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HOUSTON, March 16, 2026 /PRNewswire/ — Summit Midstream Corporation (NYSE: SMC) (“Summit”, “SMC” or the “Company”) announced today its financial and operating results for fourth quarter and full-year 2025, Permian and Rockies segment growth update, and provided full-year 2026 financial guidance.

   

Highlights

• Fourth quarter net loss of $7.3 million, Adjusted EBITDA of $58.5 million, cash flow available for distributions (“Distributable Cash Flow” or “DCF”) of $33.7 million and free cash flow (“FCF”) of $17.0 million
• Recently signed three 10+-year firm take-or-pay contracts on Double E that are expected to drive Permian Segment Adjusted EBITDA from $34 million in 2025 to approximately $60 million in 2029 
• Launched a binding open season on Double E to secure market commitments to support a mainline compression project to increase firm capacity by up to 50% from 1.6 Bcf/d to approximately 2.4 Bcf/d
• Refinanced Double E capital structure¹ with a new term loan that will fund Double E capital projects (including the mainline compression project) and provide an $85 million one-time distribution to Summit to pay down debt and repay $45 million of arrears on its corporate Series A Preferred Stock
• Executed a new 10-year crude oil gathering agreement covering more than 200,000 acres in the Williston
• Active customer base with seven rigs running, approximately 90 DUCs and 116 to 126 wells expected in 2026
• Provided 2026 full-year financial guidance range of $225 million to $265 million in Adjusted EBITDA and total capital expenditures of $85 million to $105 million, including $35 million attributable to Double E

Management Commentary

Heath Deneke, President, Chief Executive Officer and Chairman, commented, “We are pleased with the commercial and financial progress achieved over the past two quarters, which underscore the strategic value of our infrastructure, embedded growth opportunities, and our continued focus on execution with financial discipline. With the signing of major long-term agreements on the Double E Pipeline and in the Williston Basin, we are building on strong commercial momentum in our Permian and Rockies segments, while maintaining steady operational performance, strengthening our balance sheet and allocating capital prudently. We’re also further advancing Double E’s growth with a new open season to support a mainline compression project that could expand pipeline capacity by 50% by the end of 2028. Additionally, the Double E refinancing underscores Summit’s financial flexibility and ability to execute on important growth initiatives while continuing to maintain focus on reaching long-term corporate leverage targets. The planned repayment of the arrears on the Series A Preferred Stock further simplifies Summit’s balance sheet and is also an important step towards enabling a sustainable return of capital program for our shareholders in the future.   

Operationally, despite the earlier oil price headwinds, we maintained an active customer base with seven rigs currently running behind our systems, approximately 90 DUCs and between 116 to 126 wells expected to be turned in line in 2026. Our 2026 outlook reflects sustained activity across our systems and incremental investment in high-return growth projects, which we expect will drive EBITDA growth in 2027 and beyond. Furthermore, given the mid-$60 oil price assumption embedded in our 2026 guidance, we are optimistic that customer activity levels could further increase in the second half of the year if the recent spike in oil prices continues to lift the backend of the forward price curve.”

Double E Commercial Update

Producers Midstream II reached a final investment decision on Train II of its Dude processing plant in Lea County, New Mexico, which was a condition precedent to the commencement of the previously announced 10-year, 100 MMcf/d firm transportation agreement. The new contract is expected to commence service in the fourth quarter of 2026.

Double E Pipeline entered into a new 11-year take-or-pay natural gas firm transportation agreement with a large, investment-grade shipper for 210 MMcf/d of capacity, including 80 MMcf/d expected to commence in the fourth quarter of 2026 and an additional 130 MMcf/d expected to commence in the second half of 2028. These commitments also expand Double E’s downstream connectivity with new delivery points into the Transwestern Central Pool, the Hugh Brinson Pipeline and a planned future connection with the Desert Southwest Pipeline. The new delivery points will significantly broaden Double E Shipper’s access to diverse and growing end use markets in addition to the multiple interconnects with downstream egress pipelines connecting the Waha Hub to Gulf Coast markets.

Double E Pipeline also entered into a new 11+ year natural gas transportation agreement with an undisclosed shipper for 230 MMcf/d of firm capacity, with 100 MMcf/d expected to start in the fourth quarter of 2027, 80 MMcf/d in the fourth quarter of 2028, and an additional 50 MMcfd in the second quarter of 2029. The agreement is contingent upon satisfaction of certain customary conditions precedent and is subject to shipper providing notice of its final investment decision to construct an expansion of its processing facility prior to October 1, 2026.

With the additional contracts, Summit expects its 70% interest in Double E to generate approximately $60 million of Segment Adjusted EBITDA in 2029, representing an approximate 76% increase to the $34 million of Segment Adjusted EBITDA generated in 2025. These projects are expected to cost approximately $50 million, net to Summit’s 70% interest, with approximately $35 million expected in 2026 and the remainder in 2027. These capital requirements are expected to be fully funded with the new term loan at Summit Permian Transmission which is non-recourse to Summit. Further, Double E has launched a binding open season to secure market commitments to support a mainline compression project to expand the pipeline’s capacity from approximately 1.6 Bcf/d to over 2.4 Bcf/d by the end of 2028. The compression expansion remains subject to additional commercial support via incremental long-term take-or-pay agreements and FERC and other regulatory approvals.

Double E Refinancing Transaction

Subsequent to quarter-end, Summit refinanced the Summit Permian Transmission, LLC and Summit Permian Transmission Holdco, LLC capital structure with a new $440 million term loan facility, including a $340 million borrowing at closing, $50 million committed delayed draw facility used to fund the Producers Midstream and other expansion projects, as well as a $50 million uncommitted accordion to fund the expected mainline compression expansion project. Proceeds from the new facility were used to refinance the $112.7 million Summit Permian Transmission term loan, $141.9 million Summit Permian Transmission Holdco’s preferred units², an $85 million one-time distribution to Summit, and pay other fees and expenses. Summit intends to use the $85 million one-time distribution to pay down approximately $45 million of accrued and unpaid dividends on its Series A Preferred Stock and approximately $40 million of ABL borrowings. Repayment of the accrued and unpaid dividends represents a critical step of Summit’s objective to resume dividend payments on its common stock once Summit achieves its long-term leverage target of 3.5x. In addition, the $40 million ABL repayment reduces Summit’s leverage by approximately 0.2x, aligning with its continued focus on corporate de-levering.

Pro Forma Capitalization

Williston Commercial Update

During the fourth quarter, Summit executed a new 10-year crude gathering agreement with a Bakken producer, anchored by a large Area of Dedication covering more than 200,000 acres across its existing footprint in Divide County, North Dakota. The first new pad — consisting of four 3-mile laterals — is expected to be turned in line in the first quarter of 2026. This agreement meaningfully expands Summit’s dedicated acreage and long-term economic inventory supporting its infrastructure, while positioning the Company to pursue additional development opportunities across northern Williams and southern Divide Counties. With the efficiency gains associated with 3-mile laterals, these areas have become economically attractive in the current oil price environment. As Bakken producers continue expanding activity in the northern and western portions of the basin, Summit expects increasing commercial momentum and growth around its Polar and Divide systems.

Fourth Quarter 2025 Business Highlights

SMC’s average daily natural gas throughput on its wholly owned operated systems decreased 3.4% to 894 MMcf/d, while liquids volumes decreased 8.3% to 66 Mbbl/d, relative to the third quarter of 2025. Double E pipeline transported an average of 861 MMcf/d and contributed $8.7 million in Adjusted EBITDA, net to SMC, for the fourth quarter of 2025.

Natural gas price-driven segments:

• Natural gas price-driven segments generated $31.5 million in combined Segment Adjusted EBITDA, a $4.6 million decrease relative to the third quarter and combined capital expenditures of $9.2 million.
• Mid-Con Segment Adjusted EBITDA totaled $21.5 million, a decrease of $2.1 million relative to the third quarter of 2025, primarily due to a decrease in volume throughput on the system. Volume throughput on the system decreased by 3.7% primarily due to natural production declines partially offset by six new well connections in the Arkoma. Subsequent to quarter end, six new wells were connected in the Arkoma. There is currently one rig running in the Arkoma, with 21 DUCs behind the system, including 17 DUCs in the Barnett, which are all expected to come online in 2026.
• Piceance Segment Adjusted EBITDA totaled $10.0 million, a decrease of $2.5 million relative to the third quarter of 2025, primarily due to realization of previously deferred revenue in the third quarter and a 5.4% decrease in volume throughput. There were no new wells connected to the system during the fourth quarter.

Oil price-driven segments:

• Oil price-driven segments generated $36.6 million of combined Segment Adjusted EBITDA, representing a $1.1 million decrease relative to the third quarter of 2025, and had combined capital expenditures of $9.0 million.
• Rockies Segment Adjusted EBITDA totaled $27.8 million, a decrease of $1.2 million relative to the third quarter of 2025, primarily driven by a 8.3% decrease in liquids volume throughput, partially offset by a 1.3% increase in natural gas volume throughput, relative to the third quarter of 2025. The decrease in liquids volumes was primarily driven by natural production declines and no new well connections in the Williston Basin during the quarter. Natural gas volume growth was supported by 33 new well connections in the DJ Basin, which are expected to reach peak production in the second quarter of 2026. There are currently six rigs running and approximately 65 DUCs behind the system.
• Permian Segment Adjusted EBITDA totaled $8.8 million, an increase of $0.1 million relative to the third quarter of 2025, primarily due to a 20.9% increase in volumes shipped on the Double E Pipeline leading to an increase in proportionate Adjusted EBITDA from our Double E joint venture. 

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 $19.1 million in the fourth quarter of 2025, inclusive of maintenance capital expenditures of $4.0 million. Capital expenditures in the fourth quarter of 2025 were primarily related to pad connections in the Rockies and Mid-Con segments.

2026 Guidance

SMC is releasing guidance for 2026, which is summarized in the table below. These projections are subject to risks and uncertainties as described in the “Forward-Looking Statements” section at the end of this release.

SMC’s guidance range is anchored by recent drilling and completion schedules provided by its customers and is reflective of the current commodity price environment. The Company’s approach to its 2026 guidance is consistent with the framework used for its 2025 guidance range. If SMC’s producer customers hit their production targets and timing of planned well connects, the Company would expect to be near the high end of the 2026 guidance range. The midpoint of the guidance range reflects a conservative, yet appropriate, level of risking to the most recent drill schedules and volume forecasts provided by its customers. The low end of the guidance range reflects additional delays to customer drilling and completion schedules and planned well connects.

SMC expects approximately 116 to 126 well connections in 2026. Of the expected well connections in 2026, approximately 20% are natural gas-oriented wells and approximately 80% are crude oil-oriented wells. Customers are currently running seven rigs behind SMC systems, with approximately 90 DUCs, providing line of sight to the 2026 estimated well connections and associated volume growth.

SMC expects its natural gas gathering system throughput to range from 875 MMcf/d to 920 MMcf/d. Double E existing take-or-pay contracts of 1,115 MMcf/d is expected to increase to 1,285 MMcf/d when the Producers Midstream II and other projects are placed into service, as early as the fourth quarter of 2026. Liquids volumes are expected to range from 65 Mbbl/d to 90 Mbbl/d.

The guidance outlook also reflects a reduction in MVC shortfall payments in the Piceance from $16.9 million in 2025 to approximately $13.0 million in 2026, and excludes approximately $2 million of deferred revenue that benefited 2025 results.

The midpoint of the guidance range assumes strip commodity prices as of February 19, 2026, implying an average 2026 Henry Hub price of approximately $3.40 per MMBtu and WTI of approximately $64 per barrel.

Adjusted EBITDA is expected to range from $225 million to $265 million. SMC’s 2026 capital expenditure guidance of $50 million to $70 million, excluding Double E, includes capital reimbursements related to specific development projects with certain customers. The Company’s full year 2026 growth capex guidance range is primarily related to new pad connections in the Rockies and Mid-Con segments. Included in this range is approximately $15 million to $20 million of maintenance capex. Double E capital expenditures for 2026 are expected to be approximately $35 million, net to SMC, primarily related to a new plant connection and downstream connections associated with the recently announced shipper contracts.

Capital & Liquidity

As of December 31, 2025, SMC had $9.3 million in unrestricted cash on hand and $113 million drawn under its $500 million ABL Revolver with $386 million of borrowing availability, after accounting for $0.8 million of issued, but undrawn letters of credit. As of December 31, 2025, SMC’s gross availability based on the borrowing base calculation in the credit agreement was $810 million, which is $310 million greater than the $500 million of lender commitments to the ABL Revolver. As of December 31, 2025, SMC was in compliance with all financial covenants, including interest coverage of 2.7x relative to a minimum interest coverage covenant of 2.0x and first lien leverage ratio of 0.5x relative to a maximum first lien leverage ratio of 2.5x. As of December 31, 2025, SMC reported a total leverage ratio of approximately 4.1x, excluding the potential earnout liability in connection with the Tall Oak Acquisition.

As of January 2, 2026, the Permian Transmission Credit Facility balance was $112.7 million a reduction of $4.3 million relative to the September 30, 2025 balance of $117.0 million due to scheduled mandatory amortization. Summit Midstream Permian has $3.8 million of cash-on-hand as of January 2, 2026.

Subsequent to quarter-end, Summit Permian Transmission, LLC entered into a new $440 million senior secured term facility, which includes a $50 million committed accordion feature and a $50 million uncommitted accordion feature (the “Term Facility”) maturing in March 2031. Proceeds from the Term Facility were used to refinance Summit Permian Transmission’s existing credit facility, Summit Permian Transmission Holdco’s preferred units, fund an $85 million restricted payment to SMC, provide liquidity to fund SMC’s share of capital expenditures including those associated with the recently announced expansion projects, and pay other fees and expenses.

MVC Shortfall Payments

SMC billed its customers $4.3 million in the fourth quarter of 2025 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 fourth quarter of 2025, SMC recognized $4.3 million of gathering revenue associated with MVC shortfall payments. SMC had no adjustments to MVC shortfall payments in the fourth quarter of 2025. SMC’s MVC shortfall payment mechanisms contributed $4.3 million of total Adjusted EBITDA in the fourth quarter of 2025.

Quarterly Dividend

The Board of Directors of Summit Midstream Corporation continued to suspend cash dividends payable on the common stock for the period ended December 31, 2025. The quarterly cash dividend on the Series A Preferred Stock, for the period ended March 14, 2026, will be paid to preferred shareholders of record as of the close of business on March 2, 2026.

The Board of Directors approved the full repayment of all previously deferred Series A Preferred Stock dividends, payable on March 27, 2026 to holders of record as of the close of business on March 17, 2026.

Fourth Quarter 2025 Earnings Call Information

SMC will host a conference call at 10:00 a.m. Eastern on March 17, 2026, to discuss its quarterly operating and financial results. The call can be accessed via teleconference at the following link:  Q4 2025 Summit Midstream Corporation Earnings Conference Call (https://register-conf.media-server.com/register/BI12ac80a058874aaa998fdc335346beed). Once registration is completed, participants will receive a dial-in number along with a personalized PIN to access the call. While not required, it is recommended that participants join 10 minutes prior to the event start. The conference call, live webcast and archive of the call can be accessed through the Investors section of SMC’s website at www.summitmidstream.com.

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, Segment Adjusted EBITDA, Distributable Cash Flow, and Free Cash Flow, non-GAAP financial measures.

Adjusted EBITDA

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, income tax benefit, income (loss) from equity method investees and other noncash income or gains. Because Adjusted EBITDA may be defined differently by other entities in our industry, our definition of this non-GAAP financial measure may not be comparable to similarly titled measures of other entities, thereby diminishing its utility.

Management uses Adjusted EBITDA in making financial, operating and planning decisions and in evaluating our financial performance. Furthermore, management believes that Adjusted EBITDA 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 is used as a supplemental financial measure to assess:

• the ability of our assets to generate cash sufficient to make future potential cash dividends 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 MVC 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.

Adjusted EBITDA has limitations as an analytical tool and investors should not consider it in isolation or as a substitute for analysis of our results as reported under GAAP. For example:

• certain items excluded from Adjusted EBITDA 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 does not reflect our cash expenditures or future requirements for capital expenditures or contractual commitments;
• Adjusted EBITDA does 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 does not reflect any cash requirements for such replacements.

We compensate for the limitations of Adjusted EBITDA as an analytical tool by reviewing the comparable GAAP financial measures, understanding the differences between the financial measures and incorporating these data points into our decision-making process.

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) adjustments related to capital reimbursement activity, (vi) stock-based and noncash compensation, (vii) impairments and (viii) other noncash expenses or losses, less other noncash income or gains. 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 during the respective period.

Distributable Cash Flow

We define Distributable Cash Flow as Adjusted EBITDA, as defined above, less cash interest paid, cash paid for taxes, net interest expense accrued and paid on the senior notes, and maintenance capital expenditures.

Free Cash Flow

We define free cash flow as distributable cash flow attributable to common and preferred shareholders less growth capital expenditures, less investments in equity method investees, less dividends to common and preferred shareholders. Free cash flow excludes proceeds from asset sales and cash consideration paid for acquisitions.

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 Corporation

SMC is a value-driven corporation 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. SMC 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 five unconventional resource basins: (i) the Williston Basin, which includes the Bakken and Three Forks shale formations in North Dakota; (ii) the Denver-Julesburg Basin, which includes the Niobrara and Codell shale formations in Colorado and Wyoming; (iii) the Fort Worth Basin, which includes the Barnett Shale formation in Texas; (iv) the Arkoma Basin, which includes the Woodford and Caney shale formations in Oklahoma; and (v) the Piceance Basin, which includes the Mesaverde formation as well as the Mancos and Niobrara shale formations in Colorado. SMC has an equity method investment in Double E Pipeline, LLC, which provides interstate natural gas transportation service from multiple receipt points in the Delaware Basin to various delivery points in and around the Waha Hub in Texas. SMC 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 include, without limitation, any statement that may project, indicate or imply future results, events, performance or achievements and may contain the words “expect,” “intend,” “plan,” “anticipate,” “estimate,” “believe,” “will be,” “will continue,” “will likely result,” and similar expressions, or future conditional verbs such as “may,” “will,” “should,” “would” and “could.” In addition, any statement concerning future financial performance (including future revenues, earnings or growth rates), payment of dividends on any series of stock, ongoing business strategies and possible actions taken by SMC or its subsidiaries are also forward-looking statements. Forward-looking statements also contain known and unknown risks and uncertainties (many of which are difficult to predict and beyond management’s control) that may cause SMC’s actual results in future periods to differ materially from anticipated or projected results. An extensive list of specific material risks and uncertainties affecting SMC is contained in its 2025 Annual Report on Form 10-K filed with the Securities and Exchange Commission (the “SEC”) on March 16, 2026, 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 SMC undertakes no obligation to update or revise any forward-looking statements to reflect new information or events.

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SOURCE Summit Midstream Corporation

832-413-4770, ir@summitmidstream.com