Release – Summit Midstream Corporation Schedules Third Quarter 2026 Earnings Call

Summit Midstream Partners Logo. (PRNewsFoto/Summit Midstream Partners)

Research News and Market Data on SMC

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HOUSTON, Nov. 2, 2026 /PRNewswire/ — Summit Midstream Corporation (NYSE: SMC) (“Summit”, “SMC” or the “Company”) announced today that it will report operating and financial results for the third quarter of 2026 on Monday, November 9, 2026, after the close of trading on the New York Stock Exchange.

Third Quarter 2026 Earnings Call

SMC will host a conference call at 10:00 a.m. Eastern on November 10, 2026, to discuss its quarterly operating and financial results. The call can be accessed via teleconference at: Q3 2026 Summit Midstream Corporation Earnings Conference Call (https://register-conf.media-server.com/register/BI10be65af5cb84a17b15c9a100f09cd74). 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.

Upcoming Investor Conferences

Members of SMC’s senior management team will attend the 2026 Bank of America Leverage Finance Conference taking place on December 1–2, 2026 and the 2026 Wells Fargo Energy & Power Symposium taking place on December 8–9, 2026. The presentation materials associated with these events will be accessible through the Investors section of SMC’s website at www.summitmidstream.com prior to the beginning of the conference.

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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Release – InPlay Oil Corp. Confirms Monthly Dividend for November 2026

InPlay Oil logo

Research News and Market Data on IPOOF

Nov 02, 2026, 06:30 ET

CALGARY, AB, Nov. 2, 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 November 30, 2026, to shareholders of record at the close of business on November 16, 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.

www.inplayoil.com

SOURCE InPlay Oil Corp.

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; www.inplayoil.com

Bimergen Energy (BESS) – Powering Up a 2 GW Opportunity


Thursday, October 29, 2026

Mark Reichman, Managing Director, Equity Research Analyst, Natural Resources, Noble Capital Markets, Inc.

Richard Magnusen, Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Initiating coverage with an Outperform rating. Bimergen Energy develops, finances, owns, and operates utility-scale battery energy storage systems (BESS). The company has assembled 23 development projects representing approximately 2.0 gigawatts (GW) of capacity across several regional U.S. power markets. We believe the portfolio provides a range of options to unlock value as Bimergen advances projects through development, monetization, financing, construction, and ultimately commercial operation.

Multiple paths to value creation. Bimergen can monetize projects by retaining minority interests alongside strategic partners or owning completed assets and generate recurring operating revenue. The company has begun demonstrating this flexibility through the sale of the 100-megawatt (MW) Redbird project and two smaller ERCOT projects to Frontier Power while retaining a 7.5% economic interest. We believe this transaction provides initial evidence that development-stage projects can create tangible value before commercial operation.


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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. 

VivoPower International PLC (VIVO) – Advancing Mo i Rana Development and Sovereign AI Strategy


Tuesday, October 27, 2026

Michael Kupinski, Director of Research, Equity Research Analyst, Digital, Media & Technology , Noble Capital Markets, Inc.

Jacob Mutchler, Research Analyst, Noble Capital Markets, Inc.

Refer to the full report for the price target, fundamental analysis, and rating.

Construction mobilized at Mo i Rana. On October 12, 2026, VivoPower announced the start of construction for the initial 40MW AI data center at its Mo i Rana facility in Norway. While a definitive lease agreement has not yet been announced, the company confirmed that it has selected a global AI industry leader as its preferred tenant, with the facility’s design and construction tailored to the prospective customer’s requirements.

Existing operations maintained during construction. VivoPower has engaged local contractors to complete site preparation and structural works ahead of the specialized mechanical and electrical fit-out. Under the original development plan, construction will proceed on adjacent land while existing Bitcoin mining and grid-balancing operations continue. After the mining lease expires in June 2027, the existing power capacity is earmarked for AI applications, with an additional 40MW development planned thereafter.


Get the Full Report

Equity Research is available at no cost to Registered users of Channelchek. Not a Member? Click ‘Join’ to join the Channelchek Community. There is no cost to register, and we never collect credit card information.

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. 

Oil Prices Surge Above $110 as U.S.-Iran Tensions Raise Fears of Escalation After Midterms

Oil prices surged Thursday as investors weighed reports that the United States and Israel could intensify military operations against Iran following the November midterm elections, raising concerns about additional disruptions to global energy supplies and renewed inflationary pressure.

Brent crude futures climbed above $111 per barrel during early trading on October 22, approaching a five-month high, while U.S. West Texas Intermediate crude rose toward $100. The gains reflected growing uncertainty surrounding the Middle East conflict and the potential consequences for oil production, shipping routes, and global economic growth.

According to reports citing The New York Times, U.S. and Israeli officials have been considering expanded military operations targeting Iranian energy infrastructure and other strategic facilities after the November 3 elections. The reported plans remain uncertain, and no final decision on additional military action has been publicly confirmed.

The developments have intensified concerns surrounding the Strait of Hormuz, a critical shipping passage connecting major Persian Gulf oil producers with international markets. Disruptions to tanker traffic through the waterway have already constrained energy shipments, contributing to higher crude prices and increased volatility across commodity markets.

Recent attacks have added to the uncertainty. Iran-aligned Houthi forces launched strikes against targets in Saudi Arabia, including energy-related infrastructure, while additional incidents involving vessels in the Persian Gulf have heightened concerns about regional security.

The combination of military tensions and shipping disruptions has created a significant geopolitical risk premium in oil prices, with traders increasingly focused on the possibility of prolonged supply shortages.

Energy markets received additional support from U.S. inventory data released Wednesday. The Energy Information Administration reported that domestic crude inventories declined by approximately 3.1 million barrels during the previous week, exceeding analysts’ expectations for a smaller reduction.

The larger-than-expected drawdown suggests that available supplies remain tight, adding upward pressure to prices at a time when geopolitical developments are already limiting market confidence.

For investors, rising crude prices have implications extending well beyond the energy sector. Higher oil costs can increase gasoline and diesel prices, raise transportation expenses, and push up production costs for businesses across the economy.

Those pressures could complicate the Federal Reserve’s efforts to contain inflation. If energy prices remain elevated, policymakers may face additional challenges in determining when borrowing costs can move lower without reigniting broader price pressures.

The developments are particularly relevant for smaller companies, which may have less flexibility to absorb higher operating expenses or secure financing during periods of elevated interest rates.

At the same time, stronger oil prices can create opportunities for energy producers. Companies operating in North American oil and natural gas markets may benefit from improved commodity pricing, although production costs, hedging arrangements, and individual operating conditions influence their financial performance.

Among companies followed by Noble Capital Markets, InPlay Oil Corp. (TSX: IPO) operates in the Canadian oil and natural gas sector, while Alliance Resource Partners (NASDAQ: ARLP) maintains significant exposure to domestic energy markets through its coal operations and related interests. Their businesses illustrate different areas of the energy industry that investors may evaluate as commodity markets respond to geopolitical developments.

However, higher energy prices are not universally positive for the sector. Companies dependent on fuel-intensive transportation, manufacturing, and logistics may experience additional margin pressure if elevated prices persist.

The coming weeks could prove important for global oil markets as investors monitor diplomatic negotiations, military developments, and the outlook for energy shipments through the Persian Gulf.

For now, the combination of geopolitical uncertainty and tightening inventories suggests that oil prices could remain volatile, with significant implications for inflation, corporate earnings, and financial markets heading into the final months of 2026.

The $4 Gallon Is No Longer a Shock. It’s the New Baseline.

By Wednesday, American drivers are expected to log more days above $4 a gallon in a single year than in any year on record, surpassing a mark set in 2022. That is the forecast of Patrick De Haan, head of petroleum analysis at GasBuddy, and the numbers support it.

AAA puts the national average for regular gasoline at $4.35 a gallon, about $1.27 higher than a year ago and still shy of the May peak above $4.50. Diesel sits at $6.25. Prices have drifted down a few cents over the past month, which is hardly comfort when the starting point is this high.

What stands out is not the peak but the persistence. A price spike is a shock; a price that stays elevated for months becomes a baseline. Households stop treating $4 gas as an emergency and start budgeting around it, which means cutting somewhere else. That quiet adjustment is how fuel costs feed into broader economic weakness, and it helps explain why consumers have grown so frustrated with the cost of living. The University of Michigan’s October sentiment survey fell to a five-month low, and gas prices that have held above $4 since mid-summer are part of that story.

The supply picture offers little relief. Crude rose Monday after deadly attacks in the Middle East and fresh doubts about a proposed Russia-Ukraine energy ceasefire, with Brent near $106 a barrel and West Texas Intermediate around $93. At home, Hurricane Isaias knocked two major Gulf Coast refineries offline, and the full extent of the damage is still being assessed. Refiners make diesel and heating oil from the same crude supply, so a disruption in one product can pull the others higher, just as winter demand arrives. Gasoline futures are up more than 86% this year and heating oil futures more than 124%.

Diesel deserves more attention than it gets. It moves the farm equipment, trucks, and delivery vans that carry nearly everything people buy, so higher diesel costs eventually show up on shelves and invoices. Drivers see the gasoline price on a sign; they don’t see the diesel surcharge folded into their groceries.

The pain is not evenly shared. Producers are positioned to benefit. InPlay Oil Corp. (IPOOF), an Alberta light oil producer covered by Noble Capital Markets research, reported record quarterly adjusted funds flow of $44.7 million in the second quarter, citing high oil prices, and raised its 2026 guidance. The company also reported production of 18,663 barrels of oil equivalent per day, about 62% light oil and natural gas liquids, and agreed to a $54.25 million acquisition after quarter end. Those figures are company-reported. Transportation and logistics businesses, along with lower-income households that spend a larger share of their budgets on fuel, face the opposite side of the trade.

Three things will decide how long this lasts: how quickly the damaged refineries come back, whether Middle East tensions and the Russia-Ukraine ceasefire push crude higher, and how tight distillate supply gets as temperatures fall. If those break the wrong way, the $4 gallon will remain a feature of the economy rather than a talking point, and the consumer will keep feeling it.

Google Signs $4.3 Billion, 20-Year Nuclear Power Deal With Constellation Energy

Google (Nasdaq: GOOG, GOOGL) announced Tuesday a $4.3 billion agreement with Constellation Energy (Nasdaq: CEG) to bring 890 megawatts of nuclear power online through a 20-year power purchase agreement, the latest step in the technology industry’s race to secure electricity for the AI buildout. Constellation shares were up more than 12% in Tuesday trading, while Google was slightly lower.

The new capacity will not come from new reactors. It will come from upgrades at six existing nuclear plants across Illinois, New Jersey, and Pennsylvania, including modernized turbines, steam generators, and digital control systems. Upgrading existing plants is generally a faster route to new capacity than building reactors from scratch, which can take years to permit and construct. By the usual rule of thumb that a gigawatt powers nearly 800,000 homes, 890 megawatts is enough for roughly 700,000.

The structure matters for both sides. Google says the contract gives Constellation the revenue certainty it needs to invest in updates to 11 of its reactors, and that it is designed so utility customers do not absorb added costs from the AI boom. Constellation will also use Google’s Gemini Enterprise software for site selection, outage management, and infrastructure protection, which makes this a technology partnership as well as a power contract.

Google is not alone in locking up nuclear supply. Microsoft signed a 20-year agreement with Constellation in 2024 to source power from a previously shuttered reactor at Three Mile Island by 2028. Amazon has signed its own nuclear power deal with Constellation, and Meta has agreed to a 20-year purchase of power from Vistra’s plants and also has a 20-year agreement for the output of Constellation’s Clinton plant in Illinois. That gives Constellation long-term agreements with four of the largest technology companies. Google has also invested in nuclear projects in Georgia, Iowa, and Tennessee, and companies across the industry are exploring small modular reactors designed to deliver megawatts rather than a full gigawatt.

The pattern points to where the AI buildout is actually constrained. Chips and data center shells can be ordered, but reliable around-the-clock power cannot be added quickly. That is why the largest buyers are signing two-decade contracts years before the electricity arrives, a dynamic that runs through the US data center construction boom. It also helps explain why a single contract can move a power generator’s stock by double digits, since it converts uncertain future demand into contracted revenue. Nuclear carries a lingering public stigma, but it offers clean, steady output compared with carbon-based options.

For small and microcap investors, the read-through is about the supply chain around power rather than the contracts themselves. Upgrading six plants and eleven reactors means demand for turbine and steam generator components, digital controls, engineering services, and grid equipment, areas where smaller specialized companies operate. The caution is that Constellation’s jump shows how quickly the market prices in announced deals. Whether smaller names benefit depends on whether orders actually reach them and whether the hyperscalers keep spending at the current pace while borrowing costs stay elevated.

Oil Just Fell to a Two-Week Low. Saudi Arabia and Iraq Are Quietly Rerouting Around the Strait of Hormuz

Oil prices extended a six-session decline Wednesday, with Brent crude falling to $98.16 a barrel and West Texas Intermediate dropping to $89.01, both settling at roughly two-week lows. Brent closed below $100 a barrel Tuesday for the first time since September 8, a notable reversal after weeks of escalation-driven price spikes that we’ve tracked closely throughout this conflict.

Two forces are driving the decline, and both matter for understanding where oil heads next. The first is diplomatic. President Trump warned Tuesday that the US could take severe action against Iran, while simultaneously saying his envoys had held productive talks with Iranian mediators in New York and describing real momentum toward reaching a deal to end the nearly seven-month war. Markets appear to be choosing to price in the possibility of talks succeeding, even amid continued tough rhetoric on both sides.

The second, more concrete factor is supply, and it’s arguably the more important development. Saudi Arabia restarted its East-West Pipeline to the Red Sea on Tuesday, a route that reroutes roughly 4 million barrels per day, about 4% of global oil supply, around the Strait of Hormuz entirely. The pipeline had been shut since September 11 following drone attacks Saudi Arabia has blamed on Iraqi militia forces. Saudi Arabia is also now offering additional barrels to Asian refiners for pickup outside the strait altogether. Iraq is following a similar playbook, with its oil minister confirming exports have climbed above 3 million barrels per day and stating the country expects to boost shipments routed through Turkey to more than 600,000 barrels per day. Shiptracking data shows Iraqi exports climbing in August from July’s levels, though they still remain below the roughly 3.4 to 3.7 million barrel per day pace seen before the war began.

Adding further downward pressure, industry data released Tuesday showed US crude inventories rose by 1.8 million barrels last week, catching analysts off guard, who had broadly expected a decline.

For investors tracking the small and microcap space, this shift is worth watching closely, and it cuts in the opposite direction from what we detailed when covering diesel’s all-time high and the broader oil surge earlier this month. Consumer-facing companies in transportation, logistics, and hospitality, squeezed hard by the run-up in fuel costs, stand to benefit if this decline holds and extends toward the pump, a group that includes companies like Commercial Vehicle Group, a supplier to the trucking industry, and The ONE Group Hospitality, a restaurant operator directly exposed to consumer discretionary spending. Domestic energy producers, conversely, face renewed margin pressure as prices retreat from the highs that supported their economics all summer, a dynamic worth watching for companies like InPlay Oil and Alliance Resource Partners. Whether this reversal proves durable likely depends on whether the diplomatic momentum Trump described translates into an actual agreement, or whether these alternative supply routes simply prove temporary workarounds to a conflict still very much unresolved.

Greenland Stocks Doubled Today. The Rare Earths Aren’t Here Yet

Shares of several US-listed companies with exposure to Greenland exploded higher Monday after the United States, Denmark, and Greenland reached an agreement on expanded American security arrangements on the Arctic territory. Greenland Energy surged more than 165% in premarket trading, Greenland Mines climbed over 110%, and Critical Metals Corp rose nearly 30%. The moves reflect genuine excitement about what this agreement could eventually unlock, though the timeline and feasibility of actually extracting Greenland’s mineral wealth remain far less certain than the stock charts suggest.

The framework, announced September 18 and expected to be formally signed this week during the United Nations General Assembly, expands US defense construction rights on the island, granting Washington unilateral authority to build and expand military infrastructure without case-by-case approval from Copenhagen or Nuuk. It also guarantees permanent basing, transit, and overflight rights, while formally restricting adversary nations, specifically China and Russia, from establishing military positions or making what the agreement calls sensitive investments, a provision that appears squarely aimed at critical minerals and mining. Importantly, Greenland’s sovereignty remains fully with the Kingdom of Denmark under the deal, and the agreement still requires parliamentary approval before taking effect, meaning this is a framework, not yet a finalized, binding arrangement.

The strategic logic is straightforward on paper. Greenland sits on substantial untapped reserves of rare earth elements, the materials essential to defense systems, electric vehicles, and advanced electronics, and a security agreement that locks out Chinese and Russian involvement positions the island as a potential Western alternative to China’s current dominance of the global rare earth supply chain, a theme we detailed closely when covering Energy Fuels’ recent mine-to-magnet acquisition earlier this year.

The three companies driving today’s rally each have a distinct claim to that opportunity. Critical Metals Corp is developing the Tanbreez rare earths mine in southern Greenland and already holds a 15-year offtake partnership with magnet manufacturer REalloys covering up to 15% of the project’s future production. Greenland Mines is advancing the Skaergaard project, one of the world’s largest undeveloped palladium, gold, and platinum deposits, alongside a separate neodymium-praseodymium rare earths project. Greenland Energy is pursuing oil and gas exploration rather than rare earths specifically, though it recently delayed its own drilling plans after Greenland’s government issued a formal warning to its joint venture partner over bringing equipment ashore without proper authorization, a reminder that operating in Greenland carries real regulatory friction even with Washington’s backing.

Independent industry analysts have raised serious and specific concerns about how quickly, or whether, any of this translates into actual production. Multiple recent assessments from mining and metals consultancies note that Greenland’s rare earth deposits face unresolved processing economics, significant Arctic infrastructure deficits, no existing non-Chinese separation capacity anywhere on the island, and in some cases genuine radioactive waste concerns tied to the specific mineralogy of these deposits. Outside the capital city of Nuuk, much of Greenland depends on ships, aircraft, and dog sleds for basic transport, and its harsh climate and remoteness substantially raise the cost of any extraction effort. As several analysts have put it, security guarantees may attract Western capital, but they cannot substitute for proven metallurgy, functioning ports, reliable power, skilled labor, and an actual mine-to-magnet supply chain, all of which still need to be built essentially from scratch.

Greenland is not the only place this strategic push is playing out, and investors don’t need direct exposure to the island itself to participate in the broader theme. A wider push toward allied, non-Chinese critical mineral development has been building across North America for the past several years, with junior mining companies in the United States and Canada working to establish domestic and allied supply chains for materials the world currently sources overwhelmingly from China. Companies like Century Lithium Corp and Tectonic Metals Inc, both developing projects in North American jurisdictions, are not connected to today’s Greenland agreement in any way, but they operate in the same strategic category, positioning allied-nation mineral resources as an alternative to Chinese dominance, that is fueling investor enthusiasm for Greenland right now.

For investors, today’s moves are a clear example of a security and geopolitical catalyst driving share prices far ahead of underlying commercial reality. That doesn’t mean the opportunity isn’t real, both the Trump administration’s strategic interest and the individual companies’ project economics could genuinely develop over time. But the gap between a triple-digit percentage stock move today and a functioning rare earth supply chain years from now is substantial, and investors should weigh the extraction and infrastructure challenges just as carefully as the geopolitical tailwind.

Oil Nears $100 as Middle East Conflict Raises New Risks for Global Energy Supply

Oil prices moved back toward the psychologically important $100-per-barrel level Tuesday as escalating conflict across the Middle East raised fresh concerns about the security of global energy supplies. Brent crude briefly traded near $98 after Iran-aligned Houthi militants in Yemen attacked several energy facilities in Saudi Arabia, forcing temporary operational shutdowns at some sites.

The latest move extends a sharp rise in crude prices this month. Oil is now up more than 8% in September as markets respond to renewed U.S.-Iran hostilities, continued disruption around the Strait of Hormuz, and the growing possibility that additional energy infrastructure across the region could come under pressure.

The Saudi attacks matter not only because of the facilities involved, but because they broaden the geography of the conflict. Saudi Arabia has relied heavily on infrastructure outside the Persian Gulf to move oil while shipping through Hormuz remains constrained. Any sustained threat to facilities or transportation routes on the kingdom’s western side could weaken one of the principal alternatives available to keep crude flowing.

Two Critical Energy Routes Are Under Pressure

The Strait of Hormuz remains the central concern. Historically, roughly one-fifth of global petroleum liquids consumption has passed through the waterway, making it the world’s most important oil transit chokepoint. With traffic through Hormuz sharply reduced during the current conflict, producers have increasingly relied on pipelines and alternative export routes to move crude.

That has elevated the importance of the Red Sea and the Bab el-Mandeb Strait, the narrow passage connecting the Red Sea with the Gulf of Aden. Saudi Arabia’s East-West pipeline allows crude produced in the eastern part of the country to reach the Red Sea port of Yanbu without entering Hormuz, while other regional producers have also increased use of alternate routes.

The risk now is that pressure is building around both systems at once. Hormuz remains constrained, while Houthi attacks and renewed fighting in Yemen raise concerns around Saudi energy infrastructure and Red Sea shipping. The result is a narrower margin for error across one of the world’s most important energy-producing regions.

Why Prices Can Move Quickly

Oil markets do not wait for confirmed supply losses before reacting. Prices often move on the possibility that future supply could be disrupted, particularly when spare export capacity is limited and transportation alternatives are already being stretched.

That is especially true in the Middle East. Pipelines operated by Saudi Arabia and the United Arab Emirates can bypass Hormuz, but their combined capacity represents only a fraction of the oil that normally moves through the strait. Other barrels can be rerouted through the Red Sea or around Africa, but those alternatives typically add cost, distance and shipping time.

As a result, even attacks that do not immediately remove large volumes from the market can create a meaningful geopolitical risk premium. Traders are not only evaluating what has already been lost; they are pricing the possibility that additional production, refining capacity or shipping routes could be affected next.

Could Brent Break Above $100?

With Brent already approaching $100, that threshold is increasingly within reach. Goldman Sachs has suggested that prices could rise materially further if Persian Gulf supply remains below pre-conflict levels or if attacks on shipping and energy infrastructure intensify.

There is precedent for rapid price moves when key transit routes come under pressure. Brent climbed sharply earlier this summer as attacks on vessels and restrictions around Hormuz tightened available supply. Whether crude returns to those levels — or moves beyond them — will depend heavily on the duration of the conflict and whether the latest attacks lead to sustained production or export disruptions.

If Saudi operations normalize quickly and regional tensions ease, some of the geopolitical premium currently embedded in crude prices could reverse. If the conflict broadens, however, the supply outlook becomes considerably more difficult.

The Impact Extends Beyond Energy Markets

A sustained move toward or above $100 oil would have consequences well beyond producers and refiners. Higher crude prices filter through transportation, manufacturing, agriculture and consumer goods, making energy costs an important part of the inflation outlook.

That creates a more complicated backdrop for financial markets. Higher oil prices can benefit producers, drilling companies and other energy-linked businesses, but they can also raise operating costs for transportation-heavy industries and put additional pressure on consumers through gasoline, diesel and freight expenses.

For policymakers and investors, the concern is that an extended energy shock could reinforce inflation at a time when markets remain highly sensitive to interest-rate expectations.

What Investors Should Watch Next

The immediate focus will be on whether the Saudi facilities affected by Tuesday’s attacks return to full operation, but the larger issue is whether the geographic scope of the conflict continues to expand.

The global oil system has so far adapted to reduced traffic through Hormuz by shifting barrels through pipelines and alternative routes. That flexibility has helped prevent a much larger supply shock. But if those backup routes themselves become less reliable, the market’s ability to absorb disruption would weaken.

For investors, the key indicators now are tanker traffic through Hormuz and the Red Sea, the extent of damage to Saudi infrastructure, the pace of operational recovery, and whether attacks move closer to additional production, refining or export assets.

Crude remains available, but the cushion protecting global supply is getting thinner. That is why the move toward $100 oil may matter less as a round-number milestone than as a signal that markets are beginning to price in a broader regional energy-security problem.

Why Diesel Just Hit an All-Time High, Even as Oil Prices Cool

US retail diesel prices climbed to $5.85 per gallon Friday, according to AAA data, surpassing the previous all-time high of $5.816 set in June 2022 in the aftermath of Russia’s invasion of Ukraine. Diesel is often called the workhorse fuel of the global economy, powering the trucking fleets and cargo vessels that move goods across the country and around the world, which makes a record this significant a genuine economic pressure point rather than just another data point at the pump.

What makes this move particularly notable is what’s actually driving it. Crude oil prices have eased somewhat off their wartime highs from earlier this year and are up only about 5% since their July 18 low. Diesel, by contrast, has surged roughly 40% over that same stretch. This is not primarily a crude oil story, it is a refined product story, and the distinction matters for understanding just how structurally tight this market has become.

Two separate conflicts are compounding the pressure simultaneously. The ongoing war in Iran has cut off refined product flows from the Persian Gulf, a region we’ve tracked closely throughout this conflict, while Ukrainian strikes on Russian oil refineries have taken capacity offline from one of the world’s other major diesel exporters. Together, the Middle East and Russia accounted for roughly a third of global diesel exports in 2025, and losing meaningful capacity from both simultaneously has left the market with essentially no cushion. US distillate stockpiles are now at their lowest levels on record for this time of year, and East Coast inventories, the region most dependent on diesel and heating oil for winter demand, are at all-time lows just as the heating season approaches.

The obvious question is why domestic refiners can’t simply ramp up production to meet the shortfall. President Trump pressed refining executives on this directly at the White House this week, with midterm elections approaching and fuel affordability an increasingly visible political issue. The honest answer is capacity. Major refiners including Marathon Petroleum and Shell have both indicated in recent earnings reports that their systems are already running near full capacity, leaving little room to meaningfully increase throughput even under direct pressure to do so.

For investors tracking the small and microcap space, this dynamic cuts in two directions that mirror exactly what we’ve seen play out with gasoline prices throughout this conflict. Consumer-facing companies dependent on trucking and freight, along with any business reliant on diesel-powered logistics, face real and mounting cost pressure heading into the fall. Domestic energy producers and refiners with available capacity, meanwhile, continue benefiting from a pricing environment that shows no near-term sign of easing. With winter heating demand still ahead and refined product inventories already at record lows, this is a story likely to remain relevant well beyond the current news cycle.

Enbridge Just Bought 500 Miles of Pipeline in the Busiest Oil Field in America

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.

Release – InPlay Oil Corp. Confirms Monthly Dividend for September 2026

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Research News and Market Data on IPOOF

Sep 01, 2026, 07:30 ET

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.

www.inplayoil.com 

SOURCE InPlay Oil Corp.

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