Guyana Has Nearly Paid Off Exxon. Now Comes the Real Money

Energy

Key Facts

—The cost bank. Exxon’s recoverable costs reached about $55bn, with $51bn already repaid by end-2025.

—The remainder. Only about $4.5bn was left to recover, likely cleared this year.

—The split. The 2016 contract gives Guyana half the profit once costs are recovered.

—The ceiling. Up to 75% of revenue can go to costs each period under the deal.

—The flow. Stabroek generated roughly $12.3bn in revenue in the first half of 2026.

—The risk. Without ring-fencing, new projects could reset the cost meter and delay the windfall.

Guyana is about to cross the line where its Guyana oil profits stop mostly repaying Exxon and start flowing to the country itself, unless an accounting choice quietly pushes that day further away.

For most of Guyana’s short oil history, the bulk of the money has gone to paying back ExxonMobil and its partners for what they spent building the fields. That phase is almost over.

By the company’s own account, Guyana has nearly cleared the costs of the seven projects approved so far. Crossing that threshold should unlock a far larger share of the revenue for the state.

For a reader in London or Munich, this is the moment that decides whether the boom enriches a nation of under a million people, or whether the windfall keeps slipping over the horizon.

How the Guyana oil profits are supposed to work

The rules sit in a contract signed in 2016. It is a production-sharing agreement, which means the oil revenue is split according to a formula rather than a simple royalty.

Each period, up to three-quarters of the revenue can be set aside to repay the companies’ costs. Whatever profit is left after that is then divided equally between Guyana and the Exxon-led group.

The catch is the order of operations. Until the accumulated costs, known as the cost bank, are paid off, most of the money flows back to the operators rather than to the treasury.

That is why the size of the cost bank matters so much. It is the meter that decides when Guyana stops being a junior partner in its own oil and starts taking its full half.

The meter is almost cleared

The numbers suggest the turning point is near. At a press conference this month, an Exxon executive said the cost bank had reached more than US$55 billion by the end of 2025, of which about US$51 billion had already been recovered.

That leaves only around US$4.5 billion still to be repaid. The executive added that higher oil prices were drawing down the balance faster, so it could be cleared, in his words, likely this year.

The cash flow dwarfs that remainder. According to an analysis by the newspaper Kaieteur News, at around US$80 a barrel and roughly 900,000 barrels a day, the field generated about US$12.3 billion in revenue in the first half of 2026 alone.

Run that through the formula and the gap is stark. With up to three-quarters of revenue available for costs, more than US$9 billion could have gone to cost recovery in that half-year, far more than the US$4.5 billion still outstanding.

Why the windfall could still be delayed

If the maths is that clear, why is Guyana not already collecting its full share? The answer lies in how new projects are accounted for, and in a missing safeguard called ring-fencing.

Ring-fencing would keep each project’s costs and revenues separate. Without it, the spending on brand-new developments can be lumped in with the producing fields, refilling the cost bank just as it empties.

This is not hypothetical. Exxon has applied for an eighth and ninth project, and fresh multibillion-dollar build costs could be recovered from the cash the existing fields are now throwing off.

The effect would be to keep deferring the day Guyana takes its full half. Each new approval without a ring-fence pushes the country’s true payday further into the future.

The contract Guyana cannot easily rewrite

The frustration is sharpened by the deal’s history. The 2016 agreement has long been criticised at home as too generous, with a modest royalty and no ring-fencing clause built in.

Rewriting it is hard. The government has signalled it wants tougher terms on future blocks, but the existing contract governs the projects that matter most today, and the operators have little reason to reopen it.

So the leverage sits in the approvals. Whether Guyana attaches a ring-fencing condition to the next project is the clearest test of how much of the windfall it intends to keep.

What it means for investors

For investors, the cost-bank story is a window into the real economics of the world’s hottest oil play. The break-even is famously low, near US$30 a barrel, so the cash being generated is enormous.

The question is how that cash is divided over time. A clearing cost bank means a step-change in government revenue, which feeds the sovereign wealth fund and the spending that follows.

It also shapes the political climate the companies operate in. The closer Guyana gets to its promised half, the less friction over the deal; the longer it is deferred, the louder the calls to renegotiate.

The wider lesson is that in production-sharing deals, the headline split is only half the story. The accounting around costs decides who really banks the money, and in Guyana that accounting is about to be tested in full view.

Frequently Asked Questions

When do Guyana oil profits rise sharply?

Once the cost bank is fully repaid, a much larger share of revenue becomes profit to be split. Exxon says only about US$4.5 billion remained at end-2025 and could clear this year, which would lift Guyana’s take toward its full half.

What is ring-fencing and why does it matter?

Ring-fencing keeps each project’s costs separate, so a producing field’s revenue cannot be used to repay a new project’s build costs. Its absence in Guyana’s contract means new developments can refill the cost bank and delay the country’s full profit share.

How much oil revenue is at stake?

By one analysis, the Stabroek block generated about US$12.3 billion in revenue in the first half of 2026, at roughly 900,000 barrels a day. With output heading toward 1.7 million barrels a day by 2030, the sums only grow.

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