Europe’s Energy Infrastructure
Why electricity networks are becoming Europe’s strategic backbone
Europe’s energy transition is often described in terms of generation: more wind turbines, more solar panels and greater offshore capacity. But Europe’s real strategic constraint is increasingly located elsewhere.
Electricity must be transported from where it can be generated to where it is needed. Offshore wind from the North Sea must reach industrial centres in Germany, Belgium and the Netherlands. Nordic hydropower must help balance fluctuations elsewhere. Solar electricity from southern Europe must become part of a continental system rather than remain constrained by weak connections across national borders.
This is no longer only an energy question. If limited grid capacity determines where factories, data centres and electrolysers can be built, electricity networks begin to shape Europe’s industrial geography—and with it the continent’s ability to compete technologically with the United States and China.
Europe’s energy transition will succeed only if its grids become as European as its ambitions.
The central question is therefore not simply how Europe produces more electricity. It is whether dozens of nationally organised energy systems can gradually be transformed into one European infrastructure.
A European system built from national grids
Europe does not have one electricity grid in the same institutional sense that it has one internal market. It has national and regional networks that have become increasingly interconnected.
ENTSO-E coordinates the transmission system operators responsible for keeping this vast system balanced. Its interconnected area stretches from Portugal to Ukraine and from Norway to Italy. Yet ENTSO-E does not own the cables, build the substations or determine national investment priorities. Those responsibilities remain with operators such as TenneT, Elia, RTE, Amprion, Terna and Red Eléctrica. This creates Europe’s central infrastructural tension.
Europe increasingly depends on electricity moving across borders, but most investment decisions are still assessed through national regulatory systems. A connection that benefits several countries may impose most of its construction costs, land-use disputes and political controversy on only one or two of them.
The physical grid is becoming European faster than its governance.
The electricity may travel across Europe. The mandate to build the infrastructure usually does not.
Transmission operators as industrial architects
TenneT and Elia illustrate how the role of the transmission system operator is changing. They are no longer merely maintaining national high-voltage networks. They are designing offshore connections, coordinating cross-border flows and making decisions that influence the location of future European industry.
TenneT occupies a particularly strategic position because it operates transmission infrastructure in both the Netherlands and Germany. Its standardised 2 GW offshore connection systems are intended to transport large volumes of North Sea wind power to the mainland. Elia performs a comparable bridging role through its activities in Belgium and Germany and its involvement in offshore infrastructure around the Princess Elisabeth Zone.
These companies are becoming more than utilities. They are turning into architects of Europe’s economic geography. Where they create capacity, factories, data centres, electrolysers and charging infrastructure can grow. Where networks remain congested, investment may be delayed, reduced or diverted elsewhere.
Grid capacity does not replace taxation, labour availability or access to capital as a location factor. But it is rapidly becoming a precondition without which those other advantages lose much of their value. The electricity grid therefore does not merely serve the economy. It increasingly determines where parts of that economy can exist.
Interconnectors are Europe’s energy corridors
Interconnectors make it possible to move electricity between national systems. They allow countries to share reserves, absorb fluctuations and use differences in weather, demand and generation more efficiently.
A cable between two countries is therefore more than a commercial connection. It creates a form of mutual dependence.
Energy sovereignty begins with the ability to move electricity across borders.
Norway can export hydropower when wind generation elsewhere is low. Denmark can move surplus wind power into neighbouring markets. France can export nuclear electricity while importing when domestic generation becomes constrained. The Iberian Peninsula could contribute substantially more renewable power if its connections with the rest of Europe were stronger.
ENTSO-E estimates that an additional 224 GW of cross-border grid capacity beyond the 2030 system would be economically efficient by 2050. It also identifies 540 GW of economically efficient storage power capacity. The projects currently under development address only part of this longer-term requirement.
This is the emerging map of European energy power: not simply where electricity is produced, but which regions can move it, store it and redirect it.
Why HVDC changes the geography
High-voltage direct current technology—HVDC—is becoming one of the enabling technologies of this European system.
Alternating-current networks remain essential within national grids. HVDC is particularly valuable for transporting large volumes of electricity over long distances, connecting different synchronous areas and bringing offshore wind power ashore through subsea cables with lower losses over such distances. More importantly, it could allow Europe to move beyond the bilateral interconnector.
Future offshore infrastructure may connect wind farms to several countries simultaneously. An offshore hub could collect electricity, deliver it to different markets and function as a cross-border trading connection. The offshore wind farm, export cable and interconnector would then begin to merge into a single infrastructure.
This is the significance of projects associated with Belgium’s Princess Elisabeth Zone and proposed hybrid connections such as Nautilus and TritonLink. They point towards a more interconnected North Sea grid rather than a collection of separate cables running from individual wind farms to individual countries.
The North Sea could consequently become not only a source of energy, but a European electricity platform.
Yet this transition is not technically automatic. Most HVDC systems have traditionally been developed as point-to-point connections, frequently around the technology of an individual supplier. A meshed offshore grid will require converters, control systems and protection technologies from different manufacturers to operate together.
The grid no longer follows industrial geography. It increasingly creates it.
The EU-supported InterOPERA project is working on precisely this challenge: making multi-terminal, multi-vendor HVDC systems interoperable by design.
Europe must therefore build not only more HVDC infrastructure, but also the industrial standards and production capacity that allow individual projects to become one expandable system.
The offshore grid still comes ashore
Yet every offshore vision eventually encounters an onshore reality. Electricity arriving from the North Sea must still pass through converter stations, substations, high-voltage corridors and regional distribution networks. If those networks cannot absorb it, additional offshore generation does not solve the underlying constraint.
This is increasingly visible in the Netherlands, Germany, Belgium and elsewhere. Renewable projects, industrial electrification, housing developments and data centres compete for limited connection capacity.
Net congestion is no longer a local technical inconvenience. It has become an economic allocation mechanism.
A region may possess land, capital, skilled workers and market demand—and still be unable to accommodate a new factory because the electricity network is full.
This exposes a fundamental sequencing problem. Europe has often stimulated renewable generation and electrification before expanding the infrastructure required to connect them. Projects can consequently be financially viable, politically desirable and technically ready, yet remain unable to access the grid.
Flexibility is infrastructure too
Building more cables is necessary, but it will not be sufficient. A system dominated by variable electricity generation must also become more flexible. Batteries, pumped storage, demand response, heat networks, industrial load management and intelligently charged electric vehicles can help align consumption with periods of abundant generation.
This changes the meaning of infrastructure. A steel plant that can temporarily adjust part of its electricity use, a neighbourhood battery or a fleet of intelligently charged vehicles can release capacity elsewhere in the system.
Europe cannot build a continental energy system through national planning alone.
But flexibility should not become an excuse for failing to build networks. Digital optimisation can use existing infrastructure more efficiently. It cannot permanently compensate for a shortage of physical capacity.
Europe needs both: stronger grids and a more responsive system around them.
Who pays for the European grid?
The European Commission’s Grids Package recognises that national planning alone is no longer sufficient. It seeks more coordinated cross-border planning, faster permitting and stronger protection of critical energy infrastructure. European electricity-grid investment needs are estimated at more than €1 trillion by 2040. But the central difficulty is not simply raising capital. It is deciding who should ultimately carry the cost.
A transmission corridor may run through one country while lowering prices, improving security of supply or enabling industrial development in several others. National regulators must then determine whether the country hosting the infrastructure should pay for it or whether beneficiary countries should contribute.
Europe already has a mechanism for this: cross-border cost allocation, or CBCA. In theory, it allows the costs of Projects of Common Interest to be divided among the countries that benefit. In practice, ACER has concluded that gaps remain in the way European benefits and national costs are aligned. This is where physical integration becomes a governance test.
Europe must coordinate regulators with different national mandates, distribute costs and risks between countries, secure specialised components and build public legitimacy for infrastructure whose value may be continental rather than immediately local.
Europe does not need to abolish its national energy systems. But it does need to make them function as parts of a larger whole.
The decisive question is no longer whether European countries can exchange electricity. It is whether Europe can plan, finance and govern that infrastructure as one system.
Unless its governance becomes as interconnected as its grid, congestion will begin to determine not only where electricity can flow, but where Europe’s industrial future can still be built.
Building Europe’s Electro-Powered Continent is an ongoing Strategic Briefings series within the Innovation & Technology Lab, examining how Europe’s diverse energy landscape, industrial capabilities, infrastructure and innovation ecosystem are converging into the foundations of an increasingly electrified continent.
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Illustration: Altair Media / OpenAI
Caption
Europe’s electricity system is becoming increasingly interconnected, but its planning, financing and governance remain largely national. Transmission operators, interconnectors, HVDC technology, offshore grids and flexibility must ultimately function as parts of a single European infrastructure.
