South Norway Power Faces EUR 200/MWh Q4 Risk as Dry Weather Strains Hydro Supply
NO2 day-ahead prices were at €158.28/MWh in late August, with Montel analysis flagging cold, dry autumn conditions as the trigger for a further sharp rise.
South Norway's NO2 day-ahead price reached €158.28/MWh in Thursday's (2026-08-20) session, as Montel reported that chief analyst Sigbjorn Seland sees prices potentially exceeding EUR 200/MWh in the fourth quarter if cold, dry weather compounds an existing deficit in hydropower supply.5
The EUR 200/MWh level would represent a rise of roughly 26% from the August 20 price. Hydropower generates the bulk of Norway's electricity, leaving the market with little thermal generation to absorb a supply shortfall. When reservoirs are low and inflows weak, there is no gas-fired backstop to cap prices in the way a thermally-heavy grid would provide.5,2
Nordic hydropower reserves stood 26 TWh below seasonal norms as of May 2026, with Montel EQ data showing weather projections at that time pointing to drier-than-normal conditions over the following 14 days. Seland's August warning implies that summer inflows have not materially closed the gap.2,5
The Q4 scenario requires cold temperatures and sustained dryness simultaneously. Cold weather alone raises demand without stressing supply. Dry weather alone pressures reservoirs but may not produce a sharp price move without the demand surge driving it. The combination drives the EUR 200/MWh forecast.5
Price spikes in Norwegian bidding zones are not new ground in 2026. Day-ahead prices in the NO3 central bidding zone hit a three-year high on Thursday (2026-05-21), prompting one analyst quoted by Montel to describe the move as "extremely problematic." The analyst linked the spike to how cross-border interconnector capacity is allocated in the Nordic day-ahead market — a mechanism that can amplify rather than dampen price dislocations when supply is tight.1
Interconnector flows cut both ways. The cables linking Norway to Britain, Germany and the Netherlands can pull imports northward when Norwegian prices are high, partly offsetting hydro shortfalls. But physical capacity is finite, and a broad European cold period would lift demand across all interconnected markets at once, limiting how much relief that flow can provide.1,2
Some analysts argue the upside case is overstated. A sharp increase in European renewable output — wind and solar both expanding — could generate enough surplus power to flow into Norway and soften the hydro deficit, analysts told Montel. That argument holds in a mild, windy autumn. It weakens if cold temperatures suppress wind generation across northern Europe at the same time.2
Statkraft announced plans to invest Nkr80bn, around €8.5bn, in Norwegian hydropower over the next 10 years, Montel reported. The scale reflects how the sector views the depth of the supply problem. None of that capacity helps in October or November.3
Norway's energy ministry had not yet decided on the price level for its fixed electricity price scheme for 2027 as of Wednesday (2026-08-12), Montel reported, despite wholesale prices rising sharply through the year. The scheme is linked to wholesale prices, meaning the ministry's delayed decision leaves industrial and household buyers without a fixed-rate reference as the market approaches its most expensive quarter.4
Autumn precipitation across the Nordic watershed will be the clearest early signal. Wet conditions over the next six to eight weeks could rebuild reservoir buffers and take EUR 200/MWh off the table. Dry weather into October, coinciding with the first sustained cold of the season, would bring it firmly back into view, with European interconnector imports the primary available buffer in a market with limited alternatives.5,2