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The practical comparison therefore turns on six questions: how each resource varies, how large and mature its technology base is, what the available cost evidence actually measures, and how projects fit particular seabed, weather, environmental and grid conditions.
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What each technology captures
Tidal-stream turbines use moving water
Tidal-stream systems generate electricity from the kinetic energy of tidal currents. Turbines can be fixed to the seabed or suspended from floating structures anchored to it. Developers normally install multiple machines as an array, then connect the array to export cables and the electricity grid.
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Offshore wind uses atmospheric wind
Offshore wind turbines convert the aerodynamic force of wind into electricity. Projects may use foundations attached to the seabed in shallower water or floating platforms in deeper water. Turbine ratings in the current commercial fleet are much larger than those typical of tidal devices, and wind farms can contain dozens or hundreds of machines spread over a large area.
Wind is variable and forecastable only within limits. Weather systems can produce long periods of high output or low output, and the timing is not locked to a celestial cycle. Offshore wind’s advantage in this comparison is not perfect predictability but its extensive deployment, supply chain and operating record.
Wave converters extract surface motion
Wave power is not a smaller form of tidal power. Wave-energy converters harvest the up-and-down, back-and-forth or pressure changes associated with surface waves. Designs include different floating, hinged, oscillating and point-absorber arrangements, each with its own mooring, survivability and maintenance requirements.
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1Scan for outdated or missing drivers - takes under a minute2Repair Windows errors before they cause bigger problems3Fix the driver behind crashes, sound loss and screen glitchesWave conditions depend on storms, wind fields and the distance over which waves have travelled. UK government guidance published in 2013 said wave power was more predictable than wind and tended to increase in winter. That statement is historical guidance, not a current quantitative performance comparison for every wave device or site.
Predictability: a timetable, not a guarantee of constant power
Tidal timing is the clearest differentiator. The gravitational cycles that drive tides can be calculated years ahead, allowing operators to forecast when a particular site should reach ebb or flood current. The 2013 UK guidance described tidal-stream energy as “predictable and consistent,” but its age matters: the sentence does not establish modern fleet-wide performance.
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Prediction does not remove variability. Current speed changes continuously during each tidal phase, and slack-water periods can reduce production. The timing and strength of currents also vary between locations because of bathymetry, coastline shape and local flow interactions. Maintenance outages, cable faults and curtailment can further reduce delivered electricity.
Offshore wind forecasts are updated from weather observations and numerical models. They can be accurate over short horizons but become less certain farther ahead. Wave forecasts face similar weather uncertainty, with additional dependence on swell arriving from distant storms. Seasonal patterns can help planning, yet neither wind nor waves follows a fixed daily schedule.
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For a power system, tidal output can complement variable wind by filling some known intervals, but it cannot be treated as firm capacity without storage, dispatchable backup, interconnection or demand flexibility. Predictable timing improves scheduling; it does not by itself make tidal electricity constant, cheaper or more valuable than every megawatt-hour from another source.
Scale and commercial maturity
The deployment gap is substantial. The US Department of Energy’s Offshore Wind Market Report (2024) counted 68,258 MW of global offshore-wind capacity across 319 operating projects at the end of 2023. That figure describes the operating global fleet at that date and is not a forecast of future construction.
By contrast, the UK Department for Energy Security and Net Zero (DESNZ) stated in its 2025 renewable-energy infrastructure policy that “Tidal stream technologies are in the early stages of commercial development, with 10MW of installed capacity in the UK as of 2022.” The 10MW figure is a dated UK total, not a global inventory.
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DESNZ’s 2025 Energy Innovation Needs Assessment gives a useful device-scale context: tidal-stream machines are typically around 1–2 MW, whereas offshore-wind turbines are around 8–12 MW. A project can still aggregate many tidal machines, but each machine is smaller and arrays have less cumulative operating history. Wave projects use several converter architectures, so a single representative device rating is not supplied by the cited evidence.
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| Technology | Scale evidence | Typical device size cited by DESNZ | Maturity interpretation |
|---|---|---|---|
| Tidal stream | 10 MW installed in the UK in 2022 | About 1–2 MW per device | Early commercial development |
| Offshore wind | 68,258 MW globally across 319 operating projects at the end of 2023 | About 8–12 MW per turbine | Established deployment-scale comparator |
Installed capacity is not the same as annual energy production, and project counts do not reveal whether every machine has operated continuously. They do, however, show why offshore wind has deeper experience with construction, financing, maintenance vessels, supply chains and grid integration than tidal stream.
What the published load-factor figures do—and do not—show
DESNZ used the following figures in its 2025 calculation for the 2026–27 Renewables Obligation:
| Technology | Load factor used | How DESNZ characterised the evidence |
|---|---|---|
| Offshore wind | 39.9% | Weighted historical generation data |
| Tidal stream | 14.1% | Weighted historical generation data |
| Wave | 2.9% | Assumption based on internal discussions |
These percentages are administrative assumptions for that scheme and period, not results from one controlled test using identical sites, equipment, financing or weather. They cannot establish a universal engineering ranking. A load factor is the energy generated over a period divided by the energy that would have been produced if the plant had operated at full rated output throughout; it is influenced by resource quality, design, downtime, grid constraints and the age of the fleet.
Why a simple cost ranking would mislead
No current source cited for this comparison supplies a fully aligned cost series for tidal stream, fixed-bottom offshore wind, floating offshore wind and wave power in the same geography and price year. A claim that one technology is simply “cheapest” would therefore hide assumptions that materially change the result.
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DESNZ’s levelised-cost-of-electricity work defines LCOE as the average lifetime cost per megawatt-hour generated. Generic estimates include construction, operation and decommissioning. They are not quotations for a particular project. DESNZ’s cover note warns that actual projects can differ significantly from generic figures and highlights uncertainty for nascent technologies, where developers have limited cost data available.
The 2023 DESNZ work separates demonstration, first-of-a-kind and nth-of-a-kind projects. Those categories represent different stages of learning, supply-chain scale and financing risk. Combining them into one number would make a demonstration device appear directly comparable with a mature wind farm even though their capital costs, contingency allowances and failure risks are different.
When reading any LCOE table, align at least these variables before drawing a conclusion:
- Price year, currency and country or market;
- Fixed-bottom versus floating offshore wind;
- Demonstration, first-of-a-kind or nth-of-a-kind maturity;
- Capacity factor and expected availability;
- Plant life, discount rate and financing structure;
- Whether transmission, port upgrades, balancing and decommissioning are inside the system boundary.
The 2015 International Ocean Energy Systems (OES) LCOE assessment can provide historical context about development pathways, but it is too old to establish current deployment status or present-day costs. Its figures should not be used as a current league table.
Siting, infrastructure and operations
Tidal-stream site constraints
Tidal arrays need strong, repeatable currents and a seabed or mooring arrangement that can withstand those flows. Channels and straits can offer excellent resource conditions but may also be busy navigation routes, ecological corridors or difficult places to install and service cables. Subsea access, weather windows, vessel availability and export-cable landing points can dominate practical design choices.
Floating tidal structures can ease some seabed installation work, yet they still require anchors, moorings and dynamic cables. Fixed seabed turbines avoid some motion-related cable challenges but transfer structural and installation loads to the seabed. Neither configuration removes the need for a suitable grid connection.
Offshore-wind site constraints
Wind farms need adequate wind speeds, seabed conditions compatible with foundations or floating moorings, construction ports and a route to shore. Larger turbines can reduce the number of machines for a given project capacity, but they impose heavy-lift, blade-transport and component-replacement requirements. Floating wind expands the potential depth range while adding mooring, anchoring and dynamic-cable complexity.
Wave-energy site constraints
Wave devices must survive repeated loading and extreme storms while remaining productive in ordinary seas. Moorings, array spacing, access for inspection and the route for subsea cables all affect economics. A location with powerful waves may also have severe survivability demands, so the best resource is not automatically the best project site.
Environmental evidence and permitting
All three technologies require marine spatial planning, environmental assessment and monitoring. Tidal turbines add questions about collision risk, underwater noise, altered flow and interactions with fish, marine mammals and seabed habitats. Because commercial tidal-array deployment remains limited, the evidence base for ecosystem effects is less extensive than the operating record for offshore wind.
That limitation does not prove that tidal arrays are harmful or harmless. It means impacts must be assessed at the proposed location, with baseline surveys, construction controls and post-installation monitoring where regulators require them. The same site-specific principle applies to wind foundations, floating moorings, cables, vessel traffic and wave-device arrays.
Project developers also have to account for cumulative effects: several nearby arrays may change navigation patterns, fishing access, sediment conditions or the combined level of underwater noise even when each individual project meets its permit conditions.
How to choose the right comparison for an energy plan
- Define the service required. Decide whether the project is intended to provide bulk annual energy, predictable production windows, local supply resilience or a demonstration of a new marine technology.
- Characterise the site. Measure current speeds and directions for tidal projects, wind distributions for wind farms, or wave height, period and direction for wave devices. Include extreme conditions, not only average resource.
- Check infrastructure early. Identify suitable ports, installation vessels, mooring or foundation logistics, cable landfalls and available grid capacity before comparing devices.
- Match the maturity assumption. Compare a commercial offshore-wind project with a tidal or wave demonstration only if the purpose is to understand innovation risk; use separate first-of-a-kind and mature cases for financial analysis.
- Model the whole system. Include variability, forecasting error, curtailment, storage, balancing, transmission and decommissioning. A resource with predictable timing may reduce some forecasting uncertainty without eliminating the need for flexibility.
- Plan environmental monitoring. Build site-specific baseline studies and adaptive monitoring into the schedule and budget, especially where commercial operating evidence is sparse.
Bottom line
Tidal stream’s defining advantage is a forecastable production pattern from moving water, while its defining limitation is early commercial maturity and a much smaller installed base. Offshore wind offers the strongest evidence of large-scale deployment and operating experience, but its weather-driven output is less precisely timed. Wave power is technologically separate from both, with diverse converters and a less-developed commercial record. Treat predictability as one system attribute—not a promise of constant generation—and treat cost figures as conditional estimates whose meaning depends on technology maturity, finance, site and system boundaries.
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