Why Coal and Uranium Could Win the Energy Resilience Trade

Queues of scooters snaked around a Bali petrol station this month, and a few days earlier shipping tracker Kpler estimated that just 2.9 million barrels moved through the Strait of Hormuz on 11 October, against almost 20.8 million on 8 October. Yet the International Energy Agency (IEA) has described a 2026 oil surplus widening toward 4 million barrels per day (mb/d). Both pictures cannot look the same from the forecourt.

The gap matters for anyone weighing the energy resilience trade. Asia and Europe are being squeezed by shipping disruption, thin gas storage and drawn-down emergency reserves, while headline global stocks still look comfortable. Officials also have good reasons to describe the stress as temporary.

The stakes run both ways. Coal and uranium sit in washed-out sentiment territory, which is where asymmetric setups tend to form. If the restocking thesis is wrong, though, cheap can get cheaper.

Here is a framework for judging whether restocking demand and a longer resilience buildout justify those two setups, and the specific points where the argument can break.

Is the shortage real, and why would officials say it is not?

What the physical evidence shows

The Bali queues have an official explanation. State energy company Pertamina said a tanker had trouble discharging its cargo, creating a distribution delay rather than a national shortfall, according to AFP on 14 October. A replacement vessel carrying more than 22 million litres arrived on 13 October, roughly seven days of Bali demand.

That account may be accurate. It also describes a system with about a week of cushion.

Wider in the region, the signals are thinner but point the same way. Reuters and humanitarian monitor ACAPS reported in March that Bangladesh and Pakistan suspended gas to fertiliser plants, and that Thailand halted fuel exports to Myanmar as a precaution.

Hormuz in four days Kpler estimated 20.8 million barrels crossed the strait on 8 October and 2.9 million on 11 October. Middle East exports averaged about 17 mb/d that week against roughly 23.3 mb/d before the conflict, with commercial crossings falling from 32 ships to just six on a single day.

The sharp one-week drop is easier to interpret once Hormuz oil flows are read as a chokepoint problem: a narrow stretch of water carries a large share of Asian import supply, so even short interruptions show up first in regional fuel queues.

Why governments avoid the word shortage

Official caution here is rational. If drivers believe fuel will vanish, they fill tanks and jerry cans, and the fear becomes the shortage. The 1973 embargo and the 1979 Iranian Revolution both turned visible queues into political symbols, and Fergus Cullen of the Trader Ferg Substack argues Jimmy Carter’s use of the word “shortage” hurt his presidency.

Cullen also flags a quieter shift: rationing by quantity rather than price. Costco limited motor oil purchases in September, according to CNBC and Yahoo Finance, though sources did not reconcile the size of the cap or the price rise.

That kind of cap changes behaviour faster than any price move. When officials call queues logistics, cargo arrivals, export bans and purchase limits tell you more than the reassurance does.

Why can a world of full tanks still face a refill scramble?

The contradiction in the headlines largely dissolves once you separate total oil from oil that is usable where you need it. Global observed stocks count everything measured: crude in onshore tanks, oil sitting on tankers at sea, and fuel held by companies and governments. Oil on a ship stuck outside Hormuz counts, but it cannot fuel a Bali scooter.

Commercial stocks are held by refiners and traders. Strategic reserves are government stockpiles for emergencies, and once drawn they must eventually be rebuilt.

The IEA figures show the tension. Observed stocks stood at 8.21 billion barrels in January, then drew 129 million barrels in March and 117 million in April, followed by a 3.1 mb/d draw in August, according to Reuters reporting of IEA data. Separate IEA commentary described a four-year high near 7.9 billion barrels and a surplus near 4 mb/d, with more than a third of the build in China. The definitions and timing differ, and the sources do not reconcile them.

The March and April draws are part of a broader inventory drawdown that has pulled down OECD onshore stocks even as China’s build keeps the global total looking healthy.

Gas tells a sharper story. EU storage was 73.9% full on 12 October, about 14.9 percentage points below the five-year average, according to GIE data cited by Voltstack and TASS. Cullen’s German figure of about 60% covers a different scope and should not be conflated with it.

Where the bear case is strongest

• Bull: large draws in OECD onshore stocks, depleted US and Japanese reserves, and EU gas storage well below normal.
• Bear: a big starting inventory base, demand destruction from high prices, OPEC+ output expected to rise about 1.4 mb/d in 2026, and a Hormuz reopening releasing stranded barrels.
• Consensus marker: Cullen cites ARK Invest’s Cathie Wood calling for $50 oil as an example of consensus thinking.

Both lists can be true at once. A high global number does not rule out tightness in the regions and products where you hold exposure. What remains unproven is timing and size: no verified Brent, WTI or diesel crack levels were found, and no public refill targets for the US, Japan or India.

Can coal capture the resilience bid while sentiment stays washed out?

If regional tightness is the real story, coal is where it shows up first. Cullen reads Newcastle thermal coal as having bottomed, broken out, then compressed sideways, with a winter surprise as the possible catalyst. Reports place the benchmark around $143-152 per tonne in early October, with Morgan Downey’s citing $152.20 on 6 October, the highest since October 2024.

The physical driver is substitution. When liquefied natural gas (LNG) gets scarce or expensive, Asian utilities burn more coal. The Japan Korea Marker (JKM), Asia’s spot LNG benchmark, hit $25.88/MMBtu on 7 October, a premium of $1.47-$3.49 over European gas, as Europe’s refill and Asian demand chase the same cargoes.

The IEA forecasts Chinese coal demand rising 1% to about 5 billion tonnes in 2026, ASEAN demand near 574 Mt, and Southeast Asian coal demand growing 4.4% a year through 2030.

The coal-to-gold ratio Cullen argues the ratio has reverted about a third of the way toward 2022 levels. On his view, a full reversion would imply gold near 3,900 and Newcastle around $250-260 per tonne. This is a speculative scenario, not a forecast.

The setup looks asymmetric, but not safe. Coal’s upside leans on LNG staying scarce, so a coal position is really a bet on how long the disruption lasts.

Whether a Newcastle coal price surge reaches producer earnings depends on contract exposure and volumes, which is why diversified miners and pure-play coal names can respond very differently to the same benchmark move.

Does uranium’s contracting gap make it the slow-burn resilience play?

Uranium answers a different question. Coal depends on the disruption lasting; uranium depends on utilities eventually running out of patience.

Reactors need fuel regardless of short-term power prices. Spot sat near $89.63/lb at the end of September, and the term price, set in long-dated supply deals, reached about $96/lb, reportedly above the 2007 peak.

The utility contracting cycle runs on a slower clock than spot trading, since buyers lock in supply years ahead and often wait until coverage is thin before returning to the market.

The coverage cliff Sprott estimates US utility contracted coverage could fall from about 98% of requirements in 2026 to 60% in 2030 and 9% in 2033 if existing flexibility is fully exercised.

Utilities are not rushing. Sprott counted about 37 million pounds contracted globally in 2026 by 10 August, and later reporting showed term contracting down about 15% year-on-year to just over 38 million pounds by 31 August. Compare that with Cameco’s figure of 116 million pounds contracted across 2025, and the “sticker shock” is visible.

Weak contracting is the bullish signal and the reason equities stay depressed. Miners sell much output under older contracts, so realised prices lag spot and earnings forecasts can fall while the chart looks strong.

What could delay the shortage

• Bull case: steady reactor demand, falling future coverage, life extensions and energy-security policy.
• Risks: mine restarts, secondary supply, enrichment expansion, reactor delays, policy reversals and realised prices below spot.

That makes uranium a longer-dated resilience asset than coal. The catalyst timing is unknowable, so the setup asks for patience rather than a near-term trigger.

Weighing the evidence before building a resilience position

The pattern holds together: regional physical markets are tight, inventory data conflicts but reconciles, and coal and uranium offer washed-out setups on very different clocks. Four variables will tell you whether the thesis is strengthening:

1. Hormuz flows against the pre-war level of about 23.3 mb/d.
2. EU gas storage relative to its five-year average heading into winter.
3. Newcastle and JKM prices and the Asian LNG premium.
4. Utility term contracting volumes in uranium.

The clearest failure point is a ceasefire that reopens Hormuz and floods supply back. If that happens, the regional squeeze could unwind faster than the refill demand arrives.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. Past performance does not guarantee future results, and forward-looking views are speculative and subject to change.