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Shell Sees LNG Growth Opportunities From Canada to Venezuela Amid Supply Crunch
Shell is positioning for LNG growth across the Americas, pointing to opportunities from Canada to Venezuela as global energy disruptions keep the market tight. The company is linking that outlook to acquisitions and expansions, including the ARC deal and LNG Canada, alongside potential export growth and new partnership structures aimed at meeting rising LNG demand.
The immediate read for the gas market is straightforward: a major portfolio player is signaling that supply remains constrained enough to justify adding optionality across upstream gas, liquefaction and export channels. LNG Canada is especially relevant because any incremental Pacific Basin supply from Canada improves access to Asian demand and diversifies flows away from more congested Atlantic routes. The Venezuela reference is more strategic than immediate, but it underlines how seriously large LNG players are scanning underdeveloped gas positions for future export relevance.
The signal to the market is that the supply crunch narrative is still strong enough for Shell to keep building LNG exposure across multiple jurisdictions rather than waiting for looser balances.
🔎 Source
@songofoil
🇮🇷 Iran says four tankers hit mines in Hormuz as U.S. strike risk rises after midterms
Iran said four tankers were hit by mines in and around the Strait of Hormuz, directly challenging U.S. claims that key shipping lanes had been cleared. The IRGC said three tankers caught fire after striking mines on an unauthorized southern route near the Omani coast, while Iran’s army said a fourth vessel burned east of the strait. Separately, UKMTO reported a small boat attached two explosive devices to a tanker about 25 nautical miles northeast of Khasab, Oman, causing an engine-room fire that disabled the vessel. The strait normally carries about one-fifth of global energy supplies, but traffic has already fallen to single-digit daily transits since the war began in late February.
The escalation comes as Iran-backed Houthis claimed six operations against Saudi airports and oil facilities, opening a second pressure point across the region, even as Saudi and Iranian officials had just met in Tehran to discuss de-escalation. In Washington, the signaling is mixed: JD Vance has reportedly used Qatari mediation to float a framework for talks with Tehran, while reports indicate the Trump administration is weighing renewed military action after the Nov. 3 midterm elections, with Adm. Brad Cooper briefing Trump on regional options.
For oil and LNG markets, the message is that Hormuz clearance remains contested, physical transit risk is still rising, and any post-election U.S. military move would immediately reprice Middle East supply security.
🔎 Source
@songofoil
How Trump’s Russian Diesel Could End Up in Cuba Instead
A tanker carrying Russian diesel linked to a transaction initiated during Donald Trump’s first term has reportedly dropped New York as its destination amid a legal dispute, prompting speculation that the cargo could be diverted to Cuba instead. The key immediate fact is the change in declared destination against the backdrop of a legal showdown, with Russian diesel now potentially shifting away from the US market.
For the market, the signal is less about volume than about sanctions, compliance risk, and cargo optionality. A destination change from New York to Cuba would underline how politically sensitive refined-product flows can be rerouted when legal or regulatory pressure rises. It also highlights that even a single diesel cargo can become a geopolitical issue when Russian-origin barrels intersect with US jurisdiction and Caribbean demand.
The near-term takeaway is that legal risk is now driving trade-flow uncertainty at least as much as underlying diesel market fundamentals.
🔎 Source
@songofoil
🇨🇦 Shell to take 30% stake in Equinor's Bay du Nord oil project in Canada
Equinor and Shell have signed an agreement under which Shell will acquire a 30% interest in the Bay du Nord project offshore Newfoundland and Labrador in Canada, the companies said on Friday. The deal brings another major international oil company into one of Canada’s key offshore developments, with Equinor reducing its working interest while keeping the project moving forward.
The immediate read-through is portfolio de-risking and capital sharing on a high-cost, long-cycle offshore oil project. Bringing Shell into Bay du Nord strengthens the project’s commercial backing and spreads execution risk at a time when large upstream developments continue to compete for capital discipline. For Canada, it is also a constructive signal for future offshore supply potential from the Atlantic basin, even if any production impact remains longer-dated rather than near-term.
For the market, this is less about immediate barrels and more about confidence that high-quality offshore oil projects can still attract top-tier partners and capital.
🔎 Source
@songofoil
🇻🇪 Nabors returns to Venezuela with early 2027 rig deployment
Nabors Industries signed a multiyear contract to deploy one rig in Venezuela in early 2027, marking its return to drilling operations in the country. The announcement came alongside third-quarter operating updates showing International Drilling daily adjusted gross margin at a record $19,060, up $1,526 quarter-on-quarter, with the international average rig count rising to 94.9 from 93.4.
The Venezuela move lands as Nabors continues to expand internationally even as Saudi Arabia sees a temporary reset. SANAD, its land drilling joint venture, deployed its 17th newbuild rig, with one more due this year and two in Q1 2027 to bring the fleet to 20, although five rigs were suspended and management expects a lower SANAD rig count in the fourth quarter. Capital spending for 2026 is now guided at $710 million to $720 million, including $295 million to $305 million for the SANAD newbuild program.
The strategic signal is clear: Nabors is using high-spec rig demand and margin expansion in international markets to re-enter constrained but politically important basins like Venezuela.
🔎 Source
@songofoil
🇮🇷 Iran threatens South Korean shipping group over Hormuz transits
Iran has threatened South Korea’s Sinokor over what it describes as repeated crossing violations in the Strait of Hormuz, according to the report. The snippet says Tehran has historically enforced such rules through military action, which immediately raises the seriousness of the warning beyond routine maritime bureaucracy.
For oil and LNG markets, any direct pressure on commercial shipping in Hormuz matters because the strait remains the key chokepoint for Gulf crude, products and LNG exports. Even without a reported disruption, threats of enforcement increase voyage risk, strengthen the case for higher freight and insurance premia, and put charterers, shipowners and Asian buyers on alert for possible delays or rerouting decisions.
The immediate signal is not lost supply, but a higher geopolitical risk premium around Hormuz transits and another reminder that shipping exposure in the Gulf can reprice very quickly.
🔎 Source
@songofoil
🇺🇸 US LNG Feedgas Rebounds Above 20 Bcf/d, Seen Holding Into Mid-November
US LNG feedgas demand has moved back above 20 Bcf/d, with the rebound driven by strong performance at key export terminals and expectations that these levels can hold into mid-November. The move points to renewed utilization across the US liquefaction system after earlier softness and puts export demand back near the levels the market watches most closely for balances.
For gas and LNG markets, feedgas above 20 Bcf/d is a clear signal that US export pull is reasserting itself just as participants track Asian LNG futures, European market dynamics and coal price signals. If sustained, that tightens the call on US gas supply domestically while reinforcing Atlantic Basin LNG availability into Europe and optionality for cargo flows into Asia, depending on prompt netbacks.
The near-term market signal is straightforward: stronger US terminal runs support LNG-linked gas demand and keep the global balance sensitive to weather, coal-to-gas competition and regional price spreads.
🔎 Source
@songofoil
🇺🇸 EIA pushes US oil outlook to the edge of 14 million bpd
The EIA lifted its 2026 US crude oil production forecast in the October STEO to 13.87 million bpd, up from 13.83 million bpd in September, 13.80 million bpd in August and 13.78 million bpd in July. For 2027, the agency now sees output at 14.30 million bpd versus 14.26 million bpd previously. The quarterly profile is even more telling: 14.13 million bpd in 1Q 2027, 14.26 million bpd in 2Q, 14.32 million bpd in 3Q and 14.50 million bpd in 4Q.
The US has still never averaged 14 million bpd on either an annual or monthly basis, but it is getting very close. The highest annual level on EIA data was 13.662 million bpd in 2025, while the peak monthly figure was 13.995 million bpd in October 2025. The 2026 supply base remains overwhelmingly Lower 48 driven at 11.39 million bpd, with the Federal Gulf of America at 2.03 million bpd and Alaska at 0.45 million bpd.
The strategic takeaway is that US crude supply growth is still capping upside for global oil balances, with the real milestone now shifting from whether 14 million bpd is possible to when it becomes routine.
🔎 Source
@songofoil
🇹🇱 Timor GAP moves to take full control of Greater Sunrise
Timor GAP agreed to acquire Woodside Energy’s entire 33.44% stake in the Greater Sunrise project for $200 million, adding to its previously announced deal for Osaka Gas’ 10% interest. If both transactions close, Timor GAP will hold 100% of the Sunrise joint venture. The Woodside deal is targeted to close in first-half 2027, subject to government, regulatory, and joint-venture approvals.
The payment structure is heavily back-ended. Timor GAP will pay $13.71 million at closing, another $11.29 million within 30 days of final investment decision, and $175 million within 365 days of first cargo loading for customer sale. Greater Sunrise, which includes the Sunrise and Troubadour gas-condensate fields, lies about 150 km southeast of Timor-Leste and 450 km northwest of Darwin, with estimated resources of 5.1 tcf of gas and 226 million bbl of condensate. Full ownership strengthens Dili’s push for the Timor LNG concept via pipeline to Natarbora under the Timor-Leste-Australia Maritime Boundaries Treaty.
This is a sovereignty-first restructuring that gives Timor-Leste maximum control over monetization, but it also concentrates execution, financing, and commercialization risk in a single state-backed player.
🔎 Source
@songofoil
🇺🇸 Freeport LNG Feedgas Cuts Knock US Demand From Recent Highs
Feedgas cuts at Freeport LNG have pulled US natural gas demand off recent highs, with lower intake at one of the country’s key export terminals offsetting part of the ramp-up elsewhere. The shift comes even as deliveries increase at other LNG facilities, including Plaquemines and Golden Pass, highlighting a mixed feedgas picture across the US Gulf Coast.
The immediate market read is that aggregate US gas demand loses some support when Freeport steps back, even if newer or expanding terminals continue to absorb more volumes. That matters for prompt gas balances because Freeport has been a major source of incremental LNG-linked demand, while higher flows to Plaquemines and Golden Pass suggest the broader export growth story remains intact but uneven in the near term.
The signal for the market is that US LNG demand growth is still advancing, but short-term price support will depend on whether gains at other terminals can fully compensate for operational dips at established plants like Freeport.
🔎 Source
@songofoil
Oil adds risk premium after Houthi strike claim on Ras Tanura
Brent rose $1.50, or 1.32%, to $115.59/bbl on Wednesday, while WTI gained $1.47, or 1.47%, to $101.37/bbl, as the market repriced Middle East supply risk. The move followed a Houthi claim that it attacked Saudi Arabia’s Ras Tanura refinery with a ballistic missile on Tuesday, raising fresh concern over the security of critical Gulf oil infrastructure.
The price reaction reflects more than a single incident. Traders are now balancing the prospect of a prolonged regional conflict with harder rhetoric from Trump, who said the war with Iran would end on his terms and reiterated that Tehran must be prevented from acquiring nuclear weapons. At the same time, uncertainty around Israel’s election outcome added another layer of geopolitical noise, reinforcing the premium already embedded in crude.
As long as attacks or credible threats reach core Saudi export and refining assets, oil will keep trading on disruption risk rather than on prompt physical balances alone.
🔎 Source
@songofoil
Syria tries to reprice its geography into an oil corridor
Syria is pitching itself to investors as an alternative export route for Iraqi crude to the Mediterranean as disruption in the Strait of Hormuz revives interest in bypass corridors. Damascus is promoting rehabilitation of pipelines, refining and storage assets, with Baniyas positioned as a key node. The logic is straightforward: Syria’s own oil sector has collapsed, with production down from a peak of around 672,000 b/d in 2002 to about 34,000 b/d in 2025, while gas output fell from 8.4 bcm in 2010 to roughly 3.3 bcm in 2025.
The country is no longer selling a production story so much as a transit and infrastructure story. Iraq is already moving some crude through Syria by road on a limited scale, and the current Gulf war has sharply increased the strategic value of any route that reduces dependence on Hormuz. Damascus is also trying to convert that geopolitical premium into foreign capital, with Gulf and U.S. companies reported to be exploring openings as Washington backs Syria’s economic reintegration and alternative regional energy routes.
If security, sanctions risk and investment terms do not materially improve, Syria will remain more useful as a contingency map option than as a bankable energy corridor.
🔎 Source
@songofoil
🇩🇿 Algeria Votes to Send Troops to Protect Niger Oil Facilities
Algerian lawmakers have approved sending troops to protect oil facilities in neighboring Niger, marking a more assertive foreign policy step by the North African OPEC member. The move directly links Algeria’s security posture to the protection of upstream energy infrastructure beyond its own borders.
For the market, the signal is less about immediate barrels and more about security risk management around Sahel energy assets. Any formal military backing for Niger oil facilities points to persistent concern over supply disruption risks in a region where infrastructure security is a core variable for production continuity, investment confidence, and export reliability.
The immediate takeaway is that regional energy security in the Sahel is becoming more explicitly militarized, and that raises the strategic value of protected oil infrastructure even if near-term supply balances do not change overnight.
🔎 Source
@songofoil
🇷🇺 Russian Refiners Ramp Up Diesel Output to Supply Trump Deal
Russian refiners are raising diesel production toward 180,000 tons per day after Moscow issued export quotas under a supply arrangement with the United States. The key operational signal is clear: refinery runs and diesel yields are being pushed higher to meet export commitments under a politically framed bilateral deal.
For the market, this points to additional Russian diesel barrels being directed into export channels rather than held back domestically. At 180,000 tons a day, the move is large enough to matter for middle-distillate balances, especially if quotas create a more predictable flow of cargoes. That should be read as a bearish signal for diesel cracks and for competing suppliers into any overlapping destination markets, while also underscoring that Russian product exports remain highly policy-driven.
The immediate takeaway is that state-directed export quotas are translating into more Russian diesel on the water, with direct implications for distillate trade flows and pricing.
🔎 Source
@songofoil
Iran hosts regional powers for talks to prevent fresh escalation
Senior security officials from Saudi Arabia, Pakistan and Turkey met Iranian counterparts in Tehran on Monday, signaling an active regional effort to contain a new security deterioration.
For oil and LNG markets, the immediate relevance is geopolitical risk management around the Gulf and adjacent trade corridors. A Tehran meeting with Saudi, Pakistani and Turkish participation suggests key regional actors are trying to keep tensions from spilling into shipping, energy infrastructure or cross-border security dynamics that would quickly feed into crude risk premia.
The market signal is straightforward: diplomacy is being mobilized to cap escalation risk, but the fact that this format was necessary keeps a geopolitical bid under regional energy benchmarks.
🔎 Source
@songofoil
Natural gas bulls find little shelter from storage surprise
U.S. natural gas futures turned lower after the market absorbed an 80 Bcf storage injection that came in above expectations, pushing prices back below $2.900/MMBtu. The move came despite renewed LNG demand, with the storage data overriding support from export-side consumption.
The immediate read is straightforward: a larger-than-expected build points to looser near-term balances than bulls were positioned for, especially if weather demand is not strong enough to offset healthy injections. Renewed LNG demand still matters for the structural call on U.S. gas, but in the prompt market it was not enough to neutralize bearish storage optics.
For now, storage is reasserting itself as the dominant price signal, and sub-$2.900/MMBtu trading suggests the market needs either stronger weather-driven demand or tighter injections to rebuild upside momentum.
🔎 Source
@songofoil
UBS Sees $110 Brent by Year-End as Gulf Flows Stay Below Prewar Levels
UBS has lifted its Brent forecast for the second time this month, now looking for crude at $110/bbl by the end of 2026 versus a previous $100/bbl. The call is tied to Gulf oil flows remaining below prewar levels, with the bank effectively pricing in a more persistent disruption to regional exports than previously assumed.
The market message is straightforward: when a major house revises higher twice in one month, it signals that supply-risk premium is being treated as more durable rather than temporary. If Gulf flows stay constrained, balances tighten not only in prompt barrels but across the forward curve, supporting Brent and reinforcing freight, rerouting and refinery feedstock uncertainty for import-dependent buyers.
The key signal is that price upside is no longer being framed as a short-lived shock but as a sustained consequence of reduced Gulf availability.
🔎 Source
@songofoil
🇰🇿 Exxon blocks Kashagan settlement proposal over Kazakhstan's $5 billion fine
ExxonMobil has blocked a proposal for partners in Kazakhstan’s Kashagan oil field to reach a settlement with the government over a disputed $5 billion environmental fine, according to a report published Friday citing people familiar with the matter. The dispute centers on one of Kazakhstan’s most strategically important oil projects, where any disagreement among shareholders and the state immediately becomes a market-relevant issue.
The immediate implication is not necessarily a supply disruption, but a prolongation of legal and commercial uncertainty around Kashagan. For the market, that matters because unresolved fiscal or environmental claims can complicate partner coordination, investment decisions and the pace of future project activity at a field that remains central to Kazakhstan’s export outlook. A blocked settlement proposal also signals that negotiations with Astana may become more protracted and more politically sensitive.
The near-term signal is clear: no resolution yet, and Kashagan’s country risk premium stays firmly in view.
🔎 Source
@songofoil
🇺🇸 TotalEnergies deepens Chevron tie-up in the U.S. Gulf
TotalEnergies is taking a 25% working interest in 26 Chevron-operated exploration leases in the U.S. Gulf, while Chevron will take a 75% operated interest in two TotalEnergies exploration leases adjacent to acreage the companies already hold together. The 26 blocks are located 150-250 km offshore, with 24 in Green Canyon and two in Walker Ridge. Financial terms were not disclosed.
The transaction extends the companies’ offshore Gulf partnership after TotalEnergies entered 40 Chevron-operated exploration blocks in June 2025. It also strengthens TotalEnergies’ position around existing deepwater production hubs, including Ballymore at 40%, Anchor at 37.14%, Jack at 25% and Tahiti at 17%. The acreage is described as targeting well-proven plays, which lowers geological risk while preserving exposure to high-impact exploration upside.
This is a portfolio-building move: more Gulf barrels, more adjacency to infrastructure, and more optionality in one of the few OECD basins still offering scalable deepwater growth.
🔎 Source
@songofoil
🇮🇷 Iranians face energy squeeze from war as natural gas runs short
Tehran is telling citizens to curb energy consumption and urging civil servants to work from home as the country faces a natural gas shortage and tries to avert a broader crisis. The key signal is that the strain is serious enough to force demand-side emergency measures rather than routine balancing.
For the market, this points to mounting stress in Iran’s domestic gas and power system at a time when war is disrupting normal energy management. When authorities move to suppress consumption, the immediate implication is tighter fuel availability for households, power generation and industry, with higher risk of industrial curtailments and wider knock-on effects across domestic supply chains. Even without export volumes at stake, a gas shortage in a major hydrocarbon producer underscores how conflict can quickly turn upstream resource wealth into downstream energy insecurity.
The market takeaway is simple: wartime disruption is now translating into visible demand destruction and system stress inside Iran, adding another layer of regional energy risk.
🔎 Source
@songofoil
🇺🇸 Howard Energy Buys Iron Horse Midstream in Anadarko-to-Gulf Natural Gas Push
Howard Energy Partners is acquiring Iron Horse Midstream in a $2.5 billion deal that expands its natural gas footprint from the Anadarko Basin toward the Gulf Coast. The acquisition adds 425 MMcf/d of processing capacity in the Anadarko, plus 400 miles of pipelines, strengthening Howard’s position in Oklahoma and its ability to move supply into higher-demand downstream markets.
The immediate read-through is midstream-led preparation for stronger Gulf Coast gas pull. Additional processing and pipeline connectivity out of the Anadarko Basin should improve the basin’s ability to place molecules into Gulf Coast demand centers tied to LNG, industrial load and power generation, while also increasing optionality for producers in Oklahoma. For the market, this is less about upstream volume growth today than about de-risking future flows into a structurally premium demand corridor.
The signal is clear: infrastructure owners are still willing to spend heavily to secure basin-to-coast gas positioning ahead of expected Gulf Coast demand growth.
🔎 Source
@songofoil
🇨🇦 Shell to take 30% stake in Equinor's Bay du Nord oil project in Canada
Equinor and Shell have signed an agreement under which Shell will acquire a 30% interest in the Bay du Nord project offshore Newfoundland and Labrador in Canada, the companies said on Friday. The transaction brings a second global major into one of Canada’s key offshore oil developments and deepens Shell’s upstream position in the Atlantic basin.
The immediate read-through is strategic rather than near-term volumetric: bringing Shell into the project spreads capital and execution risk and should improve the project’s commercial resilience. For the market, that matters because Bay du Nord has been watched as a long-cycle offshore barrel that could support future non-OPEC supply from a stable OECD jurisdiction. The move also reinforces that large-cap oil companies are still prepared to back offshore projects with material reserve potential when portfolio fit and risk-sharing are right.
The signal is constructive for Canadian offshore oil and for confidence in longer-cycle supply additions, even if no immediate impact on prompt crude balances follows from the deal.
🔎 Source
@songofoil
🇦🇪 SNOC brings Hadiba gas field into first production phase
Sharjah National Oil Corporation has completed the first phase of development at the Hadiba gas and condensate field in the UAE, moving the asset from discovery in May 2024 to first gas in less than a year. The initial phase covered appraisal drilling, well data analysis, gas-gathering infrastructure, pipeline construction and facility commissioning. SNOC now says Hadiba is central to plans to more than double current gas production in Sharjah, with higher output targeted in 2027 and stable production expected by 2028.
The field lies northeast of the Sajaa gas field and fits the UAE’s broader push to lift domestic gas supply and reduce reliance on imports. For Sharjah, the value is not only new molecules but also execution speed: SNOC advanced the project despite regional shipping disruptions and material supply constraints. The company is also pointing to positive reservoir quality, favorable pressure characteristics and early production performance as signs that Hadiba has stronger long-term commercial potential than a routine appraisal result.
The strategic read is straightforward: Sharjah is trying to convert smaller, fast-cycle domestic gas discoveries into energy security gains on a compressed timeline.
🔎 Source
@songofoil
🇮🇷 Iran threatens South Korean shipping group over Hormuz transits
Iran has threatened South Korean shipping group Sinokor over alleged repeated crossing violations in the Strait of Hormuz, according to the snippet. The key point is not just the warning itself, but that the regime has historically enforced such rules through military action, turning what might otherwise look like a routine navigation dispute into a live shipping-risk issue in one of the world’s most critical energy chokepoints.
For oil, products and LNG markets, any escalation around Hormuz immediately matters because freight risk can reprice faster than outright supply. Even without a physical disruption, pressure on a commercial shipping operator raises the prospect of higher insurance costs, more cautious transit behavior and renewed scrutiny of voyage planning through the strait. That is especially relevant for Asian buyers and shipowners, including South Korean interests, given Hormuz’s central role in Gulf crude and LNG exports.
The market signal is straightforward: a threat tied to possible military enforcement in Hormuz is enough to keep geopolitical risk premium in freight and prompt attention across Gulf-linked energy flows.
🔎 Source
@songofoil
🇷🇺 Russia's Crude Exports Set to Fall as Diesel Production Rises
Russia’s crude exports from its western ports could fall by as much as 200,000 barrels per day in November as refiners raise diesel production under a new agreement between Moscow and Washington. The immediate signal is a shift in refinery runs and product yield rather than an upstream supply shock, with more crude being processed domestically instead of moving out through western export channels.
For the market, that points to a tighter prompt crude balance for barrels loading from Russia’s western ports, while potentially improving diesel availability if refiners sustain higher output. The key trade-flow implication is straightforward: fewer seaborne crude barrels from western Russia and more value retained through refined product exports or domestic product supply, depending on how the new arrangement is implemented.
The November watchpoint is whether the full 200,000 bpd reduction materializes, because that would be enough to affect regional crude flows even if the broader impact is partly offset by higher diesel production.
🔎 Source
@songofoil
Sanctioned Oil Tankers Find a Lucrative New Trade in the Persian Gulf
Former shadow fleet tankers that had been moving Venezuelan crude are now shifting into Middle Eastern oil trades in the Persian Gulf. The move comes as Washington seeks to expand legitimate shipping capacity, creating a notable reshuffle in tanker employment rather than a simple exit of sanctioned tonnage from the market.
The immediate implication is that vessels previously tied to one sanctioned barrel stream are being redeployed into another high-demand export region where freight economics remain attractive. For the oil market, that points to continued flexibility in physical trade flows and suggests tanker availability in the Gulf is being supplemented by ships that had operated on the margins of compliance, with potential effects on freight competition and crude evacuation efficiency.
The signal is clear: sanctions pressure is not removing tonnage from the system so much as redirecting it to where margins and demand are strongest.
🔎 Source
@songofoil
🇨🇦 Shell to take 30% stake in Equinor's Bay du Nord oil project in Canada
Equinor and Shell have signed an agreement under which Shell will acquire a 30% interest in the Bay du Nord project offshore Newfoundland and Labrador in Canada, the companies said on Friday. The deal brings another major into one of Canada’s most closely watched offshore oil developments and formalizes a larger risk-sharing structure around the project.
The immediate read-through is strategic rather than near-term barrels. A supermajor taking 30% signals continued commercial confidence in a frontier offshore project that has faced a long and closely watched development path. For the market, that supports the case for Bay du Nord moving forward with a broader partner base, which matters for future Atlantic Basin supply optionality even if it does not change prompt crude balances.
The signal is clear: large-cap oil is still willing to back long-cycle offshore barrels in stable jurisdictions when project quality justifies it.
🔎 Source
@songofoil
🇮🇳 India's BPCL to Cut Russian Oil Imports Due to Higher Prices
India’s BPCL will reduce Russian crude purchases in November as elevated freight costs and higher premiums erode the discount that made Russian barrels attractive. On the numbers available, the switch is purely economic: Middle Eastern crude is now the better deal for the refiner.
The immediate market read is that delivered Russian crude into India is losing competitiveness versus Gulf supply, at least for this buyer and this loading window. That matters because the Russian export model into Asia has depended not just on headline discounts, but on freight economics and secondary costs. If those components rise enough, refiners can rotate back to Middle Eastern grades without changing their core procurement logic.
The signal is straightforward: Russian barrels still need a clear landed-cost advantage to defend market share in India.
🔎 Source
@songofoil
🇪🇬 Egypt Votes to Defend Saudi Arabia, Risking Houthi Fire
Egypt’s parliament on Monday authorized military support to defend Saudi Arabia. The move formalizes Cairo’s readiness to back the kingdom directly and raises the risk that Egypt could be drawn more visibly into the Red Sea and Yemen security theater, where Houthi attacks have already shaped regional risk calculations.
For energy markets, the significance is not immediate supply loss but higher security sensitivity around Red Sea transit and Saudi infrastructure risk. Any widening of the conflict footprint involving another major Arab military raises the probability of retaliation threats, which in turn can feed into tanker risk premiums, shipping insurance costs, and broader geopolitical pricing across crude and refined products.
The market signal is simple: another step toward wider regional military alignment means another reason to keep a geopolitical premium in the barrel.
🔎 Source
@songofoil
🇺🇸 EIA pushes US oil outlook to the edge of 14 million bpd
The EIA lifted its 2026 US crude oil production forecast again, now seeing output including lease condensate at 13.87 million bpd, up from 13.83 million bpd in September, 13.80 million bpd in August, and 13.78 million bpd in July. For 2027, the agency raised the forecast to 14.30 million bpd from 14.26 million bpd previously. The quarterly profile is now firmly above the 14 million bpd threshold, with 14.13 million bpd expected in Q1 2027, 14.26 million bpd in Q2, 14.32 million bpd in Q3, and 14.50 million bpd in Q4.
The revisions underscore how US supply growth continues to be driven primarily by the Lower 48 onshore base. In 2026, the EIA sees the Lower 48 excluding the Gulf contributing 11.39 million bpd, the federal Gulf of America 2.03 million bpd, and Alaska 0.45 million bpd. That comes after average US crude production of 13.66 million bpd in 2025, already a record annual level. The historical marker is important: the highest monthly US crude output on EIA data remains 13.995 million bpd in October 2025, meaning the agency is now effectively signaling a sustained break above a level the US has not yet reached on either a monthly or annual average basis.
For oil balances, this keeps the US firmly in the role of marginal non-OPEC supply anchor and raises the bar for any producer group attempting to tighten the market through restraint alone.
🔎 Source
@songofoil