Deep dive: Offshore wind & floating wind — what's working, what's not, and what's next

Europe's offshore wind capacity crossed 38 GW by the end of 2025, generating enough electricity to power approximately 43 million households and avoiding over 80 million tonnes of CO2 annually (WindEurope, 2026). That milestone came alongside the first commercial-scale floating wind arrays reaching operational status in waters deeper than 100 meters, unlocking vast resource areas previously considered inaccessible. The European Commission's revised target of 120 GW of offshore wind by 2030 demands a pace of deployment roughly triple the historical average, turning procurement strategy, supply chain readiness, and permitting efficiency into decisive competitive advantages. For procurement leaders across energy, infrastructure, and industrial sectors, understanding which subsegments within offshore wind are accelerating and which are stalling is critical for capital allocation and contract timing.

Why It Matters

Offshore wind generates electricity at capacity factors of 45 to 55%, roughly double the output of onshore wind at typical European sites, making it one of the most productive renewable energy sources available at scale (International Renewable Energy Agency, 2025). The higher and more consistent wind speeds found offshore translate into more predictable generation profiles, reducing the need for balancing services and improving grid integration economics. A single 15 MW offshore turbine produces enough electricity annually to power 18,000 to 20,000 European households, and modern wind farms comprising 80 to 100 such turbines deliver multi-gigawatt output from a single project.

Policy momentum across Europe is substantial. The North Sea Energy Cooperation agreement, signed by nine countries in 2025, commits to 260 GW of combined North Sea offshore wind capacity by 2050. Germany's Wind Energy Area Requirements Act accelerated seabed designation, targeting 30 GW by 2030 and 70 GW by 2045. The UK's Contract for Difference (CfD) Allocation Round 6 awarded 12 GW of new offshore wind capacity in 2025, the largest single auction globally. France, the Netherlands, Denmark, and Poland each have pipelines exceeding 10 GW, with projects entering procurement and construction phases simultaneously.

Levelized cost of energy (LCOE) for fixed-bottom offshore wind in European waters fell to EUR 48 to 65 per MWh in 2025, a 60% decline from 2015 levels (BloombergNEF, 2026). Floating wind LCOE remains higher at EUR 100 to 150 per MWh but is projected to fall below EUR 80 per MWh by 2030 as project scale increases and fabrication processes mature. These cost trajectories are reshaping corporate power purchase agreement (PPA) markets, with industrial buyers increasingly contracting directly with offshore wind developers to secure long-term price certainty.

Key Concepts

Fixed-bottom foundations are the dominant installation method for offshore wind in water depths up to 50 to 60 meters. Monopile foundations account for approximately 80% of European installations, with jacket and gravity-based structures used in deeper or geologically challenging locations. Monopile fabrication has scaled to produce units weighing 2,000 to 2,500 tonnes, with installation vessels driving them into the seabed using hydraulic hammers in operations that take 4 to 8 hours per foundation. The supply chain for monopile steel requires 50,000 to 80,000 tonnes per GW of installed capacity.

Floating wind platforms extend offshore wind deployment into waters deeper than 60 meters, where fixed foundations become technically impractical or prohibitively expensive. Three primary platform designs are competing for market dominance: semi-submersible (used by Principle Power's WindFloat and BW Ideol's Damping Pool), spar buoy (deployed in Equinor's Hywind projects), and tension-leg platforms (TLP, under development by SBM Offshore and others). Each design involves trade-offs in steel consumption, fabrication complexity, port requirements, and motion characteristics that affect turbine performance.

High-voltage direct current (HVDC) transmission is the enabling technology for large offshore wind farms located 80 km or more from shore. HVDC systems convert alternating current generated by turbines to direct current for efficient long-distance subsea transmission, with losses of approximately 3% per 1,000 km compared to 6 to 8% for equivalent HVAC systems. Converter stations, both offshore and onshore, represent 15 to 25% of total project capital expenditure and have lead times of 3 to 4 years.

Dynamic cable systems connect floating wind turbines to the seabed export cable through flexible power cables capable of accommodating platform movement. These cables must withstand continuous bending cycles driven by wave and current loading over a 25 to 30 year operational life. The global manufacturing capacity for dynamic cables remains limited to fewer than five qualified suppliers, creating a supply bottleneck for floating wind scale-up.

What's Working

Fixed-Bottom Offshore Wind at Scale

The fixed-bottom offshore wind sector in Northern Europe has matured into a reliable, bankable technology with consistently strong project execution. Orsted's Hornsea 3 project in the UK (2.9 GW) entered construction in 2025 with a projected LCOE below EUR 50 per MWh, making it cost-competitive with new-build gas generation. The project uses Siemens Gamesa's SG 14-236 DD turbines, each rated at 14.7 MW with 236-meter rotor diameters, and has secured fabrication contracts with European monopile manufacturers EEW and Sif for delivery through 2027.

In the Netherlands, TenneT's standardized 2 GW HVDC offshore grid connection program has reduced per-MW connection costs by 20 to 30% compared to bespoke project-by-project approaches. Each standardized platform connects two 1 GW wind farms to shore, and the replication of identical converter station designs has cut construction timelines from 48 to 36 months. This model is being adopted by Germany's Amprion and 50Hertz transmission operators as a template for their North Sea connection programs.

Denmark's energy islands concept, with a planned 10 GW hub in the North Sea, represents the next evolution of fixed-bottom deployment. The artificial island will serve as a central collection point for multiple surrounding wind farms, reducing the number of individual shore connections and enabling power-to-hydrogen production at scale. The Danish Energy Agency awarded preliminary engineering contracts in 2025, with first power expected by 2033.

Floating Wind Demonstration Success

Equinor's Hywind Tampen project in Norway (88 MW) has completed three full years of operation, delivering capacity factors averaging 52% and demonstrating that floating wind turbines can achieve performance levels comparable to fixed-bottom installations (Equinor, 2025). The project's 11 Siemens Gamesa 8 MW turbines, mounted on concrete spar buoy foundations, supply approximately 35% of the electricity needs for the Gullfaks and Snorre oil and gas platforms, displacing gas turbine generation and reducing platform emissions by 200,000 tonnes of CO2 annually.

Principle Power's WindFloat Atlantic project off the coast of Portugal (25 MW) has operated since 2020 with availability rates exceeding 95%, surviving multiple Atlantic storm events with wave heights above 10 meters. The semi-submersible platform design demonstrated that turbine nacelle accelerations remain within manufacturer specifications even in severe sea states, validating the structural integrity assumptions underlying floating wind engineering models.

France has emerged as the most active market for floating wind development, with three pre-commercial projects totaling 750 MW under construction off Brittany and the Mediterranean coast. These projects secured strike prices of EUR 120 to 140 per MWh, approximately 25% lower than earlier pilot projects, reflecting learning-curve cost reductions in platform fabrication and marine installation operations.

Turbine Technology Scaling

Turbine manufacturers have achieved remarkable power rating increases, from 8 MW in 2020 to 15 MW in commercial deployment by 2025, with 18 to 20 MW designs in advanced testing. Vestas's V236-15.0 MW turbine, now operating at multiple European offshore sites, swept area of 43,742 square meters enables each unit to capture 34% more energy than its 12 MW predecessor. Siemens Gamesa has announced the SG 21-252 DD for commercial availability in 2028, targeting installation at projects across the North Sea and Baltic Sea.

Larger turbines directly reduce balance-of-plant costs. A wind farm using 15 MW turbines requires 40% fewer foundations, array cables, and installation vessel trips than the same capacity built with 8 MW units. This scaling effect has been the single largest driver of LCOE reduction over the past five years, contributing an estimated EUR 15 to 20 per MWh of cost savings.

What's Not Working

Supply Chain Bottlenecks

The European offshore wind supply chain is under severe strain. Foundation fabrication capacity across Europe can produce approximately 400 monopiles per year, sufficient for roughly 6 GW of annual installation, but planned deployment requires 12 to 15 GW annually from 2028 onward (WindEurope, 2026). Installation vessel availability is equally constrained: only seven vessels globally are capable of installing turbines rated at 14 MW or above, and new vessel orders placed in 2025 will not deliver until 2028 to 2029. The Jones Act equivalent in the EU's maritime policy further limits non-European vessel deployment for installation operations within member state waters.

Cable supply presents another critical bottleneck. Lead times for HVDC subsea cables have extended from 24 to 40 months, with manufacturers including Prysmian, NKT, and Nexans operating at near-full capacity. Cable manufacturing capacity would need to roughly double by 2028 to meet European offshore wind targets, requiring capital investments of EUR 3 to 5 billion in new production facilities.

Permitting Delays

Despite political ambition, permitting timelines for offshore wind projects in Europe average 7 to 10 years from initial site identification to construction start, compared to 3 to 5 years in the UK and Denmark (European Court of Auditors, 2025). Germany's permitting backlog includes over 20 GW of projects awaiting environmental impact assessments, with individual assessments requiring 18 to 36 months for completion. In France, legal challenges from fishing industry groups and environmental organizations have delayed several projects by 3 to 5 years. The EU's revised Renewable Energy Directive mandates streamlined permitting with a maximum 2-year timeline for designated acceleration areas, but implementation across member states remains inconsistent.

Floating Wind Cost Reduction Pace

Floating wind costs have declined more slowly than the industry projected five years ago. The expected cost reductions from serial fabrication have not fully materialized because no project has yet reached the scale (200 MW or more) necessary to justify purpose-built fabrication facilities and achieve genuine industrialization. Each floating wind project to date has relied on custom fabrication at shipyards originally designed for oil and gas structures, with limited automation and high labor intensity. Steel consumption per MW for floating platforms (150 to 250 tonnes) exceeds fixed-bottom monopiles (30 to 50 tonnes per MW) by a factor of four to five, creating inherent material cost floors that limit convergence with fixed-bottom economics.

Key Players

Established Companies

• Orsted: the world's largest offshore wind developer with 15.5 GW installed globally, operating projects across the North Sea, Baltic Sea, and Taiwan Strait, and pioneering power-to-X integration at offshore wind sites
• Siemens Gamesa: the leading offshore wind turbine manufacturer with over 70% market share in Europe, producing the SG 14-236 DD and developing the SG 21-252 DD platform for next-generation projects
• Equinor: a Norwegian energy company with over 3 GW of offshore wind in operation or construction, including the world's largest floating wind installation at Hywind Tampen
• TenneT: the Dutch-German transmission system operator building standardized 2 GW HVDC offshore grid connections, with EUR 30 billion committed to North Sea grid infrastructure through 2035

Startups

• Principle Power: developer of the WindFloat semi-submersible floating platform, with projects operational in Portugal and under development in France, South Korea, and the US
• Hexicon: a Swedish floating wind technology company developing twin-turbine semi-submersible platforms that increase energy yield per anchor point by 30 to 40%
• Gazelle Wind Power: developer of a hybrid floating platform combining tension-leg and semi-submersible concepts, targeting 50% less steel consumption than conventional floating designs

Investors

• Copenhagen Infrastructure Partners: the world's largest dedicated renewable energy infrastructure fund with EUR 28 billion under management and 15 GW of offshore wind projects in development
• Macquarie Green Investment Group: invested over EUR 10 billion in European offshore wind projects since 2017, including stakes in major North Sea and Baltic developments
• European Investment Bank: committed EUR 15 billion in offshore wind project financing since 2020, including concessional lending for floating wind demonstration projects

KPI Benchmarks by Subsegment

Metric	Fixed-Bottom (Mature)	Fixed-Bottom (New Markets)	Floating Wind
Capacity factor	45-55%	38-48%	45-52%
LCOE (EUR/MWh)	48-65	60-85	100-150
Availability	95-98%	92-96%	90-95%
Construction timeline (months)	24-36	30-48	30-42
Foundation steel per MW (tonnes)	30-50	35-55	150-250
Project development timeline (years)	5-8	7-12	4-7
Design life (years)	25-30	25-30	25-30

Action Checklist

• Map corporate electricity demand against offshore wind PPA availability in relevant grid zones, targeting contracts with projects achieving financial close within the next 24 months
• Evaluate exposure to offshore wind supply chain bottlenecks (foundations, cables, vessels) and consider pre-commitment or framework agreements with Tier 1 suppliers
• Assess floating wind technology readiness for specific procurement contexts where deepwater sites offer better wind resources than available fixed-bottom locations
• Engage with transmission system operators to understand grid connection timelines and capacity allocation processes for planned offshore wind zones
• Review port infrastructure requirements for offshore wind component staging and assembly, particularly for floating platforms requiring deep-water quayside access
• Develop procurement criteria that differentiate offshore wind PPAs by project risk profile, including construction stage, developer track record, and grid connection certainty
• Monitor HVDC cable and converter station lead times, as these supply constraints increasingly determine project delivery schedules
• Establish relationships with emerging floating wind developers for early-mover access to next-generation projects expected to reach financial close in 2028 to 2030

FAQ

Q: When will floating wind achieve cost parity with fixed-bottom offshore wind? A: Full cost parity is unlikely before 2032 to 2035 under current technology trajectories. However, floating wind does not need to match fixed-bottom costs to be commercially viable: it needs to compete with the marginal cost of the next available energy source in regions where fixed-bottom sites are exhausted or unavailable. In markets like the Mediterranean, the US West Coast, Japan, and South Korea, floating wind competes against gas-fired generation or onshore renewables with transmission constraints, and is projected to reach competitiveness against these alternatives by 2029 to 2031 at LCOE levels of EUR 70 to 90 per MWh.

Q: What are the key procurement risks for offshore wind PPAs in 2026? A: The three primary risks are delivery delay (supply chain bottlenecks pushing commercial operation dates by 12 to 24 months), price escalation (steel, copper, and vessel day-rates increasing project costs by 10 to 20% above contracted levels), and grid connection uncertainty (transmission infrastructure lagging behind generation buildout). Mitigate these risks by structuring PPAs with milestone-linked pricing, delay compensation clauses, and alternatives sourcing provisions. Require developers to demonstrate secured supply chain commitments for critical components including foundations, cables, and installation vessels before signing long-term offtake agreements.

Q: How does offshore wind compare to onshore wind and solar for corporate PPA procurement in Europe? A: Offshore wind PPAs typically command a 10 to 20% price premium over onshore wind and a 15 to 30% premium over solar in European markets, reflecting higher capital intensity and longer development timelines. However, offshore wind delivers 40 to 60% higher capacity factors and a more consistent generation profile, particularly during winter months when European electricity demand peaks and solar output declines. For buyers seeking to match 24/7 clean energy targets, offshore wind provides superior temporal coverage: a portfolio combining offshore wind with solar achieves 70 to 80% hourly matching compared to 50 to 60% for solar-only or onshore wind-only configurations.

Q: What role does green hydrogen production play in the offshore wind investment case? A: Power-to-hydrogen integration is emerging as a complementary revenue stream for offshore wind projects, particularly in periods of grid curtailment or negative electricity prices. Pilot electrolysis facilities at offshore wind sites in the Netherlands and Germany are producing green hydrogen at EUR 4 to 6 per kg, with costs projected to fall below EUR 3 per kg by 2030 as electrolyzer scale increases. For procurement teams in sectors requiring green hydrogen (steel, ammonia, refining), direct contracting with offshore wind-to-hydrogen projects offers supply certainty and traceability advantages over spot market procurement.

Sources

• WindEurope. (2026). Offshore Wind in Europe: 2025 Statistics and 2030 Outlook. Brussels: WindEurope.
• BloombergNEF. (2026). Global Offshore Wind Market Outlook 2026. London: BNEF.
• International Renewable Energy Agency. (2025). Renewable Power Generation Costs in 2025. Abu Dhabi: IRENA.
• Equinor. (2025). Hywind Tampen: Three Years of Floating Wind Operations. Stavanger: Equinor.
• European Court of Auditors. (2025). EU Offshore Renewable Energy: Ambitious Targets but Delivery Challenges. Luxembourg: ECA.
• International Energy Agency. (2025). Offshore Wind Outlook 2025: Special Report. Paris: IEA.