Norway Power Subsidies Near EUR 10 Billion as AI Demand Strains Nordic Capacity
Five years of Norwegian electricity support payments approach NOK 100 billion, while AI-driven data centre demand adds structural pressure to European power balances.
Goldman Sachs Research projects global data centre electricity consumption will rise roughly 50% by 2027 compared to 2023 levels, with a potential surge of up to 165% by decade's end.6 That demand is already converting into large capital commitments: Bitzero, a computing infrastructure company, has secured a 15-year, $2.6 billion AI power lease with OneQode, its largest single contracted block, with CBRE marketing a separate Finland site to hyperscalers.5
The scale of those commitments puts Norway's power position in sharper relief. The country has spent NOK 86.7 billion (EUR 8 billion) subsidising domestic electricity consumption since launching a household support scheme in December 2021, a Montel investigation found.3 Payments are on course to exceed NOK 100 billion by the end of 2026, making the scheme one of the largest sustained fiscal commitments in recent Norwegian energy policy.
Norway's day-ahead power price in the southern NO2 zone stood at $119.31 on Tuesday (2026-06-23), sustaining the subsidy obligation at levels that have persisted well above pre-crisis norms. The country's hydro-dominated grid means prices track reservoir conditions closely, but European gas market tightness has kept the floor elevated since 2021.
The political constraints are explicit. Finance minister Jens Stoltenberg told Montel that the fixed retail price structure has insulated the market from broader regulatory intervention by preventing consumer discontent from building.4 That arrangement, as he acknowledged, means the government has absorbed an open-ended payment obligation calibrated to wholesale prices it does not control directly.
On the supply side, Oslo has moved to shore up European gas export volumes. The Norwegian energy ministry in May (2026-05-19) approved development plans for three North Sea gas fields — Albuskjell, Vest Ekofisk and Tommeliten Gamma — mothballed for three decades, with first gas targeted for 2028.2 All three fields are in the southern North Sea, feeding the pipeline network supplying Continental European markets. Higher Norwegian gas export volumes support the Continental gas price signal, which feeds back into Norwegian hydro dispatch decisions when reservoir-level economics tighten.
The link between gas revenue and domestic power pricing has defined the Norwegian subsidy debate. When ICE Endex TTF front-month prices rose sharply in 2021 and 2022, Norwegian wholesale power followed hydro dispatch opportunities higher, generating windfall income for state-controlled generators while consumers absorbed equivalent costs through the retail channel.
Carbon pricing has added a further layer. EU ETS revenues reached EUR 43.2 billion in 2025, up 11% on the prior year and equivalent to 62% of all revenues raised through global carbon pricing mechanisms, the International Carbon Action Partnership reported.1 Higher carbon prices raise the cost of thermal alternatives in the European merit order, which improves the competitive position of Norwegian hydro capacity but also sustains the wholesale price floor that underpins the subsidy bill.
The private market valuation of secured power tells its own story. Bitzero holds more than 1 gigawatt of secured capacity across four sites with the $2.6 billion OneQode lease in place, yet trades at a market capitalisation of roughly $130 million.5 Comparable companies with similar or smaller power commitments trade above $8 billion, OilPrice data show — a gap that reflects both equity market pricing of power scarcity and the premium the AI infrastructure buildout is creating for committed capacity.
Whether Oslo can engineer an exit from the household support scheme before the 2028 gas field start-up creates fiscal headroom will depend on whether European gas prices ease sufficiently to bring Norwegian wholesale power back within domestic retail cost tolerance. That timing, rather than the energy ministry's supply policy, is the binding constraint.