Press Release

THE WOODLANDS, Texas, Aug. 9, 2019 /PRNewswire/ -- Summit Midstream Partners, LP (NYSE: SMLP) announced today its financial and operating results for the three months ended June 30, 2019, including net income of $4.8 million, adjusted EBITDA of $68.6 million, distributable cash flow of $38.4 million, and a distribution coverage ratio of 1.62x.

Leonard Mallett, interim President and Chief Executive Officer, commented, "SMLP's second quarter of 2019 results were driven by adjusted EBITDA growth in our Utica Shale, Ohio Gathering, and DJ Basin segments. In addition, our quarterly results benefitted from an enhanced focus on expense control, which we expect will have a greater impact on our financial results in the second half of the year. We are encouraged by the outlook for the second half of 2019, and have already seen many of our customers increase completion activity across our systems. With respect to our financial guidance, we expect for full year 2019 adjusted EBITDA to be at the low end of our $295.0 million to $315.0 million range, primarily due to a more moderated ramp of volume growth in our Permian Basin and Utica Shale segments."

"I am proud of our team for executing on two critical milestones during the second quarter of 2019.  First, the successful commissioning of our new 60 MMcf/d processing plant substantially increased our processing capacity in the DJ Basin, and current throughput levels are approximately 50% higher than those reported for the second quarter of 2019. Second, our new joint venture with Exxon Mobil for the Double E Pipeline will significantly increase our scale in the Permian Basin and will diversify our overall business. In addition, the 10-year precedent agreements secured by Double E will provide SMLP with a stable source of cash flows for many years to come. Project execution for Double E has kicked off in earnest, and the section 7(c) application for Double E was filed with the FERC in late July."

"Our team's focus for the balance of the year will be aimed at executing on our strategic plan, including our ongoing evaluation of asset sales and other opportunities to further strengthen and accelerate deleveraging. We are optimistic that we will be able to demonstrate notable progress on these efforts before the end of 2019."

Double E Pipeline
In June 2019, SMLP decided to proceed with the Double E Pipeline ("Double E"), after having secured sufficient transportation commitments, and having executed definitive joint venture agreements with a subsidiary of Exxon Mobil Corporation ("Exxon"). Double E will provide natural gas transportation service from multiple receipt points in the Delaware Basin to various delivery points in and around the Waha Hub in Texas. Double E has secured binding 10-year take-or-pay volume commitments for a substantial majority of its initial throughput capacity of 1.35 billion cubic feet per day ("Bcf/d") from several of the largest and most respected production companies operating in the Delaware Basin. Commercial discussions with additional potential shippers are ongoing and SMLP will look for opportunities to subscribe the limited remaining capacity prior to commissioning.

SMLP owns 70% of Double E, will lead the development, permitting and construction of the project, and will operate the pipeline system upon commissioning. SMLP estimates that the capital expenditures required to fully develop the project will total approximately $500 million, that its share of the capital expenditures will be approximately $350 million, and that more than 90% of those capital expenditures will be incurred in 2020 and 2021. 

Double E filed its section 7(c) application with the Federal Energy Regulatory Commission in July 2019. Assuming timely receipt of the requisite regulatory approvals, SMLP expects that the project will be placed into service in the third quarter of 2021. 

Second Quarter 2019 Segment Results
The following table presents average daily throughput by reportable segment:

Utica Shale
The Utica Shale reportable segment includes Summit Midstream Utica ("SMU"), a natural gas gathering system located in Belmont and Monroe counties in southeastern Ohio. SMU gathers and delivers dry natural gas to interconnections with a third-party intrastate pipeline that provides access to the Clarington Hub. 

Segment adjusted EBITDA for the second quarter of 2019 totaled $6.6 million, up 7.2% from $6.2 million in the first quarter of 2019. Volume throughput averaged 260 MMcf/d in the second quarter of 2019, and included 220 MMcf/d of volumes gathered from pad sites directly connected to the SMU gathering system and 40 MMcf/d from the TPL-7 Connector, which generates a substantially lower gathering margin. Higher margin volumes from pad sites directly connected to the SMU gathering system increased by 7.3% compared to the first quarter of 2019, the second consecutive quarter that this metric increased. Volumes in the second quarter of 2019 benefitted from four new wells that were turned in line late in the quarter. Second quarter of 2019 results were impacted by approximately 23 MMcf/d of temporary volume curtailments associated with infill drilling and completion activities on existing pad sites.    

Our customers are currently operating one drilling rig upstream of the SMU gathering system, and as a result, we continue to expect that Utica Shale segment adjusted EBITDA for the second half of 2019 will be higher than the $12.8 million generated in the first half of the year.

Ohio Gathering
The Ohio Gathering reportable segment includes our ownership interest in the Ohio Gathering system, a natural gas gathering system spanning the condensate, liquids-rich and dry gas windows of the Utica Shale in Harrison, Guernsey, Noble, Belmont and Monroe counties in southeastern Ohio, as well as our ownership interest in Ohio Condensate, a condensate stabilization facility located in Harrison County, Ohio. Segment adjusted EBITDA for the Ohio Gathering segment includes our proportional share of adjusted EBITDA from Ohio Gathering and Ohio Condensate, subject to a one-month lag. 

Segment adjusted EBITDA for the second quarter of 2019 totaled $9.9 million, up 7.9% from $9.2 million in the first quarter of 2019. Volume throughput on the Ohio Gathering system averaged 713 MMcf/d, gross, in the second quarter of 2019, compared to 711 MMcf/d, gross, in the first quarter of 2019. Volumes benefitted from a consistent level of drilling and completion activity, with 13 new well connections in the second quarter of 2019, including five new wells that were connected in the last month of the quarter and are expected to have a more meaningful impact in the third quarter of 2019. Our customers currently have 32 drilled but uncompleted wells ("DUCs") in inventory, and, beginning in the third quarter of 2019, we expect to see completion activities shift from the condensate window to the more prolific wet gas window of the play, which supports our expectation for higher volumes throughout the balance of 2019.

Williston Basin
The Polar and Divide and Bison Midstream systems provide our midstream services for the Williston Basin reportable segment. The Polar and Divide system gathers crude oil in Williams and Divide counties in North Dakota and delivers to third-party intra- and interstate pipelines as well as third-party rail terminals. The Polar and Divide system also gathers and delivers produced water to various third-party disposal wells in the region. 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.    

Segment adjusted EBITDA for the Williston Basin segment totaled $16.7 million in the second quarter of 2019, compared to $18.7 million in the first quarter of 2019. Lower segment adjusted EBITDA was primarily related to the sale of Tioga Midstream, which closed on March 22, 2019 and contributed approximately $0.9 million to segment adjusted EBITDA in the first quarter of 2019. 

Liquids volumes in the second quarter of 2019 averaged 94.3 Mbbl/d compared to 103.0 Mbbl/d in the first quarter of 2019, primarily as a result of (i) the sale of the Tioga Midstream system and (ii) natural production declines associated with 44 new wells that were commissioned behind the Polar and Divide system in the second half of 2018. Natural gas volumes in the second quarter of 2019 averaged 11 MMcf/d compared to 16 MMcf/d in the first quarter of 2019, primarily as a result of (i) the sale of the Tioga Midstream system and (ii) maintenance on third party-owned infrastructure located downstream of the Bison Midstream system, which created an operational disruption on the Bison Midstream system for approximately 15 days during the quarter. Our customers are currently operating one drilling rig upstream of our Bison Midstream system and we expect to connect eight new associated natural gas wells in the fourth quarter of 2019.

Our Polar and Divide system customers in the Williston Basin connected 23 new wells in the second quarter of 2019, including 12 wells at the end of the quarter, which resulted in average liquids volumes of more than 100 Mbbl/d for the last ten days of the second quarter of 2019. We maintain a robust outlook for liquids volumes and Williston Basin segment adjusted EBITDA for the second half of the year, based on our expectation for approximately 50 new well connections in the second half of 2019, which is supported by two active drilling rigs and 36 DUCs that our customers have in inventory. 

DJ Basin
The DJ Basin reportable segment includes the Niobrara Gathering & Processing system ("Niobrara G&P"), an associated natural gas gathering and processing system located in the DJ Basin in northeastern Colorado. Niobrara G&P delivers residue gas to the Colorado Interstate Gas and Trailblazer Pipeline and processed NGLs to the Overland Pass Pipeline.

Segment adjusted EBITDA for the second quarter of 2019 totaled $2.8 million, up 5.3% from $2.7 million in the first quarter of 2019. Volume throughput averaged 20 MMcf/d in the second quarter of 2019, compared to 21 MMcf/d in the first quarter of 2019, primarily due to approximately two weeks of planned downtime associated with the commissioning of our new 60 MMcf/d processing plant, which was placed into service in June 2019. Segment adjusted EBITDA was higher for the second quarter of 2019 compared to the prior quarter, despite lower quarterly volume throughput, due to a shift in volume mix in favor of a customer that generates a higher gathering and processing rate.

Volumes at our new processing plant are currently averaging more than 30 MMcf/d and are expected to ramp throughout the balance of 2019, based on existing production behind our system and new production associated with our customers' drilling and completion schedules, which includes two rigs that are currently operating upstream of the Niobrara G&P system and 23 DUCs that our customers have in inventory. 

The commissioning of the new processing plant also triggered a $0.6 million per month contractual demand payment that will complement higher revenues associated with the expanded processing capacity. SMLP will begin recognizing these new demand payments in the third quarter of 2019.

Permian Basin
The Permian Basin reportable segment includes Summit Midstream Permian ("Summit Permian"), an associated natural gas gathering and processing system located in the northern Delaware Basin in southeastern New Mexico. Summit Permian operates the 60 MMcf/d Lane Gathering & Processing system ("Lane G&P"), which delivers residue gas to the Transwestern Pipeline and processed NGLs to the Lone Star Express pipeline. 

Segment adjusted EBITDA for the second quarter of 2019 totaled ($0.7) million compared to ($0.6) million in the first quarter of 2019. Segment adjusted EBITDA was negatively impacted by $0.8 million of higher operating expenses compared to the first quarter of 2019, primarily related to the continued build-out and establishment of our operations in this new region. 

Volume throughput averaged 17 MMcf/d in the second quarter of 2019, up 13.3% from the prior quarter, and benefited from the commissioning of the Blue Quail Compressor Station at the end of the quarter, which facilitated a new source of volume on the Lane G&P system. Our customers currently have 13 DUCs in inventory, and we expect to connect these wells in the second half of 2019.

Legacy Areas
Our Legacy Areas, which include our Piceance Basin, Barnett Shale, and Marcellus Shale reportable segments, are located in production basins in which we expect our gathering systems to experience relatively lower long-term growth and to attract a minority of our capital expenditures. Our Legacy Areas are served by the Grand River system for the Piceance Basin reportable segment, the DFW Midstream system for the Barnett Shale reportable segment, and the Mountaineer Midstream system for the Marcellus Shale reportable segment.

Segment adjusted EBITDA for the Piceance Basin, Barnett Shale, and Marcellus Shale reportable segments totaled $40.4 million in the second quarter of 2019, compared to $42.5 million in the first quarter of 2019. There were no new wells connected in our Legacy Areas during the second quarter of 2019, and as a result, total volume throughput declined by 6.5% compared to the first quarter of 2019. We expect drilling and completion activity in our Legacy Areas to resume in the third quarter of 2019 as a result of (i) the completion of three DUCs located upstream of the DFW Midstream system, which are located on the same pad site that has the largest well ever drilled in the region and (ii) the completion of five Mountaineer Midstream DUCs early in the fourth quarter of 2019.

We incurred $0.3 million of total capital expenditures in our Legacy Areas in the second quarter of 2019, or less than 1.0% of the total capital expenditures incurred by SMLP for the period. Total segment adjusted EBITDA exceeded total segment capital expenditures for our Legacy Areas in the second quarter of 2019 by $40.1 million.

MVC Shortfall Payments
SMLP billed its customers $12.1 million in the second quarter of 2019 related to MVC shortfalls. For those customers that do not have MVC shortfall credit banking mechanisms in their gathering agreements, the MVC shortfall payments are accounted for as gathering revenue in the period in which they are earned. In the second quarter of 2019, SMLP recognized $12.5 million of gathering revenue associated with MVC shortfall payments. SMLP also recognized $3.5 million of adjustments to MVC shortfall payments in the second quarter of 2019, primarily related to future expected shortfall payments from customers in the Williston Basin segment and the Barnett Shale segment. SMLP's MVC shortfall payment mechanisms contributed $­­16.0 million of total adjusted EBITDA in the second quarter of 2019.

 

Capital Expenditures
Capital expenditures totaled $50.2 million in the second quarter of 2019, including maintenance capital expenditures of $3.7 million. Development activities during the second quarter of 2019 were primarily related to our 60 MMcf/d DJ Basin processing plant, the Double E project, and the Blue Quail Compressor Station that serves Lane G&P.

Capital & Liquidity
As of June 30, 2019, SMLP had $668 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 $1.37 billion (inclusive of $800.0 million of senior unsecured notes), SMLP's total leverage ratio and senior secured leverage ratio (as defined in the credit agreement) as of June 30, 2019, were 4.84 to 1.0 and 2.02 to 1.0, respectively.

In the second quarter of 2019, and in connection with its decision to proceed with Double E, SMLP and its lenders amended the credit agreement for its revolving credit facility to provide additional flexibility with respect to its financial performance metrics during the construction of the project.

Deferred Purchase Price Obligation
The consideration for the 2016 Drop Down consisted of an initial cash payment on March 3, 2016, and the Deferred Purchase Price Obligation ("DPPO"), which will be satisfied no later than December 31, 2020. At the discretion of the board of directors of SMLP's general partner, the DPPO can be made in either cash or SMLP common units, or a combination thereof.

In the first quarter of 2019, the Contribution Agreement associated with the 2016 Drop Down was amended to incorporate (i) a $100.0 million prepayment of the DPPO, which was paid in the second quarter of 2019 and (ii) an agreement to fix the remaining obligation due in 2020 at $303.5 million.

Quarterly Distribution
On July 25, 2019, the board of directors of SMLP's general partner declared a quarterly cash distribution of $0.2875 per unit on all of its outstanding common units, or $1.15 per unit on an annualized basis, for the quarter ended June 30, 2019. This distribution will be paid on August 14, 2019, to unitholders of record as of the close of business on August 7, 2019.

Second Quarter 2019 Earnings Call Information
SMLP will host a conference call at 10:00 a.m. Eastern on Friday, August 9, 2019, 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 48729287.  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 August 23, 2019, at 11:59 p.m. Eastern, and can be accessed by dialing 888-843-7419 and entering the replay passcode 48729287#.  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 attend the 2019 Citi One-on-One Midstream / Energy Infrastructure Conference in Las Vegas, Nevada on August 14-15, 2019.  The presentation materials associated with this event will be accessible through the Investors section of SMLP's website at www.summitmidstream.com prior to the beginning of the 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, adjustments related to capital reimbursement activity, unit-based and noncash compensation, the change in the Deferred Purchase Price Obligation fair value, impairments, items of income or loss that we characterize as unrepresentative of our ongoing operations 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, distributions to Series A Preferred unitholders, Series A Preferred units distribution 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 income or expense items that we characterize as unrepresentative of our ongoing operations.

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 and (ii) 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 six unconventional resource basins: (i) the Appalachian Basin, which includes the Utica and Marcellus shale formations in Ohio and West Virginia; (ii) the Williston Basin, which includes the Bakken and Three Forks shale formations in North Dakota; (iii) the Denver-Julesburg Basin, which includes the Niobrara and Codell shale formations in Colorado and Wyoming; (iv) the Permian Basin, which includes the Bone Spring and Wolfcamp formations in New Mexico; (v) the Fort Worth Basin, which includes the Barnett Shale formation in Texas; and (vi) the Piceance Basin, which includes the Mesaverde formation as well as the Mancos and Niobrara shale formations in Colorado and Utah.  SMLP has an equity investment in and operates Double E Pipeline, LLC, which is developing natural gas transmission infrastructure that will provide transportation service from multiple receipt points in the Delaware Basin to various delivery points in and around the Waha Hub in Texas. SMLP also has an equity investment in Ohio Gathering, which operates extensive natural gas gathering and condensate stabilization infrastructure in the Utica Shale in Ohio.  SMLP is headquartered in The Woodlands, Texas.

About Summit Midstream Partners, LLC
Summit Midstream Partners, LLC ("Summit Investments") beneficially owns a 41.8% limited partner interest in SMLP and indirectly owns and controls the non-economic 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 a 7.2% 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 2018 Annual Report on Form 10-K filed with the Securities and Exchange Commission on February 26, 2019, and as amended and updated from time to time. Any forward-looking statements in this press release, including forward-looking statements regarding 2019 financial guidance or financial or operating expectations for 2019, 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.

 

 

 

 

 

 

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SOURCE Summit Midstream Partners, LP

Blake Motley, Vice President of Strategy and Head of Investor Relations, 832-930-7539, ir@summitmidstream.com