidstream.com, Enable makes available free of charge a variety of information to investors. Enable’s goal is to maintain the Investor Relations section of its website as a portal through which investors can easily find or navigate to pertinent information about Enable, including but not limited to:
- Enable’s annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K and any amendments to those reports as soon as reasonably practicable after Enable electronically files that material with or furnishes it to the SEC;
- press releases on quarterly distributions, quarterly earnings and other developments;
- governance information, including Enable’s governance guidelines, committee charters and code of ethics and business conduct;
- information on events and presentations, including an archive of available calls, webcasts and presentations;
- news and other announcements that Enable may post from time to time that investors may find useful or interesting; and
- opportunities to sign up for email alerts and RSS feeds to have information pushed in real time.
ABOUT ENABLE MIDSTREAM PARTNERS
Enable owns, operates and develops strategically located natural gas and crude oil infrastructure assets. Enable’s assets include approximately 14,000 miles of natural gas, crude oil, condensate and produced water gathering pipelines, approximately 2.6 Bcf/d of natural gas processing capacity, approximately 7,800 miles of interstate pipelines (including Southeast Supply Header, LLC of which Enable owns
This release is intended to be a qualified notice under Treasury Regulation Section 1.1446-4(b). Brokers and nominees should treat one hundred percent (
NON-GAAP FINANCIAL MEASURES
Enable has included the non-GAAP financial measures Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio in this press release based on information in its consolidated financial statements.
Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio are supplemental financial measures that management and external users of Enable’s financial statements, such as industry analysts, investors, lenders and rating agencies may use, to assess:
- Enable’s operating performance as compared to those of other publicly traded partnerships in the midstream energy industry, without regard to capital structure or historical cost basis;
- The ability of Enable’s assets to generate sufficient cash flow to make distributions to its partners;
- Enable’s ability to incur and service debt and fund capital expenditures; and
- The viability of acquisitions and other capital expenditure projects and the returns on investment of various investment opportunities.
This press release includes a reconciliation of Gross margin to total revenues, Adjusted EBITDA and DCF to net income attributable to limited partners, Adjusted EBITDA to net cash provided by operating activities and Adjusted interest expense to interest expense, the most directly comparable GAAP financial measures as applicable, for each of the periods indicated. Distribution coverage ratio is a financial performance measure used by management to reflect the relationship between Enable’s financial operating performance and cash distributions. Enable believes that the presentation of Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio provides information useful to investors in assessing its financial condition and results of operations. Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio should not be considered as alternatives to net income, operating income, total revenue, cash flow from operating activities or any other measure of financial performance or liquidity presented in accordance with GAAP. Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio have important limitations as analytical tools because they exclude some but not all items that affect the most directly comparable GAAP measures. Additionally, because Gross margin, Adjusted EBITDA, DCF, Adjusted interest expense and distribution coverage ratio may be defined differently by other companies in Enable’s industry, its definitions of these measures may not be comparable to similarly titled measures of other companies, thereby diminishing their utility.
FORWARD-LOOKING STATEMENTS
Some of the information in this press release may contain forward-looking statements. Forward-looking statements give our current expectations and contain projections of results of operations or of financial condition, or forecasts of future events. Words such as “could,” “will,” “should,” “may,” “assume,” “forecast,” “position,” “predict,” “strategy,” “expect,” “intend,” “plan,” “estimate,” “anticipate,” “believe,” “project,” “budget,” “potential,” or “continue,” and similar expressions are used to identify forward-looking statements. Without limiting the generality of the foregoing, forward-looking statements contained in this press release include our expectations of plans, strategies, objectives, growth and anticipated financial and operational performance, including our 2020 outlook presented in our first quarter 2020 financial results press release dated May 6, 2020, as updated by this press release. In particular, our statements with respect to continuity plans and preparedness measures we have implemented in response to the novel coronavirus (COVID-19) pandemic and its expected impact on our business, operations, earnings and results are forward-looking statements. Forward-looking statements can be affected by assumptions used or by known or unknown risks or uncertainties. Consequently, no forward-looking statements can be guaranteed.
A forward-looking statement may include a statement of the assumptions or bases underlying the forward-looking statement. We believe that we have chosen these assumptions or bases in good faith and that they are reasonable. However, when considering these forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this press release, our Quarterly Report on Form 10-Q for the three months ended March 31, 2020 (March 31 Quarterly Report), and our Annual Report on Form 10-K for the year ended Dec. 31, 2019 (Annual Report). Those risk factors and other factors noted throughout this press release and in our March 31 Quarterly Report and Annual Report could cause our actual results to differ materially from those disclosed in any forward-looking statement. You are cautioned not to place undue reliance on any forward-looking statements.
Any forward-looking statements speak only as of the date on which such statement is made, and we undertake no obligation to correct or update any forward-looking statement, whether as a result of new information or otherwise, except as required by applicable law.
ENABLE MIDSTREAM PARTNERS, LP CONSOLIDATED STATEMENTS OF INCOME (Unaudited) |
|||||||||||||||||||
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||||||||||
|
|
|
|
|
|
|
|
||||||||||||
|
(In millions, except per unit data) |
||||||||||||||||||
Revenues (including revenues from affiliates): |
|
|
|
|
|
|
|
||||||||||||
Product sales |
$ |
280 |
|
|
|
$ |
320 |
|
|
|
$ |
764 |
|
|
|
$ |
1,156 |
|
|
Service revenue |
316 |
|
|
|
379 |
|
|
|
995 |
|
|
|
1,073 |
|
|
||||
Total Revenues |
596 |
|
|
|
699 |
|
|
|
1,759 |
|
|
|
2,229 |
|
|
||||
Cost and Expenses (including expenses from affiliates): |
|
|
|
|
|
|
|
||||||||||||
Cost of natural gas and natural gas liquids (excluding depreciation and amortization shown separately) |
250 |
|
|
|
263 |
|
|
|
653 |
|
|
|
958 |
|
|
||||
Operation and maintenance |
96 |
|
|
|
105 |
|
|
|
313 |
|
|
|
307 |
|
|
||||
General and administrative |
28 |
|
|
|
31 |
|
|
|
73 |
|
|
|
82 |
|
|
||||
Depreciation and amortization |
105 |
|
|
|
108 |
|
|
|
314 |
|
|
|
323 |
|
|
||||
Impairments of property, plant and equipment and goodwill |
— |
|
|
|
— |
|
|
|
28 |
|
|
|
— |
|
|
||||
Taxes other than income tax |
17 |
|
|
|
17 |
|
|
|
52 |
|
|
|
52 |
|
|
||||
Total Cost and Expenses |
496 |
|
|
|
524 |
|
|
|
1,433 |
|
|
|
1,722 |
|
|
||||
Operating Income |
100 |
|
|
|
175 |
|
|
|
326 |
|
|
|
507 |
|
|
||||
Other Income (Expense): |
|
|
|
|
|
|
|
||||||||||||
Interest expense |
(43 |
) |
|
|
(48 |
) |
|
|
(136 |
) |
|
|
(142 |
) |
|
||||
Equity in earnings (loss) of equity method affiliate, net |
(222 |
) |
|
|
5 |
|
|
|
(211 |
) |
|
|
12 |
|
|
||||
Other, net |
2 |
|
|
|
1 |
|
|
|
7 |
|
|
|
2 |
|
|
||||
Total Other Expense |
(263 |
) |
|
|
(42 |
) |
|
|
(340 |
) |
|
|
(128 |
) |
|
||||
Income Before Income Tax |
(163 |
) |
|
|
133 |
|
|
|
(14 |
) |
|
|
379 |
|
|
||||
Income tax benefit |
— |
|
|
|
— |
|
|
|
— |
|
|
|
(1 |
) |
|
||||
Net Income (Loss) |
$ |
(163 |
) |
|
|
$ |
133 |
|
|
|
$ |
(14 |
) |
|
|
$ |
380 |
|
|
Less: Net income (loss) attributable to noncontrolling interest |
1 |
|
|
|
1 |
|
|
|
(6 |
) |
|
|
2 |
|
|
||||
Net Income (Loss) Attributable to Limited Partners |
$ |
(164 |
) |
|
|
$ |
132 |
|
|
|
$ |
(8 |
) |
|
|
$ |
378 |
|
|
Less: Series A Preferred Unit distributions |
9 |
|
|
|
9 |
|
|
|
27 |
|
|
|
27 |
|
|
||||
Net Income (Loss) Attributable to Common Units |
$ |
(173 |
) |
|
|
$ |
123 |
|
|
|
$ |
(35 |
) |
|
|
$ |
351 |
|
|
|
|
|
|
|
|
|
|
||||||||||||
Basic earnings (loss) per unit |
|
|
|
|
|
|
|
||||||||||||
Common units |
$ |
(0.40 |
) |
|
|
$ |
0.28 |
|
|
|
$ |
(0.08 |
) |
|
|
$ |
0.81 |
|
|
Diluted earnings (loss) per unit |
|
|
|
|
|
|
|
||||||||||||
Common units |
$ |
(0.40 |
) |
|
|
$ |
0.28 |
|
|
|
$ |
(0.08 |
) |
|
|
$ |
0.81 |
|
|
ENABLE MIDSTREAM PARTNERS, LP RECONCILIATION OF NON-GAAP FINANCIAL MEASURES |
|||||||||||||||
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||||||
|
|
|
|
|
|
|
|
||||||||
|
(In millions) |
||||||||||||||
Reconciliation of Gross margin to Total Revenues: |
|
|
|
|
|
|
|
||||||||
Consolidated |
|
|
|
|
|
|
|
||||||||
Product sales |
$ |
280 |
|
|
$ |
320 |
|
|
$ |
764 |
|
|
$ |
1,156 |
|
Service revenue |
316 |
|
|
379 |
|
|
995 |
|
|
1,073 |
|
||||
Total Revenues |
596 |
|
|
699 |
|
|
1,759 |
|
|
2,229 |
|
||||
Cost of natural gas and natural gas liquids (excluding depreciation and amortization) |
250 |
|
|
263 |
|
|
653 |
|
|
958 |
|
||||
Gross margin |
$ |
346 |
|
|
$ |
436 |
|
|
$ |
1,106 |
|
|
$ |
1,271 |
|
|
|
|
|
|
|
|
|
||||||||
Reportable Segments |
|
|
|
|
|
|
|
||||||||
Gathering and Processing |
|
|
|
|
|
|
|
||||||||
Product sales |
$ |
271 |
|
|
$ |
294 |
|
|
$ |
739 |
|
|
$ |
1,096 |
|
Service revenue |
192 |
|
|
248 |
|
|
592 |
|
|
663 |
|
||||
Total Revenues |
463 |
|
|
542 |
|
|
1,331 |
|
|
1,759 |
|
||||
Cost of natural gas and natural gas liquids (excluding depreciation and amortization) |
244 |
|
|
238 |
|
|
631 |
|
|
895 |
|
||||
Gross margin |
$ |
219 |
|
|
$ |
304 |
|
|
$ |
700 |
|
|
$ |
864 |
|
|
|
|
|
|
|
|
|
||||||||
Transportation and Storage |
|
|
|
|
|
|
|
||||||||
Product sales |
$ |
79 |
|
|
$ |
100 |
|
|
$ |
213 |
|
|
$ |
381 |
|
Service revenue |
126 |
|
|
134 |
|
|
409 |
|
|
421 |
|
||||
Total Revenues |
205 |
|
|
234 |
|
|
622 |
|
|
802 |
|
||||
Cost of natural gas and natural gas liquids (excluding depreciation and amortization) |
78 |
|
|
102 |
|
|
215 |
|
|
394 |
|
||||
Gross margin |
$ |
127 |
|
|
$ |
132 |
|
|
$ |
407 |
|
|
$ |
408 |
|
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||||||
|
|
|
|
|
|
|
|
||||||||
|
(In millions, except Distribution coverage ratio) |
||||||||||||||
Reconciliation of Adjusted EBITDA and DCF to net income (loss) attributable to limited partners and calculation of Distribution coverage ratio: |
|
|
|
|
|
|
|
||||||||
Net income (loss) attributable to limited partners |
$ |
(164 |
) |
|
$ |
132 |
|
|
$ |
(8 |
) |
|
$ |
378 |
|
Depreciation and amortization expense |
105 |
|
|
108 |
|
|
314 |
|
|
323 |
|
||||
Interest expense, net of interest income |
43 |
|
|
48 |
|
|
135 |
|
|
141 |
|
||||
Income tax benefit |
— |
|
|
— |
|
|
— |
|
|
(1 |
) |
||||
Distributions received from equity method affiliate in excess of equity earnings |
1 |
|
|
(1 |
) |
|
9 |
|
|
8 |
|
||||
Impairment of equity method affiliate investment |
225 |
|
|
— |
|
|
225 |
|
|
— |
|
||||
Non-cash equity-based compensation |
3 |
|
|
4 |
|
|
10 |
|
|
13 |
|
||||
Change in fair value of derivatives (1) |
15 |
|
|
2 |
|
|
17 |
|
|
3 |
|
||||
Other non-cash losses (2) |
1 |
|
|
2 |
|
|
23 |
|
|
9 |
|
||||
Impairments of property, plant and equipment and goodwill |
— |
|
|
— |
|
|
28 |
|
|
— |
|
||||
Gain on extinguishment of debt |
— |
|
|
— |
|
|
(5 |
) |
|
— |
|
||||
Noncontrolling Interest Share of Adjusted EBITDA |
— |
|
|
— |
|
|
(9 |
) |
|
(1 |
) |
||||
Adjusted EBITDA |
$ |
229 |
|
|
$ |
295 |
|
|
$ |
739 |
|
|
$ |
873 |
|
Series A Preferred Unit distributions (3) |
(9 |
) |
|
(9 |
) |
|
(27 |
) |
|
(27 |
) |
||||
Distributions for phantom and performance units (4) |
— |
|
|
(1 |
) |
|
(1 |
) |
|
(10 |
) |
||||
Adjusted interest expense (5) |
(42 |
) |
|
(47 |
) |
|
(134 |
) |
|
(143 |
) |
||||
Maintenance capital expenditures |
(31 |
) |
|
(36 |
) |
|
(69 |
) |
|
(86 |
) |
||||
Current income taxes |
— |
|
|
— |
|
|
1 |
|
|
— |
|
||||
DCF |
$ |
147 |
|
|
$ |
202 |
|
|
$ |
509 |
|
|
$ |
607 |
|
|
|
|
|
|
|
|
|
||||||||
Distributions related to common unitholders (6) |
$ |
72 |
|
|
$ |
144 |
|
|
$ |
216 |
|
|
$ |
426 |
|
|
|
|
|
|
|
|
|
||||||||
Distribution coverage ratio (7) |
2.04 |
|
|
1.40 |
|
|
2.36 |
|
|
1.42 |
|
||||
___________________ |
|
(1) |
Change in fair value of derivatives includes changes in the fair value of derivatives that are not designated as hedging instruments. |
(2) |
Other non-cash losses includes write-downs and net loss on sale and retirement of assets. |
(3) |
Represents the quarterly cash distributions on the Series A Preferred Units declared for the three and nine months ended September 30, 2020 and 2019. In accordance with the Partnership Agreement, the Series A Preferred Unit distributions are deemed to have been paid out of available cash with respect to the quarter immediately preceding the quarter in which the distribution is made. |
(4) |
Distributions for phantom and performance units represent distribution equivalent rights paid in cash. Phantom unit distribution equivalent rights are paid during the vesting period and performance unit distribution equivalent rights are paid at vesting. |
(5) |
See below for a reconciliation of Adjusted interest expense to Interest expense. |
(6) |
Represents cash distributions declared for common units outstanding as of each respective period. Amounts for 2020 reflect estimated cash distributions for common units outstanding for the quarter ended September 30, 2020. |
(7) |
Distribution coverage ratio is computed by dividing DCF by Distributions related to common unitholders. |
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||||||
|
|
|
|
|
|
|
|
||||||||
|
(In millions) |
||||||||||||||
Reconciliation of Adjusted EBITDA to net cash provided by operating activities: |
|
|
|
|
|
|
|
||||||||
Net cash provided by operating activities |
$ |
232 |
|
|
$ |
264 |
|
|
$ |
543 |
|
|
$ |
691 |
|
Interest expense, net of interest income |
43 |
|
|
48 |
|
|
135 |
|
|
141 |
|
||||
Noncontrolling interest share of cash provided by operating activities |
(1 |
) |
|
(1 |
) |
|
(3 |
) |
|
(2 |
) |
||||
Current income taxes |
— |
|
|
— |
|
|
1 |
|
|
— |
|
||||
Other non-cash items (1) |
(2 |
) |
|
— |
|
|
— |
|
|
4 |
|
||||
Proceeds from insurance |
1 |
|
|
— |
|
|
1 |
|
|
— |
|
||||
Changes in operating working capital which (provided) used cash: |
|
|
|
|
|
|
|
||||||||
Accounts receivable |
3 |
|
|
41 |
|
|
(27 |
) |
|
(16 |
) |
||||
Accounts payable |
(24 |
) |
|
(2 |
) |
|
46 |
|
|
110 |
|
||||
Other, including changes in noncurrent assets and liabilities |
(39 |
) |
|
(56 |
) |
|
17 |
|
|
(66 |
) |
||||
Return of investment in equity method affiliate |
1 |
|
|
(1 |
) |
|
9 |
|
|
8 |
|
||||
Change in fair value of derivatives (2) |
15 |
|
|
2 |
|
|
17 |
|
|
3 |
|
||||
Adjusted EBITDA |
$ |
229 |
|
|
$ |
295 |
|
|
$ |
739 |
|
|
$ |
873 |
|
____________________ |
|
(1) |
Other non-cash items includes write-downs of assets. |
(2) |
Change in fair value of derivatives includes changes in the fair value of derivatives that are not designated as hedging instruments. |
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||||||
|
|
|
|
|
|
|
|
||||||||
|
(In millions) |
||||||||||||||
Reconciliation of Adjusted interest expense to Interest expense: |
|
|
|
|
|
|
|
||||||||
Interest expense |
$ |
43 |
|
|
$ |
48 |
|
|
$ |
136 |
|
|
$ |
142 |
|
Interest income |
— |
|
|
— |
|
|
(1 |
) |
|
(1 |
) |
||||
Amortization of premium on long-term debt |
— |
|
|
1 |
|
|
1 |
|
|
4 |
|
||||
Capitalized interest on expansion capital |
1 |
|
|
— |
|
|
2 |
|
|
1 |
|
||||
Amortization of debt expense and discount |
(2 |
) |
|
(2 |
) |
|
(4 |
) |
|
(3 |
) |
||||
Adjusted interest expense |
$ |
42 |
|
|
$ |
47 |
|
|
$ |
134 |
|
|
$ |
143 |
|
ENABLE MIDSTREAM PARTNERS, LP OPERATING DATA |
|||||||||||
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||
|
|
|
|
|
|
|
|
||||
Operating Data: |
|
||||||||||
Natural gas gathered volumes—TBtu |
374 |
|
|
411 |
|
|
1,164 |
|
|
1,240 |
|
Natural gas gathered volumes—TBtu/d |
4.07 |
|
|
4.47 |
|
|
4.25 |
|
|
4.54 |
|
Natural gas processed volumes—TBtu (1) |
190 |
|
|
229 |
|
|
597 |
|
|
689 |
|
Natural gas processed volumes—TBtu/d (1) |
2.06 |
|
|
2.49 |
|
|
2.18 |
|
|
2.52 |
|
NGLs produced—MBbl/d (1)(2) |
133.11 |
|
|
117.78 |
|
|
122.29 |
|
|
128.62 |
|
NGLs sold—MBbl/d (2)(3) |
138.55 |
|
|
118.29 |
|
|
127.66 |
|
|
131.49 |
|
Condensate sold—MBbl/d |
5.58 |
|
|
6.16 |
|
|
6.50 |
|
|
7.36 |
|
Crude oil and condensate gathered volumes—MBbl/d |
138.02 |
|
|
132.99 |
|
|
121.38 |
|
|
120.17 |
|
Transported volumes—TBtu |
440 |
|
|
549 |
|
|
1,532 |
|
|
1,703 |
|
Transported volumes—TBtu/d |
4.78 |
|
|
5.97 |
|
|
5.58 |
|
|
6.22 |
|
Interstate firm contracted capacity—Bcf/d |
5.73 |
|
|
6.02 |
|
|
6.00 |
|
|
6.31 |
|
Intrastate average deliveries—TBtu/d |
1.74 |
|
|
2.10 |
|
|
1.83 |
|
|
2.16 |
|
____________________ |
|
(1) |
Includes volumes under third-party processing arrangements. |
(2) |
Excludes condensate. |
(3) |
NGLs sold includes volumes of NGLs withdrawn from inventory or purchased for system balancing purposes. |
|
Three Months Ended
|
|
Nine Months Ended
|
||||||||
|
2020 |
|
2019 |
|
2020 |
|
2019 |
||||
|
|
|
|
|
|
|
|
||||
Anadarko |
|
|
|
|
|
|
|
||||
Gathered volumes—TBtu/d |
1.94 |
|
|
2.27 |
|
|
2.04 |
|
|
2.32 |
|
Natural gas processed volumes—TBtu/d (1) |
1.76 |
|
|
2.04 |
|
|
1.85 |
|
|
2.07 |
|
NGLs produced—MBbl/d (1)(2) |
120.80 |
|
|
103.53 |
|
|
109.29 |
|
|
111.99 |
|
Crude oil and condensate gathered volumes—MBbl/d |
104.93 |
|
|
91.58 |
|
|
93.65 |
|
|
82.75 |
|
Arkoma |
|
|
|
|
|
|
|
||||
Gathered volumes—TBtu/d |
0.41 |
|
|
0.46 |
|
|
0.42 |
|
|
0.48 |
|
Natural gas processed volumes—TBtu/d (1) |
0.08 |
|
|
0.10 |
|
|
0.08 |
|
|
0.10 |
|
NGLs produced—MBbl/d (1)(2) |
3.94 |
|
|
4.42 |
|
|
3.96 |
|
|
5.89 |
|
Ark-La-Tex |
|
|
|
|
|
|
|
||||
Gathered volumes—TBtu/d |
1.72 |
|
|
1.74 |
|
|
1.79 |
|
|
1.74 |
|
Natural gas processed volumes—TBtu/d |
0.22 |
|
|
0.35 |
|
|
0.25 |
|
|
0.35 |
|
NGLs produced—MBbl/d (2) |
8.37 |
|
|
9.83 |
|
|
9.04 |
|
|
10.74 |
|
Williston |
|
|
|
|
|
|
|
||||
Crude oil gathered volumes—MBbl/d |
33.09 |
|
|
41.41 |
|
|
27.73 |
|
|
37.42 |
|
__________________ |
|
(1) |
Includes volumes under third-party processing arrangements. |
(2) |
Excludes condensate. |
