Modeling Options Inputs
The following inputs describe the options available in the modeling_options file.
WISDEM wind turbine modeling options schema
Type: objectSchema that describes the modeling options for WISDEM
Used to store file name of modeling options file
Prints additional outputs to screen (and to a file log in the future)
Number of iterations for the top-level coupling solver
Number of load cases
Value must be greater or equal to 0
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Number of angles of attack in a common grid to define polars
Number of coordinate point used to define airfoils
Number of spanwise stations in a common grid used to define blade properties
Number of wind speeds to compute the power curve
Number of wind speeds to spline the power curve
Number of pitch angles to determine the Cp-Ct-Cq-surfaces
Min pitch angle of the Cp-Ct-Cq-surfaces
Max pitch angle of the Cp-Ct-Cq-surfaces
Number of tsr values to determine the Cp-Ct-Cq-surfaces
Min TSR of the Cp-Ct-Cq-surfaces
Max TSR of the Cp-Ct-Cq-surfaces
Number of wind speeds to determine the Cp-Ct-Cq-surfaces
Flag to derive the regulation trajectory in region III in terms of pitch and TSR
If True, pitch is fixed in region I1/2, i.e. when min rpm is enforced.
Composite layer modeling the spar cap on the suction side in the geometry yaml. This entry is used to compute ultimate strains.
Composite layer modeling the spar cap on the pressure side in the geometry yaml. This entry is used to compute ultimate strains.
Composite layer modeling the trailing edge reinforcement on the suction side in the geometry yaml. This entry is used to compute ultimate strains.
Composite layer modeling the trailing edge reinforcement on the pressure side in the geometry yaml. This entry is used to compute ultimate strains.
Partial safety factor on modal frequencies
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Number of standard deviations for strength of gust
Value must be greater or equal to 0.0 and lesser or equal to 15.0
Safety factor for the max stress of blade root fasteners
Value must be greater or equal to 0.1 and lesser or equal to 100.0
Include Prandtl hub loss model in CCBlade calls
Include Prandtl tip loss model in CCBlade calls
Include effect of wake rotation (i.e., tangential induction factor is nonzero) in CCBlade calls
Use drag coefficient in computing induction factors in CCBlade calls
Number of sectors to divide rotor face into in computing thrust and power.
Value must be greater or equal to 1 and lesser or equal to 10
Flag switching on and off the 3d DU-Selig airfoil correction implemented in Polar.py
Whether or not to optimize the placement of the webs and caps in the blade for along maximum chordwise thickness.
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Partial safety factor on loads
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for materials
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for consequence of failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Value of desired torque density of the gearbox. If zero, DrivetrainSE sizes the gearbox.
Partial safety factor for hub sizing
Value must be greater or equal to 1.0 and lesser or equal to 7.0
Partial safety factor for spinner sizing
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Type of generator architecture for detailed property, performance, and cost modeling
Must be one of:
- "dfig"
- "eesg"
- "scig"
- "pmsg_outer"
- "pmsg_arms"
- "pmsg_disc"
- "DFIG"
- "EESG"
- "SCIG"
- "PMSG_Outer"
- "PMSG_Arms"
- "PMSG_Disc"
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Wind scaling relationship with height
Must be one of:
- "PowerWind"
- "LogisticWind"
Partial safety factor on loads
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for materials
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for consequence of failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for buckling
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor on modal frequencies
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for fatigue failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Buckling utilization calculation method- Eurocode 1994 or DNVGL RP-C202
Must be one of:
- "Eurocode"
- "Euro-code"
- "eurocode"
- "euro-code"
- "DNVGL"
- "dnvgl"
- "DNV-GL"
- "dnv-gl"
Buckling length factor in Eurocode safety check
Value must be greater or equal to 1.0 and lesser or equal to 100.0
Set of Frame3DD options used for tower analysis
Inclusion of shear area for symmetric sections
Inclusion of shear stiffening through axial loading
Eigenvalue solver 1=Subspace-Jacobi iteration, 2=Stodola (matrix iteration)
Must be one of:
- 1
- 2
Convergence tolerance for modal eigenvalue solution
Value must be greater or equal to 1e-12 and lesser or equal to 1e-1
Number of Frame3DD element refinements for every specified section along tower/member
Nikhar's method for modal identification
Can be monopile or jacket.
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Wind scaling relationship with height
Must be one of:
- "PowerWind"
- "LogisticWind"
Partial safety factor on loads
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for materials
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for consequence of failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for buckling
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor on modal frequencies
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for fatigue failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Buckling utilization calculation method- Eurocode 1994 or DNVGL RP-C202
Must be one of:
- "Eurocode"
- "Euro-code"
- "eurocode"
- "euro-code"
- "DNVGL"
- "dnvgl"
- "DNV-GL"
- "dnv-gl"
Buckling length factor in Eurocode safety check
Value must be greater or equal to 1.0 and lesser or equal to 100.0
Set of Frame3DD options used for tower analysis
Inclusion of shear area for symmetric sections
Inclusion of shear stiffening through axial loading
Eigenvalue solver 1=Subspace-Jacobi iteration, 2=Stodola (matrix iteration)
Must be one of:
- 1
- 2
Convergence tolerance for modal eigenvalue solution
Value must be greater or equal to 1e-12 and lesser or equal to 1e-1
If False, then a monopile is modeled with a perfectly clamped foundation. If True, then spring-stiffness equivalents are computed from soil properties for all DOF.
Model the monopile base as a gravity-based foundation with no pile embedment
Number of Frame3DD element refinements for every specified section along tower/member
Number of legs for the jacket. Only used if type==jacket.
Number of bays for the jacket, or x-joints per tower leg pair. Only used if type==jacket.
If true, add a mud brace at the bottom of each jacket leg. Only used if type==jacket.
If true, save .pngs of the jacket truss during analysis or optimization. Jacket only.
Nikhar's method for modal identification
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Distance between turbines in the primary grid streamwise direction in rotor diameters
Value must be greater or equal to 1 and lesser or equal to 100
Distance between turbine rows in the cross-wind direction in rotor diameters
Value must be greater or equal to 1 and lesser or equal to 100
Distance from centroid of plant to substation in km
Value must be greater or equal to 0 and lesser or equal to 1000
Distance from substation to grid connection in km
Value must be greater or equal to 0 and lesser or equal to 1000
Distance from plant centroid to export cable landfall for offshore plants
Value must be greater or equal to 0 and lesser or equal to 1000
Distance from port to plant centroid for offshore plants
Value must be greater or equal to 0 and lesser or equal to 1000
Voltage of cabling to grid interconnection
Value must be greater or equal to 0 and lesser or equal to 1000
Additional contingency cost during project construction
Value must be greater or equal to 0 and lesser or equal to 1.e4
Additional insurance cost during project construction
Value must be greater or equal to 0 and lesser or equal to 1.e4
Additional financing cost during project construction
Value must be greater or equal to 0 and lesser or equal to 1.e4
Additional BOS cost to commission the turbines and wind farm
Value must be greater or equal to 0 and lesser or equal to 1.e4
Additional BOS cost to decommission the turbines and wind farm
Value must be greater or equal to 0 and lesser or equal to 1.e4
Monthly port rental fees
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Cost to secure site lease
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Cost to do engineering site assessment
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Cost for additional review by permitting agencies, such as the U.S. Dept of Interior Bureau of Ocean Energy Management (BOEM)
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Cost to do construction planning
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Cost to do installation planning
Value must be greater or equal to 0 and lesser or equal to 1000000000.0
Suppress screen output (currently only works for ORBIT)
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Hour of the day where any work-related activities begin.
Value must be greater or equal to 0 and lesser or equal to 24
Hour of the day where any work-related activities end.
Value must be greater or equal to 0 and lesser or equal to 24
Distance, in km, that servicing equipment must travel daily to reach the wind farm.
Value must be greater or equal to 0 and lesser or equal to 1e3
Number of crew transfer vessels (offshore) or onsite trucks (land-based) that should be made available to the wind farm.
Value must be greater or equal to 1 and lesser or equal to 20
Number of heavy lift vessels (fixed-bottom offshore) or crawler cranes (land-based) that should be made available to the wind farm.
Value must be greater or equal to 1 and lesser or equal to 10
Number of tugboat groups that should be available to the port to tow floating turbines to port and back.
Value must be greater or equal to 1 and lesser or equal to 10
Hour of the day where any work-related activities begin for port-side repairs.
Value must be greater or equal to 0 and lesser or equal to 24
Hour of the day where any work-related activities end for port-side repairs.
Value must be greater or equal to 0 and lesser or equal to 24
Number of port-side crews available to work on simultaneous repairs for any at-port turbine.
Value must be greater or equal to 1 and lesser or equal to 100
Number of turbines that can be at port at once.
Value must be greater or equal to 1 and lesser or equal to 100
Distance, in km, that tugboats must travel to reach the wind farm for tow-to-port repairs.
Value must be greater or equal to 0 and lesser or equal to 1e3
Starting date, in MM/DD format; year will be inserted automatically based on input to years.
Starting date, in MM/DD format, for an annual period where the site is inaccessible.
Ending date, in MM/DD format, for an annual period where the site is inaccessible.
Starting date, in MM/DD format, for an annual period where traveling speed is reduced.
Ending date, in MM/DD format, for an annual period where traveling speed is reduced.
Reduced speed applied to servicing equipment in the reduced speed period.
Value must be greater or equal to 0 and lesser or equal to 100
Random seed for the internal random generator.
Value must be greater or equal to 1 and lesser or equal to 4294967295
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Number of Frame3DD element refinements for every specified section along tower/member
Set of Frame3DD options used for floating tower analysis
Inclusion of shear area for symmetric sections
Inclusion of shear stiffening through axial loading
Eigenvalue solver 1=Subspace-Jacobi iteration, 2=Stodola (matrix iteration)
Must be one of:
- 1
- 2
Numerical matrix diagonal adder for eigenvalue solve of unrestrained structure
Convergence tolerance for modal eigenvalue solution
Value must be greater or equal to 1e-12 and lesser or equal to 1e-1
If true, skip duplicate modes during identification
Partial safety factor on loads
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for materials
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for consequence of failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for buckling
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor on modal frequencies
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Partial safety factor for fatigue failure
Value must be greater or equal to 1.0 and lesser or equal to 5.0
Nikhar's method for modal identification
Whether or not to assume a symmetric mooring system
Data for a levelized cost of energy analysis.
Whether or not to run this module or pull from elastic properties
Must be one of:
- true
- false
- true
- false
- true
- false
- 0
- 1
- "user_elastic"
- "User_Elastic"
- "USER_ELASTIC"
Factor to model losses in annual energy production in a wind farm compared to the annual energy production at the turbine level (wakes mostly).
Value must be greater or equal to 0 and lesser or equal to 1
Fixed charge rate to compute the levelized cost of energy. See this for inspiration https://www.nrel.gov/docs/fy20osti/74598.pdf
Value must be greater or equal to 0 and lesser or equal to 1
Balance of stations costs expressed in USD per kW. See this for inspiration https://www.nrel.gov/docs/fy20osti/74598.pdf
Value must be greater or equal to 0 and lesser or equal to 10000
Operational expenditures expressed in USD per kW. See this for inspiration https://www.nrel.gov/docs/fy20osti/74598.pdf
Value must be greater or equal to 0 and lesser or equal to 1000
Number of turbines in the park, used to compute levelized cost of energy. Often wind parks are assumed of 600 MW. See this for inspiration https://www.nrel.gov/docs/fy20osti/74598.pdf
Value must be greater or equal to 0 and lesser or equal to 10000
Hourly loaded wage per worker including all benefits and overhead. This is currently only applied to steel, column structures.
Value must be greater or equal to 0.0 and lesser or equal to 1000.0
Cost per unit area for finishing and surface treatments. This is currently only applied to steel, column structures.
Value must be greater or equal to 0.0 and lesser or equal to 1000.0
Regression-based blade cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based hub cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based pitch system cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based spinner cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based low speed shaft cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based bearing cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based gearbox cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based cost of gearboxes based on torque, tuned in 2024
Value must be greater or equal to 0.0 and lesser or equal to 1000.0
Regression-based high speed side cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based generator cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based bedplate cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based yaw system cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based converter cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based transformer cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based HVAC system cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based nacelle cover cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based electrical plant connection cost/rating ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based nacelle platform cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based tower cost/mass ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Regression-based controller and sensor system cost/rating ratio
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
crane cost if present
Value must be greater or equal to 0.0 and lesser or equal to 1000000.0
Electricity price used to compute value in beyond lcoe metrics
Value must be greater or equal to 0.0 and lesser or equal to 1.0
Reserve margin price used to compute value in beyond lcoe metrics
Value must be greater or equal to 0.0 and lesser or equal to 10000.0
Capacity credit used to compute value in beyond lcoe metrics
Value must be greater or equal to 0.0 and lesser or equal to 1.0
Benchmark price used to nondimensionalize value in beyond lcoe metrics
Value must be greater or equal to 0.0 and lesser or equal to 1.0
This is only used if not running the full WISDEM turbine Group and you need to input the mass properties, forces, and moments for a tower-only analysis
Mass at external boundary of the system. For the tower, this would be the RNA mass.
Distance from system boundary to center of mass of the applied load. For the tower, this would be the RNA center of mass in tower-top coordinates.
No Additional ItemsEach item of this array must be:
Moment of inertia of external mass in coordinate system at the system boundary. For the tower, this would be the RNA MoI in tower-top coordinates.
No Additional ItemsEach item of this array must be:
The loading scenarios associated with the applied mass. For the tower, this would be operating, parked, etc.
No Additional ItemsEach item of this array must be:
Force vector applied at system boundary
No Additional ItemsEach item of this array must be:
Force vector applied at system boundary
No Additional ItemsEach item of this array must be:
Applied wind reference velocity, if necessary
The field :code:environment includes the data characterizing air and water where the wind turbine operates.
Gravitational acceleration
Value must be greater or equal to 0 and lesser or equal to 100.0
Density of air.
Value must be greater or equal to 0 and lesser or equal to 1.5
Dynamic viscosity of air.
Value must be greater or equal to 0 and lesser or equal to 2e-05
Atmospheric pressure of air
Value must be greater or equal to 0 and lesser or equal to 1000000.0
Vapor pressure of fluid
Value must be greater or equal to 0 and lesser or equal to 1000000.0
Shape factor of the Weibull wind distribution.
Value must be greater or equal to 1 and lesser or equal to 3
Speed of sound in air.
Value must be greater or equal to 330.0 and lesser or equal to 350.0
Shear exponent of the atmospheric boundary layer.
Value must be greater or equal to 0 and lesser or equal to 1
Density of water.
Value must be greater or equal to 950 and lesser or equal to 1100
Dynamic viscosity of water.
Value must be greater or equal to 0.001 and lesser or equal to 0.002
Water depth for offshore environment.
Value must be greater or equal to 0.0 and lesser or equal to 10000.0
Shear modulus of the soil.
Value must be greater or equal to 10000000.0 and lesser or equal to 500000000.0
Poisson ratio of the soil.
Value must be greater or equal to 0 and lesser or equal to 0.6
Average inflow wind speed. If different than 0, this will overwrite the V mean of the IEC wind class
Value must be greater or equal to 0.0 and lesser or equal to 20.0
Average height of the highest one-third of waves in a wave record or time series (meters)
Value must be greater or equal to 0.01 and lesser or equal to 200
Average period of the highest one-third of waves in a wave record or time series (seconds)
Value must be greater or equal to 0.05 and lesser or equal to 1000.0