Market Overview

Enable Midstream Announces Second Quarter 2017 Financial Results, Quarterly Distributions and Recontracting of a Key Firm Transportation Agreement

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  • 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.

 

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