Press Release

HOUSTON, Nov. 6, 2020 /PRNewswire/ -- Summit Midstream Partners, LP (NYSE: SMLP) announced today its financial and operating results for the three months ended September 30, 2020, including net income of $25.6 million, adjusted EBITDA of $59.8 million and DCF of $37.6 million.  Net income included a $24.7 million gain from early extinguishment of debt due to SMLP's open market repurchases and public tender offers for its senior unsecured notes, at discounts to par value.  Operated natural gas volume throughput averaged 1,392 million cubic feet per day ("MMcf/d") and liquids volume throughput averaged 69.0 thousand barrels per day ("Mbbl/d") for the third quarter of 2020.  Operated natural gas volumes were relatively flat with the second quarter of 2020, which was impacted by an aggregate volume increase of 64 MMcf/d from the Marcellus Shale and DJ Basin segments relative to second quarter volumes, partially offset by a 15.4% decrease in Utica Shale segment volume, primarily due to a five-well pad site, representing more than 150 MMcf/d, that was temporarily shut-in due to low commodity prices from mid-June through mid-August.  Quarterly liquids volume throughput decreased by 9.2% from the second quarter of 2020, primarily due to natural production declines, the shut-in of approximately 5 Mbbl/d of liquids throughput across our systems due to low commodity prices and the continued deferral of drilling and completion activities by certain customers in the Williston Basin segment.

Heath Deneke, President, Chief Executive Officer and Chairman, commented, "Summit generated $59.8 million of adjusted EBITDA during the third quarter, which was slightly above our expectations in August.  Our results improved throughout the third quarter as customers continued to return previously shut-in production to service in large part due to strengthening of natural gas prices.  Given that most of the temporary production shut-ins that impacted our financial results in the second and third quarters have been restored or are in the process of being restored, we continue to expect full-year 2020 adjusted EBITDA to be within our $250 million to $260 million guidance range." 

"We continue to make excellent progress advancing the Double E project while locking in substantial savings relative to the original development budget.  Although the project did not receive FERC approval in the third quarter of 2020 as originally anticipated, we were pleased that FERC issued the 7(c) certificate authorizing the project in October.  This approval represents a significant milestone for the project and enables us to advance plans to secure third-party financing to fund the vast majority, if not all, of our remaining Double E capital expenditures.  We expect to have third-party financing in place concurrent with receipt of FERC's notice to proceed with construction, which is expected to be obtained in the first quarter of 2021.  Given the success we've had in locking in capital savings relative to budget, the total estimated cost to complete Double E is now expected to come in under $430 million, gross, which represents an approximate 15% reduction relative to the original capital budget.  As a result, SMLP's 70% share of development capital is now estimated to be approximately $300 million, of which, approximately $175 million remains to be spent as of September 30, 2020."

"Due to the delay in receiving FERC approval on the Double E project and the associated impact to the timing of our third-party financing plans, SMLP now expects to directly fund an incremental $10 million to $20 million of Double E capital in 2020 beyond what was previously assumed in our capital guidance for the year.  As a result, we are revising SMLP's 2020 capital expenditure guidance to $55 million to $65 million."

"We also continued to make significant progress on our liability management strategy in the third quarter of 2020, completing and announcing several transactions, consistent with our primary objectives to reduce leverage, simplify the balance sheet and create long-term value for stakeholders across our capital structure.  Since closing of the GP Buy-In Transaction in May, including the October 2020 privately negotiated transaction to repurchase $95.6 million of our 2025 senior notes at a substantial discount to par value, we have repurchased a total of $306.5 million face value of our aggregate senior notes and reduced net indebtedness by more than $150 million relative to the end of 2019.  Additionally, we exchanged 62,816 Series A Preferred Units for approximately 12.3 million SMLP common units during 3Q 2020, reducing the face value of SMLP's aggregate Series A Preferred Units by approximately $62.8 million at an implied discount of 84% based on SMLP's common unit trading price at closing.  Furthermore, during the third quarter, we executed a transaction support agreement to retire the $155.2 million SMP Holdings Term Loan through a settlement with the Term Loan lenders.  Upon closing of the TL Restructuring, we plan to make a $26.5 million cash payment to SMP Holdings, representing a full settlement of the $180.75 million DPPO, and will release the 34.6 million SMLP common units that were previously pledged as collateral to Term Loan lenders.  In exchange, the lenders will forgive the full amount of the $155.2 million Term Loan and the GP interest will be released from the collateral package.  The TL Restructuring has garnered the support and consent from 100% of the lenders and is expected to close in the fourth quarter of 2020.  Together with the Series A Preferred Equity Exchange, the senior note repurchases and the full settlement of the DPPO, SMLP has eliminated approximately $550.1 million of its fixed capital obligations since closing the GP Buy-In Transaction.  These liability management transactions have been highly accretive to SMLP's equity valuation given the substantial discounts captured and I believe that SMLP is far better situated for long-term success as a result of these initiatives."

Summary of Selected Balance Sheet Items Impacted by SMLP's Liability Management Initiatives in 2020
The table below summarizes the par value of key selected SMLP balance sheet line items that have been, or are expected to be impacted by SMLP's liability management initiatives in 2020.  Current par value is shown pro forma as of November 5, 2020 and includes expected impacts from the SMP Holdings Term Loan Restructuring transaction, which was announced in September 2020 and is expected to close in the fourth quarter of 2020. 

 

 

Third Quarter 2020 Business Highlights
In the third quarter of 2020, SMLP's average daily natural gas throughput for its operated systems increased 0.1% relative to the second quarter of 2020, to 1,392 MMcf/d, and liquids volumes decreased 9.2% relative to the second quarter of 2020, to 69 Mbbl/d.  SMLP's customers had approximately 21 DUCs in inventory and 18 wells that had been completed but not turned-in-line upstream of its systems as of September 30, 2020.

Core Focus Areas:

• Core Focus Areas generated combined quarterly segment adjusted EBITDA of $32.0 million and had combined capital expenditures of $6.3 million.

• Utica Shale segment adjusted EBITDA totaled $7.5 million, a $3.2 million decrease from the second quarter of 2020, which was driven by a 15.4% decrease in volume throughput.  Volume throughput was lower in the third quarter of 2020 due to the shut-in of a five-well pad site through mid-August that averaged more than 150 MMcf/d once back online, deferrals of new well connections and natural production declines.  A total of 10 wells were connected in the Utica Shale segment during the quarter, of which seven wells were turned-in-line upstream of the TPL-7 Connector pipeline.  We do not anticipate any new well connections for the remainder of the year, but we do expect additional activity in the first half of 2021 as a result of a previously announced gathering agreement amendment to incentivize accelerated drilling behind our SMU system. 

• Ohio Gathering segment adjusted EBITDA totaled $7.1 million, a 5.1% decrease from the second quarter of 2020.  Lower segment adjusted EBITDA was driven by a 5.2% decrease in volume throughput due to production shut-ins, which accounted for approximately 139 MMcf/d of gross volumes for the quarter, partially offset by 15 new wells that were connected, of which 10 wells were turned-in-line in September; as a result of our one-month lag in reporting for Ohio Gathering, these 10 September wells were not included in our third quarter operating or financial results.

• Williston Basin segment adjusted EBITDA totaled $11.7 million in the third quarter of 2020, an 8.0% decrease from the second quarter of 2020, primarily due to a 9.2% decrease in liquids volume throughput to 69 Mbbl/d.  This volume throughput decrease was driven largely by natural production declines and impacted by production shut-ins of approximately 5 Mbbl/d for the quarter.  In September, two of our Williston Basin customers emerged from bankruptcy proceedings and at the end of the third quarter, there were approximately 6 DUCs in inventory and 8 wells that have been completed, but not yet turned to production behind our Williston Basin systems.

• DJ Basin segment adjusted EBITDA totaled $4.8 million in the third quarter of 2020, a 9.8% increase from the second quarter of 2020, due to a 35.0% quarter-over-quarter increase in total throughput to 27 MMcf/d.  The volume throughput increase was primarily driven by shut-in wells coming back online and nine new wells connected behind the DJ Basin system in the quarter.  As of September 30, 2020, our customers had 10 completed wells that had not yet been turned-in-line behind our DJ Basin system; however, four of those wells came online in October 2020 and the remaining six are expected to be online by year end.

• Permian Basin segment adjusted EBITDA totaled $0.9 million in the third quarter of 2020, a decrease of approximately 51.1% relative to the prior quarter primarily due decreased margins on natural gas and NGL sales, higher operating expenses and change in customer volume mix.  The 6.3% increase in volume throughput was largely attributable to having a full quarter of throughput from a customer who signed a contract extension in May.  Our customers have two DUCs in inventory behind the Permian Basin system, but we do not expect them to be turned-in-line until 2021.

Legacy Areas:

• Legacy Areas generated $34.7 million of combined segment adjusted EBITDA in the third quarter of 2020 and had combined capital expenditures of $1.3 million.

• Piceance Basin segment adjusted EBITDA of $21.5 million decreased by $0.2 million from the second quarter of 2020 due to lower volume throughput of 1.6%, which was primarily driven by the impact of natural production declines.

• Barnett Shale segment adjusted EBITDA decreased by $1.3 million from the second quarter of 2020 to $7.2 million, primarily due to decreased gas sales and margin mix due to recent contract amendments.  Throughput volumes increased by 2.5% primarily due to workovers and recompletions of existing wells behind the DFW Midstream system.

• Marcellus Shale segment adjusted EBITDA increased by 23.2% compared to the second quarter of 2020, to $6.0 million, due to a 16.8 % increase in volume throughput to 396 MMcf/d.  Our anchor customer connected nine wells in July, which represented the primary driver of increased performance.  There were nine DUCs in inventory behind our Marcellus Shale infrastructure at the end of the third quarter, which we do not expect to be turned-in-line until the first half of 2021.

The following table presents average daily throughput by reportable segment for the periods indicated:

 

 The following table presents adjusted EBITDA by reportable segment for the periods indicated:

 

 

 

Capital Expenditures
Capital expenditures totaled $7.9 million in the third quarter of 2020, a decrease of 10.8% compared to the second quarter of 2020, which included maintenance capital expenditures of $3.5 million.  Capital expenditures in the third quarter of 2020 were primarily related to growth projects in our DJ Basin segment.   

 

 

Capital & Liquidity
As of September 30, 2020, SMLP had $437.4 million of undrawn commitments under its $1.25 billion revolving credit facility, after accounting for a $4.1 million issued but undrawn letter of credit.  Subject to covenant limits, our available borrowing capacity at September 30, 2020 totaled approximately $172 million.

Based upon the terms of SMLP's revolving credit facility and total outstanding debt, net of cash, of $1.35 billion (inclusive of $589.1 million of senior unsecured notes), SMLP's total leverage ratio and senior secured leverage ratio (as defined in the credit agreement) as of September 30, 2020, were 4.87 to 1.0 and 2.74 to 1.0, respectively, relative to maximum threshold limits of 5.50 to 1.0 and 3.75 to 1.0.

Double E Update
During the third quarter of 2020, SMLP made cash investments totaling $11.2 million with respect to its 70% equity investment in Double E.  The estimated cost to complete the Double E Pipeline Project has decreased by approximately 15% relative to original development budget, and as such, SMLP's 70% share of capital costs is now approximately $300 million, of which approximately $125 million has been funded as of September 30, 2020.  As previously reported, on October 15, 2020, Double E received Federal Energy Regulatory Commission ("FERC") approval of its application to construct and operate the Double E Pipeline Project pursuant to Section 7(c) of the Natural Gas Act.  SMLP is in the process of finalizing third-party financing for its remaining Double E capital obligations and expects to secure this financing concurrently with FERC's notice to proceed with construction, which is anticipated in the first quarter of 2021.  SMLP plans to directly fund its Double E capital obligations until third-party financing can be obtained.  The estimated in-service date for Double E has been extended to the fourth quarter of 2021.

MVC Shortfall Payments
SMLP billed its customers $12.9 million in the third quarter of 2020 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 third quarter of 2020, SMLP recognized $12.9 million of gathering revenue associated with MVC shortfall payments.  SMLP also recognized $2.3 million of adjustments to MVC shortfall payments in the third quarter of 2020 related to shortfall payment adjustments from customers in the Williston Basin segment and the Piceance Basin segment.  SMLP's MVC shortfall payment mechanisms contributed $15.2 million of total adjusted EBITDA in the third quarter of 2020.

 

 

 

 

 

 

Quarterly Distribution Update
The board of directors of SMLP's general partner continues to suspend cash distributions payable on its common units and on its 9.50% Series A fixed-to-floating rate cumulative redeemable perpetual preferred units for the period ended September 30, 2020.  Unpaid distributions on the preferred units will continue to accrue.

Previously Announced Reverse Unit Split
On October 30, 2020, SMLP announced a 1-for-15 reverse unit split on its common units. Pursuant to the reverse unit split, common unitholders will receive one common unit for every 15 common units owned at the close of business on November 9, 2020.  The split will take effect after markets close on Monday, November 9, 2020, and the common units will trade on a split-adjusted basis beginning on Tuesday, November 10, 2020.   

Third Quarter 2020 Earnings Call Information
SMLP will host a conference call at 10:00 a.m. Eastern on Friday, November 6, 2020, 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 49988072.  The conference call, live webcast and archive of the call can be accessed through the Investors section of SMLP's website at www.summitmidstream.com.

Upcoming Investor Conferences
Members of SMLP's senior management team will attend the RBC Capital Markets Midstream and Energy Infrastructure Conference which will take place on November 18-19, 2020 and the 2020 Wells Fargo Midstream and Utility Symposium which will take place on December 8-9.  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 respective 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, 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, adjusted Series A Preferred Units cash distribution, 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 future potential 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 support future potential 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 value-driven 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, processing and transportation services pursuant to primarily long-term, fee-based 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. SMLP has an equity investment in 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 Houston, Texas.

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 2019 Annual Report on Form 10-K filed with the Securities and Exchange Commission on March 9, 2020, and as amended and updated from time to time. Any forward-looking statements in this press release, including forward-looking statements regarding 2020 financial guidance or financial or operating expectations for 2020, 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

Ross Wong, Senior Director, Corporate Development & Finance, 832-930-7512, ir@summitmidstream.com