Grid Connection Models Across Europe[Draft]
How each European country connects offshore wind to the grid — comparing OFTO, TSO-build, developer-build, and hybrid models across 11 markets.
Last updated: March 2026 · Data from 11 country regulatory framework research documents
Countries Covered11
Model Archetypes4
Operational~33 GW
Total Pipeline~169 GW
The way a country connects offshore wind farms to the grid is the single most important regulatory design decision — it determines who bears construction risk, who pays, and how fast projects can be delivered. Europe has converged on a handful of models, but each country has its own variation.
Model Archetypes
TSO-Build (Centralised)
The Transmission System Operator is legally responsible for planning, building, and operating all offshore grid connections. Costs are socialised via consumer levies or regulated tariffs. Lowest developer risk but least developer flexibility.
OFTO (Competitive Ownership Tender)
Unique to the UK. Developer builds the transmission asset, then a competitive tender appoints a private owner-operator for 25 years. Creates a market for transmission ownership while socialising costs via TNUoS.
Developer-Build
The developer is responsible for building and often operating their own grid connection. Cost is reflected in the project economics / bid price. Highest developer risk but maximum flexibility. Common in newer markets or where state capacity is limited.
Full Comparison Matrix
Each row is one country. Click the country name to see the full regulatory framework page.
| Country | Model | Builder | Operator | Cost Recovery | Risk (Build / Ops) | Operational | Pipeline |
|---|---|---|---|---|---|---|---|
 United Kingdom | OFTO (competitive tender) | Developer builds | OFTO (25-year licence) | Socialised | Developer / OFTO | 11.6 GW | 37.8 GW |
 Germany | TSO-build (centralised) | TSO (TenneT / 50Hertz / Amprion) | TSO (permanent) | Socialised | TSO (with EnWG §17e delay compensation to developers) / TSO | 9.7 GW | 35 GW |
 Netherlands | TSO-build (TenneT sole) | TenneT (sole TSO) | TenneT (permanent) | Regulated tariff | Government pre-surveys de-risk; TenneT builds / TenneT | 4.9 GW | 23 GW |
 Denmark | Evolved (TSO → developer-pays) | Energinet (legacy) → developer (Thor+) | Energinet or developer (varies) | Developer-borne | Developer (from Thor onwards) / Developer or Energinet (transfer varies) | 2.7 GW | 10.5 GW |
 France | TSO-build (RTE sole) | RTE (sole TSO) | RTE (permanent) | Socialised | RTE (liable for delay costs up to 3-year cap) / RTE | 1.5 GW | 26 GW |
 Belgium | TSO-build (Elia + developer contribution) | Elia (TSO) | Elia (permanent) | Hybrid | Elia / Elia | 2.3 GW | 3.5 GW |
 Ireland | Plan-led TSO-build (EirGrid) | EirGrid (Phase 2+); developer (Phase 1) | EirGrid (permanent) | Regulated tariff | EirGrid (Phase 2+) / EirGrid | 25 MW | 5.2 GW |
 Finland | Mixed (territorial + EEZ split) | Developer (territorial); Fingrid coordination (EEZ) | Developer / Fingrid | Hybrid | Developer (territorial); TBD (EEZ) / Developer / Fingrid | 0 MW | — |
 Norway | Developer-build (radial) | Developer | Developer (radial); Statnett coordinates onshore | Developer-borne | Developer (state support provides safety net) / Developer | 0 MW | 10 GW |
 Sweden | Developer-build (under reform) | Developer (shifting to TSO under reform) | Developer (likely shifting to TSO) | TBD | Developer / Developer | 0 MW | — |
 Poland | Developer-build (CfD supported) | Developer | Developer | Developer-borne | Developer / Developer | 0 MW | 17.9 GW |
Cost Allocation
Who ultimately pays for offshore grid connections varies hugely and has major implications for project economics, consumer bills, and investment appetite.
SocialisedUnited Kingdom— TNUoS charges socialised across all GB system usersGermany— Offshore grid levy on consumers (~0.82–0.94 ct/kWh 2025–26)Netherlands— ACM-regulated tariffs; EUR 30B 2GW ProgrammeFrance— TURPE network tariff; EUR 37B for offshore grid through 2040Ireland— RAB model regulated by CRU; EUR 2.4B EirGrid investment (PR6 2026–30)
Costs spread across all electricity consumers via grid levies or network tariffs. Lowest barrier to developer entry but highest consumer exposure.
United Kingdom— TNUoS charges socialised across all GB system usersGermany— Offshore grid levy on consumers (~0.82–0.94 ct/kWh 2025–26)Netherlands— ACM-regulated tariffs; EUR 30B 2GW ProgrammeFrance— TURPE network tariff; EUR 37B for offshore grid through 2040Ireland— RAB model regulated by CRU; EUR 2.4B EirGrid investment (PR6 2026–30)Developer-BorneDenmark— Reflected in developer bid price; no consumer grid levyNorway— Developer-borne with state support via CfD/investment grantsPoland— Developer-borne with CfD subsidy providing revenue stability
Developer absorbs grid connection costs, reflected in project economics or bid price. Highest barrier to entry but lowest consumer exposure.
Denmark— Reflected in developer bid price; no consumer grid levyNorway— Developer-borne with state support via CfD/investment grantsPoland— Developer-borne with CfD subsidy providing revenue stabilityHybrid / TBDBelgium— CREG-regulated tariffs; developer pays 1/3 cable costs (up to EUR 25M/concession)Finland— Mixed state/regulated tariffs; Fingrid coordinates EEZ connectionsSweden— Under reform; market design transition in progress
Mixed models where costs are shared between developers and consumers, or markets where the framework is still being designed.
Belgium— CREG-regulated tariffs; developer pays 1/3 cable costs (up to EUR 25M/concession)Finland— Mixed state/regulated tariffs; Fingrid coordinates EEZ connectionsSweden— Under reform; market design transition in progressSite Selection Approaches
| Country | Model | How It Works |
|---|---|---|
| United Kingdom | Developer-led | Crown Estate designates zones; developers apply to NESO for grid connection |
| Germany | State-led | BSH designates sites in FEP; BNetzA auctions generation rights |
| Netherlands | State-led | Programma Noordzee designates; RVO tenders; minister issues kavelbesluit |
| Denmark | State-led | DEA designates sites and runs tenders; open-door suspended Feb 2023 |
| France | State-led | DSF via CNDP public debates; minister launches tenders; CRE advises |
| Belgium | State-led | FPS Economy domain concessions; MSP designates zones; CREG advises |
| Ireland | State-led | DCEE publishes DMAPs; MARA awards MACs competitively |
| Finland | Mixed | Metsähallitus (territorial waters); government/TEM (EEZ via Energy Authority tenders) |
| Norway | State-led | Ministry opens areas by Royal Decree; NVE runs strategic assessment (KU) |
| Sweden | Open-door | Historically open-door; SOU 2024:89 proposes government-designated areas |
| Poland | State-led | Maritime Spatial Plan designates zones; PSZW + URE auctions |
Technology Convergence
The industry is converging toward ±525 kV HVDC, 2 GW platforms as the standard for new connections. Germany is leading with its BalWin/LanWin series; the Netherlands is following with its 2GW Programme. Countries still on HVAC are typically in earlier stages of deployment.
| Country | Current Standard | Evolution |
|---|---|---|
| United Kingdom | ±320 kV HVDC (TR10+); legacy 132–220 kV HVAC | 132 kV HVAC (TR1–5) → 220 kV HVAC (TR6–9) → ±320 kV HVDC (TR10+) |
| Germany | ±320 kV HVDC standard; 2 GW ±525 kV from 2029 | ±150 kV HVDC → ±320 kV standard → 2 GW ±525 kV platforms |
| Netherlands | 700 MW HVAC (Phase 1); 2 GW HVDC ±525 kV (Phase 2) | Developer-built AC → 700 MW standardised HVAC → 2 GW HVDC |
| Denmark | 220 kV HVAC; ±320/525 kV HVDC for energy islands | 150 kV HVAC → 220 kV HVAC → HVDC for Bornholm/North Sea Island |
| France | 225 kV HVAC (AO1–AO3); ±320 kV HVDC (Centre Manche) | 225 kV HVAC → ±320 kV HVDC → ±525 kV planned (AO10+) |
| Belgium | 150 kV HVAC (Zone 1); 220 kV + HVDC export (Princess Elisabeth Island) | Radial developer-built → MOG 150 kV → Princess Elisabeth Island HVDC hub |
| Ireland | 220 kV HVAC (ORESS 1 east coast); south coast TBD | 38 kV MVAC (Arklow) → 220 kV HVAC (ORESS 1) → HVAC/HVDC TBD (south coast) |
| Finland | Onshore 110–400 kV; offshore TBD per project | Territorial AC → EEZ standardisation pending |
| Norway | HVDC radial (SN II ~200 km); AC radial (Utsira Nord) | Hywind Demo → Hywind Tampen → SN II HVDC / Utsira Nord AC → future ±525 kV |
| Sweden | 220–400 kV HVAC; HVDC planned for larger capacities | Forsmark 2 400 kV HVAC → future HVDC (market reform pending) |
| Poland | 220–275 kV HVAC (Phase I); ±525 kV HVDC (Phase II) | Phase I HVAC standardisation → Phase II HVDC (Bałtyk 1 first) |
Key Regulatory Bodies
The top 3–5 regulatory authorities per country. Permitting complexity varies from Denmark's one-stop-shop (DEA) to the UK's multi-agency model (5+ bodies).
| Country | Key Bodies | Permitting Model | Duration |
|---|---|---|---|
| United Kingdom | Multi-agency (PINS DCO, Ofgem, Crown Estate, MMO) | 6–10 years concept to energisation | |
| Germany | Centralised (BSH one-stop-shop for EEZ) | 12–18 months EEZ; ~5–7 years auction to power | |
| Netherlands | Government-led (Omgevingswet; Rijkswaterstaat/Commissie m.e.r.) | 3–4 years tender to commissioning | |
| Denmark | One-stop-shop (DEA issues 3 sequential licences) | 7–10 years designation to commissioning | |
| France | Multi-authority (CNDP, Préfet Maritime, Autorité Environnementale) | 7–9 years tender to commissioning | |
| Belgium | Federal/regional split (FPS Economy + FPS Health + Flemish Govt) | 4–6 years tender to commissioning | |
| Ireland | Two-stage (MARA MAC + An Coimisiún Pleanála SID planning) | 8–11 years designation to commissioning | |
| Finland | EEZ auction + concession (Energy Authority / Fingrid) | TBD (no precedent yet) | |
| Norway | Three-stage licensing (NVE KU → Ministry licence → Havtil HSE) | 8–12 years KU start to commissioning | |
| Sweden | Government EEZ Act permits (Regeringen); Ei regulates | 10+ years (historically); reform aims to streamline | |
| Poland | Multi-permit sequence (PSZW, RDOŚ environmental, PSE grid, URE CfD) | ~2–3 years pre-COD from CfD award |
Key Insights
Risk & Cost Trade-offs
The fundamental trade-off is between developer flexibility and public cost socialisation. TSO-build (DE, NL, FR) socialises all grid costs via consumer levies — this de-risks projects for developers but means consumers underwrite grid investment regardless of project success. Developer-build (NO, SE, PL) puts full risk on the developer but keeps consumer bills lower. The UK's OFTO model is unique — it creates a competitive private market for transmission ownership while still socialising costs via TNUoS, combining elements of both.
Convergence Toward Standardisation
Markets are converging on two dimensions simultaneously. Technologically, the shift from HVAC to ±525 kV HVDC with 2 GW standardised platforms is being led by Germany and the Netherlands. Commercially, the "race to zero" auction model has failed in multiple markets (DE, DK, NL, FR, BE), driving a near-universal reset to CfD-style support mechanisms. The combined effect is a maturing industry settling on proven models after a period of experimentation.
Meshed Grid Readiness
The North Sea is moving from point-to-point radial connections toward a meshed offshore grid (NSEC, EU ONDP). Only a few countries have regulatory frameworks ready for cross-border cost sharing and hybrid interconnection: Belgium (Princess Elisabeth Island as multi-terminal hub for Nautilus/TritonLink), Germany(Bornholm Energy Island), and the UK (LionLink, Nautilus). Most others will need regulatory reform before meshed grid concepts can proceed.