Floating offshore wind Market Outlook 2026–2041: Growth Drivers, Key Companies, Strategic Developments & Adoption Forecast — A Meticulous Next™ Foresight Brief

This Meticulous Next™ brief examines floating offshore wind, meaning wind turbines mounted on floating platforms moored to the seabed, which allow wind farms in water too deep for fixed foundations. It tests whether commercial-scale arrays awarded in Europe and Asia are built at falling cost, and which participants capture value among developers, utilities, platform designers, cable and turbine suppliers, ports and governments.

The operating base is small and the results are strong. The first floating farm, Hywind Scotland, was installed in 2017 at 30 MW and averaged a capacity factor of 49.5% in the 12 months to the end of May 2022, WindFloat Atlantic in Portugal at 25 MW has operated since 2020 and produced about 80 GWh in 2023, and Hywind Tampen in Norway at 88 MW supplies oil and gas platforms. The conclusion is that deepwater sites deliver high output, and the open question is the cost of building at scale.

Awards are now moving from demonstration to commercial scale. The Crown Estate offered up to 4.5 GW across three Celtic Sea sites in Round 5, with Equinor and Gwynt Glas winning two sites in June 2025 and Ocean Winds, a joint venture of EDP Renováveis and Engie, set to receive the third by direct award, and floating projects won 14.5 GW of the 25 GW awarded in the ScotWind round. In Asia, South Korea opened a second half 2026 auction of about 2.2 GW with 500 MW reserved for floating, accepting applications from 30 October to 10 December 2026 with awards expected from December. The conclusion is that arrays of hundreds of megawatts are being awarded in Europe and Asia, and Asia now follows Europe into commercial floating auctions.

Cost sets the pace of build. The first floating farms had a levelised cost above USD 200 a megawatt hour against about USD 50 for fixed-bottom wind according to DNV, the United Kingdom set an administrative strike price of GBP 176 a megawatt hour for floating wind in its sixth auction round at 2012 prices, and Equinor and Masdar target EUR 40 to 60 a megawatt hour for Hywind projects by 2030. South Korea set price caps of KRW 174,003 a megawatt hour for floating against KRW 168,937 for fixed-bottom wind and scores bids on domestic supply chain and community acceptance as well as price. The conclusion is that support prices still bridge the gap with fixed-bottom wind, and local content rules shape who supplies the arrays.

The brief treats floating offshore wind as an accelerating signal with a fifteen year horizon to 2041. It identifies which sites, platform designs and developers scale first and what each means for developers, utilities, suppliers, ports and governments. It is a focused 118-page decision brief that presents an indicative trajectory rather than a segmented market model.

A floating offshore wind turbine stands on a buoyant platform held in place by mooring lines anchored to the seabed, and power travels to shore through a dynamic cable that moves with the platform. This allows wind farms in water deeper than about 60 metres, where fixed foundations are not practical and wind is stronger and steadier.

Platforms are semi-submersible, spar, barge or tension leg designs. Floating turbines can need about twice the steel of a fixed-bottom turbine of equal size, which raises the importance of series production in fabrication yards.

Performance depends on platform motion and turbine loads, the life of moorings and dynamic cables, and the depth and capacity of ports that must assemble and launch the platforms.

Uses are grid power from deepwater sites, power for offshore oil and gas platforms and supply to coastal regions with narrow shelves such as Norway, Portugal, France, Japan, South Korea and the west coast of the United States.

The limits are cost compared with fixed-bottom wind, port depth, grid connection capacity and steel demand. The period turns on whether series production brings cost down enough to reduce support prices.

The floating offshore wind market, covering floating platforms, turbines, mooring, dynamic cables, installation and operation of floating wind farms, and excluding fixed-bottom offshore wind and onshore wind, is valued at USD 1.5–2.5 billion in 2026 and is projected to reach USD 29.61–49.36 billion by 2041, at a CAGR of 22%.

The 2026 base rests on the operating farms in Scotland, Portugal and Norway, projects under construction and the development spend of awarded sites. Growth then follows build of the Celtic Sea sites, ScotWind floating projects, French and Portuguese arrays and the first Korean and Japanese awards.

The forecast is sensitive to support prices, platform production capacity, port investment and grid connection. Regionally, Europe holds the largest base through the United Kingdom, Norway, France and Portugal, Asia-Pacific grows fastest through South Korea, Japan and Taiwan, and North America adds projects on the west coast later in the period.

The base case assumes the first Celtic Sea and Korean arrays reach financing by 2028, arrays of 500 MW or more operate by 2031 and the technology reaches the mainstream by 2033. An accelerated case assumes series production cuts cost faster and auctions in Japan and France are timely, bringing the inflection to 2030 and lifting the 2041 value to the top of the range. A delayed case assumes port and grid constraints and cuts in support prices, moving the inflection to 2037 and holding growth at the bottom of the range.

Growth drivers

• Access to deepwater wind sites.
• Auction capacity in Europe and Asia.
• Capacity factor of floating farms.
• Supply of power to oil and gas platforms and coastal grids.

Enablers

• Government port and manufacturing funding.
• Oil and gas offshore skills and vessels.
• Larger turbines.
• Support price schemes.

Restraints and barriers

• Cost compared with fixed-bottom wind.
• Port depth and capacity.
• Grid connection capacity.
• Steel demand and platform supply.

The direction of floating offshore wind is set by deepwater wind resource, commercial-scale auctions, cost reduction and series production, port, vessel and grid investment, and support price and supply chain risk.

The key participants in floating offshore wind include Equinor ASA, EDP Renováveis, S.A., Engie SA, Électricité de France S.A., Ørsted A/S, RWE AG, Iberdrola, S.A., TotalEnergies SE, Shell plc, Copenhagen Infrastructure Partners P/S, Principle Power, Inc., BW Ideol AS, Hexicon AB, Vestas Wind Systems A/S, Siemens Energy AG, GE Vernova Inc., Subsea7 S.A., Prysmian S.p.A., The Crown Estate, Crown Estate Scotland, Gwynt Glas, DP Energy, Ocean Winds, BlueFloat Energy, Korea Electric Power Corporation, HD Hyundai Co., Ltd., Samsung Heavy Industries Co., Ltd., Doosan Enerbility Co., Ltd., Aker Solutions ASA, Saipem S.p.A., Department for Energy Security and Net Zero, Ofgem, Scottish Government, Enova SF, European Commission, Offshore Renewable Energy Catapult, RenewableUK, WindEurope, Global Wind Energy Council, DNV Group AS, Ardersier Port and Port-La-Nouvelle.

The brief profiles representative participants in each archetype and assesses which are positioned to lead as commercial arrays are built.

Equinor leads on operating floating farms, Principle Power and BW Ideol lead among platform designers, and Ocean Winds, Iberdrola and Ørsted lead among developers with awarded sites. Competitive intensity is moderate among developers and low among platform suppliers, rising as Asian shipyards enter.

Where value migrates.

In 2026 value sits with developers that hold awarded sites and the platform designers attached to them, because sites are scarce and each award fixes a supply chain. By 2033 it moves toward platform and cable suppliers with series production, because cost falls where yards build repeatable units. By 2041 it settles in platforms that combine developer, platform, port and grid capacity. Margins hold for developers with secure support prices and suppliers with scale and narrow for fabricators dependent on a single project.

The signals converge on awards and cost. Celtic Sea sites awarded in 2025, 14.5 GW of floating projects in ScotWind, a Korean auction with 500 MW of floating capacity and farms with capacity factors near 50% support growth, while cost compared with fixed-bottom wind, port depth and grid capacity limit the pace.

Structural limits show where progress could slow: cost, ports, grid connection and steel demand. The brief therefore tracks four indicators: arrays awarded, arrays in construction, support prices and platforms delivered each year.

Demonstration farms first, then commercial arrays of 500 MW or more, then series production across several countries are the expected order of adoption.