Author: Derek Michalski, Chief Editor.
The Netherlands has moved beyond the point at which grid congestion can be treated as a temporary infrastructure bottleneck. In significant parts of the country, electricity network capacity has become a binding constraint on industrial investment, electrification, renewable development and the expansion of large electricity users. The response is increasingly extending beyond conventional grid reinforcement into connection prioritisation, flexible access, congestion management and a reassessment of how scarce network capacity should be allocated.
The scale is substantial. In February 2026, the Dutch government reported that TenneT’s national transmission-grid waiting list contained 212 requests for electricity offtake representing 38 GW of capacity, while regional distribution-system operators were dealing with a further 14,044 requests representing 9 GW. These figures sit alongside substantial queues for generation connections.
The Netherlands is consequently becoming one of Europe’s most consequential test cases for a power system in which demand for connections is growing faster than the physical network can be expanded.
From network constraint to economic constraint
Dutch grid congestion is not primarily a question of insufficient annual electricity production. It is a question of whether electricity can be transported through a particular part of the network at the time it is required.
That distinction has become increasingly important as the structure of the Dutch power system has changed. Renewable generation has expanded rapidly, while electricity demand is being reshaped by industrial electrification, heat pumps, electric mobility, hydrogen production, data centres and other large loads. The resulting flows are more variable, more geographically distributed and increasingly bidirectional.
Congestion can therefore arise on both sides of the market. Generation congestion occurs when renewable projects cannot export their electricity because the local network has insufficient capacity; existing solar and wind assets can also face restrictions during periods of high production. Consumption congestion occurs when businesses or other customers cannot obtain additional transport capacity because the network is already operating close to its limits.
The economic consequence is that electricity infrastructure is increasingly determining the location and timing of private investment. A project can have land, planning consent, technology, financing and an offtake strategy, yet remain commercially unusable without sufficient grid capacity.
That changes the role of the network connection within the investment case. Grid access is becoming an asset characteristic in its own right, alongside site control, permitting, revenue certainty and financing.
TenneT is expanding rapidly — but the network cannot be built fast enough
The Netherlands is not failing to invest in its grid. The opposite is true.
TenneT invested approximately €4.9 billion in the Dutch grid in 2025, as part of €14.8 billion invested across its Dutch and German activities. Yet the transmission operator has warned that the scale of future investment required is vastly larger. TenneT estimates that around €1.2 trillion of investment could be required across its Dutch and German transmission systems by 2040.
The problem is therefore not simply capital availability. Transmission infrastructure has long development cycles, while electricity demand can materialise much faster.
A data centre, industrial plant, electrolyser or battery project can progress from investment decision to construction within a relatively short period. A major substation, transmission corridor or high-voltage connection can require years of planning, permitting, procurement and construction.
The resulting mismatch creates a structural timing problem. Investment in generation and demand can move faster than investment in the network needed to accommodate it.
The Dutch government has consequently been pursuing measures intended to accelerate grid construction, simplify procedures and make more effective use of existing infrastructure. The national grid-congestion programme increasingly rests on three complementary approaches: building more capacity, using existing capacity more efficiently and improving coordination and information across the system.
Scarcity is changing the connection regime
The most consequential development is the gradual erosion of the traditional first-come, first-served model.
Where capacity is abundant, the order in which customers apply for a connection is largely an administrative matter. Under structural scarcity, it becomes an allocation mechanism.
The Dutch authorities have therefore introduced prioritisation principles for new and expanded connections in congested areas. Priority is increasingly being given to activities that contribute to resolving congestion, critical societal functions and essential services, rather than treating every connection request as economically equivalent.
This represents a significant change in the relationship between network operators and grid users. Connection capacity is no longer simply a service that the system operator provides following a technical assessment. It is a scarce infrastructure resource whose allocation has economic and, increasingly, public-policy consequences.
The issue is complicated further by the quality of the connection queue itself. A connection request does not necessarily represent a project that will reach financial close or construction. Projects differ substantially in maturity, financing, permitting status and probability of delivery.
This creates an obvious problem for network planning. Reserving capacity for projects that subsequently fail to materialise can prevent more mature projects from progressing. Conversely, imposing stringent maturity requirements too early can make it difficult for legitimate projects to develop the certainty required to secure investment.
The Netherlands is therefore moving towards a more sophisticated approach in which project maturity, system impact and flexibility increasingly matter alongside the date of the original application.
The cost of congestion is already material
Grid congestion has moved beyond an issue for network operators and developers into a broader economic problem.
Alliander, one of the Netherlands’ major distribution-system operators, cites research by Ecorys estimating the societal cost of Dutch grid congestion at between €10 billion and €40 billion per year. The estimate captures the wider economic consequences of companies being unable to expand, electrify or establish new operations as planned.
For industrial companies, the impact can be direct. Production expansion may be delayed because additional electricity cannot be transported to the site. Electrification projects can become uneconomic if the connection timetable does not match the replacement cycle of existing equipment. New developments may be forced towards locations where grid capacity is available rather than where the underlying industrial logic would otherwise place them.
This introduces a new variable into industrial location decisions.
Historically, access to ports, roads, labour, customers and raw materials were among the dominant considerations. Increasingly, access to electricity infrastructure is joining that list.
Data centres are exposing the limits of the system
The growth of data-centre demand has brought the issue into sharper public focus, particularly around Amsterdam and North Holland.
The underlying problem is not that data centres are uniquely responsible for Dutch congestion. Industrial electrification, distributed generation, electric heating and transport are all contributing to the increase in network demand. But hyperscale and AI-related facilities are unusual because an individual project can require a very large and relatively concentrated electricity connection.
In April 2026, a Dutch court upheld TenneT’s decision not to proceed with a planned connection for a data centre in Haarlemmermeer because of network-capacity constraints. The case involved Goodman, which had sought a connection in the area around Schiphol.
The significance extends beyond the individual project.
A grid connection can now become the decisive factor determining whether a major digital-infrastructure investment can proceed. This is particularly relevant as AI workloads increase electricity requirements and data-centre developers compete for locations with reliable access to high-voltage networks.
Amsterdam has already imposed restrictions on new or expanded data-centre development, with the municipality’s current policy extending the restriction until at least 2030. National policy also limits the development of hyperscale facilities to designated locations.
The Dutch experience illustrates a broader European trend: large electricity consumers are increasingly being assessed not only on their investment and employment contribution, but also on their impact on constrained power systems.
Flexibility is becoming a substitute for part of the network
Grid expansion remains indispensable, but the Netherlands is also demonstrating why simply building more lines and substations will not be sufficient.
The alternative is to increase the utilisation of infrastructure that already exists.
The Dutch regulator, the Authority for Consumers & Markets (ACM), has developed mechanisms intended to encourage large electricity users to reduce consumption during periods of network stress. Since January 2025, large users connected directly to TenneT’s high-voltage network have been able to receive financial incentives for reducing their use during congested periods.
Other arrangements allow customers to accept restrictions on their use of network capacity in exchange for improved access or other commercial benefits.
This is changing the economics of connection.
A conventional connection provides a customer with a defined level of capacity that can generally be used when required. A flexible connection instead makes part of that capacity conditional on the state of the electricity system.
For some loads, the distinction is commercially significant.
Battery storage is inherently capable of shifting consumption and injection. Electrolysers can potentially adjust operating schedules in response to power prices and network conditions. Industrial processes may have some degree of load flexibility. Aggregated demand response can also provide network operators with additional options during constrained periods.
The value of these assets is consequently no longer confined to energy-market arbitrage or ancillary services. Their ability to modify their grid impact can itself have infrastructure value.
Hydrogen exposes the economics of non-firm access
The Dutch hydrogen strategy provides a particularly useful example of the tension between electrification ambitions and grid availability.
Large-scale electrolysis requires substantial electricity capacity. If a developer assumes continuous access to several hundred megawatts of grid capacity, network congestion can become a fundamental constraint on project economics.
A flexible connection changes the calculation.
An electrolyser operating under a non-firm arrangement may accept periods in which grid access is restricted, provided that the resulting utilisation profile remains compatible with its commercial model. The project may then combine grid electricity with contracted renewable generation, storage or other flexibility mechanisms.
This creates a more complex optimisation problem involving connection capacity, utilisation, electricity prices, hydrogen offtake, curtailment and ancillary revenues.
For investors, the distinction between firm capacity and usable capacity is therefore becoming increasingly important.
A nominal 500 MW connection does not necessarily have the same economic value as 500 MW of firm capacity available without restrictions.
The contractual characteristics of the connection can materially affect project returns.
Congestion is increasingly a spatial-planning problem
One of the deeper consequences of Dutch congestion is that the electricity network is beginning to influence where economic activity can be located.
The traditional planning sequence was broadly sequential: identify a suitable site, secure planning permissions, develop the project and then establish the required grid connection.
That sequence is becoming increasingly difficult to sustain.
For large electricity users, network availability needs to enter the site-selection process much earlier. For renewable developers, the value of a site depends partly on the ability to export electricity. For hydrogen projects, proximity to both electricity infrastructure and potential offtakers can determine the economics. For data centres, high-capacity grid access is becoming one of the principal determinants of viable locations.
This has implications for Dutch regional development policy. A location with available network capacity can gain an economic advantage over a location with superior conventional infrastructure but years of grid constraints.
The electricity network is therefore becoming part of the country’s industrial geography.
Congestion and adequacy are converging
The Netherlands faces an additional complication: the congestion problem is developing alongside a growing concern over electricity adequacy.
TenneT has warned that the Netherlands could face increasing electricity shortages after 2030 without additional measures. Its projections indicate that the annual shortfall could rise to 37–46 hours by 2035 under the scenarios assessed.
These are different problems, but they interact.
Congestion means that available electricity cannot always be transported to where it is needed. Adequacy concerns whether sufficient dependable generation is available across the system when demand is high and renewable output is low.
A system can therefore experience periods of local network scarcity alongside periods of national generation surplus, while also facing future shortages of firm capacity.
That makes the Dutch challenge substantially more complicated than a conventional transmission-expansion programme.
It requires coordination between network investment, generation investment, demand flexibility, storage, market design and industrial policy.
The Dutch government’s decision to develop a capacity mechanism reflects this wider concern. The mechanism is intended to provide additional incentives for dependable capacity as electricity demand increases and the economics of conventional generation become more challenging.
A new investment hierarchy is emerging
For energy investors, the Dutch experience points towards a fundamental change in project underwriting.
Grid access can no longer be treated as a binary variable — connected or not connected. The characteristics of the connection increasingly matter: capacity, firmness, timing, curtailment provisions, flexibility requirements, reinforcement obligations and exposure to network constraints.
This creates a hierarchy of project quality that was less pronounced when grid capacity was readily available.
A fully permitted project with a firm connection may command substantially greater investment value than an otherwise comparable project with a conditional or uncertain connection. Similarly, a flexible industrial load may gain an advantage over an inflexible load if both are competing for scarce capacity.
The consequence is that grid strategy increasingly belongs within the core investment case rather than being handled as a technical workstream by the development team.
For infrastructure funds, utilities, industrial companies and project developers, the ability to secure and optimise grid access can become a source of competitive advantage.
The Netherlands is a European warning signal
The Dutch situation is extreme, but the underlying dynamics are not unique.
The Nordic TSOs — Fingrid, Energinet, Statnett and Svenska kraftnät — have all reported rapidly increasing demand for grid connections. Denmark is considering stronger political prioritisation of scarce capacity. Finland is developing flexible connection agreements. Sweden is preparing a pilot for capacity zones. The UK has already undertaken major reforms of its connection queue to prioritise projects with greater maturity.
The common thread is a transition from connection management to system allocation.
Europe’s electricity networks are being asked to accommodate simultaneous growth in renewable generation, industrial demand, electrification, storage and digital infrastructure. Network investment will have to accelerate substantially, but even aggressive investment programmes cannot eliminate spatial and temporal constraints in the short term.
That leaves flexibility, maturity-based connection processes and more deliberate spatial planning as increasingly important components of power-system design.
From grid expansion to grid optimisation
The Netherlands demonstrates that the next phase of Europe’s electricity transition will not be determined solely by how many gigawatts of generation can be built.
It will also depend on how effectively the network can accommodate those assets and connect new demand.
The immediate response is necessarily multi-dimensional: accelerate transmission and distribution investment; shorten permitting and procurement cycles; improve utilisation of existing infrastructure; introduce more sophisticated connection agreements; incentivise flexible demand; improve queue discipline; and align industrial and spatial planning with the physical characteristics of the electricity system.
The investment implications are equally significant. Grid infrastructure is becoming a strategic bottleneck for capital deployment across renewable generation, storage, hydrogen, data centres and industrial electrification. Projects with secured and appropriately structured grid access will increasingly differentiate themselves from projects that merely possess land, permits or attractive power-market fundamentals.
The Netherlands therefore offers a preview of a broader European transition. As electricity demand and renewable generation continue to grow, grid capacity is becoming a scarce economic resource rather than a passive utility service.
That scarcity will increasingly shape where projects are built, which projects reach financial close, how flexible they need to be and ultimately where Europe’s next generation of industrial and energy infrastructure is located.
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The Netherlands: Europe’s Most Extreme Example of Grid Congestion
The Netherlands has become one of Europe’s clearest examples of what happens when electricity demand, renewable generation and electrification advance faster than the physical power network can adapt. Grid congestion is no longer a localised problem affecting a handful of projects. It is increasingly influencing industrial investment, data-centre development, renewable deployment, hydrogen projects and the ability of businesses to expand.
The scale of the challenge is substantial. As of early 2026, requests for new or additional electricity consumption connected to the Dutch transmission system represented around 38 GW across 212 projects, while distribution networks were dealing with thousands more applications. These figures illustrate the widening gap between the capacity that companies want to secure and the network capacity that can realistically be delivered within the required timeframe.
The Netherlands is consequently becoming an important test case for a broader European problem: how to allocate scarce grid capacity while simultaneously accelerating electrification.
A power system constrained by location and timing
Dutch grid congestion is not primarily a shortage of electricity generation. It is a shortage of transport capacity at particular locations and during particular periods.
The structure of the electricity system has changed rapidly. Wind and solar generation have expanded, while demand is being reshaped by industrial electrification, electric transport, heat pumps, hydrogen production and data centres. Electricity flows are becoming more variable and increasingly bidirectional, placing demands on networks that were designed for a substantially different system.
This produces an increasingly difficult paradox. The Netherlands can experience periods of abundant electricity while businesses elsewhere are unable to obtain additional grid capacity. Renewable generators can face restrictions on exporting power at times of high production, while industrial customers simultaneously wait years for additional connection capacity.
The constraint is therefore increasingly physical rather than purely energy-market related.
Grid investment cannot keep pace on its own
TenneT and the Dutch distribution-system operators are investing heavily in network expansion. TenneT invested approximately €4.9 billion in the Dutch electricity grid during 2025, while its longer-term investment requirements across the Netherlands and Germany run into hundreds of billions of euros.
Yet the speed at which infrastructure can be planned and constructed remains fundamentally different from the speed at which electricity demand can emerge.
A data centre, electrolyser, battery facility or industrial plant can progress from investment decision to construction within a few years. New substations, transmission corridors and major grid reinforcements can require significantly longer development periods because of permitting, land acquisition, procurement and construction constraints.
This creates a structural mismatch between the investment cycles of grid users and network operators.
The Netherlands is therefore having to pursue two strategies simultaneously: accelerate network expansion while extracting more value from the infrastructure already in place.
Connection capacity is becoming an allocation problem
As scarcity has become structural, the traditional first-come, first-served approach to connections is increasingly difficult to sustain.
The Dutch authorities and network operators are introducing stronger prioritisation mechanisms, with greater consideration given to critical societal functions, projects that can contribute to congestion reduction and activities considered strategically important.
This changes the economics of the connection queue. The date on which an application was submitted is becoming less decisive than the project’s maturity, system impact and ability to operate within network constraints.
The distinction between a connection request and a deliverable project is particularly important. Large queues contain projects at very different stages of development, ranging from mature investments with financing and permits to early-stage projects that may never reach construction.
For network planners, reserving scarce capacity for projects that subsequently disappear creates an opportunity cost. For developers, meanwhile, the value of a project increasingly depends on its ability to demonstrate that it can actually proceed.
Flexibility is becoming part of the grid solution
Network expansion remains essential, but the Dutch experience demonstrates that infrastructure investment alone cannot resolve the immediate capacity shortage.
Greater flexibility is becoming a second pillar of the response.
Large electricity users can increasingly be offered arrangements under which their consumption is reduced or restricted during periods of network stress. In return, they may obtain access to capacity that would otherwise be unavailable.
This creates a different model of grid connection. Rather than treating capacity as permanently available, the system can distinguish between firm and flexible demand.
The implications vary significantly by technology. Batteries can shift consumption and generation almost instantaneously. Electrolysers can potentially adjust production according to electricity prices and system conditions. Some industrial processes can modify operating schedules. Data centres, by contrast, generally have much more limited flexibility in their core computing loads.
The commercial value of flexibility is therefore moving beyond electricity-market optimisation. The ability to reduce network impact can itself become a project attribute.
Hydrogen faces a particularly difficult equation
The Netherlands’ ambitions for hydrogen illustrate the problem clearly.
Large-scale electrolysis requires substantial electricity capacity, yet the locations that are attractive for hydrogen production are often also areas where the electricity network is under pressure.
A project designed around continuous grid access may therefore face a long connection delay or require substantial reinforcement. A project capable of accepting non-firm access has more options, but its economics then depend on utilisation, electricity prices, hydrogen offtake and the frequency and duration of grid restrictions.
This means that the financial modelling of electrolysers increasingly needs to incorporate the quality of the grid connection, rather than simply its nominal capacity.
A 500 MW connection that can operate continuously has fundamentally different economics from 500 MW that is subject to congestion management.
Data centres are intensifying the pressure
The rapid growth of data-centre demand has made grid scarcity particularly visible.
The Netherlands has long been one of Europe’s leading data-centre locations, but Amsterdam and other major hubs are increasingly constrained by electricity availability. New projects can require very large, concentrated connections, placing them in direct competition with industrial users and other major loads.
The issue is becoming particularly relevant as AI infrastructure increases electricity requirements. Data-centre developers are increasingly assessing power availability alongside fibre connectivity, land, latency and planning conditions when selecting sites.
This is beginning to reshape the geography of digital infrastructure.
The most attractive location is no longer necessarily the one with the strongest existing digital ecosystem. A site with access to sufficient electricity capacity — and a credible pathway to additional capacity — can become considerably more valuable.
Congestion is now colliding with adequacy
The Netherlands also faces a second electricity-system challenge: maintaining sufficient dependable generation as demand rises.
These are distinct problems. Congestion concerns the ability to transport electricity through constrained parts of the network; adequacy concerns whether enough dependable generation is available when demand is high and renewable output is low.
However, the two increasingly interact.
A system can have significant renewable generation and still experience local network shortages. It can also have periods of surplus electricity while facing inadequate firm capacity during periods of low wind and solar output.
This makes the Dutch challenge a system-design problem rather than simply a transmission problem. Generation, storage, demand flexibility, network investment and market design increasingly have to be considered together.
A new variable in infrastructure investment
For investors, the most significant consequence is that grid access is becoming an investment attribute.
Connection capacity can influence project value in the same way as land, permitting, offtake arrangements or financing. The terms attached to the connection — firmness, curtailment, flexibility requirements, timing and reinforcement obligations — can materially affect returns.
This has already begun to influence project location decisions. Industrial companies, hydrogen developers, data-centre operators and renewable investors increasingly need to consider grid availability at the earliest stages of site selection.
The Dutch electricity network is consequently becoming part of the country’s industrial geography.
A preview of Europe’s next grid problem
The Netherlands is an extreme case, but its underlying dynamics are spreading.
Across the Nordic countries, TSOs are reporting unprecedented growth in connection requests. Denmark is reassessing how scarce capacity should be prioritised. Finland is developing flexible connection agreements, while Sweden is exploring capacity zones and stronger spatial signals for new generation and consumption. The UK has already undertaken major reforms to its connection queue.
The direction of travel is clear: European power systems are moving from a model based primarily on connecting demand and expanding the network behind it towards one based on managing scarcity across the entire system.
More grid investment is indispensable. But the Dutch experience demonstrates that investment alone will not close the gap quickly enough.
The next phase will require a combination of accelerated network construction, more disciplined connection queues, flexible access arrangements, stronger locational signals and closer coordination between generation, demand and infrastructure planning.
For developers and investors, the implication is straightforward. Grid access is moving from a technical prerequisite to a core component of project economics.
The Netherlands is showing what that looks like when the constraint becomes systemic. For the rest of Europe, it may be the clearest indication yet of how power-system investment will be shaped in the coming decade.
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