European winter power hits 20% premium over 2027 on gas and hydro crunch

Winter baseload contracts in Europe have priced in a 20%-plus premium over 2027 equivalents, a backwardation not seen since the height of the post-invasion gas crisis three years ago. German winter baseload sits above €110/MWh against a 2027 year-ahead of roughly €92/MWh; Italy is worse at above €120/MWh versus approximately €104/MWh for 2027, according to LSEG data.

Two converging supply problems are driving the move. First, Iranian restrictions on liquefied natural gas (LNG) shipments through the Strait of Hormuz, imposed in retaliation for US and Israeli military action since late February, have removed roughly 20% of global LNG supply and intensified European competition with Asia for flexible cargoes. Second, an abnormally dry winter has left the hydrological balance for continental Europe and the Nordics at its lowest level in a decade, curtailing the flexible reservoir capacity that typically backstops the grid when gas prices rise. Equinor has publicly flagged that a severe European gas shortage is possible if Hormuz disruption persists for another one to three months.

What this means for UK commercial energy buyers

UK day-ahead baseload over the past year offers the reference point against which buyers should read European winter premiums and their likely spillover into Season-1 forwards.

UK power pricing does not track European curves directly, but the two markets are linked through interconnector flows and shared LNG competition. A sustained European winter premium tightens the supply picture that National Grid ESO must manage across interconnected capacity, and it places upward pressure on UK Season-1 (winter 2025-26) forward contracts. Buyers approaching winter renewals in the next 60 to 90 days are looking at a market where the short end of the curve reflects genuine supply anxiety rather than speculative positioning.

The key variables to hold in mind:

• European gas storage at 38.2% of capacity, against a seasonal norm of roughly 52% and an EU target of 90% by 1 November 2025
• Injection rates would need to nearly double over the remaining roughly 160 days to reach that target
• Dutch TTF (Title Transfer Facility) day-ahead gas is currently around €46/MWh, with analysts at BNP Paribas noting it does not yet carry a winter risk premium
• Nordic and Alpine hydro reservoir levels at a ten-year low, removing a key grid stabiliser
• Germany and Italy, the two most gas-dependent European power markets, are most directly exposed and their prices set the regional reference
• An El Niño forecast adds further uncertainty: a milder winter would ease demand, but a hotter, drier summer would further constrain hydro output

For UK buyers on fixed contracts already in place, the immediate exposure is limited. For those with renewals landing in Q3 or Q4 2025, the forward curve is pricing in risk that has not yet fully materialised in spot gas. BNP Paribas analyst Jason Ying has noted that if Hormuz remains blocked through summer, tight storage persists, and the hydro deficit continues, European power prices have further to move.

Watch the weekly Gas Infrastructure Europe storage release each Thursday for signs that injection rates are accelerating, and track TTF front-winter versus year-ahead spread as the most direct indicator of whether traders believe the supply gap is closing.