WO2022270025A1 - Method and device for diagnosing remaining service life of wind power generator - Google Patents

Method and device for diagnosing remaining service life of wind power generator Download PDF

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Publication number
WO2022270025A1
WO2022270025A1 PCT/JP2022/009676 JP2022009676W WO2022270025A1 WO 2022270025 A1 WO2022270025 A1 WO 2022270025A1 JP 2022009676 W JP2022009676 W JP 2022009676W WO 2022270025 A1 WO2022270025 A1 WO 2022270025A1
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Prior art keywords
fatigue
remaining life
wind
diagnosing
blade
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PCT/JP2022/009676
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French (fr)
Japanese (ja)
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伸夫 苗村
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株式会社日立製作所
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Publication of WO2022270025A1 publication Critical patent/WO2022270025A1/en

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D1/00—Wind motors with rotation axis substantially parallel to the air flow entering the rotor 
    • F03D1/06—Rotors
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D17/00—Monitoring or testing of wind motors, e.g. diagnostics
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01M—TESTING STATIC OR DYNAMIC BALANCE OF MACHINES OR STRUCTURES; TESTING OF STRUCTURES OR APPARATUS, NOT OTHERWISE PROVIDED FOR
    • G01M99/00—Subject matter not provided for in other groups of this subclass
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/70—Wind energy
    • Y02E10/72—Wind turbines with rotation axis in wind direction

Definitions

  • the present invention relates to a method for diagnosing the remaining life of a wind power generator and a device for diagnosing the remaining life.
  • a megawatt class wind power generator As a megawatt class wind power generator, it has a rotor with blades attached radially to a rotating hub, a nacelle that supports the rotor via the main shaft, and a tower that supports the nacelle from below while allowing yaw rotation. is frequently used.
  • a wind power generator uses the ever-changing wind as an energy source to generate electricity. Therefore, when the wind speed and turbulence of the wind actually flowing into the wind turbine generator are weaker than the design conditions, there is a margin for fatigue to accumulate in the wind turbine generator, and it is often possible to operate the wind turbine generator for a longer period than the design life. Such extension of life is becoming more frequent, but when extending the life, it is necessary to accurately estimate how many years the target wind turbine generator can be operated in the future.
  • Patent Document 1 As a method for estimating the life of a wind power generator, in Patent Document 1, a strain sensor is attached to a small part of the wind power generator, and the design information of the wind power generator is used to estimate the degree of fatigue damage and remaining life at unmeasured positions. A method for estimating is proposed.
  • Patent Document 2 using the fluctuating dynamic pressure, which is the product of the average value and the standard deviation of the wind speed, the frequency distribution of the fluctuating dynamic pressure in the wind turbine generator to be diagnosed and the frequency of fluctuating dynamic pressure under design conditions.
  • a method to quantify the degree of fatigue accumulation from the distribution has been proposed. Also, by multiplying the fluctuating dynamic pressure by the thrust coefficient of the rotor and the moment coefficient of the blades, the dynamic characteristics are considered.
  • Patent Document 1 requires a strain sensor that is rarely installed in commercial wind power generators, and it is difficult to obtain the necessary design information unless you are a wind power generator manufacturer.
  • Patent Document 2 Although the method described in Patent Document 2 can be easily applied, the dynamic characteristics of the wind power generator that can be considered are limited to the thrust coefficient and moment coefficient. Therefore, if the mechanical properties change greatly depending on the wind speed and turbulence intensity, and the degree of fatigue accumulation is affected, it may be difficult to estimate the life with high accuracy.
  • the present invention has been made in view of such circumstances, and wind power generators can use only information that can be easily obtained to evaluate the remaining life of a wind power generator, taking into account the mechanical characteristics of the wind power generator. It is an object of the present invention to provide a method for diagnosing the remaining life of a wind power generator and a device for diagnosing the remaining life.
  • a method for diagnosing the remaining life of a wind turbine generator is a method for diagnosing the remaining life of a wind turbine generator using a remaining life diagnosis device, wherein the remaining life diagnosis device includes a fatigue model creation unit , a design fatigue calculation unit, an actual fatigue calculation unit, and a remaining life evaluation unit, and the fatigue model creation unit models the fatigue characteristics of the wind turbine generator (for example, the fatigue equivalent load acting on the wind turbine generator),
  • the design fatigue calculation unit calculates the design fatigue from the fatigue characteristics and the design wind conditions
  • the actual fatigue calculation unit calculates the actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator
  • the remaining life evaluation unit is characterized by calculating the remaining life using the design fatigue and the actual fatigue.
  • FIG. 1 is an overall schematic configuration diagram of a wind turbine generator according to an embodiment
  • FIG. It is a figure which shows the structure of the remaining-life diagnostic apparatus which concerns on this embodiment. It is a figure for demonstrating the in-plane direction and the out-of-plane direction of a blade.
  • FIG. 4 is a diagram for explaining a method of calculating a fatigue equivalent load in the in-plane direction of the blade;
  • FIG. 4 is a diagram for explaining an example of density distribution modes of blades;
  • FIG. 4 is a diagram for explaining the bending moment distribution of the blade;
  • FIG. 4 is a diagram for explaining the fatigue equivalent load in the in-plane direction of the blade;
  • FIG. 4 is a diagram for explaining a method of calculating a fatigue equivalent load in the in-plane direction of the blade;
  • FIG. 4 is a diagram for explaining an example of density distribution modes of blades;
  • FIG. 4 is a diagram for explaining the bending moment distribution of the blade;
  • FIG. 4 is
  • FIG. 4 is a diagram for explaining a method of calculating a fatigue equivalent load in the out-of-plane direction of the blade; It is a figure for demonstrating how to obtain
  • FIG. 4 is a diagram for explaining changes in equivalent fatigue load in the out-of-plane direction of the blade due to turbulence intensity.
  • FIG. 3 is a diagram for explaining wind speed frequency distributions under design wind conditions and actual wind conditions;
  • FIG. 1 is an overall schematic configuration diagram of a wind turbine generator 1 according to this embodiment.
  • the wind turbine generator 1 includes blades 2 that rotate with wind, a hub 3 that supports the blades 2, a nacelle 4, and a tower 5 that rotatably supports the nacelle 4.
  • the nacelle 4 there are a main shaft 6 connected to the hub 3 and rotating together with the hub 3, a gearbox 7 connected to the main shaft 6 and increasing the rotational speed, and a rotor driven at the rotational speed increased by the gearbox 7.
  • It has a generator 8 that rotates to generate power.
  • a portion that transmits the rotational energy of the blades 2 to the generator 8 is called a power transmission section, and in this embodiment, the main shaft 6 and the gearbox 7 are included in the power transmission section.
  • the gearbox 7 and generator 8 are held on the main frame 9 .
  • a rotor 10 is composed of the blades 2 and the hub 3 .
  • a power converter 11 for converting the frequency of power, a switching switch and transformer (not shown) for switching current, and a control device 12 are arranged.
  • a control device 12 for example, a control panel or SCADA (Supervisory Control And Data Acquisition) is used.
  • the wind turbine generator 1 shown in FIG. 1 shows an example in which the rotor 10 is composed of three blades 2 and a hub 3, it is not limited to this, and the rotor 10 consists of a hub 3 and at least one blade 2. may be configured
  • FIG. 2 is a diagram showing the configuration of the remaining life diagnostic device 20 according to this embodiment.
  • FIG. 2 shows the configuration of the remaining life diagnostic device 20 for the blades 2 of the wind turbine generator 1 shown in FIG.
  • the remaining life diagnosis device 20 includes a processing unit, an external storage unit, an input unit, a display unit, a communication unit, etc.
  • the processing unit includes a fatigue model creation unit 21, a design fatigue calculation unit 22, and an actual fatigue calculation unit 23, a remaining life evaluation unit 24 is provided.
  • the display unit is a display or the like, and displays the execution status and execution results of the processing by the remaining life diagnosis device 20 .
  • the input unit is a device such as a keyboard and a mouse for inputting instructions to the computer, and inputs instructions such as program activation.
  • the processing unit is a central processing unit (CPU) and executes various programs stored in memory.
  • the communication unit exchanges various data and commands with other devices via a LAN or the like.
  • the external storage unit stores various data for the remaining life diagnostic device 20 to execute processing.
  • the memory holds various programs and temporary data for the remaining life assessment device 20 to execute processing.
  • the fatigue model creation unit 21 estimates the shape of the blades 2 and the operating conditions of the wind power generator 1 using catalogs and monitoring devices for wind power generators, construction drawings, and known theoretical formulas, and uses numerical simulations to Equivalent fatigue loads acting on the blade 2 in the in-plane direction and out-of-plane direction are calculated.
  • FIG. 3 is a diagram for explaining the in-plane direction and the out-of-plane direction of the blade 2.
  • FIG. FIG. 3 illustrates definitions of the in-plane and out-of-plane directions.
  • Reference numeral 100 is a rear view of the nacelle 4 as seen from the rear. In this rear view 100, the rotation direction of the blades 2 (see broken lines) is the in-plane direction.
  • reference numeral 110 is a lateral view of the nacelle 4 viewed from the lateral direction, and in this lateral view 110, the longitudinal direction of the blades 2 (see broken lines) is the out-of-plane direction.
  • the processing in the fatigue model creation unit 21 differs depending on the diagnosis target.
  • components other than the blades for example, the tower 5, the main shaft 6, the gearbox 7, the generator 8, the main frame 9, etc. can be diagnosed.
  • FIG. 4 is a diagram for explaining the method of calculating the fatigue equivalent load in the in-plane direction of the blade.
  • FIG. 4 shows one method for modeling the in-plane fatigue equivalent load.
  • a density distribution estimation formula 403 represented by (Formula 1) below is constructed.
  • r n is the dimensionless length with 0 at the root of the blade and 1 at the tip
  • m(r n ) is the density distribution per unit length in the longitudinal direction of the blade
  • ⁇ (r n ) is the density distribution mode 401
  • R is the rotor radius 402 or blade length
  • A, B are unknown correction factors.
  • Equation 1 uses the 1.3 power of the rotor radius 402 (R), it does not necessarily have to be the 1.3 power.
  • the power of 1.5 is preferable, and with future weight reduction of blades, it is possible that a value smaller than the power of 1.3 will become appropriate.
  • ⁇ (r n ) is readily obtained by dividing the publicly available blade density distribution by R to the 1.3 power.
  • FIG. 5 is a diagram for explaining an example of the density distribution mode of the blade.
  • the horizontal axis is the dimensionless length with 0 at the root of the blade and 1 at the tip, and the vertical axis is the density distribution mode.
  • the upper part of FIG. 5 shows the shape of the blade 2 .
  • the density distribution of the blade 2 (blade density distribution mode) is, for example, a density distribution as shown in FIG.
  • the correction coefficients A and B in Equation 1 are determined by solving the following simultaneous equations 406 regarding blade mass 404 (M) and blade center of gravity 405 (CG).
  • FIG. 6 is a diagram for explaining the bending moment distribution of the blade 2.
  • the horizontal axis is the non-dimensional length with 0 at the root of the blade and 1 at the tip, and the vertical axis is the bending moment distribution.
  • the upper part of FIG. 6 shows the shape of the blade 2 . It is possible to calculate the blade bending moment distribution 408 (see FIG. 4) due to its own weight when the blade 2 is horizontal as shown in FIG. 6, and calculate the in-plane blade fatigue equivalent load 411 (see FIG. 4) can be used as a weighted amplitude for
  • the blade bending moment due to the blade's own weight when the blade is horizontal corresponds to the maximum amplitude of the moment acting on the blade. It can be estimated with accuracy.
  • the calculation of the blade fatigue equivalent load 411 in the in-plane direction requires the rotor rotation speed (rotation speed characteristic 410) for each operating wind speed of the wind power generator. This can be estimated using the method of least squares or the like from the information 409 of the wind speed and rotation speed included in the SCADA data.
  • the blade fatigue equivalent load 411 in the in-plane direction at an arbitrary wind speed at an arbitrary longitudinal position of the blade can be calculated.
  • FIG. 7 is a diagram for explaining the fatigue equivalent load in the in-plane direction of the blade.
  • the horizontal axis is the average wind speed
  • the vertical axis is the fatigue equivalent load in the in-plane direction.
  • the blade fatigue equivalent load 411 in the in-plane direction obtained is due to the blade's own weight, and the effects of blade vibration and the like are not considered, so a correction factor may be introduced as necessary.
  • the blade fatigue equivalent load 411 in the in-plane direction may be calculated by numerical simulation.
  • FIG. 8 is a diagram for explaining a calculation method of the fatigue equivalent load in the out-of-plane direction of the blade 2.
  • FIG. FIG. 8 shows one method for modeling out-of-plane fatigue equivalent loads.
  • a blade shape 801 is acquired from a photograph, a drawing, or the like, and a blade chord length distribution 802 is obtained based on a known blade length, root diameter, or the like.
  • the nacelle 4 as shown in FIG.
  • An appropriate shape can be obtained by photographing the blade 2 from the direction just beside the .
  • FIG. 9 is a diagram for explaining how to obtain the optimum circumferential speed ratio.
  • the horizontal axis indicates the average wind speed, and the vertical axis indicates the rotor rotation speed.
  • the gradient in the range where the rotor rotation speed changes with respect to the wind speed as shown in Fig. 9 is calculated by the method of least squares, etc., and divided by the rotor radius.
  • Get the speed ratio 803 TSR: Tip Speed Ratio).
  • TSR Tip Speed Ratio
  • ⁇ (r) is the torsion angle
  • ⁇ (r) is the angle of attack, which is the angle between the composite velocity vector consisting of wind speed and rotational speed and the blade chord length direction.
  • the angle of attack varies depending on the airfoil that forms the cross section of the blade 2.
  • the angle of attack at the maximum lift-to-drag ratio of the airfoil is often used. It is preferable to use a value such as 8 degrees on the inner side of the position and 4 degrees on the outer side.
  • Equation 4 is an example of giving each torsional distribution, and in recent years, the blade 2 is sometimes designed not for maximizing the amount of power generation but for minimizing the power generation cost, so another equation can be used. good.
  • FIG. 10 is a diagram for explaining rotation speed and pitch angle characteristics.
  • the diagram denoted by reference numeral 200 is a rotational speed characteristic diagram 200 when the horizontal axis is the wind speed and the vertical axis is the rotor rotational speed.
  • the figure 210 is a pitch angle characteristic diagram 210 when the horizontal axis is the wind speed and the vertical axis is the pitch angle.
  • a rotation speed/pitch angle characteristic 806 as shown in FIG. 10 can be estimated from the rotation speed characteristic diagram 200 and the pitch angle characteristic diagram 210 in FIG.
  • FIG. 11 is a diagram for explaining changes in fatigue equivalent load in the out-of-plane direction of the blade 2 due to turbulence intensity.
  • the horizontal axis is the average wind speed, and the vertical axis is the fatigue equivalent load in the out-of-plane direction. Since the fatigue equivalent load in the out-of-plane direction changes greatly depending on the turbulence intensity, it is desirable to perform simulations for various turbulence intensities and calculate the fatigue equivalent load for each turbulence intensity as shown in FIG. .
  • the blade density distribution 407 (see FIG. 4) can be estimated, in addition to the hydrodynamic calculation, aeroelastic calculation can be applied, and the effect of vibration of the blade 2 can be reflected in the in-plane and out-of-plane fatigue equivalent loads. .
  • a simple method can be used to calculate the out-of-plane blade fatigue equivalent load 807 (see FIG. 8).
  • the blade element momentum theory is used to calculate the fluid force when the blade 2 is positioned directly above and below the nacelle 4, the bending moment distribution is obtained, and the difference between the bending moments when directly above and below is calculated.
  • the load amplitude is raised to the power of the slope of the SN curve for the blade material and multiplied by the number of revolutions to obtain the out-of-plane blade fatigue equivalent load 807 (see FIG. 8).
  • Design fatigue calculator 22 Using the fatigue equivalent load obtained by the fatigue model generating unit 21 and the design wind conditions as described above, the design fatigue calculation unit 22 calculates fatigue accumulation in the design wind conditions.
  • the design wind conditions are determined by the type certification of the wind power generator, and are generally defined by the annual average wind speed and the turbulence class.
  • FIG. 12 is a diagram for explaining the wind speed frequency distribution under design wind conditions and actual wind conditions.
  • the horizontal axis is the average wind speed
  • the vertical axis is the wind speed frequency distribution.
  • FIG. 12 shows an example of the wind speed frequency distribution. It is preferable to use actual wind conditions, but the measured data is not always the same every year. Therefore, the design fatigue calculation unit 22 calculates fatigue accumulation in the design wind conditions. On the other hand, the actual fatigue calculation unit 23, which will be described later, calculates the accumulation of fatigue under actual wind conditions at the construction site of the wind turbine generator 1.
  • the turbulence class is used to correct the fatigue equivalent load.
  • the turbulence class is defined by I in (Equation 5) below.
  • the value of I specified as the design wind condition may be used to multiply the fatigue equivalent load by a correction value defined as a function of I.
  • the fatigue equivalent load after correction as shown in FIG. 11 is calculated for cases where the value of I is 0.16, 0.14, and 0.12 according to the magnitude of the turbulence intensity.
  • U in and U out are the cut-in and cut-out wind speeds representing the minimum and maximum wind speeds at which the wind turbine generator 1 generates power
  • ⁇ (U) is the frequency of wind speed generation
  • DEL′(U) is the corrected wind speed.
  • the fatigue equivalent load, m is the slope of the SN curve for the blade material.
  • ⁇ (U) is determined so that the integrated value of ⁇ (U) becomes the design life of the wind turbine generator 1 .
  • the actual fatigue calculation unit 23 uses (Formula 6) to calculate the D factor under the actual wind conditions at the construction site of the wind turbine generator 1 as the actual fatigue.
  • the fatigue equivalent load is corrected as necessary.
  • the turbulence class parameter I used for correction was obtained by calculating the 90% tile value of the turbulence intensity at each wind speed using the wind speed and turbulence intensity of the SCADA data representing the actual wind conditions. It is determined using the method of least squares or the like so that (Equation 5) is closest to the curve.
  • the wind speed frequency distribution ⁇ (U) under actual wind conditions as shown in FIG. 12 is obtained from the SCADA data, and D factor representing the accumulation of fatigue under actual wind conditions is calculated using Equation (6).
  • the D factor of (Equation 6) and the L of (Equation 7) are calculated for both the out-of-plane direction and the in-plane direction.
  • L calculated in the in-plane direction the smaller one may be considered as the remaining life of the blade 2 .
  • the fatigue equivalent load is calculated for a plurality of components including components other than the blade 2, the minimum value of L calculated for each is considered to be the remaining life of the wind power generator 1. good too.
  • the method for diagnosing the remaining life of the wind turbine generator 1 of the present embodiment is a method for diagnosing the remaining life of the wind turbine generator using the remaining life diagnosis device 20.
  • the remaining life diagnosis device 20 includes a fatigue model creation unit 21, a design fatigue It has a calculation unit 22, an actual fatigue calculation unit 23, and a remaining life evaluation unit 24, and the fatigue model creation unit 21 models the fatigue characteristics of the wind power generator 1 (for example, the fatigue equivalent load acting on the wind power generator),
  • the design fatigue calculation unit 22 calculates the design fatigue from the fatigue characteristics and the design wind conditions
  • the actual fatigue calculation unit 23 calculates the actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator
  • the life evaluator 24 is characterized by calculating remaining life using design fatigue and actual fatigue. For example, the fatigue equivalent load acting on the wind power generator is modeled from easily available information, and the design wind condition ⁇ By quantifying and comparing accumulated fatigue under actual wind conditions, the remaining life can be diagnosed with high accuracy.
  • the remaining life diagnostic device 20 of the wind turbine generator 1 having the above configuration, according to the embodiment, the remaining life of the blade can be diagnosed from easily available information.
  • the fatigue equivalent load is calculated by considering the blade mechanical properties that change significantly with wind speed and turbulence intensity, and fatigue accumulation is calculated using the fatigue equivalent load and the frequency of occurrence of wind speed and turbulence intensity.
  • the fluctuating dynamic pressure which is the product of the average value and the standard deviation of the wind speed, is multiplied by a thrust coefficient or a moment coefficient representing the dynamic characteristics at the average wind speed to calculate the accumulated fatigue. , it may not be possible to take into account changes in the thrust and moment coefficients that fluctuate within the standard deviation of the wind speed corresponding to turbulence.

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Abstract

The present invention provides a method for diagnosing the remaining service life of a wind power generator (1) using a remaining service life diagnostic device (20), wherein: the remaining service life diagnostic device (20) has a fatigue model creation unit (21), a design fatigue calculation unit (22), an actual fatigue calculation unit (23), and a remaining service life evaluation unit (24); the fatigue model creation unit (21) models the fatigue characteristics of the wind power generator 1 (e.g., a fatigue equivalent load acting on the wind power generator); the design fatigue calculation unit (22) calculates design fatigue from fatigue characteristics and design wind conditions; the actual fatigue calculation unit (23) calculates actual fatigue from the fatigue characteristics and the actual wind conditions at the site where the wind turbine generator is constructed; and the remaining service life evaluation unit (24) calculates the remaining service life using the design fatigue and the actual fatigue. For example, the remaining service life is diagnosed with high accuracy by modeling the fatigue equivalent load acting on the wind power generator from readily available information, and quantifying and comparing accumulation of fatigue under design and actual wind conditions from the obtained fatigue equivalent load and wind speed frequency distribution and turbulence intensity under the design and actual wind conditions.

Description

風力発電装置の余寿命診断方法および余寿命診断装置Remaining life diagnostic method and remaining life diagnostic device for wind turbine generator
　本発明は、風力発電装置の余寿命診断方法および余寿命診断装置に関する。 The present invention relates to a method for diagnosing the remaining life of a wind power generator and a device for diagnosing the remaining life.
　再生可能エネルギー活用への関心の高まりから、風力発電装置の世界的な市場拡大が予測されている。メガワット級の風力発電装置としては、ブレードを回転するハブに放射状に取りつけたロータと、主軸を介してロータを支持するナセルと、ナセルを下部からヨー回転を許して支持するタワーを備えているものが頻繁に用いられる。 Due to growing interest in the use of renewable energy, the global market for wind turbines is expected to expand. As a megawatt class wind power generator, it has a rotor with blades attached radially to a rotating hub, a nacelle that supports the rotor via the main shaft, and a tower that supports the nacelle from below while allowing yaw rotation. is frequently used.
　風力発電装置では、時々刻々と変化する風をエネルギー源として発電を行う。したがって、実際に風力発電装置に流入する風の風速や乱れが設計条件よりも弱い場合、風力発電装置に蓄積する疲労に余裕が生じ、設計寿命よりも長期間にわたって運転可能となることが多い。このような寿命の延長は頻繁に行われつつあるが、寿命延長の際には対象の風力発電装置が今後何年間、運転可能であるかを正確に見積もる必要がある。 A wind power generator uses the ever-changing wind as an energy source to generate electricity. Therefore, when the wind speed and turbulence of the wind actually flowing into the wind turbine generator are weaker than the design conditions, there is a margin for fatigue to accumulate in the wind turbine generator, and it is often possible to operate the wind turbine generator for a longer period than the design life. Such extension of life is becoming more frequent, but when extending the life, it is necessary to accurately estimate how many years the target wind turbine generator can be operated in the future.
　風力発電装置の寿命推定する方法として、特許文献１では風力発電装置のごく一部にひずみセンサを取り付け、風力発電装置の設計情報を用いることで、未計測位置での疲労損傷度および余寿命を推定する方法が提案されている。 As a method for estimating the life of a wind power generator, in Patent Document 1, a strain sensor is attached to a small part of the wind power generator, and the design information of the wind power generator is used to estimate the degree of fatigue damage and remaining life at unmeasured positions. A method for estimating is proposed.
　特許文献２では、風速の平均値と標準偏差の積である変動動圧を用いて、診断対象の風力発電装置での変動動圧の発生頻度分布と、設計条件での変動動圧の発生頻度分布とから疲労の蓄積度合いを定量化する方法が提案されている。また、変動動圧にロータのスラスト係数やブレードのモーメント係数を乗じることで、力学的特性を考慮する構成となっている。 In Patent Document 2, using the fluctuating dynamic pressure, which is the product of the average value and the standard deviation of the wind speed, the frequency distribution of the fluctuating dynamic pressure in the wind turbine generator to be diagnosed and the frequency of fluctuating dynamic pressure under design conditions. A method to quantify the degree of fatigue accumulation from the distribution has been proposed. Also, by multiplying the fluctuating dynamic pressure by the thrust coefficient of the rotor and the moment coefficient of the blades, the dynamic characteristics are considered.
特開２０１６－２１７１３３号公報JP 2016-217133 A 特開２０１６－１８８６１２号公報JP 2016-188612 A
　しかしながら、特許文献１に記載の方法は、商用風力発電装置では取り付けられることの少ないひずみセンサが必要であり、風力発電装置メーカでない限り必要な設計情報を入手することは困難である。 However, the method described in Patent Document 1 requires a strain sensor that is rarely installed in commercial wind power generators, and it is difficult to obtain the necessary design information unless you are a wind power generator manufacturer.
　一方、特許文献２に記載の方法は、容易に適用可能ではあるものの、考慮可能な風力発電装置の力学的特性はスラスト係数やモーメント係数に限定される。したがって、風速や乱流強度に応じて力学的特性が大きく変化し、疲労の蓄積度合いに影響を与える場合には、高精度な寿命推定が困難になる可能性がある。 On the other hand, although the method described in Patent Document 2 can be easily applied, the dynamic characteristics of the wind power generator that can be considered are limited to the thrust coefficient and moment coefficient. Therefore, if the mechanical properties change greatly depending on the wind speed and turbulence intensity, and the degree of fatigue accumulation is affected, it may be difficult to estimate the life with high accuracy.
　本発明はこのような状況を鑑みて成されたものであり、風力発電事業者であれば容易に入手可能な情報のみを用いて、風力発電装置の力学的特性を考慮した余寿命評価ができる風力発電装置の余寿命診断方法および余寿命診断装置を提供することを目的とする。 The present invention has been made in view of such circumstances, and wind power generators can use only information that can be easily obtained to evaluate the remaining life of a wind power generator, taking into account the mechanical characteristics of the wind power generator. It is an object of the present invention to provide a method for diagnosing the remaining life of a wind power generator and a device for diagnosing the remaining life.
　前記課題を解決するため、本発明の風力発電装置の余寿命診断方法は、余寿命診断装置を用いた風力発電装置の余寿命診断方法であって、前記余寿命診断装置は、疲労モデル作成部、設計疲労演算部、実疲労演算部および余寿命評価部を有し、前記疲労モデル作成部は、風力発電装置の疲労特性（例えば、風力発電装置に作用する疲労等価荷重）をモデル化し、前記設計疲労演算部は、前記疲労特性と設計風況とから設計疲労を計算し、前記実疲労演算部は、前記疲労特性と風力発電装置の建設地における実風況とから実疲労を計算し、前記余寿命評価部は、前記設計疲労と前記実疲労を用いて余寿命を計算することを特徴とする。本発明のその他の態様については、後記する実施形態において説明する。 In order to solve the above problems, a method for diagnosing the remaining life of a wind turbine generator according to the present invention is a method for diagnosing the remaining life of a wind turbine generator using a remaining life diagnosis device, wherein the remaining life diagnosis device includes a fatigue model creation unit , a design fatigue calculation unit, an actual fatigue calculation unit, and a remaining life evaluation unit, and the fatigue model creation unit models the fatigue characteristics of the wind turbine generator (for example, the fatigue equivalent load acting on the wind turbine generator), The design fatigue calculation unit calculates the design fatigue from the fatigue characteristics and the design wind conditions, the actual fatigue calculation unit calculates the actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator, The remaining life evaluation unit is characterized by calculating the remaining life using the design fatigue and the actual fatigue. Other aspects of the present invention are described in embodiments below.
　本発明によれば、風力発電事業者であれば容易に入手可能な情報のみを用いて、風力発電装置の力学的特性を考慮した余寿命評価ができる。 According to the present invention, it is possible for a wind power generation business operator to evaluate the remaining life of a wind power generator taking into account the mechanical characteristics thereof, using only information that can be easily obtained.
本実施形態に係る風力発電装置の全体概略構成図である。1 is an overall schematic configuration diagram of a wind turbine generator according to an embodiment; FIG. 本実施形態に係る余寿命診断装置の構成を示す図である。It is a figure which shows the structure of the remaining-life diagnostic apparatus which concerns on this embodiment. ブレードの面内方向および面外方向を説明するための図である。It is a figure for demonstrating the in-plane direction and the out-of-plane direction of a blade. ブレードの面内方向の疲労等価荷重の計算方法を説明するための図である。FIG. 4 is a diagram for explaining a method of calculating a fatigue equivalent load in the in-plane direction of the blade; ブレードの密度分布モードの例を説明するための図である。FIG. 4 is a diagram for explaining an example of density distribution modes of blades; ブレードの曲げモーメント分布を説明するための図である。FIG. 4 is a diagram for explaining the bending moment distribution of the blade; ブレードの面内方向の疲労等価荷重を説明するための図である。FIG. 4 is a diagram for explaining the fatigue equivalent load in the in-plane direction of the blade; ブレードの面外方向の疲労等価荷重の計算方法を説明するための図である。FIG. 4 is a diagram for explaining a method of calculating a fatigue equivalent load in the out-of-plane direction of the blade; 最適周速比の求め方を説明するための図である。It is a figure for demonstrating how to obtain|require an optimal peripheral speed ratio. 回転数及びピッチ角特性について説明するための図である。It is a figure for demonstrating rotation speed and a pitch angle characteristic. 乱流強度によるブレードの面外方向の疲労等価荷重の変化を説明するための図である。FIG. 4 is a diagram for explaining changes in equivalent fatigue load in the out-of-plane direction of the blade due to turbulence intensity. 設計風況及び実風況での風速頻度分布を説明するための図である。FIG. 3 is a diagram for explaining wind speed frequency distributions under design wind conditions and actual wind conditions;
　本発明を実施するための実施形態について、適宜図面を参照しながら詳細に説明する。
　図１は、本実施形態に係る風力発電装置１の全体概略構成図である。図１に示すように、風力発電装置１は、風を受けて回転するブレード２、ブレード２を支持するハブ３、ナセル４、及びナセル４を回動可能に支持するタワー５を備える。ナセル４内に、ハブ３に接続されハブ３と共に回転する主軸６、主軸６に接続され回転速度を増速する増速機７、及び増速機７により増速された回転速度で回転子を回転させて発電運転する発電機８を備えている。ブレード２の回転エネルギーを発電機８に伝達する部位は、動力伝達部と称され、本実施形態では、主軸６及び増速機７が動力伝達部に含まれる。そして、増速機７及び発電機８は、メインフレーム９上に保持されている。また、ブレード２及びハブ３によりロータ１０が構成される。 Embodiments for carrying out the present invention will be described in detail with reference to the drawings as appropriate.
FIG. 1 is an overall schematic configuration diagram of a wind turbine generator 1 according to this embodiment. As shown in FIG. 1, the wind turbine generator 1 includes blades 2 that rotate with wind, a hub 3 that supports the blades 2, a nacelle 4, and a tower 5 that rotatably supports the nacelle 4. As shown in FIG. In the nacelle 4, there are a main shaft 6 connected to the hub 3 and rotating together with the hub 3, a gearbox 7 connected to the main shaft 6 and increasing the rotational speed, and a rotor driven at the rotational speed increased by the gearbox 7. It has a generator 8 that rotates to generate power. A portion that transmits the rotational energy of the blades 2 to the generator 8 is called a power transmission section, and in this embodiment, the main shaft 6 and the gearbox 7 are included in the power transmission section. The gearbox 7 and generator 8 are held on the main frame 9 . A rotor 10 is composed of the blades 2 and the hub 3 .
　タワー５内の底部（下部）に、電力の周波数を変換する電力変換器１１、電流の開閉を行うスイッチング用の開閉器及び変圧器（図示せず）、及び制御装置１２などが配されている。制御装置１２として、例えば、制御盤又はＳＣＡＤＡ（Supervisory Control And Data Acquisition）が用いられる。 At the bottom (lower part) in the tower 5, a power converter 11 for converting the frequency of power, a switching switch and transformer (not shown) for switching current, and a control device 12 are arranged. . As the control device 12, for example, a control panel or SCADA (Supervisory Control And Data Acquisition) is used.
　なお、図１に示す風力発電装置１は、３枚のブレード２とハブ３にてロータ１０を構成する例を示すが、これに限られず、ロータ１０はハブ３と少なくとも１枚のブレード２にて構成してもよい。 Although the wind turbine generator 1 shown in FIG. 1 shows an example in which the rotor 10 is composed of three blades 2 and a hub 3, it is not limited to this, and the rotor 10 consists of a hub 3 and at least one blade 2. may be configured
　図２は、本実施形態に係る余寿命診断装置２０の構成を示す図である。図２は、図１で示した風力発電装置１のブレード２に対する余寿命診断装置２０の構成を示す。余寿命診断装置２０は、処理部、外部記憶部、入力部、表示部、通信部などを含んで構成され、処理部には、疲労モデル作成部２１、設計疲労演算部２２、実疲労演算部２３、余寿命評価部２４を備える。表示部は、ディスプレイなどであり、余寿命診断装置２０による処理の実行状況や実行結果などを表示する。入力部は、キーボードやマウスなどのコンピュータに指示を入力するための装置であり、プログラム起動などの指示を入力する。処理部は、中央演算処理装置（ＣＰＵ）であり、メモリに格納される各種プログラムを実行する。通信部は、ＬＡＮなどを介して、他の装置と各種データやコマンドを交換する。外部記憶部は、余寿命診断装置２０が処理を実行するための各種データを保存する。メモリは、余寿命診断装置２０が処理を実行する各種プログラムおよび一時的なデータを保持する。 FIG. 2 is a diagram showing the configuration of the remaining life diagnostic device 20 according to this embodiment. FIG. 2 shows the configuration of the remaining life diagnostic device 20 for the blades 2 of the wind turbine generator 1 shown in FIG. The remaining life diagnosis device 20 includes a processing unit, an external storage unit, an input unit, a display unit, a communication unit, etc. The processing unit includes a fatigue model creation unit 21, a design fatigue calculation unit 22, and an actual fatigue calculation unit 23, a remaining life evaluation unit 24 is provided. The display unit is a display or the like, and displays the execution status and execution results of the processing by the remaining life diagnosis device 20 . The input unit is a device such as a keyboard and a mouse for inputting instructions to the computer, and inputs instructions such as program activation. The processing unit is a central processing unit (CPU) and executes various programs stored in memory. The communication unit exchanges various data and commands with other devices via a LAN or the like. The external storage unit stores various data for the remaining life diagnostic device 20 to execute processing. The memory holds various programs and temporary data for the remaining life assessment device 20 to execute processing.
（疲労モデル作成部２１）
　疲労モデル作成部２１では、風力発電装置のカタログやモニタリング装置、施工図面や公知の理論式などを用いて、ブレード２の形状および風力発電装置１の運転条件を推定し、数値シミュレーションを用いて、ブレード２に作用する回転面内方向および面外方向の疲労等価荷重を計算する。 (Fatigue model creation unit 21)
The fatigue model creation unit 21 estimates the shape of the blades 2 and the operating conditions of the wind power generator 1 using catalogs and monitoring devices for wind power generators, construction drawings, and known theoretical formulas, and uses numerical simulations to Equivalent fatigue loads acting on the blade 2 in the in-plane direction and out-of-plane direction are calculated.
　図３は、ブレード２の面内方向および面外方向を説明するための図である。図３に回転面内と、面外方向の定義を図示する。符号１００は、ナセル４を後方から見た後方図であり、この後方図１００ではブレード２の回転方向（破線参照）を面内方向とする。一方、符号１１０は、ナセル４を横方向から見た横方向図であり、この横方向図１１０ではブレード２の前後方向（破線参照）を面外方向とする。 FIG. 3 is a diagram for explaining the in-plane direction and the out-of-plane direction of the blade 2. FIG. FIG. 3 illustrates definitions of the in-plane and out-of-plane directions. Reference numeral 100 is a rear view of the nacelle 4 as seen from the rear. In this rear view 100, the rotation direction of the blades 2 (see broken lines) is the in-plane direction. On the other hand, reference numeral 110 is a lateral view of the nacelle 4 viewed from the lateral direction, and in this lateral view 110, the longitudinal direction of the blades 2 (see broken lines) is the out-of-plane direction.
　図２に戻り、疲労モデル作成部２１内での処理は、診断対象ごとに異なり、実施形態ではブレード２の面内方向及び面外方向の荷重を対象とするが、この一方でもよく、診断対象はブレード２以外の風力発電装置１の構成要素でもよい。ブレード以外の構成要素としては、例えば、タワー５、主軸６、増速機７、発電機８、メインフレーム９などを診断対象にできる。 Returning to FIG. 2, the processing in the fatigue model creation unit 21 differs depending on the diagnosis target. may be components of the wind turbine generator 1 other than the blades 2 . As components other than the blades, for example, the tower 5, the main shaft 6, the gearbox 7, the generator 8, the main frame 9, etc. can be diagnosed.
　図４は、ブレードの面内方向の疲労等価荷重の計算方法を説明するための図である。図４に、面内方向の疲労等価荷重をモデル化するための一つの方法を示す。まず、典型的なブレードの密度分布モード４０１とロータ半径４０２から、以下の（式１）で表される密度分布推定式４０３を構築する。 FIG. 4 is a diagram for explaining the method of calculating the fatigue equivalent load in the in-plane direction of the blade. FIG. 4 shows one method for modeling the in-plane fatigue equivalent load. First, from a typical blade density distribution mode 401 and a rotor radius 402, a density distribution estimation formula 403 represented by (Formula 1) below is constructed.
Figure JPOXMLDOC01-appb-M000001
Figure JPOXMLDOC01-appb-M000001
　ここで、ｒｎはブレードの根元を０、先端を１とした無次元長さ、ｍ(ｒｎ)はブレードの長手方向の単位長さ当たり密度分布、Φ(ｒｎ)は密度分布モード４０１、Ｒはロータ半径４０２またはブレード長さ、Ａ、Ｂは未知の補正係数である。 Here, r n is the dimensionless length with 0 at the root of the blade and 1 at the tip, m(r n ) is the density distribution per unit length in the longitudinal direction of the blade, Φ(r n ) is the density distribution mode 401 , R is the rotor radius 402 or blade length, and A, B are unknown correction factors.
　発明者らの鋭意検討の結果、種々のブレードの密度分布ｍ(ｒｎ)をロータ半径４０２（Ｒ）の１.３乗で除した値は、おおよそ同様の分布Φ(ｒｎ)を持つことが明らかになった。したがって、このΦ(ｒｎ)とＲから密度分布を逆算することができる。ただし、Φ(ｒｎ)をそのまま用いると、ブレード質量４０４やブレード重心４０５が実物と異なる場合があるため、補正係数Ａ，Ｂを用いて、ブレード質量４０４とブレード重心４０５を実物と一致させる。 As a result of diligent studies by the inventors, it was found that the values obtained by dividing the density distribution m(r n ) of various blades by the 1.3 power of the rotor radius 402 (R) have approximately the same distribution Φ(r n ). became clear. Therefore, the density distribution can be back-calculated from this Φ(r n ) and R. However, if Φ(r n ) is used as it is, the blade mass 404 and the blade center of gravity 405 may differ from the real thing.
　なお、（式１）ではロータ半径４０２（Ｒ）の１．３乗を用いているが、必ずしも１.３乗である必要はない。過去には１.５乗がよいとする文献があり、今後のブレードの軽量化に伴って、１.３乗よりも小さな値が妥当となることもあり得る。Φ(ｒｎ)は一般に公開されているブレードの密度分布をＲの１.３乗で除すことで容易に入手できる。 Although (Equation 1) uses the 1.3 power of the rotor radius 402 (R), it does not necessarily have to be the 1.3 power. In the past, there is literature that the power of 1.5 is preferable, and with future weight reduction of blades, it is possible that a value smaller than the power of 1.3 will become appropriate. Φ(r n ) is readily obtained by dividing the publicly available blade density distribution by R to the 1.3 power.
　図５は、ブレードの密度分布モードの例を説明するための図である。図５において、横軸はブレードの根元を０、先端を１とした無次元長さであり、縦軸は密度分布モードである。図５の上側にブレード２の形状を示す。ブレード２の密度分布（ブレードの密度分布モード）は、例えば図５に示すような密度分布となる。 FIG. 5 is a diagram for explaining an example of the density distribution mode of the blade. In FIG. 5, the horizontal axis is the dimensionless length with 0 at the root of the blade and 1 at the tip, and the vertical axis is the density distribution mode. The upper part of FIG. 5 shows the shape of the blade 2 . The density distribution of the blade 2 (blade density distribution mode) is, for example, a density distribution as shown in FIG.
　式１の補正係数Ａ，Ｂは、ブレード質量４０４（Ｍ）とブレード重心４０５（ＣＧ）に関する下記の連立方程式４０６を解くことで決定される。 The correction coefficients A and B in Equation 1 are determined by solving the following simultaneous equations 406 regarding blade mass 404 (M) and blade center of gravity 405 (CG).
Figure JPOXMLDOC01-appb-M000002
Figure JPOXMLDOC01-appb-M000002
Figure JPOXMLDOC01-appb-M000003
Figure JPOXMLDOC01-appb-M000003
　ここで、ｒはブレードの根元からの距離、ＲＢはロータ半径Ｒからハブ半径を引いたブレード長さである。（式２）、（式３）は、未知の変数である補正係数Ａ，Ｂを含むため、これらを連立して解くことで補正係数Ａ，Ｂの値が一意に定まり、得られた補正係数Ａ，Ｂを式１に代入すると、図４に戻り、ブレード密度４０７が推定できる。ブレード密度４０７が分かれば、ブレード曲げモーメント分布４０８が計算できる。 where r is the distance from the root of the blade and RB is the blade length obtained by subtracting the hub radius from the rotor radius R. (Formula 2) and (Formula 3) include correction coefficients A and B, which are unknown variables. Substituting A and B into Equation 1, returning to FIG. 4, the blade density 407 can be estimated. Knowing the blade density 407, the blade bending moment distribution 408 can be calculated.
　図６は、ブレード２の曲げモーメント分布を説明するための図である。図６において、横軸はブレードの根元を０、先端を１とした無次元長さであり、縦軸は曲げモーメント分布である。図６の上側に、ブレード２の形状を示す。図６に示すようなブレード２が水平方向になった際の自重によるブレード曲げモーメント分布４０８（図４参照）を計算でき、これを面内方向のブレード疲労等価荷重４１１（図４参照）を計算するための加重振幅として使用できる。 FIG. 6 is a diagram for explaining the bending moment distribution of the blade 2. FIG. In FIG. 6, the horizontal axis is the non-dimensional length with 0 at the root of the blade and 1 at the tip, and the vertical axis is the bending moment distribution. The upper part of FIG. 6 shows the shape of the blade 2 . It is possible to calculate the blade bending moment distribution 408 (see FIG. 4) due to its own weight when the blade 2 is horizontal as shown in FIG. 6, and calculate the in-plane blade fatigue equivalent load 411 (see FIG. 4) can be used as a weighted amplitude for
　なお、面内方向では、ブレードが真横になった際の自重によるブレード曲げモーメントが、ブレードに作用するモーメントの最大振幅に対応するため、この自重によるモーメントのみを考慮すれば、疲労等価荷重を高精度に推定できる。 In the in-plane direction, the blade bending moment due to the blade's own weight when the blade is horizontal corresponds to the maximum amplitude of the moment acting on the blade. It can be estimated with accuracy.
　一方、図４に戻り、面内方向のブレード疲労等価荷重４１１の計算には、風力発電装置の運転風速ごとのロータ回転数（回転数特性４１０）が必要である。これは、ＳＣＡＤＡデータに含まれる風速と回転数の情報４０９から最小二乗法などを用いて推定できる。 On the other hand, returning to FIG. 4, the calculation of the blade fatigue equivalent load 411 in the in-plane direction requires the rotor rotation speed (rotation speed characteristic 410) for each operating wind speed of the wind power generator. This can be estimated using the method of least squares or the like from the information 409 of the wind speed and rotation speed included in the SCADA data.
　このようにして得たブレード曲げモーメント分布４０８と回転数特性４１０から、ブレードの任意の長さ方向位置における任意の風速での面内方向のブレード疲労等価荷重４１１を計算できる。 From the blade bending moment distribution 408 and the rotation speed characteristic 410 obtained in this way, the blade fatigue equivalent load 411 in the in-plane direction at an arbitrary wind speed at an arbitrary longitudinal position of the blade can be calculated.
　図７は、ブレードの面内方向の疲労等価荷重を説明するための図である。横軸は平均風速であり、縦軸は面内方向の疲労等価荷重である。例えば、図７に示すようなブレード根元での面内方向のブレード疲労等価荷重４１１（図４参照）を計算する場合、ブレード曲げモーメント分布４０８（図４参照）から根元での値を選択し、ブレード材料のＳＮ曲線の傾きでべき乗して、回転数特性４１０（図４参照）から得られる回転数を乗じると、疲労等価荷重が得られる。 FIG. 7 is a diagram for explaining the fatigue equivalent load in the in-plane direction of the blade. The horizontal axis is the average wind speed, and the vertical axis is the fatigue equivalent load in the in-plane direction. For example, when calculating the in-plane blade fatigue equivalent load 411 (see FIG. 4) at the blade root as shown in FIG. 7, select the value at the root from the blade bending moment distribution 408 (see FIG. 4), When raised to the power by the slope of the SN curve for the blade material and multiplied by the number of rotations obtained from the number of rotations characteristic 410 (see FIG. 4), the fatigue equivalent load is obtained.
　ただし、図４に戻り、得られる面内方向のブレード疲労等価荷重４１１はブレードの自重によるものであり、ブレードの振動などの影響は考慮されないため、必要に応じて補正係数を導入してもよい。あるいは、振動を考慮できるように、後述の面外方向の疲労等価荷重を計算する際に使用するブレード形状と、密度分布、回転数特性、回転数特性と同様の方法で取得できるピッチ角特性を用いて数値シミュレーションによって、面内方向のブレード疲労等価荷重４１１を計算してもよい。 However, returning to FIG. 4, the blade fatigue equivalent load 411 in the in-plane direction obtained is due to the blade's own weight, and the effects of blade vibration and the like are not considered, so a correction factor may be introduced as necessary. . Alternatively, in order to consider vibration, the blade shape used when calculating the fatigue equivalent load in the out-of-plane direction described later, the density distribution, the rotation speed characteristics, and the pitch angle characteristics that can be obtained in the same way as the rotation speed characteristics. The blade fatigue equivalent load 411 in the in-plane direction may be calculated by numerical simulation.
　図８は、ブレード２の面外方向の疲労等価荷重の計算方法を説明するための図である。図８に面外方向の疲労等価荷重をモデル化するための一つの方法を示す。まず、ブレード形状８０１を写真や図面などから取得し、既知のブレード長さや根元の直径などを基準として翼弦長分布８０２を得る。写真を用いる場合、例えば、風力発電装置１が停止しており、ブレード２が風による力を受けないフェザーとなった状態で、ブレード２が真下を向いているときに図１のようにナセル４の真横の方向から、ブレード２を撮影すると、妥当な形状を取得できる。 FIG. 8 is a diagram for explaining a calculation method of the fatigue equivalent load in the out-of-plane direction of the blade 2. FIG. FIG. 8 shows one method for modeling out-of-plane fatigue equivalent loads. First, a blade shape 801 is acquired from a photograph, a drawing, or the like, and a blade chord length distribution 802 is obtained based on a known blade length, root diameter, or the like. When using a photograph, for example, when the wind power generator 1 is stopped and the blades 2 are in a feathered state that does not receive the force of the wind, the nacelle 4 as shown in FIG. An appropriate shape can be obtained by photographing the blade 2 from the direction just beside the .
　図９は、最適周速比の求め方を説明するための図である。横軸は平均風速、縦軸はロータ回転数を示す。ＳＣＡＤＡ４０９のデータに含まれる風速と回転数から、図９に示すようなロータ回転数が風速に対して変化する範囲での勾配を最小二乗法などで計算し、ロータ半径で除すことで、周速比８０３（ＴＳＲ：Tip Speed Ratio）を得る。周速比８０３が分かると、例えば発電量を最大化する場合のブレード２のねじり角分布８０４を、以下の理論式によって求めることができる。 FIG. 9 is a diagram for explaining how to obtain the optimum circumferential speed ratio. The horizontal axis indicates the average wind speed, and the vertical axis indicates the rotor rotation speed. From the wind speed and rotation speed included in the SCADA409 data, the gradient in the range where the rotor rotation speed changes with respect to the wind speed as shown in Fig. 9 is calculated by the method of least squares, etc., and divided by the rotor radius. Get the speed ratio 803 (TSR: Tip Speed Ratio). Once the peripheral speed ratio 803 is known, for example, the torsion angle distribution 804 of the blade 2 when maximizing the amount of power generation can be obtained by the following theoretical formula.
Figure JPOXMLDOC01-appb-M000004
Figure JPOXMLDOC01-appb-M000004
　ここで、θ(ｒ)はねじり角、α(ｒ)は風速と回転速度からなる合成速度ベクトルと翼弦長方向とのなす角度である迎え角を示す。迎え角はブレード２の断面を構成する翼型によって異なるが、風力発電装置１では、翼型の最大揚抗比での迎え角が用いられることが多く、例えば、ブレード２の翼弦長が最大となる位置よりも内側では８度、外側では４度といった値を用いるとよい。 Here, θ(r) is the torsion angle, and α(r) is the angle of attack, which is the angle between the composite velocity vector consisting of wind speed and rotational speed and the blade chord length direction. The angle of attack varies depending on the airfoil that forms the cross section of the blade 2. In the wind turbine generator 1, the angle of attack at the maximum lift-to-drag ratio of the airfoil is often used. It is preferable to use a value such as 8 degrees on the inner side of the position and 4 degrees on the outer side.
　（式４）はねじり各分布を与える一例であり、近年では発電量の最大化ではなく、発電コストの最小化などでブレード２が設計されることもあることから、別の式を用いてもよい。 (Equation 4) is an example of giving each torsional distribution, and in recent years, the blade 2 is sometimes designed not for maximizing the amount of power generation but for minimizing the power generation cost, so another equation can be used. good.
　最後に、面内方向の疲労等価荷重でも述べたように、ＳＣＡＤＡ８０５のデータに含まれる風速と回転数およびピッチ角の情報から最小二乗法による線形回帰や移動平均などを用いて、回転数・ピッチ角特性８０６を推定する。 Finally, as described in the in-plane direction fatigue equivalent load, the wind speed, rotation speed, and pitch angle information included in the SCADA805 data were used to calculate the rotation speed and pitch using linear regression and moving averages using the least squares method. Estimate angular properties 806 .
　図１０は、回転数及びピッチ角特性について説明するための図である。図１０について、符号２００の図は、横軸を風速、縦軸をロータ回転数としたときの回転数特性図２００である。一方、符号２１０の図は、横軸を風速、縦軸をピッチ角としたときのピッチ角特性図２１０である。図１０に示すような回転数・ピッチ角特性８０６を、図１０の回転数特性図２００やピッチ角特性図２１０から推定することができる。 FIG. 10 is a diagram for explaining rotation speed and pitch angle characteristics. Regarding FIG. 10 , the diagram denoted by reference numeral 200 is a rotational speed characteristic diagram 200 when the horizontal axis is the wind speed and the vertical axis is the rotor rotational speed. On the other hand, the figure 210 is a pitch angle characteristic diagram 210 when the horizontal axis is the wind speed and the vertical axis is the pitch angle. A rotation speed/pitch angle characteristic 806 as shown in FIG. 10 can be estimated from the rotation speed characteristic diagram 200 and the pitch angle characteristic diagram 210 in FIG.
　これらの情報を用いると、翼素運動量理論や数値流体力学を用いたシミュレーションによって、ブレード２に作用する流体力を計算し、面外方向のブレード疲労等価荷重８０７を算出することができる。 Using this information, it is possible to calculate the fluid force acting on the blade 2 and calculate the blade fatigue equivalent load 807 in the out-of-plane direction through simulations using blade element momentum theory and computational fluid dynamics.
　図１１は、乱流強度によるブレード２の面外方向の疲労等価荷重の変化を説明するための図である。横軸は平均風速であり、縦軸は面外方向の疲労等価荷重である。面外方向の疲労等価荷重は、乱流強度によって大きく変化するため、シミュレーションは種々の乱流強度に対して行い、図１１に示すように乱流強度ごとの疲労等価荷重を算出することが望ましい。 FIG. 11 is a diagram for explaining changes in fatigue equivalent load in the out-of-plane direction of the blade 2 due to turbulence intensity. The horizontal axis is the average wind speed, and the vertical axis is the fatigue equivalent load in the out-of-plane direction. Since the fatigue equivalent load in the out-of-plane direction changes greatly depending on the turbulence intensity, it is desirable to perform simulations for various turbulence intensities and calculate the fatigue equivalent load for each turbulence intensity as shown in FIG. .
　ブレード密度分布４０７（図４参照）が推定できていれば、流体力の計算に加えて、空力弾性計算が適用でき、ブレード２の振動の影響を面内及び面外の疲労等価荷重に反映できる。あるいは、簡素な方法で面外方向のブレード疲労等価荷重８０７（図８参照）を計算することもできる。例えば、翼素運動量理論を用いてブレード２がナセル４の直上および直下に位置する際の流体力を計算し、曲げモーメント分布を求めて、直上および直下の際の曲げモーメントの差分として計算される荷重振幅を、ブレード材料のＳＮ曲線の傾きでべき乗して、回転数を乗じると、面外方向のブレード疲労等価荷重８０７（図８参照）が得られる。 If the blade density distribution 407 (see FIG. 4) can be estimated, in addition to the hydrodynamic calculation, aeroelastic calculation can be applied, and the effect of vibration of the blade 2 can be reflected in the in-plane and out-of-plane fatigue equivalent loads. . Alternatively, a simple method can be used to calculate the out-of-plane blade fatigue equivalent load 807 (see FIG. 8). For example, the blade element momentum theory is used to calculate the fluid force when the blade 2 is positioned directly above and below the nacelle 4, the bending moment distribution is obtained, and the difference between the bending moments when directly above and below is calculated. The load amplitude is raised to the power of the slope of the SN curve for the blade material and multiplied by the number of revolutions to obtain the out-of-plane blade fatigue equivalent load 807 (see FIG. 8).
（設計疲労演算部２２）
　以上のようにして、疲労モデル作成部２１で得られた疲労等価荷重と、設計風況を用いて、設計疲労演算部２２では、設計風況における疲労蓄積を計算する。設計風況は風力発電装置の型式認証などで定められており、一般的には年平均風速と乱流クラスで定義される。 (Design fatigue calculator 22)
Using the fatigue equivalent load obtained by the fatigue model generating unit 21 and the design wind conditions as described above, the design fatigue calculation unit 22 calculates fatigue accumulation in the design wind conditions. The design wind conditions are determined by the type certification of the wind power generator, and are generally defined by the annual average wind speed and the turbulence class.
　図１２は、設計風況及び実風況での風速頻度分布を説明するための図である。横軸は平均風速、縦軸は風速頻度分布である。図１２は、風速頻度分布の一例を示すもので、実風風況を用いるのがよいが、その測定データも毎年同じになるとは限らない。そこで、設計疲労演算部２２では、設計風況における疲労蓄積を計算する。他方、後述する実疲労演算部２３では、風力発電装置１の建設地における実風況での疲労蓄積を計算する。 FIG. 12 is a diagram for explaining the wind speed frequency distribution under design wind conditions and actual wind conditions. The horizontal axis is the average wind speed, and the vertical axis is the wind speed frequency distribution. FIG. 12 shows an example of the wind speed frequency distribution. It is preferable to use actual wind conditions, but the measured data is not always the same every year. Therefore, the design fatigue calculation unit 22 calculates fatigue accumulation in the design wind conditions. On the other hand, the actual fatigue calculation unit 23, which will be described later, calculates the accumulation of fatigue under actual wind conditions at the construction site of the wind turbine generator 1. FIG.
　まず、疲労等価荷重に乱流強度の影響が考慮されていない場合には、乱流クラスを用いて、疲労等価荷重を補正する。具体的には、上述の疲労等価荷重の計算方法で、面内方向の計算の際に数値シミュレーションを用いなかった場合や、面外方向の計算で簡素な方法を用いた場合、補正を施してもよい。ただし、面内方向については乱流の影響は小さいため、無視してもよい。補正の方法としては、例えば、乱流クラスを定義するパラメータを用いることが考えられる。乱流クラスは、以下の（式５）のIで定義される。 First, if the effect of turbulence intensity is not considered in the fatigue equivalent load, the turbulence class is used to correct the fatigue equivalent load. Specifically, in the calculation method of the fatigue equivalent load described above, if numerical simulation is not used for calculation in the in-plane direction, or if a simple method is used for calculation in the out-of-plane direction, correction is performed. good too. However, since the influence of turbulence in the in-plane direction is small, it can be ignored. As a correction method, for example, it is conceivable to use parameters that define the turbulence class. The turbulence class is defined by I in (Equation 5) below.
Figure JPOXMLDOC01-appb-M000005
Figure JPOXMLDOC01-appb-M000005
　ここで、Ｕは風速、ＴＩは乱流強度の９０％タイル値である。補正では、設計風況として指定されているＩの値を用いて、疲労等価荷重にＩの関数として定義される補正値を乗じたりすればよい。例えば、乱流強度の大小に応じて、Ｉの値が０．１６、０．１４、０．１２の場合に対して、図１１のような補正後の疲労等価荷重を計算する。このようにして得た補正後の疲労等価荷重と図１２に示すような年平均風速で定まるレイリー分布の風速頻度分布を用いて、下記の（式６）で定義されるＤｆａｃｔｏｒによって設計疲労を定量化する。 where U is the wind speed and TI is the 90% tile value of the turbulence intensity. For correction, the value of I specified as the design wind condition may be used to multiply the fatigue equivalent load by a correction value defined as a function of I. For example, the fatigue equivalent load after correction as shown in FIG. 11 is calculated for cases where the value of I is 0.16, 0.14, and 0.12 according to the magnitude of the turbulence intensity. Using the corrected fatigue equivalent load obtained in this way and the wind speed frequency distribution of the Rayleigh distribution determined by the annual average wind speed as shown in FIG. Quantify.
Figure JPOXMLDOC01-appb-M000006
Figure JPOXMLDOC01-appb-M000006
　ここで、Ｕｉｎ、Ｕｏｕｔは風力発電装置１が発電を行う最小風速と最大風速を表すカットイン、カットアウト風速、φ（Ｕ）は風速の発生頻度、ＤＥＬ′(Ｕ)は補正後の疲労等価荷重、ｍはブレード材料のＳＮ曲線の傾きである。設計疲労の計算では、φ（Ｕ）に設計風況の年平均風速で定義されるレイリー分布に従う風速頻度分布を用いるとよい。このとき、φ（Ｕ）の積分値が風力発電装置１の設計寿命となるように、φ（Ｕ）を定めておく。 Here, U in and U out are the cut-in and cut-out wind speeds representing the minimum and maximum wind speeds at which the wind turbine generator 1 generates power, φ(U) is the frequency of wind speed generation, and DEL′(U) is the corrected wind speed. The fatigue equivalent load, m, is the slope of the SN curve for the blade material. In calculating the design fatigue, it is preferable to use the wind speed frequency distribution according to the Rayleigh distribution defined by the annual average wind speed of the design wind condition for φ(U). At this time, φ(U) is determined so that the integrated value of φ(U) becomes the design life of the wind turbine generator 1 .
（実疲労演算部２３）
　実疲労演算部２３では、（式６）を用いて、風力発電装置１の建設地における実風況でのＤｆａｃｔｏｒを実疲労として計算する。まず、設計疲労演算部２２と同様に、必要に応じて疲労等価荷重に補正を施す。このとき、補正に用いる乱流クラスのパラメータIは、実風況を表すＳＣＡＤＡデータの風速、乱流強度を用いて、各風速での乱流強度の９０％タイル値を計算し、得られた曲線に（式５）が最接近するように最小二乗法などを用いて決定する。次に、ＳＣＡＤＡデータから図１２に示すような実風況での風速頻度分布φ（Ｕ）を求め、式６を用いて実風況での疲労蓄積を表すＤｆａｃｔｏｒを計算する。 (Actual fatigue calculator 23)
The actual fatigue calculation unit 23 uses (Formula 6) to calculate the D factor under the actual wind conditions at the construction site of the wind turbine generator 1 as the actual fatigue. First, similarly to the design fatigue calculation unit 22, the fatigue equivalent load is corrected as necessary. At this time, the turbulence class parameter I used for correction was obtained by calculating the 90% tile value of the turbulence intensity at each wind speed using the wind speed and turbulence intensity of the SCADA data representing the actual wind conditions. It is determined using the method of least squares or the like so that (Equation 5) is closest to the curve. Next, the wind speed frequency distribution φ(U) under actual wind conditions as shown in FIG. 12 is obtained from the SCADA data, and D factor representing the accumulation of fatigue under actual wind conditions is calculated using Equation (6).
（余寿命評価部２４）
　最後に、余寿命評価部２４では、設計疲労演算部２２および実疲労演算部２３で計算された、設計風況でのＤｆａｃｔｏｒ（Ｄｄ）と実風況でのＤｆａｃｔｏｒ（Ｄｒ）から、余寿命を計算する。診断対象である風力発電装置１のこれまでの運転期間をＴ０、Ｄｒの計算時に使用した風速頻度分布の基となるＳＣＡＤＡデータの取得期間をＴ１とすると、風力発電装置１のブレード２の余寿命Ｌは下記の（式７）で計算できる。 (Remaining life evaluation unit 24)
Finally , in the remaining life evaluation unit 24, the remaining Calculate lifespan. Assuming that the operating period of the wind power generator 1 to be diagnosed is T0 and the acquisition period of the SCADA data that is the basis of the wind speed frequency distribution used when calculating Dr is T1, the remaining life of the blade 2 of the wind power generator 1 is L can be calculated by the following (Equation 7).
　Ｌ＝Ｔ１／（Ｄｒ／Ｄｄ）－Ｔ０　　・・・（式７） 　L=T1/(Dr/Dd)-T0...(Formula 7)
　また、風力発電装置１のブレード２の現時点での疲労損傷度Ｄは、
　Ｄ＝（Ｄｒ×Ｔ０）／（Ｄｄ×Ｔ１）・・・（式８）
となる。Ｔ０＝Ｔ１のときは、ＤｒとＤｄの比Ｄｒ／Ｄｄが疲労損傷度となる。なお、面外方向、面内方向の両方の疲労等価荷重を計算している場合には、（式６）のＤｆａｃｔｏｒや（式７）のＬを両方に対して計算し、面外方向と面内方向に対して計算したＬのうち、小さい方をブレード２の余寿命と考えればよい。同様に、疲労等価荷重をブレード２以外の構成要素を含む複数の構成要素に対しても計算した場合には、各々に対して計算したＬの最小値を風力発電装置１の余寿命と考えてもよい。 Further, the fatigue damage degree D of the blades 2 of the wind power generator 1 at the present time is
D=(Dr×T0)/(Dd×T1) (Formula 8)
becomes. When T0=T1, the ratio Dr/Dd between Dr and Dd is the degree of fatigue damage. In addition, when calculating the fatigue equivalent load in both the out-of-plane direction and the in-plane direction, the D factor of (Equation 6) and the L of (Equation 7) are calculated for both the out-of-plane direction and the in-plane direction. Among L calculated in the in-plane direction, the smaller one may be considered as the remaining life of the blade 2 . Similarly, when the fatigue equivalent load is calculated for a plurality of components including components other than the blade 2, the minimum value of L calculated for each is considered to be the remaining life of the wind power generator 1. good too.
　本実施形態の風力発電装置１の余寿命診断方法は、余寿命診断装置２０を用いた風力発電装置の余寿命診断方法であって、余寿命診断装置２０は、疲労モデル作成部２１、設計疲労演算部２２、実疲労演算部２３および余寿命評価部２４を有し、疲労モデル作成部２１は、風力発電装置１の疲労特性（例えば、風力発電装置に作用する疲労等価荷重）をモデル化し、設計疲労演算部２２は、疲労特性と設計風況とから設計疲労を計算し、実疲労演算部２３は、疲労特性と風力発電装置の建設地における実風況とから実疲労を計算し、余寿命評価部２４は、設計疲労と実疲労を用いて余寿命を計算することが特徴である。例えば、容易に入手可能な情報から風力発電装置に作用する疲労等価荷重をモデル化し、得られた疲労等価荷重と設計風況・実風況での風速頻度分布および乱流強度から、設計風況・実風況での疲労蓄積を定量化・比較することで、高精度に余寿命を診断することができる。 The method for diagnosing the remaining life of the wind turbine generator 1 of the present embodiment is a method for diagnosing the remaining life of the wind turbine generator using the remaining life diagnosis device 20. The remaining life diagnosis device 20 includes a fatigue model creation unit 21, a design fatigue It has a calculation unit 22, an actual fatigue calculation unit 23, and a remaining life evaluation unit 24, and the fatigue model creation unit 21 models the fatigue characteristics of the wind power generator 1 (for example, the fatigue equivalent load acting on the wind power generator), The design fatigue calculation unit 22 calculates the design fatigue from the fatigue characteristics and the design wind conditions, the actual fatigue calculation unit 23 calculates the actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator, The life evaluator 24 is characterized by calculating remaining life using design fatigue and actual fatigue. For example, the fatigue equivalent load acting on the wind power generator is modeled from easily available information, and the design wind condition・By quantifying and comparing accumulated fatigue under actual wind conditions, the remaining life can be diagnosed with high accuracy.
　以上の構成を有する風力発電装置１の余寿命診断装置２０を用いることで、実施形態によれば、容易に入手可能な情報からブレードの余寿命を診断することができる。この実施形態では、風速と乱流強度に伴って大きく変化するブレードの力学的特性を考慮して疲労等価荷重を計算し、疲労等価荷重と風速及び乱流強度の発生頻度を用いて疲労蓄積を評価することで、高精度な余寿命診断が可能となる。一方、前述の特許文献２の方法では、風速の平均値と標準偏差の積である変動動圧に、平均風速での力学的特性を表すスラスト係数またはモーメント係数を乗じて疲労蓄積を計算するため、乱流に相当する風速の標準偏差の範囲で変動するスラスト係数やモーメント係数の変化を考慮できない可能性がある。 By using the remaining life diagnostic device 20 of the wind turbine generator 1 having the above configuration, according to the embodiment, the remaining life of the blade can be diagnosed from easily available information. In this embodiment, the fatigue equivalent load is calculated by considering the blade mechanical properties that change significantly with wind speed and turbulence intensity, and fatigue accumulation is calculated using the fatigue equivalent load and the frequency of occurrence of wind speed and turbulence intensity. By evaluating, highly accurate remaining life diagnosis becomes possible. On the other hand, in the method of Patent Document 2 described above, the fluctuating dynamic pressure, which is the product of the average value and the standard deviation of the wind speed, is multiplied by a thrust coefficient or a moment coefficient representing the dynamic characteristics at the average wind speed to calculate the accumulated fatigue. , it may not be possible to take into account changes in the thrust and moment coefficients that fluctuate within the standard deviation of the wind speed corresponding to turbulence.
　１　　風力発電装置
　２　　ブレード
　３　　ハブ
　４　　ナセル
　５　　タワー
　６　　主軸
　７　　増速機
　８　　発電機
　９　　メインフレーム
　１０　　ロータ
　１１　　電力変換器
　１２　　制御装置
　２０　　余寿命診断装置
　２１　　疲労モデル作成部
　２２　　設計疲労演算部
　２３　　実疲労演算部
　２４　　余寿命評価部
　４０１　　密度分布モード
　４０２　　ロータ半径
　４０３　　密度分布推定式
　４０４　　ブレード質量
　４０５　　ブレード重心
　４０６　　質量・重心の連立方程式
　４０７　　ブレード密度分布
　４０８　　ブレード曲げモーメント分布
　４０９　　ＳＣＡＤＡ（風速、回転数）
　４１０　　回転数特性
　４１１　　面内方向のブレード疲労等価荷重
　８０１　　ブレード形状
　８０２　　翼弦長分布
　８０３　　周速比
　８０４　　ねじり角分布
　８０５　　ＳＣＡＤＡ（風速、ピッチ角）
　８０６　　回転数・ピッチ角特性
　８０７　　面外方向のブレード疲労等価荷重 1 wind turbine generator 2 blade 3 hub 4 nacelle 5 tower 6 main shaft 7 gearbox 8 power generator 9 main frame 10 rotor 11 power converter 12 control device 20 remaining life diagnosis device 21 fatigue model creation unit 22 design fatigue calculation unit 23 actual Fatigue calculation unit 24 Remaining life evaluation unit 401 Density distribution mode 402 Rotor radius 403 Density distribution estimation formula 404 Blade mass 405 Blade center of gravity 406 Simultaneous equation of mass and center of gravity 407 Blade density distribution 408 Blade bending moment distribution 409 SCADA (wind speed, rotation speed)
410 Rotation speed characteristics 411 Blade fatigue equivalent load in the in-plane direction 801 Blade shape 802 Blade chord length distribution 803 Peripheral speed ratio 804 Torsion angle distribution 805 SCADA (wind speed, pitch angle)
806 Rotation speed/pitch angle characteristics 807 Out-of-plane blade fatigue equivalent load

Claims (13)

  1. 　余寿命診断装置を用いた風力発電装置の余寿命診断方法であって、
    　前記余寿命診断装置は、疲労モデル作成部、設計疲労演算部、実疲労演算部および余寿命評価部を有し、
    　前記疲労モデル作成部は、風力発電装置の疲労特性をモデル化し、
    　前記設計疲労演算部は、前記疲労特性と設計風況とから設計疲労を計算し、
    　前記実疲労演算部は、前記疲労特性と風力発電装置の建設地における実風況とから実疲労を計算し、
    　前記余寿命評価部は、前記設計疲労と前記実疲労を用いて余寿命を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     A method for diagnosing the remaining life of a wind power generator using a remaining life diagnosis device,
    The remaining life diagnosis device has a fatigue model creation unit, a design fatigue calculation unit, an actual fatigue calculation unit, and a remaining life evaluation unit,
    The fatigue model creation unit models the fatigue characteristics of the wind turbine generator,
    The design fatigue calculation unit calculates design fatigue from the fatigue characteristics and design wind conditions,
    The actual fatigue calculation unit calculates the actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator,
    A method for diagnosing the remaining life of a wind power generator, wherein the remaining life evaluation unit calculates the remaining life using the design fatigue and the actual fatigue.
  2. 　請求項１に記載の風力発電装置の余寿命診断方法において、
    　前記設計疲労演算部に用いられる前記設計風況が、年平均風速と乱流クラスによって定義される
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 1,
    A method for diagnosing the remaining life of a wind power generator, wherein the design wind condition used in the design fatigue calculation unit is defined by an annual average wind speed and a turbulence class.
  3. 　請求項２に記載の風力発電装置の余寿命診断方法において、
    　前記実疲労演算部に用いられる前記実風況が、前記風力発電装置で計測された風速および乱流強度である
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 2,
    A method for diagnosing the remaining life of a wind turbine generator, wherein the actual wind conditions used in the actual fatigue calculation unit are wind speed and turbulence intensity measured by the wind turbine generator.
  4. 　請求項１に記載の風力発電装置の余寿命診断方法において、
    　前記余寿命評価部は、前記実疲労を前記設計疲労で除した疲労損傷度を用いて、前記余寿命を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 1,
    The remaining life assessment method for a wind power generator, wherein the remaining life evaluation unit calculates the remaining life using a fatigue damage degree obtained by dividing the actual fatigue by the design fatigue.
  5. 　請求項１から４のいずれかに記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、前記風力発電装置の構成要素の疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to any one of claims 1 to 4,
    A method for diagnosing the remaining life of a wind power generator, wherein the fatigue model creation unit calculates a fatigue equivalent load of a component of the wind power generator.
  6. 　請求項５に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、前記風力発電装置のブレードの疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 5,
    A method for diagnosing the remaining life of a wind power generator, wherein the fatigue model creation unit calculates a fatigue equivalent load of a blade of the wind power generator.
  7. 　請求項６に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、前記風力発電装置で計測された風速と回転数を使用して前記ブレードの前記疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 6,
    A method for diagnosing a remaining life of a wind power generator, wherein the fatigue model creation unit calculates the fatigue equivalent load of the blade using wind speed and rotation speed measured by the wind power generator.
  8. 　請求項７に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、前記風力発電装置のロータ直径、ブレード質量、ブレード重心からロータ面内方向の前記ブレードの前記疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 7,
    The fatigue model creation unit calculates the fatigue equivalent load of the blade in the in-plane direction of the rotor from the rotor diameter, the blade mass, and the center of gravity of the blade of the wind turbine generator.
  9. 　請求項７に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、前記風力発電装置のブレード形状およびねじり角の理論式からロータ面外方向の前記ブレードの前記疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 7,
    A method for diagnosing a remaining life of a wind power generator, wherein the fatigue model creation unit calculates the fatigue equivalent load of the blade in the out-of-plane direction of the rotor from a theoretical formula of blade shape and torsion angle of the wind power generator.
  10. 　請求項９に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部で用いる前記ねじり角の理論式において、前記風力発電装置で計測された風速と回転数の関係から算出した最適周速比を用いる
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 9,
    Remaining life diagnosis of a wind power generator, characterized in that an optimum circumferential speed ratio calculated from a relationship between wind speed and rotation speed measured by the wind power generator is used in the theoretical formula of the torsion angle used in the fatigue model creation unit. Method.
  11. 　請求項９に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部で用いる前記ブレード形状には、前記ブレードの写真を用いる
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 9,
    A method for diagnosing the remaining life of a wind power generator, wherein a photograph of the blade is used as the shape of the blade used in the fatigue model creation unit.
  12. 　請求項１に記載の風力発電装置の余寿命診断方法において、
    　前記疲労モデル作成部は、ブレードの形状および風力発電装置の運転条件を推定し、数値シミュレーションを用いて、ブレードに作用する回転面内方向および面外方向の疲労等価荷重を計算する
    　ことを特徴とする風力発電装置の余寿命診断方法。     In the method for diagnosing the remaining life of a wind turbine generator according to claim 1,
    The fatigue model creation unit estimates the shape of the blade and the operating conditions of the wind power generator, and uses numerical simulation to calculate the equivalent fatigue load acting on the blade in the in-plane direction and out-of-plane direction. A method for diagnosing the remaining life of a wind turbine generator.
  13. 　風力発電装置の疲労特性をモデル化する疲労モデル作成部と、
    　前記疲労特性と設計風況とから設計疲労を計算する設計疲労演算部と、
    　前記疲労特性と風力発電装置の建設地における実風況とから実疲労を計算する実疲労演算部と、
    　前記設計疲労と前記実疲労を用いて余寿命を計算する余寿命評価部とを備える
    　ことを特徴とする風力発電装置の余寿命診断装置。     a fatigue model creation unit that models the fatigue characteristics of the wind power generator;
    a design fatigue calculation unit that calculates design fatigue from the fatigue characteristics and design wind conditions;
    an actual fatigue calculation unit that calculates actual fatigue from the fatigue characteristics and the actual wind conditions at the construction site of the wind turbine generator;
    A remaining life assessment device for a wind power generator, comprising: a remaining life evaluation unit that calculates a remaining life using the design fatigue and the actual fatigue.
PCT/JP2022/009676 2021-06-22 2022-03-07 Method and device for diagnosing remaining service life of wind power generator WO2022270025A1 (en)

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