Song of Oil and LNG

War and climate change drive surge in global shipping costs Shipping rates are rising across multiple chokepoints at once, with pressure reported on routes linked to the Panama Canal, Rhine, Red Sea and Black Sea, while a closure of Hormuz is also hitting seaborne trade. The common thread is disruption from both geopolitical conflict and climate-related constraints, tightening vessel availability and increasing transit risk across key global corridors. For oil, LNG and refined products, this matters immediately because these routes are not marginal. Hormuz is a core artery for Gulf exports, the Red Sea is central to Suez-linked voyages, the Panama Canal shapes Atlantic-Pacific LNG arbitrage, and the Rhine is critical for inland European energy logistics. When several of these systems are impaired at the same time, freight becomes a larger share of delivered energy cost, voyage times lengthen, and regional price dislocations widen even without an outright supply loss. The market signal is straightforward: higher shipping friction is becoming a pricing input in its own right across crude, products and LNG. 🔎 Source @songofoil

🇦🇴 Chevron Strikes Oil and Gas Offshore Angola in Major Discovery Chevron has made a major offshore oil and gas discovery in Angola, with the find seen as potentially tieable into existing Block 0 infrastructure. Even with limited disclosed detail on volumes, the key point is that this is not a greenfield concept on paper: the reference to Block 0 suggests a development pathway anchored in established offshore assets, which matters far more for timing and commerciality than an isolated discovery without evacuation options. For the market, that lowers the threshold for monetization. Infrastructure-led offshore discoveries can move faster and at lower unit cost than stand-alone projects, which is especially relevant for Angola as it tries to stabilize and refresh upstream output. The presence of both oil and gas also adds optionality, with liquids supporting near-term value and associated gas potentially feeding domestic use, reinjection, or future commercialization depending on scale and reservoir specifics. The signal is constructive for Angola’s upstream outlook: if the discovery is commercially confirmed, it strengthens the case that existing offshore hubs can still unlock incremental barrels and extend asset life. 🔎 Source @songofoil

🇱🇾 Libya Seeks Up to $40 Billion to Boost Oil Output to 2 Million Bpd Libya is seeking up to $40 billion in investment to lift crude production to 2 million bpd by 2030. The target implies a major upstream and infrastructure expansion effort over the rest of the decade, with the country explicitly linking output growth to large-scale capital inflows. For the oil market, this is a long-dated supply story rather than an immediate barrel event. If Libya were to move materially toward 2 million bpd, it would strengthen Mediterranean crude availability and add to medium-term OPEC supply optionality, but the path depends first on financing, project execution, and sustained operating stability. The signal is clear: Libya wants to reposition itself as a larger strategic supplier, but for now the market will treat the 2030 target as aspirational until investment commitments start converting into incremental production. 🔎 Source @songofoil

Global refining is now the binding constraint S&P Global Energy says the global refining system has little spare room left to absorb new disruptions. Global refinery runs in July were 7.5 million bpd below year-ago levels, and second-half 2026 runs are now seen averaging 80.1 million bpd, 2.4 million bpd below the previous outlook. Refined product exports from key suppliers are down 30 percent, or 4 million bpd, versus the same period of 2025, while gasoline, diesel and jet fuel are trading near $130-$170 per barrel, back to levels last seen during the 2022 post-invasion shock. The stress points are concentrated across the main export system. Middle East crude runs are expected at about 8 million bpd in 2026, roughly 1.6 million bpd below 2025, with capacity still impaired, stranded or operationally unreliable. Russia’s diesel export ban has removed 10 percent of waterborne supply, after diesel exports had already fallen by about 500,000 bpd year on year before the July 8 ban. China also failed to deliver a durable easing in product exports after renewed Strait of Hormuz disruption, with July crude throughput almost 2.9 million bpd below year-ago levels. Meanwhile, U.S. refiners are running at a record 96 percent utilization rate, effectively carrying the balancing role into hurricane season and autumn maintenance. This market is no longer short crude first but short flexible refining capacity, which means any fresh outage now transmits directly into product prices and physical tightness. 🔎 Source @songofoil

IEA cuts 2026 oil outlook The IEA now expects global oil demand to fall by 1.6 million barrels per day in 2026, pointing to Hormuz disruption, depleted inventories and record refining margins as the drivers reshaping the market. The combination in the agency’s framing is notable: a major chokepoint disruption, tighter stock buffers and stressed downstream economics are now feeding directly into the demand side of the balance. For the market, this is a bearish demand revision wrapped inside a bullish supply-risk narrative. Hormuz disruption and low inventories would normally support crude and products through security-of-supply premiums, while record refining margins signal acute tightness in usable barrels rather than comfort in the system. But if those conditions are severe enough to destroy 1.6 million bpd of demand in 2026, the implication is that high prices and logistical stress are expected to curb consumption materially even as prompt fundamentals stay tight. The signal is a more fragile oil market structure for 2026: tighter near-term physical conditions, but weaker demand once disruption and high costs start forcing consumption lower. 🔎 Source @songofoil

🇺🇸 Federal court voids Texas GulfLink license, halting 1 million b/d export project The US Court of Appeals for the Fifth Circuit on Aug. 12 vacated the federal license for Sentinel Midstream’s Texas GulfLink deepwater crude export terminal, citing serious procedural errors by the US Maritime Administration. The ruling stops development of the project, which was planned 30 miles offshore Freeport, Texas, with capacity to export up to 1 million b/d on VLCCs. GulfLink includes a 44-mile, 42-in. pipeline, carried a $2.1 billion price tag, and had targeted start-up around 2028. The court found MARAD violated the Deepwater Port Act of 1974 by improperly defining the project’s application area and ignoring overlapping pipeline infrastructure with the competing SPOT project. Under the law, only one crude deepwater port can be licensed within a single application area. That overlap became the decisive issue, with the court concluding the error was material enough to invalidate the license rather than send it back while keeping approvals in force. The case effectively gives fresh leverage to competing export infrastructure and adds new uncertainty to a project tied to a broader US-Japan trade arrangement. For US Gulf Coast crude logistics, the ruling is a reminder that legal and permitting geometry can be as market-moving as headline export demand. 🔎 Source @songofoil

IEA emergency oil stock releases lose momentum IEA member countries released 26 million bbl of emergency stocks in July, taking cumulative withdrawals to 300 million bbl under the 400 million bbl coordinated action announced on Mar. 11. Government stock draws averaged 750,000 b/d in July, down from 1.5 million b/d in June and 2.5 million b/d in May. More than 100 million bbl remains unused, with further releases now dependent on market conditions and supply security. The slowdown was most visible in Asia Oceania, where July releases fell to 4 million bbl from 8 million bbl in June and 44 million bbl in May as crude supply availability improved in Japan and Korea. The US also cut back, releasing 17 million bbl from the SPR in July, about half the June volume. But the buffer is less effective than the headline suggests: most of the remaining barrels are crude, while the market is increasingly tight in products. At the same time, global observed oil inventories fell by 69 million bbl in July, with oil on water down 63 million bbl as shipping through Hormuz and Bab el-Mandeb remained severely constrained. The signal is clear: emergency reserves are no longer offsetting the physical strain in the system, and the remaining barrels offer limited relief if transport chokepoints keep product markets tight. 🔎 Source @songofoil

🇺🇸 US to Soon Unveil Unprecedented Sanctions on Iran The US is preparing to unveil what Treasury Secretary Scott Bessent described as unprecedented sanctions on Iran. According to the snippet, the measures are part of a one-two punch alongside the continued blockade of Iran’s ports, signaling simultaneous pressure on both financial channels and physical export logistics. For oil markets, the immediate implication is tighter execution risk around Iranian crude and condensate flows. Even without confirmed volumes or implementation dates, a combined sanctions-and-port-blockade approach points to harder vessel access, payments friction, insurance and shipping complications, and a narrower pool of buyers and intermediaries willing to handle Iranian barrels. The market signal is straightforward: higher geopolitical risk around Middle East supply and a potentially firmer floor under prompt crude pricing if enforcement proves more than rhetorical. 🔎 Source @songofoil

Hormuz Closure, Storage Gap Keep Europe Bidding for US LNG The closure of the Strait of Hormuz and Europe’s historically low gas storage levels are keeping European buyers active in the US LNG market even as cooling demand starts to fade. The key shift is that procurement is being driven less by immediate weather-linked consumption and more by inventory risk, with buyers moving to secure cargoes before Asia steps up competition. That matters because Hormuz disruption raises the strategic premium on Atlantic Basin supply, while low European storage keeps import demand anchored beyond short-term temperature relief. In practice, this supports continued European bidding for US cargoes and limits the downside for Atlantic LNG demand even if near-term power burn eases. The trade-flow implication is straightforward: Europe is trying to lock in molecules early rather than risk tighter prompt availability once Asian demand strengthens. The market signal is that storage deficits and geopolitical chokepoints are outweighing softer cooling demand, keeping Europe structurally supportive for US LNG. 🔎 Source @songofoil

🇬🇧 UK North Sea operators move to cut decommissioning costs with vessel-sharing plan The North Sea Transition Authority and 17 operators have signed a charter to address the UK Continental Shelf well decommissioning backlog through deeper collaboration, data sharing and joint vessel use. The focus is subsea wellhead removals, where industry estimates show shifting final wellhead removal from rigs to vessels could cut remaining subsea removal costs by about 30%, or roughly £200 million. UKCS operators worked on 257 wells in 2025, including 114 final abandonments, up from 238 wells and 103 final abandonments in 2024. The push reflects the scale of the backlog rather than any easing in the liability. Around 500 inactive wells are still awaiting final abandonment, and more than 1,000 additional wells are expected to need decommissioning over the next five years. Total UKCS decommissioning spend hit a record £2.6 billion in 2025 versus £2.4 billion in 2024, while the estimated cost of remaining decommissioning edged down only marginally to £43.4 billion from £43.6 billion, with geopolitical instability and supply-chain competition still keeping pressure on costs. Participants include bp, Shell, Harbour Energy, EnQuest, Ithaca Energy, Serica Energy, Apache, CNOOC International, Eni, INEOS Energy Europe and Perenco. For the UK North Sea, the immediate strategic value is clear: free up rig capacity, lower abandonment costs and slow the rise of long-tail decommissioning liabilities across a mature basin. 🔎 Source @songofoil

🇮🇳 India cuts windfall tax on exports of petrol, diesel, aviation fuel India has lowered windfall taxes on exports of petrol, diesel and aviation turbine fuel, according to a government order, with the change taking effect from Saturday. The move directly affects refined product exports from one of Asia’s key export-oriented refining hubs. The immediate implication is a marginally better export netback for Indian refiners on clean products. That should support refinery economics and helps preserve India’s role in supplying diesel, gasoline and jet fuel into regional and global markets when arbitrage remains sensitive to policy friction as much as to outright crude prices. For the market, this is a modestly bearish signal for clean product balances at the margin: lower export taxes make Indian barrels more competitive and help keep product flows moving. 🔎 Source @songofoil

🇿🇦 South Africa's Top Court Blocks Shell Wild Coast Exploration South Africa’s Constitutional Court has blocked Shell-led exploration along the country’s Wild Coast, delivering another legal setback for offshore activity in the country. The ruling hits a Shell-led campaign and comes as South Africa’s upstream sector is already lagging regional momentum, with neighboring Namibia moving faster on offshore development. The immediate implication is further delay for South Africa’s offshore resource appraisal and a higher perceived legal and permitting risk for explorers looking at the basin. That does not change near-term oil and gas balances on its own, but it does matter for longer-dated supply optionality, capital allocation, and the relative attractiveness of frontier acreage in southern Africa, where Namibia is increasingly seen as the clearer growth story. For the market, this is another reminder that above-ground risk can be just as decisive as geology in shaping African offshore investment flows. 🔎 Source @songofoil

🇻🇪 bp secures Loran Phase 2 gas license offshore Venezuela bp has signed agreements with the Venezuelan government to advance offshore gas development, including an exploration and production license for Phase 2 of the Loran field in the Plataforma Deltana area. Loran Phase 2 holds an estimated 4 tcf of recoverable gas resources. bp will operate the project alongside XRG and UCC Oil and Gas Holding, with each partner holding 33.3%, subject to regulatory approvals. The award follows an April 2026 memorandum of understanding between bp and Caracas covering exploration and future development in Plataforma Deltana. The asset is part of the cross-border Loran-Manatee accumulation shared with Trinidad and Tobago, giving the project regional significance beyond Venezuela alone. The timing also matters: earlier in April, Chevron agreed to transfer its operated interests in Plataforma Deltana Blocks 2 and 3 to Venezuela as part of an asset swap with PDVSA, effectively creating room for a new alignment of offshore gas partners. For Venezuela, this is another step toward monetizing stranded offshore gas with international capital and operators, while for bp and its partners it is a calculated entry into a resource-rich but politically complex basin. 🔎 Source @songofoil

Global refining is now the real supply constraint S&P Global Energy says the global refining system has little spare room left to respond, with refinery runs in July 7.5 million bpd below year-ago levels and second-half 2026 runs now expected at 80.1 million bpd, 2.4 million bpd below its previous outlook. Refined product exports from key suppliers are down 30%, or 4 million bpd, versus the same period of 2025, while gasoline, diesel and jet fuel are trading near $130-$170 per barrel, back to levels comparable with the 2022 post-Ukraine shock. The squeeze is being driven by simultaneous disruptions across every major swing region. Middle East crude runs are seen at about 8 million bpd in 2026, roughly 1.6 million bpd below 2025, with capacity physically impaired, logistically stranded or unable to restart confidently. Russia’s diesel export ban has removed 10% of waterborne supply, after diesel exports had already fallen by around 500,000 bpd before the July 8 ban. China has not delivered the hoped-for easing in export controls, and July crude runs were almost 2.9 million bpd below year-ago levels. That leaves U.S. refiners, running at a record 96% utilization, as the keystone holding product markets together just ahead of hurricane risk and fall maintenance. The market is no longer short crude first but short conversion capacity, which means the next disruption will hit products and margins faster than outright oil balances. 🔎 Source @songofoil

🇺🇸 U.S. SPR drawdown nears operational floor for salt cavern storage The U.S. Strategic Petroleum Reserve has fallen below 300 million barrels for the first time since the early 1980s after a 172 million barrel emergency release tied to the Iran war, according to Department of Energy data released this week. The drawdown is set to leave the SPR at around 243 million barrels, well above the DOE’s stated physical minimum of 70 million barrels but within the 250 million to 300 million barrel range that some experts describe as the practical operational floor for cavern integrity and emergency response capability. The dispute is not about whether the caverns are empty, but about how repeated deep drawdowns and refills affect long-term salt cavern geometry, spacing and deliverability. The SPR stores crude in 60 underground salt caverns across four Gulf Coast sites in Texas and Louisiana. The DOE says collapse risks are false and that only the oil-water ratio changes inside always-full caverns. But the GAO said in May that repeated partial drawdowns can create undesirable cavern shapes and that every cycle expands cavern volume and reduces spacing within the salt dome, even if most caverns remained in very good condition after the 2022 release. The strategic takeaway is that the SPR still works as a security tool, but once inventories approach 250 million barrels the market starts to lose confidence not just in volumes on paper, but in the reserve’s physical ability to deliver barrels at crisis speed. 🔎 Source @songofoil

🇦🇪 Argus tracks shifting Abu Dhabi crude Argus Media has launched daily price assessments for Abu Dhabi offshore crude transferred in the Gulf of Oman, as disruption risk around the Strait of Hormuz reshapes regional trading patterns. The move points to a growing need for transparent pricing around barrels changing hands outside the traditional chokepoint route. For the market, this is a sign that physical trade flows are adapting fast enough to require a new benchmark reference point. If Abu Dhabi offshore crude is increasingly being transferred in the Gulf of Oman rather than moving through established loading and transit patterns tied to Hormuz, pricing visibility becomes critical for traders, refiners, shipowners, and risk managers. New daily assessments also help formalize alternative logistics and can support liquidity in contingency trade routes. The signal is clear: Gulf crude pricing infrastructure is adjusting to geopolitical shipping risk in real time. 🔎 Source @songofoil

IEA cuts 2026 oil outlook The IEA now expects global oil demand to fall by 1.6 million barrels per day in 2026, citing a market reshaped by Hormuz disruption, depleted inventories and record refining margins. The combination points to a supply-chain shock feeding through into end-user consumption rather than a simple macro slowdown. For the market, this is a clear signal that logistics stress and product-market tightness can destroy demand even when crude fundamentals alone do not fully explain the move. Any sustained disruption around Hormuz immediately raises the risk premium across crude and products, while depleted inventories leave less buffer and record refining margins translate into higher delivered fuel costs for consumers and industry. The key takeaway is that 2026 demand risk is now increasingly tied to physical chokepoints and downstream pricing, not just headline GDP assumptions. 🔎 Source @songofoil

🇺🇸 US to Soon Unveil Unprecedented Sanctions on Iran The US is preparing what Treasury Secretary Scott Bessent described as unprecedented sanctions on Iran, as part of a one-two punch that also includes the continued blockade of Iran’s ports. The signal is clear: Washington is escalating financial and physical pressure simultaneously, targeting both Iran’s ability to transact and its ability to move cargo. For oil markets, the immediate read-through is higher enforcement risk around Iranian crude and condensate flows, shipping access, port operations, and payment channels. Even without new volume figures, the combination of sanctions plus a port blockade points to tighter logistics, more difficult vessel movements, and higher compliance risk for buyers, shippers, insurers, and banks dealing with Iranian-linked trade. That does not automatically remove barrels overnight, but it raises the probability of disruption and widens the risk premium around Middle East supply flows. The market signal is straightforward: if the announced measures match the rhetoric, Iranian export continuity becomes harder to sustain and the geopolitical premium in crude should firm. 🔎 Source @songofoil

🇷🇺 Russia's Black Sea's Sheskharis terminal halts loadings after drone attack, sources say Crude oil exports from Russia’s Sheskharis terminal at the Black Sea port of Novorossiysk were suspended on Friday after a drone attack, according to three sources familiar with the matter. The halt adds disruption at one of Russia’s key export outlets on the Black Sea and directly affects loadings from a major seaborne crude corridor. The immediate market implication is operational rather than structural, but Novorossiysk matters because any interruption there can delay cargo programs, tighten prompt vessel scheduling in the Black Sea and push some barrels into later loading windows. For buyers, traders and shipowners, the key variable is duration: a short outage is manageable through rescheduling, while a prolonged halt would raise the risk of export slippage from a strategically important Russian outlet. The signal for the market is straightforward: watch whether this remains a brief logistics disruption or develops into a sustained constraint on Black Sea crude flows. 🔎 Source @songofoil

Natural Gas Turbine Demand Surges as Data Centers Drive Power Growth Demand for natural gas turbines is accelerating as data center buildout pushes power growth higher, with major manufacturers including GE Vernova, Siemens Energy, and Mitsubishi Heavy Industries reporting strong order activity and pointing to continued momentum. The trend is being reinforced by technology upgrades and heavier investment into electricity infrastructure. For gas markets, this is a clear signal that new power demand tied to digital infrastructure is increasingly translating into firm thermal generation requirements, especially where grid reliability and speed of deployment matter more than waiting for long-cycle alternatives. Strong turbine bookings do not equal immediate gas burn, but they do point to a thicker medium-term pipeline for gas-fired capacity and a stronger structural case for natural gas in power systems under stress from fast load growth. The market takeaway is that data centers are no longer a niche power-demand story: they are becoming a tangible support for future gas-fired generation, grid capex, and upstream demand expectations. 🔎 Source @songofoil