Can TenneT’s New CEO Deliver Where Europe’s Grid Falls Short

When Frans Everts takes over as chief executive of TenneT on 1 November 2026, he inherits a waiting list of 212 requests for large-scale grid connection totalling roughly 38 GW, set against a current system peak demand of about 19 GW. The backlog is not a queue. It is nearly double the entire current peak of one of Northwest Europe’s most heavily loaded transmission systems.

That gap is why a single leadership handover at a transmission system operator (TSO) matters far beyond the company itself. TenneT’s build rate is one of the clearest available indicators of whether the region hits its electrification targets. When grid delivery slows, offshore wind commissioning slips, industrial demand strands, and system costs rise across every connected market.

The question worth answering is not who Everts is. It is whether TenneT’s structural position makes his task achievable, or sets him up for a constrained first term before he has issued a single instruction.

What Frans Everts inherits: a grid giant mid-transformation

Start with the raw footprint. TenneT operates more than 26,000 kilometres of electricity transmission infrastructure across the Netherlands and Germany, serving approximately 43 million people. In the first half of 2026 alone, the company invested €6 billion (around US$7.1 billion) into that network. This is one of the largest regulated capital programmes in European infrastructure, and it runs at that pace every six months.

That scale is the baseline against which every challenge in this analysis should be read. TenneT is not a company deciding whether to build. It is a company deciding how to build faster than any TSO has managed before.

Everts arrives with a specific kind of experience. He spent over 37 years at Shell, most recently leading the company’s Dutch operations, and previously running Shell Energy in North America and overseeing global communications. His four-year term begins 1 November 2026, succeeding Manon van Beek, who led TenneT through its most financially transformative period to date.

The strategy he inherits is already sharpened into three stated priorities:

• Build the grid faster
• Deliver together for customers
• Utilise the grid better

Everts has not announced new quantified TenneT-specific targets. He has signalled continuity with existing capex and congestion programmes, and has publicly framed his ambition around lifting electricity’s share of the energy system toward 50%.

The board’s bet on execution over transformation

Supervisory Board Chair Anja Mutsaers characterised the appointment as centred on execution capability and cross-European collaboration. Read that framing closely, because it is a diagnosis as much as a job description.

The board is not asking Everts to rewrite the strategy. It is asking him to deliver one that already exists, at a scale that is straining the organisation. That tells you what TenneT believes it most lacks right now: not vision, but the industrial execution muscle to turn an ambitious build plan into commissioned assets on schedule.

His continuity posture reinforces the point. By signalling no new targets, Everts is telling the market that near-term announcements should be read as delivery updates, not strategic pivots.

There is a genuine tension worth naming. Moving an integrated-oil executive into the top seat of a regulated public-interest monopoly raises legitimate governance questions under European Commission unbundling principles, which emphasise separating TSOs from supply and trading interests. The board’s bet is that Shell-scale execution experience outweighs the cultural distance. Whether that bet pays off is the through-line of everything that follows.

The EU unbundling rules for transmission operators, established under the Third Energy Package and assessed in subsequent Commission working documents, prohibit TSOs from holding interests in supply or generation businesses, a constraint that makes the board’s decision to appoint an integrated-oil executive a governance question with genuine regulatory texture.

The €12 billion ownership shake-up and what it means for governance

TenneT faced a straightforward problem with no simple solution. Its German capital programme required equity it could not raise from the Dutch state alone. The answer was to partially privatise the German subsidiary through two linked transactions.

The first brought in KfW, the German state development bank, which agreed in February 2026 to acquire a 25.1% stake for approximately €3.3 billion (around US$3.9 billion). That deal closed in July 2026.

The second, announced by the Dutch government in September 2025, brought in institutional capital: APG (on behalf of pension fund ABP), Singapore’s GIC, and Norges Bank Investment Management (NBIM). Together they have committed up to €9.5 billion (about US$11.2 billion) in equity through 2029, building toward a combined 46% stake in TenneT Germany. After both transactions, TenneT Holding’s stake in the German unit dilutes to roughly 28.9%.

The pricing tells its own story. The transactions value the German unit at an Enterprise Value to Regulated Asset Base (EV/RAB) multiple of approximately 1.09, a measure comparing the price paid against the value of assets the regulator allows the company to earn a return on. A multiple that close to 1.0 signals that institutional investors view TenneT Germany as a low-risk, long-duration asset priced for stability rather than growth.

That read is reassuring on financing cost. It also carries a sharp edge for you as an investor. When shareholders pay a premium for predictability, any operational or regulatory stumble lands harder, because it violates the exact thesis they bought into.

Fitch Ratings’ assessment Fitch described the institutional deal as credit-positive, noting it strengthens TenneT Germany’s capital base and supports its intensive capex plan while leaving the regulatory risk profile unchanged.

The governance complication is structural, not incidental. State shareholders prioritise security of supply and the pace of build. Private institutional investors prioritise stable regulated returns. When those objectives diverge under a shared ownership roof, the friction is built into the decision-making, and it is Everts who must manage it.

None of this is unprecedented. RTE in France and Elia in Belgium and Germany both partially privatised while preserving TSO independence. For anyone tracking European grid investment flows, the TenneT structure is a template for how states fund historic capex without surrendering full control, and the tensions it creates will recur across the continent this decade.

38 GW of unmet demand and a congestion crisis with no short-term exit

Return to the number in the opening. TenneT holds a waiting list of 212 large-scale offtake requests totalling approximately 38 GW, against a current peak demand of about 19 GW, rising to a projected 27 GW by 2030. The backlog alone is roughly double the entire present system peak.

Nationally, the picture is broader still. Roughly 14,000 to 15,000 businesses and projects sit on distribution waiting lists across the Netherlands. The Netherlands Environmental Assessment Agency (PBL) reports that most of the country now faces structural net congestion.

Four structural drivers explain why Dutch congestion runs worse than in peer markets:

• Rapid growth in demand and decentralised supply outstripping the pace of grid reinforcement
• Misaligned spatial planning, with energy-intensive projects sited in weaker grid areas
• Permitting friction and supply chain and labour shortages
• A rigid, first-come-first-served capacity system that locks up the grid even when reserved capacity sits unused

The interpretation is uncomfortable but clear. This is not a queue Everts can clear with better administration. It is a structural mismatch between the pace of electrification demand and the pace of grid build, and it predates him.

Negative electricity price dynamics compound the congestion problem in a structurally underappreciated way: when wholesale prices turn sub-zero during peak renewable output, the economic case for demand-side flexibility weakens, reducing the incentive for large industrial offtakers to shift load in ways that would otherwise relieve congested nodes.

What the new ACM priority framework changes, and what it does not

The Dutch regulator ACM introduced a new priority framework effective 1 July 2026, replacing the first-come-first-served system in congested areas. National security, healthcare, drinking water, and housing now move to the front of the queue. Commercial businesses move to the back, regardless of how ready their projects are.

Alongside it, a package to accelerate grid delivery, struck with the Ministry of Climate and Green Growth, targets a reduction in the time from permitting to completed construction, bringing what has historically taken between eight and twelve years down to a range of roughly four and a half to seven and a half years. TenneT is also pushing flexible, time-based contracts for large batteries to unlock stranded capacity.

TenneT’s push to deploy flexible, time-based contracts for large batteries sits within a broader European acceleration: battery storage capacity additions reached a record 27.1 GWh across the EU in 2025, a supply base Everts can draw on as a congestion management tool rather than waiting solely for new transmission build.

Here is the limitation you should hold onto. Prioritisation reallocates existing capacity; it does not create new capacity. For any business or developer relying on Dutch grid access, that distinction defines the investment environment: a commercial applicant with a shovel-ready project may still wait years. For infrastructure investors, the same backlog is the clearest signal of where TenneT’s regulated asset base will expand fastest once constraints ease.

The 2GW offshore programme: contractor collapse, re-contracting, and the 2031 test

The most acute disruption Everts inherits has already been partly resolved, which is the right way to read it. This is a management challenge mid-correction, not a crisis still spiralling.

The 2GW Programme is a set of fourteen large-scale offshore HVDC connections (high-voltage direct current links carrying North Sea wind power to the mainland grid). Six of those systems were originally awarded in March 2023 to a consortium of Hitachi Energy and Petrofac, under a framework valued at approximately €13-14 billion.

In October 2025, TenneT partially terminated the contract with immediate effect, citing Petrofac’s failure to meet its contractual obligations during financial difficulties. Petrofac subsequently entered administration.

The re-contracting has since taken shape. Larsen and Toubro (L&T) was nominated as the replacement EPC contractor for Petrofac’s portion, while Hitachi Energy remains the core electrical systems provider. The six affected and re-assigned systems are:

1. IJmuiden Ver Alpha
2. Nederwiek 1
3. Nederwiek 3
4. Doordewind 1
5. Doordewind 2
6. LanWin 5

The transition carried a cost in schedule. Portions of planned 2026 offshore capex have been deferred into 2027, pulling full-year 2026 investment below plan. The clearest public indicator of schedule slippage is the NOR-9-2 connection, now carrying a documented two-year delay from 2029 to 2031.

The credibility benchmark TenneT’s overarching target remains for all fourteen 2GW offshore systems to be operational by 2031. That date is the line Everts will be measured against.

The L&T re-contracting is a necessary fix, but it does not reset the clock. Everts begins his tenure managing a handover mid-programme, on assets where any further contractor-level disruption pushes key systems beyond 2031 and into direct conflict with offshore wind commissioning schedules across the North Sea.

The National Grid Block Island cable in the US is the cautionary reference here. Insufficient cable burial depth led to costly remediation and regulatory intervention, a reminder that offshore execution risk is not only about who holds the contract but how rigorously the work is supervised. For investors in offshore wind projects connected to TenneT, the read is direct: treat 2031 as a working assumption to monitor actively, not a confirmed delivery date.

Offshore wind contract termination risk has moved from a theoretical line item to a live programme variable in 2025–2026, with contractor financial distress and force majeure claims reshaping how developers and TSOs structure EPC agreements on both sides of the Atlantic.

Building at this pace is an industry-wide challenge, not a TenneT-specific failure

Step back from the four layers of pressure. The most useful reframe is that most of TenneT’s difficulties are symptoms of a European execution gap, not evidence of a company failing in isolation.

The ownership question has tested precedents. Partial privatisation of a TSO is a proven model, not an experiment:

• RTE (France): In 2017, EDF sold a 49.9% indirect stake to Caisse des Dépôts and CNP Assurances. European Commission certification confirmed RTE retained independent TSO status. Massive equity inflows, governance integrity preserved.
• Elia (Belgium/Germany): Elia reorganised into a listed holding owning distinct Belgian and German TSOs, with KfW holding a 20% stake in the German holding entity Eurogrid. Multi-jurisdictional ownership has supported major offshore integration.

For investors, those cases carry a specific message. TenneT’s ownership restructuring is not structurally novel, and the governance risks are manageable with clear subsidiary mandates. That is one category of risk you can reasonably treat as containable.

The harder constraint is one no single operator controls. The offshore build rate demands simultaneous scaling of cable manufacturing, specialist installation vessels, and skilled workforce capacity across the entire European supply chain. TenneT’s €6 billion half-year capex signals the capital intensity, but capital is not the binding limit. Execution capacity is.

Germany’s parallel capex pressure sits directly behind TenneT’s financing choices: the German HVDC grid transformation programme, valued at roughly 24 billion EUR, is drawing on the same contractor pool, cable manufacturers, and installation vessels that TenneT’s 2GW offshore systems depend on.

What the peer precedents do and do not resolve for TenneT

RTE and Elia confirm the ownership model works. What neither faced was TenneT’s specific combination: a contractor collapse on the scale of the Petrofac termination running at the same time as a domestic congestion crisis of the current magnitude.

That is the genuinely novel challenge Everts confronts. Not one hard problem, but three overlapping ones, with no sequential path to resolving them.

This is where his Shell background cuts both ways, and both readings are true at once. His experience scaling complex industrial systems is strong preparation for a build-execution mandate. It is also no substitute for deep regulatory and grid-operations experience. For anyone pricing European grid assets, the honest split is this: some risks are company-specific and manageable through better leadership, and some are structural and must be priced into any thesis regardless of who runs the company.

Whether the 2031 target holds will define Everts’ first term

Three variables will determine how Everts’ first term is judged, and they resolve on different clocks.

1. The 2031 offshore delivery target. The single most visible external credibility test. Any further slippage on the fourteen 2GW systems reads directly as programme failure.
2. The pace of Dutch congestion relief. Businesses and voters will feel this before any offshore milestone lands, with severely congested zones not clearing until 2029 at the earliest and some constraints persisting to 2035.
3. The governance coherence of the new ownership structure. Whether the state and institutional shareholders can hold a common line when their objectives diverge under operational stress.

The uncomfortable detail sits in the timeline. Everts’ term runs from November 2026 to roughly November 2030, meaning the 2031 offshore target falls a full year after he leaves. His tenure will be judged on trajectory and programme integrity, not delivered outcomes, which places a premium on transparent reporting and early warning of further delays.

Separate what he controls from what he does not. Internal execution, contractor management, and stakeholder communication sit within his grip. Permitting timelines, supply chain capacity, and the interest rate environment shaping institutional co-investors’ return expectations do not.

Sustaining the €6 billion half-year capex run-rate is the baseline, not the ambition. TenneT’s trajectory over the next four years is a live test of whether Europe’s regulated infrastructure model can deliver electrification at the pace decarbonisation commitments demand. Those are the milestones worth watching, and their sequencing is the framework for reading every quarterly disclosure to come.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions. Past performance does not guarantee future results. Financial projections are subject to market conditions and various risk factors, and forward-looking targets are subject to change based on regulatory, supply chain, and operational developments.