EnLink Midstream Reports Second Quarter 2021, Expects 2021 Adjusted EBITDA in the Upper End of June Guidance
EnLink Midstream reported a second-quarter net income of $9.4 million and adjusted EBITDA of $257.5 million, representing a 6.5% increase from the same period in 2020. The company experienced increased producer activity, particularly in the Permian and Oklahoma segments, attributed to higher commodity prices. Free cash flow after distributions was $71.5 million, contributing to a total of $359.4 million over the trailing twelve months. EnLink plans to maintain a balanced approach in utilizing free cash flow while striving to reduce leverage to below 4x.
- Adjusted EBITDA grew 6.5% year-over-year.
- Free cash flow after distributions of $71.5 million for Q2 2021.
- Strong producer activity in Permian and Oklahoma segments.
- Maintained flat operating and G&A expenses despite inflationary pressures.
- Significant progress towards reducing leverage, targeting below 4x.
- Net income decreased from $30 million in Q2 2020 to $9.4 million in Q2 2021.
- Segment profit in Louisiana declined by 18% compared to Q1 2021.
- North Texas segment profit decreased 25% compared to Q1 2021.
DALLAS, Aug. 3, 2021 /PRNewswire/ -- EnLink Midstream, LLC (NYSE: ENLC) (EnLink) reported financial results for the second quarter of 2021.
Highlights
- Reported net income of
$9.4 million , net cash provided by operating activities of$176.4 million , and adjusted EBITDA, net to EnLink, of$257.5 million for the second quarter of 2021, driven by strong producer activity and continued focus on efficiencies. - Grew adjusted EBITDA
6.5% compared to the second quarter of 2020, after excluding the impact of now expired 2020 minimum volume commitments (MVC). - Continued to focus on operating efficiencies leading to approximately flat operating and G&A expenses in the first half of 2021 compared to the second half of 2020, net of Project War Horse and Winter Storm Uri impacts, while in a growth and inflationary environment.
- Experienced increased producer activity during the quarter in EnLink's Permian and Oklahoma segments as operators responded to the strengthened commodity price environment.
- Formed the previously announced EnLink Carbon Solutions Group to develop carbon solutions service offerings built on EnLink's extensive footprint and longstanding customer relationships in Louisiana.
- Continued to generate positive segment cash flow in all four business segments during the second quarter of 2021.
- Delivered
$71.5 million of free cash flow after distributions (FCFAD) for the second quarter of 2021 as a result of strong operational results and timing of capex. On a trailing 12-month basis as of June 30, 2021, EnLink has generated$359.4 million in total FCFAD. - Exited the quarter with leverage at 4.1x as EnLink approaches its near-term target of less than 4x. EnLink will continue to de-lever while pursuing a more balanced approach for uses of FCFAD as it nears its near-term leverage goal.
- Paid down
$100 million of December 2021 term loan during the second quarter of 2021. - Repurchased
$10 million of common units in June and July 2021.
"EnLink delivered another solid quarter of operating and financial results as we continue to make progress on our strategic plan," said Barry E. Davis, EnLink Chairman and CEO. "With the tremendous execution by our team, continued momentum in producer activity on our footprint, and strong commodity prices, we expect to end 2021 in the upper end of our previously updated adjusted EBITDA guidance range of
"Our vision is to become the future of midstream by leading in innovation and creating sustainable value for EnLink and our unitholders. We took big steps toward achieving this vision with the creation of our Carbon Solutions Group, which will work on decarbonization projects that create compelling business opportunities for EnLink and our industrial partners, while also strengthening EnLink's leading role in the global energy transition. Our extensive network of pipelines in Louisiana and decades of operational excellence uniquely positions us to build a carbon capture and sequestration business that is mutually beneficial to EnLink and our existing customer base along the Mississippi River corridor, one of the highest CO2-emitting regions in the country."
Adjusted EBITDA, segment cash flow, and free cash flow after distributions used in this press release are non-GAAP measures and are explained in greater detail under "Non-GAAP Financial Information" below.
Second Quarter 2021 Financial Results and Highlights
Three Months Ended | |||||
$millions, unless noted | June 30, 2021 | March 31, 2021 | June 30, 2020 | ||
Net income (loss) | 9 | 13 | 30 | ||
Adjusted EBITDA, net to EnLink | 258 | 249 | 255 | ||
Net cash provided by operating activities | 176 | 226 | 135 | ||
Free cash flow after distributions | 72 | 94 | 72 | ||
Total capex & plant relocation costs, net to EnLink | 58 | 28 | 58 | ||
Debt to Adjusted EBITDA* | 4.1x | 4.2x | 4.3x | ||
Outstanding common units** | 488,622,133 | 490,055,937 | 489,593,587 | ||
*As calculated under EnLink's Revolver. | |||||
**Outstanding common units as of July 29, 2021, April 29, 2021, and June 30, 2020, respectively. | |||||
Second Quarter 2021 Segment Updates
Permian Basin:
- Segment profit of
$44.0 million for the second quarter of 2021 was3% higher than the first quarter of 2021 and28% higher than the second quarter of 2020. Segment profit includes$10.0 million and$6.0 million of operating expenses in the second quarter of 2021 and first quarter of 2021, respectively, related to our plant relocation project, Project War Horse. - Segment cash flow totaled
$4.5 million for the second quarter of 2021, marking the fourth consecutive quarter of positive segment cash flow. This was achieved despite a ramp up of capital expenditures and Project War Horse operating expenses incurred during the quarter. - Average natural gas gathering volumes for the second quarter of 2021 were approximately
11% higher as compared to the first quarter of 2021 and approximately18% higher as compared to the second quarter of 2020. Average natural gas processing volumes for the second quarter of 2021 increased approximately9% compared to the prior quarter and were7% higher as compared to the second quarter of 2020. - While volumes in the first quarter of 2021 were adversely impacted by Winter Storm Uri, gas gathering and processing volumes in the second quarter were
10% higher and6% higher, respectively, over the fourth quarter of 2020. The second quarter of 2021 benefited from producers quickly bringing wells back online following Winter Storm Uri and continued momentum in rig and completion activity. - Average crude gathering volumes increased by approximately
13% for the second quarter of 2021 as compared to the first quarter of 2021 due to timing of producer completion activity.
Louisiana:
- Segment profit of
$67.3 million for the second quarter of 2021 was18% lower as compared to the first quarter of 2021 and approximately5% higher as compared to the second quarter of 2020. The sequential decline was due to normal natural gas liquids (NGL) business seasonality. The improvement over the prior year was driven by the inception of the Venture Global contract in the first quarter of 2021 and higher NGL fractionation volumes. - Segment cash flow for the second quarter of 2021 was
$65.1 million , and Louisiana is expected to continue generating strong segment cash flow for the remainder of 2021 with the fourth quarter expected to continue as the seasonally strongest quarter. - Average natural gas transportation volumes for the second quarter of 2021 were approximately
1% lower as compared to the first quarter of 2021 and approximately14% higher as compared to the second quarter of 2020. - NGL fractionation volumes for the second quarter of 2021 were approximately
9% higher as compared to the first quarter of 2021 and approximately5% higher as compared to the second quarter of 2020. - Average crude volumes handled in EnLink's Ohio River Valley operations for the second quarter of 2021 were lower by approximately
3% as compared to the second quarter of 2020 due to lower overall levels of activity in the region.
Oklahoma:
- Segment profit of
$85.6 million for the second quarter of 2021 was approximately54% higher as compared to the first quarter of 2021, which was negatively impacted by Winter Storm Uri. Excluding the impact of MVC payments that expired in 2020, segment profit grew over5% in the second quarter of 2021 compared to the fourth quarter of 2020. - Segment cash flow for the second quarter of 2021 was
$80.7 million , and Oklahoma is expected to continue generating strong segment cash flow for the remainder of 2021. - Average natural gas gathering volumes for the second quarter of 2021 were approximately
8% higher as compared to the first quarter of 2021. Average natural gas processing volumes for the second quarter of 2021 increased by approximately9% when compared to the first quarter of 2021. - Including the adverse impact of Winter Storm Uri in the first quarter, gathering and processing volumes were
2% lower compared to the fourth quarter of 2020, as producer activity improved during the second quarter, helping to moderate the decline in volumes. - The Devon and Dow Inc. joint venture continues to progress as expected under the joint venture's development plan, operating two rigs during the second quarter of 2021. First volumes are expected in the second half of 2021.
- Average crude gathering volumes during the second quarter of 2021 were approximately
36% higher as compared to the first quarter of 2021.
North Texas:
- Segment profit of
$57.9 million for the second quarter of 2021 decreased by approximately25% as compared to the first quarter of 2021, which was positively impacted by Winter Storm Uri. Segment profit declined by approximately6% compared to the fourth quarter of 2020. - Segment cash flow for the first quarter of 2021 was
$56.0 million . North Texas is expected to generate strong segment cash flow for the remainder of 2021. - Average natural gas gathering and transportation volumes for the second quarter of 2021 increased by approximately
2% as compared to the first quarter of 2021. Average natural gas processing volumes for the second quarter of 2021 were flat when compared to the first quarter of 2021. - BKV and other operators continued to focus on production optimization through restimulation activity in the basin.
Second Quarter 2021 Earnings Call Details
EnLink will hold a conference call to discuss second quarter 2021 results on August 4, 2021, at 8 a.m. Central time (9 a.m. Eastern time). The dial-in number for the call is 1-855-656-0924. Callers outside the United States should dial 1-412-542-4172. Participants can also preregister for the conference call by navigating to https://dpregister.com/sreg/10158225/ea8f026c35 where they will receive dial-in information upon completion of preregistration. Interested parties can access an archived replay of the call on the Investors' page of EnLink's website at www.EnLink.com.
About EnLink Midstream
EnLink Midstream reliably operates a differentiated midstream platform that is built for long-term, sustainable value creation. EnLink's best-in-class services span the midstream value chain, providing natural gas, crude oil, condensate, and NGL capabilities. Our purposely built, integrated asset platforms are in premier production basins and core demand centers, including the Permian Basin, Oklahoma, North Texas, and the Gulf Coast. EnLink's strong financial foundation and commitment to execution excellence drive competitive returns and value for our employees, customers, and investors. Headquartered in Dallas, EnLink is publicly traded through EnLink Midstream, LLC (NYSE: ENLC). Visit www.EnLink.com to learn how EnLink connects energy to life.
Non-GAAP Financial Information
This press release contains non-generally accepted accounting principles financial measures that we refer to as adjusted EBITDA, free cash flow after distributions, and segment cash flow.
We define adjusted EBITDA as net income (loss) plus (less) interest expense, net of interest income; depreciation and amortization; impairments; (income) loss from unconsolidated affiliate investments; distributions from unconsolidated affiliate investments; (gain) loss on disposition of assets; (gain) loss on extinguishment of debt; unit-based compensation; income tax expense (benefit); unrealized (gain) loss on commodity swaps; relocation costs associated with the War Horse processing facility; accretion expense associated with asset retirement obligations; transaction costs; (non-cash rent); and (non-controlling interest share of adjusted EBITDA from joint ventures).
We define free cash flow after distributions as adjusted EBITDA, net to ENLC, plus (less) (growth capital expenditures, excluding capital expenditures that were contributed by other entities and relate to the non-controlling interest share of our consolidated entities); (maintenance capital expenditures, excluding capital expenditures that were contributed by other entities and relate to the non-controlling interest share of our consolidated entities); (interest expense, net of interest income); (distributions declared on common units); (accrued cash distributions on Series B Preferred Units and Series C Preferred Units paid or expected to be paid); (relocation costs associated with the War Horse processing facility); (payments to terminate interest rate swaps); non-cash interest (income)/expense; (current income taxes); and proceeds from the sale of equipment and land.
We define segment cash flow as segment profit less growth and maintenance capital expenditures, which are gross to EnLink prior to giving effect to the contributions by other entities related to the non-controlling interest share of our consolidated entities.
EnLink believes these measures are useful to investors because they may provide users of this financial information with meaningful comparisons between current results and previously-reported results and a meaningful measure of the company's cash flow after it has satisfied the capital and related requirements of its operations. In addition, adjusted EBITDA and free cash flow after distributions are both used as metrics in our short-term incentive program for compensating employees.
Adjusted EBITDA, free cash flow after distributions, and segment cash flow, as defined above, are not measures of financial performance or liquidity under GAAP. They should not be considered in isolation or as an indicator of EnLink's performance. Furthermore, they should not be seen as a substitute for metrics prepared in accordance with GAAP. Reconciliations of these measures to their most directly comparable GAAP measures are included in the following tables. See ENLC's filings with the Securities and Exchange Commission for more information.
Other definitions and explanations of terms used in this press release:
Segment profit (loss) is defined as operating income (loss) plus general and administrative expenses, depreciation and amortization, (gain) loss on disposition of assets, and impairments. Segment profit (loss) includes non-cash compensation expenses reflected in operating expenses. See "Item 8. Financial Statements and Supplementary Data - Note 15 - Segment Information" in ENLC's Annual Report on Form 10-K for the year ended December 31, 2020, and, when available, "Item 1. Financial Statements - Note 13—Segment Information" in ENLC's Quarterly Report on Form 10-Q for the three months ended June 30, 2021, for further information about segment profit (loss).
The Ascension JV is a joint venture between a subsidiary of EnLink and a subsidiary of Marathon Petroleum Corporation in which EnLink owns a
The Delaware Basin JV is a joint venture between EnLink and an affiliate of NGP in which EnLink owns a
Forward-Looking Statements
This press release contains forward-looking statements within the meaning of the federal securities laws. Although these statements reflect the current views, assumptions and expectations of our management, the matters addressed herein involve certain assumptions, risks and uncertainties that could cause actual activities, performance, outcomes and results to differ materially from those indicated herein. Therefore, you should not rely on any of these forward-looking statements. All statements, other than statements of historical fact, included in this press release constitute forward-looking statements, including but not limited to statements identified by the words "forecast," "may," "believe," "will," "should," "plan," "predict," "anticipate," "intend," "estimate," and "expect" and similar expressions. Such forward-looking statements include, but are not limited to, statements about guidance, projected or forecasted financial and operating results, expected financial and operations results associated with certain projects, acquisitions, or growth capital expenditures, future operational results of our customers, results in certain basins, future cost savings or operational initiatives, profitability, financial or leverage metrics, the impact of Winter Storm Uri on us and our financial results and operations, including the impact of any customer billing disputes and litigation arising out of Uri, future expectations regarding sustainability initiatives, our future capital structure and credit ratings, the impact of the COVID-19 pandemic on us and our financial results and operations, objectives, strategies, expectations, and intentions, and other statements that are not historical facts. Factors that could result in such differences or otherwise materially affect our financial condition, results of operations, or cash flows include, without limitation (a) the impact of the ongoing coronavirus (COVID-19) pandemic including the impact of the emergence of any new variants of the virus on our business, financial condition, and results of operations, (b) potential conflicts of interest of Global Infrastructure Partners ("GIP") with us and the potential for GIP to favor GIP's own interests to the detriment of our other unitholders, (c) GIP's ability to compete with us and the fact that it is not required to offer us the opportunity to acquire additional assets or businesses, (d) a default under GIP's credit facility could result in a change in control of us, could adversely affect the price of our common units, and could result in a default under our credit facility, (e) the dependence on Devon for a substantial portion of the natural gas and crude that we gather, process, and transport, (f) developments that materially and adversely affect Devon or other customers, (g) adverse developments in the midstream business that may reduce our ability to make distributions, (h) competition for crude oil, condensate, natural gas, and NGL supplies and any decrease in the availability of such commodities, (i) decreases in the volumes that we gather, process, fractionate, or transport, (j) construction risks in our major development projects, (k) our ability to receive or renew required permits and other approvals, (l) increased federal, state, and local legislation, and regulatory initiatives, as well as government reviews relating to hydraulic fracturing resulting in increased costs and reductions or delays in natural gas production by our customers, (m) climate change legislation and regulatory initiatives resulting in increased operating costs and reduced demand for the natural gas and NGL services we provide, (n) changes in the availability and cost of capital, including as a result of a change in our credit rating, (o) volatile prices and market demand for crude oil, condensate, natural gas, and NGLs that are beyond our control, (p) our debt levels could limit our flexibility and adversely affect our financial health or limit our flexibility to obtain financing and to pursue other business opportunities, (q) operating hazards, natural disasters, weather-related issues or delays, casualty losses, and other matters beyond our control, (r) reductions in demand for NGL products by the petrochemical, refining, or other industries or by the fuel markets, (s) impairments to goodwill, long-lived assets and equity method investments, and (t) the effects of existing and future laws and governmental regulations, including environmental and climate change requirements and other uncertainties. These and other applicable uncertainties, factors, and risks are described more fully in EnLink Midstream, LLC's and EnLink Midstream Partners, LP's filings with the Securities and Exchange Commission, including EnLink Midstream, LLC's and EnLink Midstream Partners, LP's Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, and Current Reports on Form 8-K. Neither EnLink Midstream, LLC nor EnLink Midstream Partners, LP assumes any obligation to update any forward-looking statements.
The EnLink management team based the forecasted financial information included herein on certain information and assumptions, including, among others, the producer budgets / forecasts to which EnLink has access as of the date of this press release and the projects / opportunities expected to require capital expenditures as of the date of this press release. The assumptions, information, and estimates underlying the forecasted financial information included in the guidance information in this press release are inherently uncertain and, though considered reasonable by the EnLink management team as of the date of its preparation, are subject to a wide variety of significant business, economic, and competitive risks and uncertainties that could cause actual results to differ materially from those contained in the forecasted financial information. Accordingly, there can be no assurance that the forecasted results are indicative of EnLink's future performance or that actual results will not differ materially from those presented in the forecasted financial information. Inclusion of the forecasted financial information in this press release should not be regarded as a representation by any person that the results contained in the forecasted financial information will be achieved.
Investor Relations: Brian Brungardt, Director of Investor Relations, 214-721-9353, brian.brungardt@enlink.com
Media Relations: Jill McMillan, Vice President of Strategic Relations & Public Affairs, 214-721-9271, jill.mcmillan@enlink.com
EnLink Midstream, LLC | |||||||||||||||
Selected Financial Data | |||||||||||||||
(All amounts in millions except per unit amounts) | |||||||||||||||
(Unaudited) | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2021 | 2020 | 2021 | 2020 | ||||||||||||
Total revenues | $ | 1,406.7 | $ | 744.9 | $ | 2,655.1 | $ | 1,901.0 | |||||||
Operating costs and expenses: | |||||||||||||||
Cost of sales, exclusive of operating expenses and depreciation and amortization (1)(2) | 1,055.1 | 397.7 | 1,989.8 | 1,153.0 | |||||||||||
Operating expenses | 96.8 | 88.1 | 153.1 | 188.8 | |||||||||||
Depreciation and amortization | 151.9 | 158.2 | 302.9 | 321.0 | |||||||||||
Impairments | — | 1.5 | — | 354.5 | |||||||||||
(Gain) loss on disposition of assets | (0.3) | 5.2 | (0.3) | 4.6 | |||||||||||
General and administrative | 26.1 | 23.5 | 52.1 | 53.9 | |||||||||||
Total operating costs and expenses | 1,329.6 | 674.2 | 2,497.6 | 2,075.8 | |||||||||||
Operating income (loss) | 77.1 | 70.7 | 157.5 | (174.8) | |||||||||||
Other income (expense): | |||||||||||||||
Interest expense, net of interest income | (60.0) | (55.2) | (120.0) | (110.8) | |||||||||||
Gain on extinguishment of debt | — | 26.7 | — | 32.0 | |||||||||||
Income (loss) from unconsolidated affiliates | (1.3) | (0.7) | (7.6) | 1.0 | |||||||||||
Other income | 0.2 | — | 0.1 | — | |||||||||||
Total other expense | (61.1) | (29.2) | (127.5) | (77.8) | |||||||||||
Income (loss) before non-controlling interest and income taxes | 16.0 | 41.5 | 30.0 | (252.6) | |||||||||||
Income tax benefit (expense) | (6.6) | (11.7) | (8.0) | 22.0 | |||||||||||
Net income (loss) | 9.4 | 29.8 | 22.0 | (230.6) | |||||||||||
Net income attributable to non-controlling interest | 31.0 | 25.7 | 56.3 | 52.1 | |||||||||||
Net income (loss) attributable to ENLC | $ | (21.6) | $ | 4.1 | $ | (34.3) | $ | (282.7) | |||||||
Net income (loss) attributable to ENLC per unit: | |||||||||||||||
Basic common unit | $ | (0.04) | $ | 0.01 | $ | (0.07) | $ | (0.58) | |||||||
Diluted common unit | $ | (0.04) | $ | 0.01 | $ | (0.07) | $ | (0.58) | |||||||
Weighted average common units outstanding (basic and diluted) | 490.0 | 489.3 | 490.0 | 489.0 | |||||||||||
Weighted average common units outstanding (diluted) | 490.0 | 490.4 | 490.0 | 489.0 | |||||||||||
________________________________ | |
(1) | Includes related party cost of sales of |
(2) | Includes related party cost of sales of |
EnLink Midstream, LLC | |||||||||||||||
Reconciliation of Net Income (Loss) to Adjusted EBITDA | |||||||||||||||
(All amounts in millions) | |||||||||||||||
(Unaudited) | |||||||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||||||
2021 | 2020 | 2021 | 2020 | ||||||||||||
Net income (loss) | $ | 9.4 | $ | 29.8 | $ | 22.0 | $ | (230.6) | |||||||
Interest expense, net of interest income | 60.0 | 55.2 | 120.0 | 110.8 | |||||||||||
Depreciation and amortization | 151.9 | 158.2 | 302.9 | 321.0 | |||||||||||
Impairments | — | 1.5 | — | 354.5 | |||||||||||
(Income) loss from unconsolidated affiliates | 1.3 | 0.7 | 7.6 | (1.0) | |||||||||||
Distributions from unconsolidated affiliates | 0.1 | 0.2 | 3.7 | 2.0 | |||||||||||
(Gain) loss on disposition of assets | (0.3) | 5.2 | (0.3) | 4.6 | |||||||||||
Gain on extinguishment of debt | — | (26.7) | — | (32.0) | |||||||||||
Unit-based compensation | 6.4 | 7.4 | 12.9 | 16.2 | |||||||||||
Income tax expense (benefit) | 6.6 | 11.7 | 8.0 | (22.0) | |||||||||||
Unrealized loss on commodity swaps | 23.8 | 18.8 | 31.7 | 5.8 | |||||||||||
Relocation costs associated with the War Horse processing facility (1) | 10.2 | — | 17.8 | — | |||||||||||
Other (2) | 0.4 | (0.4) | — | (0.5) | |||||||||||
Adjusted EBITDA before non-controlling interest | 269.8 | 261.6 | 526.3 | 528.8 | |||||||||||
Non-controlling interest share of adjusted EBITDA from joint ventures (3) | (12.3) | (6.5) | (19.4) | (13.7) | |||||||||||
Adjusted EBITDA, net to ENLC | $ | 257.5 | $ | 255.1 | $ | 506.9 | $ | 515.1 | |||||||
____________________________ | |
(1) | Represents cost incurred related to the relocation of equipment and facilities from the Battle Ridge processing plant, in the Oklahoma segment, to the Permian segment that we expect to complete in 2021 and are not part of our ongoing operations. |
(2) | Includes accretion expense associated with asset retirement obligations; transaction costs, and non-cash rent, which relates to lease incentives pro-rated over the lease term. |
(3) | Non-controlling interest share of adjusted EBITDA from joint ventures includes NGP Natural Resources XI, L.P.'s ("NGP")'s |
EnLink Midstream, LLC | |||||||||||||||
Reconciliation of Net Cash Provided by Operating Activities to Adjusted EBITDA | |||||||||||||||
and Free Cash Flow After Distributions | |||||||||||||||
(All amounts in millions except ratios and per unit amounts) | |||||||||||||||
(Unaudited) | |||||||||||||||
Three Months Ended June 30, | Six Months Ended | ||||||||||||||
2021 | 2020 | 2021 | 2020 | ||||||||||||
Net cash provided by operating activities | $ | 176.4 | $ | 134.8 | $ | 402.2 | $ | 316.8 | |||||||
Interest expense (1) | 55.6 | 54.0 | 111.5 | 108.7 | |||||||||||
Utility credits (2) | 3.4 | — | 43.8 | — | |||||||||||
Payments to terminate interest rate swaps (3) | 1.3 | — | 1.3 | — | |||||||||||
Accruals for settled commodity swap transactions | (2.6) | (5.2) | (2.5) | (0.2) | |||||||||||
Distributions from unconsolidated affiliate investment in excess of earnings | 0.1 | 0.6 | 3.7 | 0.8 | |||||||||||
Relocation costs associated with the War Horse processing facility (4) | 10.2 | — | 17.8 | — | |||||||||||
Other (5) | 1.4 | (0.1) | 2.6 | 0.6 | |||||||||||
Changes in operating assets and liabilities which (provided) used cash: | |||||||||||||||
Accounts receivable, accrued revenues, inventories, and other | 91.7 | 50.2 | 109.2 | (119.1) | |||||||||||
Accounts payable, accrued product purchases, and other accrued liabilities | (67.7) | 27.3 | (163.3) | 221.2 | |||||||||||
Adjusted EBITDA before non-controlling interest | 269.8 | 261.6 | 526.3 | 528.8 | |||||||||||
Non-controlling interest share of adjusted EBITDA from joint ventures (6) | (12.3) | (6.5) | (19.4) | (13.7) | |||||||||||
Adjusted EBITDA, net to ENLC | 257.5 | 255.1 | 506.9 | 515.1 | |||||||||||
Growth capital expenditures, net to ENLC (7) | (40.0) | (50.7) | (55.9) | (133.3) | |||||||||||
Maintenance capital expenditures, net to ENLC (7) | (7.5) | (7.7) | (12.2) | (15.9) | |||||||||||
Interest expense, net of interest income | (60.0) | (55.2) | (120.0) | (110.8) | |||||||||||
Distributions declared on common units | (46.7) | (46.4) | (93.4) | (92.9) | |||||||||||
ENLK preferred unit accrued cash distributions (8) | (23.0) | (22.8) | (46.0) | (45.6) | |||||||||||
Relocation costs associated with the War Horse processing facility (4) | (10.2) | — | (17.8) | — | |||||||||||
Non-cash interest expense | 2.4 | — | 4.6 | — | |||||||||||
Payments to terminate interest rate swaps (3) | (1.3) | — | (1.3) | — | |||||||||||
Other (9) | 0.3 | — | 0.8 | 0.2 | |||||||||||
Free cash flow after distributions | $ | 71.5 | $ | 72.3 | $ | 165.7 | $ | 116.8 | |||||||
Actual declared distribution to common unitholders | $ | 46.7 | $ | 46.4 | $ | 93.4 | $ | 92.9 | |||||||
Distribution coverage | 3.61x | 3.65x | 3.56x | 3.69x | |||||||||||
Distributions declared per ENLC unit | $ | 0.09375 | $ | 0.09375 | $ | 0.18750 | $ | 0.18750 | |||||||
____________________________ | |
(1) | Net of amortization of debt issuance costs and discount and premium, which are included in interest expense but not included in net cash provided by operating activities, and non-cash interest income, which is netted against interest expense but not included in adjusted EBITDA. |
(2) | Under our utility agreements, we are entitled to a base load of electricity and pay or receive credits, based on market pricing, when we exceed or do not use the base load amounts. Due to Winter Storm Uri, we received credits from our utility providers based on market rates for our unused electricity. |
(3) | Represents cash paid for the early termination of |
(4) | Represents cost incurred related to the relocation of equipment and facilities from the Battle Ridge processing plant, in the Oklahoma segment, to the Permian segment that we expect to complete in 2021 and are not part of our ongoing operations. |
(5) | Includes current income tax expense; amortization of designated cash flow hedge; transaction costs; and non-cash rent, which relates to lease incentives pro-rated over the lease term. |
(6) | Non-controlling interest share of adjusted EBITDA from joint ventures includes NGP's |
(7) | Excludes capital expenditures that were contributed by other entities and relate to the non-controlling interest share of our consolidated entities. |
(8) | Represents the cash distributions earned by the Series B Preferred Units and Series C Preferred Units, which are not available to common unitholders. |
(9) | Includes current income tax expense and proceeds from the sale of surplus or unused equipment and land, which occurred in the normal operation of our business. |
EnLink Midstream, LLC | |||||||||||||||
Reconciliation of Segment Profit to Segment Cash Flow | |||||||||||||||
(All amounts in millions) | |||||||||||||||
(Unaudited) | |||||||||||||||
Permian | Louisiana | Oklahoma | North Texas | ||||||||||||
Three Months Ended June 30, 2021 | |||||||||||||||
Segment profit | $ | 44.0 | $ | 67.3 | $ | 85.6 | $ | 57.9 | |||||||
Capital expenditures | (39.5) | (2.2) | (4.9) | (1.9) | |||||||||||
Segment cash flow | $ | 4.5 | $ | 65.1 | $ | 80.7 | $ | 56.0 | |||||||
Three Months Ended June 30, 2020 | |||||||||||||||
Segment profit | $ | 34.4 | $ | 63.8 | $ | 92.6 | $ | 68.3 | |||||||
Capital expenditures | (46.9) | (15.6) | (3.0) | (3.0) | |||||||||||
Segment cash flow | $ | (12.5) | $ | 48.2 | $ | 89.6 | $ | 65.3 | |||||||
Six Months Ended June 30, 2021 | |||||||||||||||
Segment profit | $ | 86.8 | $ | 149.5 | $ | 141.1 | $ | 134.8 | |||||||
Capital expenditures | (52.8) | (5.0) | (6.8) | (4.3) | |||||||||||
Segment cash flow | $ | 34.0 | $ | 144.5 | $ | 134.3 | $ | 130.5 | |||||||
Six Months Ended June 30, 2020 | |||||||||||||||
Segment profit | $ | 77.0 | $ | 139.1 | $ | 200.6 | $ | 142.5 | |||||||
Capital expenditures | (132.9) | (30.8) | (11.5) | (7.7) | |||||||||||
Segment cash flow | $ | (55.9) | $ | 108.3 | $ | 189.1 | $ | 134.8 | |||||||
EnLink Midstream, LLC | |||||||||||
Operating Data | |||||||||||
(Unaudited) | |||||||||||
Three Months Ended June 30, | Six Months Ended June 30, | ||||||||||
2021 | 2020 | 2021 | 2020 | ||||||||
Midstream Volumes: | |||||||||||
Permian Segment | |||||||||||
Gathering and Transportation (MMBtu/d) | 1,025,900 | 871,500 | 976,000 | 851,300 | |||||||
Processing (MMBtu/d) | 958,400 | 896,100 | 917,500 | 878,900 | |||||||
Crude Oil Handling (Bbls/d) | 121,900 | 112,300 | 115,100 | 122,900 | |||||||
Louisiana Segment | |||||||||||
Gathering and Transportation (MMBtu/d) | 2,139,300 | 1,873,600 | 2,145,300 | 1,958,400 | |||||||
Crude Oil Handling (Bbls/d) | 15,200 | 15,700 | 15,100 | 16,600 | |||||||
NGL Fractionation (Gals/d) | 7,729,300 | 7,344,800 | 7,419,500 | 7,764,500 | |||||||
Brine Disposal (Bbls/d) | 2,900 | 1,400 | 2,200 | 1,600 | |||||||
Oklahoma Segment | |||||||||||
Gathering and Transportation (MMBtu/d) | 1,016,200 | 1,092,600 | 977,000 | 1,156,800 | |||||||
Processing (MMBtu/d) | 1,040,000 | 1,082,100 | 997,900 | 1,118,300 | |||||||
Crude Oil Handling (Bbls/d) | 23,800 | 30,000 | 20,700 | 33,300 | |||||||
North Texas Segment | |||||||||||
Gathering and Transportation (MMBtu/d) | 1,377,400 | 1,485,900 | 1,367,200 | 1,531,800 | |||||||
Processing (MMBtu/d) | 627,600 | 670,600 | 626,100 | 685,200 | |||||||
EnLink Midstream, LLC | |||
Forward-Looking Reconciliation of Net Income to Adjusted EBITDA and Free Cash Flow After Distributions | |||
(All amounts in millions) | |||
(Unaudited) | |||
2021 Outlook (1) | |||
Net income of EnLink Midstream, LLC (2) | $ | 145.0 | |
Interest expense, net of interest income | 242.0 | ||
Depreciation and amortization | 604.0 | ||
Income from unconsolidated affiliate investments | (2.0) | ||
Distributions from unconsolidated affiliate investments | 1.0 | ||
Unit-based compensation | 31.0 | ||
Income taxes | 30.0 | ||
Project War Horse (3) | 25.0 | ||
Other (4) | (1.0) | ||
Adjusted EBITDA before non-controlling interest | 1075.0 | ||
Non-controlling interest share of adjusted EBITDA (5) | (35.0) | ||
Adjusted EBITDA, net to EnLink Midstream, LLC | 1040.0 | ||
Interest expense, net of interest income | (242.0) | ||
Maintenance capital expenditures, net to ENLK (6) | (40.0) | ||
Preferred unit accrued cash distributions (7) | (92.0) | ||
Other (8) | 10.0 | ||
Distributable cash flow | 676.0 | ||
Common distributions declared | (186.0) | ||
Growth capital expenditures, net to EnLink and Project War Horse (3)(6) | (140.0) | ||
Free cash flow after distributions | $ | 350.0 | |
___________________________ | |
(1) | Represents the forward-looking net income guidance of EnLink Midstream, LLC for the year ended December 31, 2021. The forward-looking net income guidance excludes the potential impact of gains or losses on derivative activity, gains or losses on disposition of assets, impairment expense, gains or losses as a result of legal settlements, gains or losses on extinguishment of debt, the financial effects of future acquisitions, and proceeds from the sale of equipment. The exclusion of these items is due to the uncertainty regarding the occurrence, timing and/or amount of these events. |
(2) | Net income includes estimated net income attributable to (i) NGP Natural Resources XI, L.P.'s ("NGP") |
(3) | Project War Horse includes operating expenses incurred related to the relocation of equipment and facilities from the Battle Ridge processing plant, in the Oklahoma segment, to the Permian segment that we expect to complete in 2021 and are not part of our ongoing operations. |
(4) | Includes (i) estimated accretion expense associated with asset retirement obligations and (ii) estimated non-cash rent, which relates to lease incentives pro-rated over the lease term. |
(5) | Non-controlling interest share of adjusted EBITDA includes estimates for (i) NGP's |
(6) | Excludes capital expenditures that are contributed by other entities and relate to the non-controlling interest share of our consolidated entities. |
(7) | Represents the cash distributions earned by the ENLK Series B Preferred Units and ENLK Series C Preferred Units. Cash distributions to be paid to holders of the ENLK Series B Preferred Units and ENLK Series C Preferred Units are not available to common unitholders. |
(8) | Includes non-cash interest (income)/expense and current tax income/(expense). |
EnLink Midstream does not provide a reconciliation of forward-looking Net Cash Provided by Operating Activities to Adjusted EBITDA and Excess Free Cash Flow because the companies are unable to predict with reasonable certainty changes in working capital, which may impact cash provided or used during the year. Working capital includes accounts receivable, accounts payable and other current assets and liabilities. These items are uncertain and depend on various factors outside the companies' control. For the same reasons, EnLink is unable to address the probable significance of the unavailable information, which could be material to future results.
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SOURCE EnLink Midstream, LLC
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