Somewhere beyond the reach of conventional turbine foundations — in waters too deep for steel to meet seabed — a new generation of wind energy is taking shape. Floating offshore wind promises access to vast, untapped resources that fixed-bottom platforms were never built to reach. But the technology remains largely unproven at commercial scale, and the industry knows it.
The question isn’t whether floating wind can work. Small projects have already shown it can. The harder question is whether it can grow — systematically, economically, at the pace the energy transition demands.
An industry built on stepping stones
Fixed-bottom offshore wind didn’t arrive fully formed. The sector’s first project — Denmark’s Vindeby farm, commissioned in 1991 — comprised just 11 turbines generating a modest 4.95 megawatts. Two decades of deliberate, incremental expansion followed. Each successive project pushed a little further from shore, deployed slightly larger turbines, and tested new installation methods. By the time developers were constructing multi-gigawatt arrays in the North Sea, they had accumulated deep operational experience and a supply chain capable of supporting that ambition.
This stepping stone model was not accidental. Early technology was expensive and unproven, and investors demanded evidence before committing capital at scale. As projects grew and costs fell, confidence followed. Offshore wind’s levelized cost of energy dropped substantially through the 2010s, driven by learning-by-doing, supply chain maturation, and competitive auction processes that rewarded efficiency.
That history is now the template floating wind proponents want to replicate. If fixed-bottom could travel from a handful of nearshore turbines to one of the world’s most competitive power sources, floating wind can trace a similar arc — provided the industry is patient enough to walk the same path.
Where floating wind stands today
Right now, floating offshore wind is roughly where fixed-bottom was in the mid-1990s. A handful of demonstration projects exist — most notably Equinor’s Hywind Scotland, the world’s first commercial-scale floating wind farm, which has operated since 2017 with five turbines and 30 megawatts of capacity. Other pilot arrays are scattered across European and Asian waters, but total global installed capacity remains measured in tens of megawatts, not gigawatts.
The gap between that reality and commercial viability is significant. Fixed-bottom projects routinely exceed one gigawatt today; floating wind has yet to cross that threshold anywhere in the world. Costs remain substantially higher, partly because floating foundations are more complex to manufacture and install, and partly because the purpose-built supply chain barely exists yet.
Industry experts are candid about the technology’s readiness. The engineering works — Hywind Scotland has demonstrated that — but operating at small scale and operating economically at large scale are very different problems. The financial and logistical infrastructure needed to support commercial floating wind development still needs to be built.
Why deeper water changes everything
The case for floating wind rests on simple geography. Fixed-bottom foundations become uneconomical at water depths beyond roughly 60 meters — the steel structures required grow prohibitively large and expensive. Yet some of the world’s strongest and most consistent offshore wind resources lie in waters far deeper than that.
The US West Coast, Japan, Norway, and parts of the Mediterranean sit on continental shelves that drop away quickly from shore, placing their best wind resources effectively off-limits to conventional turbines. Floating technology removes that constraint, unlocking resource potential that could be measured in hundreds of gigawatts globally.
Accessing those resources introduces genuine engineering complexity. Floating platforms must be moored dynamically to the seabed using anchoring systems that allow controlled movement while maintaining position. Electrical cables connecting turbines to each other and to shore must flex without fatigue. Substations, in some configurations, may need to float as well. Every element adds cost and introduces failure modes that fixed-bottom developers never had to manage.
The risk profile of a floating project at an equivalent early stage of development is therefore meaningfully higher than it was for fixed-bottom. That’s not an argument against proceeding — it’s an argument for proceeding carefully.
Building the stepping stones: what the path forward looks like
Industry experts advocate a staged development pathway that mirrors fixed-bottom’s historical trajectory. The sequence runs from small pilot arrays — projects of perhaps 50 to 150 megawatts — through intermediate-scale developments in the 500-megawatt range, before graduating to full commercial farms. Each stage generates operational data, refines installation methods, and demonstrates bankability to increasingly cautious lenders.
Government policy has a critical role in making those early stages viable. Pilot projects rarely pencil out on merchant economics alone; targeted support mechanisms — contracts for difference, capital grants, or ringfenced auction tracks — can bridge the gap between current costs and commercial viability while the technology matures.
Supply chain development must run in parallel. Ports capable of assembling floating foundations, specialized installation vessels, and component manufacturers with floating-specific expertise don’t yet exist at the required scale. Building that infrastructure takes time and investment, and it can’t wait until the first gigawatt-scale projects are ready to proceed. Every completed project becomes a proof point — for regulators, financiers, and insurers — that the technology performs as modeled and that costs are moving in the right direction.
Lessons the sector cannot afford to skip
The temptation to accelerate is understandable. Climate targets are urgent, resource potential is substantial, and investor appetite for clean energy assets remains strong. But the history of energy infrastructure includes numerous examples of technologies pushed to scale before they were ready, with predictable results: cost overruns, technical failures, and the erosion of investor confidence that can set a sector back by years.
Fixed-bottom offshore wind benefited specifically from not skipping steps. Each incremental project caught problems early, when they were still manageable — developers learned how foundations behaved in real sea conditions, how installation vessels could be optimized, and how long-term maintenance requirements differed from initial projections. That accumulated knowledge is what made rapid scaling possible later.
Experts are realistic about the timeline. Reaching cost-competitive floating wind at meaningful scale is likely a 2030s story in optimistic scenarios, and only if the intermediate steps are taken seriously in the years immediately ahead.
The stepping stone model is sometimes framed as a constraint, a frustrating slowness imposed on a technology the world needs urgently. It’s better understood as the opposite: the most reliable route available to an industry that can’t afford to fail. Each stone laid carefully makes the next one easier to place — and eventually, the crossing becomes possible.
The projects commissioned over the next five to ten years will determine whether floating wind fulfills its potential or stalls at the demonstration stage. Watch for intermediate-scale arrays moving from planning to construction, for supply chain investments that signal long-term commitment, and for the cost curves that will tell the real story of whether the stepping stone model is working. The foundation is being laid. What gets built on it remains to be seen.