EnLink Midstream Reports Third Quarter 2019 Results, Provides Updates
DALLAS, Nov. 7, 2019 /PRNewswire/ -- EnLink Midstream, LLC (NYSE: ENLC) (EnLink) reported financial results for the third quarter of 2019, updated certain 2019 full-year guidance metrics, and detailed its 2020 growth capital expenditures outlook. EnLink also provided an update from Barry Davis, Chairman and Chief Executive Officer, regarding strategic actions being taken by EnLink, which represent up to $75 million of adjusted EBITDA to the company in 2020.
Highlights:
-- Provided an update from Davis on observations since his return to the
CEO role in early August 2019 and provided an execution plan to respond
to changing market conditions. The plan in aggregate is expected to
result in up to $75 million of cost reductions, margin enhancements, and
commercial wins during 2020. A number of initiatives are already
underway, which will generate significant positive results in the near
term.
-- Announced expectation for full-year 2019 growth capital expenditures,
net to EnLink, to be at the low end of the previously announced guidance
range of $630 million to $710 million.
-- Outlined forecast for full-year 2020 growth capital expenditures, net to
EnLink, of $275 million to $375 million. This forecast represents an
approximate 50% decrease as compared to the projected full-year 2019
growth capital expenditures of around $630 million.
-- Announced further commercial success in Louisiana with the signing of a
new long-term natural gas purchase agreement at attractive rates. Under
the terms of the agreement, EnLink will utilize its existing assets to
transport natural gas from northern Louisiana to Gulf Coast demand
markets with no incremental capital expenditures.
-- Placed into service the 65 million cubic feet per day (MMcf/d) Riptide
natural gas processing plant expansion in the Permian Basin in late
September 2019, bringing total processing capacity in the Permian Basin
to over 800 MMcf/d.
-- Previously declared a quarterly cash distribution of $0.283 per unit on
all outstanding common units for the third quarter of 2019, which was
the same as the declared distribution for the second quarter of 2019.
"EnLink's third quarter performance demonstrates the strength of our large-scale diversified platform, and the flexibility of our operations in the midst of a changing operating environment," Davis said. "We expect growth in the fourth quarter, as compared to the third quarter, and are forecasting 2019 adjusted EBITDA to be at the low end of our guidance range. EnLink remains in a solid competitive position, and we are taking decisive actions to enhance the profitability of our existing business, position ourselves to capture long-term opportunities, strengthen our financial position, and drive organizational efficiency throughout the company."
Adjusted EBITDA and distributable cash flow used in this press release are non-GAAP measures and are explained in greater detail under "Non-GAAP Financial Information and Other Definitions" below.
Third Quarter 2019 Financial Results and 2019 Full-Year Guidance Update
-- Reported net income attributable to EnLink of $11.8 million for the
third quarter of 2019. EnLink is projecting a net loss for full-year
2019, which is expected to be below the previously announced guidance
range.
-- Achieved adjusted EBITDA net to EnLink of $261.2 million for the third
quarter of 2019. Adjusted EBITDA for full-year 2019 is expected to be at
the low end of the previously announced guidance range of $1.07 billion
to $1.1 billion.
-- Reported net cash provided by operating activities of $256.0 million for
the third quarter of 2019.
-- Achieved distributable cash flow (DCF) of $168.2 million for the third
quarter of 2019. DCF for full-year 2019 is expected to be at the low end
of the previously announced guidance range of $715 million to $735
million.
-- Distribution coverage was 1.21x for the third quarter of 2019.
Distribution coverage for full-year 2019 is expected to be at the low
end of the previously announced guidance range of 1.3x to 1.5x.
-- Growth capital expenditures, net to EnLink, were approximately $149
million for the third quarter of 2019 and approximately $510 million
year to date through September 30, 2019. EnLink expects growth capital
expenditures for full-year 2019 to be at the low end of the previously
announced guidance range of $630 million to $710 million.
-- Debt-to-adjusted EBITDA, as calculated under the terms of EnLink's
credit facility, was 4.2x for the third quarter of 2019. EnLink expects
debt-to-adjusted EBITDA for full-year 2019 to be around the high-end of
the previously announced guidance range of 3.9x to 4.2x.
-- As of November 4, 2019, EnLink had 487,612,888 common units outstanding.
Third Quarter 2019 Segment Updates
Permian Basin:
-- Segment profit of $36.3 million for the third quarter of 2019 was
approximately 9% higher as compared to the second quarter of 2019 and
approximately 6% lower as compared to the third quarter of 2018. Third
quarter 2019 segment profit was muted as compared to the prior quarter
and the same period during 2018 due in part to a reduction in average
crude gathering volumes.
-- Average natural gas gathering and transportation volumes for the third
quarter of 2019 were approximately 11% higher as compared to the second
quarter of 2019 and approximately 35% higher as compared to the third
quarter of 2018. Average natural gas processing volumes for the third
quarter of 2019 increased approximately 10% and 40% as compared to the
second quarter of 2019 and the third quarter of 2018, respectively.
-- Average crude gathering volumes decreased by approximately 22% for the
third quarter of 2019 as compared to the second quarter of 2019 and
declined approximately 14% as compared to the third quarter of 2018,
driven primarily by lower crude first-purchase volumes.
-- The previously announced 65 MMcf/d expansion of the Riptide natural gas
processing facility in the Midland Basin became operational in late
September 2019, which supports volume growth in the company's Midland
Basin footprint.
-- The Tiger natural gas processing plant construction in the Delaware
Basin is progressing well and is expected to become operational during
the second half of 2020, as planned. Once operational, the 200 MMcf/d
Tiger plant will bring total EnLink processing capacity to over 1
billion cubic feet per day in the Permian.
Louisiana:
-- Segment profit of $67.0 million for the third quarter of 2019 was
approximately 3% higher as compared to the second quarter of 2019 and
roughly flat as compared to the third quarter of 2018. Third quarter
2019 segment profit as compared to the prior quarter and the same period
during 2018 includes the expiration of legacy natural gas transportation
contracts and less favorable economics for natural gas processing.
-- Average natural gas liquids (NGL) fractionation volumes for the third
quarter of 2019 were approximately 3% lower as compared to the second
quarter of 2019, due to a lower ethane composition in the average barrel
from increased industry ethane rejection. Average NGL fractionation
volumes for the third quarter of 2019 increased by approximately 10% as
compared to the third quarter of 2018 as a result of the Cajun-Sibon III
expansion being placed into service during the second quarter of 2019.
-- Average natural gas gathering and transportation volumes for the third
quarter of 2019 were approximately 8% higher as compared to the second
quarter of 2019 and approximately 9% lower as compared to the third
quarter of 2018. Average natural gas processing volumes for the third
quarter of 2019 increased approximately 15% and decreased 10% as
compared to the second quarter of 2019 and the third quarter of 2018,
respectively.
-- EnLink announced commercial success related to the signing of a
long-term natural gas purchase agreement at attractive rates. EnLink
will utilize its existing assets to transport natural gas from northern
Louisiana to Gulf Coast demand markets, with no incremental capital
expenditures.
-- Average crude volumes handled in EnLink's Ohio River Valley operations
for the third quarter of 2019 were approximately 5% higher as compared
to the second quarter of 2019 and increased by 24% as compared to the
third quarter of 2018.
Oklahoma:
-- Segment profit of $109.1 million for the third quarter of 2019 was
approximately 4% lower as compared to the second quarter of 2019 and
roughly flat as compared to the third quarter of 2018. Third quarter
2019 segment profit as compared to the prior quarter and the same period
during 2018 reflects the current commodity price environment and its
impact on fixed recovery contracts.
-- Average natural gas gathering and transportation volumes for the third
quarter of 2019 were approximately 3% higher as compared to the second
quarter of 2019 and approximately 7% higher as compared to the third
quarter of 2018. Average natural gas processing volumes for the third
quarter of 2019 increased approximately 2% and 7% when compared to the
second quarter of 2019 and the third quarter of 2018, respectively.
-- Average crude gathering volumes in the third quarter of 2019 increased
quarter over quarter and year over year. Crude gathering volumes for the
third quarter of 2019 were approximately 10% higher as compared to the
second quarter of 2019 and approximately 250% higher as compared to the
third quarter of 2018 due to the continued ramp of crude gathering
services.
North Texas:
-- Segment profit of $69.4 million for the third quarter of 2019 was
approximately 5% lower as compared to the second quarter of 2019, driven
primarily by contract mix changes. Segment profit for the third quarter
of 2019 was approximately 27% lower as compared to the third quarter of
2018, driven by the expiration of minimum volume commitments (MVC) with
Devon Energy Corp. on December 31, 2018. $22.1 million of MVC payments
were included in the third quarter of 2018 results.
-- Average natural gas gathering, transportation, and processing volumes
for the third quarter of 2019 were roughly flat, as compared to the
second quarter of 2019. Average natural gas gathering and
transportation, and processing volumes for the third quarter of 2019
were approximately 4% lower and 2% higher as compared to the third
quarter of 2018, respectively.
CEO Action Plan
Upon returning to the CEO role in early August 2019, Davis immediately began a comprehensive evaluation of EnLink's business strengths and opportunities in the context of the current evolving energy landscape, in which pressured commodity prices and lower capital spending by producers are reducing activity levels in U.S. supply basins, particularly in Oklahoma.
In terms of strengths, Davis highlighted EnLink's solid financial profile and diversified assets that position the company well for stable cash flow generation and for targeted, attractive growth opportunities. The company is generating strong cash flow - in excess of $1 billion of annual adjusted EBITDA - from its diversified portfolio of assets. The company's strategic growth assets located in the Permian Basin and along the Gulf Coast create opportunities for future growth, and EnLink's leading, scale positions in Oklahoma and North Texas continue to generate significant cash flow and are positioned to benefit from ongoing optimization.
From an opportunities standpoint, Davis and EnLink's executive leadership team have outlined key execution priorities:
-- Enhance the profitability of EnLink's existing business: Enhance margins
by filling available asset capacity, optimize operating efficiency, and
capitalize on opportunities to expand business with customers.
-- Position EnLink to capture long-term opportunities: Pursue attractive
bolt-on opportunities in response to customer needs; expand market share
by leveraging leading platform positions in key supply and demand
markets.
-- Strengthen EnLink's financial position: Execute rigorous capital
allocation process, grow free cash flow, and maintain a strong balance
sheet.
-- Drive organizational efficiency: Optimize costs and efficiencies
companywide and maintain a high level of customer service and safety.
The team has initially identified meaningful opportunities within each priority and expects the execution of the plan will result in aggregate cost reductions, margin enhancements, and commercial wins of up to $75 million for 2020. A number of initiatives are already underway, which will generate significant positive results in the near-term.
2020 Capital Expenditures Outlook
-- Growth capital expenditures, net to EnLink, for full-year 2020 are
projected to range from $275 million to $375 million, representing an
approximate 50% decline as compared to the growth capital expenditures
expected for full-year 2019.
-- EnLink's 2020 growth projects are expected to be focused in the Permian
Basin, representing up to 75% of expected investment, with longer-dated
opportunities under evaluation along the Gulf Coast.
-- The majority of 2020 growth capital expenditures are forecasted to be
well connects, gathering lines and compression additions. Approximately
$60 million to $80 million of 2020 growth capital expenditures will be
invested in the Tiger plant and associated infrastructure construction
in the Delaware Basin, for which the full adjusted EBITDA contribution
will be recognized in 2021.
Third Quarter 2019 Earnings Call Details
EnLink will hold a conference call to discuss third quarter 2019 results on Friday, November 8, at 9 a.m. Central time (10 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 http://dpregister.com/10134790 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 EnLink.com.
About the EnLink Midstream Companies
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 and Other Definitions
This press release contains non-generally accepted accounting principles financial measures that we refer to as adjusted EBITDA, and distributable cash flow available to common unitholders (distributable cash flow). We define adjusted EBITDA as net income (loss) plus net interest expense, income tax expense (benefit), depreciation and amortization expense, impairments, unit-based compensation, (gain) loss on non-cash derivatives, (gain) loss on disposition of assets, loss on secured term loan receivable, successful transaction costs (if any), accretion expense associated with asset retirement obligations, and distributions from unconsolidated affiliate investments less payments under onerous performance obligations, non-controlling interest, income (loss) from unconsolidated affiliate investments, non-cash rent, and non-cash revenue from contract restructuring. We define distributable cash flow as adjusted EBITDA (defined above, net to ENLC), less interest expense, interest rate swaps, current income taxes and other non-distributable cash flows, accrued cash distributions on EnLink Midstream Partners, LP's (ENLK) Series B Cumulative Convertible Preferred Units (the "ENLK Series B Preferred Units") and ENLK's Series C Fixed-to-Floating Rate Cumulative Redeemable Perpetual Preferred Units (the "ENLK Series C Preferred Units") paid or expected to be paid, and maintenance capital expenditures, excluding maintenance capital expenditures that were contributed by other entities and relate to the non-controlling interest share of our consolidated entities.
Distribution coverage is calculated by dividing distributable cash flow by distributions declared to common unitholders.
Growth capital expenditures generally include capital expenditures made for acquisitions or capital improvements that we expect will increase our asset base, operating income or operating capacity over the long-term. Maintenance capital expenditures generally include capital expenditures made to replace partially or fully depreciated assets in order to maintain the existing operating capacity of the assets and to extend their useful lives.
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 achievement is a primary metric used in our short-term incentive program for compensating employees.
Segment profit (loss) is defined as operating income (loss) plus general and administrative expenses, depreciation and amortization, (gain) loss on disposition of assets, impairments, and loss on secured term loan receivable. 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, 2018, and, when available, "Item 1. Financial Statements - Note 14-Segment Information" in ENLC's Quarterly Report on Form 10-Q for the three and nine months ended September 30, 2019, for further information about segment profit (loss).
Adjusted EBITDA and distributable 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.
For a reconciliation of full-year 2019 adjusted EBITDA and DCF guidance discussed in this press release to 2019 net income (loss) guidance, see the revised forward-looking reconciliation in our earnings press release for the second quarter of 2019, issued on August 6, 2019, and also included as an exhibit to ENLC's Current Report on Form 8-K, filed with the Securities and Exchange Commission on August 6, 2019, both of which are available on the Investors' page of EnLink's website at EnLink.com.
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, when additional capacity will be operational, timing for completion of construction or expansion projects, expected financial and operational results associated with certain projects or growth capital expenditures, future operational results of our customers, results in certain basins, future rig count information, future cost savings, profitability, financial metrics, operating efficiencies and other benefits of cost savings or operational initiatives, our future capital structure and credit ratings, 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) 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 the unitholders, (b) 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, (c) 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, (d) the dependence on Devon for a substantial portion of the natural gas and crude that we gather, process, and transport, (e) developments that materially and adversely affect Devon or other customers, (f) adverse developments in the midstream business that may reduce our ability to make distributions, (g) competition for crude oil, condensate, natural gas, and NGL supplies and any decrease in the availability of such commodities, (h) decreases in the volumes that we gather, process, fractionate, or transport, (i) construction risks in our major development projects, (j) our ability to receive or renew required permits and other approvals, (k) changes in the availability and cost of capital, including as a result of a change in our credit rating, (l) operating hazards, natural disasters, weather-related issues or delays, casualty losses, and other matters beyond our control, (m) impairments to goodwill, long-lived assets and equity method investments, and (n) 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 growth 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: Kate Walsh, Vice President of Investor Relations & Tax, 214-721-9696, kate.walsh@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 Nine Months Ended
September 30,
September 30,
2019 2018 2019 2018
Total revenues $
1,408.0 $
2,114.3 $
4,897.2 $
5,640.7
Cost of sales 999.5 1,696.6 3,663.0 4,403.7
Gross operating margin 408.5 417.7 1,234.2 1,237.0
Operating costs and expenses,
excluding cost of sales:
Operating expenses 119.2 114.7 351.6 337.3
General and
administrative 38.5 41.9 122.1 99.8
(Gain) loss on
disposition of assets (3.0) (2.9) 1.3
Depreciation and
amortization 157.3 146.7 463.1 430.1
Impairments - 24.6 186.5 24.6
Loss on secured term
loan receivable - 52.9
Total operating costs
and expenses, excluding
cost of sales 312.0 327.9 1,173.3 893.1
Operating income 96.5 89.8 60.9 343.9
Other income (expense):
Interest expense, net of
interest income (56.6) (45.2) (160.5) (134.3)
Income from
unconsolidated
affiliates 4.0 4.3 14.0 11.7
Other income (expense) (0.1) 0.1 0.1 0.3
Total other expense (52.7) (40.8) (146.4) (122.3)
Income (loss) before
non-controlling
interest and income
taxes 43.8 49.0 (85.5) 221.6
Income tax expense (6.3) (4.0) (2.7) (17.3)
Net income (loss) 37.5 45.0 (88.2) 204.3
Net income attributable
to non-controlling
interest 25.7 37.3 92.4 156.2
Net income (loss)
attributable to ENLC $
11.8 $
7.7 $
(180.6) $
48.1
Net income (loss) attributable to ENLC
per unit:
Basic common unit $
0.02 $
0.04 $
(0.40) $
0.27
Diluted common unit $
0.02 $
0.04 $
(0.40) $
0.26
===
EnLink Midstream, LLC
Reconciliation of Net Income to Adjusted EBITDA
(All amounts in millions)
(Unaudited)
Three Months Ended Nine Months Ended
September 30,
September 30,
2019 2018 2019 2018
Net income (loss) $
37.5 $
45.0 $
(88.2) $
204.3
Interest expense, net
of interest income 56.6 45.2 160.5 134.3
Depreciation and
amortization 157.3 146.7 463.1 430.1
Impairments - 24.6 186.5 24.6
Non-cash revenue from
contract
restructuring (1) - (45.5)
Loss on secured term
loan receivable (1) - 52.9
Income from
unconsolidated
affiliates (4.0) (4.3) (14.0) (11.7)
Distributions from
unconsolidated
affiliates 5.4 5.3 15.5 16.7
(Gain) loss on
disposition of assets (3.0) (2.9) 1.3
Unit-based
compensation 12.1 17.1 31.2 31.8
Income tax expense 6.3 4.0 2.7 17.3
(Gain) loss on non-
cash derivatives 0.5 0.8 (4.7) 14.8
Payments under onerous
performance
obligation offset to
other current and
long-term
liabilities - (4.5) (9.0) (13.5)
Transaction costs (2) - 2.8 13.9 2.8
Other (3) (1.2) (0.3) (0.8) 0.5
Adjusted EBITDA before
non-controlling
interest 267.5 282.4 $
806.7 $
807.8
Non-controlling
interest share of
adjusted EBITDA from
joint ventures (4) (6.3) (6.1) (18.1) (13.8)
Adjusted EBITDA, net
to ENLC $
261.2 $
276.3 $
788.6 $
794.0
===
____________________________
(1) In May 2018, we restructured our natural gas gathering and
processing contract with White Star, and, as a result,
recognized non-cash revenue representing the discounted present
value of a secured term loan receivable granted to us by White
Star. In late May 2019, White Star, the counterparty to our
$58.0 million second lien secured term loan receivable,
defaulted on its approximately $10 million installment payment
under the term loan and filed for reorganization under Chapter
11 of the U.S. Bankruptcy Code. We do not believe that it is
probable that White Star will be able to repay the outstanding
amounts owed to us under the second lien secured term loan.
(2) Represents transaction costs primarily attributable to costs
incurred related to the acquisition of all outstanding,
publicly-held ENLK common units in January 2019 and costs we
incurred related to the acquisition by GIP of equity interests
in ENLK, ENLC, and the managing member of ENLC previously held
by subsidiaries of Devon Energy Corporation (the "GIP
Transaction") in July 2018.
(3) Includes accretion expense associated with asset retirement
obligations and non-cash rent, which relates to lease
incentives pro-rated over the lease term.
(4) Non-controlling interest share of adjusted EBITDA from joint
ventures includes NGP Natural Resources XI, L.P.'s ("NGP") 49.9%
share of adjusted EBITDA from the Delaware Basin JV, Marathon
Petroleum Corporation's 50% share of adjusted EBITDA from the
Ascension JV, and other minor non-controlling interests.
EnLink Midstream, LLC
Reconciliation of Net Cash Provided by Operating Activities to Adjusted EBITDA
and Distributable Cash Flow
(All amounts in millions except ratios and per unit amounts)
(Unaudited)
Three Months Nine Months
Ended Ended
September
30,
September
30,
2019 2019
Net cash provided
by operating
activities $
256.0 $
777.5
Interest expense
(1) 55.8 159.2
Current income tax
expense 0.7 2.0
Transaction costs
(2) - 13.9
Other (3) (1.6) (1.5)
Changes in operating assets and
liabilities which (provided)
used cash:
Accounts
receivable,
accrued revenues,
inventories, and
other (78.0) (341.3)
Accounts payable,
accrued product
purchases, and
other accrued
liabilities (4) 34.6 196.9
Adjusted EBITDA
before non-
controlling
interest 267.5 806.7
Non-controlling
interest share of
adjusted EBITDA
from joint
ventures (5) (6.3) (18.1)
Adjusted EBITDA,
net to ENLC 261.2 788.6
Interest expense,
net of interest
income (56.6) (160.5)
Current taxes and
other (0.6) (4.1)
Maintenance capital
expenditures, net
to ENLC (6) (12.7) (34.4)
ENLK preferred unit
accrued cash
distributions (7) (23.1) (68.9)
Distributable cash
flow $
168.2 $
520.7
Actual declared
distribution to
common unitholders $
139.2 $
415.8
Distribution
coverage 1.21x 1.25x
Distributions
declared per ENLC
unit $
0.283 $
0.845
____________________________
(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) Represents transaction costs primarily attributable to costs
incurred related to the acquisition of all outstanding, publicly-
held ENLK common units in January 2019.
(3) Includes accruals for settled commodity swap transactions,
distributions received from equity method investments to the
extent those distributions exceed earnings from the investment,
and non-cash rent, which relates to lease incentives pro-rated
over the lease term.
(4) Net of payments under onerous performance obligation offset to
other current and long-term liabilities.
(5) Non-controlling interest share of adjusted EBITDA from joint
ventures includes NGP's 49.9% share of adjusted EBITDA from the
Delaware Basin JV, Marathon Petroleum Corporation's 50% share of
adjusted EBITDA from the Ascension JV, and other minor non-
controlling interests.
(6) Excludes maintenance capital expenditures that were 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 of $17.1
million and $6.0 million, respectively, for the three months
ended September 30, 2019, and cash distributions earned by the
ENLK Series B Preferred Units and ENLK Series C Preferred Units
of $50.9 million and $18.0 million, respectively, for the nine
months ended September 30, 2019. 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.
Distributable cash flow is not presented for the three and nine months ended September 30, 2018, because distributable cash flow was not used as a supplemental liquidity measure by ENLC during 2018. ENLC began using distributable cash flow as a supplemental liquidity measure in 2019 as a result of the simplification of our corporate structure in the Merger.
EnLink Midstream, LLC
Operating Data
(Unaudited)
Three Months Ended Nine Months Ended
September 30, September 30,
2019 2018 2019 2018
Midstream Volumes:
Permian Segment
Gathering and
Transportation (MMBtu/
d) 751,400 557,100 695,300 498,000
Processing (MMBtu/d) 798,200 566,200 745,100 512,900
Crude Oil Handling (Bbls/
d) 112,900 131,700 135,000 119,900
North Texas Segment
Gathering and
Transportation (MMBtu/
d) 1,644,300 1,710,200 1,658,000 1,741,100
Processing (MMBtu/d) 760,700 744,600 753,600 750,200
Oklahoma Segment
Gathering and
Transportation (MMBtu/
d) 1,351,800 1,259,700 1,304,100 1,181,800
Processing (MMBtu/d) 1,323,100 1,239,000 1,284,800 1,170,300
Crude Oil Handling (Bbls/
d) 59,600 17,400 47,600 12,900
Louisiana Segment
Gathering and
Transportation (MMBtu/
d) 2,078,500 2,273,700 2,025,000 2,197,100
Processing (MMBtu/d) 385,500 429,200 396,600 422,200
Crude Oil Handling (Bbls/
d) 21,200 17,200 18,800 14,800
NGL Fractionation (Gals/
d) 7,240,100 6,545,100 7,231,400 6,457,000
Brine Disposal (Bbls/d) 2,500 3,300 3,100 3,200
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SOURCE EnLink Midstream, LLC
