In volatile markets, the advantage often lies not in reserves — but in refining capacity and logistical optionality.
From a physical crude standpoint, it’s difficult to capture meaningful upside unless you are one of three types of participants:
For most others, the opportunity tends to sit further downstream in the chain.
At the moment, refinery shutdown announcements across China are giving the major oil companies pause. The “Big Six” oil majors appear reluctant to place too many additional cargoes on the water until the dust settles.
That caution is understandable.
Refining capacity — not reserves — may ultimately determine who benefits most from the current volatility.
The six major international oil companies stack up globally in refining capacity as follows:
EXXON : 3.90 million bpd
TOTAL : 1.85 million bpd
CHEVRON : 1.65 million bpd
BP : 1.60 million bpd
SHELL : 1.40 million bpd
ENI : 1.15 million bpd
In theory, Exxon should therefore be the biggest beneficiary in a volatile crude environment.
Yet equity markets rarely move purely on refining fundamentals.
Over the past week, the performance of these companies’ share prices told a very different story:
TOTAL : +4.4%
CHEVRON : +4.0%
SHELL : +3.3%
BP : +2.6%
ENI : +2.3%
EXXON : -0.9%
The worst performer by percentage move was the company with the largest refining footprint.
That discrepancy may simply reflect the equity market’s limited understanding of what actually drives volatility in crude markets.
For many hedge funds, gaining exposure to crude volatility is more easily done through equities rather than derivatives.
Buying shares in the oil majors offers indirect exposure to crude price movements without engaging directly in the derivatives markets.
That’s a typical buy-side macro strategy.
But the approach taken by the large commodity trading houses — Vitol, Trafigura, Mercuria, Gunvor and Glencore — is very different.
These firms operate as merchant principals, sitting somewhere between traditional buy-side investors and sell-side intermediaries.
They deploy capital directly into physical trades, logistics and refining optionality.
A good example occurred as conflict broke out in the Middle East.
One of the first physical moves Vitol made was to add Angolan crude to its heavy sweet blending pool.
For West Africa heavy sweet barrels, Vitol usually favours Cameroon. Angola was therefore an unusual addition.
They purchased 1 million barrels of Angolan crude to run through their teapot refinery in Malaysia.
Details of the trade:
Once refined, 40–50% of the barrel yields 0.5% fuel oil.
At the time, spreads were approximately +80.
Within roughly six weeks, the ex-wharf value could reach +100.
Unlike national oil companies, trading houses with refining assets can speculatively refine without sovereign obligations or domestic supply commitments.
While most participants were chasing diesel-rich crudes, Vitol targeted a weaker link.
The value of that barrel could be realised in two markets simultaneously.
In sports betting, this would be called a parlay.
During black swan events, this kind of positioning can produce extraordinary profits — or losses.
Vitol leaned into the risk rather than avoiding it.
And the entire decision tree revolved around one thing:
their refinery in Malaysia.
Another example unfolded in the Caribbean.
The Suezmax Karekare loaded HSFO from Colombia in late February, before geopolitical tensions escalated.
The cargo discharged into Vitol’s storage tanks in St. Eustatius.
Colombian HSFO typically carries high metals content, making it unattractive in Asian markets.
At the same facility, Vitol already held “wet” SRFO from Venezuela — another grade that normally struggles to compete in Asia due to abundant high-quality SRFO supply.
Then geopolitics shifted.
Iranian SRFO was effectively removed from the market.
Suddenly the system was short SRFO.
Both barrels now worked on the arbitrage into Asia.
Even better, the grades complemented each other:
The blend suddenly became highly viable.
Pure arbitrage poetry.
There is also a broader structural element developing.
With Qatar offline in LNG markets, utilities may return to HSFO-based power generation.
That brings several regional markets into focus.
Bangladesh represents a potential opportunity where significant margins can be captured with relatively simple shipping logistics.
Japan may prove the clearest indicator.
Taiyo Oil recently entered the market for two SRFO fixtures into Kikuma.
Normally they secure one cargo per month.
The sudden doubling of activity was almost Pavlovian.
Understanding Japan’s electricity market may require engagement with interdealer brokers, many of whom run desks in Tokyo trading intra-day power generation swaps.
For comparison, Australia’s Lekki market behaves in a similar fashion.
Pakistan has been exporting HSFO recently, but its crude slate is now under pressure.
They are struggling to secure their usual barrels from the Arabian Gulf.
Pakistan is even reluctant to send vessels into the Red Sea to load from Aramco at Yanbu.
The state shipping line PNSC appears unusually cautious.
If that continues, Pakistan may soon need to import HSFO instead.
A likely scenario would be Pakistani vessels loading cargoes from Singapore, offering sellers a potential +40 ex-wharf margin without logistics risk.
Finally, the Red Sea.
For Saudi Arabia’s Red Sea power stations, Russian fuel oil may become the quiet solution.
Fortunately for them, the region is not currently at peak summer temperatures.
If this situation were unfolding in August, the scramble for fuel oil would already be underway.
