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Short answer: tidal-stream energy uses submerged turbines in fast-moving tidal currents, offshore wind uses wind turbines at sea, and wave power converts the motion of surface waves. Tidal timing is highly predictable, but tidal output still rises and falls through each cycle. Offshore wind is vastly more deployed and commercially mature in the available evidence. Wave power uses a separate family of converter designs and has less established deployment data.
The fairest comparison therefore depends on more than predictability. Scale, operating history, device size, financing assumptions, grid connection, marine conditions and site-specific environmental evidence all materially affect the result.
What each technology actually captures
Tidal-stream energy
Tidal-stream systems extract kinetic energy from water moving with the tide. Turbines may be fixed to the seabed or suspended from floating structures anchored to it. Arrays also require subsea cables, export cables and a grid connection.
Seabed topography can accelerate water through channels, straits and inlets, making those locations attractive. The resource has a regular astronomical driver, so the timing of high-flow and low-flow periods can be forecast years ahead. That does not mean a turbine produces at its rated output continuously: velocity changes during every tidal cycle, and the usable resource varies from site to site.
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Offshore wind
Offshore wind turbines convert the kinetic energy of moving air into electricity. The cited market evidence treats offshore wind as the deployment-scale comparator: projects use large turbines, extensive arrays, subsea collection systems and export connections. Fixed-bottom projects are installed in shallower water, while floating projects use moored platforms in deeper water.
A cost estimate for floating offshore wind cannot be treated as a cost estimate for all offshore wind. Foundation type, water depth, port requirements, turbine rating, financing and construction conditions can change project economics substantially.
Wave power
Wave-energy converters harvest the motion of surface waves rather than a horizontal tidal current or wind stream. Designs include different kinds of oscillating, floating or shoreline-connected devices, so “wave power” is not one machine architecture. Deployment depth, wave climate, mooring loads, survivability and the method used to bring power ashore differ by design.
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UK government guidance published in 2013 said wave power is more predictable than wind and tends to increase in winter. That is useful historical context, not a current quantitative performance comparison for every wave technology or site.
Predictability is useful, but it is not dispatchability
Tidal timing is the clearest advantage of tidal stream. Operators can forecast when currents will strengthen and weaken, allowing better scheduling of maintenance, storage and other generators. The forecast describes timing; it does not remove the daily and fortnightly variations in current speed.
Actual tidal generation depends on local bathymetry, turbulence, water depth, device orientation, turbine power curves, array spacing and downtime. A predictable lull is still a lull. Tidal stream should therefore be described as predictable variable generation, not as constant or automatically dispatchable power.
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Offshore wind output is governed by weather systems. Forecasting has improved, but wind speed and direction can change over minutes to days, and prolonged low-wind periods remain possible. Wind farms can produce at night and in winter, yet their output is not tied to a fixed astronomical timetable.
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Wave conditions are linked to winds over the ocean and can persist after the local wind changes. Wave output is variable as storms and swells arrive and decay. The 2013 UK guidance’s statement that wave energy is more predictable than wind should not be converted into a universal claim that wave power is steadier, firmer or more valuable than tidal or wind generation.
How deployment scale and maturity differ
The strongest evidence gap between the technologies is commercial scale. The UK’s 2025 National Policy Statement for renewable energy infrastructure (EN-3), section 2.11.3, states: “Tidal stream technologies are in the early stages of commercial development, with 10MW of installed capacity in the UK as of 2022.” The figure is a dated UK total, not a global inventory.
By contrast, the US Department of Energy’s 2024 Offshore Wind Market Report recorded 68,258MW of global offshore-wind capacity across 319 operating projects at the end of 2023. That report tracks the global fleet through 2023 and US developments through May 31, 2024. Its figure is not directly comparable with the UK tidal number because the geography, technology and reporting scope differ, but it illustrates the order-of-magnitude difference in operating fleets.
| Indicator | Tidal stream | Offshore wind | Wave power |
|---|---|---|---|
| Recent installed-capacity figure in the cited evidence | 10MW in the UK as of 2022 | 68,258MW globally across 319 operating projects at the end of 2023 | No current, comparable global total established |
| Typical device size cited by DESNZ | About 1–2MW per device | About 8–12MW per turbine | Not stated as one representative size because converter designs vary |
| Commercial position | Early commercial development | Established deployment-scale technology in the cited evidence | Multiple converter approaches with less established fleet evidence |
Device rating is not the same as project output. A 10MW tidal array made from several 1–2MW machines has different construction, maintenance and cable requirements from a wind project using 8–12MW turbines. Wave projects can also combine many smaller converters, but their system architecture depends heavily on the chosen design.
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For the UK’s 2026–27 Renewables Obligation calculation, the Department for Energy Security and Net Zero reported a 39.9% offshore-wind load factor, a 14.1% tidal load factor and a 2.9% wave load factor. These are policy-calculation assumptions, not the result of one controlled engineering test.
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| Technology | Figure | How the source characterises it |
|---|---|---|
| Offshore wind | 39.9% | Weighted historical generation data used for the 2026–27 Renewables Obligation calculation |
| Tidal stream | 14.1% | Weighted historical generation data used for the same policy calculation |
| Wave power | 2.9% | Assumption based on internal discussions for that policy calculation |
Because the evidence bases differ, these percentages cannot establish a universal performance ranking. They also do not describe every country, site, project vintage or future machine. A load factor is the average generation over a period divided by the maximum possible generation at continuous rated output; it does not show when electricity arrives. Tidal electricity may have a lower average in this dataset while still offering better timing forecasts than weather-dependent generation.
Why cost comparisons are easy to misread
Levelised cost of electricity (LCOE) expresses the average lifetime cost per megawatt-hour generated. DESNZ describes generic plant estimates as covering construction, operation and decommissioning. That is a useful common framework, but a generic LCOE is not a quotation for a particular project.
The department’s 2023 LCOE work separates demonstration, first-of-a-kind and nth-of-a-kind projects. Those categories represent different learning stages. Demonstration equipment carries technology and supply-chain risk; a first commercial project may still pay a premium for bespoke engineering; an nth-of-a-kind fleet can benefit from repeat manufacturing and established installation methods.
Early tidal and wave estimates are especially uncertain because there are fewer commercial arrays, less long-term operating data and limited access to developer cost information. Offshore-wind estimates also vary by foundation type and project conditions. A floating-wind estimate should not be used as a proxy for fixed-bottom wind, and neither should be compared with a tidal estimate unless the assumptions are aligned.
A defensible comparison must match:
- price year and currency;
- country, water depth and site conditions;
- financing assumptions and discount rate;
- capacity factor and availability;
- plant life, replacement schedule and decommissioning;
- system boundaries, including transmission and port infrastructure; and
- technology maturity, from demonstration to repeat commercial build.
Without that alignment, declaring one technology the cheapest creates false precision. The available evidence does not support a single current cost winner across tidal stream, fixed-bottom offshore wind, floating offshore wind and wave power.
Sites, infrastructure and operations
Tidal-stream sites
Tidal arrays need strong, sustained currents, suitable seabed or mooring conditions, navigational clearance and a practical route to shore. High-flow channels can be attractive electrically but difficult operationally: fast water increases loads on rotors, foundations, cables and vessels. Maintenance windows are constrained by the same tides that create the resource.
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Subsea export cables must be protected from fishing gear, anchors, seabed movement and fatigue. Array design has to balance energy capture against wake interactions and access for inspection. Because commercial experience is limited, construction and maintenance assumptions can dominate a project model.
Offshore-wind sites
Wind farms need adequate wind speeds, lease or consented sea space, suitable foundations or floating moorings, installation ports and grid capacity. Larger turbines can reduce the number of machines and inter-array connections for a given project rating, but each unit is heavier and creates demanding logistics.
Distance from shore affects export-cable length, electrical losses, vessel time and the feasibility of repair. Floating projects can access deeper water but add platform, mooring and anchoring systems.
Wave-energy sites
Wave converters must survive repeated cyclic loading, severe storms and corrosion while remaining productive in ordinary seas. Moorings, subsea cables and access arrangements vary by converter type. A location with a large theoretical wave resource may still be unsuitable if survivability, maintenance or grid connection costs are excessive.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Environmental evidence and consenting
All three technologies occupy marine space and require location-specific assessment. Relevant questions include effects on seabed habitat, marine mammals, fish, birds, navigation, fishing, sediment movement, underwater noise and electromagnetic fields from cables. The importance of each issue depends on the device, array layout, construction method and receiving environment.
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Tidal stream has a shorter record of commercial-scale operation than offshore wind. The UK’s 2025 infrastructure policy therefore notes uncertainty about possible ecosystem impacts while deployment remains limited. That uncertainty is not proof of harm, nor proof of no harm; it is a reason to establish a baseline, monitor the site and adapt operations when evidence warrants it.
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Wave devices and wind farms likewise require environmental impact assessment and consent, but evidence from one technology cannot automatically be transferred to another. A wind-turbine foundation, a tidal rotor and a floating wave converter interact with water, seabed and wildlife in different ways.
Which technology fits which planning need?
Choose tidal stream when timing and a suitable current resource matter most
Tidal stream is attractive where surveys confirm strong currents, the seabed or mooring plan is workable, and a developer can tolerate early-commercial technology risk. Its forecastable production pattern can complement weather-dependent generation, but storage, interconnection or other generators may still be needed during predictable low-flow periods.
Choose offshore wind when scale and deployment experience dominate
Offshore wind is the more established option in the cited fleet data. It offers much larger turbines and a mature project-development ecosystem, although projects remain exposed to permitting, supply-chain, financing, port and transmission constraints. Its output is forecastable over useful horizons but not scheduled by an astronomical cycle.
Consider wave power only with a technology-specific case
Wave power should be assessed by converter design and site, not by a generic label. Survivability, maintenance access, moorings, cable routing and the evidence behind the expected load factor are central questions. The available figures do not establish a current global deployment scale or a universal cost advantage.
A practical comparison checklist
- Define the service. Decide whether the project is intended to maximise annual energy, provide a predictable production profile, diversify a coastal portfolio or support a local grid.
- Characterise the resource. Use measured current, wind or wave data at the proposed site rather than applying a national average.
- Specify the technology. Record turbine rating, foundation or mooring, converter type, array spacing, cable route and expected availability.
- Align the economics. Compare the same currency year, discount rate, plant life, capacity-factor method, transmission boundary and maturity stage.
- Test operations. Include weather and tide access windows, vessel availability, spare parts, corrosion, cable faults and replacement strategy.
- Complete site-specific consent work. Establish ecological baselines, consult marine users and define monitoring triggers before construction.
- Model the grid profile. Represent the timing of output, not only annual megawatt-hours; predictable variation is still variation.
Bottom line for energy planners
Tidal stream, offshore wind and wave power are complementary marine technologies, not interchangeable products. Tidal stream’s distinctive benefit is forecastable timing from the tidal cycle. Offshore wind’s decisive advantage in the cited evidence is scale and operating maturity. Wave power remains a design-specific proposition whose performance and deployment cannot be inferred from tidal turbines or wind farms.
The most responsible comparison reports the technology, site, maturity stage and evidence method alongside every number. It treats the UK 10MW tidal figure as a dated national snapshot, the 68,258MW offshore-wind figure as a global fleet count through 2023, and the 39.9%, 14.1% and 2.9% figures as policy assumptions built from different evidence. That level of qualification is essential when decisions involve long-lived marine infrastructure.
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