Overview of Floating Offshore Wind (Text Version)
This is the text version for the "Overview of Floating Offshore Wind" video.
Tiffany speaking: Hello, everyone. Welcome to this webinar overview of floating offshore wind. My name is Tiffany Byrne and I will be moderating the webinar. Before we introduce the speaker, I want to cover some logistics to make sure you get the most out of the webinar. Today, we have over 500 participants who have registered therefore, it will not be possible to capture all the questions you may have in real time.
As such, all of your lines will be muted. There is a chat feature within your webinar control that you can use to pose questions throughout the duration of the webinar. We're going to gather all the questions offline and answer them in a written Q&A document which will be disseminated later with a final presentation document. The webinar audio will also be recorded and it is our intent to post it with a presentation on YouTube after everything is complete. We will send an e-mail to the webinar registrants with the finalized YouTube webinar link and Q&A document.
Now, I would like to start the webinar, which is scheduled to run for about one hour. We're right on time. Our speaker today is Walt Musial, who is a principal engineer and leads the offshore wind research platform at the National Renewable Energy Laboratory – also known as NREL – where he has worked for over 31 years. In 2003, Walt initiated the Offshore Wind Energy Research Program at NREL, which focuses on a wide range of industry needs and critical technology challenges. Today, Walt will be providing you with an introduction to the emerging energy field of floating offshore wind. Take it away, Walt.
Walt speaking: Thank you, Tiffany. So, this is Walt Musial, again, and today, I'm going to do an overview of floating offshore wind. I want to make sure everybody understands that I'm trying to speak to multiple audiences. I think that this is – the intent of this presentation is to reach people who may be familiar with wind power and possibly offshore wind but maybe haven't seen much at all about floating wind. But if you're new to the field, there's some introductory material that I'm gonna cover.
Change to slide 2:
And if you're new to the field of wind, there's a little bit of that, but I can't promise that some of the material might be passed. I skipped some of the introductory material just for the sake of time. So, I'm considering this an overview of the new technology of floating and we'll get right into it.
Change to slide 3:
I just want – I just put my bio in there. I won't cover that. Tiffany did a great job just now, but if you want to go back to this, it'll be there.
Change to slide 4:
I've been working with floating concepts for about – since I've started the offshore wind program, but it's really just starting to take off now. I want to start with this first slide, which is really an introduction to the wind turbine itself. And so, let's look at that to start. The wind turbine configuration is a horizontal axis, three-bladed upwind machine. And I'll break that down for a minute. All commercial wind turbines fit this description except for a few that have been built in the downwind configuration recently.
But, in general, this is what they look like. The upwind configuration means they face into the wind and the wind passes through the rotor before it passes through the tower. And the wind creates torque, which is the rotational force that spins the low-speed shaft. And we need to turn that torque into electricity. To do that, generally, the land-based machines have a gear box, which is the cutaway that you're seeing in this picture. The gear box speeds up that low-speed rotation and directs it into the generator where electricity is produced.
So, the machines all work this way. There's wires that run down the tower and then, multiple turbines are connected to form what most people know as a wind farm. We all call the wind farm a wind plant or a project. Some of these terms are interchangeable. So, if you hear them, don't get too confused.
It's just sometimes, it's just a matter of where you – what you got used to. The generating capacity of the modern utility scale offshore wind farms are now approaching the same scale as conventional coal, natural gas, and nuclear power plants. So, we're talking about large-scale energy production all using these turbine configurations. I want to add, though, that offshore wind turbines sometimes have eliminated the gear box. That's to reduce the part count.
So, you'll hear or see turbines that are called "direct drive machines" or "direct drive generators". That means the low-speed shaft connects directly to the generator without a gear box. Those require a lot of technology in the system – in the drive train system – but they're now becoming the main – one of the main configurations that is used to offshore wind. And I'm gonna say more about the turbines as we get forward here.
Change to slide 5:
The first project in the United States was the 30-megawatt Block Island Wind Farm, and it's shown here in this figure. It's comprised of five six-megawatt turbines that were originally Alstom machines. It's called the GE Haliade Turbines – six megawatts each. And it was installed in 2016 off of Block Island. To this date, this is the only wind farm in the United States offshore.
The wind plant is – and you can see it in the picture, especially the one to the right – in relationship to where it is on Block Island. These turbines can provide enough power for up to 16,000 homes in Rhode Island. And if you can see the island of Block Island, there aren't 16,000 homes there. So, most of this power is used on the mainland. So, when they built this wind farm, there was a cable that was brought to the mainland shore of Rhode Island and it comes ashore at Narragansett and powers – most of the power powers the homes in that region.
So, this is a very small wind farm. It was the first one and it's still operating, of course. But there's now over 26,000 megawatts of offshore wind that are currently planned in the United States, and this includes – if the way you look at it can be through the regulatory lens and the leasing system or through the policy lens in which states have committed specifically to build offshore wind power in their region. And a lot of this is happening – most of this is happening on the East Coast, but it's starting to spread into other areas where we might see floating wind and this is a floating wind presentation and I'll get to that in just a minute.
Change to slide 6:
So, more basics. So, how much power does a Block Island wind turbine make? These are six-megawatt wind turbines. They're big for land-based machines but today, they're actually becoming small in terms of an offshore project. And you can see this picture that was taken in 2016 off a boat and these are the turbines.
One of these turbines would have a power curve that looks like the curve on the right side. This is the how all turbines generally look in terms of their ability to produce power – where the wind starts up – and this scale is in meters per second. If you're not used to meters per second, I put the conversion factor at the bottom. So, 2.24 miles per hour equals 1 meter per second. So, at three meters per second you're roughly seven miles per hour where you start to get enough wind to cut in.
That's where it starts to ramp up. Now, it goes up in a cubic relationship in region 2 of this power curve until it reaches a point around 11 meters per second where you reach rated power. That's the rating on the generator, at which point, the turbine can't generate any more power so, its starts to regulate power using the pitch control system throughout the rest of the power curve and that's called region three. And that continues regulating power by pitching the blades to feather as they get further and further toward what's called "cut out" and that's the 25 meter per second wind speed, at which point – that's about 56 miles per hour – at which point, there's just not enough time to when the wind blows that hard to make it make sense for the turbines to stay on so, we shut the machines down and then, the machines are furled there on after that up and through extreme winds. And this site could see hurricane wind speeds but the machines will be off at that time – and you can see why following this power curve.
Change to slide 7:
So, now I'm just – I've been just talking about offshore fixed bottom machines and that's what these machines are. You can see those yellow substructures are attached to the bottom of the sea in about 30 meters of water depth. These are called fixed bottom machines. So, a floating machine is quite different but a lot the same.
So, this next picture kind of shows some of the parts of the wind turbine that are above the water line. So, a fixed bottom offshore wind turbine and a floating offshore wind turbine might look at lot the same depending on the substructure that's used, and you can see this turbine on the right is actually a floating machine. It looks a lot like the fixed bottom machines because you can't really tell if it's fixed to the bottom. The fixed bottom machines that we use are a lot the same as land-based machines, actually, but they're bigger and they have much more complex support structures that have to be installed out in the ocean, and they're designed to withstand the harsh conditions of the marine environment – like, corrosion and things that happen. And they have to be maintained in that environment as well.
The floating turbines look similar but the big difference is that they're supported from the bottom by buoyant substructures. Those are moored to the seabed. So, they're floating, but they're moored through cables and lines that connect to anchor systems. Before I move on, I want to just clear up a couple things about terminology because people get confused when I refer to the support structures or the – which is also – some people call those the foundations. The substructure is actually a part of the support structure.
The substructure is the part that – a platform that it's attached to. The support structure includes the platform that it's attached to as well as all the mooring lines and the anchor system. And some people might call that the foundation, but the foundation is really just the part that attaches it to the ground. So, hopefully, that terminology will help as we go forward, but I'm using the terminology that the engineers used to design these. So, when we're talking about the platform itself, it's the substructure, and the whole thing itself is called the "support structure", which includes the tower, by the way.
Change to slide 8:
So, when we get into the differences between fixed bottom and floating, there's kind of a cutoff line of depth. They're very depth dependent. Almost everything that's been installed so far has been in depths below 60 meters and therefore has been fixed bottom. The new technology that's emerging for floating is really addressing applications where the depth is above 60 meters and that's shown in this picture. So, you see kind of below the water line, these are artistic views of different types of foundations, different types of substructures.
There's the Monopile, which is the most common, and then, there's 4-Legged Jacket, which is the kind of substructure that you saw in that Rhode Island Block Island picture, and then, beyond that, are these floating systems, and I'm gonna spend more time talking about those in just a minute.
So, looking at this same picture on the right, if you just stick to the fixed-bottom systems, there's 27,000 megawatts installed globally in the fixed-bottom type. And of the floating type, there's only 82 megawatts. So. 03 percent of the total installed capacity is floating. We're just getting started, people. So, that's what this slide is really telling you.
And so, we're excited about the floating industry. The established fixed-bottom industry is already going and I included a few of the leading countries that are installed. Over certain number of megawatts, these are the top seven countries in the world that have installed capacity of offshore wind, but this is all fixed-bottom technology. For floating, we're just getting started.
Change to slide 9:
So, why are we excited about this? It's because 80 percent of the offshore wind resources in the world that could be feasibly developed are greater than 60 meters, which points to this technology. If we use floating technology, we'll be enabling sites that are further from shore, more out of sight than the fixed-bottom systems, and they tend to have better winds. So, the economics and the feasibility of floating is in our favor in a lot of these areas. And we're already starting. We already have 82 megawatts installed but a lot of that is just starting to accelerate right now and we expect that we'll see floating technology at the utility scale – and by that, I mean 600 megawatts to 1,000 megawatts per project by the years 2024.
That's only four or five years away. Some of the areas that are being considered globally are circled on this map and you can see it's the West Coast of the United States, of course, where we've done a lot of looking already. Some of the East Coast and Great Lakes, areas in Europe that are now moving in that direction – South America and then, Asia. So, we are – this is going be a global industry and we're excited about the possibility of moving and adapting the technology for floating technology.
Change to slide 10:
Now, turning back to the United States, we have – this is our map showing two things and I have to apologize. It's an old map. We're using resource data that is old and it's no longer developed using the methods that we use today but it tells my story the way I want to here. You can see the colors represent the good and the excellent resources of the United States, but superimposed on this map is also population densities. And the key point for why are we pursuing offshore wind is the first bullet, which really indicates that the resources match up with where the people live and where the energy gets used.
So, you can see that the – 80 percent of the population of the US lives near the coast. They live in states that's adjacent to a coastal – an ocean or a Great Lake. And that makes it a lot easier to build transmission, to bring that resource and convert it to electricity and bring it to where the electricity's used. As you go offshore, you can also see from this map that the resources – the winds are stronger and they're more consistent. And that gives us more energy and easier to achieve the cost goals that we're shooting for.
Another benefit is that especially in populated areas, it's really hard to find large tracks of land to build big solar arrays or big wind power plants, but offshore, it's much easier to cluster a wind farm into a large area where it's not seen by people on shore and bring that power inland. So, we can build larger projects. By developing this industry, we're going to create a lot of jobs – and, at the end, I have some targets on that – and it's going – it's already revitalizing a lot of the port and coastal manufacturing supply chains that were dormant from the loss of some of the shipping industry and other things that have happened over the years. But some of those facilities do exist and we'll be upgrading them.
Change to slide 11:
So, now, turning – you got another resource map. This is the one we actually use and it's based on wind speed. So, the darker red colors represent the higher wind speeds and the best sites are obviously where the wind speeds are strongest, but also, where the water's not too deep. So, even with floating wind, we don't want to exceed certain depth limits, so at least we're basing our resource assessments on a certain depth limit and we've set these technology filters to do that. So, this map is only showing you wind resources in areas where the water depths are less than 1,000 meters deep and where the wind speeds are greater than 7 meters per second in velocity.
And then, there's a few conversions there in case you'd like to speak in miles per hour or knots. 7 meters per second is 15.7 miles per hour and 13.6 knots. So, given these assumptions, the US wind potential is approximately two times greater than the US electric energy use. So, there's a lot of resource there and offshore wind can contribute a lot to our total generation portfolio. Of course, it's not the only thing that we'll rely on, but it's something that – especially in coastal communities – we can use to supplement renewable power.
Change to slide 12:
So, there's – I don't have a lot on regulatory, but I do want to show what's happening, and most of this is in the fixed-bottom industry. These are maps that cover the regulatory activity in the United States and most people in the US might be able to recognize that I've sliced out the East Coast and the West Coast and Hawaii here. There's very active leasing going on through the Bureau of Ocean Energy Management, which has regulatory authority over the outer continental shelf, which extends from 3 nautical miles to 200 nautical miles. And over the last approximately eight years, they have granted 15 lease areas in the United States, which gives the developers who own them exclusive site control of up to 25 gigawatts of development capacity. That's what we typically refer to as the regulatory pipeline.
We also have the policy pipeline, which is about the same. It's a little bit more now. BOEM has also identified 13 call areas. Now, a call area is a potential wind energy are that's under public review. It might become a wind energy area or it might not be or it might change in its scope or dimensions. We don't know yet. But we haven't counted the call areas in the regulatory pipeline up to this date.
There's also another category, which are these unsolicited projects that are applications for additional projects that BOEM has received and for any reason, a developer can submit an application for a project, but it does still have to go through a regulatory process that includes, at some attention, to whether there's competitive interest in that area. And I don't have a lot more on the regulatory, but that's something maybe for another topic.
Change to slide 13:
So, in the United States, we have areas where floating might be considered, and this map was drawn in a different way. These are – this was based on our bathymetry and there's two colors here. There's a light kind of aqua color and there's a dark blue. And the light color indicates areas where our cost – technoeconomic models – predict that fixed-bottom technology will be superior and the dark blue indicates areas where the models indicate that floating might be superior. And you can see there's many areas where floating technology might make more sense.
Of course, there's – these boundaries can change as technology changes, but you can see that if you get North of Boston, North of Massachusetts, the shallow water goes away. If you're on the West Coast, there's virtually no shallow water unless it's really close to shore. And in Hawaii, I would say the same thing. The Great Lakes might stand out as having no deep water, but that's not the case. When we did the resource assessment, we eliminated all the deep water because, at the time we did that, the resource for deep water was considered unfeasible for the technology in the Great Lakes at the time because ice flows and freeze-overs in the winter could potentially prevent the current technology from being successful year round. There's been a lot of talk about reassessing that position and the technology for deep water in those conditions is considered possible by many people.
So, in the Pacific region, we have kind of a push toward floating because obviously, there's high water depths requiring that technology. In the North Atlantic, we have high demand because there's a scarcity of shallow sites that are already there and the demand is high. So, we'll probably see floating in the North Atlantic. We might see it there first in the United States. And then, in the Great Lakes, as I indicated, there's likely to be a push toward floating because visual impacts may require further distances, especially in populated areas. So, those are the areas we're looking at. There's certainly arguments for the South Atlantic and the Gulf of Mexico, but both of those regions have lots of shallow water.
Change to slide 14:
So, from the technology standpoint, we're leaning heavily on the oil and gas experience that helped accelerate the first generation of floating wind turbine prototypes, which is kind of – we're passed that point and we're moving toward a pilot stage. But the basic substructures that were used were derived from the oil and gas industry, but we're finding that those criteria that we use to design an oil rig, if you use them alone, they don't result in safe – they can result in safe designs and successful designs, but they can be bulky and expensive. So, the next phase is likely to be an optimized engineering approach which could yield commercial mass-produced, utility scale systems. And so, we're seeing that right now and there's a lot of knowledge transfer and job transfer coming in from the oil industry and you'll see – and if you look – that the oil industry is heavily involved in the early phases of the offshore industry because a lot of those skills transfer directly.
Change to slide 15:
So, the characteristics of the basic floating platform types are as follows. You can see this kind of illustration of three different types. They relate to three platform types that get their static stability through different methods. So, one is a spar, which has a deep draft, but it achieves its stability through ballast weights that's installed very low. The semisubmersible is a low draft system that has a wide footprint on the water plane where it distributes its buoyancy, and this is challenged by high exposures to waves and structure above the water line, because a lot of the steel has to be right at the water line.
For a tension-leg platform – we see that on the far right – that achieves its static stability through mooring line tension, which has a submerged buoyancy tank. And these can be the lightest weight systems, but the problem with these is they're unstable until you hook up the mooring lines and they have very high vertical load mooring line capacity. So, the anchors have to pull up at about 10 times the force of the other 2 – the spars or the semisubmersibles. So, they all have challenges and we're finding that as the industry evolves and works towards optimization, that these challenges can be mitigated by hybrids of the various systems. And we're seeing that.
Change to slide 16:
So, from a surface view, there are two types of platforms that you can see here – or that are shown at least. One's a semisubmersible and one's the spar and they are shown with just – so you can visualize what they look like from the top. You can tell the semisubmersible because you can see the structure; with the spar, not so much.
Change to slide 17:
So, from a – if you look at this illustration, it shows some of the other pieces now, so, I'm gonna focus on the non-turbine equipment. We already talked about floating substructures and the dynamic array cables connecting the turbines create a lot of the infrastructure and cost of the system. Then, there's the mooring and anchor systems that connect the platforms to the bottom and the installation assembly, which is not shown in the drawing, but this is really the equipment that has to be deployed to install all these both in the harbors and out at sea. And then, there's the substations – both offshore and onshore – the export cable that connects between them, and then, there's some costs associated with decommissioning that happens 25 to 30 years after they're installed because that's their expected design life. So, about 75 percent of that capital cost goes into the non-turbine cost.
Change to slide 18:
So, this figure is showing the breakdown of how those capital costs are distributed, and you can see – only about 25 percent of the cost goes to the turbine. The rest of it's made up of all these other things, including the substructure and the electric infrastructure, the assembly and installation, and so on – insurance. And so, focusing on that bigger part of the pie is the best way to lower the system cost or the project cost if we're looking ahead to reduce costs.
Change to slide 19:
So, I'm just gonna go through some parts of the wind farm that we already talked about just so that we have kind of a better technical understanding and the first is the mooring line anchor configuration systems. There's several different types of anchors and I've only shown the drag embedment anchors here, but these mooring lines come down from the system and they connect to the seabed. This is shown at a fairly high depth, but they – and it's showing kind of a hybrid mooring line where you have synthetic mooring line at the top, which doesn't really have much weight to it, and a chain mooring which is how a lot of these platforms stabilize, because they use the weight of the chain mooring to draw the system down and to stabilize it. And so, this is one configuration but it's an example of how it might look. And for those wondering what those lines look like, I put in my colleague, Marco, standing next to a synthetic mooring line.
You can see how big the diameter is. They're huge lines. And this is how we keep the platform from moving around.
Change to slide 20:
And now, if we go to the electrical side, these are additional cables that carry the electricity. So, all of these dots represent turbines. They're connected together and they all aggregate at a substation and, from that substation, an export cable brings the power to an onshore substation through fairly high capacity subsea cables. In the array cables, they're smaller, but they're still big and their voltages are 66 kilovolts. Now, this is a new innovation that allows us to lower the cost of the wind plant.
The electric cable costs will increase as the turbine spacing increases and decreases with turbine size because with fewer turbines – or larger turbines – you need to connect fewer turbines and the cable costs go down. But the exact spacing of these turbines is really a tradeoff between wake losses that happen in between the turbines and array cable costs. So, the larger the spacing, the more cable you need and the more expensive it gets, but you have less energy losses. So, other factors also could play a role – such as navigational safety – and this has been brought up in some negotiations earlier on in among projects that are going in on the East Coast. And so, this is something that needs to be discussed and it's not really part of this discussion here.
Change to slide 21:
But I do want to touch on how turbine spacing is determined and how it might change as projects get bigger. Turbine spacing is based on the rotor diameter. The rotor diameter is the diameter that the blades sweep as they turn around. So, one rotor diameter is, on a big GE machine, is 220 meters. But to create adequate spacing, those machines have to be somewhere between six and eight diameters apart.
I've seen projects as low as 4 diameters, maybe up to 10, but typically in between that, and they have to have adequate spacing so that the wind has a chance to replenish itself as it's being propagated downstream so that the turbines in the back row have wind as well as the turbines in the front row. And so, this is an illustration of how an eight-diameter turbine spacing would look. The array is just a representation of a geometric array where the turbine spacing's not to scale, but it shows how that might look in terms of laying out 8D versus10D. But the – I guess that's all I'll say about that, except for the fact that when we go from these fixed-bottom arrays to floating, we're gonna use the same criteria and the same physics results. There's some advantages that we can talk about but I'm probably not gonna get to that today.
Change to slide 22:
Another thing that I want to talk about in this next slide is the watch circle. That's really accounting for the fact that these turbines can drift within their station and that's because the mooring lines have some slack in them and, as the wind blows, the upwind side will become more taut and the downwind side becomes more slack – as shown in the figure – and they drift around in a circle. Well, how big will that circle be? It really depends on the design. It depends on how long the mooring lines are and the water depth and the design of the mooring system and also, the turbine size.
But you can appreciate that the turbines aren't necessarily exactly fixed in space. They can move in actually six degrees of freedom as they're anchored to the sea bottom and that can affect some things, but generally, the platform's job is to control that motion and to make sure that the turbines are protected from excessive wave action and things that might damage them or cause additional fatigue.
Change to slide 23:
So, all these turbines have dynamic array cables. That means that the turbines are moving. As we said, the platforms are moving, and we have to protect that power cable from bending and breaking because of those turbine motions. So, there's all kinds of protection systems that are involved in the dynamic array cable to protect the static part of the power cable from seeing all those deflections and motions. They help to isolate the cable from those platform motions.
And then, those subsea cables can be buried – which they typically are for fixed bottom systems – or, if it's really deep, they may just be secured with a matressing system or some other means. And that's part of the design.
Change to slide 24:
They all connect to a substation. Now, I don't have a picture of a floating substation because I don't think there is one that has been built yet, but we're working on the same concept as this one. This is one from the London array and it's a fixed bottom substation, but it will look – chances are, it will look very similar to this, but it will have dynamic array cables attached to it. And these are under development right now.
Change to slide 25:
A big part of a floating – and a big difference between floating offshore wind and fixed-bottom offshore wind – is the port and infrastructure requirements. We envision that floating systems will be mostly assembled and constructed at t-side or at a wharf facility and that means that a lot of the assembly and commissioning will happen there, too. That's a good thing, because it will avoid a lot of the labor at sea, which is very expensive and can be more dangerous than labor conducted in the harbor. So, we need wharf facilities that are adequate and they need to be probably be upgraded or built from the existing ones. We need a navigation channel and wet storage that will allow the tow-out of a system with the drafts that are being designed.
And most of the platforms that have been designed so far are semisubmersibles because they gravitate toward low-draft systems that are easily towed out. We need an upland yard for lay down and storage and staging of the parts. We need cranes that have very high capacities – not just in how much they can lift tonnage, but how high it can go. And then, the crews and access for maintenance can be – they don't have to be collocated in the manufacturing ports and they don't have the same restrictions. A lot of these assembly ports need to have no overhead obstructions – such as bridges – so that the whole assembly can be towed out in one piece.
Change to slide 26:
So, for floating operations and maintenance, we see there's two categories that I've divided here. One is small repairs – where the turbine will be boarded directly by the maintenance crews through small ships. If it's major repair, they can be disconnected from the mooring lines and towed into their construction or maintenance facility.
Change to slide 27:
So, now, I want to talk about the path to commercialization, which is something that's underway right now and it's happening more or less organically in the industry. So, the top row here really talks about the prototypes that have already been deployed and there's several of them. They were mostly funded by research programs worldwide. The first one was the high wind one, which is, I think, letter F, which is missing, but it was installed in Norway. But there's been several after that.
That was really to prove the concept of the floating systems. And most of these were very successful and produced the energy that they were expected to produce, but that phase is really over now and we're really entering a pre-commercial phase, which began a while back. We saw a project in 2017 installed by Statoil and now, it's Equinor. The second project of that scale was a 25-megawatt project called Windfloat Atlantic by Principle Power and both of those are shown in the photographs that you see on the left. But there's about 14 projects total, totaling about 229 megawatts that are underway and that are already under construction or have been approved or are about to come online.
And that phase of pre-commercial installation is expected to be complete in the next three or four years. And I think from that, we will see – these are really bank-financed projects but with subsidies. From that, we will see the emergence of the commercial systems, which are really the final – the utility scale arrays. Some of those are being talked about right now and we're talking about arrays that are over 400 megawatts in capacity. And around 2024 is where we kind of see that happening and that's about the same time that we would expect competitive costs – cost competitive with market conditions. And that's kind of the progression that's happening right now.
Change to slide 28:
Leading some of this is what I mentioned earlier – these hybrid systems – which will be hybrids of the three archetypes that was shown in the earlier picture where they achieve and they overcome some of the shortcomings of the other platform types by combining features of the different types of platforms. So, what's needed is, for example, is a low draft to enter the typical port facilities, but a stable platform that can be deployed on station. And some of these concepts that I'm showing here are already in development in part of the pilot projects that are being deployed in the Europe and around the world.
Change to slide 29:
Here's a couple examples of these projects and I don't want to spend a lot of time, but the first project was also Equinor, a 30-megawatt 5-turbine project using Siemens turbines off of Peterhead, Scotland. And here's a picture of one of the turbines from a boat. And this project is operating fantastically, as I understand it. It's achieving capacity factors that are higher than expected. It's doing really well.
Change to slide 30:
This is a brand-new project, Windfloat Atlantic, that was just installed this year. They produced first power on December 31st. 25-megawatt 3-turbine project near Porto, Portugal. And you can see this turbine being towed out to station. No heavy lift vessels necessary to get this on station. And we're waiting anxiously to see how this one performs.
Change to slide 31:
So, now, I want to talk about cost and I want to make sure I don't run out of time doing it so, I just – I'm trying not to rush here, but how do we predict the cost of a floating wind turbine, especially when the commercial systems haven't arrived yet? So, we've been working this question for many years now and I'm gonna try to explain, in a few minutes, just how that's done.
Change to slide 32:
So, only 82 megawatts of floating wind has been installed so far and there have been no utility scale projects built. We've done some studies to show that, at the pilot scale – this is about one-tenth the size of the utility scale – that the costs are at least three times higher than what we think the commercial cost will be and this would be true for a fixed-bottom system or a floating system. It just works out that way because there's a lot of fixed costs that you have to pay for whether the project is big or small. So, the cost estimates that we used to get us to the commercial scale costs of floating wind, we rely on the market data that we get for fixed-bottom systems to validate our system. We use, also, the US Power Purchase Agreements that are being negotiated now.
When we do analysis on those to see if the European projects and the US projects are in the same ballpark. We also fill gaps – there's a lot of gaps, because the fixed-bottom systems and the floating systems don't have exactly the same components, so, we need to get vendor quotes in the areas where they don't. We use developer information that's provided to us. Sometimes, that's proprietary to fill those gaps. And then, we run our geospatial technoeconomic cost models to generate the cost predictions at different stages of technology development for future years. And then, we compare those to inputs that we get from a wide range of industry literature sources that are out there, and everything kind of tends to agree, it seems.
If you want to read some of the publications that have been done, I've put a couple in of recent publications. There's a report that we wrote on the cost modeling of floating offshore wind for the New England Aqua Ventus concrete semisubmersible that was published just in January this past year and then, there was another report that we did for Oregon – this was sponsored by BOEM – to look at the costs of what offshore wind would be, feasible sites in the state of Oregon. And you can access those online.
Change to slide 33:
So, here's what the auction prices in Europe have been doing over the last five years and it's what's gotten people excited. These prices have come down very rapidly – about a 70 percent decline – and that's what's creating the motivation for a lot of the policy commitments that are based on the fact that cost and price are related. So, why are these prices falling? Big part is because technology is improving. Larger turbines are enabling some of the cost reductions.
We're also seeing lower risks because supply chains are maturing and people are just getting more comfortable with the operation of these projects, which are performing as they should be. And through increased competition in the auction process now, we're seeing competition among developers to help bring these projects down. There's other reasons why these prices are falling but those are kind of the big ones. When we compared power purchase agreements in our analysis in the United States for the early projects that are now coming in right now in the United States, we're not seeing a huge penalty between the European prices and the US prices. And you can see the Vineyard Wind Analysis is plotted on this curve and you can see it's right there in the middle of those data.
Change to slide 34:
So, this is kind of a simplification what costs are doing and what we've been – what our models have been showing. You can see that because fixed-bottom and floating share supply chains, turbines and array and export cables, the regulations that we use, the port and infrastructure facilities to a large extent and the O&M and maintenance, can be – they're synergistic with each other, and that's driving floating down along with the fixed-bottom cost. You can see in the bar chart that the models are suggesting that we can hit – and this is not an NREL analysis, but the models that – the $0.05 per kilowatt hour for fixed-bottom offshore is feasible globally by 2025 – some of these projects are coming in without subsidies right now. So, what does that mean for floating? In our models, by 2030, we think, in a lot of the areas where we're deploying, where we want to deploy floating offshore wind, that we can get to $0.06 per kilowatt hour – even below that – if the wind regime is really high.
And so, you can see there's a lag of about five to seven years between the fixed and the floating curve but generally, there's nothing in the floating cost equation that would make floating more expensive, so, we expect the floating cost to converge with the fixed-bottom wind cost over time. And that will probably happen somewhere just after 2030, according to our models. But others might have more aggressive thinking about that. It's possible that that might happen sooner. We'll see.
Change to slide 35:
So, one of the things that is driving this is large turbine, so, I wanted to get to that. This curve shows the expected growth of turbines. We're expecting – we have 12 megawatt turbines in development right now. We expect turbines will get to 15 by 2030. This is like, twice as big as the land-based systems.
Probably even bigger than that. That's conservative. This is being driven by a few different factors. Offshore – there's fewer installation and transportation constraints than there are on land and so, we can do it. But larger turbines lower project costs and that's a given.
We've seen that – we can demonstrate that because it really lowers all of the _____ of substation costs that are incurred through the array cables and the O&M and there's more energy that's produced. So, that is reflected in the cost curves. But fewer turbines are also cheaper to maintain and what we're seeing – what we haven't seen is a hard limit to this turbine growth, but it does take a lot of technology to advance to a higher – a larger platform. And so, it does take time for us to move through this. I'm not sure how large turbines will get, but we're pretty sure they'll get to 15 megawatts at some point.
So, what does that mean for floating? Right now, floating and fixed use the same turbines, but someday, we may see optimization around the turbine itself, and that's yet to be seen.
Change to slide 36:
So, here's some – just some photos that – courtesy of GE – that I'm showing that show the larger turbines are real and there's new technology that's enabling these huge machines to be built. And GE expects that this will be commercially available by 2022. Another manufacturer, Siemens, has announced larger machines and they're doing approximately the same thing in the same time frame, so, we're gonna see the industry offshore jump to these 10 to 12 megawatt turbines very soon. So, if you take just a – for comparison, one of these 12 megawatt Haliade X turbines could power 4,000 to 4,500 average US homes, depending on the wind regime. And they may be even saying more, but that's what I calculate and that's quite a bit for one machine.
Change to slide 37:
So, finally, I want to talk about economic impacts and these are the impacts associated with offshore wind. DOE did a study in 2015 that looked at offshore wind and we estimated that about 80,000 full-time equivalent jobs would be created by 2030 by the offshore wind industry. So, economic benefits from jobs is certainly one thing, but there's other synergies that can help other renewables' growth, like, for example, solar, which obviously only creates energy when the sun is out. Wind blows 24 – can blow 24 hours around the clock. So, wind – and sometimes, at night, wind is even stronger.
So, coupling offshore wind with solar might be a match that helps generate even more energy and helps offset the times when solar isn't able to produce power. Offshore winds also putting power in on the low congestion side of the grid so offshore wind transmission from the coast can offset congestion that's already building up on the land-based side of the grid, and this has been shown in a couple of different studies, but more work really needs to be done in this area.
Change to slide 38:
So, key takeaways. I talked about the resources and showed that these resources are very close to population centers and that means that we're gonna generate power where the power is needed and where it's used. 80 percent of the global resources that are in the – of the offshore wind resources in the world are suited for floating offshore wind. So, floating could become a much larger part of the offshore wind industry than fixed bottom in the long-term just simply because there's more resources for floating, more geographic areas for us to go to. Floating offshore wind is expected to be deployed at the utility scale, which is up to like, a gigawatt scale project at a time, by 2024. We're seeing this happen.
Right now, there's a lot of planning that's actually going on right now. There's one project in Korea that I could point to. So, this is something that's happening. The cost of – the next bullet is the cost of fixed-bottom offshore wind has decreased 70 percent. A lot of people may not have heard that, but that's now able to compete in some electricity markets without subsidies, and these are – some of the European projects are showing that.
That may be true in this country someday as well. But we're also seeing that larger offshore wind turbines have led the way for lower costs. So, larger turbines are changing those balance of system costs and lowering them down so that offshore wind can compete on the regular market for electricity. And then, we're seeing that the floating costs are – because floating is such a nascent industry, those costs are lagging what's already happening in the fixed-bottom industry and we think that those lags will be about five to seven years, but floating will eventually catch up and the two curves will converge somewhere in the $0.05 or below per kilowatt hour range. So, that means that both floating and fixed-bottom offshore wind will be – we expect will be competitive with most forms of energy by 2030 or before. And I think that's my last bit.
Change to slide 39:
So, thanks for your attention and, as we said in the beginning, your questions will be fielded through the chat line and we'll post them – we'll answer them formally and then, post them as we go. So, please, ask away.
Here, we will leave the line open for just a little bit longer in the webinar so that you can ask any additional questions that you may have. We do want to thank everybody for their questions and for tuning into the webinar today and we do look forward to future communications from our audience on floating offshore wind. And, just to reiterate, the webinar presentation has been recorded. It will be disseminated to the registrants of the webinar and posted on YouTube, along with the formal Q&A document capturing all of the questions asked during the webinar. Thank you for tuning in.