Enbridge announced Wednesday it has agreed to acquire Salt Creek Midstream’s crude oil gathering business for $600 million in cash, extending its footprint deeper into the Permian Basin’s Delaware sub-basin, one of the most productive and competitive crude-producing regions in North America. The deal gives Enbridge full ownership of the Orla and Wink North gathering systems, along with a 50% interest in the Delaware Crossing system, a joint venture it will now share with Chevron. Together, the acquired infrastructure spans roughly 500 miles of crude gathering pipeline, serving more than 20 producers across approximately 320,000 net dedicated acres under long-term agreements averaging about 10 years remaining. The transaction is expected to close later in 2026 and Enbridge says it will be immediately accretive to both distributable cash flow and earnings per share, with the company’s full-year 2026 guidance left unchanged.
While $600 million is a relatively modest transaction for a company with more than $7 billion in annual growth capital capacity, the strategic logic behind it is worth understanding, because it reflects a broader pattern reshaping the entire energy value chain right now, not just Enbridge’s balance sheet. These gathering systems connect directly into several major Permian takeaway pipelines, including Enbridge’s own majority-owned Gray Oak Pipeline, and ultimately feed into the company’s Ingleside Energy Center, the largest crude export terminal in North America. In other words, Enbridge isn’t just buying pipe in the ground, it’s buying the wellhead connections that feed its existing export infrastructure, capturing more of the value chain from the point oil is produced all the way to the point it leaves the country.
That wellhead-to-water strategy matters for a specific reason tied to where Permian production is heading. Output from the Delaware Basin has continued climbing even as producers maintain tighter capital discipline elsewhere, and long-haul export capacity out of the region has been tightening as a result. Owning the gathering systems that feed into export terminals, rather than just the long-haul pipelines themselves, positions Enbridge to capture additional volumes if and when the next wave of Permian takeaway constraints materializes, a bet on the structural trajectory of US shale production rather than a short-term volume play.
For investors tracking the small and microcap energy space, this deal is a useful signal of where consolidation pressure continues to build. Midstream infrastructure, the pipelines, storage, and gathering systems that move crude and natural gas from wellhead to market, has become one of the more actively contested corners of the energy sector this year, as both large integrated players and smaller specialized operators compete for scarce, strategically located assets. Companies like Summit Midstream Corporation, which operates gathering and processing infrastructure across multiple US shale basins, sit in exactly this part of the value chain, and deals of this size and structure offer a useful read on the kind of asset characteristics, long-term contracts, direct export connectivity, and diversified producer bases, that strategic buyers are willing to pay a premium for right now. On the upstream side, smaller independent producers such as InPlay Oil continue benefiting from the same underlying dynamic driving this transaction, sustained demand for Permian and broader shale production that keeps pressure on the infrastructure required to move it to market.
The Enbridge-Salt Creek deal is not a headline-grabbing transaction on its own. But it is a clean, concrete example of the consolidation logic playing out across the entire energy infrastructure landscape, one that smaller midstream and upstream companies operating in the same basins are positioned to benefit from as that trend continues.
CALGARY, AB, Sept. 1, 2026 /CNW/ — InPlay Oil Corp. (TSX: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company”) is pleased to confirm that its Board of Directors has declared a monthly cash dividend of $0.09 per common share payable on September 29, 2026, to shareholders of record at the close of business on September 15, 2026. The monthly cash dividend is expected to be designated as an “eligible dividend” for Canadian federal and provincial income tax purposes.
About InPlay Oil Corp.
InPlay is a junior oil and gas exploration and production company with operations in Alberta focused on light oil production. The company operates long-lived, low-decline properties with drilling development and enhanced oil recovery potential as well as undeveloped lands with exploration possibilities. The common shares of InPlay trade on the Toronto Stock Exchange under the symbol IPO and the OTCQX Exchange under the symbol IPOOF.
For further information please contact: Doug Bartole, President and Chief Executive Officer, InPlay Oil Corp., Telephone: (587) 955-0632; Darren Dittmer, Chief Financial Officer, InPlay Oil Corp., Telephone: (587) 955-0634
HOUSTON, Aug. 31, 2026 /PRNewswire/ — Summit Midstream Corporation (NYSE: SMC) (“Summit”, “SMC” or the “Company”) announced today that Double E Pipeline, LLC (“Double E”) has concluded a successful open season and reached a final investment decision on its previously announced mainline compression expansion project, supported by a new long-term firm transportation agreement with an investment-grade shipper.
Highlights
Reached a final investment decision on the mainline compression expansion, with an expected in-service date in the fourth quarter of 2028
Executed a new long-term take-or-pay firm transportation agreement with an investment-grade shipper for 200 MMcf/d, bringing total contracted firm capacity on Double E to approximately 2.2 Bcf/d
Converted the $50 million uncommitted accordion at Summit Permian Transmission to committed, bringing total committed financing capacity to $100 million and fully funding Summit’s expected Double E capital contributions
Robust future growth opportunities associated with data center developments in Texas and New Mexico and connectivity with additional egress pipelines
Management Commentary
Heath Deneke, President, Chief Executive Officer and Chairman, commented, “Today’s announcement is a significant milestone for Summit and Double E and further demonstrates the importance of the pipeline to producers and processors in the Delaware Basin. Double E provides reliable gas transmission service with access to multiple downstream markets, and we continue to expand that connectivity as the basin grows. The strong shipper interest we have seen through the open season reinforces the value of that position and our confidence in the long-term growth opportunity for Double E.
“The open season resulted in 550 MMcf/d of new long-term take-or-pay commitments which underpinned the final investment decision to move forward with the compression expansion and we continue to advance discussions with multiple shippers to subscribe the remaining 450 MMcf/d of incremental forward haul capacity. With these newly signed contracts, we expect to invest approximately $100 million, net to Summit’s 70% interest, to install the mainline compression station, incremental plant connections and related infrastructure, all of which will be funded entirely with the previously announced term loan at Summit Permian Transmission and the now-committed $50 million accordion. We continue to see tremendous production growth surrounding our Delaware Basin operating footprint and fully expect to enter into long-term contracts for the remaining expansion capacity in the coming months. When the project is fully subscribed, we expect our Permian Segment Adjusted EBITDA to grow from approximately $37 million in 2026 to over $100 million by 2030.”
“As we look into the future for the Double E Pipeline beyond filling the mainline compression expansion capacity to Waha, we are very excited about a new phase of demand-pull growth opportunities that are emerging from data center development in Texas and New Mexico as well as additional egress pipelines that are hungry for enhanced access to Permian gas supply. With our connectivity to numerous gas processing facilities in the basin and the Waha Hub, we are incredibly well positioned to attract those markets to the Double E Pipeline and leverage the bi-directional capability of the system to nearly double the outlook for the business in the years ahead.”
Double E Mainline Compression Expansion
The expansion project consists of the installation of a bi-directional mainline compressor station on the Double E system, which will increase the pipeline’s forward haul capacity to Waha by approximately 900 MMcf/d. The compression project along with new plant connections and related infrastructure is expected to cost approximately $100 million net to Summit’s 70% interest and is expected to be placed in service by the fourth quarter of 2028.
The Double E joint venture has already placed a purchase order for the long-lead gas turbine compression units required for the project, securing manufacturing slots necessary to support the targeted in-service date. The project remains subject to FERC and other customary regulatory approvals.
With the new 200 MMcf/d agreement, Double E has secured approximately 550 MMcf/d of binding long-term take-or-pay commitments through the compression expansion open season. Total contracted firm capacity on the pipeline is now approximately 2.2 Bcf/d, held by a diversified group of primarily investment-grade shippers. Double E continues to advance discussions with additional prospective shippers regarding remaining capacity on the expansion.
Summit Permian Transmission Financing
In connection with the final investment decision, Summit Permian Transmission converted the previously uncommitted $50 million accordion under its existing $440 million senior secured term facility maturing in March 2031 into a committed facility. Combined with the $50 million committed delayed draw term facility established at closing in March 2026, Summit expects to have sufficient commitments to fund all of its expected capital contributions to Double E over the next several years. The Summit Permian Transmission term facility remains non-recourse to SMC.
About Double E Pipeline, LLC
Double E is a 135-mile FERC-regulated interstate natural gas transmission pipeline that commenced operations in November 2021 and provides transportation service from receipt points in the Delaware Basin to various delivery points in and around the Waha Hub in Texas.
Double E is owned by subsidiaries of Summit Midstream Corporation (NYSE: SMC) and ExxonMobil (NYSE: XOM) with an ownership interest of 70% and 30%, respectively. Summit Midstream Permian II, LLC is the operator of Double E.
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.
CALGARY, AB, Aug. 21, 2026 /CNW/ — InPlay Oil Corp. (TSX: IPO) (TASE: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company“) is pleased to announce the closing of its previously announced acquisition of a private oil and gas producer for cash consideration of $54.25 million, prior to closing adjustments (the “Acquisition“). Further details regarding the Acquisition can be found in InPlay’s press release dated August 5, 2026.
The Acquisition adds approximately 1,400 boe/d(1) (85% light oil and NGLs), bringing InPlay’s total Belly River production to approximately 2,000 boe/d and total corporate production to approximately 20,100 boe/d(1) (63% light oil and NGLs). InPlay has identified 50 drilling locations on the acquired assets including over 10 years of Tier 1 drilling inventory(2). The Acquisition was completed at 2.0x net operating income(3)(4) and delivered annualized per-share accretion of 18% to both Adjusted Funds Flow(5) and Free Adjusted Funds Flow (“FAFF”)(3), 12% to oil production per share, and 9% to funds flow per barrel netback.
ADVISORS
ATB Capital Markets acted as financial advisors to InPlay with respect to the Acquisition. Burnet, Duckworth & Palmer LLP acted as legal counsel to InPlay with respect to the Acquisition.
About InPlay Oil Corp.
InPlay Oil Corp. is a growth-oriented, sustainable oil and gas producer focused on long-term value creation for its shareholders. The Company’s operations are centered in the Western Canadian Sedimentary Basin, where InPlay holds a diverse portfolio of oil and natural gas assets. InPlay is committed to delivering strong per-share growth, maintaining a disciplined approach to capital investment, and providing consistent returns to shareholders.
For further information please contact:
Doug Bartole President and Chief Executive Officer InPlay Oil Corp. Telephone: (587) 955-0632
Kevin Leonard Vice President, Business & Corporate Development InPlay Oil Corp. Telephone: (587) 955-0635
Notes:
1.
See “Reader Advisories – Production Breakdown by Product Type” contained within this press release.
2.
See “Reader Advisories – Drilling Locations” for additional details.
3.
Non-GAAP financial measure or ratio. See “Reader Advisories – Non-GAAP and Other Financial Measures” for additional details.
4.
The acquired assets’ sustaining net operating income of $28 million multiplies 1,500 boe/d of sustaining production by the operating netback of $51.75/boe. Operating Netback estimate of $51.75/boe assumes current guidance commodity price assumptions of US$80.50 WTI, US$1.15 MSW differential, $1.75 AECO, 0.73 FX, in addition to $18.50/boe operating and transportation costs, and $16.90/boe royalties.
5.
Capital management measure. See “Non-GAAP and Other Financial Measures” for additional details.
Reader Advisories
Non-GAAP and Other Financial Measures
Throughout this document and other materials disclosed by the Company, InPlay uses certain measures to analyze financial performance, financial position and cash flow. These non-GAAP and other financial measures do not have any standardized meaning prescribed under GAAP and therefore may not be comparable to similar measures presented by other entities. The non-GAAP and other financial measures should not be considered alternatives to, or more meaningful than, financial measures that are determined in accordance with GAAP as indicators of the Company’s performance. Management believes that the presentation of these non-GAAP and other financial measures provides useful information to shareholders and investors in understanding and evaluating the Company’s ongoing operating performance, and the measures provide increased transparency and the ability to better analyze InPlay’s business performance against prior periods on a comparable basis.
Non-GAAP Financial Measures and Ratios
Included in this document are references to the terms “free adjusted funds flow”, “operating income” and “operating netback per boe”. Management believes these measures and ratios are helpful supplementary measures of financial and operating performance and provide users with similar, but potentially not comparable, information that is commonly used by other oil and natural gas companies. These terms do not have any standardized meaning prescribed by GAAP and should not be considered an alternative to, or more meaningful than “profit before taxes”, “profit and comprehensive income”, “adjusted funds flow”, “capital expenditures”, “net debt” or assets and liabilities as determined in accordance with GAAP as a measure of the Company’s performance and financial position.
Free Adjusted Funds Flow
Management considers FAFF an important measure to identify the Company’s ability to improve its financial condition through debt repayment and its ability to provide returns to shareholders. FAFF should not be considered as an alternative to or more meaningful than AFF as determined in accordance with GAAP as an indicator of the Company’s performance. FAFF is calculated by the Company as AFF less exploration and development capital expenditures and property dispositions (acquisitions) and is a measure of the cashflow remaining after capital expenditures before corporate acquisitions that can be used for additional capital activity, corporate acquisitions, repayment of debt or decommissioning expenditures or potentially return of capital to shareholders.
Operating Income/Operating Netback per boe/Operating Income Multiple
InPlay uses “operating income”, “operating netback per boe” and “operating income profit margin” as key performance indicators. Operating income is calculated by the Company as oil and natural gas sales less royalties, operating expenses and transportation expenses and is a measure of the profitability of operations before administrative, share-based compensation, financing and other non-cash items. Management considers operating income an important measure to evaluate its operational performance as it demonstrates its field level profitability. Operating income should not be considered as an alternative to or more meaningful than net income as determined in accordance with GAAP as an indicator of the Company’s performance. Operating netback per boe is calculated by the Company as operating income divided by average production for the respective period. Management considers operating netback per boe an important measure to evaluate its operational performance as it demonstrates its field level profitability per unit of production. Operating income multiple is calculated by the Company as the Acquisition consideration divided by operating income for the acquired assets for the relevant period. Management considers operating income multiple a key performance indicator as it is a key metric used to evaluate the Acquisition in comparison to other transactions. Refer below for a calculation of the operating income multiple in relation to the Acquisition.
2026E
Net Consideration (before adjustments)
$ millions
$54.25
Operating Income
$ millions
$26.5
Operating Income Multiple
2.0x
Capital Management Measures
Adjusted Funds Flow
Management considers adjusted funds flow to be an important measure of InPlay’s ability to generate the funds necessary to finance capital expenditures. Adjusted funds flow is a GAAP measure and is disclosed in the notes to the Company’s financial statements for the three and six months ended June 30, 2026. All references to adjusted funds flow throughout this document are calculated as funds flow adjusting for foreign exchange loss, transaction and integration costs and decommissioning expenditures. Foreign exchange loss is primarily an unrealized movement on the Company’s NIS denominated Bonds due to movements in the CAD/NIS exchange rate. In addition, InPlay has effectively mitigated its exposure to fluctuations in the CAD to NIS exchange rate on the NIS denominated Bond by entering into NIS/CAD foreign exchange hedges with notional amounts and terms that align with the future cash outflow requirements of the Bonds. Therefore, at the end of the life of the Bonds, the FX impact on the Company will be insignificant. Transaction and integration costs are non-recurring costs for the purposes of an acquisition, making the exclusion of these items relevant in Management’s view to the reader in the evaluation of InPlay’s operating performance. Decommissioning expenditures are adjusted from funds flow as they are incurred on a discretionary and irregular basis and are primarily incurred on previous operating assets. The Company also presents adjusted funds flow per share whereby per share amounts are calculated using weighted average shares outstanding consistent with the calculation of profit per common share.
Production Breakdown by Product Type:
Disclosure of production on a per boe basis in this press release consists of the constituent product types as defined in National Instrument 51-101, Standards of Disclosure for Oil and Gas Activities (“NI 51-101“) and their respective quantities disclosed in the table below:
Light and Medium Crude oil(bbls/d)
NGLs(boe/d)
Conventional Natural gas(Mcf/d)
Total(boe/d)
2025 Average Production
8,143
2,180
40,323
17,043
2026 Annual Guidance
9,605
2,290
43,530
19,150(1)
Acquired Assets
1,125
92
1,100
1,400
Post-Acquisition
10,500
2,200
44,400
20,100
Notes:
1.
This reflects the mid-point of the Company’s 2026 production guidance range of 18,900 to 19,400 boe/d.
2.
With respect to forward‑looking production guidance, product type breakdown is based upon management’s expectations based on reasonable assumptions but are subject to variability based on actual well results.
BOE Equivalent
Barrel of oil equivalents or BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given that the value ratio based on the current price of crude oil as compared to natural gas is significantly different than the energy equivalency of 6:1, utilizing a 6:1 conversion basis may be misleading as an indication of value.
Drilling Locations
This press release discloses drilling inventory in two categories: (a) proved locations; and (b) probable locations. Proved locations and probable locations are derived from the independent reserves evaluation effective December 31, 2025 for the acquired assets and account for drilling locations that have associated proved and/or probable reserves, as applicable. Of the 50 net drilling locations identified herein, 25.5 are proved locations and 1.8 are probable locations. The drilling locations considered for future development will ultimately depend upon the availability of capital, regulatory approvals, seasonal restrictions, oil and natural gas prices, costs, actual drilling results, additional reservoir information that is obtained and other factors.
Booked locations are proved locations and probable locations derived from the independent reserves evaluation effective December 31, 2025 for the acquired assets, respectively, and account for drilling locations that have associated proved and/or probable reserves, as applicable. We have not risked potential drilling locations, and actual locations drilled and quantities that may be ultimately recovered may differ substantially from estimates. We make no commitment to drill all of the drilling locations that have been identified. Factors affecting ultimate recovery include the scope of our on‐going drilling program, which will be directly affected by the availability of capital, drilling, and production costs, availability of drilling and completion services and equipment, drilling results, lease expirations, regulatory approvals, and geological and mechanical factors. Estimates of reserves, type/decline curves, EURs, per‐well economics, and resource potential may change significantly as development of our oil and gas assets provides additional data. Additionally, initial production rates are subject to decline over time and should not be reflective of sustained production levels.
Abbreviations
2026E
Estimate for the year ending December 31, 2026
AECO
Alberta Energy Company “C” Meter Station of the NOVA Pipeline System
Michael Kupinski, Director of Research, Equity Research Analyst, Digital, Media & Technology , Noble Capital Markets, Inc.
George Proost, Research Associate, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Shareholder debt fully retired, materially improving credit quality. On August 3, 2026, VivoPower eliminated 100% of its $28.8m shareholder debt principal owed to AWN Holdings. $16.5 million was converted under PIPE 2 and $12.3 million was repaid in cash. The move removes the associated interest expense and materially improves credit quality ahead of the Nordic AI buildout, leaving no principal obligation to AWN.
PIPE secured to fund the AI conversion. A $50 million PIPE priced at US$7.50 per share on July 29, 2026, was led by Blue Sky Capital, alongside Nordic, EU, and GCC institutional and family-office investors. Proceeds are directed at the Mo i Rana AI data center conversion in Norway and further debt reduction.
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This Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).
*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Mobix Labs (Nasdaq: MOBX), a semiconductor and defense electronics company, announced Wednesday it has signed a definitive all-stock agreement to acquire Special Project Delivery, a pre-revenue infrastructure development platform pursuing rare earth elements, critical minerals, energy storage, and Western US water resources. The deal is structured with consideration capped at 4.8 million Mobix shares, with closing targeted before the end of 2026, subject to shareholder approval.
Shares of Mobix climbed 5% in premarket trading following the announcement, recovering from a nearly 6% decline the prior session.
This is not a typical semiconductor company acquisition. Mobix currently supplies advanced wireless components and RF technology used in aerospace, defense, and homeland security systems, work that includes existing relationships with Boeing on 737 aircraft programs. The SPD deal adds an entirely different layer to that business: upstream control over the raw materials, energy infrastructure, and water resources that defense manufacturing and critical mineral processing actually depend on.
Mobix Chairman Jim Peterson framed the deal as central to the company’s broader National Security Matters initiative, describing control of strategic domestic mineral rights as fundamental to America’s long-term industrial strength. That initiative, launched earlier this year, has already included a separate acquisition of drone maker Vision Aerial, positioning Mobix as a company trying to assemble components, autonomous systems, and now raw materials under a single national security platform, rather than remaining a narrow RF and semiconductor supplier.
Investors need to understand what this transaction is and is not. SPD is explicitly described as pre-revenue, meaning it currently generates no sales. The company’s positioning across rare earth elements, critical minerals, energy storage, and water infrastructure remains largely conceptual at this stage, with no specific mineral deposits, resource grades, separation technology, capital expenditure estimates, permitting status, or customer commitments disclosed publicly as part of this announcement. Mobix itself is a microcap company that has carried substantial losses and limited liquidity in its own recent financial history.
This combination of a loss-making microcap acquirer and a pre-revenue target operating in a capital-intensive, multi-year development category, rare earth and critical mineral processing, is a materially higher-risk profile than a typical revenue-generating acquisition. The strategic thesis, positioning around America’s push to reduce dependence on foreign rare earth supply chains, is genuinely timely and aligned with a broader theme playing out across defense and industrial policy in 2026. But thematic alignment and executable, funded infrastructure are two very different things at this stage of the deal.
Why the Theme Itself Is Worth Watching Regardless
Independent of this specific transaction’s execution risk, the broader push toward domestic rare earth and critical mineral supply chains remains one of the more significant structural themes in the small cap space this year. Government-backed investment in quantum computing, semiconductor manufacturing, and critical minerals has accelerated sharply, and smaller companies positioning early in that supply chain, whether through actual production assets or, as in this case, an earlier-stage development platform, are drawing real investor attention as a result.
For investors tracking this space, the Mobix-SPD deal is a useful case study in distinguishing between a company aligning itself with a compelling macro theme and a company that has actually built or acquired producing assets within that theme. The rare earth and critical minerals buildout in the United States is real and accelerating. Whether any single microcap deal successfully executes on that opportunity is a separate question entirely, one that depends on capital access, permitting, technical validation, and years of infrastructure development still ahead.
Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Second Quarter FY 2026 Financial Results. Summit Midstream generated $155.0 million of revenue, up 10.6% from the prior year quarter, and reported net income attributable to Summit Midstream Corp. of $1.6 million, or $0.11 per share, compared with a net loss of $8.0 million, or $(0.66) per share, during the prior year period. Adj. EBITDA amounted to $60.7 million compared to $61.1 million during the prior year period, as stronger Rockies and Permian performance was offset by weaker Mid-Con and Piceance segment results. We had forecast revenue of $144.4 million and adj. EBITDA of $59.7 million. Distributable cash flow increased to $36.8 million from $32.4 million, and free cash flow increased modestly to $9.4 million compared to $9.2 million during the second quarter of 2025. Sequentially, SMC’s second quarter results demonstrated meaningful improvement, supported by stronger producer activity and higher throughput across much of the portfolio.
Guidance Narrowed. Management narrowed its FY 2026 guidance range for adj. EBITDA to $235 million to $255 million from $225 million to $265 million, and increased capital expenditure guidance to $100 million to $120 million from $85 million to $105 million. The increased capital budget is primarily tied to approximately 30 additional Williston Basin well connections and incremental investment in the Double E pipeline, while accelerating producer activity, additional firm transportation agreements, and a potential Double E compression expansion support the longer-term growth outlook.
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Accretive Strategic Acquisition. InPlay Oil announced the acquisition of a private oil and gas producer for C$54.25 million, adding approximately 1,400 boe/d of oil-weighted production and increasing company-wide production to more than 20,100 boe/d. The acquired assets are contiguous with InPlay’s existing operations, enabling approximately C$2.5 million of annual cost synergies, while adding 50 drilling locations and immediately enhancing adjusted funds flow and free adjusted funds flow on a per-share basis. The transaction is expected to close by the end of August, subject to customary closing conditions. Post-close, InPlay expects to have more than 450 total drilling locations, including approximately 230 Tier-1 locations.
Corporate Guidance. InPlay continues to execute strongly, with recent Cardium wells materially outperforming expectations and being drilled ahead of schedule, allowing InPlay to expand its 2026 drilling program to 17 net wells on a pro forma basis. Reflecting stronger operational performance and the acquisition, management increased 2026 guidance, including adjusted funds flow (AFF) to C$161 million to C$169 million, free adjusted funds flow (FAFF) to C$79 million to C$89 million, and FAFF yield to 19% to 21%, despite higher capital spending of C$80 million to C$82 million.
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*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
CALGARY, AB, Aug. 5, 2026 /CNW/ — InPlay Oil Corp. (TSX: IPO) (TASE: IPO) (OTCQX: IPOOF) (“InPlay” or the “Company“) is pleased to announce that it has entered into a definitive agreement today to acquire a private oil and gas producer for cash consideration of $54.25 million, prior to closing adjustments (the “Acquisition“).
The Acquisition supports InPlay’s long-term strategy of building a disciplined and sustainable light oil focused growth company. The Acquisition builds on InPlay’s proven track record of executing highly accretive acquisitions, having successfully completed five strategic acquisitions over the past decade that have helped increase production 10x and grow total proved plus probable reserves 13.5x. The acquired assets are currently producing approximately 1,400 boe/d(1) (85% light oil and NGLs) which will increase InPlay’s production to over 20,100 boe/d(1) (62 – 63% light oil and NGLs), with light oil production expected to increase to over 10,500 bbl/d. The high oil weighting of the acquired assets further enhances InPlay’s strong netbacks, providing meaningful accretion to Adjusted Funds Flow (“AFF“)(2) and Free Adjusted Funds Flow (“FAFF“)(3) on a per share basis. The acquired assets generate strong cash flow and free cash flow which will enhance InPlay’s shareholder return strategy. InPlay is forecasted to generate FAFF of approximately $79 – $89 million for 2026 on a pro forma basis, including only four months for the acquired assets, which equates to a FAFF yield(3) of 20%. InPlay pays a dividend of $0.09 per month ($1.08 per year), which equates to a dividend yield of 7.2%. In addition, InPlay recently implemented a Normal Course Issuer Bid, pursuant to which the Company repurchased 0.5% of basic shares outstanding for cancellation during the month of June.
ACQUISITION HIGHLIGHTS
Highly Accretive Acquisition Metrics: Purchase price represents 2.0x net operating income(3) and 27% FAFF yield; per-share accretion of 18% to both AFF and FAFF on an annualized basis; 12% accretion to oil production per share, and 9% accretion to funds flow per barrel netback.
Enhanced Free Adjusted Funds Flow with Growth Potential: InPlay forecasts the acquired assets require sustaining capital of approximately $12 million to reach and maintain production of approximately 1,500 boe/d. Based on an operating netback(3) of approximately $51.75/boe(4), the acquired assets generate sustaining net operating income(3) of $28 million and FAFF of $16 million prior to accounting for synergies.
Acquired Assets are Contiguous with InPlay Assets Providing Significant Synergies: The acquired assets directly offset the Company’s existing operations and are supported by Company owned and operated facilities and infrastructure, creating meaningful operational synergies and enhancing the efficiency of future development. The Company expects to integrate the acquired assets without adding corporate office personnel. As a result of these synergies, the Acquisition is expected to generate approximately $2.5 million in annual cost savings, with the majority captured immediately post closing.
Expands InPlay’s Belly River Position: Pro forma the Acquisition, InPlay will be producing approximately 2,000 boe/d(1) from the Belly River, which at approximately 85% liquids weighting offers strong netbacks and high rate of return development opportunities.
Sustainability and Drilling Inventory: The acquired assets include 50 identified drilling locations, 75% of which are Tier 1 inventory(6) with expected payouts of less than 1.5 years at US $70/bbl WTI pricing.
“This Acquisition represents another important step in advancing InPlay’s strategy of building a disciplined, sustainable light oil company which includes strategic acquisitions” commented Doug Bartole, President and Chief Executive Officer of InPlay. “While modest in size, the Acquisition is a smart and highly accretive transaction that is expected to generate meaningful value relative to the capital invested. The acquired assets are highly complementary to our existing operations, provide meaningful operating and infrastructure synergies, and add a deep inventory of high-return drilling opportunities within our core area. The Acquisition is expected to be immediately accretive to adjusted funds flow and free adjusted funds flow per share, while maintaining conservative leverage and further enhancing our ability to generate sustainable returns for shareholders.”
ACQUISITION DETAILS
InPlay has entered into an arrangement agreement (the “Arrangement Agreement“) with a privately held arm’s length oil and gas producer (the “Vendor“), to acquire all of the issued and outstanding shares of the Vendor for cash consideration of $54.25 million, prior to closing adjustments. Concurrent with the execution of the Arrangement Agreement, certain shareholders of the Vendor, representing in excess of 72% of the Vendor shares outstanding, have entered into irrevocable written resolutions in support of the Acquisition. The Acquisition is expected to close by the end of August 2026, subject to the satisfaction or waiver of customary closing conditions.
The Acquisition will be funded by a draw on InPlay’s $190 million credit facility, with an expanded borrowing base totalling $250 million(11). Based on pro forma guidance as outlined below, InPlay anticipates Q4-2026 net debt to EBITDA(3) of 1.2x – 1.3x. The Company retains strong financial flexibility including an estimated working capital(5) surplus at June 30, 2026 of approximately $19.4 million and maintains unique access to the Israeli bond and equity markets. InPlay’s series A senior unsecured bonds (which are listed on the Tel Aviv Stock Exchange) are currently trading at a yield to maturity of approximately 6.1% and include a tap feature of approximately $115 million.
The acquired assets are currently producing approximately 1,400 boe/d with the latest well coming on stream in Q1 2026. InPlay plans to drill 2.0 net Belly River wells on the acquired assets post-closing and forecasts the acquired assets will require sustaining capital of approximately $12 million to reach and maintain annual average production of approximately 1,500 boe/d. Based on an operating netback of approximately $51.75/boe, the acquired assets generate sustaining net operating income of $28 million, resulting in sustaining FAFF of $16 million. The acquired assets contain 50 net drilling locations, and subject to supportive commodity prices, the acquired assets are expected to offer strong growth potential in excess of the target sustaining production.
The Acquisition’s purchase price represents approximately 2.0x operating income and is highly accretive to InPlay on both AFF and FAFF per share metrics while maintaining conservative corporate leverage ratios. A summary of the relevant metrics of the Acquisition is as follows:
OPERATIONS UPDATE
InPlay’s capital program for the second quarter of 2026 consisted of completing and bringing online three gross (3.0 net) Cardium wells in Pembina drilled in the first quarter of 2026, and the drilling and completion of three gross (3.0 net) additional Cardium wells also in Pembina. The most recent three wells were drilled approximately 40 days ahead of schedule, as the Company was able to access the field earlier than is normally anticipated during spring break-up. These wells were brought on production in late May and have materially exceeded internal expectations. Initial production (“IP“) rates for these three wells are as follows:
The three wells drilled in the first quarter continue to deliver strong results ahead of internal expectations. The IP rates for these wells are as follows:
InPlay’s year to date capital program has been completed below budget, resulting in strong capital efficiencies and continuing the “more with less” performance achieved in 2025. Supported by enhanced efficiencies and strong commodity prices, InPlay now plans to drill a total of 15.0 net Cardium wells in 2026, including 7.0 net Cardium wells during the second half of the year, for total capital expenditures of approximately $73 – $74 million, prior to incorporating the expanded pro forma capital program. This compares with InPlay’s original 2026 capital program of $66 million to $74 million, which contemplated the drilling of 12.0 to 14.0 net wells.
Additionally, InPlay plans to drill 2.0 net Belly River wells on the newly acquired assets, bringing the pro forma 2026 drilling program to a total of 17.0 net wells and combined capital expenditures of approximately $80 – $82 million.
In addition, InPlay plans to accelerate its asset retirement closure spend to reduce its decommissioning liability. This increase in asset retirement spending is supported by enhanced FAFF resulting from a more efficient 2026 capital program, stronger commodity prices and an expanded asset base associated with the Acquisition.
UPDATED 2026 PRO FORMA GUIDANCE
InPlay is also updating its previously announced 2026 guidance as follows:
ADVISORS
Burnet, Duckworth & Palmer LLP is acting as legal counsel to InPlay with respect to the Acquisition.
National Bank Financial Inc. (“NBF”) is acting as Exclusive Financial Advisor to the Vendor with respect to the Acquisition. NBF has provided the Vendor with a fairness opinion that the consideration to be received by the shareholders of the Vendor is fair, from a financial point of view, to the shareholders of the Vendor.
An updated corporate presentation will be available on our website in due course. For further information please contact:
Doug Bartole President and Chief Executive Officer InPlay Oil Corp. Telephone: (587) 955-0632
Kevin Leonard Vice President Corporate & Business Development InPlay Oil Corp. Telephone: (587) 955-0635
Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.
Refer to the full report for the price target, fundamental analysis, and rating.
Updating estimates. We have increased our Q2 FY2026 revenue, adjusted funds flow (AFF), and AFF per share estimates to C$122.0 million, C$49.6 million, and C$1.77, respectively, from C$104.0 million, C$36.2 million, and C$1.29. While we have lowered our production estimate to 18,663 barrels of oil equivalent per day (boe/d) from 18,875 boe/d due to Q2 weather impacts, the increases in our estimates are largely due to higher crude oil prices. For FY 2026, we now project revenue, AFF, and AFF per share of C$425.6 million, C$162.5 million, and C$5.80, respectively, compared to our prior estimates of C$406.2 million, C$148.4 million, and C$5.29. Our FY 2026 average production forecast of 18,900 boe/d is unchanged.
Outlook. InPlay has approximately 190 Tier 1 drilling locations that provide an estimated 10 to 15 years of high-return inventory. The company’s low-decline asset base supports sustainable free cash flow generation while limiting capital requirements needed to maintain production. Conservative leverage provides capacity for future acquisitions while maintaining shareholder returns through the dividend.
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This Company Sponsored Research is provided by Noble Capital Markets, Inc., a FINRA and S.E.C. registered broker-dealer (B/D).
*Analyst certification and important disclosures included in the full report. NOTE: investment decisions should not be based upon the content of this research summary. Proper due diligence is required before making any investment decision.
HOUSTON, July 30, 2026 /PRNewswire/ — Summit Midstream Corporation (NYSE: SMC) (“Summit”, “SMC” or the “Company”) announced today that it will report operating and financial results for the second quarter of 2026 on Monday, August 10, 2026, after the close of trading on the New York Stock Exchange.
Second Quarter 2026 Earnings Call
SMC will host a conference call at 10:00 a.m. Eastern on August 11, 2026, to discuss its quarterly operating and financial results. The call can be accessed via teleconference at: Q2 2026 Summit Midstream Corporation Earnings Conference Call (https://register-conf.media-server.com/register/BI8cebf785fce846a9bb80ae80660d3cbc). 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.
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.
Magnolia Oil and Gas (NYSE: MGY) announced Monday it has entered into a definitive purchase agreement to acquire WildFire Energy for approximately $4.06 billion, marking the largest acquisition in the company’s history and one of the most significant domestic upstream deals of 2026. WildFire, backed by private equity firms Warburg Pincus and Kayne Anderson, operates in the same South Texas basin where Magnolia has built its entire business, making this a pure concentration play rather than a diversification move.
Under the terms of the agreement, WildFire owners will receive 32.2 million shares of Magnolia’s Class A common stock, and Magnolia will assume $600 million in outstanding notes due in 2029. The transaction is expected to close in late Q3 2026. Committed financing has been arranged through JPMorgan Chase and Citigroup.
What Magnolia Is Actually Getting
The deal goes well beyond additional drilling locations. WildFire’s assets are concentrated in the Eagle Ford Shale and Austin Chalk formations in the Giddings area of South Texas, directly adjacent to and overlapping with Magnolia’s existing operations. That geographic overlap is central to the deal thesis because it allows Magnolia to integrate the acquired production into its existing infrastructure with minimal incremental investment.
Two components of the transaction stand out from a typical upstream acquisition. First, the deal includes a sand mine that supplies approximately 80% of Magnolia’s current annual sand consumption, including 100% of WildFire’s sand requirements, with additional third-party sales on top. Controlling your own frac sand supply in a market where sand costs represent a meaningful share of well completion expenses is a structural cost advantage that compounds over every well drilled.
Second, the transaction includes more than 500 miles of gas gathering pipelines in the Giddings area. Owning midstream infrastructure rather than paying third-party gathering and processing fees directly improves operating margins on every barrel produced. For investors who follow midstream economics, companies like Summit Midstream Partners understand exactly how valuable that kind of infrastructure control can be at scale.
The Shareholder Return Story
Magnolia is framing this as a free cash flow accretion story above all else. The confidence in the acquired asset quality translated into an immediate 9% increase in the quarterly dividend to $0.18 per share, payable in Q3 2026. The company also reaffirmed its ongoing commitment to repurchasing at least 1% of outstanding shares per quarter.
On the production side, Magnolia reported Q2 total production averaging 106,100 barrels of oil equivalent per day, with D&C capital of $125 million and $296 million of cash on the balance sheet at quarter end. The company raised its full-year 2026 standalone production growth guidance from 5% to 6% alongside the deal announcement.
The Broader E&P Consolidation Signal
For investors tracking domestic energy producers in the small and microcap space, the Magnolia-WildFire combination reinforces a consolidation pattern that has been accelerating throughout 2026. Private equity-backed E&P companies that built significant acreage positions during the downturn are now exiting to public company buyers at scale. The acquirers with the strongest balance sheets, the lowest cost structures, and the most disciplined capital allocation frameworks are the ones winning the assets.
That dynamic creates a dual opportunity for smaller energy names. Companies like InPlay Oil and Gas and Alliance Resource Partners that operate with similar discipline in their respective basins represent the kind of focused, well-run operators that either benefit from the same elevated pricing environment driving Magnolia’s economics or become attractive consolidation targets themselves as the deal cycle continues.
The brief window of optimism that followed the US-Iran ceasefire is closing fast. Oil shipments through the Strait of Hormuz, which had recovered to roughly 50% of pre-war levels under the June 17 memorandum of understanding, have fallen sharply over the past week as the ceasefire arrangement fell apart and active fighting resumed between US and Iranian military forces. According to Goldman Sachs, flows through the strait have dropped back to an estimated 3 to 5 million barrels per day, down from approximately 10 million barrels per day in early July.
The reversal leaves the global oil market short roughly 13.4 million barrels per day of Gulf supply, a deficit that is already showing up at the pump and in the price of crude. Brent crude has jumped more than 8% over the past five trading sessions to trade back above $84 per barrel. WTI has climbed more than 8% to above $79. Both benchmarks are moving in the wrong direction for an economy that had only just begun pricing in a post-war energy recovery.
What Went Wrong
The MOU signed June 17 was supposed to reopen the strait to pre-war commercial traffic within 30 days and establish a framework for broader negotiations. For roughly four weeks, that framework held. Tanker crossings increased, oil prices declined sharply, and the global economy began adjusting to a lower energy cost environment. Gas prices fell below $4 nationally for the first time in months.
That progress has now reversed. US Central Command announced a new wave of strikes against Iranian military targets Wednesday, the fifth consecutive day of US military action in the region. Iran has continued retaliating with attacks against US installations throughout the Gulf. A second US naval blockade of the strait, which began Tuesday evening, has already redirected commercial vessels attempting to transit the waterway. Energy market analysts at Rystad Energy have stated that expectations for near-term flow normalization have failed to materialize, and the latest escalation has further reduced the probability of a recovery in the weeks ahead.
The Small Cap Squeeze Returns
For investors in the sub-$2 billion market cap space, this reversal hits on two fronts simultaneously. The consumer-facing small caps that had only just begun to benefit from lower fuel costs are now watching that relief evaporate. Companies in transportation, logistics, food service, and retail, including names like ONE Group Hospitality and Travelzoo, are right back in the margin compression environment that characterized the spring. Diesel prices, which had been trending lower, are poised to reverse alongside crude if the strait remains effectively closed.
On the other side of the trade, domestic energy producers are seeing the price environment strengthen again. Independent oil and gas operators, including names like InPlay Oil and Alliance Resource Partners, along with midstream players like Summit Midstream Partners, benefit directly from sustained crude prices above $80. The economics for US producers improve at every dollar WTI moves higher, and the re-escalation removes the near-term risk that a permanent peace deal would collapse prices back toward pre-war levels.
Goldman Sachs strategists have cautioned that recovery this time could be slower than the initial post-ceasefire rebound, given depleted global inventories and continued shipper reluctance to route through the region even via Omani waters. China, the world’s largest crude importer, had reduced its intake by 5 million barrels per day during the first phase of the conflict, but that restraint could shift as Gulf producers adjust pricing and Beijing reassesses its long-term stockpile strategy.
The ceasefire was supposed to be the beginning of the end. Instead, the strait is closing again, and the energy cost pressure that defined the first half of 2026 is threatening to define the second half as well.
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