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Gulf Supply Shock: Kuwait and UAE Cuts | Analysis by Brian Moineau

Posted on by Brian Moineau

When the Strait of Hormuz Stutters: Kuwait and the UAE Turn Down the Taps

The image of huge tankers idling off a Gulf coast — engines quiet, destinies paused — has moved from the pages of history to this month’s headlines. This time, it’s not just dramatic footage: the near-closure of the Strait of Hormuz has prompted Kuwait and the United Arab Emirates to actively reduce oil and refining output. That isn’t a remote geopolitical drama. It’s a fast-moving shock to global supply chains, fuel prices, and the choices governments and companies must make this spring.

Why the cuts matter (and why they happened now)

  • The Strait of Hormuz is a choke point for global energy: a meaningful share of the world’s seaborne crude and LNG moves through this narrow waterway.
  • Recent attacks and warnings tied to the widening Iran war have made many shipowners and insurers avoid transiting the strait. Commercial traffic has slowed to a near-standstill in early March 2026.
  • Faced with limited export options and rising risk, Kuwait Petroleum Corp. and Abu Dhabi National Oil Co. (ADNOC) told markets they were managing production and lowering refinery throughput to match storage and export constraints. Kuwait’s initial cuts were about 100,000 barrels a day with plans to increase reductions depending on storage capacity and the status of Hormuz. (fortune.com)

Quick takeaways from the situation

  • Global oil flows are structurally exposed to a small number of maritime choke points; when those are threatened, supply swings fast.
  • Physical constraints (tankers avoiding Hormuz) and commercial constraints (insurance, buyer reluctance) compound each other — making a logistical slowdown feel like a supply shortage.
  • Even with alternate pipelines and export routes (for example, the UAE’s pipeline to Fujairah), bypass capacity is limited compared with total Gulf output, so price volatility and supply anxieties persist. (rigzone.com)

The immediate ripple effects

  • Markets: Brent and other benchmarks jumped as traders priced in the risk of sustained export disruption. Volatility surged because the practical loss of seaborne capacity happens faster than new capacity can be brought online. (euronews.com)
  • Refining and storage logistics: Refiners that rely on Gulf shipments face scheduling chaos; onshore storage is finite, so upstream producers are forced to curtail output rather than export into a bottleneck. Kuwait’s steps to trim both field and refinery output are a direct consequence. (fortune.com)
  • Regional balance: Countries with pipelines that bypass Hormuz (Saudi East–West pipeline, UAE’s Fujairah link) can cushion some flows, but combined bypass capacity still covers well under half of usual seaborne trade through Hormuz; large gaps remain. (specialeurasia.com)

Context you should know

  • This is not a simple “country X turned down the taps” story. It’s a chain reaction: geopolitical attacks and warnings → shipping and insurance pull back → physical exports slow → producers with constrained storage reduce output to avoid oversupply at home → global markets reprice risk.
  • Historical parallels exist (for example, tanker disruptions in the 1980s or episodic harassment in the Gulf), but modern markets are more interconnected and faster — so price moves can be sharper. Analysts and shipping intelligence reported tanker transits dropping to single digits some days in early March 2026, versus dozens per day in normal times. (euronews.com)

Who gets hurt — and who benefits (short term)

  • Hurt: Import-dependent economies (especially in Asia) face higher fuel bills and inflation pressures; refiners and logistics operators suffer schedule and margin disruptions; local consumers may see higher pump prices.
  • Beneficiaries (briefly): Owners of stored crude and some traders can profit from spikes; certain alternative suppliers or routes (pipelines to non-Hormuz ports, spare OPEC+ capacity held in reserve elsewhere) may gain market share temporarily.
  • Longer term: Repeated disruptions incentivize demand-side adjustments (fuel switching, strategic reserves) and supply-side investments (more pipeline capacity, diversification of trade routes), but those changes take time and money.

The investor dilemma

  • Oil-market investors face a choice between short-term volatility plays and longer-term fundamentals. Price spikes driven by transit risk are often followed by mean reversion once shipping resumes — but if the disruption lengthens, structural supply gaps could persist.
  • For companies with exposure to Gulf exports (tankers, insurers, intermediaries), balance-sheet stress and insurance premium spikes are realistic near-term risks. (enterpriseam.com)

What to watch next

  • Shipping and insurance notices: continuous updates from maritime advisors and insurers tell you whether transits are resuming or further constrained. The ISS shipping advisory and commercial trackers have been essential for real-time clarity. (iss-shipping.com)
  • Output statements from regional producers: watch ADNOC, Kuwait Petroleum Corp., Saudi Aramco and Iraq for how far and how long they plan to curtail production.
  • Price signals: sustained moves in Brent above recent ranges would indicate markets expect a longer disruption; abrupt falls would suggest temporary panic priced out.
  • Diplomatic and naval developments: any multinational efforts to secure shipping lanes or de-escalation steps will materially affect flows.

My take

This episode underscores a stubborn reality: geography still matters. No matter how sophisticated the markets, a narrow ribbon of water — the Strait of Hormuz — can force oil producers to choose between flooding domestic storage or throttling production. The response from Kuwait and the UAE is pragmatic: protect domestic infrastructure and avoid creating a crude glut they can’t export. But for consumers and businesses down the supply chain, pragmatic decisions by producers translate into higher prices and greater uncertainty.

Expect policymakers and traders to sharpen contingency planning — more attention on pipeline capacity, strategic reserves, and alternate suppliers — but also expect a period of elevated volatility while the situation remains unresolved.

Sources



Related update: We recently published an article that expands on this topic: read the latest post.

Related update: We recently published an article that expands on this topic: read the latest post.

Big Oil Doubles Down as Prices Falter | Analysis by Brian Moineau

Posted on by Brian Moineau

A surprising act of confidence: Why Exxon and Chevron kept pumping in Q3

The image of major oil companies throttling back while prices sag feels intuitive — yet in Q3 2025 Exxon Mobil and Chevron did the opposite. Both U.S. giants raised oil-equivalent production even as analysts and agencies warned of a growing global supply surplus and softening oil prices. That choice matters for markets, investors and the energy transition — and it tells us something about how the biggest producers think about the future.

Key takeaways

  • Exxon and Chevron increased third-quarter 2025 output, setting new records in several regions.
  • Their production growth is driven by recent project start-ups, acquisitions (Chevron/Hess) and Permian and Guyana expansions (Exxon).
  • The increases come amid IEA and bank forecasts of a potential supply glut and downward pressure on prices.
  • The companies appear to be prioritizing volume, cash generation and project execution over short-term price signaling.
  • That strategy reduces per-barrel breakevens through scale and cost discipline, but it also risks amplifying a market surplus if too many producers do the same.

The scene: more barrels while the price outlook cools

In Q3 2025 Exxon reported oil-equivalent production of roughly 4.8 million boe/d, reflecting record Permian and Guyana volumes and recent project start‑ups (Yellowtail among them). Chevron posted production north of 4.0 million boe/d, helped materially by the Hess acquisition and ramp-ups across its portfolio. Both companies beat many expectations for operational delivery even as headline crude prices slid from earlier 2024–2025 highs. (corporate.exxonmobil.com)

Meanwhile, the International Energy Agency and several major banks warned that global supply is outpacing demand growth — a dynamic that could leave the market with a multi-million-barrel-per-day surplus into 2026 and keep downward pressure on benchmarks like Brent and WTI. Those forecasts, plus OPEC+ output decisions and slowing demand growth projections, have shaped a decidedly more bearish short‑term outlook for oil. (reuters.com)

Why keep the taps wide open?

Several practical and strategic reasons explain the behavior.

  • Project momentum and economics

    • Large investments and recently started projects (Exxon’s Guyana developments, Chevron’s post-Hess additions) are optimized to run. Once capital is committed, incremental unit costs fall as production scales — so maximizing throughput preserves investment economics and cash flow. (corporate.exxonmobil.com)

  • Cash generation and shareholder returns

    • Even at lower prices, higher volumes translate to meaningful cash flow. Both companies have continued to prioritize returning capital via dividends and buybacks; maintaining or growing production supports that. (investing.com)

  • Competitive and strategic positioning

    • Winning in long-cycle growth areas (Guyana, Permian) cements competitive advantages. Producing now also preserves market share and prevents leaving value on the table that competitors might capture.

  • Operational discipline lowers risk

    • Both firms emphasize cost control and higher-margin barrels (low breakeven wells, advantaged crude streams). Their messaging suggests confidence that many of their new barrels remain profitable even with softer benchmark prices. (corporate.exxonmobil.com)

The market tension: short-term glut vs. long-term demand view

From the IEA’s perspective, 2025–2026 could see several million barrels per day of surplus, driven by faster supply growth (OPEC+ easing cuts and higher non-OPEC output) and modest demand expansion. That’s a recipe for weaker prices near term. Yet Exxon and Chevron publicly lean on a longer-term view: resilient oil demand through the mid- to long-term and value tied to low-cost growth projects. The result is a strategic push to convert investments into volumes and cash today rather than mothballing assets in hopes of higher future prices. (reuters.com)

What investors and policymakers should watch

  • Price sensitivity: If more majors chase volume, the supply/demand imbalance could deepen, pressuring prices and testing the majors’ margin assumptions.
  • Capex discipline: Watch whether future spending remains disciplined or ramps further — more capex means more future supply.
  • OPEC+ moves: Any shift in OPEC+ policy (reinstating cuts or holding production steady) would quickly change the short-term equation.
  • Balance sheets and returns: Continued strong cash flow supports buybacks/dividends, but sustained low prices would force re‑prioritization.
  • Transition signalling: How these firms balance hydrocarbons growth with decarbonization investments will shape their political and social license to operate.

A short reflection

Watching Exxon and Chevron push production higher even with a bearish short-term outlook is a reminder that big oil plays a long game. Their choices reflect a mix of sunk-cost economics, shareholder obligations and confidence in portfolio quality. For markets, that can mean more price volatility in the near term; for the energy transition, it highlights a stubborn supply-side inertia that renewables and efficiency must outpace to shift demand-supply fundamentals.

Sources



Related update: We recently published an article that expands on this topic: read the latest post.