Commerzbank Says Treasuries Resume Rally, US Equity Futures Lower, Brent Oil Steady

Brent oil prices are holding steady amid a backdrop of rising US Treasury prices and lower US equity futures. The rally in Treasuries indicates a flight to safety among investors, which often correlates with increased volatility in risk assets, including oil. This dynamic suggests that while oil prices may remain stable for now, underlying market sentiment is cautious. The stability in Brent could be attributed to a balance between supply concerns and demand signals, as OPEC's recent output decisions continue to influence market dynamics. Additionally, the strength of the dollar plays a crucial role; a stronger dollar typically pressures oil prices, but current trends indicate that oil is resilient despite currency fluctuations. Investors should also consider the implications of lower equity futures, which may signal reduced economic optimism and could dampen future demand for oil. Furthermore, any shifts in refinery capacity or inventory data could quickly alter the current equilibrium in oil prices. As geopolitical tensions persist, they remain a wildcard that could disrupt supply chains and impact pricing. Overall, while Brent oil remains steady, the interplay of these factors suggests that volatility could be on the horizon, warranting close monitoring by market participants.

Iran Reports More Tanker Fires in Strait of Hormuz

Tensions in the Strait of Hormuz have escalated following reports of multiple tanker fires, including incidents involving two oil tankers and a tugboat, attributed to Iran's Islamic Revolutionary Guard Corps. One tanker reportedly struck a naval mine while navigating south of the Strait, highlighting the increasing risks for vessels in this critical shipping lane. The Strait of Hormuz is a vital chokepoint for global oil supply, with approximately 20% of the world's oil passing through it. Such incidents can lead to heightened geopolitical tensions, which often result in increased oil prices as markets react to potential supply disruptions. Investors should be wary of the implications these events have on shipping insurance costs and the overall security of oil transport in the region. Additionally, the Iranian military's aggressive posture may provoke responses from other nations, further complicating the geopolitical landscape. As these incidents unfold, they could lead to a tightening of supply if shipping routes become more perilous. Market participants will be closely monitoring the situation, as any escalation could trigger a significant price reaction. Overall, the combination of geopolitical instability and the potential for supply chain disruptions could support higher oil prices in the near term.

Stock markets diverge, oil prices steady tracking Trump and AI

Oil prices have remained steady amid the diverging trends in stock markets, reflecting a complex interplay of geopolitical and economic factors. The recent midterm elections in the U.S. have led to a shift in sentiment, with President Trump's significant defeat easing some concerns about potential escalations in the Middle East. This reduction in geopolitical risk is crucial for oil markets, as tensions in the region often lead to price volatility. Additionally, the ongoing surge in AI investments is creating a mixed economic outlook, which can influence energy demand forecasts. Investors should note that while stock markets react to political developments, oil prices are more directly tied to supply and demand dynamics. The stability in oil prices suggests that traders are currently not overly concerned about immediate supply disruptions. However, any resurgence of conflict in oil-producing regions could quickly change this outlook. Furthermore, the interplay between inflation and energy costs remains a critical factor, as rising prices can dampen demand. As the market digests these developments, the focus will likely shift to inventory data and refinery capacity, which will provide further insights into the health of the oil market. Overall, while the political landscape shifts, oil prices are holding steady, indicating a cautious optimism among investors.

US Elections, Crude Prices, Chip-Wreck Roil Asian Stock Markets

Crude prices are facing downward pressure as Asian stock markets experience volatility, particularly influenced by developments in the US elections and broader economic concerns. The uncertainty surrounding the elections is creating a risk-off sentiment among investors, which often translates into weaker demand for oil as economic growth prospects dim. Additionally, the turmoil in Asian markets, particularly those exposed to China, is raising alarms about global economic stability, further dampening oil demand expectations. As investors reassess their positions, crude prices may continue to reflect this cautious outlook, especially if stock market instability persists. The interplay between US political developments and global economic indicators is crucial, as any signs of economic slowdown could lead to reduced consumption of oil. Furthermore, geopolitical tensions and inflationary pressures are also contributing to the complex landscape for energy markets. With refinery capacity remaining a critical factor, any disruptions in processing could exacerbate supply concerns. As the market digests these signals, traders should remain vigilant about potential shifts in inventory data, which could provide further insights into demand trends. Overall, the combination of political uncertainty and economic turbulence is likely to keep crude prices under pressure in the near term. Investors should prepare for continued volatility as these factors unfold.

Oil Prices Rebound After Sharp Decline as US Election Results Shift Expectations for Iran Conflict

Oil prices rebounded after a significant decline, with Brent crude futures rising as investors recalibrated their expectations regarding the US-Iran conflict following the Democratic Party's midterm election victories. The sharp drop of over 8% in the previous session reflected market concerns about escalating tensions and potential military actions. However, the election results may shift the political landscape, potentially increasing pressure on President Trump to seek a diplomatic resolution with Iran rather than pursuing aggressive policies. This change in sentiment could stabilize oil prices, as a negotiated settlement would likely ease supply concerns stemming from geopolitical risks. Additionally, the market is closely monitoring US production levels and inventory data, which remain critical in balancing supply and demand dynamics. With refinery capacity also playing a role in determining market conditions, any disruptions or changes in output could further influence price movements. Investors should remain vigilant about how these political developments unfold, as they could have lasting implications for energy markets. The interplay between US domestic politics and international relations will be crucial in shaping future oil price trajectories. Overall, the rebound indicates a cautious optimism among traders, but volatility is likely to persist as the situation evolves.

3 Nuclear Stocks With Revenue Growth Up To 384%

Oil prices have dropped sharply following the recent midterm victories for Democrats in the US, signaling a potential shift in energy policy that could favor cleaner energy sources. This political landscape is prompting investors to reassess long-term energy and power needs, particularly as cleaner baseload electricity gains traction as a critical infrastructure component for AI data centers and climate initiatives. The focus on nuclear energy is becoming increasingly relevant, with revenue growth for certain nuclear stocks reported as high as 384%. This surge in interest for nuclear power stocks indicates a broader market shift towards sustainable energy solutions, which could further pressure traditional oil markets. As the demand for cleaner energy sources rises, oil prices may face downward pressure as investors pivot towards sectors that align with climate goals. Additionally, the bond markets are reacting swiftly, reflecting a recalibration of risk and investment strategies in the energy sector. The implications for oil prices are significant; as cleaner technologies gain momentum, the long-term outlook for oil demand could weaken. Investors should closely monitor these developments, as the transition to nuclear and other renewable energy sources could reshape the energy landscape. The potential for reduced oil consumption in favor of nuclear energy could lead to increased volatility in oil prices as market dynamics evolve. Overall, the intersection of political shifts, technological advancements, and changing consumer preferences is creating a complex environment for oil and energy markets.

GPGI Reports Third Quarter 2026 Results

(NYSE: GPGI) GPGI, Inc. announced its financial and operating results for the third quarter ended September 30, 2026. Dave Cote, Executive Chairman, stated that GPGI delivered third quarter results in line with expectations, citing record strength at CompoSecure and improving demand at Husky. Adjusted Net Sales for the third quarter of 2026 were $509.6 million, compared to $487.9 million in the third quarter of 2025. Pro Forma Adjusted EBITDA for the third quarter of 2026 was $146.3 million, up from $137.3 million in the prior year period. GAAP Net Income for the third quarter of 2026 was $76.0 million, with Adjusted Net Income also at $76.2 million, compared to a GAAP Net Loss of $174.7 million and Adjusted Net Income of $34.0 million in the third quarter of 2025. Diluted EPS for the third quarter of 2026 was $0.26, matching the Adjusted EPS of $0.26, versus a GAAP EPS of ($1.58) and Adjusted EPS of $0.29 in the third quarter of 2025. As of September 30, 2026, Cash & Short-Term Investments were $5.5 million on a GAAP basis and $175.8 million on an adjusted basis, compared to $127.4 million GAAP and $265.3 million adjusted as of September 30, 2025. Total Debt as of September 30, 2026 was $2,097.0 million, compared to $190.0 million as of September 30, 2025. Of the cash balance as of September 30, 2026, $170.3 million was held at GPGI Holdings and not included in the GAAP results. GPGI is required to account for its operating subsidiary, GPGI Holdings, L.L.C., under the equity method in accordance with U.S. GAAP, effective February 28, 2025, following the spin-off of Resolute Holdings Management, Inc. and the execution of the CompoSecure Management Agreement. Both CompoSecure and Husky business units are under GPGI Holdings. GPGI provides supplemental non-GAAP information to reflect consolidated results and the effect of the Husky transaction as if it had occurred on January 1, 2025. The company held a third quarter 2026 earnings conference call on November 5, 2026, at 8:00 a.m. EST. The company’s non-GAAP measures include Adjusted Net Sales, Adjusted Net Income, Adjusted Net Income per Share, Adjusted Net Debt, Pro Forma Net Sales, Pro Forma Adjusted EBITDA, Pro Forma Adjusted EBITDA Margin, and Pro Forma Adjusted Free Cash Flow. Adjustments to EBITDA for the third quarter of 2026 included depreciation and amortization of $32.6 million, income tax expense of ($5.0) million, net interest expense of $32.1 million, stock-based compensation of $6.6 million, Husky transaction costs of $1.0 million, loss on sale of assets of $0.2 million, FX loss of $0.3 million, and severance cost of $2.5 million. For the third quarter of 2025, Pro Forma Adjusted EBITDA was $137.3 million, with adjustments including depreciation and amortization of $40.3 million, income tax expense of $122.0 million, net interest expense of $66.4 million, stock-based compensation of $6.2 million, mark to market adjustments of $179.9 million, business transformation and other costs of $10.5 million, platinum management fee of $1.3 million, incremental pro forma management fee of ($10.5) million, additional earnout cost of $5.0 million, and Husky transaction costs of $2.8 million. GPGI is managed by Resolute Holdings Management, Inc. (NYSE: RHLD) and currently consists of CompoSecure and Husky as its main business units.

Kimbell Royalty Partners Announces Record Third Quarter 2026 Results

(NYSE:KRP) Kimbell Royalty Partners, LP announced record Q3 2026 daily production of 27,565 Boe per day (6:1). The company completed a $221.2 million Drop Down acquisition, which closed on August 21, 2026, contributing 41 days of production in the quarter. Following the acquisition, run-rate production reached 28,910 Boe per day (6:1). Q3 2026 oil, natural gas, and NGL revenues were $96.9 million, and including the acquired production from the effective date, revenues totaled $104.6 million. Net income for Q3 2026 was approximately $17.3 million, with net income attributable to common units of approximately $12.4 million. Consolidated Adjusted EBITDA for Q3 2026 was $80.4 million, or $87.5 million including the acquired production. On October 15, 2026, the borrowing base and elected commitments on Kimbell's secured revolving credit facility increased from $660 million to $750 million. On October 16, 2026, Kimbell gave notice to redeem 50% of the remaining Series A Cumulative Convertible Preferred Units; after closing, expected on November 16, 2026, the remaining outstanding Preferred Units will be less than 3% of Kimbell's $2.8 billion enterprise value. As of September 30, 2026, Kimbell's major properties had a record 9.37 net DUCs and net permitted locations, compared to an estimated 8.20 net wells needed to maintain flat production. Kimbell had 93 rigs actively drilling on its acreage as of September 30, 2026, an increase of 2 rigs from Q2 2026, representing approximately 16% market share of all land rigs drilling in the continental United States. The company announced a Q3 2026 cash distribution of $0.45 per common unit, reflecting a payout ratio of 75% of cash available for distribution and implying a 10.7% annualized yield based on the October 30, 2026 closing price of $16.88 per common unit. The remaining 25% of cash available for distribution will be used to repay approximately $18.8 million of outstanding borrowings under the secured revolving credit facility. Kimbell expects that approximately 76% of its Q3 2026 distribution will be considered a non-taxable return of capital. Total revenues for Q3 2026 were $86.3 million. Average realized prices in Q3 2026 were $86.18 per Bbl of oil, $2.21 per Mcf of natural gas, $25.23 per Bbl of NGLs, and $40.41 per Boe combined. G&A expense for Q3 2026 was $10.7 million, with $6.3 million as Cash G&A expense ($2.48 per Boe), and unit-based compensation was $4.4 million ($1.73 per Boe). As of September 30, 2026, Kimbell had $535.8 million in debt outstanding under its secured revolving credit facility, net debt to trailing twelve month consolidated Adjusted EBITDA of approximately 1.5x, and $124.2 million in undrawn capacity. The redemption of 50% of the remaining Preferred Units is expected to close on November 16, 2026 for an aggregate redemption price of approximately $100.2 million, funded with borrowings under the credit facility. As of September 30, 2026 and November 5, 2026, Kimbell had 105,451,405 common units and 18,752,185 Class B units outstanding. Q3 2026 average daily production was 27,565 Boe per day, with 45% from natural gas and 55% from liquids (34% oil, 21% NGLs). As of September 30, 2026, Kimbell's major properties had 1,005 gross (4.56 net) DUCs and 705 gross (4.81 net) permitted locations. The company provided a detailed hedge book as of September 30, 2026, including fixed price swaps for oil and natural gas through Q3 2028, with weighted average fixed prices ranging from $58.06 to $70.35 per Bbl for oil and $3.15 to $4.46 per MMBTU for natural gas. Since June 2026, Kimbell has closed $367 million in acquisitions. The company affirms its financial and operational guidance ranges for Q4 2026 as previously disclosed.

Surge Energy reports Q3 results

TC Energy Non-GAAP EPS of C$0.94 beats by C$0.06, revenue of C$4.03B beats by C$80M

TC Energy reports strong third quarter 2026 operating and financial results

(NYSE:TRP) TC Energy Corporation released its third quarter 2026 results, highlighting strong operational and financial performance across its North American natural gas systems. François Poirier, President and Chief Executive Officer, stated that exceptional operational performance, constructive settlement outcomes, and projects placed in service ahead of schedule and under budget have supported an increase to the 2026 comparable EBITDA outlook to $11.8 to $12.0 billion. For the third quarter of 2026, comparable earnings were $1.0 billion or $0.94 per common share, compared to $0.8 billion or $0.77 per common share in the third quarter of 2025. Net income attributable to common shares was $1.0 billion or $0.98 per common share, up from $0.8 billion or $0.78 per common share in the prior year period. Comparable EBITDA for the quarter was $3.0 billion, compared to $2.7 billion in the third quarter of 2025. Segmented earnings were $2.3 billion, up from $1.9 billion in the prior year period. The Board of Directors declared a quarterly dividend of $0.8775 per common share for the quarter ending December 31, 2026. Capital expenditures for 2026 are anticipated to be at the lower end of $6.0 to $6.5 billion prior to adjustments for non-controlling interests, or $5.5 to $6.0 billion of net capital expenditures. For 2027, comparable EBITDA is expected to be $12.3 to $12.5 billion, with capital expenditures of $6.7 to $7.2 billion prior to adjustments, or $6.0 to $6.5 billion net. The five-year comparable EBITDA compound annual growth rate is expected to be five to seven per cent out to 2031. Operationally, Canadian Natural Gas Pipelines deliveries averaged 24.3 Bcf/d, NGTL System receipts averaged 14.3 Bcf/d, Canadian Mainline Western receipts averaged 4.3 Bcf/d, U.S. Natural Gas Pipelines daily average flows were 27.0 Bcf/d, and Mexico Natural Gas Pipelines flows averaged 3.7 Bcf/d. Bruce Power achieved 96.6 per cent availability, and the cogeneration power plant fleet achieved 89.6 per cent availability in the third quarter of 2026. The company announced approximately $3 billion of new, low-risk, in-corridor growth projects, bringing year-to-date sanctioned capital projects to approximately $6 billion at a weighted average build multiple of approximately 6.5 times. The Crossroads Expansion project was approved with an expected build multiple of approximately 6.0 times, an anticipated in-service date in 2030, and an estimated project cost of approximately US$1.8 billion. The American Midwest project was also approved, with an expected build multiple of approximately 6.0 times, an anticipated in-service date in 2030, and a total estimated project cost of approximately US$0.4 billion, of which TC Energy's proportionate share of equity contributions is approximately US$0.1 billion. The Coastal GasLink Phase 2 Expansion was approved with an estimated project cost of $4.9 billion, construction expected to commence in early 2027, and an anticipated in-service date in the early 2030s. Coastal GasLink LP secured project-level financing of up to $3.3 billion, with TC Energy's proportionate share of committed equity up to approximately $250 million. The ANR Optimization project was approved with an anticipated in-service date in 2029 and an estimated project cost of approximately US$0.1 billion. Year-to-date, approximately $2.5 billion of projects have been placed in service, with approximately $3.4 billion of capital expected to be placed in service in 2026 and $4.5 to $5.0 billion in 2027. Projects placed in service from 2025 to 2026 year-to-date were delivered more than 10 per cent under budget in aggregate. The Gillis Access project extension was placed in service on November 1, 2026, with a total project cost of approximately US$0.4 billion. Bruce Power commenced the Unit 5 Major Component Replacement in November 2026, and Unit 4 MCR is ahead of schedule and under budget. FERC approved the Great Lakes Stipulation and Agreement of Settlement on September 15, 2026, and GTN filed the Stipulation and Agreement of Settlement with FERC on October 15, 2026, subject to approval. Net cash provided by operations for the third quarter was $1,782 million, and comparable funds generated from operations were $2,236 million. Capital spending for the quarter was $1,412 million. Dividends declared per common share were $0.8775 for the quarter. The company completed a transaction with FN CGL Pipeline Limited Partnership, an Indigenous-led investment entity representing five First Nations, providing participating communities with an economic interest in the entity that holds TC Energy's limited partner interest in Coastal GasLink. A second transaction involving additional First Nations is expected to close in the fourth quarter of 2026.

CVR Energy: Marathon Deal Adds Scale But Limited Value

Genesis Energy GAAP EPS of -$0.05 beats by $0.13, revenue of $449.2M

Canadian Natural Resources Limited Announces Quarterly Dividend

(TSX:CNQ) (NYSE:CNQ) Canadian Natural Resources Limited announced that its Board of Directors has declared a quarterly cash dividend on its common shares of C$0.625 per share. The dividend will be payable on January 5, 2027 to shareholders of record at the close of business on December 15, 2026. The company previously announced a dividend increase in March of this year. The year 2026 marks the 26th consecutive year of dividend increases for Canadian Natural Resources Limited. Over this period, the company has achieved a compound annual growth rate (CAGR) of 20% in its dividend. The Board of Directors stated that this record demonstrates their confidence in the sustainability of the company's business model, its strong balance sheet, and the strength of its diverse, long life low decline reserves and asset base. Canadian Natural Resources Limited is described as a senior crude oil and natural gas production company. The company has continuing operations in its core areas located in Western Canada, the U.K. portion of the North Sea, and Offshore Africa. Scott G. Stauth is named as President. Victor C. Darel is named as Chief Financial Officer. Lance J. Casson is named as Manager, Investor Relations. The trading symbol for the company is CNQ on both the Toronto Stock Exchange and the New York Stock Exchange.

Canadian Natural Resources Limited Announces 2026 Third Quarter Results

(TSX:CNQ) (NYSE:CNQ) Canadian Natural Resources Limited reported third quarter 2026 results, highlighting production of approximately 1,217,000 barrels per day (bbl/d) of liquids and 2.6 billion cubic feet per day (Bcf/d) of natural gas, totaling approximately 1,652,000 barrels of oil equivalent per day (BOE/d), inclusive of a planned turnaround at Horizon. Record quarterly thermal in situ production reached approximately 300,000 bbl/d, up 25,000 bbl/d from Q3/25, driven by new pads at Pike and Primrose. North American Conventional E&P assets, excluding thermal in situ, achieved record quarterly liquids production of approximately 358,000 bbl/d, an increase of 49,000 bbl/d from Q3/25, attributed to acquisitions and strong well performance. The planned turnaround at Horizon was completed in 28 days, seven days ahead of schedule, resulting in approximately 23,000 bbl/d of additional high margin Synthetic Crude Oil (SCO) production in Q4/26. Oil Sands Mining and Upgrading production rates are currently averaging approximately 640,000 bbl/d. The company is targeting to extend Horizon turnaround intervals to once every three years, increasing average production capacity by 5,000 bbl/d of SCO, bringing total Oil Sands Mining and Upgrading production capacity to approximately 597,000 bbl/d. The Naphtha Recovery Unit Tailings Treatment (NRUTT) project at Horizon is on track and on budget, with targeted incremental annual production of approximately 6,300 bbl/d of SCO after mechanical completion in Q3/27. The company achieved its net debt target of $13 billion in Q3/26, and now targets to allocate 100% of free cash flow to shareholder returns through share repurchases. The pace of monthly share repurchases is targeted at $800 million per month in November and December 2026. In the first nine months of 2026, approximately $10.6 billion was returned to shareholders, including $6.8 billion directly through dividends and share buybacks and $3.8 billion indirectly through net debt reduction. Adjusted funds flow for the quarter was approximately $5.5 billion or $2.68 per share, and adjusted net earnings were $3.4 billion or $1.67 per share. Quarterly net earnings were approximately $3.0 billion. Sulphur pricing contributed pre-tax net revenue of approximately $0.5 billion in Q3/26 and $0.9 billion year to date. The Board approved a quarterly cash dividend of $0.625 per common share, payable January 5, 2027, representing an annualized dividend of $2.50 per share. Year to date, up to November 4, 2026, the company returned approximately $8.9 billion directly to shareholders through $5.1 billion in dividends and $3.8 billion in share repurchases, cancelling approximately 58.2 million shares at a weighted average price of $65.85 per share. Share repurchases in October 2026 totaled $728 million. Oil Sands Mining and Upgrading operating costs averaged $25.80/bbl (US$18.44/bbl) of SCO in Q3/26. Thermal in situ operating costs averaged $10.19/bbl (US$7.28/bbl) in Q3/26. Jackfish achieved record quarterly production of 143,039 bbl/d in Q3/26, exceeding facility nameplate capacity by approximately 23,000 bbl/d. The two new SAGD pads at Pike 1 are producing approximately 46,500 bbl/d at a Steam to Oil Ratio (SOR) of 1.7x. At Primrose, two CSS pads are targeted to come on production in Q1/27 and Q2/27, and at Kirby, a SAGD pad is targeted for Q3/27. The company is piloting solvent enhanced oil recovery technology on certain thermal in situ assets. The federal government designated the Pacific Link pipeline as a project of national interest and announced the Productivity Mega Deduction (PMD), expected to enhance competitiveness and investment in Canada. The trilateral Memorandum of Understanding (MOU) between the Oil Sands Alliance, the Government of Alberta, and the Federal government is expected to support future economic growth and provide a pathway to reduce GHG emissions. The next step is finalizing definitive agreements of the MOU.

Dangote’s fuel storage and pipeline project in Namibia breaks ground

Dangote Group has broken ground on a fuel storage and regional pipeline project valued at $2.5bn in Walvis Bay, Namibia.

Suncor Energy Inc (SU) (Q3 2026) Earnings Call Highlights: Record $6.7 Billion AFFO, $5. ...

Suncor Energy Inc (SU) delivered record quarterly cash generation, returned over $2 billion to shareholders, and agreed to sell non-core East Coast offshore assets for $1.2 billion upfront.

3 LNG Stocks Investors Are Watching As Long Term Gas Contracts Return

Global LNG producers such as Woodside are rewriting their playbooks, lining up multi year project pipelines, fresh cost cuts and new capital return rules just as long term gas contracts gain traction again. That mix of future cash flow targets, volume growth plans and payout flexibility has the attention of investors who do not want to miss a potential inflection in LNG linked income streams. This article discusses three stocks exposed to this news and outlines how these shifting cash flow...

Ovintiv Inc (OVV) Q3 2026 Earnings Call Highlights: Strong Cash Flow, Logan Energy Deal, and ...

Ovintiv Inc (OVV) beat consensus with $4.51 cash flow per share and $680 million free cash flow, returned ~69% to shareholders, and expanded its Montney position with the Logan Energy acquisition.

Cenovus Energy Inc (CVE) (Q3 2026) Earnings Call Highlights: Record $6. ...

Cenovus Energy Inc (CVE) posted record quarterly operating margin and adjusted funds flow on the back of record oil sands output, cut net debt to $3 billion, and returned $1.9 billion to shareholders.

Diamondback Energy: Undervalued Permian Excellence Built For Any Oil Environment

Africa’s LNG Exports Set to Soar 175% as Buyers Flee Hormuz

Energy buyers burned by the Strait of Hormuz are turning to Africa, and the money is following. The African Energy Chamber projects that Africa’s upstream sector will attract ~$40 billion a year through 2030, lifting the continent’s hydrocarbon output to 12.5 MMboe/d. Mozambique, Nigeria, Angola, Libya and Ivory Coast will take the largest shares of that capital, while new projects in Uganda, Kenya and Namibia expand the production base. Major offshore discoveries and a wave of upstream deals are turning Africa into the world’s…

Butane’s Perfect Storm Sends Prices to Decade Highs

Butane prices are surging across the world. Northwest European November butane prices have reached $1,125/t by early November, their highest level in 30 years, having exceeded even the peaks following Russia’s invasion of Ukraine. In Asia, the AFEI butane index stood at $1,180/t on November 3. US butane Belvieu prices have climbed to a 14-year high $920/t. This surge in prices reflects several overlapping trends, with the most significant being a reorientation of global propane/butane trade flows since the US-Iran war kicked off in March.…

Woodside Energy to cut at least 10% of workforce, targets $400M in cost savings

Cenovus says widest Canadian crude discount since 2018 temporary, will not change production plans

Qatar Becomes Largest Buyer of U.S. LNG Amid Hormuz Crisis

In an extraordinary turn of events, Qatar, the world’s second-largest LNG exporter before the Iran war, will become the biggest buyer of liquefied natural gas from the United States, the producer that overtook the Gulf nation as top LNG exporter earlier this decade. This extraordinary turn of events is, of course, the result of the extraordinary disruption that the Iran war and the closure of the Strait of Hormuz inflicted on Qatar, the LNG producer whose expansion plans for the rest of this decade were rivaled only by the U.S. The war and…

SM Energy targets early 2027 relief from Uinta production bottlenecks

(Oil Gas 360) SM Energy is evaluating potential changes to its drilling program in early 2027 as crude oil [ ]

Saturn Oil & Gas Inc. Announces Record Third Quarter 2026 Results with Production Exceeding Guidance and Analyst Expectations(8) for the Ninth Consecutive Quarter

(TSX:SOIL) (OTCQX:OILSF) Saturn Oil & Gas Inc. reported record quarterly production of 43,704 boe/d (82% oil and liquids) for Q3 2026, exceeding both guidance and analyst expectations, with volumes averaging 42,758 boe/d for the first nine months of 2026. The company generated record adjusted funds flow (AFF) of $150 million ($0.84/share) in Q3, bringing year-to-date AFF to $380 million. Adjusted EBITDA for the quarter reached $171 million, contributing to $439 million in adjusted EBITDA through September 30, 2026. Cash flow from operating activities was $156 million in Q3, up 24% from Q3 2025. Saturn executed its largest capital program to date, investing $128 million in Q3, drilling 60 gross (54.5 net) wells, including 32 (29.6 net) in southeast Saskatchewan, 20 (16.9 net) in West Central Saskatchewan, and 8 (8.0 net) in Central Alberta. Approximately $30 million of Q3 capital was deferred into Q4 due to wet weather in southeast Saskatchewan. Free funds flow for the quarter was $22 million ($0.12/share), with $167 million ($0.93/share) generated in the first nine months. The company added 3,700 boe/d of 96% light oil and liquids through strategic tuck-in acquisitions, investing $176.6 million to acquire Burgess Creek Exploration Inc. and Triland Energy Inc. in southeast Saskatchewan at 1.7 times run-rate net operating income. Saturn closed a dual-tranche offering of senior unsecured notes due 2031, issuing US$575 million at 8.5% and C$185 million at 7.5%, using proceeds to retire $706.7 million (US$503.8 million) of senior secured second lien notes due 2029. The new notes reduce effective interest costs by approximately 2%, extend tenor by two years, eliminate the mandatory 10% amortization, are unsecured, and relax certain covenants. Full-year 2026 capital guidance was increased to $355 to $375 million, with exit production guidance raised to 48,000 to 50,000 boe/d, and subsequently to 54,000 to 56,000 boe/d with the Corex Acquisition. Net debt at quarter-end was $1,001 million, with net debt to annualized adjusted EBITDA of 1.5 times and approximately $500 million of liquidity on an undrawn credit facility. Saturn renewed its Normal Course Issuer Bid (NCIB), repurchasing 12.1 million shares from August 27, 2025, to July 22, 2026, at a weighted average price of $3.29 per share, returning $66 million to shareholders through the repurchase and cancellation of 24.2 million shares since August 2024. During Q3, $10.3 million was returned to shareholders via repurchase and cancellation of 1.5 million shares at a weighted average price of $6.69 per share. The renewed NCIB authorizes up to 12.2 million common shares for repurchase until September 7, 2027, with a daily maximum of 200,855 shares. Subsequent to quarter-end, Saturn announced the $302 million acquisition of Corex Resources Ltd., adding approximately 7,000 bbl/d of 100% light oil production, expanding into Manitoba, and supporting an increased 2026 exit production target. The Corex Acquisition price represents 1.6 times run-rate net operating income and 82% of PDP NPV10 value, with consideration of $252 million in cash and $50 million in common shares. The transaction is expected to close prior to Christmas. The company expects to gain 323 gross (279 net) identified drilling locations, including nearly 30 net unbooked OHML opportunities in the Lodgepole at Virden and an estimated 25 net OHML locations in the Spearfish formation. Saturn anticipates capturing approximately $6 million in estimated annual efficiencies through facility consolidation and other operational improvements. Q3 petroleum and natural gas sales were $349,724,000, with year-to-date sales of $978,675,000. Net loss for the quarter was $48,296,000 ($0.27/share). Capital expenditures for Q3 were $127,957,000, with year-to-date capital expenditures of $212,788,000. Total assets at quarter-end were $2,581,111,000, and shareholders' equity was $853,336,000. The company maintained an active commodity hedging program and significant liquidity. Saturn's technical team continues to evaluate future OHML development locations, including in Manitoba assets to be acquired through Corex. The company expects to complete a seven-well Cardium pad at West Pembina shortly, with new volumes anticipated later in Q4 2026. At Flat Lake, Saturn reduced expected completion costs by approximately $1 million by utilizing surface groundwater for completions. The company remains focused on disciplined growth, reducing debt, and returning capital to shareholders.

Hornbeck Offshore Announces Third Quarter 2026 Results

(NYSE:HOS) Hornbeck Offshore Services, Inc. announced key operational and financial highlights for the third quarter ended September 30, 2026. The company completed its combination with Helix on September 1, 2026, resulting in a differentiated offshore services company with expanded capabilities in marine transportation, subsea services, and well intervention. Hornbeck announced five-year integrated services agreements with Shell in the U.S. Gulf of America, commencing in 2027, and was awarded a two-year decommissioning contract for integrated well intervention services in the North Sea, commencing in the second quarter of 2027. The company committed to acquire eight new work-class ROV systems, with deliveries beginning in the second quarter of 2027. Hornbeck has implemented $20 million of annualized cost savings to date. For the third quarter of 2026, revenue was $293 million and Adjusted EBITDA was $106 million, resulting in an Adjusted EBITDA margin of 36%. Adjusted Free Cash Flow was $59 million, with a conversion rate of 56%. The company provided Adjusted EBITDA guidance of $90 to $100 million for the fourth quarter of 2026 and $500 to $550 million for the full year 2027. As of September 30, 2026, total basic shares outstanding were 325,608,491, including 221,971,035 common shares and 103,637,456 Jones Act Warrants (strike price $0.00001 per share). The company recorded $119.8 million of merger and integration costs and $0.2 million of terminated offering costs during the third quarter of 2026. Excluding these costs, operating income for the third quarter would have been $59.9 million, operating margin 20.4%, net income $28.2 million, and diluted EPS $0.13 per share. Segment results included Marine Transportation & Specialty Vessel revenues of $141.2 million, Subsea Services Vessel revenues of $53.3 million, and Well Intervention revenues of $76.6 million. The company operated an average active fleet of 38.5 vessels in Marine Transportation, 9.0 vessels in Subsea Services, and 2.6 vessels in Well Intervention. As of September 30, 2026, contracted revenue backlog was approximately $1.9 billion, with $333.2 million expected to be recognized during the remainder of 2026, $792.8 million during 2027, and $741.3 million thereafter. The company had a cash balance of $471.6 million, total face value of debt of $730.6 million, and net debt of $259.0 million. Cash plus undrawn capacity under the revolving credit facility was $596.6 million. Hornbeck identified at least $75 million of annual revenue and cost synergies from the Helix merger, with $45 million in revenue synergies and $30 million in cost synergies expected within three years. The company has implemented actions representing approximately $20 million of expected annualized cost savings and is targeting $30 million annual cost synergy run-rate within the first year following the combination. The company is also targeting approximately $15 million of revenue synergies within the first year. Guidance for 2027 includes an anticipated contribution from the first of two HOS 400-class MPSV newbuilds, expected to enter commercial service late in the third quarter of 2027.

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LNG spot market prices in Asia have tripled since the start of the year. Asia and Europe are locked in a race for a limited number of cargoes. The U.S. is exporting record volumes of the fuel. And QatarEnergy just extended a force majeure on its own LNG exports. The world is short on gas—and will remain so for a while. The Japan-Korea Marker, the Asian LNG benchmark, topped $31 per million British thermal units this month. In fact, the benchmark briefly rose above $33 per mmBtu, compared with a little over $9 per mmBtu in January this year.…

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