Extreme heat accelerated disappearance of Triglav glacier from mountain revered as a symbol of Slovenian identity
The final ice patch has vanished from Slovenia’s Triglav glacier, the latest Alpine casualty of Europe’s scorching summer.
The once mighty ice mass lost 93% of its surface area between 1983 and 2003, shrinking to cover less than a hectare of overheated rock, but went on to surprise researchers who feared its imminent demise, clinging on to the mountain for two more decades.
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© Photograph: Anton Melik Geographical Institute
© Photograph: Anton Melik Geographical Institute
© Photograph: Anton Melik Geographical Institute
© Susan Montoya Bryan/Associated Press
Extreme heat accelerated disappearance of Triglav glacier from mountain revered as a symbol of Slovenian identity
The final ice patch has vanished from Slovenia’s Triglav glacier, the latest Alpine casualty of Europe’s scorching summer.
The once mighty ice mass lost 93% of its surface area between 1983 and 2003, shrinking to cover less than a hectare of overheated rock, but went on to surprise researchers who feared its imminent demise, clinging on to the mountain for two more decades.
Continue reading...
© Photograph: Anton Melik Geographical Institute
© Photograph: Anton Melik Geographical Institute
© Photograph: Anton Melik Geographical Institute
President has taken an axe to National Oceanic and Atmospheric Administration, stalling climate research on and response to extreme weather events
Sweeping cuts to the premier US climate agency under Donald Trump have severely hampered the country’s capacity to forecast, research and respond to extreme weather events, former government officials and scientists have warned, as the US faces a cascade of hazards fueled by a potentially historic El Niño this winter.
From the start of his second term, the president has taken aim at the National Oceanic and Atmospheric Administration (Noaa), slashing staff levels, canceling contracts and grants, and shutting down databases and research laboratories. The agency that has long been considered a global crown jewel in climate science and forecasting, has lost roughly 20% of its staff since January 2025.
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© Photograph: Mario Tama/Getty Images
© Photograph: Mario Tama/Getty Images
© Photograph: Mario Tama/Getty Images
The figures reveal a persistent difficulty for European energy policy: although the continent has an increasingly interconnected electricity market, businesses and consumers remain exposed to very different underlying wholesale costs depending on location.
According to European day-ahead electricity market data, Sweden’s SE2 bidding zone recorded an average of €6.23 per megawatt-hour, while Finland stood at approximately €6.65. Romania reached €255.20, roughly 41 times northern Sweden’s price. Bulgaria registered approximately €254, Hungary €241 and Greece €225. Germany recorded approximately €155, Belgium €160 and France €162.
These are wholesale prices for delivery on 27 October, not final bills for households or businesses. Their differences nevertheless raise questions about how effectively Europe’s electricity networks distribute power from areas of lower-cost generation to those facing greater costs.
European electricity trading is organised through interconnected national and regional markets. Cross-border capacity allows relatively inexpensive power to reach regions where demand is greater or local generation is more expensive.
When transmission capacity is adequate, neighbouring prices can converge. Physical networks, however, have limits. Congested interconnectors can prevent additional imports even when large price differences exist.
Other influences include availability of power stations, renewable output, fuel prices, consumption and system stability. Regions with substantial hydropower, nuclear generation or strong renewable production may experience comparatively low prices. Markets relying on gas-fired generation can be more expensive when gas plants are needed to satisfy the final increment of demand.
The result is a market responding to common European conditions but still shaped by local generation and transmission constraints.
The European Union Agency for the Cooperation of Energy Regulators, ACER, has repeatedly examined the causes of regional price divergence. In its 2026 assessment of cross-zonal electricity trade, the agency considered unusually high prices and limited access to lower-cost power in southeastern Europe.
Constraints include available cross-border capacity and shortages of flexible generation able to respond to changing renewable output, especially in the evening. Countries including Greece, Bulgaria, Romania, Hungary, Croatia and Slovenia have encountered substantial regional differences.
Those findings do not prove the cause of each price movement on 27 October. They do, however, explain why disparities can persist despite common market rules. ACER has advocated improved coordination among transmission operators, more effective use of existing networks and additional flexibility through storage and demand management.
Energy-intensive industries, including steel, chemicals and fertiliser production, are particularly sensitive to electricity costs. Where contracts are exposed to wholesale markets, sustained regional price differences can influence output and investment decisions.
The relationship between wholesale prices and bills is not immediate. Firms may hedge prices, use long-term contracts or produce their own power. Network charges, taxes and government support also affect the amount paid. Still, persistent market differences can shape industrial competitiveness.
As EU Today reported, EU energy ministers are due to examine proposed changes to electricity network charges and market administration on 29 October. Network tariffs are distinct from wholesale prices, but both affect total electricity costs.
According to ACER’s energy-market monitoring, renewable sources represented around half of EU electricity generation in 2025. Solar energy can reduce prices during the day, but output falls sharply towards evening, sometimes requiring more expensive power stations to increase generation.
This increases the value of storage, flexible production, responsive demand and international connections that can balance surpluses and shortages between regions. Yet major transmission lines can take years to complete owing to planning, permitting, investment and construction requirements.
The priority is therefore not simply to install more renewable capacity. Europe’s grids and supporting technologies must be capable of moving and using that output efficiently.
A single day’s wholesale prices should not be mistaken for long-term average electricity costs or a permanent competitive advantage. Nevertheless, the persistence of regional disparities documented by regulators shows the problem extends beyond isolated daily volatility.
For EU institutions, the question is whether further market integration can make energy more affordable while preserving incentives to invest in generation and transmission. National governments must balance security of supply, infrastructure financing and industrial competitiveness.
Electricity trading across Europe is increasingly integrated. The physical systems supplying it remain considerably less uniform. Until those constraints are addressed, the price of power will continue to reflect geography as well as the underlying cost of energy.
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