Journal cover Journal topic
Wind Energy Science The interactive open-access journal of the European Academy of Wind Energy
Journal topic
WES | Articles | Volume 3, issue 2
Wind Energ. Sci., 3, 553–572, 2018
https://doi.org/10.5194/wes-3-553-2018
© Author(s) 2018. This work is distributed under
the Creative Commons Attribution 4.0 License.
Wind Energ. Sci., 3, 553–572, 2018
https://doi.org/10.5194/wes-3-553-2018
© Author(s) 2018. This work is distributed under
the Creative Commons Attribution 4.0 License.

Research articles 23 Aug 2018

Research articles | 23 Aug 2018

A systematic approach to offshore wind turbine jacket predesign and optimization: geometry, cost, and surrogate structural code check models

A systematic approach to offshore wind turbine jacket predesign and optimization: geometry,...
Jan Häfele1, Rick R. Damiani2, Ryan N. King2, Cristian G. Gebhardt1, and Raimund Rolfes1 Jan Häfele et al.
  • 1Leibniz Universität Hannover, Institute of Structural Analysis, Appelstr. 9a, 30167 Hanover, Germany
  • 2National Renewable Energy Laboratory, 15013 Denver West Parkway, Golden, CO 80401, USA

Correspondence: Jan Häfele (j.haefele@isd.uni-hannover.de)

Abstract
Back to toptop

The main obstacles in preliminary design studies or optimization of jacket substructures for offshore wind turbines are high numerical expenses for structural code checks and simplistic cost assumptions. In order to create a basis for fast design evaluations, this work provides the following: first, a jacket model is proposed that covers topology and tube sizing with a limited set of design variables. Second, a cost model is proposed that goes beyond the simple and common mass-dependent approach. And third, the issue of numerical efficiency is addressed by surrogate models for both fatigue and ultimate limit state code checks. In addition, this work shows an example utilizing all models. The outcome can be utilized for preliminary design studies and jacket optimization schemes. It is suitable for scientific and industrial applications.

1 Introduction
Back to toptop

In the oil and gas industry, the jacket substructure is well established due to a good trade-off between cost efficiency and reliability. It has been considered for offshore wind turbine substructures for several years and has already had some successful applications in Europe and the United States. Smith et al. (2015) showed that among all wind farms announced to be built from the second quarter of 2015 until 2020, 16 % of the substructures are jackets, whereas this share was only 10 % for wind farms built before 2015 (see Fig. 1 for the market shares of offshore wind turbine substructures in the past and present). Despite potential advantages, the market is still strongly dominated by monopiles (Ho et al.2016), as financial aspects and significantly lower uncertainty play an important role from an economical point of view (BVGassociates2012). However, the development of new turbines with higher rated power in combination with the need for deeper water installations might be a catalyst for a technological leap toward jacket substructures. Damiani et al. (2016) calculated that for water depths deeper than 40 m jackets promise lower costs than monopiles, considering six offshore sites along the US Eastern Seaboard and the Gulf of Mexico. The break-even point or water depth at which the jacket technology becomes truly competitive is, however, dependent on the costs of the vessels used to transport and install the structures. State-of-the-art jackets can still benefit from design studies and structural optimization to render lower costs to the project (BVGassociates2013), which is addressed by current research. The accumulation of publications dealing with this topic in the recent past is a confirmation of this statement. Chew et al. (2016) and Oest et al. (2016) performed structural optimization of jacket substructures with simulation-based approaches using gradient-based algorithms. The basis for these papers was the structure defined in the first phase of the Offshore Code Comparison Collaboration Continuation (OC4) project (Popko et al.2014). Damiani et al. (2017) studied the impact of environmental and turbine parameters on the costs or mass of jackets, considering 81 different structures. Hübler et al. (2017b) analyzed the effect of variations in jacket design on the economic viability. AlHamaydeh et al. (2017) and Kaveh and Sabeti (2018) used meta-heuristic algorithms for the optimization of jacket substructures but without realistic – in particular, fatigue limit state – load assumptions. Stolpe and Sandal (2018) introduced discrete variables in the jacket optimization problem formulation to account for the fact that steel tubes are only available in fixed dimensions.

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f01

Figure 1Share of utilized substructures among operating turbines in 2015 and from 2015 to 2020 according to Smith et al. (2015).

Download

From a global perspective, the main obstacles that lead to nonoptimal structures are both the dependence on expert knowledge and the large computational cost associated with the optimization of a complex structure. Many design assessments or optimization approaches addressing this problem fail (because they lead to either unrealistic or impractical design) for the following simple reasons.

  • Design variables. Most approaches do not consider the structural topology, but only the sizing of predefined members. Involving topological parameters, which may be real or discrete, as design variables is mandatory for a proper design that makes use of a mixed-integer formulation.

  • Cost assumptions. Often, the mass of the entire jacket is used as an objective function in optimization approaches. But obviously, the cost breakdown for a welded structure includes many items that do not depend on the mass of the structure. Moreover, other expenses such as transport and installation costs should not be ignored.

  • Load assumptions. The assumption of simplified environmental states (for instance, the omission of wind–wave misalignment) is the state of the art in many jacket design procedures because it relaxes the computational demand and fills any existing gap in the knowledge of the actual metocean conditions.

  • Structural code checks. A realistic jacket design involves structural design code checks for fatigue and ultimate limit state based on time domain simulations. Many approaches miss either one or both of them, most likely because the computational implementation is resource intensive.

  • Simulation approaches. Design iterations cause changes in the structural behavior. A coupled simulation or at least a rigorous approach addressing this aspect is mandatory. However, it is often seen that sequential approaches are applied when decoupled loads are exchanged at the interface between substructure and turbine tower, even in the case of fatigue assessment.

One possible approach to address some of these issues was the jacket sizing tool proposed by Damiani and Song (2013), which enables conceptual design by considering preliminary load assumptions. It, however, lacked extensions to full dynamics simulations and fatigue limit states. Wind turbine cost models are available (Fingersh et al.2006; National Wind Technology Center Information Portal2014) and were used for the definition of wind turbine optimization objectives and constraints (Ning et al.2013), but without explicit or detailed cost formulations for jacket substructures. The goal of the current work is to provide a basic jacket model that can be efficiently used in conceptual studies and optimization approaches by providing a basis for more realistic designs and mainly using mathematically manageable equations. Or, in other words, the main innovation of this study is a basic jacket model that prevents the issues stated above. The first part of this study addresses the first two points described above. The last three points are handled in the second part, as they involve a completely different field. This paper is structured as follows: Sect. 2 explains the utilized jacket model with the assumptions made for the structural details. In Sect. 3, a simple cost model is proposed, which covers cost contributions from materials, fabrication, transition piece, coating, and transport and installation (including foundation). In Sect. 4, load sets are defined for both fatigue and ultimate limit state load cases and a design of experiments is created to fit appropriate surrogate models. The paper concludes with remarks on the benefits of the jacket model, its limitations, and a brief outlook on further work based on this model.

2 Jacket model
Back to toptop

The previous section summarized some issues leading to certain requirements of a simple jacket model.

  • The set of design variables must be as comprehensive as necessary to accurately model the fundamental topology, physics, and dynamics of a typical jacket but as small as possible for ease of computation, too.

  • The design variables must cover both topological and geometrical parameters.

  • Structural details with little bearing on the mechanical behavior shall be disregarded.

  • The cost model formulation shall only depend on the parameters of the jacket model.

  • The structure shall be manufacturable, transportable, and installable.

  • The structure shall be easily transferable to common design tools (mostly based on finite-element formulations).

A concept matching all of these points was initially described by Häfele and Rolfes (2016) and is extended in this section. First, the topology is defined; then the tube dimensions and material properties are derived.

2.1 Topology

The main presumption is that the jacket model need not be limited to a certain number of legs or brace layers (bays), but instead allows for different topologies. As foot and head girth are measures related to four-legged structures, a general formulation in terms of foot (on the ground layer) and head (on the same layer as the transition piece) circles with foot and head radii RFoot and RHead, respectively, is introduced. In order to prevent obtaining structures with a funnel shape, a parameter, ξ, is introduced, which relates the two radii (and can be set to a value less than or equal to 1). The two circles depict the bottom and top of a frustum of length, L (see Fig. 2a). The NL legs can then be constructed as straight lines on the surface of the cone, equidistantly distributed. This is illustrated for a four-legged jacket in Fig. 2b. However, this procedure is applicable to every number of legs that is greater than or equal to three. With these variables, the angle enclosed by two legs can be found according to the following equation:

(1)ϑ=2πNL.

The spatial batter angle, Φs, is the inclination angle of each leg with respect to the symmetry axis of the frustum (sometimes denoted as the three-dimensional batter angle):

(2)Φs=arctanRfoot1-ξL.

The planar batter angle, Φp, is the inclination angle projected to a vertical–horizontal layer through the symmetry axis of the frustum (sometimes denoted as the two-dimensional batter angle):

(3)Φp=arctanRfoot1-ξsinϑ2L.

The parameter, NX, defines the number of bays. A bay is one part of the jacket that is delimited by NL double-K joints at the lower side and NL double-K joints at the upper side and comprises all structural elements in between, in particular NX X joints. The ith bay is denoted with i, where

(4)iN1,NX.

The ratio, q, relates the heights of two consecutive bays, Li+1 and Li, which is assumed to be constant:

(5)q=Li+1Li.

It has to be noted that L1 is the height of the lowest bay and LNX is the height of the highest one. Based on previous assumptions and elementary geometrical considerations, circles on every double-K joint layer can be constructed. With the height of the entire jacket, L, the distance between the ground and lowest bay, LOSG, and the distance between the transition piece and highest bay, LTP, the ith jacket bay height, Li, can be calculated by

(6)Li=L-LOSG-LTPn=1NXqn-i.

The radius of each bay (at the lower double-K joint layer), Ri, is

(7)Ri=Rfoot-tanΦsLOSG+n=1i-1Ln.

This step is shown in Fig. 2c. The distance between the lower layer of double-K joints and the layer of X joints for the ith bay, Lm,i, can be calculated by simple geometrical relations:

(8)Lm,i=LiRiRi+Ri+1.

The radius of the ith X joint layer is

(9)Rm,i=Rfoot-tanΦsLOSG+n=1i-1Ln+Lm,i.

The lower and upper brace-to-leg connection angles, ψ1,i and ψ2,i, respectively, and the brace-to-brace connection angle, ψ3,i, in the ith bay are related by trigonometrical relations (see Fig. 3):

ψ1,i=π2-arctanRfoot1-ξsinϑ2cosΦpL(10)-arctanLm,iRisinϑ2cosΦp,ψ2,i=π2+arctanRfoot1-ξsinϑ2cosΦpL(11)-arctanLm,iRisinϑ2cosΦp,(12)ψ3,i=2arctanLm,iRisinϑ2cosΦp.

In addition, LMSL is the distance between the transition piece (which is at the same height as the tower foot) and mean sea level layer or, in other words, the difference between jacket length and water depth. This information is necessary to create a mesh for the computation of hydrodynamic loads. The flag, xMB, determines whether the jacket is equipped with mud braces or not. The final topology is illustrated in Fig. 2d, in this example with four legs (NL=4), four bays (NX=4), and a mud brace (xMB=true).

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f02

Figure 2Creation of the jacket topology in four steps.

Download

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f03

Figure 3The ith jacket bay topology projected to the layer of X and double-K joints on one side of the structure.

Download

2.2 Tube dimensions

The proposed jacket model makes no use of prefabricated joints (as in the state of the art), and no joint cans or stiffeners (mainly to improve punching shear resistance) are used. The consequences of only single-sided welds and no stiffened joints should be considered. However, the number of (expensive) welds is reduced to a minimum, which reduces the number of degrees of freedom in a structural analysis as well. Moreover, the cost model is not burdened by possible impacts of series manufacturing for prefabricated joints. This is not far away from practical application: it was analyzed for substructures with a rated power higher than 10 MW in the research project Innwind.EU and evaluated as the most efficient one concerning fabrication costs (Scholle et al.2015).

Instead of regarding the diameters and thicknesses of each tube as independent variables, which would lead – depending on the structural topology – to a high number of design variables, the tube dimensions are interpolated between values at the top and the bottom of the structure. Another potential problem is that the tube dimensions, if all are regarded as independent, might lead to undesirable relations between the tube dimensions. Standards and guidelines provided by DNV GL AS (2016b, a) for the design and certification of offshore structures propose the adoption of three ratio parameters initially defined by Efthymiou (1988). However, one variable has to be independent; in our case, it is the leg diameter, DL, which is assumed to be constant.

γb and γt define the ratios between leg radii (not the diameters) and thicknesses:

(13)γb=DL2TLb,(14)γt=DL2TLt,

where the index b indicates the affiliation to the lowermost (bottom) and t to the uppermost (top) tubes. The parameters βb and βt define the ratios of brace and leg diameter at the bottom and top, respectively:

(15)βb=DBbDL,(16)βt=DBtDL.

The values τb and τt define the relations between brace and leg thicknesses at the bottom and top, respectively:

(17)τb=TBbTLb,(18)τt=TBtTLt.

The final determination of the leg and brace dimensions as functions of the height elevation is illustrated in Figs. 4 and 5. The values γi, βi, and τi can be calculated as follows:

(19)γi=γb,i=1γt-γbLOSG+n=1i-1Ln+Lm,iL-LNX+Lm,NX-LTP+γbelse,(20)βi=βt-βbL-LNX-LOSG-LTPn=1i-1Ln+βb,(21)τi=τt-τbL-LNX-LOSG-LTPn=1i-1Ln+τb.

These equations depict a linear-stepwise interpolation from the values at the bottom (index b) to the top (index t). To allow for a smooth transition of the leg thicknesses on the height of the double-K joints, steps of γi are located on the height of the X joints. Steps of βi and τi are located on the height of the double-K joints in order to enable the use of constant tube sizes in each bay.

2.3 Material properties

The entire jacket is supposed to be made of the same isotropic material, which can be described by the Young's modulus, E, the shear modulus, G, and the material density, ρ.

2.4 Parameter summary and array of design variables

There are 20 parameters of the jacket model in total: 10 describe the topology, 7 the tube dimensions, and 3 the material properties. It can be assumed that site- and material-dependent parameters are commonly predetermined, so the number of free design variables might be smaller than 20. To ease the notation in what follows, all variables of the jacket model are assembled in the array x:

x=NLNXRfootξLLMSLLOSGLTPxMB(22)qDLγbγtβbβtτbτtEGρT.
3 Cost modeling
Back to toptop

A possible approach to the jacket substructure cost calculation is to regard the total capital expenses, Ctotal, as a linear combination of multiple contributions, with each one given by a cost factor, cj, multiplied by the corresponding unit cost aj:

(23)Ctotal(x)=ajcj(x)Cj(x).

Basic factors for material, fabrication, coating, transition piece, structural appurtenances (if regarded as additional parts), and transport and installation (including costs for the pile foundation) are assumed here, acknowledging that this breakdown may look different if increasing the level of detail.

c1: material factor
c2: fabrication factor
c3: coating factor
c4: transition piece factor
c5: transport factor
c6: foundation and installation factor
c7: fixed expenses factor

3.1 Material expenses

The material expenses are supposed to be proportional to the mass of the components. Therefore, c1 is the total jacket mass, which is the mass of the assembled substructure excluding the transition piece, foundation, or appurtenances of any kind and which can be obtained by evaluating structural analysis tools or by applying simple geometrical relations from the jacket topology (Fig. 3). The latter can be expressed as a sum:

(24)c1(x)=2ρNLπDL2i=1NXβiτi2γi+τi24γi2Li2cos2Φp+Ri+Ri+12sin2ϑ2Mass of all diagonal braces+xMBρNLπDL2βbτb2γb+τb24γb22R1sinϑ2Mass of mud braces+ρNLπDL2i=1NX12γi+14γi2Lm,icosΦs+12γi+1+14γi+12Li-Lm,icosΦsMass of intermediate leg elements+ρNLπDL212γb+14γb2LOSGcosΦsMass of intermediate lowermost elements+ρNLπDL212γt+14γt2LTPcosΦsMass of uppermost leg elements.

3.2 Fabrication expenses

Although it can be assumed that fabrication expenses contribute significantly to the overall jacket costs, this factor is often neglected because it is difficult to measure. A common approach in practical applications is to assume a proportional relation to the cumulated weld volume. In this cost model, c2 is the cumulative volume of all structural welds. With the weld root thickness, t0 (given as 3 mm in Germanischer Lloyd2012) and assuming a 45 weld angle around the entire weld, the sectional weld area can be approximated and multiplied by the weld length, which is the perimeter of the ellipse that is projected to the connected chord surface1; thus

(25)c2(x)=2NLπDLi=1NXβiDL2τi28γi2+t0DLτi22γi12sin2ψ1,i+12+12sin2ψ2,i+12+12sin2ψ3,i+12Brace-to-brace and brace-to-leg weld volume+2xMBNLπDLβbDL2τb28γb2+t0DLτb22γbMud brace-to-leg weld volume+NLπDLi=1NXDL2min1γi2,1γi+128+DLt0min1γi,1γi+122Leg-to-leg weld volume.

The equation uses the perimeter of the ellipse that is projected on a plane to calculate the weld length. This is not exactly equal to the real weld length, but simplifies the equation considerably.

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f04

Figure 4Definition of leg dimensions with a dependency on the jacket height. Values are illustrated by darker coloring at the bottom and shade to lighter at the top of the structure.

Download

3.3 Coating expenses

Coating is necessary to protect the jacket from corrosion and causes non-negligible costs. It is assumed that the entire outer surface area of all tubes is coated after manufacturing and the coating expenses are proportional to the outer surface area c3:

(26)c3(x)=2NLπDLi=1NXβiLi2cos2Φp+Ri+Ri+12sin2ϑ2Outer surface area of all diagonal braces+xMBNLπDLβb2R1sinϑ2Outer surface area of mud braces+NLπDLLcosΦsOuter surface area of all legs.

The equation assumes that the reduction of the entire outer surface area due to intersecting tubes is negligible.

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f05

Figure 5Definition of brace dimensions with a dependency on the jacket height. Values are illustrated by darker coloring at the bottom and shade to lighter at the top of the structure.

Download

3.4 Transition piece expenses

Although there are different transition piece types, a stellar-type transition piece is assumed, which connects the uppermost leg ends with straight bars to a center point. In this case, it can be assumed that the costs depend linearly, on the one hand, on the number of legs and, on the other hand, on the head radius; thus the factor c4 reads

(27)c4(x)=NLRfootξ.

3.5 Transport expenses

For a simplified cost estimation, the expenses to be raised for the transport of the structure from the port to the wind farm site can be roughly measured in terms of a linear mass dependency, and therefore factors c5 and c1 are equal:

(28)c5(x)=c1(x).

However, this value (mass after production) is supposed to be slightly different from the wrought mass that is used due to overlapping joints and material removal prior to welding. To simplify the cost calculation, it is assumed that both values are equal.

3.6 Foundation and installation expenses

The foundation is the structural part that provides an interface to the seabed. Both the production costs for the foundation structures, no matter of which type, and the on-site installation costs depend linearly on the number of legs in our approach. For the sake of simplicity, it is assumed that these costs do not cover costs due to modifications of the structural pile design. They are assembled in the foundation and installation expenses, and the corresponding factor c6 reads

(29)c6(x)=NL.

3.7 Fixed expenses

There are costs that cannot be measured in terms of any parameters of the jacket model:

(30)c7(x)=1.

These kinds of costs – in the nomenclature of this work proportional to the factor c7 – arise for every structure and are indeed very important for a cost assessment, but have a rather minor impact on design studies or optimization results, as there is no contribution to differential operators. Examples are costs for structural appurtenances, like boat landings and ladders, or production facilities and infrastructure, like scaffolds or cranes.

4 Surrogate models for fatigue and ultimate limit state
Back to toptop

A general presupposition made in this work is that realistic jacket design necessitates simulation-based proofs to ensure the structural functionality in different limit states. While the proof of serviceability limit state is mostly simple in the case of relatively stiff lattice structures, for which the tubular tower dominates the modal behavior of the entire turbine, the checks for fatigue and ultimate limit state are computationally expensive. There are indeed simulation-based optimization approaches in the literature, but all with very limited design load sets and proposals trying to find efficient load sets or simplifications of load cases.

Recent work showed that Gaussian process regression (GPR) models are appropriate to predict numerically obtained fatigue damages for two test structures from environmental state inputs (Brandt et al.2017). It is thus straightforward to transfer the same methodology to the prediction of fatigue damages or utilization ratios due to extreme loads for varying jacket designs in the case that the load sets are given. It is also imaginable to apply a classification approach to this type of problem, with the statements “structural code check successful” or “structural code check failed” as outputs. However, this would limit the imaginable applications, so regression is applied. In the following, a brief introduction to Gaussian process regression is given. For the sake of simplicity, the output dimension of the problem is restricted to one, which is a single-output regression problem. The basis for GPR is the Bayesian regression problem:

(31)y=f(x)+e

with

(32)eN0,σn2.

We want to make predictions, y*, for an arbitrary set of (prediction) input variables, x*, based on information gathered from the training set, which is represented by the input matrix, X, and the vector of corresponding output values, y. The key assumption of Gaussian process regression is that a Gaussian distribution over f(x) exists; thus

(33)f(x)GPm(x),k(x,x),

with

(34)m(x)=Ef(x)

and

(35)k(x,x)=covf(x),f(x),

which is a Mercer kernel function. Due to the marginalization property of Gaussian processes, there is a joint distribution of training and prediction sets:

(36)yy*0,K(X,X)k(X,x*)k(x*,X)k(x*,x*).

In this equation, K and k were introduced to ease the notation and just represent matrices and vectors for which each element is the corresponding value of k. The mean of the joint distribution was set to zero. From this equation, the conditional posterior distribution of y* can be obtained:

y*|x*Nk(X,x*)TK(X,X)+σn2I-1y,(37)k(x*,x*)-k(x*,X)K(X,X)+σn2I-1k(X,x*).

For further details, the interested reader is referred to Rasmussen and Williams (2008), which is the most comprehensive work in this field in the opinion of the authors. Due to the probabilistic nature of these models, the computation of prediction intervals is possible. This is a substantial advantage because realistic load sets are large and thus the size of the design of experiments is limited. In addition, when the uncertainty arising from design load set assumptions is known, it can be easily considered by an appropriate choice and parameterization of the kernel function.

The prediction of values from a GPR model requires the complete input and output training to set it up. In contrast to the proposed geometry and cost assumptions, the derivation of surrogate models for fatigue and ultimate limit state depends highly on the reference turbine and the environmental conditions. The first one has been selected to be the National Renewable Energy Laboratory (NREL) 5 MW turbine, defined by Jonkman et al. (2009). The water depth at the fictive location is 50 m. In addition, the research platforms FINO3 (mainly) and FINO1 (for validation purposes) provide detailed, long-term measurements to derive the environmental conditions. Soil properties are adopted from the definition of the soil layers in the Offshore Code Comparison Collaboration (OC3) project (Jonkman and Musial2010). The transition piece is considered with a lumped mass of 660 t at the bottom of the tubular steel tower. There are, however, some limitations in these assumptions that cannot be suppressed. No structural appurtenances like ladders, boat landings, sacrificial anodes, or J tubes are considered in the structural model. The assumption of 50 m of water depth does not match the water depths at the FINO locations. Nevertheless, no other measurements of environmental states are available, and this assumption was also made in the design basis of the UpWind project (Fischer et al.2010).

4.1 Training and validation data sets

To obtain training data for surrogate modeling, 200 test jackets were sampled from the design space by a space-filling design of experiments with minimum correlation between all samples. Assuming that it is the state-of-the-art reference for 5 MW wind turbine jacket structures, the boundaries in Table 1 were chosen in a realistic range around the values of the OC4 jacket Popko et al. (2014), excluding “too optimistic”2 jacket designs. Although the number of samples seems to be low, it has to be considered that the number of time domain simulations depends linearly on the sample size. Moreover, Eq. (24) requires the inversion of K(X,X), which may lead to weak numerical performance of the prediction. Furthermore, an independent validation set with 40 samples from the entire design space was generated, which was created by another space-filling design of experiments. It has to be noted that the purpose of this data set is just validation of the final parameterized models; it is not involved in the training phase and is not part of the cross-validation procedure.

Table 1Jacket model parameter boundaries for the design of experiments. Topological, tube sizing, and material parameters are separated in groups; single values indicate that the corresponding value is held constant.

Download Print Version | Download XLSX

4.2 Design load sets

In order to conduct time domain simulations, load sets for both fatigue and ultimate limit state have to be defined. For the fatigue case, broad knowledge about the required size of design load sets is already available because it was analyzed previously in a comprehensive study (Häfele et al.2017a, b) in which both probabilistic and unidirectional load sets were investigated. However, as the GPR allows us to propagate uncertainties, it is reasonable to utilize a probabilistic load set with 128 production load cases (design load case (DLC) 1.2 and 6.4 according to IEC-61400-3; see International Electrotechnical Commision2009) for damage estimation (see Table 2), which is a finding of the previously mentioned study. In the extreme load case, the focus is rather on the consideration of multiple special events than on the reproduction of the long-term behavior. Table 3 features a summary of all design load cases that are to be calculated for every sample. There are 10 extreme load cases that were identified to be potentially critical. DLC 1.3 and 1.6a are production load cases with extreme turbulence and severe sea state, respectively. DLC 2.3 is a design load case for which electrical grid loss occurs during the production state. DLC 6.1a and 6.2a are events with extreme mean wind speed, the first one with an extreme sea state and the second one with an extreme yaw error. The values of the parameters in Table 3 were obtained by evaluating probability density functions of environmental parameters at the FINO locations given by Hübler et al. (2017a).

Table 2Considered design load sets according to IEC-61400-3 (International Electrotechnical Commision2009) for the fatigue limit state (SF: partial safety factor, vs: mean wind speed, P: probability density function, TI: turbulence intensity, Hs: significant wave height, Tp: wave peak period, θwind: wind direction, θwave: wave direction, uw: near-surface current velocity, uss: subsurface current velocity, MSL: mean sea level). Yaw error is normally distributed with 8 mean value and 1 standard deviation.

Download Print Version | Download XLSX

Table 3Considered design load sets according to IEC-61400-3 (International Electrotechnical Commision2009) for the ultimate limit state (SF: partial safety factor, vs: mean wind speed, TI: turbulence intensity, Hs: significant wave height, Tp: wave peak period, θwind: wind direction, θwave: wave direction, uw: near-surface current velocity, uss: subsurface current velocity, MSL: mean sea level). Yaw error is constantly set to 8 if not stated differently.

Download Print Version | Download XLSX

4.3 Time domain simulations

As the varying jacket design changes the structural behavior of the entire turbine, only fully coupled simulations were conducted for this study, as so-called sequential or uncoupled approaches are considered not sufficiently accurate. All simulations are computed with FAST (National Wind Technology Center Information Portal2016) in the current version at the publication of this study and comprise 10 min time series3 plus an additional 3 min time for transient decay. To account for soil–structure interaction, a reduced representation of the substructure (see Häfele et al.2016) is considered, in which eight interior modes are the basis for the representation of the jacket with foundation. The pile foundation is considered by lumped mass and stiffness matrices at the transition between substructure and ground. These matrices are derived by a preprocessing procedure in which the piles with py and Tz curves according to the American Petroleum Institute (2002) are discretized with finite elements. In the fatigue limit state case, the soil is linearized in the zero-deflection operating point. The operating-point-dependent soil behavior cannot be neglected in the extreme load case and is considered by an ad hoc approach (Hübler et al.2016).

4.4 Post-processing of time domain results

Fatigue is evaluated in terms of the maximum cumulative damage that occurs in the critical joint after summing up all hot spot damages. An SN curve approach defined by the structural code DNV GL RP-0005 (DNV GL AS2016a) is utilized for this purpose. Hot spot stresses are obtained by stress concentration factors. Stress cycles are evaluated by a rainflow-counting algorithm and added up according to linear damage accumulation. Fatigue checks are only performed for tubular joints corresponding to class T according to the structural code. The related SN curve has an endurance stress limit of 52.63×106 N m−2 at 107 cycles and slopes of 3 and 5 before and after endurance limit, respectively.

Ultimate limit state proofs are performed according to the structural code NORSOK N-004 (NORSOK2004), which is a well-established standard for this purpose. Although the extreme load assessment involves all tubes of the jacket, the output value is only the one with the highest utilization ratio among all considered load cases, including partial safety factors. Punching shear resistance of tubular joints is not considered in the surrogate model because it is not part of the predesign process. Steel with a yield stress of 355 MPa (S355) is considered as the material for the entire structure, excluding structural appurtenances.

4.5 Derivation and parameterization of Gaussian process regression models

While the outputs of both limit state assessments are single real values, it has to be conceived that the output values are distributed differently. GPR models are mainly governed by the kernel function choice and the corresponding hyperparameters. Different kernel functions were tested with respect to the creation of appropriate surrogate models and evaluated in terms of cross-validations in this section. Due to the highly nonlinear character of the utilized structural codes and therefore significant variance in the model outputs, a certain extent of uncertainty has to be tolerated. For the learning procedure, the fatigue damages are logarithmized because the underlying SN curve is also logarithmic and the range of values covers at least 4 powers of 10. For the ultimate limit state, results cover only a range from zero to about 3, and no normalization is necessary. However, to exclude severe outliers from the training set of the surrogate model for the ultimate limit state, 10 % of the samples with the highest extreme load utilization ratios are excluded.

The problem of choosing the right kernel function is discussed by many authors. In order to limit the extent of this section, the reader is referred to the works of Duvenaud (2014) and King (2016) for further details. In general, the kernel choice implies a belief about the shape or smoothness of the covariance. In this case, four commonly used stationary kernel functions are compared that represent relatively smooth approximations of the function.

The squared exponential kernel reads

(38)kSE(x,x)=exp-(x-x)(x-x)T2l2.

The Matérn 3∕2 kernel is

kMa3/2(x,x)=1+3(x-x)(x-x)Tl(39)exp-3(x-x)(x-x)Tl,

the Matérn 5∕2 kernel is

kMa5/2(x,x)=1+5(x-x)(x-x)Tl+5(x-x)(x-x)T3l2(40)exp-5(x-x)(x-x)Tl,

and the rational quadratic kernel is

(41)kRQ(x,x)=1+(x-x)(x-x)T2al2a,

where l is a length scale and a a weighting parameter. It is best practice to choose different scales for all input parameters. This is called automatic relevance determination (Duvenaud2014).

The squared exponential kernel is a common choice for Gaussian processes as an “initial guess” because it is infinitely differentiable and therefore very smooth. The Matérn kernels are less smooth than the squared exponential kernel: Matérn 3∕2 is once and Matérn 5∕2 twice differentiable. The rational quadratic kernel is a sum of squared exponential kernels with the capability to weight between large- and small-scale variations. To figure out which kernel function is most suitable for both surrogate models, various cross-validations are performed. An N-fold cross-validation means that the training data set (which comprises 200 jacket samples in the fatigue limit state case and 180 samples in the ultimate limit state case in this study) is divided into N parts with equal size. N−1 parts are then used to train the model and the leftover is the test set, which is used to predict a vector of validation results, y*. This is repeated N times to compute the mean of the two common error measures, bias ebias and mean squared error emse:

(42)ebias=1Nn=1N1Mm=1Myn,m*-yn,m,(43)emse=1Nn=1N1Mm=1Myn,m*-yn,m2,

where yn,m* is the mth predicted element in the nth cross-validation set and yn,m is the corresponding value in the output vector. M is the size of the cross-validation leftover. For instance, in the case of a 10-fold cross-validation, M is 20. While the mean squared error is always positive, the bias can have both positive and negative values. Table 4 shows validation results for the four kernels using leave-one-out, 10-fold, and 5-fold cross-validations. There are no values completely off and all kernel functions lead to similar results in the fatigue limit state case; the Matérn 5∕2 function is eventually chosen for both surrogate models.

Table 4Cross-validation results for kernel functions applied to fatigue and ultimate limit state outputs, each case with ideal hyperparameters obtained by maximum likelihood estimation.

Download Print Version | Download XLSX

4.6 Validation of Gaussian process regression models

Based on the kernel function selection, the surrogate models are validated with 40 samples from the design space given in Table 1. A Matérn 5∕2 kernel with independent hyperparameters and a Gaussian likelihood function with lnσn2=-2.06, where σn2 is the mean standard deviation of logarithmized damage per load case accounting for load set reduction uncertainty evaluated from the results by Häfele et al. (2017a, b), are chosen for the fatigue case. The ultimate limit state case does not incorporate prior knowledge of uncertainty because it is assumed that one of the considered load cases in Table 3 is the severest imaginable one. The predicted validation values for both fatigue and ultimate limit state are shown in Fig. 6. Although the drawn whiskers show quite wide prediction intervals, the mean values predict the calculated ones well in both diagrams. Therefore, it can be stated that Gaussian process regression is suitable for this task.

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f06

Figure 6Prediction results for all samples of the validation set. Asterisks depict mean predicted damages in the first and mean extreme load utilization ratios in the second plot, and whisker ranges illustrate the 95 % significance intervals. The solid red line illustrates the critical damage related to a 20-year lifetime of the structure or a utilization ratio of 1. Moreover, the 30-year damage is illustrated with a dashed red line in the first plot.

Download

5 Example
Back to toptop

Although the focus of this work shall not be a comprehensive design study, a short example is provided in this section, which shows how the proposed models can be used in further studies.

We assume that for a fixed wind farm location with 50 m of water depth, NREL 5 MW turbine, FINO3 environmental conditions, and OC3 soil properties, it has to be evaluated which of three given jacket designs is most suitable with regard to capital expenses. There is uncertainty in the capital expenditures arising from, for example, the market situation, the availability of fabrication facilities and ships, the distance of the installation site from shore, the weather situation, and the sea state. For the sake of simplicity, we assume that this uncertainty can be described in terms of normally distributed cost model parameters given as mean values and standard deviations in Table 54. The parameter distributions indicate relatively high uncertainty, in particular in the expenses for transport and installation, which is a common experience in the wind farm planning process. There are three substructure options to be compared: the first (a), derived from the so-called OC4 jacket Popko et al. (2014), and second (b) ones are four-legged (NX=4) jackets, and the third (c) one is a three-legged (NX=3) structure. All structures have a length of L=70 m with transition piece LMSL=20 m above mean sea level and use steel (E=2.100×1011 N m−2, G=8.077×1010 N m−2, ρ=7.850×103 kg m−3) as the material. The height between the ground and lowermost double-K joint layer is LOSG=5 m, and the transition piece height is LTP=4 m. Furthermore, all jackets have mud braces (xMB=true); the foot radii, Rfoot, are all 8.485 m, the bay height ratio, q, is 0.8, and the head-to-foot radius ratio, ξ, is 0.67. The leg radius-to-thickness and the leg-to-brace thickness ratios are held constant at γ=γb=γt=15.0 and τ=τb=τt=0.5, respectively. The structures differ, except for the number of legs (NL), in the number of bays (NX) and tube dimensions (DL, βb, βt). The first one (a) has four bays, a leg diameter of 1.2 m, and β=βb=βt=0.67. The second one (b) has only three bays, but higher tube diameters and thicknesses with DL=1.32 m and constant β=βb=βt=0.75. The third jacket (c) is the same as the first one (a), but with only three legs (NL=3) and an increased leg diameter DL=1.44 m. Thus, all structures are representative for different approaches known from practical applications and it is easily imaginable that they differ in all cost factors of the cost model except for the fixed expenses.

Table 5Reference unit costs for the considered example, a 5 MW reference turbine in a water depth of 50 m.

Download Print Version | Download XLSX

https://www.wind-energ-sci.net/3/553/2018/wes-3-553-2018-f07

Figure 7Probability density functions (PDFs) of the cost contributions C1C7, the total expenses Ctotal, the (logarithmized) predicted damage per load case, and the predicted extreme load utilization ratio for the considered example case. Each plot shows the probability density depending on cost, damage exponent, and utilization ratio. Structure (1) is illustrated by the solid gray line, structure (2) by the dashed gray line, and structure (3) by the dotted gray line. The solid red line illustrates the critical damage related to a 20-year lifetime of the structure or a utilization ratio of 1. Moreover, the 30-year damage is illustrated with the dashed red line.

Download

First, the cost contributions C1C7 are calculated for each substructure according to the proposed cost model. Now, two helpful properties are used to evaluate the costs:

  1. the total costs of each substructure, Ctotal, which are a linear combination of the single contributions, C1C7, and

  2. the sum of normal distributions is again normally distributed.

Figure 7 shows the resulting probability density functions of all cost contributions and the total expenses when the normally distributed unit costs in Table 5 are combined with the proposed cost model. The three-leg design (c) is the cheapest among the considered structures because the tube dimension increase of 20 % (all tube sizing parameters depend linearly on the leg diameter) is overcompensated for by the reduction in jacket legs, which shows in the factor mass, resulting in significantly lower costs. The structures (a) and (b) show stronger similarities in all cost contributions, adding up to nearly equal total expenses.

However, the cost assessment is not meaningful without consideration of structural code checks. The surrogate models for fatigue and ultimate limit state are utilized for prediction and also shown in Fig. 7. Structure (a) takes a mean damage of 10−6.72 per load case, structure (b) 10−6.91, and structure (c) 10−6.72, all with similar variance. Linear damage accumulation (implying that the lifetime is reached at a cumulated damage of 1) and a simulation time per load case of 10 min yields lifetimes of approximately 100, 155, and 100 years for the three structures, considering a fatigue safety factor of 1.25. The same procedure is applied to ultimate limit state assessment and mean tube utilization ratios of 1.05, 0.72, and 0.94 are obtained in the critical load case for the structures (a), (b), and (c), respectively. Therefore, although all structures are quite close to an ideal utilization ratio, the second structure has the highest capacity concerning extreme loads.

Although only three designs were considered in this example, it is conceivable that three-legged structures are truly competitive with respect to the given boundaries because the design of structure (c) is related to the lowest capital expenses and has sufficient load capacities in the fatigue and ultimate limit state. According to the proposed cost model, the cost saving arises mainly from two contributions, namely transition piece expenses and foundation and installation expenses, both depending linearly on the number of jacket legs. This is in agreement with experiences from practical applications because three-legged structures have recently increased in importance, which is visible in the number of offshore installations for turbines with intermediate rated power. Comparing structure (a) and (b), the cost differences are marginal, while structure (b) turns out to be much better in terms of structural properties, which is visible in a higher lifetime and a lower extreme load utilization ratio. Therefore, it can be stated that the number of jacket legs and the leg diameter (in the case of dependent brace dimensions) are key parameters in the first phase of jacket design. A quantitative sensitivity analysis of the remaining parameters has to be conducted in forthcoming studies.

It can be imagined that the approach is easily usable for far more complex studies in which the number of design samples is much higher than in the present example because the entire procedure, which usually requires enormous numerical capacity, was solved in a negligible amount of time. It was already discussed that every jacket design requires a high number of time domain simulations to perform structural code checks. Therefore, the proposed methodology is appropriate to assess the topology and dimensions of a substructure, while structural details still have to be determined with high-fidelity models.

Moreover, the example shows that uncertainty can be easily incorporated in the design assessment using the proposed models for capital expenses and structural code checks. This may lead to probabilistic studies or robust jacket design.

6 Limitations
Back to toptop

The models established in this work provide the groundwork to regard the jacket design process from a scientific point of view, not from an application-oriented design perspective, which depends highly on (human) expert knowledge. This aspect is emphasized strongly at this point because the outcome from studies based on these models will most likely not represent the geometry of the final structure, but an initial or conceptual design approach suitable for implementations with high numerical demands. Therefore, although the proposed models provide a comprehensive basis for design evaluations or optimization, they have to be used with caution. There is still a distinct amount of uncertainty in the surrogate model outputs, which arises from different sources, such as load set reductions, relatively small training sets (due to limited numerical capacity), or nonlinearities in physical models or structural code checks.

In addition, it has to be mentioned that though the methods are probably applicable to other turbines as well, the numerical parameters and results in the considered example are only valid for a jacket substructure at a given (fictive) offshore location with a 50 m water depth, FINO3 environmental conditions, and the NREL 5 MW turbine. An adaption to different boundaries requires a reestimation of the parameters.

7 Conclusions
Back to toptop

The objective of this work was to provide a minimal but comprehensive approach to conceptual studies on jacket substructures for wind turbines. For this purpose, a geometry model was defined. A completely analytical cost model was derived afterwards. The issue of computationally expensive structural code checks was faced by surrogate modeling, namely Gaussian process regression models. Finally, an example was considered to show the capabilities of the developed models in which three artificial structures were analyzed. It was shown that different jacket design approaches (varying in topology and tube dimensions) may be appropriate solutions for a given wind turbine and environmental conditions. The present work improves the state of the art by combining a jacket model with topological design variables, more realistic cost and load assumptions, structural design code checks, and coupled time domain simulations in one approach.

Deliberately, this paper does not provide too extensive numerical results for applied science. The proposed models and equations are to be used for more realistic design studies on latticed substructures for offshore wind farms. Therefore, the path can continue in two ways: first, design studies not focused on structural aspects can benefit from these models because they do not require too much knowledge about physical details. But second and intentionally, this work contributes a substantial improvement to jacket optimization approaches, yet mostly focuses on tube dimensioning and often neglects structural topology aspects, a correct cost assessment, or realistic structural code checks. In particular, the utilization of surrogate modeling is very promising when dealing with meta-heuristic algorithms like evolutionary or swarm-based approaches applied to the jacket optimization problem because the related numerical expenses are significantly lower compared to approaches based on time domain simulations. This may lead to much more detailed analyses of the optimization procedure from the mathematical point of view because approaches known from the literature are focused on technical aspects. Questions to be answered in this context are, for instance, how the constraints can be handled efficiently or which algorithm is most suitable for the jacket optimization problem.

Code and data availability
Back to toptop
Code and data availability. 

The results of training and validation sets, including fatigue and ultimate limit state code checks, are provided and available for research purposes. To set up Gaussian process regression models, we use and recommend using GPML, which can be run with Octave, MATLAB, or Python. GPML is freely available at http://www.gaussianprocess.org/gpml/code/matlab/doc/ (GPML, 2018).

Appendix A: Nomenclature
Back to toptop
DLC Design load case
𝔼 Expected value
𝒢𝒫(m,k) Gaussian process with mean function m and covariance function k
GPR Gaussian process regression
MSL Mean sea level
Set of natural numbers
𝒩(μ,σ2) Normally distributed number with mean μ and variance σ2
SF Partial safety factor
TI Turbulence intensity
Φp Planar (two-dimensional) batter angle
Φs Spatial (three-dimensional) batter angle
βb Brace-to-leg diameter ratio at bottom (jacket model parameter)
βi Brace-to-leg diameter ratio in the ith bay
βt Brace-to-leg diameter ratio at top (jacket model parameter)
γb Leg radius-to-thickness ratio at bottom (jacket model parameter)
γi Leg radius-to-thickness ratio in the ith bay
γt Leg radius-to-thickness ratio at top (jacket model parameter)
θwave Wave direction
θwind Wind direction
ξ Head-to-foot radius ratio (jacket model parameter)
ρ Material density (jacket model parameter)
σn2 Gaussian input noise variance
ϑ Angle enclosed by two jacket legs
τb Brace-to-leg thickness ratio at bottom (jacket model parameter)
τi Brace-to-leg thickness ratio in the ith bay
τt Brace-to-leg thickness ratio at top (jacket model parameter)
ψ1,i Lower brace-to-leg connection angle in the ith bay
ψ2,i Upper brace-to-leg connection angle in the ith bay
ψ3,i Brace-to-brace connection angle in the ith bay
Cj Expenses related to jth cost factor
Ctotal Total capital expenses
DBb Bottom brace diameter
DBt Top brace diameter
DL Leg diameter (jacket model parameter)
E Material Young's modulus (jacket model parameter)
G Material shear modulus (jacket model parameter)
Hs Significant wave height
I Identity martrix
K Kernel function matrix
L Overall jacket length (jacket model parameter)
LMSL Transition piece elevation over MSL (jacket model parameter)
LOSG Lowest leg segment height (jacket model parameter)
LTP Transition piece segment height (jacket model parameter)
Li ith jacket bay height
Lm,i Distance between the lower layer of K joints and the layer of X joints of the ith bay
M Size of the cross-validation leftover
N Number of cross-validation bins
NL Number of legs (jacket model parameter)
NX Number of bays (jacket model parameter)
P Probability density function
RFoot Foot radius (jacket model parameter)
RHead Head radius
Ri ith jacket bay radius at lower K joint layer
Rm,i Radius of the ith X joint layer
TBb Bottom brace thickness
TBt Top brace thickness
TLb Bottom leg thickness
TLt Top leg thickness
Tp Wave peak period
X Matrix of training inputs (one sample per row)
a Kernel weighting parameter
aj jth unit cost
cj jth cost factor
e Noise
ebias Bias error
emse Mean squared error
f Function value
k Kernel function vector
k Covariance (kernel) function
kMa3/2 Matérn 3∕2 kernel function
kMa5/2 Matérn 5∕2 kernel function
kRQ Rational quadratic kernel function
kSE Squared exponential kernel function
l Kernel length-scale parameter
m Mean function
q Ratio of two consecutive bay heights (jacket model parameter)
uss Subsurface current velocity
uw Near-surface current velocity
vs Mean wind speed
x Array of design variables/vector of training
x* Array of prediction inputs
xMB Mud brace flag (jacket model parameter)
y Vector of training outputs (one sample per row)
y General regression output value
y* Prediction value
Supplement
Back to toptop
Supplement. 

The supplement related to this article is available online at: https://doi.org/10.5194/wes-3-553-2018-supplement.

Competing interests
Back to toptop
Competing interests. 

The author declares that there is no conflict of interest.

Disclaimer
Back to toptop
Disclaimer. 

The views expressed in the article do not necessarily represent the views of the U.S. Department of Energy or the U.S. government.

Acknowledgements
Back to toptop
Acknowledgements. 

This work was supported by the compute cluster, which is funded by the Leibniz Universität Hannover, the Lower Saxony Ministry of Science and Culture (MWK), and the German Research Foundation (DFG).

Cordial thanks are given to Jason Jonkman, Amy Robertson, and Katherine Dykes from the National Renewable Energy Laboratory, who supported this work with many valuable remarks and suggestions, and Manuela Böhm from Leibniz Universität Hannover for supporting the numerical simulation work.

The Alliance for Sustainable Energy, LLC (Alliance) is the manager and operator of the National Renewable Energy Laboratory (NREL). NREL is a national laboratory of the U.S. Department of Energy, Office of Energy Efficiency and Renewable Energy. This work was authored by the Alliance and supported by the U.S. Department of Energy under contract no. DE-AC36-08GO28308. Funding was provided by the U.S. Department of Energy Office of Energy Efficiency and Renewable Energy, Wind Energy Technologies Office.

The publication of this article was funded by the open-access
fund of Leibniz Universität Hannover.

Edited by: Athanasios Kolios
Reviewed by: two anonymous referees

References
Back to toptop

AlHamaydeh, M., Barakat, S., and Nasif, O.: Optimization of Support Structures for Offshore Wind Turbines Using Genetic Algorithm with Domain-Trimming, Math. Probl. Eng., 2017, 1–14, https://doi.org/10.1155/2017/5978375, 2017. a

American Petroleum Institute: Recommended Practice for Planning, Designing and Constructing Fixed Offshore Platforms – Working Stress Design, Recommended Practice RP 2A-WSD, 2002. a

Brandt, S., Broggi, M., Häfele, J., Gebhardt, C. G., Rolfes, R., and Beer, M.: Meta-models for fatigue damage estimation of offshore wind turbines jacket substructures, Procedia Engineer., 199, 1158–1163, https://doi.org/10.1016/j.proeng.2017.09.292, 2017. a

BVGassociates: Offshore wind cost reduction pathways – Technology work stream, Tech. rep., 2012. a

BVGassociates: Offshore wind: Industry's journey to GBP 100/MWh – Cost breakdown and technology transition from 2013 to 2020, Tech. rep., 2013. a

Chew, K.-H., Tai, K., Ng, E., and Muskulus, M.: Analytical gradient-based optimization of offshore wind turbine substructures under fatigue and extreme loads, Mar. Struct., 47, 23–41, https://doi.org/10.1016/j.marstruc.2016.03.002, 2016. a

Damiani, R. and Song, H.: A Jacket Sizing Tool for Offshore Wind Turbines within the Systems Engineering Initiative, in: Offshore Technology Conference, 6–9 May 2013, Houston, TX, USA, https://doi.org/10.4043/24140-MS, 2013. a

Damiani, R., Dykes, K., and Scott, G.: A comparison study of offshore wind support structures with monopiles and jackets for U.S. waters, J. Phys. Conf. Ser., 753, 092003, https://doi.org/10.1088/1742-6596/753/9/092003, 2016. a

Damiani, R., Ning, A., Maples, B., Smith, A., and Dykes, K.: Scenario analysis for techno-economic model development of U.S. offshore wind support structures: Scenario analysis for techno-economic model development of U.S. offshore wind support structures, Wind Energy, 20, 731–747, https://doi.org/10.1002/we.2021, 2017. a

DNV GL AS: Fatigue design of offshore steel structures, Recommended Practice DNVGL-RP-C203, 2016a. a, b

DNV GL AS: Support structures for wind turbines, Offshore Standard DNVGL-ST-126, 2016b. a

Duvenaud, D. K.: Automatic Model Construction with Gaussian Processes, PhD thesis, University of Cambridge, Cambridge, UK, 2014. a, b

Efthymiou, M.: Development of SCF formulae and generalised influence functions for use in fatigue analysis, in: Proceedings of the Conference on Recent Developments in Tubular Joints Technology, 1–13, Surrey, 1988. a

Fingersh, L., Hand, M., and Laxson, A.: Wind Turbine Design Cost and Scaling Model, Technical Report NREL/TP-500-40566, Golden, CO, USA, 2006. a

Fischer, T., de Vries, W., and Schmidt, B.: Upwind Design Basis, Tech. rep., 2010. a

Germanischer Lloyd: Guideline for the Certification of Offshore Wind Turbines, Offshore Standard, 3–35, 2012. a

GPML: Gaussian process regression models, available at: http://www.gaussianprocess.org/gpml/code/matlab/doc/, last access: 13 August 2018. 

Häfele, J. and Rolfes, R.: Approaching the ideal design of jacket substructures for offshore wind turbines with a Particle Swarm Optimization algorithm, in: Proceedings of the Twenty-sixth (2016) International Offshore and Polar Engineering Conference, Rhodes, Greece, 156–163, 2016. a

Häfele, J., Hübler, C., Gebhardt, C. G., and Rolfes, R.: An improved two-step soil-structure interaction modeling method for dynamical analyses of offshore wind turbines, Appl. Ocean Res., 55, 141–150, https://doi.org/10.1016/j.apor.2015.12.001, 2016. a

Häfele, J., Hübler, C., Gebhardt, C. G., and Rolfes, R.: A comprehensive fatigue load set reduction study for offshore wind turbines with jacket substructures, Renew. Energ., 118, 99–112, https://doi.org/10.1016/j.renene.2017.10.097, 2017a. a, b

Häfele, J., Hübler, C., Gebhardt, C. G., and Rolfes, R.: Efficient Fatigue Limit State Design Load Sets for Jacket Substructures Considering Probability Distributions of Environmental States, in: Proceedings of the Twenty-seventh (2017) International Offshore and Polar Engineering Conference, San Francisco, CA, USA, 167–173, 2017b. a, b

Ho, A., Mbistrova, A., and Corbetta, G.: The European offshore wind industry – key trends and statistics 2015, Tech. rep., 2016. a

Hübler, C., Häfele, J., Ehrmann, A., and Rolfes, R.: Effective consideration of soil characteristics in time domain simulations of bottom fixed offshore wind turbines, in: Proceedings of the Twenty-sixth (2016) International Offshore and Polar Engineering Conference, Rhodes, Greece, 127–134, 2016. a

Hübler, C., Gebhardt, C. G., and Rolfes, R.: Development of a comprehensive database of scattering environmental conditions and simulation constraints for offshore wind turbines, Wind Energ. Sci., 2, 491–505, https://doi.org/10.5194/wes-2-491-2017, 2017a. a

Hübler, C., Piel, J.-H., Breitner, M. H., and Rolfes, R.: How Do Structural Designs Affect the Economic Viability of Offshore Wind Turbines? An Interdisciplinary Simulation Approach, in: Conference: International Conference on Operations Research, Berlin, Germany, 2017b. a

International Electrotechnical Commision: Wind turbines – Part 3: Design requirements for offshore wind turbines, Tech. Rep. IEC-61400-3:2009, EN 61400-3:2009, 2009. a, b, c

Jonkman, J. M. and Musial, W.: Offshore Code Comparison Collaboration (OC3) for IEA Task 23 Offshore Wind Technology and Deployment, Technical Report NREL/TP-5000-48191, National Renewable Energy Laboratory, Golden, CO, USA, 2010. a

Jonkman, J. M., Butterfield, S., Musial, W., and Scott, G.: Definition of a 5-MW Reference Wind Turbine for Offshore System Development, Technical Report NREL/TP-500-38060, National Renewable Energy Laboratory, Golden, CO, USA, 2009. a

Kaveh, A. and Sabeti, S.: Structural optimization of jacket supporting structures for offshore wind turbines using colliding bodies optimization algorithm, Struct. Des. Tall. Spec., 27, e1494, https://doi.org/10.1002/tal.1494, 2018. a

King, R. N.: Learning and Optimization for Turbulent Flows, PhD thesis, University of Colorado, Boulder, CO, USA, 2016. a

Michels, G.: Mass Production of Offshore Wind-Jackets requires new Industrial Solutions, in: Nationale Staalbouwdag, Katwijk, the Netherlands, 2014. a

National Wind Technology Center Information Portal: Plant_CostsSE, available at: https://nwtc.nrel.gov/Plant_CostsSE (last access: 23 July 2018), 2014. a, b

National Wind Technology Center Information Portal: FAST v8, available at: https://nwtc.nrel.gov/FAST8 (last access: 23 July 2018), 2016. a

Ning, A., Damiani, R., and Moriarty, P.: Objectives and Constraints for Wind Turbine Optimization, in: 51st AIAA Aerospace Sciences Meeting, Grapevine, TX, USA, https://doi.org/10.2514/6.2013-201, 2013. a

NORSOK: Design of steel structures, Standard N-004 Rev. 2, 2004. a

Oest, J., Sørensen, R., T. Overgaard, L. C., and Lund, E.: Structural optimization with fatigue and ultimate limit constraints of jacket structures for large offshore wind turbines, Struct. Multidiscip. O., 55, 779–793, https://doi.org/10.1007/s00158-016-1527-x, 2016. a

Popko, W., Vorpahl, F., Zuga, A., Kohlmeier, M., Jonkman, J., Robertson, A., Larsen, T. J., Yde, A., Saetertro, K., Okstad, K. M., Nichols, J., Nygaard, T. A., Gao, Z., Manolas, D., Kim, K., Yu, Q., Shi, W., Park, H., Vasquez-Rojas, A., Dubois, J., Kaufer, D., Thomassen, P., de Ruiter, M. J., Peeringa, J. M., Zhiwen, H., and von Waaden, H.: Offshore Code Comparison Collaboration Continuation (OC4), Phase I – Results of Coupled Simulations of an Offshore Wind Turbine with Jacket Support Structure, Journal of Ocean and Wind Energy, 1, 1–11, 2014. a, b, c

Rasmussen, C. E. and Williams, C. K. I.: Gaussian processes for machine learning, MIT Press, Cambridge, MA, USA, 3rd print edn., 2008. a

Scholle, N., Radulović, L., Nijssen, R., Ibsen, L. B., Kohlmeier, M., Foglia, A., Natarajan, A., Thiel, J., Kuhnle, B., Kraft, M., Kühn, M., Brosche, P., and Kaufer, D.: Innovations on component level (final report), INNWIND.EU Deliverable D4.1.3, 2015. a

Smith, A., Stehly, T., and Musial, W.: 2014-2015 Offshore Wind Technologies Market Report, Technical Report NREL/TP-5000-64283, National Renewable Energy Laboratory, Golden, CO, USA, 2015. a, b

Stolpe, M. and Sandal, K.: Structural optimization with several discrete design variables per part by outer approximation, Struct. Multidiscip. O., 57, 2061–2073, https://doi.org/10.1007/s00158-018-1941-3, 2018. a

1

The ellipse perimeter is approximated in a very simple way here. However, the occurring eccentricities are in a range in which this simplification causes no significant error.

2

This statement means that the structural code checks allow wider ranges of the design parameters.

3

For some extreme load events, this is a rather low value. However, due to limited capacity of computational resources, it was decided to choose this length for all simulations.

4

The mean values are in accordance with practical experience and published information about jacket expenditures (Michels2014; National Wind Technology Center Information Portal2014). The standard deviation values reflect different dimensions of scatter in the unit costs.

Publications Copernicus
Download
Short summary
The present work provides a technical basis for the design of jacket structures used as substructures for offshore wind turbines. This involves models for the geometry, costs, and structural design code checks. An example application is shown in this paper, in which three different structural designs are compared. This work may lead to improved design approaches and finally to a cost reduction of offshore substructures.
The present work provides a technical basis for the design of jacket structures used as...
Citation