South Norway Power Prices May Rise 7% When Offline Cable Returns to Service
Analysts say restoring the offline cable would reopen export flows to a tight European market, pulling south Norwegian spot prices higher.
Analysts told Montel on 2026-08-31 that south Norway's power prices may climb around 7% once an offline export cable is restored to service, linking regional spot levels directly to the availability of the country's cross-border connections to continental Europe.5
With the cable offline, Norwegian generation has no export route, and any domestic surplus weighs on south Norwegian prices. Reconnection reopens the flow toward European markets currently priced well above Norwegian levels. German front-month power settled at €149.68/MWh at 2026-09-04's close, providing the kind of price pull that makes export capacity valuable the moment it is live.5,2
Norway's structural export position makes the cable's status consequential. The country generated around 162 TWh of electricity in 2025 while consuming 139.2 TWh, according to Statnett data, and exported approximately 34 TWh against 11.5 TWh of imports. That surplus flows almost entirely through undersea cables to Germany, the Netherlands, Denmark and Britain. When one link is down, surplus builds at home.4
The hydro backdrop tightens the picture further. Nordic hydropower reserves currently sit 26 TWh below seasonal norms, with the 14-day weather outlook remaining drier than normal, Montel EQ data show. A supply-constrained system absorbs cable disruptions less easily; if reservoirs continue drawing down before autumn restores rainfall, any price move on cable reconnection could exceed analysts' base-case 7%.1
Some analysts have argued that surging EU renewables output could partially offset the Nordic hydro shortfall through increased imports into the region, Montel reported. If that materialises, it would narrow the price differential between south Norway and continental markets, reducing the immediate incentive to fill cable capacity with exports once reconnection occurs.1
The wider European market offers little comfort to buyers hoping for relief. Drought-driven constraints in southeast Europe have led analysts to forecast September average prices of EUR 170-180/MWh for that region — up roughly 60% year-on-year — Montel reported on 2026-08-06. Southeast European buyers competing for the same constrained hydro generation base that feeds Norwegian reservoirs are already operating at extreme price levels.2
ICE Endex TTF front-month gas settled at €71.95/MWh at 2026-09-04's close. Gas-fired generation at that input cost remains expensive across central Europe, sustaining demand for Norwegian hydro exports whenever the cable capacity exists to deliver them — which, currently, it does not in full.1
Norway's domestic policy adds a layer of uncertainty. The energy ministry had yet to decide, as of 2026-08-12, on a price level for its 2027 fixed-price electricity scheme, Montel reported, despite wholesale prices having risen sharply this year. A NOK 400/MWh level was under discussion. Any significant upward repricing in south Norway following cable restoration would directly affect the government's subsidy exposure under that scheme.3
The 7% figure is an analyst projection built on specific assumptions about when the cable returns and where continental demand holds. Nordic reservoirs remain 26 TWh below normal with a dry 14-day outlook, and southeast European prices are already running near EUR 170-180/MWh. If the hydro deficit deepens before autumn precipitation arrives, the actual price shift on cable reconnection could prove larger than the 2026-08-31 forecast implied.1,5,2