WO2019150805A1 - Procédé et système de production d'énergie éolienne - Google Patents

Procédé et système de production d'énergie éolienne Download PDF

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Publication number
WO2019150805A1
WO2019150805A1 PCT/JP2018/046459 JP2018046459W WO2019150805A1 WO 2019150805 A1 WO2019150805 A1 WO 2019150805A1 JP 2018046459 W JP2018046459 W JP 2018046459W WO 2019150805 A1 WO2019150805 A1 WO 2019150805A1
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Prior art keywords
wind
load
shear
power generation
wind power
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PCT/JP2018/046459
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English (en)
Japanese (ja)
Inventor
伸夫 苗村
満 佐伯
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株式会社日立製作所
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Publication of WO2019150805A1 publication Critical patent/WO2019150805A1/fr

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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
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/04—Automatic control; Regulation
    • 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 wind power generation apparatus and a wind power generation system having a function of estimating a wind condition around the wind power generation apparatus.
  • a megawatt-class wind power generator is equipped with a rotor that is mounted radially on a hub that rotates blades, a nacelle that supports the rotor via a main shaft, and a tower that allows the nacelle to support yaw rotation from below. Is frequently used. Wind power generators generate electricity using wind that changes every moment as an energy source. Therefore, when the wind speed or turbulence of the wind that actually flows into the wind turbine generator is severer than the design conditions, the load on the wind turbine generator may increase and damage to the components may be accelerated.
  • Patent Literature 1 a table that associates wind speed, power generation amount or pitch angle, which has been created in advance, from wind speed data that can be obtained with a simple device configuration, and power generation amount or blade pitch angle data, and wind condition parameters.
  • a device that estimates the life of components of a wind turbine generator and outputs maintenance information using a table that associates wind parameters and fatigue loads applied to the wind turbine generator has been proposed.
  • a microwave or radar wave emitting device generally called a Doppler lidar is attached to a nacelle or hub of a wind power generator, and the wind speed distribution in front and rear of the wind power generator is measured, thereby improving the power generation efficiency.
  • Methods have been proposed to control the pitch angle of the blades so as to maximize or minimize the load on the wind turbine generator.
  • the present invention provides a wind power generation apparatus and a wind power generation system that can accurately estimate wind shear, which is a wind speed distribution, with a simple configuration.
  • a wind turbine generator includes at least a rotor, a nacelle, and a wind turbine generator that has a tower that rotatably supports the nacelle, and a control device that controls the wind turbine generator,
  • the control device includes a load measuring unit that measures a load applied to the wind turbine generator, a storage unit that stores a wind shear function that defines a relationship between the load and the wind shear, and a window based on the load and the wind shear function.
  • a wind condition estimation device having a wind speed distribution calculation unit for calculating shear is provided.
  • the wind power generation system includes at least one wind power generation device, a control device that controls the wind power generation device, an electronic terminal that includes a display device, and a communication network that connects these devices so that they can communicate with each other.
  • the control device includes a load measuring unit that measures a load applied to the wind turbine generator, a storage unit that stores a wind shear function that defines a relationship between the load and wind shear, and the load and wind shear function And a wind speed estimation device having a wind speed distribution calculation unit for calculating wind shear based on the above.
  • another wind power generation system includes at least one wind power generation device, a control device that controls the wind power generation device, an electronic terminal that includes a display device, and communication that connects these to each other so that they can communicate with each other.
  • a network including a load measuring unit that measures a load applied to the wind turbine generator, and the electronic terminal storing a wind shear function that defines a relationship between the load and the wind shear
  • a wind speed estimation device that calculates a wind shear based on the load input from the load measurement unit via the communication network and a wind shear function stored in the storage unit It is characterized by that.
  • FIG. 1 is an overall schematic configuration diagram of a wind power generation system according to an embodiment of the present invention. It is a figure which shows the structure of the wind power generator of Example 1 which concerns on one Example of this invention. It is a figure for demonstrating the wind shear in Example 1.
  • FIG. It is a functional block diagram of the control apparatus which comprises the wind power generator of Example 1.
  • FIG. It is a figure for demonstrating the principle of the wind condition estimation apparatus which comprises the control apparatus shown in FIG. It is a figure for demonstrating the relationship between a power index and the moment in a hub center. It is a figure for demonstrating the influence of the wind speed in the relationship between the hail index and the moment in a hub center.
  • FIG. 1 is an overall schematic configuration diagram of a wind power generation system according to an embodiment of the present invention.
  • the wind power generation system 1 includes a wind power generation device 2 and an electronic terminal 4 installed in the operation management center 3 or a server (not shown), which includes a communication network 5 that can communicate with each other. Connected through.
  • the communication network 5 may be wired or wireless.
  • the wind power generator 2 includes a blade 24 that rotates by receiving wind, a hub 23 that supports the blade 24, a nacelle 22, and a tower 21 that rotatably supports the nacelle 22.
  • a main shaft 26 that is connected to the hub 23 and rotates together with the hub 23, a speed increasing device 27 that is connected to the main shaft 26 and increases the rotational speed, and a rotor at a rotational speed increased by the speed increasing device 27.
  • a generator 28 that rotates to generate electricity is provided.
  • a portion that transmits the rotational energy of the blade 24 to the generator 28 is referred to as a power transmission unit.
  • the main shaft 26 and the speed increaser 27 are included in the power transmission unit.
  • the speed increaser 27 and the generator 28 are held on the main frame 29.
  • a rotor 25 is constituted by the blade 24 and the hub 23.
  • a power converter 30 for converting the frequency of power, a switching switch and a transformer for switching current (not shown), and control A device 31 and the like are arranged at the bottom (lower part) of the tower 21, a power converter 30 for converting the frequency of power, a switching switch and a transformer for switching current (not shown), and control A device 31 and the like are arranged.
  • the control device 31 for example, a control panel or SCADA (Supervision Control And Data Acquisition) is used.
  • FIG. 1 shows an example in which the rotor 25 is constituted by three blades 24 and a hub 23.
  • the present invention is not limited to this, and the rotor 25 is connected to the hub 23 and at least one blade 24. May be configured. Embodiments of the present invention will be described below with reference to the drawings.
  • FIG. 2 is a diagram showing the configuration of the wind turbine generator of Example 1 according to an example of the present invention.
  • the structure of the wind speed distribution 11 of the height direction around the wind power generator 2 which concerns on a present Example is shown.
  • FIG. 2 shows a state in which the wind turbine generator 2 is viewed from the side, and it is assumed that the wind is blowing from the left to the right of the page.
  • the wind turbine generator 2 includes a rotor 25 radially attached to a hub 23 that rotates blades 24, a nacelle 22 that allows the rotor 25 to rotate and supports the hub 23 from the side, and a nacelle And a tower 21 which rotatably supports 22 with respect to a vertical axis from the lower part.
  • the wind power generator 2 is a downwind type wind power generator in which the rotor 25 is located on the leeward side of the tower 21, but the upwind type wind power generator in which the rotor 25 is located on the windward side of the tower 21.
  • a device may be used.
  • the wind power generator 2 includes a strain sensor 7 attached to the tower 21.
  • the strain sensor 7 is not limited to the tower 21 and may be installed on the nacelle 22 or the hub 23. Instead of the strain sensor 7, another load sensor such as an acceleration sensor may be used.
  • the wind power generator 2 also includes a pitch angle control mechanism 6 for controlling the pitch angle of the blade 24, an anemometer 8 installed on the top of the nacelle 22, a thermometer 9 installed in the nacelle 22, and a barometer 10. May be provided.
  • the anemometer 8, the thermometer 9, and the barometer 10 may be installed at other positions of the wind power generator 2, or may be installed outside the wind power generator 2 as long as they are in the vicinity of the wind power generator 2. good.
  • the thermometer 9 and the barometer 10 may not be measured, and public observation data used for weather prediction or the like may be used.
  • the wind speed distribution 11 usually changes in the height direction (Z direction), and generally the wind speed tends to increase toward the sky due to the boundary layer of the atmosphere. If the change in the wind speed in the height direction (Z direction) is called wind shear, and the power index representing the strength is ⁇ WS , the wind speed distribution in the height direction (Z direction) is expressed by the following equation (1). Can be assumed.
  • V (z) is a wind speed at a height z from the ground surface
  • z ref is a height that defines a reference wind speed
  • V (z ref ) is a reference wind speed.
  • the change in the wind speed due to the height increases as the power index ⁇ WS increases.
  • the wind index measured by V (z ref ) in equation (1) and the height from the ground surface of the anemometer 8 are used as z ref.
  • ⁇ WS is known, a wind speed distribution in the height direction can be obtained. That is, when the wind speed distribution is assumed as shown in Equation (1), the wind speed distribution estimation problem results in the power index ⁇ WS estimation problem.
  • the wind speed distribution of Expression (1) is assumed and the power index ⁇ WS representing the strength of wind shear is estimated.
  • the assumption of the wind speed distribution is not limited to Expression (1), A logarithm, a polynomial, or the like may be used, and a wind speed distribution may be assumed using a plurality of parameters.
  • FIG. 4 is a functional block diagram of the control device 31 constituting the wind power generator 2 of the present embodiment.
  • the control device 31 includes a wind speed measurement unit 12, a load measurement unit 13, a temperature measurement unit 14, an atmospheric pressure measurement unit 15, a storage unit 16 that stores a wind shear function 33, an atmospheric density calculation unit 17, a wind A shear estimation unit 18, a wind speed distribution calculation unit 19, an input I / F 34, an output I / F 35, and a communication I / F 36 are provided and are connected to each other via an internal bus 37.
  • the wind speed measurement unit 12, the load measurement unit 13, the temperature measurement unit 14, the atmospheric pressure measurement unit 15, the storage unit 16 that stores the wind shear function 33, the atmospheric density calculation unit 17, the wind shear estimation unit 18, and the wind speed distribution calculation unit 19 are
  • the wind condition estimating device 32 is configured not only to estimate the power index ⁇ WS that defines the strength of wind shear but also to determine the actual wind speed distribution. Note that if only the power index ⁇ WS is estimated, the wind condition estimation device 32 is stored in the wind speed measurement unit 12, the load measurement unit 13, the temperature measurement unit 14, the atmospheric pressure measurement unit 15, and the wind shear function 33.
  • the air density calculation unit 17 and the wind shear estimation unit 18 may be used.
  • the estimation device 32 may be configured.
  • the wind speed measuring unit 12, the load measuring unit 13, the temperature measuring unit 14, the atmospheric pressure measuring unit 15, the atmospheric density calculating unit 17, the wind shear estimating unit 18, and the wind speed distribution calculating unit 19 constituting the wind condition estimating device 32 are, for example, , A processor such as a CPU (Central Processing Unit) (not shown), a ROM that stores various programs, a RAM that temporarily stores calculation process data, a storage device such as an external storage device, and a processor such as a CPU Reads out and executes various programs stored in the ROM, and stores the calculation result as the execution result in the RAM or the external storage device.
  • CPU Central Processing Unit
  • the wind speed measuring unit 12 calculates time series data of wind speed and average wind speed averaged over a predetermined time from the wind speed measured by the anemometer 8 and input via the input I / F 34 and the internal bus 37.
  • the wind speed measurement unit 12 transfers the average wind speed to the wind shear estimation unit 18 via the internal bus 37 and transfers the time series data of the wind speed to the wind speed distribution calculation unit 19.
  • the average wind speed may be calculated every 10 minutes, or the average value may be output continuously using a moving average.
  • the load measuring unit 13 inputs the strain of the tower 21 measured by the strain sensor 7 via the input I / F 34 and the internal bus 37, and the input measurement value of the strain of the tower 21 is measured at the measurement position. By multiplying the section modulus, it is converted into a bending moment. Further, the bending moment is averaged over a predetermined time and transferred to the wind shear estimation unit 18 via the internal bus 37.
  • the strain sensor 7 may be installed at one location, but when the wind direction changes, wind power generation is performed along the direction of the nacelle 22.
  • strain sensors 7 It is desirable to install two or more strain sensors 7 at the same height point of the tower 21 in order to calculate the bending moment component in the direction in which the device 2 is toppled.
  • the position in the height direction to which the strain sensor 7 is attached is preferably near the top of the tower 21, but correction can be made from the wind speed and the thrust coefficient of the rotor 25 without directly measuring the moment of the top. Therefore, it is not necessary to limit the measurement position to the top.
  • the temperature measurement unit 14 inputs the temperature measured by the thermometer 10 via the input I / F 34 and the internal bus 37, and calculates an average temperature for a predetermined time.
  • the temperature measurement unit 14 transfers the calculated average temperature to the atmospheric density calculation unit 17 via the internal bus 37.
  • the atmospheric pressure measurement unit 15 inputs the atmospheric pressure measured by the barometer 11 via the input I / F 34 and the internal bus 37, and calculates an averaged atmospheric pressure over a predetermined time.
  • the atmospheric pressure measurement unit 15 transfers the calculated average atmospheric pressure to the atmospheric density calculation unit 17 via the internal bus 37.
  • the atmospheric density calculation unit 17 calculates the atmospheric density from the temperature and the atmospheric pressure using the gas state equation, and transfers the average value of the atmospheric density to the wind shear estimation unit 18 via the internal bus 37 every 10 minutes, for example. To do. Note that other methods may be used as long as the atmospheric density can be calculated.
  • the wind shear estimating unit 18 receives the bending moment transferred from the load measuring unit 13, the average wind speed transferred from the wind speed measuring unit 12, and the average value of the atmospheric density transferred from the atmospheric density calculating unit 17 as inputs.
  • the wind shear function 33 that defines the relationship between the value of and the power index ⁇ WS representing the strength of wind shear
  • an estimated value of the power index ⁇ WS is output for each predetermined time used for averaging.
  • the average value of the bending moment, the average wind speed, and the atmospheric density is used as the input to the wind shear estimation unit 18.
  • the load measurement unit Only the bending moment transferred from 13 may be input, and in addition to the bending moment, one of the average wind speed or the average value of the atmospheric density may be used. Further, instead of the average wind speed, another physical quantity that changes in accordance with the wind speed may be used. For example, the amount of power generation, pitch angle, rotor rotational speed, etc. can be used.
  • the wind shear function 33 stored in the storage unit 16 stores a function that can uniquely output the power exponent ⁇ WS with respect to the average value of the bending moment, the average wind speed, and the atmospheric density.
  • the function storage method is not particularly limited, and may be a response surface, a neural network, a mathematical expression such as a polynomial, or a data table in which variables are separated by bins.
  • the function creation method is not particularly limited, but, for example, a Doppler lidar is temporarily attached to the top of the nacelle 22 constituting the wind power generator 2 and the power exponent ⁇ WS is calculated from the measured wind speed distribution by the least square method or the like.
  • the wind speed distribution calculation unit 19 uses the above formula (from the estimated value of the power index ⁇ WS obtained by the wind shear estimation unit 18 and the time series data of the wind speed transferred from the wind speed measurement unit 12 via the internal bus 37. 1) is used to calculate the time series data of the wind speed distribution. It is assumed that the height z ref from the ground surface of the anemometer 8 is known.
  • the output I / F 35 outputs the time series data of the wind speed distribution calculated by the wind speed distribution calculation unit 19 and transferred via the internal bus 37 to a display unit (not shown).
  • the communication I / F 36 is an electronic terminal 4 installed in the operation management center 3 via the communication network 5 by using the time series data of the wind speed calculated by the wind speed distribution calculation unit 19 and transferred via the internal bus 37. Or it transmits to the server which is not illustrated.
  • b is the length of the blade 24
  • ⁇ is the atmospheric density
  • C t is a local thrust coefficient at a distance r from the center of the hub 23 of the blade 24
  • V is a position r of a distance r from the center of the hub 23 of the blade 24
  • C is a chord length at a distance r from the center of the hub 23 of the blade 24.
  • b and c are values inherent to the blade 24 and are constant regardless of the operating conditions.
  • Ct is also a value inherent to the blade 24, but varies according to the pitch angle, wind speed, and rotational speed.
  • the wind speed has the distribution of the above formula (1) in the height direction, but does not change with time, and the pitch angle and the rotation speed are constant. Further, it is assumed that the rotor 25 does not have a tilt angle and a coning angle and rotates in a vertical plane. At this time, in the range where the blade 24 does not stall because the angle of attack of the blades 24 with increasing wind speed increases, C t is also monotonically increasing. Therefore, as can be seen from the above formula (2), when the local wind speed V increases, the thrust force T increases as C t V 2 increases.
  • z ref represents the height of the hub 23 in FIG. 3, and the wind speed is increased above the hub 23 as the power index ⁇ WS increases. It can be seen that the wind speed increases and the wind speed decreases below the hub 23. Therefore, as shown in FIG. 5, the thrust force T also increases above the hub 23 and decreases below the hub 23 as the power index ⁇ WS increases.
  • the moment in the direction in which the wind turbine generator 2 is toppled along the direction of the nacelle 22 at the center of the hub 23 when the blade 24 is at an arbitrary position in the plane of rotation, an increase in the power index ⁇ WS It can be seen that the moment increases monotonously with this.
  • the average value of moments at the center of the hub 23 during one rotation of the rotor 25 also increases monotonously as shown in FIG. 6 as the power index ⁇ WS increases. Therefore, when the air density and the wind speed at the center of the hub 23 are constant, the power index ⁇ WS can be estimated from the moment at the center of the hub 23.
  • the figure for demonstrating the relationship between the power index shown in FIG. 6 and the moment in a hub center is produced
  • the hub 23 is obtained by extrapolating the moment measured at two positions in the height direction of the tower 21 instead of the moment at the tower 21 measured by the strain sensor 7. It is also possible to calculate the moment at the center of. As for the wind speed and the atmospheric density, it is not necessary to use the value at the center of the hub 23, and it may be measured near the wind power generator 2.
  • the pitch angle and the rotational speed are constant, since these are generally determined by control according to the wind speed, when estimating the power index ⁇ WS using the wind speed, the pitch angle Even if the rotational speed changes, the influence on the estimation accuracy is small.
  • the tilt angle and the coning angle are values inherent to the wind power generator 2 and are constant regardless of the operating conditions, and thus do not affect the estimation accuracy.
  • the storage unit 16 that stores the wind shear function 33, the wind shear estimation unit 18, and the wind speed distribution calculation unit 19 that constitute the wind condition estimation device 32 are included in the control device 31.
  • the present invention is not limited to this.
  • the storage unit 16 storing the wind shear function 33, the wind shear estimation unit 18, and the wind speed distribution calculation unit 19 are connected to the electronic terminal 4 installed in the operation management center 3 shown in FIG. It is good also as a structure to mount.
  • FIG. 9 is a functional block diagram of the control device 31a constituting the wind turbine generator of the second embodiment according to another embodiment of the present invention.
  • the control device includes a reliability evaluation apparatus 40 that evaluates the reliability of the wind turbine generator 2 using the wind shear estimated by the wind shear estimation section 18 and the wind speed distribution calculation section 19 shown in the first embodiment.
  • the point provided inside is different from the first embodiment.
  • the same components as those in the first embodiment are denoted by the same reference numerals, and the description overlapping with that in the first embodiment is omitted below.
  • FIG. 9 only the input I / F 34, the wind shear estimation unit 18, the output I / F 35, the communication I / F 36, and the internal bus 37 are the same as in the first embodiment. Show.
  • the control device 31a in addition to the input I / F 34, the wind shear estimation unit 18, the output I / F 35, and the communication I / F 36, the control device 31a according to the present embodiment includes an operation condition acquisition unit 41, a load calculation unit. 42, a storage unit 16a for storing design information 43, a reliability evaluation unit 44, and an information output unit 45, which are connected to each other via an internal bus 37.
  • a reliability evaluation device 40 is configured by the operating condition acquisition unit 41, the load calculation unit 42, the storage unit 16a that stores the design information 43, the reliability evaluation unit 44, and the information output unit 45. Note that the reliability evaluation device 40 may not include the information output unit 45.
  • the wind shear estimation unit 18, the operation condition acquisition unit 41, the load calculation unit 42, the reliability evaluation unit 44, and the information output unit 45 are, for example, a processor such as a CPU (Central Processing Unit) (not shown) and a ROM that stores various programs.
  • a processor such as a CPU (Central Processing Unit) (not shown) and a ROM that stores various programs.
  • a processor such as a CPU reads out and executes various programs stored in the ROM, and an operation result that is an execution result Are stored in RAM or an external storage device.
  • the reliability evaluation device 40 will be described by taking as an example the reliability evaluation of the blades 24 of the wind turbine generator 2. Note that the application destination of the reliability evaluation device 40 is not necessarily limited to the blade 24, and other configurations of the wind power generator 2 such as the nacelle 22 and the tower 21 as long as the wind shear affects the reliability. Parts may be used.
  • the operating condition acquisition unit 41 acquires time history data of the operating conditions of the wind turbine generator 2 related to the load acting on the blade 24.
  • the operating conditions include, for example, the wind speed and wind direction at the anemometer 8, the pitch angle and azimuth angle of the blade 24, the rotational speed of the rotor 25, the azimuth angle of the nacelle 22, and the amount of power generated by the wind power generator 2.
  • a load sensor such as a strain sensor or an acceleration sensor
  • the time history data thereof may be included.
  • SCADA is used as the control device 31a
  • the operating conditions may be acquired from this SCADA.
  • the load calculating unit 42 uses the operating conditions transferred from the operating condition acquiring unit 41, the hull index ⁇ WS transferred from the wind shear estimating unit 18, and the design information 43 of the blade 24, and the load acting on the blade 24. Calculate the time history of.
  • the wind speed distribution (wind shear) flowing into the rotor 25 is calculated from the wind speed at the anemometer 8 and the power index ⁇ WS using the above formula (1), and the wind speed distribution and operating conditions are calculated. Is used as an input for aeroelastic simulation based on blade element momentum theory or multibody dynamics.
  • the design information 43 stored in the storage unit 16a includes, for example, the dimensions and mass distribution, rigidity distribution, aerodynamic coefficient of the blade 24 and the tower 21, the tilt angle and coning angle of the rotor 25, the dimension and mass distribution of the nacelle 22, and the aerodynamic coefficient. And design data such as a control program for the wind turbine generator 2.
  • the design information 25 stored in the storage unit 16a includes data relating to the reliability of the component parts of the blade 24 as reliability information, for example, the dimensions, elastic modulus, section coefficient, stress concentration factor, S- N diagram is included.
  • the reliability evaluation unit 44 performs reliability evaluation of the components of the blade 24 using the time history of the load acting on the blade 24 output from the load calculation unit 42 and the reliability information.
  • the fatigue damage degree, remaining life, failure probability, etc. are calculated for the component parts.
  • the degree of fatigue damage from load time history data there are the following methods. First, the time history of the stress acting on the component is calculated from the load acting on the blade 24. Next, the rain flow method is applied to the stress time history data to convert it into a stress amplitude appearance frequency distribution, and the S—of the component material stored in the obtained stress amplitude appearance frequency distribution and reliability information is stored. From the N diagram, the fatigue damage degree in the time history is calculated using the linear cumulative damage degree rule.
  • the information output unit 45 displays the evaluation results transferred from the reliability evaluation unit 44 via the internal bus 37 as a table, a graph, or a contour diagram.
  • data output from the operating condition acquisition unit 41, the wind shear estimation unit 18, and the load calculation unit 42 may be displayed.
  • the wind speed distribution flowing into the rotor 25 according to the above equation (1) using the wind speed at the anemometer 8 output from the operating condition acquisition unit 41 and the power index ⁇ WS output from the wind shear estimation unit 18. May be displayed.
  • the reliability evaluation device 40 is provided in the control device 31a.
  • the present invention is not limited to this, and the electronic terminal 4 installed in the operation management center 3 shown in FIG. 1 or not shown. It is good also as a structure mounted in a server.
  • the reliability evaluation device 40 in addition to the effects of the first embodiment, by using the reliability evaluation device 40, the wind shear time history data estimated from the operating conditions of the wind turbine generator and the load of the wind turbine generator. Based on the above, it becomes possible to evaluate the reliability of the wind turbine generator.
  • FIG. 10 is a functional block diagram of the control device 31b constituting the wind turbine generator of the third embodiment according to another embodiment of the present invention.
  • the present embodiment is different from the first embodiment in that the wind power generator 2 is controlled using the wind shear estimated by the wind shear estimation unit 18 and the wind speed distribution calculation unit 19 shown in the first embodiment.
  • the same components as those in the first embodiment are denoted by the same reference numerals, and the description overlapping with that in the first embodiment is omitted below.
  • FIG. 10 only the input I / F 34, the wind shear estimation unit 18, the output I / F 35, the communication I / F 36, and the internal bus 37 are the same as in the first embodiment. Show.
  • the control device 31b in addition to the input I / F 34, the wind shear estimation unit 18, the output I / F 35, and the communication I / F 36, the control device 31b according to the present embodiment includes an operation condition acquisition unit 41, a control amount calculation unit. 51 and a storage unit 16b for storing control information 52, which are connected to each other via an internal bus 37.
  • the wind shear estimation unit 18, the operation condition acquisition unit 41, and the control amount calculation unit 51 temporarily store, for example, a processor (not shown) such as a CPU (Central Processing Unit), a ROM that stores various programs, and calculation process data.
  • a processor such as a CPU reads out and executes various programs stored in the ROM, and stores an operation result as an execution result in the RAM or the external storage device.
  • the operating condition acquisition unit 41 acquires the operating conditions of the wind turbine generator 2 as in the second embodiment.
  • the control amount calculation unit 51 includes an operation condition transferred from the operation condition acquisition unit 41 via the internal bus 37, a power index ⁇ WS transferred from the wind shear estimation unit 18 via the internal bus 37, and control information 52.
  • the pitch angle of the blade 24 and the rotational speed of the rotor 25 can be determined by, for example, maximizing the power generation amount or minimizing the load fluctuation of the blade 24. Note that the pitch angle may change while the rotor 25 rotates once.
  • the wind speed distribution flowing into the rotor 4 is calculated from the wind speed at the anemometer 8 and the power exponent ⁇ WS using the above-described equation (1), and the flow into the blade 24 is obtained for any rotor rotational speed.
  • the storage unit 16 b stores constants used for control and aerodynamic characteristics of the blade 24 as the control information 52.
  • the above-described control amount output from the control amount calculation unit 51 is output to the generator 28, the pitch angle control mechanism 6 and the like via the internal bus 37 and the output I / F 35.
  • the wind turbine generator is controlled based on the operating conditions of the wind turbine generator and the wind shear time history data estimated from the load of the wind turbine generator. It is possible to maximize the power generation amount and minimize the blade load fluctuation.
  • FIG. 11 is a diagram showing a configuration of a wind turbine generator of Example 4 according to another example of the present invention.
  • the present embodiment is different from the first embodiment in that horizontal wind shear is estimated using the wind condition estimating device 32 of the wind turbine generator 2 of the first embodiment described above.
  • the same components as those in the first embodiment are denoted by the same reference numerals, and the description overlapping with that in the first embodiment is omitted below.
  • FIG. 11 shows the configuration of the wind power generator 2 and the horizontal wind speed distribution 61 around it.
  • the state which looked at the wind power generator 2 from upper direction is shown, and the wind shall blow from the paper surface left to the right.
  • the wind power generator 2 has the same configuration as that of the first embodiment.
  • the horizontal wind speed distribution 61 shown in FIG. 11 changes in the horizontal direction. If the coefficient representing the strength of wind shear in the horizontal direction is ⁇ WS , the horizontal wind speed distribution 61 is expressed by the following equation (3). Can be assumed as follows.
  • V (y) is a wind speed at a position y in a direction perpendicular to the wind speed vector on the horizontal plane
  • y ref is a position defining a reference wind speed
  • V (y ref ) is a reference wind speed.
  • the wind speed distribution estimation problem results in the coefficient ⁇ WS estimation problem.
  • the coefficient ⁇ WS representing the strength of the wind shear in the horizontal direction is estimated on the assumption of the wind speed distribution of Expression (3), but the assumption of the wind speed distribution is limited to Expression (3). There is no need to do so, and a wind speed distribution may be assumed using a plurality of parameters.
  • the configuration of the wind condition estimating device 32 of the wind turbine generator 2 in this embodiment for estimating the coefficient ⁇ WS that defines the strength of wind shear in the horizontal direction is the same as that in the first embodiment.
  • the load measuring unit 13 measures the shear strain of the tower 21 using the strain sensor 7 and twists using the sectional secondary pole moment and the radius of the tower 21 at the measurement position. Convert to moment. Further, the twisting moment is averaged over a predetermined time and output. Since the torsional moment acts uniformly in the cross section of the tower 21, the strain sensor 7 may be installed at one place, and the position in the height direction need not be particularly limited.
  • a wind shear estimation unit 18 receives the average values of torsional moment, wind speed, and atmospheric density as input, and defines a relationship between these values and a coefficient ⁇ WS representing the strength of wind shear in the horizontal direction.
  • an estimated value of the coefficient ⁇ WS is output at every predetermined time used for averaging.
  • the torsional moment, wind speed, and atmospheric density are used as the input to the wind shear estimation unit 18.
  • the estimated accuracy of the coefficient ⁇ WS can be lowered, only the torsional moment may be input.
  • either the wind speed or the atmospheric density may be used.
  • the amount of power generation, pitch angle, rotor rotational speed, etc. can be used.
  • the torsional moment is also generated due to a deviation between the nacelle 22 called the yaw error and the wind direction. Therefore, by adding the yaw error to the input of the wind shear estimation unit 18, high accuracy can be achieved.
  • the wind shear function 33 is defined as a function that can uniquely output the coefficient ⁇ WS with respect to the input values of torsional moment, wind speed, and atmospheric density.
  • the function storage method and the creation method are not particularly limited, and the same method as in the first embodiment may be used.
  • the wind speed distribution calculating unit 19 uses the estimated value of the coefficient ⁇ WS obtained by the wind shear estimating unit 18 and the time series data of the wind speed obtained by the wind speed measuring unit 12 to calculate the time of the wind speed distribution using the above equation (3). Series data is calculated.
  • the principle of horizontal wind shear estimation by the wind condition estimation device 32 is the same as that of the first embodiment except for the following points. That is, the moment acting on the center of the hub 23 by the horizontal wind shear is generated in the direction in which the nacelle 22 is rotated in the horizontal plane. Therefore, since the torsional moment acts on the tower 21, it is necessary to measure the torsional moment in order to estimate the coefficient ⁇ WS . In addition, by simultaneously measuring the bending moment and the torsional moment of the tower 21, the wind shear in the height direction (Z direction) and the horizontal direction (y direction) in the first embodiment and the fourth embodiment may be estimated simultaneously. The estimated horizontal wind shear may be input to the reliability evaluation device 40 of the second embodiment and the control device 31b of the third embodiment.
  • FIG. 12 is a diagram showing a configuration of a wind turbine generator of Example 5 according to another example of the present invention.
  • This embodiment is different from the first embodiment in that the strain sensor 7 installed in the tower 21 shown in the first embodiment is installed in the blade 24.
  • the same components as those in the first embodiment are denoted by the same reference numerals, and the description overlapping with that in the first embodiment is omitted below.
  • FIG. 12 shows the configuration of the wind power generator 2 according to the present embodiment and the wind speed distribution 11 in the height direction around the wind power generator 2.
  • the wind power generator 2 includes the strain sensor 7 on the blade 24 in place of the tower 21 in addition to the configuration similar to that of the first embodiment.
  • the strain sensor 7 only needs to be attached to at least one blade 24 constituting the rotor 25, and another load sensor such as an acceleration sensor may be used instead of the strain sensor 7.
  • the configuration of the wind condition estimating device 32 of the wind turbine generator 2 according to the present embodiment for estimating the power index ⁇ WS that defines the strength of wind shear is the same as that of the first embodiment.
  • the load measuring unit 13 measures the strain of the blade 24 using the strain sensor 7 and multiplies the section coefficient at the measurement position to convert it into a bending moment. Further, the bending moment is statistically processed and a statistical value is output.
  • the statistical value for example, a standard deviation of a bending moment at a predetermined time, a difference between a maximum value and a minimum value (maximum amplitude), or the like is used.
  • the average value for each bin may be used by dividing the azimuth angle by bins, or the strain sensors 7 are attached to all the blades 24 constituting the rotor 25, and the center of the hub 23 is determined from the bending moment of each blade 24. A value obtained by calculation of the moment may be used.
  • the strain sensor 7 may be installed at one place, it is desirable to install two or more strain sensors 7 at the same position in the longitudinal direction of the blade 24 in order to calculate the moment component that bends the blade 24 in the wind direction.
  • the strain sensor 7 is preferably attached near the blade root of the blade 24, but the measurement position need not be limited to the vicinity of the blade root.
  • the wind shear estimation unit 18 receives as input the statistical value of the bending moment of the blade 24, the wind speed, and the average value of the atmospheric density, and defines a relationship between these values and the power index ⁇ WS representing the strength of the wind shear. By using 33, an estimated value of the power exponent ⁇ WS is output every predetermined time.
  • the bending moment, the wind speed, and the atmospheric density are used as the input to the wind shear estimation unit 18.
  • the estimated accuracy of the power index ⁇ WS can be lowered, only the bending moment may be input.
  • one of wind speed or atmospheric density may be used.
  • the wind speed other physical quantities that change in accordance with the wind speed may be used. For example, the amount of power generation, pitch angle, rotor rotational speed, etc. can be used.
  • the principle of wind shear estimation by the wind condition estimating device 32 is the same as that of the first embodiment except for the following points. That is, the thrust force acting on the blade 24 by wind shear changes according to the azimuth angle, as shown in FIG. 5, and therefore the bending moment measured by the strain sensor 7 also changes according to the azimuth angle. Therefore, the power index ⁇ WS can be estimated by expressing the fluctuation range of the bending moment acting on the blade 24 during one rotation of the rotor 25 using the standard deviation and the maximum amplitude. Further, the power exponent ⁇ WS can be estimated from the magnitude of the value of the bending moment at a certain azimuth angle without using the fluctuation range of the bending moment in one rotation. For example, as shown in FIG.
  • the bending moment and the thrust force when the blade 24 is positioned directly above the hub 23 monotonically increase with the increase of the power index ⁇ WS , and therefore, from these values, the power index ⁇ WS Can be estimated.
  • the strain sensors 7 are attached to all the blades 24 constituting the rotor 25 and the moment at the center of the hub 23 is calculated from the bending moment of each blade 24, the window is operated on the same principle as in the first embodiment. Shea can be estimated.
  • the horizontal wind shear can be estimated, or the height direction and horizontal wind shear may be estimated simultaneously. Further, the estimated wind shear may be input to the reliability evaluation device 40 of the second embodiment and the control device 31b of the third embodiment.
  • this invention is not limited to the above-mentioned Example, Various modifications are included.
  • the above-described embodiments have been described in detail for easy understanding of the present invention, and are not necessarily limited to those having all the configurations described.
  • a part of the configuration of one embodiment can be replaced with the configuration of another embodiment, and the configuration of another embodiment can be added to the configuration of one embodiment.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Wind Motors (AREA)

Abstract

L'invention concerne un dispositif et un système de production d'énergie éolienne avec lesquels il est possible d'estimer, avec une précision élevée et dans une configuration simple, un cisaillement du vent indiquant une distribution de vitesse du vent. Le dispositif de production d'énergie éolienne comprend : un dispositif de production d'énergie éolienne (2) qui comprend au moins un rotor (25), une nacelle (22), et une tour (21) supportant de façon pivotante la nacelle (22); et un dispositif de commande (31) qui commande le dispositif de production d'énergie éolienne (2). Le dispositif de commande (31) est pourvu d'un dispositif d'estimation de condition de vent (32) comprenant : une unité de mesure de charge (13) qui mesure une charge appliquée au dispositif de production d'énergie éolienne (2); une unité de stockage (16) pour stocker une fonction de cisaillement du vent (33) définissant la relation entre la charge et le cisaillement du vent; et une unité d'estimation de cisaillement du vent (18) qui calcule le cisaillement du vent sur la base de la charge et de la fonction de cisaillement du vent (33).
PCT/JP2018/046459 2018-01-31 2018-12-18 Procédé et système de production d'énergie éolienne WO2019150805A1 (fr)

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CN111044754B (zh) * 2019-12-09 2021-07-16 大唐山东烟台电力开发有限公司 一种用于风力发电机组的风况估算装置
EP4067649A1 (fr) * 2021-03-31 2022-10-05 Siemens Gamesa Renewable Energy A/S Exploitation d'une éolienne dans des conditions météorologiques difficiles

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US20100092292A1 (en) * 2008-10-10 2010-04-15 Jacob Johannes Nies Apparatus and method for continuous pitching of a wind turbine
JP2015117682A (ja) * 2013-12-20 2015-06-25 三菱重工業株式会社 風力発電装置のモニタリングシステム及びモニタリング方法
WO2017163562A1 (fr) * 2016-03-25 2017-09-28 株式会社日立製作所 Dispositif et procédé d'évaluation de durée de vie restante, et système de génération d'électricité à énergie éolienne

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Publication number Priority date Publication date Assignee Title
US20100092292A1 (en) * 2008-10-10 2010-04-15 Jacob Johannes Nies Apparatus and method for continuous pitching of a wind turbine
JP2015117682A (ja) * 2013-12-20 2015-06-25 三菱重工業株式会社 風力発電装置のモニタリングシステム及びモニタリング方法
WO2017163562A1 (fr) * 2016-03-25 2017-09-28 株式会社日立製作所 Dispositif et procédé d'évaluation de durée de vie restante, et système de génération d'électricité à énergie éolienne

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* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20220145856A1 (en) * 2020-11-06 2022-05-12 IFP Energies Nouvelles Method of determining the wind speed in the rotor plane of a wind turbine
US11885305B2 (en) * 2020-11-06 2024-01-30 IFP Energies Nouvelles Method of determining the wind speed in the rotor plane of a wind turbine

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TWI729349B (zh) 2021-06-01

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