Finland’s energy infrastructure is shaped by a cold climate, long internal distances, and a position at the edge of the European energy system. The country has responded with a reliable electricity network, strong cross-border links, extensive district heating, and fuel supply arrangements designed for severe winters. Its infrastructure has also changed quickly since 2022, when Russian electricity and pipeline gas disappeared from the Finnish market.
The system is now more self-sufficient but remains closely tied to neighboring countries. Nuclear power, wind, hydropower, electricity imports, LNG, gas pipelines, and urban heat networks each support security of supply. The next phase will require more transmission capacity as electricity-intensive industry, data centers, hydrogen projects, electric heating, and transport increase demand.
A Northern Power Grid Carrying a New Generation Mix
Fingrid operates Finland’s main transmission grid, including the highest-voltage lines and substations that connect large power plants, industrial consumers, regional networks, and international interconnectors. The network crosses a sparsely populated country, linking demand centers in southern Finland with nuclear plants on the western and southern coasts, northern hydropower, and expanding wind generation in western and northern regions.
Olkiluoto 3 entered regular operation in 2023 and added a large block of dependable nuclear output. Wind generation also continued to grow, overtaking hydropower as Finland’s second-largest electricity source in 2024. By 2025, almost all domestic electricity production came from carbon-neutral sources.
These changes reduced dependence on imported electricity but did not remove the value of cross-border trade. Wind output can change quickly, nuclear units require maintenance, and winter demand can reach exceptional levels. Finland therefore benefits from the Nordic market, where electricity moves according to availability and price.
The Aurora Line between Finland and northern Sweden entered service in November 2025. It increased transmission capacity in both directions and strengthened access to northern Swedish generation. Finland also has submarine connections with central Sweden, two Estlink cables with Estonia, and a smaller link with Norway. Together, these connections support balancing, trade, and recovery from domestic outages.
Energy Security Changed Direction After 2022
Electricity imports from Russia ended in 2022, and Russian pipeline gas stopped the same year. Finland had to replace an established supply route without interrupting service to industry, power plants, or heating customers.
Natural gas has a smaller role than in many European countries, but it remains important for industry, combined heat and power, and flexible electricity production. Supply now depends on liquefied natural gas and access to the wider Baltic market. LNG can enter through terminals at Inkoo and Hamina, or indirectly through Lithuania’s Klaipėda terminal and the regional pipeline system.
Balticconnector, the offshore pipeline between Finland and Estonia, links Finland with the Baltic states and, through the Gas Interconnection Poland–Lithuania, Central Europe. It returned to service in April 2024 after damage in October 2023. Its restoration mattered because Finnish gas security now depends on several routes rather than one dominant supplier.
The network may also serve a different long-term role. Gas use for heating is declining as electric boilers and heat pumps expand, but gas can still provide balancing power during cold, windless periods. Biomethane, synthetic methane, and hydrogen may eventually use parts of the existing system or require dedicated pipelines. The challenge is preserving flexibility without overinvesting in assets that may carry less fossil gas.
District Heating Links Cities to the Wider Energy System
District heating is central to Finland’s infrastructure because heating demand is large and seasonal. In many cities, heat is produced centrally and distributed through underground hot-water networks to apartment buildings, offices, public facilities, and commercial properties. Cities can therefore change production technologies at major plants without replacing equipment in every building.
District heating historically relied on combined heat and power plants using coal, gas, peat, or biomass. Coal is being phased out, peat has declined, and heat companies are adding electric boilers, industrial heat pumps, thermal storage, waste-heat recovery, and cleaner fuels. Data centers, wastewater plants, and industrial sites can become heat suppliers.
This creates a closer relationship between heating and electricity. Electric boilers can absorb power when wind output is strong and prices are low, while heat storage can delay consumption. During tight electricity conditions, other heat sources can reduce pressure on the grid. District heating is becoming a flexibility resource rather than only a delivery system.
The transition is especially important in Helsinki, Espoo, Tampere, Turku, and other urban areas where large networks must decarbonize without weakening winter reliability. Each city has a different mix of plants, heat pumps, storage, and local heat sources.
Grid Investment Is Following Industry North and West
Finland’s clean electricity is attracting proposals for data centers, battery plants, hydrogen production, green steel, synthetic fuels, and other electricity-intensive facilities. Many projects favor areas near wind generation, ports, industrial clusters, or available land, which do not always match the strongest parts of the existing grid.
Fingrid is carrying out its largest expansion program to date. Planned main-grid investment rose to about €2 billion for 2025–2028, while total investment is estimated at €5.2 billion through 2035. New 400-kilovolt lines, substations, transformers, and trunk connections are intended to move electricity from production areas to industrial loads and population centers.
Cross-border planning continues. Fingrid and Sweden’s transmission operator are examining Aurora Line 2 for the early 2030s and a possible Fenno-Skan 3 submarine connection. These projects could provide more Nordic flexibility and allow surplus Finnish generation to reach other markets.
Not every announced factory, data center, or hydrogen plant will be built, yet transmission projects require years of planning. Fingrid must invest early enough to avoid blocking viable projects while limiting the risk of underused lines. Grid tariffs, connection rules, and efficient use of existing capacity will therefore become more important.
Winter Reliability Remains the Test
A prolonged cold period raises electricity and heat demand while calm weather can reduce wind production. Ice, storms, equipment failures, or disruption to an interconnector can remove supply at the same time.
The system performed strongly during severe cold in early 2026, when Finland recorded new peaks for electricity consumption and production. Domestic plants and cross-border connections operated reliably, while the new Aurora Line improved supply. Fingrid also reported its best recorded main-grid transmission reliability in 2025.
Long-term resilience depends on more than generation. Finland needs dependable transmission corridors, secure substations, reserve and balancing resources, cyber protection, fuel stocks, working ports, and repair capacity for offshore cables and pipelines. Distribution networks must also withstand storms across a country with extensive forests and long rural lines.
Finland’s advantage is that these assets are being developed as parts of one security model. Nuclear power provides large-scale output, wind adds growing low-cost generation, interconnectors provide flexibility, LNG supports industry and reserves, and district heating links local demand to system conditions. The main task for the 2030s is to expand the networks quickly enough for new demand without weakening the reliability that attracts energy-intensive investment.
