Uruguay is retiring the PPA that built its own grid
Uruguay draws close to 99% of its electricity from renewables and has run as a net exporter of power since 2024, with exports reaching 130 GWh in May 2026 alone, more than triple April's 39 GWh, per export data reported by Ámbito. UTE, the state utility whose fixed-price wind and solar contracts built that grid, is telling the market its next 500 MW of solar will not be bought the same way.
That is an odd thing for a success story to do. Twenty-year terms, fixed prices, take-or-pay: that template is what most of the region is still trying to copy. Peru's last renewable auction, in 2024, cleared 20-year solar contracts at $27.36/MWh, per Osinergmin's own results, on the logic that a fixed contract is what lets a lender size debt against a forecast instead of a hope. Uruguay wrote that playbook a decade earlier. It is now the first market in the region stepping back from it, and the cause traces straight to cost.
What the old contracts actually cost
Pées Boz, a former UTE director, has put a figure on it: close to US$5 billion in surplus and overpricing costs tied to existing private contracts, from his own estimate that UTE pays above $120/MWh for solar and above $90/MWh for wind signed years ago, against roughly $40 and $38 a megawatt-hour the same technologies could clear today. That is a critic's number, not an audited one, and UTE has not published a matching figure of its own. Nobody inside Uruguay's power sector seriously disputes the direction. The contracts that built the grid now cost more than the grid needs, and ratepayers carry the gap.
Oversupply did what the contracts never priced
A twenty-year fixed PPA prices a world of scarcity, where the buyer needs every megawatt-hour on offer and pays a premium for certainty of supply. Uruguay built past that world. Once renewables cleared close to 99% of generation, UTE stopped being short of energy and started being short of places to put it, which is why exports have become the release valve. Selling the surplus abroad recovers some value for the system. It does nothing to the fixed price UTE still owes generators for power the grid did not need that hour.
A contract built for scarcity does not get cheaper once the scarcity is gone. Someone still pays the difference, and in Uruguay that someone is the ratepayer.
What UTE is actually signaling
For its next 500 MW of solar, part of a build-out UTE is targeting by 2030 and reserving for private developers, per Energía Estratégica's reporting, a tender is expected toward the end of 2026 under a structure UTE's own president says will not be a classic PPA. The same reporting has him arguing a depressed spot price will not finance the next entrant either, those projects simply would not get built at that price. Read plainly, that is UTE conceding the fixed PPA is not coming back in its old form while admitting pure merchant exposure does not pencil either. What sits between those two positions, UTE has not said, and that gap is where a lender's diligence budget will go once the tender terms land.
What we think follows
Whatever UTE calls the new instrument, it has to do the one thing the old PPA did that bare merchant exposure cannot: let a lender size amortizing debt against something steadier than a spot price UTE itself has disowned. A revenue floor, a capacity-style payment, a shorter tenor with refinancing risk priced in up front. Something has to replace twenty years of certainty, or the next 500 MW gets built on balance sheet by the few sponsors who can carry merchant risk alone, or it does not get built on schedule.
There is a reasonable case that this is just a market maturing past the point where it needs a training-wheels contract. Fair enough. It is also true that every lender who financed Uruguay's first wave did so because the PPA structure, not the resource, was the bankable part of the deal. Removing it does not remove the resource risk. It moves that risk onto whoever signs the next tender before knowing what it pays.
Our own pipeline sits in Peru, not Uruguay, carrying the opposite problem: an auction system that has not run a new round since 2024, rather than one voluntarily stepping back from its own contracts. We are building our 870+ MW platform toward a 2 GW+ target across LATAM by 2030 assuming fixed, contracted structures stay the bankable default where the market still offers them. That is exactly why Uruguay's retreat is worth watching from here.
The open question
UTE has not published what the replacement structure looks like, and the tender is still months out. We do not know whether it lands closer to a capacity contract, a contract-for-differences around a floor price, or something the region has not tried yet. Peru's own next auction remains unscheduled for different reasons, but both markets are converging on the same question from opposite directions: what a bankable renewable contract looks like once the twenty-year fixed PPA stops being the obvious answer. Uruguay will answer it first. Whichever way it goes, the region's lenders will be pricing off whatever UTE puts on paper.
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