Enable Midstream Announces Second Quarter 2017 Financial Results, Quarterly Distributions and Recontracting of a Key Firm
Transportation Agreement
- Increases in total revenues, net income attributable to limited partners, net income attributable to
common and subordinated units, gross margin, Adjusted EBITDA and distributable cash flow (DCF) for second quarter 2017 compared
to second quarter 2016
- Increases in natural gas gathered and processed volumes for second quarter 2017 compared to second
quarter 2016
- All-time high for quarterly natural gas processed volumes, supported by 44 active rigs drilling wells
expected to be connected to Enable's gathering systems
- Quarterly cash distributions of $0.318 per unit on all outstanding common and subordinated units and
$0.625 on all Series A Preferred Units
- Recontracted with a key electric utility customer for firm intrastate transportation service
Enable Midstream Partners, LP (NYSE: ENBL) (Enable) today announced second quarter 2017 financial results, quarterly
distributions and recontracting of firm intrastate transportation capacity.
Net income attributable to limited partners was $95 million for second quarter 2017, an increase of $56 million compared to $39
million for second quarter 2016. Net income attributable to common and subordinated units was $86 million for second quarter 2017,
an increase of $51 million compared to $35 million for second quarter 2016. The increase in both net income attributable to limited
partners and net income attributable to common and subordinated units was primarily related to higher gross margin, partially
offset by higher interest expense and higher depreciation and amortization expense. The increase in net income attributable to
common and subordinated units was also partially offset by the prorated distributions on the Series A Preferred Units that were
recognized in second quarter 2016 income.
Enable uses derivatives to manage commodity price risk, and the gain or loss associated with these derivatives is recognized in
earnings. Enable’s net income attributable to limited partners and to common and subordinated units for second quarter 2017
includes a $9 million gain on derivative activity, an increase of $43 million compared to a $34 million loss on derivative activity
for second quarter 2016. The increase of $43 million is comprised of an increase related to the change in fair value of derivatives
of $50 million and a decrease in realized gains on derivatives of $7 million. Additional details on derivative instruments and
hedging activities can be found in Enable’s second quarter 2017 Form 10-Q.
Adjusted EBITDA for second quarter 2017 was $215 million, an increase of $19 million compared to $196 million for second quarter
2016. The increase in Adjusted EBITDA was primarily a result of higher gross margin after adjusting for non-cash items.
DCF for second quarter 2017 was $156 million, an increase of $12 million compared to $144 million for second quarter 2016. The
increase in DCF was primarily a result of higher Adjusted EBITDA, partially offset by higher Adjusted interest expense.
Adjusted EBITDA, DCF and Adjusted interest expense are non-GAAP financial measures, and this press release provides a
reconciliation of these non-GAAP financial measures to the most directly comparable GAAP financial measures.
RECONTRACTED FIRM TRANSPORTATION SERVICE
In July, Enable Oklahoma Intrastate Transmission, LLC (EOIT) recontracted with a key electric utility customer for firm
intrastate transportation service with similar terms through 2020. Also in July, Enable recontracted approximately 30,000 dekatherm
per day (Dth/d) of firm interstate transportation capacity through the first quarter of 2021 with a utility customer on Enable Gas
Transmission, LLC (EGT). These contract extensions further support Enable’s significant firm, fee-based margins with high-quality
customers.
MANAGEMENT PERSPECTIVE
“Enable is on track for another great year in 2017,” said Enable Midstream President and CEO Rod Sailor. “The second quarter
marked our sixth consecutive quarter of per-day natural gas gathered volume growth and a record-high quarter for natural gas
processed volumes. This growth was driven by the highest level of producer rig activity on our system that we have reported in over
two years.
“We achieved this growth by leveraging our significant scale and previous capital investments while demonstrating cost
discipline. Going forward, we will continue to focus on capital-efficient growth opportunities and providing creative, timely and
cost-effective solutions for our customers.”
QUARTERLY DISTRIBUTIONS AND CONVERSION OF SUBORDINATED UNITS TO COMMON UNITS
The Board of Directors of Enable’s general partner declared a quarterly cash distribution of $0.318 per unit on all outstanding
common and subordinated units for the quarter ended June 30, 2017. The distribution is unchanged from the previous quarter.
The quarterly cash distribution of $0.318 per unit on all outstanding common and subordinated units will be paid on August 29,
2017, to unitholders of record at the close of business on August 22, 2017.
The board also declared a quarterly cash distribution of $0.625 on all Series A Preferred Units for the quarter ended
June 30, 2017. The quarterly cash distribution of $0.625 on all Series A Preferred Units outstanding will be paid on
August 14, 2017, to unitholders of record at the close of business on July 31, 2017.
Upon the payment of the second quarter distribution, the financial tests will have been met for the termination of the
subordination period for the subordinated units held by Enable's sponsors CenterPoint Energy, Inc. and OGE Energy Corp.
Accordingly, the subordinated units will convert to common units on a one-for-one basis effective August 30, 2017, the first
business day following the payment of the second quarter distribution.
BUSINESS HIGHLIGHTS
In the gathering and processing segment, per-day natural gas gathered volumes in the Anadarko and Ark-La-Tex Basins grew for the
sixth consecutive quarter as a result of continued commercial success and continued rig activity on Enable's gas gathering and
processing systems in these basins. As of July 31, 2017, there were 44 active rigs across Enable's footprint that were drilling
wells to be connected to Enable's gathering systems, representing an increase of approximately 38 percent compared to February 1,
2017. Thirty-one of those rigs were in the Anadarko Basin, and 9 were in the Ark-La-Tex Basin. Enable's Arkoma Basin and Williston
Basin footprints had 3 rigs and 1 rig, respectively.
Enable's transportation and storage segment continues to provide significant, fee-based revenues and represents over 40 percent
of Enable's 2017 year-to-date gross margin. In the second quarter of 2017, EGT recontracted a firm, fee-based interstate natural
gas transportation service agreement through the second quarter of 2019 with XTO Energy, Inc. for 170,000 Dth/d, which partially
offsets a reduction in firm transportation services between Carthage, Texas, and Perryville, Louisiana. In addition, intrastate
transportation deliveries continue to grow as a result of growing supply in the Anadarko Basin, including growth from the SCOOP and
STACK plays.
KEY OPERATING STATISTICS
Natural gas gathered volumes were 3.31 trillion British thermal units per day (TBtu/d) for second quarter 2017, an increase of 7
percent compared to 3.10 TBtu/d for second quarter 2016. The increase was primarily due to higher gathered volumes in the Anadarko
and Ark-La-Tex Basins, partially offset by lower gathered volumes in the Arkoma Basin.
Natural gas processed volumes were 1.91 TBtu/d for second quarter 2017, an increase of 9 percent compared to 1.76 TBtu/d for
second quarter 2016. The increase was primarily due to higher processed volumes in the Anadarko and Ark-La-Tex Basins, partially
offset by lower processed volumes in the Arkoma Basin.
NGLs produced were 87.12 thousand barrels per day (MBbl/d) for second quarter 2017, an increase of 5 percent compared to 83.09
MBbl/d for second quarter 2016. The increase was primarily due to higher NGL production in the Anadarko Basin, partially offset by
NGL production declines in the Arkoma Basin.
Crude oil gathered volumes were 23.20 MBbl/d for second quarter 2017, a decrease of 2.32 MBbl/d compared to 25.52 MBbl/d for
second quarter 2016. The decrease was primarily due to natural declines and producer well shut-ins while completing new wells.
Interstate transportation firm contracted capacity was 6.21 billion cubic feet per day (Bcf/d) for second quarter 2017, a
decrease of 11 percent compared to 6.95 Bcf/d for second quarter 2016. The decrease was primarily due to lower contracted firm
transportation volumes between Carthage, Texas, and Perryville, Louisiana.
Intrastate transportation average deliveries were 1.84 TBtu/d for second quarter 2017, an increase of 7 percent compared to 1.72
TBtu/d for second quarter 2016. The increase was primarily related to increased supply in the Anadarko Basin.
SECOND QUARTER FINANCIAL PERFORMANCE
Revenues were $626 million for second quarter 2017, an increase of $97 million compared to $529 million for second quarter 2016.
Revenues included $117 million of intercompany eliminations for second quarter 2017 and $83 million of intercompany eliminations
for second quarter 2016.
- Gathering and processing segment revenues were $480 million for second quarter 2017, an increase of
$93 million compared to $387 million for second quarter 2016. The increase in gathering and processing segment revenues was
primarily due to an increase in revenues from NGL sales resulting from higher average NGL prices, an increase in revenues from
sales of natural gas as a result of higher average natural gas prices, an increase in revenue from changes to the fair value of
condensate and NGL derivatives, an increase in processing service revenues resulting from higher processed volumes and a
percentage-of-proceeds contract that was converted to a fee-based contract in the second half of 2016 and an increase in natural
gas gathering revenues due to higher fees and gathered volumes in the Anadarko and Ark-La-Tex Basins.
- Transportation and storage segment revenues were $263 million for second quarter 2017, an increase of
$38 million compared to $225 million for second quarter 2016. The increase in transportation and storage segment revenues was
primarily due to an increase in revenues from changes in the fair value of natural gas derivatives, an increase in revenues from
natural gas sales associated with higher sales volumes and higher average sales prices and an increase in revenues from
off-system transportation. These increases were partially offset by realized losses on natural gas derivatives as compared to
realized gains in 2016 and a decrease in firm transportation revenues between Carthage, Texas, and Perryville, Louisiana.
Gross margin was $347 million for second quarter 2017, an increase of $72 million compared to $275 million for second quarter
2017.
- Gathering and processing segment gross margin was $211 million for second quarter 2017, an increase
of $55 million compared to $156 million for second quarter 2016. The increase in gathering and processing segment gross margin
was primarily due to an increase in natural gas sales due to higher average natural gas prices and higher volumes in the Anadarko
and Ark-La-Tex Basins, an increase in gross margin from changes in the fair value of condensate and NGL derivatives, an increase
in processing margins resulting from higher average NGL prices and higher processed volumes in the Anadarko Basin, an increase in
gathering margin due to increased gathered volumes in the Anadarko and Ark-La-Tex Basins and an increase in margin associated
with the annual fuel rate determination.
- Transportation and storage segment gross margin was $136 million for second quarter 2017, an increase
of $17 million compared to $119 million for second quarter 2016. The increase in transportation and storage segment gross margin
was primarily due to an increase in gross margin from changes in the fair value of natural gas derivatives, partially offset by a
decrease in system management activities, realized losses on natural gas derivatives as compared to realized gains in 2016 and a
decrease in firm transportation gross margin between Carthage, Texas, and Perryville, Louisiana.
Operation and maintenance and general and administrative expenses were $120 million for second quarter 2017, which is flat
compared to second quarter 2016.
Depreciation and amortization expense was $89 million for second quarter 2017, an increase of $6 million compared to $83 million
for second quarter 2016. The increase in depreciation and amortization expense was primarily a result of additional assets placed
in service.
Taxes other than income taxes were $16 million for second quarter 2017, an increase of $1 million compared to $15 million for
second quarter 2016. The increase was primarily a result of higher accrued ad valorem taxes due to additional assets placed in
service.
Interest expense was $31 million for second quarter 2017, an increase of $6 million compared to $25 million for second quarter
2016. The increase was primarily due to higher interest rates on outstanding debt as a result of a long-term debt issuance in first
quarter 2017 that resulted in the repayment of amounts outstanding under Enable's revolving credit facility.
Capital expenditures were $87 million for second quarter 2017, compared to $91 million for second quarter 2016. Expansion
capital expenditures were $70 million for second quarter 2017, compared to $74 million for second quarter 2016. Maintenance capital
expenditures were $17 million for second quarter 2017, compared to $17 million for second quarter 2016.
EARNINGS CONFERENCE CALL AND WEBCAST
A conference call discussing second quarter results is scheduled today at 10 a.m. Eastern. The dial-in number to access the
conference call is 888-632-3382 and the conference call ID is ENBLQ217. Investors may also listen to the call via Enable’s website
at http://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).
Any materials Enable files with the SEC are available to read and copy at the SEC’s Public Reference Room at 100 F Street, N.E.,
Washington, D.C. 20549. Please call the SEC at 1-800-732-0330 for further information on their Public Reference Room. Enable’s SEC
filings are also available at the SEC’s website at http://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 http://www.enablemidstream.com. On the investor relations tab of Enable’s website, http://investors.enablemidstream.com, Enable makes available free of charge a variety of information to
investors. Enable’s goal is to maintain the investor relations tab 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 report 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 12,900 miles of gathering pipelines, 14 major processing plants with approximately 2.5 Bcf/d of processing
capacity, approximately 7,800 miles of interstate pipelines (including Southeast Supply Header, LLC of which Enable owns 50
percent), approximately 2,200 miles of intrastate pipelines and eight storage facilities comprising 85.0 billion cubic feet of
storage capacity. For more information, visit http://www.enablemidstream.com.
NON-GAAP FINANCIAL MEASURES
Enable has included the non-GAAP financial measures Gross margin, Adjusted EBITDA, Adjusted interest expense, DCF and
distribution coverage ratio in this press release based on information in its condensed consolidated financial statements.
Gross margin, Adjusted EBITDA, Adjusted interest expense, DCF 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,
Adjusted interest expense, DCF and distribution coverage ratio provides information useful to investors in assessing its financial
condition and results of operations. Gross margin, Adjusted EBITDA, Adjusted interest expense, DCF 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, Adjusted
interest expense, DCF 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, Adjusted
interest expense, DCF 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, 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, the termination of the subordination period and
anticipated financial and operational performance, including revenue projections, capital expenditures and tax position.
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 and in
our Annual Report on Form 10-K for the year ended December 31, 2016. Those risk factors and other factors noted throughout
this press release and in our 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. You should also
understand that it is not possible to predict or identify all such factors and should not consider the following list to be a
complete statement of all potential risks and uncertainties.
|
|
|
|
|
| ENABLE MIDSTREAM PARTNERS, LP |
| CONDENSED CONSOLIDATED STATEMENTS OF INCOME |
|
(unaudited)
|
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
|
|
(In millions, except per unit data) |
| Revenues (including revenues from affiliates): |
|
|
|
|
|
|
|
|
| Product sales |
|
$ |
354 |
|
|
$ |
266 |
|
|
$ |
740 |
|
|
$ |
511 |
|
| Service revenue |
|
272 |
|
|
263 |
|
|
552 |
|
|
527 |
|
| Total Revenues |
|
626 |
|
|
529 |
|
|
1,292 |
|
|
1,038 |
|
| Cost and Expenses (including expenses from affiliates): |
|
|
|
|
|
|
|
|
| Cost of natural gas and natural gas liquids (excluding depreciation and amortization
shown separately) |
|
279 |
|
|
254 |
|
|
587 |
|
|
449 |
|
| Operation and maintenance |
|
97 |
|
|
93 |
|
|
186 |
|
|
188 |
|
| General and administrative |
|
23 |
|
|
27 |
|
|
48 |
|
|
47 |
|
| Depreciation and amortization |
|
89 |
|
|
83 |
|
|
177 |
|
|
164 |
|
| Taxes other than income taxes |
|
16 |
|
|
15 |
|
|
32 |
|
|
30 |
|
| Total Cost and Expenses |
|
504 |
|
|
472 |
|
|
1,030 |
|
|
878 |
|
| Operating Income |
|
122 |
|
|
57 |
|
|
262 |
|
|
160 |
|
| Other Income (Expense): |
|
|
|
|
|
|
|
|
| Interest expense (including expenses from affiliates) |
|
(31 |
) |
|
(25 |
) |
|
(58 |
) |
|
(48 |
) |
| Equity in earnings of equity method affiliate |
|
7 |
|
|
7 |
|
|
14 |
|
|
14 |
|
| Other, net |
|
(1 |
) |
|
— |
|
|
— |
|
|
— |
|
| Total Other Expense |
|
(25 |
) |
|
(18 |
) |
|
(44 |
) |
|
(34 |
) |
| Income Before Income Taxes |
|
97 |
|
|
39 |
|
|
218 |
|
|
126 |
|
| Income tax expense |
|
1 |
|
|
— |
|
|
2 |
|
|
1 |
|
| Net Income |
|
$ |
96 |
|
|
$ |
39 |
|
|
$ |
216 |
|
|
$ |
125 |
|
| Less: Net income attributable to noncontrolling interest |
|
1 |
|
|
— |
|
|
1 |
|
|
— |
|
| Net Income Attributable to Limited Partners |
|
$ |
95 |
|
|
$ |
39 |
|
|
$ |
215 |
|
|
$ |
125 |
|
| Less: Series A Preferred Unit distributions |
|
9 |
|
|
4 |
|
|
18 |
|
|
4 |
|
| Net Income Attributable to Common and Subordinated Units |
|
$ |
86 |
|
|
$ |
35 |
|
|
$ |
197 |
|
|
$ |
121 |
|
|
|
|
|
|
|
|
|
|
| Basic earnings per unit |
|
|
|
|
|
|
|
|
| Common units |
|
$ |
0.20 |
|
|
$ |
0.08 |
|
|
$ |
0.45 |
|
|
$ |
0.29 |
|
| Subordinated units |
|
$ |
0.20 |
|
|
$ |
0.08 |
|
|
$ |
0.46 |
|
|
$ |
0.29 |
|
| Diluted earnings per unit |
|
|
|
|
|
|
|
|
| Common units |
|
$ |
0.20 |
|
|
$ |
0.08 |
|
|
$ |
0.45 |
|
|
$ |
0.28 |
|
| Subordinated units |
|
$ |
0.20 |
|
|
$ |
0.08 |
|
|
$ |
0.46 |
|
|
$ |
0.29 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ENABLE MIDSTREAM PARTNERS, LP |
| RECONCILIATION OF NON-GAAP FINANCIAL MEASURES |
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
|
|
(In millions) |
| Reconciliation of Gross margin to Total Revenues: |
|
|
|
|
|
|
|
|
| Consolidated |
|
|
|
|
|
|
|
|
| Product sales |
|
$ |
354 |
|
|
$ |
266 |
|
|
$ |
740 |
|
|
$ |
511 |
| Service revenue |
|
272 |
|
|
263 |
|
|
552 |
|
|
527 |
| Total Revenues |
|
626 |
|
|
529 |
|
|
1,292 |
|
|
1,038 |
| Cost of natural gas and natural gas liquids (excluding depreciation and
amortization) |
|
279 |
|
|
254 |
|
|
587 |
|
|
449 |
| Gross margin |
|
$ |
347 |
|
|
$ |
275 |
|
|
$ |
705 |
|
|
$ |
589 |
|
|
|
|
|
|
|
|
|
| Reportable Segments |
|
|
|
|
|
|
|
|
| Gathering and Processing |
|
|
|
|
|
|
|
|
| Product sales |
|
$ |
336 |
|
|
$ |
256 |
|
|
$ |
687 |
|
|
$ |
464 |
| Service revenue |
|
144 |
|
|
131 |
|
|
284 |
|
|
256 |
| Total Revenues |
|
480 |
|
|
387 |
|
|
971 |
|
|
720 |
| Cost of natural gas and natural gas liquids (excluding depreciation and
amortization) |
|
269 |
|
|
231 |
|
|
555 |
|
|
396 |
| Gross margin |
|
$ |
211 |
|
|
$ |
156 |
|
|
$ |
416 |
|
|
$ |
324 |
|
|
|
|
|
|
|
|
|
| Transportation and Storage |
|
|
|
|
|
|
|
|
| Product sales |
|
$ |
134 |
|
|
$ |
92 |
|
|
$ |
287 |
|
|
$ |
198 |
| Service revenue |
|
129 |
|
|
133 |
|
|
270 |
|
|
273 |
| Total Revenues |
|
263 |
|
|
225 |
|
|
557 |
|
|
471 |
| Cost of natural gas and natural gas liquids (excluding depreciation and
amortization) |
|
127 |
|
|
106 |
|
|
267 |
|
|
205 |
| Gross margin |
|
$ |
136 |
|
|
$ |
119 |
|
|
$ |
290 |
|
|
$ |
266 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
|
|
(In millions, except Distribution coverage
ratio) |
| Reconciliation of Adjusted EBITDA and DCF to net income attributable to limited
partners and calculation of Distribution coverage ratio: |
|
|
|
|
|
|
|
|
| Net income attributable to limited partners |
|
$ |
95 |
|
|
$ |
39 |
|
|
$ |
215 |
|
|
$ |
125 |
|
| Depreciation and amortization expense |
|
89 |
|
|
83 |
|
|
177 |
|
|
164 |
|
| Interest expense, net of interest income |
|
31 |
|
|
25 |
|
|
58 |
|
|
48 |
|
| Income tax expense |
|
1 |
|
|
— |
|
|
2 |
|
|
1 |
|
| Distributions received from equity method affiliate in excess of equity earnings |
|
1 |
|
|
— |
|
|
5 |
|
|
13 |
|
| Non-cash equity-based compensation |
|
4 |
|
|
3 |
|
|
8 |
|
|
5 |
|
| Change in fair value of derivatives |
|
(11 |
) |
|
39 |
|
|
(35 |
) |
|
47 |
|
| Other non-cash losses(1) |
|
5 |
|
|
7 |
|
|
6 |
|
|
8 |
|
| Adjusted EBITDA |
|
$ |
215 |
|
|
$ |
196 |
|
|
$ |
436 |
|
|
$ |
411 |
|
| Series A Preferred Unit distributions(2) |
|
(9 |
) |
|
(9 |
) |
|
(18 |
) |
|
(13 |
) |
| Distributions for phantom and performance units |
|
(1 |
) |
|
— |
|
|
(1 |
) |
|
— |
|
| Adjusted interest expense(3) |
|
(32 |
) |
|
(26 |
) |
|
(59 |
) |
|
(49 |
) |
| Maintenance capital expenditures |
|
(17 |
) |
|
(17 |
) |
|
(31 |
) |
|
(30 |
) |
| Current income taxes |
|
— |
|
|
— |
|
|
— |
|
|
(1 |
) |
| DCF |
|
$ |
156 |
|
|
$ |
144 |
|
|
$ |
327 |
|
|
$ |
318 |
|
|
|
|
|
|
|
|
|
|
| Distributions related to common and subordinated
unitholders(4) |
|
$ |
138 |
|
|
$ |
134 |
|
|
$ |
275 |
|
|
$ |
268 |
|
|
|
|
|
|
|
|
|
|
| Distribution coverage ratio |
|
1.13 |
|
|
1.07 |
|
|
1.19 |
|
|
1.18 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ____________________ |
| (1) |
|
Other non-cash losses includes loss on sale of assets and write-downs of materials
and supplies. |
| (2) |
|
This amount represents the quarterly cash distributions on the Series A Preferred
Units declared for the three and six months ended June 30, 2017 and 2016. The six months ended June 30, 2016 amount includes
the prorated quarterly cash distribution on the Series A preferred Units declared on April 26, 2016. 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. |
| (3) |
|
See below for a reconciliation of Adjusted interest expense to Interest expense. |
| (4) |
|
Represents cash distributions declared for common and subordinated units outstanding
as of each respective period. Amounts for 2017 reflect estimated cash distributions for common and subordinated units
outstanding for the quarter ended June 30, 2017. |
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
|
|
(In millions) |
| Reconciliation of Adjusted EBITDA to net cash provided by operating
activities: |
|
|
|
|
|
|
|
|
| Net cash provided by operating activities |
|
$ |
226 |
|
|
$ |
172 |
|
|
$ |
382 |
|
|
$ |
289 |
|
| Interest expense, net of interest income |
|
31 |
|
|
25 |
|
|
58 |
|
|
48 |
|
| Net income attributable to noncontrolling interest |
|
(1 |
) |
|
— |
|
|
(1 |
) |
|
— |
|
| Income tax expense |
|
1 |
|
|
— |
|
|
2 |
|
|
1 |
|
| Deferred income tax expense |
|
(1 |
) |
|
— |
|
|
(2 |
) |
|
— |
|
| Other non-cash items(1) |
|
1 |
|
|
1 |
|
|
2 |
|
|
2 |
|
| Changes in operating working capital which (provided) used cash: |
|
|
|
|
|
|
|
|
| Accounts receivable |
|
(18 |
) |
|
2 |
|
|
(28 |
) |
|
(22 |
) |
| Accounts payable |
|
(9 |
) |
|
(3 |
) |
|
46 |
|
|
84 |
|
| Other, including changes in noncurrent assets and liabilities |
|
(5 |
) |
|
(40 |
) |
|
7 |
|
|
(51 |
) |
| Return of investment in equity method affiliate |
|
1 |
|
|
— |
|
|
5 |
|
|
13 |
|
| Change in fair value of derivatives |
|
(11 |
) |
|
39 |
|
|
(35 |
) |
|
47 |
|
| Adjusted EBITDA |
|
$ |
215 |
|
|
$ |
196 |
|
|
$ |
436 |
|
|
$ |
411 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ____________________ |
| (1) |
|
Other non-cash items includes amortization of debt expense, discount and premium on
long-term debt and write-downs of materials and supplies. |
|
|
|
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
|
|
(In millions) |
| Reconciliation of Adjusted interest expense to Interest expense: |
|
|
|
|
|
|
|
|
| Interest Expense |
|
$ |
31 |
|
|
$ |
25 |
|
|
$ |
58 |
|
|
$ |
48 |
|
| Amortization of premium on long-term debt |
|
2 |
|
|
1 |
|
|
3 |
|
|
3 |
|
| Capitalized interest on expansion capital |
|
— |
|
|
1 |
|
|
— |
|
|
1 |
|
| Amortization of debt expense and discount |
|
(1 |
) |
|
(1 |
) |
|
(2 |
) |
|
(3 |
) |
| Adjusted interest expense |
|
$ |
32 |
|
|
$ |
26 |
|
|
$ |
59 |
|
|
$ |
49 |
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
|
| ENABLE MIDSTREAM PARTNERS, LP |
| OPERATING DATA |
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
|
June 30, |
|
June 30, |
|
|
2017 |
|
2016 |
|
2017 |
|
2016 |
| Operating Data: |
|
|
| Gathered volumes—TBtu |
|
301 |
|
|
282 |
|
|
597 |
|
|
560 |
| Gathered volumes—TBtu/d |
|
3.31 |
|
|
3.10 |
|
|
3.30 |
|
|
3.07 |
| Natural gas processed volumes—TBtu |
|
174 |
|
|
161 |
|
|
342 |
|
|
323 |
| Natural gas processed volumes—TBtu/d |
|
1.91 |
|
|
1.76 |
|
|
1.89 |
|
|
1.78 |
| NGLs produced—MBbl/d(1) |
|
87.12 |
|
|
83.09 |
|
|
83.46 |
|
|
78.36 |
| NGLs sold—MBbl/d(1)(2) |
|
86.51 |
|
|
83.80 |
|
|
82.61 |
|
|
80.15 |
| Condensate sold—MBbl/d |
|
5.04 |
|
|
6.08 |
|
|
5.26 |
|
|
6.26 |
| Crude Oil—Gathered volumes—MBbl/d |
|
23.20 |
|
|
25.52 |
|
|
22.19 |
|
|
27.18 |
| Transported volumes—TBtu |
|
445 |
|
|
446 |
|
|
938 |
|
|
911 |
| Transported volumes—TBtu/d |
|
4.86 |
|
|
4.87 |
|
|
5.17 |
|
|
4.99 |
| Interstate firm contracted capacity—Bcf/d |
|
6.21 |
|
|
6.95 |
|
|
6.72 |
|
|
7.06 |
| Intrastate average deliveries—TBtu/d |
|
1.84 |
|
|
1.72 |
|
|
1.84 |
|
|
1.70 |
|
|
|
|
|
|
|
|
|
|
|
|
| _____________________ |
| (1) |
|
Excludes condensate. |
| (2) |
|
NGLs sold includes volumes of NGLs withdrawn from inventory or purchased for system
balancing purposes. |
|
|
|
|
|
|
|
|
Three Months Ended |
|
Six Months Ended |
|
June 30, |
|
June 30, |
|
2017 |
|
2016 |
|
2017 |
|
2016 |
| Anadarko |
|
|
|
|
|
|
|
| Gathered volumes—TBtu/d |
1.78 |
|
|
1.62 |
|
|
1.77 |
|
|
1.62 |
| Natural gas processed volumes—TBtu/d |
1.58 |
|
|
1.44 |
|
|
1.56 |
|
|
1.43 |
| NGLs produced—MBbl/d(1) |
74.14 |
|
|
69.64 |
|
|
70.74 |
|
|
64.17 |
| Arkoma |
|
|
|
|
|
|
|
| Gathered volumes—TBtu/d |
0.54 |
|
|
0.65 |
|
|
0.55 |
|
|
0.63 |
| Natural gas processed volumes—TBtu/d |
0.09 |
|
|
0.10 |
|
|
0.09 |
|
|
0.10 |
| NGLs produced—MBbl/d(1) |
4.60 |
|
|
5.03 |
|
|
4.72 |
|
|
5.01 |
| Ark-La-Tex |
|
|
|
|
|
|
|
| Gathered volumes—TBtu/d |
0.99 |
|
|
0.83 |
|
|
0.98 |
|
|
0.82 |
| Natural gas processed volumes—TBtu/d |
0.24 |
|
|
0.22 |
|
|
0.24 |
|
|
0.25 |
| NGLs produced—MBbl/d(1) |
8.38 |
|
|
8.42 |
|
|
8.00 |
|
|
9.18 |
|
_____________________
|
|
|
|
|
|
|
|
|
|
|
|
(1) Excludes condensate.
|
| |
Enable Midstream Partners, LP
Media
David Klaassen, 405-553-6431
or
Investors
Matt Beasley, 405-558-4600
View source version on businesswire.com: http://www.businesswire.com/news/home/20170801005637/en/