Why the world’s oil majors spent decades building the plumbing of performance measurement—and why everyone else is now rushing to copy it
For much of the 20th century, refineries were treated by their owners as engineering problems: keep the units running, keep the barrels flowing, and profit would follow. BP and Shell were among the first to notice that a refinery is also a bundle of options—on crude grades, on timing, on inventory, on products—and that those options, properly exercised, could be worth as much as the plant itself. Extracting that value took decades of trial, error and, above all, measurement.
That history is now repeating itself. Citgo and PBF in America, Bapco and KPC in the Middle East, and Tüpraş, Hellenic and Klesch in Europe are all building out trading desks of their own. They are following a trail blazed more recently by Aramco, ADNOC and OQ, which over the past ten years have gone from having none of these capabilities to fielding trading teams stacked with veterans poached from the majors.
Every firm on this path runs into the same thicket of questions. How much risk should a trader be allowed to run, and who keeps them honest? How should inventory and margin be hedged? Who owns which decision, and how is credit divided between the people who run the plant and the people who trade around it? None of these questions has a tidy answer, and the majors’ experience, while instructive, cannot simply be copied wholesale: it has to be bent to fit each firm’s own appetite for risk, its history and its culture. But one lesson travels well: none of the rest works without a good way of keeping score.
The Barrel Model
BP’s answer was what it called the “barrel model”, a framework that judges asset-trading performance along three axes: how inventory is managed, how well the crude and product slate is optimised, and how purchases and sales stack up against the market. Simple to state, harder to do well.
Inventory
The starting point is not the minimum stock needed to keep a refinery limping along, but the level required to run reliably and honour supply commitments—often close to the tank farm’s total capacity, since spare ullage is chronically scarce. When markets are backwardated, discipline calls for holding stocks near or below that operating level. When markets are in contango, carrying extra barrels can pay if the roll yield beats storage and financing costs—provided the resulting exposure is hedged. Measuring the gap between month-end stocks and the operating benchmark, then comparing it with what the market structure would suggest, turns inventory management from an art into a scorecard.
Hedging that inventory is its own quarrel. Holding flat-price risk through a period of severe backwardation, of the kind oil products have recently seen, means paying dearly to roll paper positions forward each month. The fix favoured by most sophisticated players is to hedge as far out the curve as balance-sheet and accounting rules allow—six months or more—leaving traders to manage only the sliver of inventory that sits above or below the operating benchmark.
Crude selection
For most refineries this is where the real money is. Choosing crudes that rank well against the plant’s own economics can add several dollars a barrel to gross margins, and more in volatile markets. To know whether a trader is any good at this, one needs a yardstick: a representative basket of crudes reflecting normal operations and available supply, refreshed at least annually as new grades appear and as shifting heavy-light spreads and product cracks reorder the pecking order. An optimisation model then generates the benchmark against which actual choices are judged. Swap in a cheaper, better-yielding crude and improve the margin, and that improvement counts as trading skill rather than luck—so long as the comparison is struck at the moment the decision was actually made, not with the benefit of hindsight once the barrels have arrived and the market has moved on. Distressed, last-minute changes to the crude schedule are, sensibly, exempted from this scrutiny.
Product slate
There is less room for manoeuvre here than on the crude side, but not none: adjusting the jet-naphtha cut point, refining blending strategy, choosing between export grades, or tilting output towards bitumen and away from fuel oil can all create value that deserves its own separate ledger, rather than being buried inside the broader margin number.
Buying and selling
The cleanest test of all is against a transparent market benchmark. Sell a cargo of diesel in northwest Europe at a $15-a-tonne premium when the market has averaged $10, and the extra $5 is unambiguously the trader’s. The same logic applies to pricing-period choices, such as fixing a cargo five days around bill of lading rather than at the monthly average. In practice the maths is messier than it sounds: Platts assessments do not perfectly capture quality, location, logistics, credit terms or shipping requirements, so adjustments are needed, and in thinner markets—components, part-processed cargoes—there may not be enough liquidity in the benchmark to make the comparison meaningful at all.
Who decides?
Measurement solves only half the problem; the other half is deciding who is accountable for what. Refinery leadership should still answer for safe operation and for the plant’s overall gross margin, and for spotting ways to debottleneck and add flexibility. But the barrel-by-barrel calls—which crude to run, how much inventory to carry, how to tune the product slate—are usually made better by people who live in the market, not by those who live on the plant.
This distinction matters because crack spreads themselves are set by forces no trader controls. When the Strait of Hormuz closes and diesel cracks spike, that is not a trading triumph; the trader’s job is to extract the most value obtainable from whatever the market hands out, whether that market is roaring, as in the past few years, or moribund, as during the pandemic. In a weak-margin world, squeezing out the last available dollar can be the difference between a marginal refinery surviving and shutting for good.
Untangling market luck from commercial skill is precisely why the majors moved decision rights for refinery optimisation off the plant and onto the trading floor, seating asset economists alongside traders so opportunities could be evaluated and acted on quickly. Rotation programmes that shuttled staff between operations and trading did double duty, building commercial fluency across the business while strengthening the ties between the two tribes. At the hub of it all sat the asset trader, broker between refinery commercial teams, economists, shipping specialists, analysts and the market traders proper—less a rainmaker than a switchboard, making sure information moved and decisions followed.
Beyond the fence line
The majors did not stop at the refinery gate. They pushed trading discipline into wholesale and retail too, on the theory that a barrel sold for volume’s sake is not the same as one sold for profit’s. That requires wholesale teams, often incentivised purely on volume, to start talking to traders—and to stop handing away value through slack contract terms on tolerances, credit and loading windows, the very terms that sharp-eyed buyers had long been happy to exploit at the refiners’ expense.
The moral, if there is one, is unglamorous: talented traders are necessary but not sufficient. What separates the refiners quietly making money from those quietly losing it is accountability that is actually clear, measurement that is actually rigorous, and a culture willing to reward the traders who create value—not merely the ones who happen to be at the desk when the market does the work for them.