British and French energy regulators have paused the approval process for a new electricity interconnector between the UK and France. The move highlights the increasingly complex economics of cross‑border energy infrastructure and raises broader questions about Europe’s long‑term energy security.（Reuters）

The announcement, issued jointly by Ofgem and France’s Commission de Régulation de l’Énergie (CRE) on 11 February 2026, stated that the conditions required for regulatory approval “have not yet been met”. The proposed link would have added roughly 1 GW of new capacity to the existing 4 GW of UK–France interconnection.

Why the Approval Was Paused

Although the UK and France already operate several major interconnectors — including IFA, IFA2 and ElecLink — regulators argued that the financial and cost‑allocation frameworks for the new project remain insufficient.

Ofgem and CRE said they could not proceed without a clear mechanism for how investment costs and operational revenues would be shared between the two countries. They will now launch a joint study to examine long‑term system needs, cost‑sharing models and the potential value of additional capacity.

This pause underscores a broader challenge: even when existing interconnection operates smoothly, aligning regulatory, economic and strategic priorities across national energy systems remains difficult.

Implications for UK and European Energy Security

1. Reliability and System Flexibility

Interconnectors play a critical role in balancing supply and demand. The UK’s system operator has repeatedly highlighted in its Future Energy Scenarios (FES) that electrification, rising peak demand and the growth of variable renewables will increase the value of cross‑border flexibility over the coming decade.

Against that backdrop, an additional 1 GW of interconnection would have strengthened the UK’s ability to manage tight system conditions. It would have been especially useful during winter peaks or periods of low wind output.

2. Renewable Integration

Expanded interconnection is central to integrating higher shares of renewable energy. However, a delay in new capacity may slow progress toward this goal. Moreover, the risk increases if investors perceive regulatory uncertainty around future cross‑border projects.

3. Investment Signals and Cost Allocation

The regulators’ emphasis on cost‑sharing frameworks reflects a wider concern across Europe: how to finance large, long‑lived energy infrastructure in a way that distributes benefits fairly. Uncertainty in this area can deter private capital and delay upgrades that markets rely on for price stability.

Regional and Market Context

The UK and France have cooperated on electricity trade for decades. As a result, the existing 4 GW of interconnection capacity has become a backbone of cross‑Channel energy flows since the 1980s. （TradingView）

At the European level, ENTSO‑E’s Ten‑Year Network Development Plan (TYNDP) identifies expanded interconnection as a core requirement for meeting 2030 and 2040 decarbonisation targets.

The pause on the UK–France project sits uneasily with broader regional planning. This planning assumes that cross‑border capacity will keep growing rather than stalling.

Market and Policy Relevance for Investors

Price Volatility

Without additional interconnection, the UK and France may face tighter supply conditions during peak demand periods. As a result, short‑term price volatility could increase.

Infrastructure Investment

Regulatory uncertainty can discourage private investment in future cross‑border projects, affecting infrastructure planning cycles and slowing the build‑out of Europe’s integrated energy market.

Policy Signals

The forthcoming joint study by Ofgem and CRE will be closely watched. Its conclusions will show how much weight policymakers place on cross‑border capacity versus domestic generation. This is a key issue as Europe navigates decarbonisation, electrification and growing energy‑security pressures.

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