A new study carried out by researchers at the US Department of Energy’s National Renewable Energy Laboratory (NREL) and General Electric Research has used conceptual designs of offshore wind turbines to assess how their drivetrains could change in the near future to produce more power while lowering costs.
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‘Offshore wind turbine manufacturers often adopt conservative choices to mitigate risk. Nobody likes to rock the boat,’ said Garrett Barter, who leads the Wind Systems Engineering research programme at NREL. ‘If they find a technology that works, they keep using it while increasing turbine size. However, the size of wind turbines has increased so much that manufacturers might have to change things soon and the drivetrain is one of the things under scrutiny.’
Barter and his colleagues designed conceptual offshore wind turbines to provide the fairest comparison among drivetrain technologies. A wind turbine’s drivetrain is composed of a gearbox and a generator – the components required to produce electricity. The gearbox is responsible for connecting the low-speed shaft attached to the turbine blades to the high-speed shaft attached to the generator.
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The drivetrain-generator configuration directly affects the overall performance of the wind turbine, as well as the cost. The purpose of the research was to determine which drivetrain technology would be the most cost competitive as the size of the wind turbine increased and whether the answer is the same for fixed-bottom and floating foundations.
Wind turbines are powered by either of two types of drivetrain. One, referred to as geared, uses a generator connected to a gearbox, which can be a high-maintenance component because of its many moving parts. The other, a direct-drive, requires larger generators, which traditionally means larger rare earth magnets, which can be expensive.
The study also considered direct-drive superconducting generators, which use superconducting magnets kept at very low temperature and don’t rely on rare earth materials. This technology is commonly found in MRI machines but hasn’t yet been industrialised for commercial wind turbines.
The current fleet of wind turbines off the US coastline can generate more than 40 megawatts of electricity, but the goal of the federal government is to increase that number significantly – to 30 gigawatts by 2030. Such a dramatic increase in deployment goals, along with market pressures, are pushing manufacturers to design larger, more powerful turbines.
The average offshore wind turbine capacity installed in 2021 was 7.4 megawatts, according to the Offshore Wind Market Report, and the number is trending upwards.
Pietro Bortolotti, who also worked on the project, said that wind turbines with a 15-megawatt capacity are in various stages of development, but those adopting a direct-drive configuration require generators that ‘get very big and very heavy very quickly at these extreme scales. If we are really going to move beyond 15 megawatts, is a direct-drive generator going to be a burden? Is it going to be a bottleneck? And if so, are there alternatives or technologies out there that maybe we can switch to facilitate that kind of growth?’
To determine the optimal designs for more powerful turbines, the researchers conceptually designed three drivetrain technologies at five different powers, ranging from 15 megawatts to 25 megawatts for both fixed-bottom and floating foundations. Software developed at NREL called the Wind Plant Integrated Systems Design and Engineering Model allowed the researchers to create 30 unique design points.
The design with the lowest levellised cost of energy (LCOE) coupled a medium-speed gearbox to a permanent-magnet synchronous generator (PMSG). The LCOE for this technology is estimated to be as much as seven per cent lower for both fixed-bottom and floating designs compared to a more common direct-drive configuration, provided the gearbox doesn’t significantly increase maintenance costs. The analysis assumed that maintenance costs are identical across drivetrain-generator technologies and constant across the different power ratings, but LCOE is quite sensitive to maintenance costs. Between the PMSG and superconducting direct-drive solutions, the latter generated LCOE savings ranging between two per cent and five per cent, depending on the rating. Superconducting generators were more beneficial in floating wind turbines than in fixed-bottom ones.
‘With these design concepts, because none of these have actually been built, the medium speed looks pretty good from an LCOE point of view,’ Barter said. ‘But if we start saying well, medium speed might have a higher maintenance cost than the direct-drive ones because there is a gearbox, we don’t know how much that increase in maintenance cost is going to be. Since we don’t know exactly what the difference is or what the maintenance burden of a novel superconducting generator will be, that’s where the caveat is. Superconducting generators raise similar questions around maintenance and reliability but also offer a promising alternative for direct-drive configurations.’
The US Department of Energy is partially funding NREL’s efforts toward developing and building a lightweight superconducting generator. For deployment in deeper ocean waters, such as in some areas along the Atlantic Coast and throughout the Pacific Coast, wind turbines will need to be constructed on floating platforms, so weight becomes an issue.
‘For floating offshore wind, the amount of weight that you have at the top of the tower is really critical to keep as under control as possible,’ Barter said. ‘If we could develop some of these new generator technologies, maybe that would make floating offshore wind more economical.’
The research has been published in Applied Energy.
