For two years, almost every power price forecast underneath a European renewables deal carried the same quiet assumption: a wall of new liquefied natural gas was coming, it would arrive around 2027 and 2028, and it would drag gas and therefore power prices down with it. Offtakers priced it in. Developers worried about it. Credit committees stress-tested against it.
That wall just moved. Qatar’s mega-expansion, the single largest piece of new gas supply this decade, has slipped, and the back end of it now lands beyond 2030. If you are modelling a PPA floor or a merchant tail for a Romanian solar or wind asset this year, the price deck under your spreadsheet is no longer the one you were using in 2025. Here is what changed, and why it strengthens the case for being long Romanian generation specifically.
What actually happened to the wave
Qatar is the anchor of the global supply story. The country exported roughly 77 million tonnes of LNG in 2025, about a fifth of all seaborne supply, and its North Field expansion was set to lift that to 142 million tonnes a year by 2030. That single program, North Field East, South and West combined, is the most consequential supply addition in the gas market for the rest of the decade.
It is now late on two counts.
First, the engineering. Even before any geopolitics, QatarEnergy pushed the start of North Field East from the third quarter of 2026 to the fourth, with insiders flagging slippage into 2027. Mega-projects routinely slip as start-up nears.
Then the war. In March 2026, Iranian strikes on Ras Laffan, Qatar’s entire LNG complex, caused extensive damage and knocked out two liquefaction trains, around 12.8 million tonnes a year, or 17 percent of national output. Qatari exports collapsed from a steady 5.6 to 7.8 million tonnes a month to 0.47 million in March and 0.23 million in April. QatarEnergy put the revenue hit near 20 billion dollars a year until repairs are done, and analysts said the expansion itself would be delayed by more than a year as labour and materials were pulled toward repairs. The third phase, North Field West, has now formally slipped to a first cargo at the end of 2031.
Put the volumes together. The expansion was going to add 65 million tonnes a year, the gas-equivalent of roughly 90 billion cubic metres. Add the trains sitting offline, another 17 billion cubic metres of annual capacity, and the slower ramp on everything behind them, and the supply the market had pencilled in for the back half of the decade now runs well over 100 billion cubic metres a year that arrives late or not at all. Call it 120 billion cubic metres of gas that the 2027 to 2030 balance was counting on and will not see on the old timeline. A senior Uniper executive put the practical horizon plainly: the repercussions are expected to persist until at least 2030.
Why this is a power-price story, not a gas story
Here is the part that matters for anyone signing offtake. The relevant question is not what gas costs. It is what power costs, because that is what a PPA settles against and what a merchant tail earns.
In Europe, gas is the marginal fuel. For most hours, a gas plant sets the wholesale price, so the gas curve and the power curve move together. Romania is coupled into that European market, and its day-ahead prices are shaped by the same gas-marginal pricing, hydrology and cross-border flows as its neighbours. So when the gas curve shifts up and stays up, the Romanian power curve does too.
And the curve has shifted. TTF, the European benchmark, sat near 27 euros per megawatt hour at the end of 2025, spiked above 70 during the March disruption, and has settled around 40 this summer as flows partly normalise. The forward view is the real story. Goldman Sachs holds its second-half 2026 TTF call near 41 euros and its 2027 average near 30, with risks skewed to the upside and the timeline for LNG normalisation pushed back. The European Commission’s own downside scenario has European gas near 80 euros in late 2026, easing only gradually through 2027 as North American supply ramps. The clean, deflationary glut-by-2028 deck that was quietly capping PPA offers a year ago has lost its near-term anchor.
The two numbers offtakers and developers actually model
Strip a renewables investment case down and most of the argument lives in two places: the PPA price, often with a floor, and the merchant tail, the years of revenue after the contract ends when the asset sells into the open market. The Qatar delay moves both.
The merchant tail gets more valuable. A large share of a project’s net present value sits in those uncontracted years, and they are discounted against a forward power curve. Push the gas relief from 2027 and 2028 out toward 2030 and beyond, and the mid-decade section of that curve, exactly the part the tail is exposed to first, sits higher than last year’s model assumed. Tails that looked thin on a fast-glut deck look materially better on a delayed-glut deck.
The PPA floor firms up. A generator’s willingness to sign a low fixed price depends on its merchant alternative. If staying merchant now looks better for longer, the floor a developer will accept rises, and the discount a buyer can extract shrinks. The same logic cuts the other way for offtakers, and that is the point: the opportunity cost of staying unhedged, or of waiting for prices to fall, just went up, because the event that was supposed to make them fall has been pushed years down the road. For a buyer, locking a price now is a hedge against a tighter decade, not a bet against an imminent crash.
For context on where these numbers actually sit, Romanian corporate PPAs have been pricing roughly between 65 and 85 euros per megawatt hour, while day-ahead prices through early 2026 swung between about 55 and 140 euros and averaged near 110 across 2025. CfD strike prices for new solar have cleared as low as the mid 30s. That spread, between sub-40 generation costs and gas-linked market prices well above them, is the whole commercial opportunity, and a tighter gas decade widens and sustains it.
Why Romania is the right place to hold this position
The thesis is not just that European power stays firm. It is that Romania is unusually well-built to convert that into contracted and merchant value at the same time.
Start with the spread. Romanian solar and wind are among the cheapest to build in Europe, with CfD solar clearing in the mid 30s to low 40s and operating costs below 20 euros per megawatt hour, yet they sell into a market priced at the margin by expensive imported gas. Cheap generation, gas-set price. The Qatar delay does not narrow that gap. It protects it.
Then the market itself. Romania is the most liquid corporate PPA market in Southeastern Europe, with strong wind penetration, solid interconnections and a maturing toolkit. Deals are no longer vanilla. Shaped contracts, virtual PPAs, hybrid solar-plus-wind, and storage-backed structures are becoming standard, with creditworthy offtakers like OMV Petrom and a wave of automotive manufacturers signing multi-year volumes, and EBRD and IFC sitting behind the financing. The DTEK solar package with OMV Petrom and the Rezolv wind VPPA with Etem Gestamp, at 461 megawatts, show the market can already absorb large, structured offtake.
Then the volatility. Romania runs the highest daily price spread in the EU, near 168 euros per megawatt hour last year. A tighter gas market does not calm that, it amplifies it, and that is precisely the spread that standalone and co-located batteries monetise. Storage turns the same volatility that threatens unhedged solar into a revenue line.
And then the asymmetry almost no one else in the region has. Romania is about to become a net gas exporter. The Neptun Deep field in the Black Sea, with first production due in 2027, will nearly double national output and make Romania the largest gas producer in the European Union. So while the rest of the continent imports the tightness that a delayed Qatari wave creates, Romania increasingly supplies its own gas, and still earns the gas-linked power price on top. Lower exposure to the shock, full participation in the upside. That is a rare position to be writing PPAs from.
The honest counterpoint
Objectivity demands the other side. The glut is delayed, not cancelled. The United States is still building the largest LNG wave in its history, with over 90 billion cubic metres a year of new capacity sanctioned in 2025 and its global market share heading from a quarter to a third by 2030. Goldman still carries a bearish 2028 to 2029 TTF view in the high to mid teens. The higher-for-longer window is the middle of the decade, not forever, and merchant tails reaching deep into the 2030s should still be modelled against a softer curve.
Romania has its own frictions too. The electricity price cap mechanism, questioned by the European Commission, discourages some buyers from contracting at all. Romania is not yet a member of the AIB, so guarantees of origin are not freely transferable across borders, which thins the pool of corporate buyers until accession, targeted for early 2027. Grid connection and curtailment remain the single biggest execution risk, balancing costs are real, and solar cannibalisation at midday is a genuine drag on unshaped capture. None of this is fatal, but it is the reason floors, shaping and storage exist.
The disciplined read is narrow and useful. The relief everyone modelled for 2027 and 2028 is now a 2030-plus event. That lifts PPA floors and mid-decade merchant tails for contracts signed this year, and it raises the cost of waiting. It does not justify underwriting high prices into perpetuity.
Momentum Energy’s View
We think the market spent two years pricing Romanian offtake against a glut that has just been postponed, and the contracts being signed this year are the ones that benefit.
If you are an offtaker, the calculus has shifted in a specific way. The downside scenario you were implicitly waiting for, a 2027 or 2028 price collapse led by Qatari and US supply, has moved out by years, while the upside risk to gas has grown. A PPA at today’s Romanian levels is no longer a bet that prices stay high. It is insurance against a decade that now looks tighter than the consensus deck assumed twelve months ago, bought from the lowest-cost generation base in the region.
If you are a developer, the delay quietly re-rates your asset. Hold firmer on floors, because your merchant alternative is stronger than last year’s model said. Value the merchant tail against the new mid-decade curve, not the old fast-glut one. Pair generation with storage to harvest the spreads a tight gas market widens. And remember the structural backstop that makes Romania different: a CfD floor if you want certainty, a liquid PPA market if you want bankability, and a domestic gas base that insulates the country from the very shock lifting everyone’s power prices.
The wave is still coming. It is just coming later, and Romania is the best-positioned market in the region to be selling power into the years before it arrives. For every PPA signed here this year, that delay is not a footnote. It is the floor under the price.
