Negative Electricity Prices in Austria: When the Exchange Pays – What It Means for Solar Owners

At 1.30pm on 1 May 2026, the day-ahead price for electricity in Austria fell to minus €498.65 per megawatt-hour. Anyone selling power into the grid at the exchange price during that quarter-hour would, on paper, have had to pay almost 50 cents per kilowatt-hour just to have someone take it off their hands. That day the price stayed below zero without a break from 9.30am to 5.15pm (day-ahead prices for Austria, German Federal Network Agency/SMARD). The cause was not a malfunction but an entirely foreseeable combination: a public holiday, little industry on the grid, and plenty of solar power. Photovoltaics were producing flat out, demand was in the doldrums, and the market could only find equilibrium through extreme negative prices.

It was not entirely new: on 2 July 2023 the Austrian day-ahead price had already reached minus €500 per megawatt-hour in the hour from 2pm. What is new is how often the price now drops below zero — and that has very concrete consequences for households with solar panels.

Why a price can fall below zero at all

Negative electricity prices seem absurd at first glance, but they follow a simple logic. Electricity still cannot be stored at scale except to a limited degree; generation and consumption must balance every single second. When photovoltaics produce massively on a sunny early-summer midday while run-of-river hydropower plants on the Danube and the Inn keep running and demand is depressed by a public holiday, there is simply more electricity than anyone needs. Some power plants nonetheless cannot or will not switch off — because ramping down and back up would cost more than a few hours of negative prices, or because subsidy regimes made feeding in attractive even when the market was long since saturated. Then producers pay to get rid of their electricity.

How sharply the number of these hours has risen is shown by the day-ahead prices for the Austrian bidding zone, which Germany's Federal Network Agency publishes on its SMARD platform. We counted them:

Source: day-ahead prices for the Austrian bidding zone, published by the Federal Network Agency on SMARD.de; our own count, as of 18 October 2026. Since 1 October 2025 the day-ahead price has been set per quarter-hour; from then on, four negative quarter-hours count as one hour.

The trend is clear, but not a straight line: by mid-October, 2026 was still below the whole of the previous year, even though May brought 26 per cent more sunshine hours than the 1991–2020 climate average and was the fifth-sunniest May on record, according to GeoSphere Austria, the national weather service (GeoSphere Austria, 1 June 2026). How often the price falls below zero depends not only on the sun, but also on demand, hydropower and export capacity.

For households without their own installation, all this is at first a footnote with at most indirect effects — for instance on the question of how electricity prices will develop overall in 2026. For owners of a solar installation, it is considerably more than that.

The OeMAG tariff is stuck at the legal floor

Those who feel the price slump most directly are the households selling their surplus power to OeMAG, the clearing and settlement agency for green electricity. Its market price has been set monthly and retroactively since 2024. The starting point is the volume-weighted exchange price of the month; it is capped below at 60 per cent and above at 100 per cent of the quarterly market price that E-Control sets under Section 41 of the Green Electricity Act, in each case minus the cost of balancing energy. For photovoltaics, that deduction is 0.408 cents per kilowatt-hour in 2026 (OeMAG, market price).

From April to July 2026 the market price paid out sat exactly on that floor: 6.772 cents per kilowatt-hour from April to June, 6.146 cents in July. Only in August and September did it rise again, to 8.997 and 10.168 cents (OeMAG). Without the statutory floor, the tariff would have fallen even further in the sunny months, because exchange prices are at their lowest precisely when PV systems deliver the most — at midday, in the sunshine. The more solar power pushes into the grid at the same time, the less each individual kilowatt-hour is worth.

The subsidy landscape, too, now reckons with negative prices. Anyone receiving a market premium under the Renewables Expansion Act (EAG) gets no premium for the whole period under Section 15 of that law as soon as the day-ahead price is negative for at least six consecutive hours (EAG Section 15). And the new Electricity Industry Act (ElWG), which parliament passed on 11 December 2025 (Austrian Economic Chamber, Lower Austria), tightens the screw further: for new or expanded PV systems, the grid operator may cap feed-in at 70 per cent of module peak output, which for a 10 kWp system means 7 kilowatts (economy ministry BMWET, peak capping). From 1 January 2027 producers feeding into the grid also pay a supply infrastructure contribution of at most 0.05 cents per kilowatt-hour fed in; systems up to and including 20 kilowatts of grid-effective capacity are exempt (ElWG Section 75a). How the investment grant for new systems works in 2026, and what is planned from 2027, is in our guide to solar PV grants in 2026.

The market's message is unambiguous: electricity that everyone produces at the same time is worth little. The reward goes to those who deliver it — or consume it — when it is actually needed.

Batteries move from luxury to logic

What does this mean in practice? First of all: the old rule of thumb — feed in as much as possible — has had its day. Anyone planning or running a system today almost always does better by keeping as much solar power as possible in their own home. Every self-consumed kilowatt-hour replaces grid electricity: an average household using 3,500 kilowatt-hours pays its regional incumbent supplier between €891 and €1,218 a year, grid charges, taxes and levies included, according to E-Control (E-Control, price monitor of 1 October 2026) — roughly 25 to 35 cents per kilowatt-hour on average. The exported one earned 6.8 cents or less at OeMAG over the summer, and in dynamic marketing models sometimes nothing at all at midday.

That shifts the economics in favour of battery storage. A battery moves the midday surplus into the evening — out of the hours of zero and negative prices and into those when electricity is worth something again. How the sums work out in concrete terms, which sizes make sense and where the limits lie is something we have crunched in a separate analysis: Is a home solar battery worth it in 2026? In short: the less an exported kilowatt-hour earns, the more each one kept in the house counts — whether a battery pays off then depends above all on its price and on your own evening consumption.

Those without a battery can still do plenty to adapt to the new price landscape:

• Deliberately shift big consumers — the hot-water boiler, washing machine, dishwasher or the EV's wallbox — into the midday hours, whether manually or via simple timers and energy management systems
• When planning a system, consider an east-west orientation, which spreads generation more evenly across the day instead of bunching it into the midday peak
• Compare feed-in contracts: alongside OeMAG, many regional utilities and independent buyers offer fixed or market-linked tariffs whose conditions are currently changing fast

Flexible tariffs: the same curve, with the sign flipped

What hurts those feeding in can delight those consuming. Dynamic electricity tariffs pass on the exchange price quarter-hour by quarter-hour or hour by hour, usually with a fixed or percentage markup, and so turn the midday dips into a savings window. Since 1 April 2026, suppliers serving more than 25,000 metering points have been required to offer such contracts (ElWG Section 22). The prerequisite is a smart meter that transmits quarter-hourly readings; anyone on a dynamic contract cannot object to that metering (ElWG Section 54). How the meters are being switched over is explained in our article on smart meters in Austria.

One illusion, however, should be buried straight away: even in negative hours, you virtually never get money for nothing. Grid charges and levies are due on every kilowatt-hour even when the energy price is below zero; what remains is usually a much lower, but still positive price. The model is attractive above all for households that can shift substantial loads, first and foremost EV drivers with a controllable wallbox or owners of heat pumps with a buffer tank.

And in the longer term? Negative prices are not an industrial accident but a transitional stage. They show that the expansion of generation has outrun the transformation of the rest of the system — grids, storage and flexible demand are lagging behind. Solar power can already be shared regionally through energy communities, at prices the members agree among themselves. The more electricity is consumed locally instead of crowding onto the exchange en masse at midday, the less often the market will have to seek forced relief through negative prices. Until then, the new ground rule of this summer applies to PV households: it is not the kilowatt-hour produced that counts, but the one delivered at the right time.