THE WOODLANDS, Texas,
May 4, 2017 /PRNewswire/ --
- First quarter 2017 net loss of $0.6
million
- First quarter 2017 adjusted EBITDA of $71.4 million and DCF of $53.0 million
- First quarter 2017 distribution coverage ratio was 1.19x
- Rig count increased significantly across SMLP's systems
- SMLP reaffirms full year 2017 adjusted EBITDA guidance of
$295.0 million to $315.0 million,
with an annualized fourth quarter 2017 run rate between
$325.0 million and $345.0
million
Summit Midstream Partners, LP (NYSE: SMLP) announced today its
financial and operating results for the three months ended
March 31, 2017. SMLP reported a
net loss of $0.6 million for the
first quarter of 2017 compared to a net loss of $3.7 million for the prior-year period. Net
cash provided by operations totaled $62.4
million in the first quarter of 2017 compared to
$66.8 million in the prior-year
period. Adjusted EBITDA totaled $71.4
million and distributable cash flow totaled $53.0 million for the first quarter of 2017
compared to $70.0 million and
$51.5 million, respectively, for the
prior-year period.
Natural gas volume throughput averaged 1,627 million cubic feet
per day ("MMcf/d") in the first quarter of 2017, an increase of
6.8% compared to 1,523 MMcf/d in the prior-year period, and an
increase of 8.2% compared to 1,504 MMcf/d in the fourth quarter of
2016. Crude oil and produced water volume throughput in the
first quarter of 2017 averaged 76.4 thousand barrels per day
("Mbbl/d"), a decrease of 19.6% compared to 95.0 Mbbl/d in the
prior-year period, and a decrease of 7.2% compared to 82.3 Mbbl/d
in the fourth quarter of 2016. SMLP's natural gas volume
throughput metrics exclude its proportionate share of volume
throughput from its 40% ownership interest in Ohio Gathering.
Steve Newby, President and Chief
Executive Officer, commented, "SMLP's first quarter 2017 financial
and operating results correspond with our expectations and full
year 2017 financial guidance. Over the last several months,
drilling activity has increased significantly across our
systems. We expect volume growth from this drilling activity
to positively impact our operating and financial results in the
second half of the year.
We took advantage of a favorable capital markets environment in
the first quarter of 2017 by accessing the bond market for
$500.0 million of senior notes at a
5.75% coupon. This opportunistic financing enabled us to
repay all of the outstanding debt under our 7.50% senior notes,
extend our debt maturity profile, and term out $172.0 million of revolver borrowings.
We continue to have a positive outlook on our business, and we
believe we'll see growth accelerate as we move throughout the
year. Our customers are increasing their drilling and
completion activity behind our systems, and many have taken steps
to strengthen their balance sheets and enhance their capital
position to execute their growth plans. In addition, we are
encouraged by the level of commercial activity we are seeing, and
we are evaluating a number of opportunities around our existing
system footprints and in new basins."
2017 Financial Guidance
SMLP is reaffirming its 2017 financial guidance with adjusted
EBITDA expected to range from $295.0 million
to $315.0 million and an annualized fourth quarter 2017
adjusted EBITDA run rate between $325.0
million and $345.0 million.
SMLP expects to incur $100.0 million to
$150.0 million of capex in 2017, including maintenance capex
of $15.0 million to $20.0
million. SMLP's 2017 capex guidance reflects the
inclusion of our contributions to equity method investees.
SMLP expects full year distribution coverage will range from 1.15x
to 1.25x.
First Quarter 2017 Segment Results
The following table presents average daily throughput by
reportable segment:
|
|
Three months
ended
March
31,
|
|
|
2017
|
|
2016
|
Average daily
throughput (MMcf/d):
|
|
|
|
|
Utica Shale
(1)
|
|
275
|
|
|
132
|
|
Williston
Basin
|
|
17
|
|
|
25
|
|
Piceance/DJ
Basins
|
|
615
|
|
|
572
|
|
Barnett
Shale
|
|
286
|
|
|
341
|
|
Marcellus
Shale
|
|
434
|
|
|
453
|
|
Aggregate average
daily throughput
|
|
1,627
|
|
|
1,523
|
|
|
|
|
|
|
Average daily
throughput (Mbbl/d):
|
|
|
|
|
Williston
Basin
|
|
76.4
|
|
|
95.0
|
|
Aggregate average
daily throughput
|
|
76.4
|
|
|
95.0
|
|
|
|
|
|
|
Ohio Gathering
average daily throughput (MMcf/d) (2)
|
|
769
|
|
|
870
|
|
|
|
|
|
|
|
|
|
(1)
|
Exclusive of volume
throughput for Ohio Gathering.
|
(2)
|
Gross basis,
represents 100% of volume throughput for Ohio Gathering, based on a
one-month lag.
|
Utica Shale
The Utica Shale reportable segment includes our 40% ownership
interest in Ohio Gathering, a natural gas gathering system in
service and under development spanning the condensate, liquids-rich
and dry gas windows of the Utica Shale in Harrison, Guernsey, Noble, Belmont and Monroe counties in southeastern Ohio.
Segment adjusted EBITDA for the Utica Shale includes our
proportional share of adjusted EBITDA from Ohio Gathering, based on
a one-month lag. The Utica Shale reportable segment also
includes Summit Utica, the natural gas gathering system we operate
which is currently in service and under development in Belmont and Monroe counties in southeastern Ohio. Summit Utica gathers and delivers
dry natural gas to interconnections with a third-party intrastate
pipeline which provides access to the Clarington Hub.
Segment adjusted EBITDA for the first quarter of 2017 totaled
$17.0 million, up 9.0% from
$15.6 million for the prior-year
period, primarily due to significantly higher volume throughput
across Summit Utica, partially offset by lower volume throughput on
Ohio Gathering and lower stabilization revenue at Ohio
Condensate. Volume throughput on the Ohio Gathering system,
which is based on a one-month lag, averaged 769 MMcf/d, gross, in
the first quarter of 2017 compared to 870 MMcf/d, gross, in the
prior-year period and 848 MMcf/d, gross, in the fourth quarter of
2016. Volume throughput on Ohio Gathering in the first
quarter of 2017 was impacted by natural declines from existing
wells on the system.
Ohio Gathering commissioned the Larew Compressor Station in
March 2017 which is expected to
facilitate incremental dry gas production beginning in the second
quarter of 2017, and generates an incremental compression fee on
all dry gas volumes. Currently, our customers are running
five drilling rigs across the Ohio Gathering footprint, and we
expect to see the volume benefit from this activity beginning in
the second half of 2017.
Volume throughput on the Summit Utica system averaged 275 MMcf/d
in the first quarter of 2017 compared to 132 MMcf/d in the
prior-year period and 211 MMcf/d in the fourth quarter of
2016. Volume throughput for the first quarter of 2017
increased relative to the prior-year period due to our continued
buildout of the Summit Utica gathering system and our connection of
23 new wells throughout 2016 and another four new wells during the
first quarter of 2017. We expect volumes on Summit Utica will
continue to grow throughout the balance of the year as new wells
located on new and existing pad sites are completed.
In April 2017, we commissioned a
new project to offload capacity constrained natural gas from a
third-party gathering system adjacent to the Summit Utica
system. We expect this project to significantly increase
volumes on Summit Utica beginning in the second quarter of 2017,
albeit at a lower gathering rate, given that we are providing
high-pressure gathering and compression services and not
low-pressure wellhead gathering services.
Williston Basin
The Bison Midstream, Polar and Divide and Tioga Midstream systems provide our
midstream services for the Williston Basin reportable segment.
Bison Midstream gathers associated natural gas production in
Mountrail and Burke counties in North Dakota and delivers to third-party
pipelines serving a third-party processing plant in Channahon,
Illinois. The Polar and Divide system gathers crude oil production in
Williams and Divide counties in North Dakota and delivers to the COLT and
Basin Transload rail terminals, as well as other third-party,
intra- and interstate pipelines. The Polar and Divide system also gathers and delivers
produced water to various third-party disposal wells in the
region. Tioga Midstream is a crude oil, produced water and
associated natural gas gathering system in Williams County, North Dakota. All crude
oil and natural gas gathered on the Tioga Midstream system is
delivered to third-party pipelines, and all produced water is
delivered to third-party disposal wells.
Segment adjusted EBITDA for the Williston Basin segment totaled $17.8 million for the first quarter of 2017
compared to $19.7 million for the
prior-year period. Compared to the prior-year period, first
quarter 2017 volumes were negatively impacted due to a minimal
number of new wells being commissioned behind our gathering systems
during the first quarter of 2017. In addition to lower
volumes, a certain Williston
customer has gathering rates that reset up or down annually, based
on actual volumes delivered, relative to a pre-determined
schedule. The higher gathering rates that we enjoyed for this
particular customer in the first quarter of 2016 were lowered in
the second half of 2016 and impacted our sequential quarterly and
year-over-year comparisons for this segment. Without any new
drilling activity in 2017, we would expect to see gathering rates
for this particular customer to reset higher in 2018. The
Williston Basin segment benefitted from the recognition of
$2.6 million in the first quarter of
2017 related to the settlement of a business interruption insurance
claim associated with the temporary suspension of produced water
gathering activities in 2015.
Liquids volumes averaged 76.4 Mbbl/d in the first quarter of
2017, a decrease of 19.6% over the prior-year period and a decrease
of 7.2% compared to the fourth quarter of 2016. Lower liquids
volumes were primarily related to natural declines from existing
wells on the Polar and Divide
system as no new wells were commissioned during the quarter.
Certain of our customers remain active across the Polar and
Divide system, with three drilling
rigs currently working and adding to an existing backlog of more
than 40 drilled uncompleted wells ("DUCs") currently behind our
Williston gathering systems.
We expect many of these DUCs to begin to be commissioned over the
next several months following the start-up of new, third-party,
long-haul takeaway pipeline.
Associated natural gas volumes averaged 17 MMcf/d in the first
quarter of 2017, a decrease of 32% over the prior-year period and
flat compared to the fourth quarter of 2016. Volume declines
were primarily related to natural declines from existing wells on
the Bison Midstream and Tioga Midstream systems as only three new
wells were connected during the quarter. In addition, the
severe winter weather experienced late in the fourth quarter of
2016 continued into the beginning of 2017 and negatively impacted
volumes during the quarter relative to the prior-year period.
Piceance/DJ Basins
The Grand River and the Niobrara G&P systems provide our
midstream services for the Piceance/DJ Basins reportable
segment. These systems provide natural gas gathering and
processing services for producers operating in the Piceance Basin
located in western Colorado and
eastern Utah and in the
Denver-Julesburg ("DJ") Basin located in northeastern
Colorado.
Segment adjusted EBITDA totaled $29.0
million for the first quarter of 2017, an increase of 16.8%
from $24.8 million for the prior-year
period. First quarter 2017 volume throughput averaged 615
MMcf/d, an increase of 7.5% from 572 MMcf/d in the prior-year
period and flat with the fourth quarter of 2016. Volume
growth relative to the prior-year period was primarily due to
ongoing drilling and completion activity from our single-basin
focused, private equity-backed customers. These customers
commissioned dozens of new wells across our Piceance and DJ Basin
gathering systems in 2016, and in the first quarter of 2017, these
customers commissioned another 31 new wells. This activity
was partially offset by the impact of our anchor customer's
continued suspension of drilling activities in the basin and the
resulting natural declines from existing production. This
impact of our anchor customer's volume declines was partially
offset by higher minimum volume commitment ("MVC") shortfall
payment adjustments associated with our gas gathering
agreements. Certain of our customers remain active across our
Piceance and DJ gathering systems with three drilling rigs
currently working.
Barnett Shale
The DFW Midstream system provides our midstream services for the
Barnett Shale reportable segment. This system gathers and
delivers low-pressure natural gas received from pad sites,
primarily located in southeastern Tarrant
County, Texas, to downstream intrastate pipelines serving
various natural gas hubs in the region.
Segment adjusted EBITDA for the Barnett Shale segment totaled
$12.1 million for the first quarter
of 2017, a decrease of 14.1% from the prior-year period.
Volume throughput of 286 MMcf/d in the first quarter of 2017 was
down 16.1% compared to the prior-year period average of 341 MMcf/d
and flat with the fourth quarter of 2016. No new wells were
commissioned behind the DFW gathering system in the first quarter
of 2017, but drilling activity behind the system has recently
increased with two rigs added to the field since the end of the
first quarter of 2017 and workover rigs returning several dormant
wells to service late in the first quarter of 2017. This
increased level of activity is largely due to the customer turnover
we've experienced behind the system in the last several quarters,
and we expect that it will lead to increasing volumes in the second
half of 2017.
Marcellus Shale
The Mountaineer Midstream system provides our midstream services
for the Marcellus Shale reportable segment. This system gathers
high-pressure natural gas received from upstream pipeline
interconnections with Antero Midstream Partners, LP and Crestwood
Equity Partners LP. Natural gas on the Mountaineer Midstream
system is delivered to the Sherwood Processing Complex located in
Doddridge County, West Virginia.
Segment adjusted EBITDA for the Marcellus Shale segment totaled
$5.6 million for the first quarter of
2017, an increase of 22.8% from $4.6
million for the prior-year period, primarily due to
$1.2 million of right-of-way repair
expenses incurred in the prior-year period. Volume throughput
for this segment averaged 434 MMcf/d in the first quarter of 2017,
a decrease of 4.2% from 453 MMcf/d in the prior-year period, and an
increase of 16.0% from the 374 MMcf/d in the fourth quarter of
2016. Volume throughput increased relative to the fourth
quarter of 2016 as a result of our customer commissioning new wells
behind our system. We expect our customer to continue to
complete its inventory of DUCs behind the Mountaineer Midstream
system throughout the balance of the year which we expect will
drive volumes higher, particularly in the second half of
2017.
MVC Shortfall Payments
SMLP billed its customers $7.0
million in the first quarter of 2017 related to MVCs.
For those customers that do not have credit banking
mechanisms in their gathering agreements, or do not have the
ability to use MVC shortfall payments as credits, the MVC shortfall
payments are accounted for as gathering revenue in the period that
they are earned. For the first quarter of 2017, SMLP
recognized $45.4 million of gathering
revenue associated with MVC shortfall payments from certain
customers in the Marcellus Shale, Piceance/DJ Basins, Williston Basin and Barnett Shale reportable
segments. Of this amount, $37.7
million was related to a certain Williston Basin customer with whom we entered
into a gathering agreement amendment during the first quarter of
2017. Pursuant to the amendment, the customer forfeited its
MVC credit bank, which had been recorded on SMLP's balance sheet in
prior periods as deferred revenue.
MVC shortfall payment adjustments in the first quarter of 2017
totaled ($28.6) million and included
($38.5) million of deferred revenue
related to MVC shortfall payments and $9.8
million related to MVC shortfall payment adjustments from
certain customers in the Piceance/DJ Basins, Williston Basin and Barnett Shale reportable
segments.
SMLP's MVC shortfall payment mechanisms contributed $16.8 million of adjusted EBITDA in the first
quarter of 2017.
|
Three months ended
March 31, 2017
|
|
MVC
billings
|
|
|
Gathering
revenue
|
|
Adjustments
to
MVC
shortfall
payments
|
|
Net
impact
to adjusted
EBITDA
|
|
(In
thousands)
|
Net change in
deferred revenue related to MVC shortfall payments:
|
|
|
|
|
|
|
|
|
Utica
Shale
|
$
|
—
|
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Williston
Basin
|
—
|
|
|
|
37,693
|
|
|
(37,693)
|
|
|
—
|
|
Piceance/DJ
Basins
|
3,574
|
|
|
|
4,366
|
|
|
(792)
|
|
|
3,574
|
|
Barnett
Shale
|
—
|
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Marcellus
Shale
|
—
|
|
|
|
—
|
|
|
—
|
|
|
—
|
|
Total net
change
|
$
|
3,574
|
|
|
|
$
|
42,059
|
|
|
$
|
(38,485)
|
|
|
$
|
3,574
|
|
|
|
|
|
|
|
|
|
|
MVC shortfall
payment adjustments:
|
|
|
|
|
|
|
|
|
Utica
Shale
|
$
|
—
|
|
|
|
$
|
—
|
|
|
$
|
—
|
|
|
$
|
—
|
|
Williston
Basin
|
1,606
|
|
|
|
1,606
|
|
|
1,982
|
|
|
3,588
|
|
Piceance/DJ
Basins
|
252
|
|
|
|
252
|
|
|
6,545
|
|
|
6,797
|
|
Barnett
Shale
|
284
|
|
|
|
284
|
|
|
1,318
|
|
|
1,602
|
|
Marcellus
Shale
|
1,240
|
|
|
|
1,240
|
|
|
—
|
|
|
1,240
|
|
Total MVC shortfall
payment adjustments
|
$
|
3,382
|
|
|
|
$
|
3,382
|
|
|
$
|
9,845
|
|
|
$
|
13,227
|
|
|
|
|
|
|
|
|
|
|
Total
|
$
|
6,956
|
|
|
|
$
|
45,441
|
|
|
$
|
(28,640)
|
|
|
$
|
16,801
|
|
Capital Expenditures
SMLP recorded total capital expenditures of $19.4 million in the first quarter of 2017,
including $4.9 million of
contributions to equity method investees. Maintenance capital
expenditures for the quarter totaled approximately $2.2 million. Development activities during
the first quarter of 2017 were primarily related to the ongoing
expansion of our Summit Utica natural gas gathering system as well
as the continued development of certain pipeline and compression
expansion projects in the Piceance/DJ Basins segment.
Capital & Liquidity
As of March 31, 2017, SMLP had
$775.0 million of available borrowing
capacity under its $1.25 billion
revolving credit facility, subject to covenant limits. Based
upon the terms of SMLP's revolving credit facility and total
outstanding debt of $1.275 billion
(inclusive of $800.0 million of
senior unsecured notes), SMLP's leverage ratio (as defined in the
credit agreement) as of March 31,
2017 was 4.35 to 1.0.
Through March 31, 2017, the upper
limit of SMLP's leverage ratio financial covenant was 5.00 to
1.0. The leverage ratio upper limit can be permanently
increased from 5.00 to 1.0 to 5.50 to 1.0 any time, at SMLP's
option, subject to the inclusion of a senior secured leverage ratio
(as defined in the credit agreement) upper limit of 3.75 to
1.00.
In February 2017, SMLP's wholly
owned subsidiary, Summit Midstream Holdings, LLC and its wholly
owned subsidiary, Summit Midstream Finance Corp., co-issued
$500.0 million of senior unsecured
notes due in 2025. The notes priced at par to yield
5.75%. The net proceeds from the offering were used to tender
and redeem all of our 7.50% senior notes originally due in 2021
(including accrued interest), and repay $172.0 million of outstanding borrowings under
our revolving credit facility. SMLP incurred $17.9 million of cash expenses related to the
tender and redemption of our 7.50% senior notes.
Deferred Purchase Price Obligation
The consideration for the 2016 Drop Down consisted of (i) an
initial $360.0 million cash payment
(the "Initial Payment") which was funded on March 3, 2016 with borrowings under SMLP's
revolving credit facility and (ii) a deferred payment which will be
paid no later than December 31, 2020
(the "Deferred Purchase Price Obligation" or the "Deferred
Payment," as defined below). At the discretion of the board
of directors of SMLP's general partner, the Deferred Payment can be
made in either cash or SMLP common units, or a combination
thereof.
The Deferred Payment will be equal to: (a) six-and-one-half
(6.5) multiplied by the average Business Adjusted EBITDA of the
2016 Drop Down Assets for 2018 and 2019; less (b) the Initial
Payment; less (c) all capital expenditures incurred for the 2016
Drop Down Assets between March 3, 2016 and December 31, 2019; plus
(d) all Business Adjusted EBITDA from the 2016 Drop Down Assets
between March 3, 2016 and December 31, 2019. SMLP currently
estimates that the Deferred Payment will be approximately $800.0
million to $900.0 million.
Quarterly Distribution
On April 27, 2017, the board of
directors of SMLP's general partner declared a quarterly cash
distribution of $0.575 per unit on
all of its outstanding common units, or $2.30 per unit on an annualized basis, for the
quarter ended March 31, 2017.
This quarterly distribution remains unchanged from the previous
quarter and from the quarter ended March
31, 2016. This distribution will be paid on
May 15, 2017, to unitholders of
record as of the close of business on May 8,
2017.
First Quarter 2017 Earnings Call Information
SMLP will host a conference call at 10:00
a.m. Eastern on Friday, May 5,
2017, to discuss its quarterly operating and financial
results. Interested parties may participate in the call by
dialing 847-585-4405 or toll-free 888-771-4371 and entering the
passcode 44766086. The conference call will also be webcast
live and can be accessed through the Investors section of SMLP's
website at www.summitmidstream.com.
A replay of the conference call will be available until
May 19, 2017 at 11:59 p.m. Eastern, and can be accessed by
dialing 888-843-7419 and entering the replay passcode
44766086#. An archive of the conference call will also be
available on SMLP's website.
Upcoming Investor Conferences
Members of SMLP's senior management team will participate in
Deutsche Bank's 2nd Annual Midstream, MLP and Natural
Gas Conference in New York, New
York on May 9, 2017; the 2017
Master Limited Partnership Association's 2017 MLP Investor
Conference in Orlando, Florida on
June 1, 2017 and June 2, 2017; and Bank of America Merrill Lynch's
2017 Energy Credit Conference in New
York, New York on June 6,
2017. The presentation materials associated with these events
will be accessible through the Investors section of SMLP's website
at www.summitmidstream.com prior to the beginning of each
conference.
Use of Non-GAAP Financial Measures
We report financial results in accordance with U.S. generally
accepted accounting principles ("GAAP"). We also present adjusted
EBITDA and distributable cash flow, each a non-GAAP financial
measure. We define adjusted EBITDA as net income or loss,
plus interest expense, income tax expense, depreciation and
amortization, our proportional adjusted EBITDA for equity method
investees, adjustments related to MVC shortfall payments,
unit-based and noncash compensation, Deferred Purchase Price
Obligation expense, early extinguishment of debt expense,
impairments and other noncash expenses or losses, less interest
income, income tax benefit, income (loss) from equity method
investees and other noncash income or gains. We define
distributable cash flow as adjusted EBITDA plus cash interest
received and cash taxes received, less cash interest paid, senior
notes interest adjustment, cash taxes paid and maintenance capital
expenditures. Because adjusted EBITDA and distributable cash
flow may be defined differently by other entities in our industry,
our definitions of these non-GAAP financial measures may not be
comparable to similarly titled measures of other entities, thereby
diminishing their utility.
Management uses these non-GAAP financial measures in making
financial, operating and planning decisions and in evaluating our
financial performance. Furthermore, management believes that these
non-GAAP financial measures may provide external users of our
financial statements, such as investors, commercial banks, research
analysts and others, with additional meaningful comparisons between
current results and results of prior periods as they are expected
to be reflective of our core ongoing business.
Adjusted EBITDA and distributable cash flow are used as
supplemental financial measures by external users of our financial
statements such as investors, commercial banks, research analysts
and others.
Adjusted EBITDA is used to assess:
- the ability of our assets to generate cash sufficient to make
cash distributions and support our indebtedness;
- the financial performance of our assets without regard to
financing methods, capital structure or historical cost basis;
- our operating performance and return on capital as compared to
those of other entities in the midstream energy sector, without
regard to financing or capital structure;
- the attractiveness of capital projects and acquisitions and the
overall rates of return on alternative investment opportunities;
and
- the financial performance of our assets without regard to (i)
income or loss from equity method investees, (ii) the impact of the
timing of minimum volume commitments shortfall payments under our
gathering agreements or (iii) the timing of impairments or other
noncash income or expense items.
Distributable cash flow is used to assess:
- the ability of our assets to generate cash sufficient to make
future cash distributions and
- the attractiveness of capital projects and acquisitions and the
overall rates of return on alternative investment
opportunities.
Both of these measures have limitations as analytical tools and
investors should not consider them in isolation or as a substitute
for analysis of our results as reported under GAAP. For
example:
- certain items excluded from adjusted EBITDA and distributable
cash flow are significant components in understanding and assessing
an entity's financial performance, such as an entity's cost of
capital and tax structure;
- adjusted EBITDA and distributable cash flow do not reflect our
cash expenditures or future requirements for capital expenditures
or contractual commitments;
- adjusted EBITDA and distributable cash flow do not reflect
changes in, or cash requirements for, our working capital needs;
and
- although depreciation and amortization are noncash charges, the
assets being depreciated and amortized will often have to be
replaced in the future, and adjusted EBITDA and distributable cash
flow do not reflect any cash requirements for such
replacements.
We compensate for the limitations of adjusted EBITDA and
distributable cash flow as analytical tools by reviewing the
comparable GAAP financial measures, understanding the differences
between the financial measures and incorporating these data points
into our decision-making process. Reconciliations of GAAP to
non-GAAP financial measures are attached to this press release.
We do not provide the GAAP financial measures of net income or
loss or net cash provided by operating activities on a
forward-looking basis because we are unable to predict, without
unreasonable effort, certain components thereof including, but not
limited to, (i) income or loss from equity method investees, (ii)
deferred purchase price obligation income or expense and (iii)
asset impairments. These items are inherently uncertain and
depend on various factors, many of which are beyond our
control. As such, any associated estimate and its impact on
our GAAP performance and cash flow measures could vary materially
based on a variety of acceptable management assumptions.
About Summit Midstream Partners, LP
SMLP is a growth-oriented limited partnership focused on
developing, owning and operating midstream energy infrastructure
assets that are strategically located in the core producing areas
of unconventional resource basins, primarily shale formations, in
the continental United States.
SMLP provides natural gas, crude oil and produced water gathering
services pursuant to primarily long-term and fee-based gathering
and processing agreements with customers and counterparties in five
unconventional resource basins: (i) the Appalachian Basin, which
includes the Marcellus and Utica
shale formations in West Virginia
and Ohio; (ii) the Williston Basin, which includes the Bakken and
Three Forks shale formations in North
Dakota; (iii) the Fort
Worth Basin, which includes the Barnett Shale formation in
Texas; (iv) the Piceance Basin,
which includes the Mesaverde formation as well as the Mancos and Niobrara shale formations in
Colorado and Utah; and (v) the Denver-Julesburg Basin,
which includes the Niobrara and Codell shale formations in
Colorado and Wyoming. SMLP
also owns substantially all of a 40% ownership interest in Ohio
Gathering, which is developing natural gas gathering and condensate
stabilization infrastructure in the Utica Shale in Ohio. SMLP
is headquartered in The Woodlands,
Texas, with regional corporate offices in Denver, Colorado and Atlanta, Georgia.
About Summit Midstream Partners, LLC
Summit Midstream Partners, LLC ("Summit Investments")
beneficially owns a 35.0% limited partner interest in SMLP and
indirectly owns and controls the general partner of SMLP, Summit
Midstream GP, LLC, which has sole responsibility for conducting the
business and managing the operations of SMLP. Summit Investments is
a privately held company controlled by Energy Capital Partners II,
LLC, and certain of its affiliates. An affiliate of Energy
Capital Partners II, LLC directly owns an 8.0% limited partner
interest in SMLP.
Forward-Looking Statements
This press release includes certain statements concerning
expectations for the future that are forward-looking within the
meaning of the federal securities laws. Forward-looking statements
contain known and unknown risks and uncertainties (many of which
are difficult to predict and beyond management's control) that may
cause SMLP's actual results in future periods to differ materially
from anticipated or projected results. An extensive list of
specific material risks and uncertainties affecting SMLP is
contained in its 2016 Annual Report on Form 10-K filed with the
Securities and Exchange Commission on February 27, 2017, and as amended and updated
from time to time. Any forward-looking statements in this press
release are made as of the date of this press release and SMLP
undertakes no obligation to update or revise any forward-looking
statements to reflect new information or events.
We do not provide the GAAP financial measures of net income
or loss or net cash provided by operating activities on a
forward-looking basis because we are unable to predict, without
unreasonable effort, certain components thereof including, but not
limited to, (i) income or loss from equity method investees, (ii)
deferred purchase price obligation income or expense and (iii)
asset impairments. These items are inherently uncertain and
depend on various factors, many of which are beyond our
control. As such, any associated estimate and its impact on
our GAAP performance and cash flow measures could vary materially
based on a variety of acceptable management
assumptions.
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED
CONDENSED CONSOLIDATED BALANCE SHEETS
|
|
|
March
31,
2017
|
|
December
31,
2016
|
|
(In
thousands)
|
Assets
|
|
|
|
Current
assets:
|
|
|
|
Cash and cash
equivalents
|
$
|
6,285
|
|
|
$
|
7,428
|
|
Accounts
receivable
|
53,669
|
|
|
97,364
|
|
Other current
assets
|
3,240
|
|
|
4,309
|
|
Total current
assets
|
63,194
|
|
|
109,101
|
|
Property, plant and
equipment, net
|
1,854,083
|
|
|
1,853,671
|
|
Intangible assets,
net
|
411,778
|
|
|
421,452
|
|
Goodwill
|
16,211
|
|
|
16,211
|
|
Investment in equity
method investees
|
702,751
|
|
|
707,415
|
|
Other noncurrent
assets
|
7,056
|
|
|
7,329
|
|
Total
assets
|
$
|
3,055,073
|
|
|
$
|
3,115,179
|
|
|
|
|
|
Liabilities and
Partners' Capital
|
|
|
|
Current
liabilities:
|
|
|
|
Trade accounts
payable
|
$
|
17,764
|
|
|
$
|
16,251
|
|
Accrued
expenses
|
12,107
|
|
|
11,389
|
|
Due to
affiliate
|
486
|
|
|
258
|
|
Ad valorem taxes
payable
|
4,066
|
|
|
10,588
|
|
Accrued
interest
|
5,703
|
|
|
17,483
|
|
Accrued environmental
remediation
|
5,883
|
|
|
4,301
|
|
Other current
liabilities
|
4,818
|
|
|
11,471
|
|
Total current
liabilities
|
50,827
|
|
|
71,741
|
|
Long-term
debt
|
1,264,912
|
|
|
1,240,301
|
|
Deferred Purchase
Price Obligation
|
584,164
|
|
|
563,281
|
|
Deferred
revenue
|
18,980
|
|
|
57,465
|
|
Noncurrent accrued
environmental remediation
|
3,263
|
|
|
5,152
|
|
Other noncurrent
liabilities
|
7,812
|
|
|
7,566
|
|
Total
liabilities
|
1,929,958
|
|
|
1,945,506
|
|
|
|
|
|
Common limited
partner capital
|
1,085,255
|
|
|
1,129,132
|
|
General partner
interests
|
28,511
|
|
|
29,294
|
|
Noncontrolling
interest
|
11,349
|
|
|
11,247
|
|
Total partners'
capital
|
1,125,115
|
|
|
1,169,673
|
|
Total liabilities and
partners' capital
|
$
|
3,055,073
|
|
|
$
|
3,115,179
|
|
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
|
|
|
Three months
ended
March
31,
|
|
2017
|
|
2016
|
|
(In
thousands,
except per-unit
amounts)
|
Revenues:
|
|
|
|
Gathering services and
related fees
|
$
|
118,013
|
|
|
$
|
78,100
|
|
Natural gas, NGLs and
condensate sales
|
11,120
|
|
|
7,588
|
|
Other
revenues
|
6,672
|
|
|
4,883
|
|
Total
revenues
|
135,805
|
|
|
90,571
|
|
Costs and
expenses:
|
|
|
|
Cost of natural gas
and NGLs
|
9,052
|
|
|
6,290
|
|
Operation and
maintenance
|
23,692
|
|
|
25,842
|
|
General and
administrative
|
14,132
|
|
|
12,879
|
|
Depreciation and
amortization
|
28,569
|
|
|
27,728
|
|
Transaction
costs
|
—
|
|
|
1,174
|
|
Loss (gain) on asset
sales, net
|
3
|
|
|
(63)
|
|
Long-lived asset
impairment
|
284
|
|
|
—
|
|
Total costs and
expenses
|
75,732
|
|
|
73,850
|
|
Other
income
|
71
|
|
|
22
|
|
Interest
expense
|
(16,716)
|
|
|
(15,882)
|
|
Early extinguishment
of debt
|
(22,020)
|
|
|
—
|
|
Deferred Purchase
Price Obligation expense
|
(20,883)
|
|
|
(7,463)
|
|
Income (loss) before
income taxes and (loss) income from equity method
investees
|
525
|
|
|
(6,602)
|
|
Income tax (expense)
benefit
|
(452)
|
|
|
77
|
|
(Loss) income from
equity method investees
|
(656)
|
|
|
2,860
|
|
Net loss
|
$
|
(583)
|
|
|
$
|
(3,665)
|
|
|
|
|
|
Loss per limited
partner unit:
|
|
|
|
Common unit –
basic
|
$
|
(0.04)
|
|
|
$
|
(0.12)
|
|
Common unit –
diluted
|
$
|
(0.04)
|
|
|
$
|
(0.12)
|
|
|
|
|
|
Weighted-average
limited partner units outstanding:
|
|
|
|
Common units –
basic
|
72,149
|
|
|
66,493
|
|
Common units –
diluted
|
72,149
|
|
|
66,493
|
|
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED OTHER
FINANCIAL AND OPERATING DATA
|
|
|
Three months
ended
March
31,
|
|
2017
|
|
2016
|
|
(Dollars in
thousands)
|
Other financial
data:
|
|
|
|
Net loss
|
$
|
(583)
|
|
|
$
|
(3,665)
|
|
Net cash provided by
operating activities
|
$
|
62,449
|
|
|
$
|
66,849
|
|
Capital
expenditures
|
$
|
14,428
|
|
|
$
|
61,326
|
|
Contributions to
equity method investees
|
$
|
4,936
|
|
|
$
|
15,645
|
|
Acquisitions of
gathering systems (1)
|
$
|
—
|
|
|
$
|
867,427
|
|
Adjusted
EBITDA
|
$
|
71,410
|
|
|
$
|
70,009
|
|
Distributable cash
flow
|
$
|
52,951
|
|
|
$
|
51,538
|
|
Distributions
declared (2)
|
$
|
44,577
|
|
|
$
|
41,045
|
|
Distribution coverage
ratio (3)
|
1.19x
|
|
|
1.26x
|
|
|
|
|
|
Operating
data:
|
|
|
|
Aggregate average
daily throughput – natural gas (MMcf/d)
|
1,627
|
|
|
1,523
|
|
Aggregate average
daily throughput – liquids (Mbbl/d)
|
76.4
|
|
|
95.0
|
|
|
|
|
|
Ohio Gathering
average daily throughput (MMcf/d) (4)
|
769
|
|
|
870
|
|
|
|
|
|
|
|
|
|
(1)
|
Reflects cash and
noncash consideration, including working capital and capital
expenditure adjustments paid (received), for acquisitions and/or
drop downs.
|
(2)
|
Represents
distributions declared in respect of a given period. For example,
for the three months ended March 31, 2017, represents the
distributions to be paid in May 2017.
|
(3)
|
Distribution coverage
ratio calculation for the three months ended March 31, 2017 and
2016 is based on distributions declared in respect of the first
quarter of 2017 and 2016. Represents the ratio of distributable
cash flow to distributions declared.
|
(4)
|
Gross basis,
represents 100% of volume throughput for Ohio Gathering, based on a
one-month lag.
|
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED
RECONCILIATION OF REPORTABLE SEGMENT ADJUSTED EBITDA
|
TO ADJUSTED
EBITDA
|
|
|
Three months
ended
March
31,
|
|
2017
|
|
2016
|
|
(In
thousands)
|
Reportable segment
adjusted EBITDA (1):
|
|
|
|
Utica Shale
(2)
|
$
|
16,985
|
|
|
$
|
15,577
|
|
Williston
Basin
|
17,809
|
|
|
19,719
|
|
Piceance/DJ
Basins
|
28,974
|
|
|
24,817
|
|
Barnett
Shale
|
12,088
|
|
|
14,077
|
|
Marcellus
Shale
|
5,647
|
|
|
4,600
|
|
Total
|
81,503
|
|
|
78,790
|
|
Less corporate and
other (3)
|
10,093
|
|
|
8,781
|
|
Adjusted
EBITDA
|
$
|
71,410
|
|
|
$
|
70,009
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
We define segment
adjusted EBITDA as total revenues less total costs and expenses;
plus (i) other income excluding interest income, (ii) our
proportional adjusted EBITDA for equity method investees, (iii)
depreciation and amortization, (iv) adjustments related to MVC
shortfall payments, (v) unit-based and noncash compensation, (vi)
Deferred Purchase Price Obligation expense, (vii) early
extinguishment of debt expense, (viii) impairments and (ix) other
noncash expenses or losses, less other noncash income or
gains.
|
(2)
|
Includes our
proportional share of adjusted EBITDA for Ohio Gathering, based on
a one-month lag. We define proportional adjusted EBITDA for
our equity method investees as the product of (i) total revenues
less total expenses, excluding impairments and other
noncash income or expense items and (ii) amortization for
deferred contract costs; multiplied by our ownership interest in
Ohio Gathering during the respective period.
|
(3)
|
Corporate and other
represents those results that are not specifically attributable to
a reportable segment or that have not been allocated to our
reportable segments, including certain general and administrative
expense items, natural gas and crude oil marketing services,
transaction costs, interest expense, early extinguishment of debt
and Deferred Purchase Price Obligation expense.
|
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED
RECONCILIATIONS TO NON-GAAP FINANCIAL MEASURES
|
|
|
Three months
ended
March
31,
|
|
2017
|
|
2016
|
|
(Dollars in
thousands)
|
Reconciliations of
net income or loss to adjusted EBITDA and distributable cash
flow:
|
|
|
|
Net loss
|
$
|
(583)
|
|
|
$
|
(3,665)
|
|
Add:
|
|
|
|
Interest
expense
|
16,716
|
|
|
15,882
|
|
Income tax
expense
|
452
|
|
|
—
|
|
Depreciation and
amortization (1)
|
28,418
|
|
|
27,865
|
|
Proportional adjusted
EBITDA for equity method investees (2)
|
9,073
|
|
|
12,388
|
|
Adjustments related to
MVC shortfall payments (3)
|
(28,640)
|
|
|
11,142
|
|
Unit-based and noncash
compensation
|
2,128
|
|
|
1,956
|
|
Deferred Purchase
Price Obligation expense (4)
|
20,883
|
|
|
7,463
|
|
Early extinguishment
of debt (5)
|
22,020
|
|
|
—
|
|
Loss (gain) on asset
sales, net
|
3
|
|
|
(63)
|
|
Long-lived asset
impairment
|
284
|
|
|
—
|
|
Less:
|
|
|
|
Interest
income
|
—
|
|
|
22
|
|
Income tax
benefit
|
—
|
|
|
77
|
|
(Loss) income from
equity method investees
|
(656)
|
|
|
2,860
|
|
Adjusted
EBITDA
|
$
|
71,410
|
|
|
$
|
70,009
|
|
Add:
|
|
|
|
Cash interest
received
|
—
|
|
|
22
|
|
Cash taxes
received
|
—
|
|
|
77
|
|
Less:
|
|
|
|
Cash interest
paid
|
28,040
|
|
|
25,164
|
|
Senior notes interest
adjustment (6)
|
(11,781)
|
|
|
(9,750)
|
|
Maintenance capital
expenditures
|
2,200
|
|
|
3,156
|
|
Distributable cash
flow
|
$
|
52,951
|
|
|
$
|
51,538
|
|
|
|
|
|
Distributions
declared (7)
|
$
|
44,577
|
|
|
$
|
41,045
|
|
|
|
|
|
Distribution coverage
ratio (8)
|
1.19x
|
|
|
1.26x
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Includes the
amortization expense associated with our favorable and unfavorable
gas gathering contracts as reported in other revenues.
|
(2)
|
Reflects our
proportionate share of Ohio Gathering adjusted EBITDA, based on a
one-month lag.
|
(3)
|
Adjustments related
to MVC shortfall payments account for (i) the net increases or
decreases in deferred revenue for MVC shortfall payments and (ii)
our inclusion of expected annual MVC shortfall payments.
|
(4)
|
Deferred Purchase
Price Obligation expense represents the change in the present value
of the Deferred Purchase Price Obligation.
|
(5)
|
Early extinguishment
of debt includes $17.9 million paid for redemption and call
premiums, as well as $4.1 million of unamortized debt issuance
costs which were written off in connection with the repurchase of
the outstanding $300.0 million 7.5% Senior Notes in the first
quarter of 2017.
|
(6)
|
Senior notes interest
adjustment represents the net of interest expense accrued and paid
during the period. Interest on the $300.0 million 5.5% senior notes
is paid in cash semi-annually in arrears on February 15 and August
15 until maturity in August 2022. Interest on the $500.0
million 5.75% senior notes is paid in cash semi-annually in arrears
on April 15 and October 15, beginning October 15, 2017 until
maturity in April 2025.
|
(7)
|
Represents
distributions declared in respect of a given period. For example,
for the three months ended March 31, 2017, represents the
distributions to be paid in May 2017.
|
(8)
|
Distribution coverage
ratio calculation for the three months ended March 31, 2017 and
2016 is based on distributions declared in respect of the first
quarter of 2017 and 2016. Represents the ratio of distributable
cash flow to distributions declared.
|
SUMMIT MIDSTREAM
PARTNERS, LP AND SUBSIDIARIES
|
UNAUDITED
RECONCILIATIONS TO NON-GAAP FINANCIAL MEASURES
|
|
|
Three months
ended
March
31,
|
|
2017
|
|
2016
|
|
(In
thousands)
|
Reconciliation of
net cash provided by operating activities to adjusted EBITDA and
distributable cash flow:
|
|
|
|
Net cash provided by
operating activities
|
$
|
62,449
|
|
|
$
|
66,849
|
|
Add:
|
|
|
|
Interest expense,
excluding amortization of debt issuance costs
|
15,684
|
|
|
14,977
|
|
Income tax
expense
|
452
|
|
|
—
|
|
Changes in operating
assets and liabilities
|
21,336
|
|
|
(23,444)
|
|
Proportional adjusted
EBITDA for equity method investees (1)
|
9,073
|
|
|
12,388
|
|
Adjustments related to
MVC shortfall payments (2)
|
(28,640)
|
|
|
11,142
|
|
Less:
|
|
|
|
Distributions from
equity method investees
|
8,944
|
|
|
11,804
|
|
Interest
income
|
—
|
|
|
22
|
|
Income tax
benefit
|
—
|
|
|
77
|
|
Adjusted
EBITDA
|
$
|
71,410
|
|
|
$
|
70,009
|
|
Add:
|
|
|
|
Cash interest
received
|
—
|
|
|
22
|
|
Cash taxes
received
|
—
|
|
|
77
|
|
Less:
|
|
|
|
Cash interest
paid
|
28,040
|
|
|
25,164
|
|
Senior notes interest
adjustment (3)
|
(11,781)
|
|
|
(9,750)
|
|
Maintenance capital
expenditures
|
2,200
|
|
|
3,156
|
|
Distributable cash
flow
|
$
|
52,951
|
|
|
$
|
51,538
|
|
|
|
|
|
|
|
|
|
|
|
|
|
(1)
|
Reflects our
proportionate share of Ohio Gathering adjusted EBITDA, based on a
one-month lag.
|
(2)
|
Adjustments related
to MVC shortfall payments account for (i) the net increases or
decreases in deferred revenue for MVC shortfall payments and (ii)
our inclusion of expected annual MVC shortfall payments.
|
(3)
|
Senior notes interest
adjustment represents the net of interest expense accrued and paid
during the period. Interest on the $300.0 million 5.5% senior notes
is paid in cash semi-annually in arrears on February 15 and August
15 until maturity in August 2022. Interest on the $500.0
million 5.75% senior notes is paid in cash semi-annually in arrears
on April 15 and October 15, beginning October 15, 2017 until
maturity in April 2025.
|
To view the original version on PR Newswire,
visit:http://www.prnewswire.com/news-releases/summit-midstream-partners-lp-reports-first-quarter-2017-financial-results-300451940.html
SOURCE Summit Midstream Partners, LP