Position detection method, device, equipment, medium and product for wind power blade girder

Abstract

The embodiment of the application discloses a kind of wind power blade girder position detection method, device, equipment, medium and product, belong to wind power generation technical field.The wind power blade girder position detection method includes: obtaining the optical signal parameter collected by fiber sensor, fiber sensor is embedded in the target position of the main mould of wind power blade;According to optical signal parameter, determine the actual offset of main girder in main mould;In the case where actual offset is greater than preset offset, output prompt information.Through embedding fiber sensor in the main mould of blade, the position of main girder can be automatically detected and judged, improve the detection efficiency and the accuracy of detection result.Furthermore, fiber sensor can be suitable for non-transparent mould inside, even in the process of laying layer, fiber sensor can also collect optical signal parameter, so that the offset of main girder can be found in time, improve blade quality.

Description

Technical Field

[0001] This application relates to the field of wind power generation technology, and in particular to a method, device, equipment, medium and product for detecting the position of the main beam of a wind turbine blade. Background Technology

[0002] The main beam is the most important area in the wind turbine blade structure, and the accuracy of the main beam's position has a significant impact on the safety, performance, and service life of the blade structure.

[0003] Currently, the main beam position detection method primarily involves placing a steel positioning fixture on the blade mold, using an overhead crane to lift and adjust the edge of the main beam to be flush with the fixture, and then measuring the horizontal or diagonal distance of the main beam in the chord direction using a spirit level or measuring tape. This method aims to collect main beam position data and identify main beam offsets. However, this detection method suffers from low accuracy and efficiency. Furthermore, due to limitations in visualization, it cannot promptly identify main beam slippage during blade layup, posing a significant risk. Summary of the Invention

[0004] This application provides a method, device, equipment, medium, and product for detecting the position of the main beam of a wind turbine blade, which can solve the problems of low accuracy and low efficiency in detecting the position of the main beam of the blade in related technologies, and the inability to identify the sliding displacement of the main beam in a timely manner during the blade layup process.

[0005] In a first aspect, embodiments of this application provide a method for detecting the position of the main beam of a wind turbine blade, including:

[0006] The optical signal parameters collected by the fiber optic sensor are obtained. The fiber optic sensor is embedded in the target position of the main mold of the wind turbine blade. The target position corresponds to the placement position of the main beam in the main mold.

[0007] The actual offset of the main beam in the main mold is determined based on the optical signal parameters.

[0008] If the actual offset is greater than the preset offset, a prompt message will be output to indicate that the main beam has shifted in the main mold.

[0009] Secondly, embodiments of this application provide a position detection device for the main beam of a wind turbine blade, comprising:

[0010] The acquisition module is used to acquire the optical signal parameters collected by the fiber optic sensor. The fiber optic sensor is embedded in the target position of the main mold of the wind turbine blade, and the target position corresponds to the placement position of the main beam in the main mold.

[0011] The determination module is used to determine the actual offset of the main beam in the main mold based on the optical signal parameters;

[0012] The output module is used to output a prompt message when the actual position is greater than the preset offset. The prompt message is used to indicate that the main beam has shifted in the main mold.

[0013] Thirdly, embodiments of this application provide a position detection device for the main beam of a wind turbine blade, including a processor and a memory. The memory stores a program or instructions that can run on the processor, and when the program or instructions are executed by the processor, they implement the steps of the method described in the first aspect.

[0014] Fourthly, embodiments of this application provide a readable storage medium on which a program or instructions are stored, which, when executed by a processor, implement the steps of the method as described in the first aspect.

[0015] Fifthly, embodiments of this application provide a computer program product stored in a storage medium, which, when executed by at least one processor, implements the steps of the method described in the first aspect.

[0016] In this embodiment, optical signal parameters collected by a fiber optic sensor are acquired. The fiber optic sensor is pre-embedded at a target position in the main mold of the wind turbine blade, and the target position corresponds to the placement position of the main beam in the main mold. Based on the optical signal parameters, the actual offset of the main beam in the main mold is determined. If the actual offset is greater than a preset offset, a prompt message is output to indicate that the main beam has shifted within the main mold. By pre-embedding a fiber optic sensor in the main mold of the blade, the position of the main beam can be automatically detected and judged, improving detection efficiency and the accuracy of detection results. Moreover, the fiber optic sensor can be used in non-transparent molds, and even during the layup process, the fiber optic sensor can collect optical signal parameters, thereby enabling timely detection of main beam shifts and improving blade quality. Attached Figure Description

[0017] The features, advantages, and technical effects of exemplary embodiments of this application will now be described with reference to the accompanying drawings.

[0018] Figure 1 A flowchart illustrating a method for detecting the position of the main beam of a wind turbine blade, provided in an embodiment of this application;

[0019] Figure 2 A flowchart illustrating another method for detecting the position of the main beam of a wind turbine blade provided in this application embodiment;

[0020] Figure 3 A schematic diagram illustrating an ideal position of the main beam within the main mold, provided for an embodiment of this application;

[0021] Figure 4 A flowchart illustrating another method for detecting the position of the main beam of a wind turbine blade provided in this application embodiment;

[0022] Figure 5 A schematic diagram illustrating the actual position of a main beam within a main mold, provided for an embodiment of this application;

[0023] Figure 6 A schematic diagram of the structure of a wind turbine blade main beam position detection device provided in an embodiment of this application;

[0024] Figure 7 This is a structural schematic diagram of a wind turbine blade main beam position detection device provided in an embodiment of this application.

[0025] The accompanying drawings are not necessarily drawn to scale. Detailed Implementation

[0026] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.

[0027] Unless otherwise defined, all technical and scientific terms used in this application have the same meaning as commonly understood by one of ordinary skill in the art to which this application pertains; the terminology used in the description of this application is for the purpose of describing particular embodiments only and is not intended to limit the application; the terms "comprising" and "having," and any variations thereof, in the description, claims, and accompanying drawings of this application are intended to cover non-exclusive inclusion. The terms "first," "second," etc., in the description, claims, or accompanying drawings of this application are used to distinguish different objects, not to describe a specific order or hierarchy.

[0028] In this application, the reference to "embodiment" means that a particular feature, structure, or characteristic described in connection with an embodiment may be included in at least one embodiment of this application. The appearance of this phrase in various places in the specification does not necessarily refer to the same embodiment, nor is it a separate or alternative embodiment that is mutually exclusive with other embodiments.

[0029] In the description of this application, it should be noted that, unless otherwise expressly specified and limited, the terms "installation," "connection," "linking," and "attachment" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal communication between two components. Those skilled in the art can understand the specific meaning of the above terms in this application according to the specific circumstances.

[0030] In the embodiments of this application, the same reference numerals denote the same components, and for the sake of brevity, detailed descriptions of the same components are omitted in different embodiments. It should be understood that the thickness, length, width, and other dimensions of various components in the embodiments of this application shown in the accompanying drawings, as well as the overall thickness, length, width, and other dimensions of the integrated device, are merely illustrative and should not constitute any limitation on this application.

[0031] In this application, "multiple" means two or more (including two).

[0032] To better understand this application, the terms used in this application will be explained below:

[0033] Wind turbine blades: Components of wind turbine generators. Each surface of the blade is designed as an airfoil. From the blade root to the blade tip, its thickness, twist angle and chord length have a certain distribution pattern, resulting in a good aerodynamic shape.

[0034] Wind turbine blade main spars: Located between the inner and outer skins of the windward and leeward sides of the wind turbine blade, the main spars are situated in the region of 1 / 3 to 1 / 2 of the chord length when viewed from the chord direction. The main spars are made of unidirectional fiber, with materials including glass fiber or carbon fiber. The main forming methods include ply-injection, prepreg ply-in, and pultruded sheet ply-in. The function of the main spars is to provide flaring bending stiffness, prevent blade collision with the tower, and bear the main bending moment and axial load of the blade, transferring the load to the blade root.

[0035] Axial direction: refers to the length direction along the blade from the root to the tip, that is, longitudinal direction.

[0036] Chord direction: refers to the chord direction of the airfoil along any spanwise position of the blade, generally at 90° with the axial direction.

[0037] As described in the background section, the main beam is the most important area in the wind turbine blade structure, and the accuracy of its position has a significant impact on the safety, performance, and service life of the blade structure. Currently, the position of the main beam is mainly determined manually using tools such as overhead cranes, steel structure positioning fixtures, and spirit levels to identify whether the main beam has shifted. This method is not only inaccurate and inefficient, but also, due to limitations in visualization during the layup process, it is impossible to identify the sliding or shifting of the main beam in a timely manner, thus affecting the quality of the blade.

[0038] To address this, this application provides a method, apparatus, equipment, medium, and product for detecting the position of the main beam of a wind turbine blade. This solves the problems of low accuracy and low efficiency in detecting the position of the main beam of the blade in related technologies, and the inability to promptly identify the sliding offset of the main beam during the blade layup process.

[0039] The method for detecting the position of the main beam of a wind turbine blade provided in this application will be described below with reference to the accompanying drawings and specific embodiments.

[0040] Figure 1 This document presents a flowchart illustrating a method for detecting the position of a wind turbine blade main beam, applicable to electronic devices with data processing capabilities, such as tablets, laptops, servers, and personal computers. This method can be applied to any blade type requiring main beam positioning testing, thus having a wide range of applications.

[0041] like Figure 1 As shown, the method for detecting the position of the main beam of the wind turbine blade may include the following steps:

[0042] S110. Obtain the optical signal parameters collected by the fiber optic sensor. The fiber optic sensor is embedded in the target position of the main mold of the wind turbine blade. The target position corresponds to the placement position of the main beam in the main mold.

[0043] S120. Determine the actual offset of the main beam in the main mold based on the optical signal parameters.

[0044] S130. If the actual offset is greater than the preset offset, output a prompt message. The prompt message is used to indicate that the main beam has shifted in the main mold.

[0045] In this embodiment, optical signal parameters collected by a fiber optic sensor are acquired. The fiber optic sensor is pre-embedded at a target position in the main mold of the wind turbine blade, and the target position corresponds to the placement position of the main beam in the main mold. Based on the optical signal parameters, the actual offset of the main beam in the main mold is determined. If the actual offset is greater than a preset offset, a first prompt message is output, indicating that the main beam has shifted within the main mold. By pre-embedding a fiber optic sensor in the main mold of the blade, the position of the main beam can be automatically detected and judged, improving detection efficiency and the accuracy of detection results. Moreover, the fiber optic sensor can be used in non-transparent molds, and even during the layup process, the fiber optic sensor can collect optical signal parameters, thereby enabling timely detection of main beam shifts and improving blade quality.

[0046] The above steps are explained in detail below:

[0047] In S110, to promptly identify the sliding displacement of the main beam during the layup process, and considering that the working environment of the blade mold may be high-pressure, corrosive, flammable, or explosive, this embodiment utilizes fiber optic sensors to detect the position of the main beam. The fiber optic sensors can be pre-embedded in the main mold of the wind turbine blade. In practical applications, multiple sets of fiber optic sensors can be used, each set including multiple fiber optic sensors to monitor different positions of the main beam. For example, each set can contain two fiber optic sensors, which can monitor the axial and chordal changes of the main beam respectively. This allows for the detection of multiple positions of the main beam, ensuring the accuracy of its placement.

[0048] The fiber optic sensor can use a laser as a light source. For example, a narrowband semiconductor laser can be used as the light source. This laser is small in size and has low power consumption, and can be directly integrated into the fiber optic sensing system for use with the fiber optic sensor.

[0049] For example, before application, a protective sleeve can be used to protect the laser to ensure that the laser's compressive strength is greater than or equal to ≥50MPa, thus matching the high-pressure forming process of the fiberglass mold. For example, the protective sleeve can be made of stainless steel or titanium alloy, and a thermoelectric cooler (TEC) and heat sink can be integrated inside the protective sleeve to control the laser's operating temperature fluctuation to ≤±0.5℃, avoiding laser thermal expansion causing optical coupling shift and affecting the detection results of the main beam.

[0050] To ensure normal signal transmission, the interface between the fiber optic sensor and the laser can be fixed by laser welding to reduce the insertion loss of the fiber optic sensor and the laser, for example, the insertion loss can be ≤0.3dB28.

[0051] For example, before application, the laser can be calibrated, such as by measuring the laser's output power with an optical power meter to ensure the output power deviation is ≤±1%, and by performing a hermetically tight packaging test on the laser to achieve a helium mass spectrometry leak detection rate ≤1×10⁻. 8 Pa·m³ / s.

[0052] The main mold here can include an upper mold assembly and a lower mold assembly; that is, the fiber optic sensor can be pre-embedded in the upper mold assembly and the lower mold assembly.

[0053] The target location is the position where the fiber optic sensor is pre-embedded, corresponding to the placement position of the main beam. For example, the fiber optic sensor can be pre-embedded in the main mold corresponding to the placement position of the main beam, thereby accurately determining the position of the main beam. There can be multiple target locations, thus enabling the detection of multiple positions on the main beam.

[0054] In some embodiments, the target location can be determined based on the blade type, the process parameters of the main beam in the main mold, etc. Different blade types have different process parameters when placing the main beam. Determining the pre-embedded position of the fiber optic sensor based on the process parameters corresponding to the blade type can accurately detect the position of the main beam.

[0055] To further improve the accuracy of the main beam position detection results, for example, after initially determining the target position, fiber optic sensors can be deployed along the main beam placement location using a distributed fiber optic network. The positions of the fiber optic sensors can be calibrated using equipment such as a total station, so that the error of the fiber optic sensors is controlled within ±0.5mm.

[0056] In some embodiments, when the main mold integrates an adjustment mechanism, the target position can correspond to the position of the adjustment mechanism. For example, the position of the adjustment mechanism in the main mold can be determined as the target position. Thus, when the main beam offset is identified, the position of the main beam can be adjusted in a timely manner using the adjustment mechanism at the corresponding position, thereby improving the adjustment efficiency and effect.

[0057] For example, the optical sensor can be pre-embedded at the target location according to pre-embedded parameters, which may include, but are not limited to, the pre-embedded depth, the bending radius of the optical fiber sensor, and the width of the encapsulation channel. The pre-embedded parameters can be determined based on experience, experiments, the size of the optical fiber sensor, and the signal transmission performance of the optical fiber sensor. In some embodiments, the pre-embedded depth can be set to 5-8 mm, the bending radius of the optical fiber sensor to be greater than or equal to 2 mm, and the width of the encapsulation channel to be 1.5-2 mm.

[0058] The optical signal parameters here can be parameters that can determine the position of the main beam, such as, but not limited to, light intensity, light phase, and light wavelength.

[0059] In S120, the actual offset can include at least one of the following: axial offset of the main beam and chordal offset. For example, the actual offset of the main beam in the main mold can be determined based on one or more of light intensity, light phase, and light wavelength.

[0060] For example, the actual optical signal parameters collected by the light sensor can be matched with reference optical signal parameters to obtain the actual offset of the main beam corresponding to the actual collected optical signal parameters. The reference optical signal parameters can be the optical signal parameters corresponding to the ideal position of the main beam, and can include the optical signal parameters corresponding to the ideal positions of the main beam in the axial and chordal directions.

[0061] For example, a machine learning model or a deep learning model can be used to input the optical signal parameters into the machine learning model or the deep learning model, and output the actual offset of the main beam.

[0062] For example, the strain of the main beam can also be inferred from the optical signal parameters, and the actual offset of the main beam can be inferred from the strain.

[0063] In S130, the preset offset can be the maximum allowable offset of the main beam in the main mold, and different offsets are allowed at different positions of the main beam. When the actual offset of the main beam is large, it will affect the quality of the blade, especially when the chordal sliding offset of the main beam is large, the manufactured blade will have a greater risk.

[0064] This embodiment outputs a prompt message when the actual offset of the main beam exceeds a preset offset, alerting relevant personnel to the main beam offset. This embodiment does not limit the output method of the prompt message; for example, it can be output via voice, SMS, email, indicator lights, or one or more other methods. In some embodiments, the prompt message can be sent to the corresponding maintenance personnel via SMS, email, or telephone, allowing the maintenance personnel to take timely measures.

[0065] For example, the prompt information may include, but is not limited to, the blade model corresponding to the main beam, the actual offset of the main beam, the difference between the actual offset and the preset offset, and the offset direction of the main beam. This information helps maintenance personnel to quickly locate the offset position of the main beam and take timely and effective measures to improve the quality of the blades and production efficiency.

[0066] Figure 2 A flowchart illustrating another method for detecting the position of the main beam of a wind turbine blade provided in this application embodiment. Figure 2 and Figure 1 The difference is that, Figure 2 It also includes S210-S220.

[0067] S210. Obtain the blade model of the wind turbine blade and the process parameters of the main beam corresponding to the blade model in the main mold.

[0068] The process parameters of the main beam in the main mold are also the positional parameters of the main beam when it is placed in the main mold. For example, the process parameters include at least one of the following: the axial parameters and chordal parameters of the main beam in the main mold. Axial parameters may include, for example, axial length, the starting position of the axial direction, and the ending position of the axial direction. Chordal parameters may include, for example, chordal width, the starting position of the chordal direction, and the ending position of the chordal direction.

[0069] Different blade models correspond to different main beam process parameters. In this embodiment, the process parameters of the main beam are dynamically determined according to the blade model, which can improve the accuracy of the test results.

[0070] For example, a mapping relationship between different blade models and the corresponding main beam process parameters can be established in advance. Subsequently, the process parameters of the main beam corresponding to the current blade model can be obtained directly by looking up the mapping relationship, which is simple and fast, and can improve the detection efficiency.

[0071] For example, the mapping relationship can be stored locally or on a server. In this case, the wind turbine blade main beam position detection device can send the blade model to the server, and the server can determine the main beam process parameters corresponding to the blade model and then send them to the wind turbine blade main beam position detection device, so that the wind turbine blade main beam position detection device can determine the pre-embedded position of the fiber optic sensor based on the process parameters.

[0072] S220. Determine the target position of the fiber optic sensor in the main mold according to the process parameters.

[0073] Based on these process parameters, the ideal position of the main beam can be determined. Figure 3 An exemplary schematic diagram of the ideal position of the main beam is provided, with dashed box 301 representing the ideal position of the main beam. The target position can be set based on the ideal position. For example, along the axial direction, a fiber optic sensor can be placed at intervals, and the spacing between adjacent fiber optic sensors can be the same or different.

[0074] This embodiment can determine the process parameters of the corresponding main beam based on the blade model, and then determine the pre-embedded position of the fiber optic sensor in the main mold according to the process parameters, which improves the accuracy of the pre-embedded position and thus can accurately measure the position of the main beam in the main mold.

[0075] Taking optical signal parameters including wavelength offset as an example, the fiber optic sensor may, for instance, include a volume Bragg grating (FBG). To determine the actual position of the main beam, Figure 4 A flowchart of a method for detecting the position of the main beam of a wind turbine blade is provided as an example. Figure 4 and Figure 1 The difference is that, Figure 1 S120 in the text can be further refined into Figure 4 S410-S420 in the series.

[0076] S410. Based on the wavelength offset and the first correlation, determine the strain force of the main beam corresponding to the wavelength offset. The first correlation is used to characterize the relationship between different wavelength offsets and the strain force and temperature of the main beam.

[0077] When the main beam shifts, its strain and temperature change due to the influence of the surrounding ply materials, which in turn causes a change in the wavelength of the light collected by the fiber optic sensor. Therefore, the strain and temperature of the main beam can be determined based on the wavelength shift of the light collected by the fiber optic sensor.

[0078] In this embodiment, a first correlation between wavelength offset and strain and temperature can be established in advance. Subsequently, the strain at the corresponding position of the main beam can be determined directly based on the first correlation.

[0079] Since both strain and temperature affect wavelength shift, the strain obtained above can be compensated using a temperature compensation model, thereby separating strain from temperature and improving the accuracy of the strain measurement. The temperature compensation model can be a machine learning model such as a support vector regression model.

[0080] For example, two fiber optic sensors can also be placed at the same location. One fiber optic sensor is bonded to the mold to sense the temperature and strain of the main beam, while the other fiber optic sensor only senses the temperature of the main beam. The influence of temperature on strain is then eliminated through differential measurement. The two fiber optic sensors are identical in model and structure.

[0081] S420. Based on the main beam strain force and the second correlation, determine the actual offset corresponding to the main beam strain force. The second correlation is used to characterize the correlation between different main beam strain forces and the main beam offset.

[0082] The main beam experiences different strain forces, resulting in different displacements. For example, a second correlation between different strain forces and displacements can be established in advance. This second correlation can be a functional relationship, a model relationship, a tabular relationship, etc.

[0083] For example, a 3D finite element model of the main beam can be established, with material properties and boundary conditions consistent with the actual process to ensure the accuracy of the results. Based on this 3D finite element model, the strain distribution of the main beam under different offsets can be simulated to obtain the second correlation.

[0084] Because wavelength modulation sensors have high accuracy and strong anti-interference capabilities, the strain of the main beam can be determined by using the wavelength offset, and then the offset of the main beam can be determined based on the strain, resulting in a more accurate result.

[0085] In practical applications, due to factors such as layering, the sensing area of ​​the fiber optic sensor may contain multiple materials. For example, in addition to the material of the main beam, there may be other auxiliary materials such as fiberglass. The material of the main beam may be, for example, pultruded sheet. Different materials correspond to different wavelength characteristics. That is, in practical applications, the wavelength offset fed back by the fiber optic sensor may be multiple, and different wavelength offsets may correspond to different materials. In order to accurately determine the wavelength offset corresponding to the pultruded sheet, S410 above may, for example, include the following steps:

[0086] Based on the relationship between wavelength offset and strain and temperature for different materials, the target wavelength offset of the material corresponding to the main beam is determined from each wavelength offset.

[0087] Based on the target wavelength offset and the first correlation with the target wavelength offset, the strain force of the main beam corresponding to the target wavelength offset is determined.

[0088] It is understandable that different materials have different relationships between wavelength shift, strain, and temperature, and the relationship between strain and temperature also varies. Based on the wavelength shift, the relationship between strain and temperature can be determined, and thus the material corresponding to each wavelength shift can be identified. This allows for the accurate determination of the target wavelength shift for the pultruded sheet. Based on the target wavelength shift of the pultruded sheet, combined with the first correlation, the strain of the main beam can be accurately determined, and consequently, the offset of the main beam can be accurately determined.

[0089] To promptly address the main beam offset issue, for example, when the actual offset exceeds a preset offset, the wind turbine blade main beam position detection method may further include the following steps:

[0090] Based on the difference between the actual offset and the preset offset, a position adjustment command is generated;

[0091] The adjustment mechanism is driven by the position adjustment command. The position of the main beam is adjusted by the adjustment mechanism so that the offset of the main beam after adjustment is less than or equal to the preset offset. The adjustment mechanism is integrated into the main mold.

[0092] The position adjustment command is used to drive the adjustment mechanism, which in turn moves the main beam to adjust its position, reduce the offset, and improve the quality of the blades.

[0093] The adjustment mechanism may include, for example, a base, an actuator, a guide mechanism, and a controller. The base can be fixed to the main mold via a high-strength alloy steel flange. The actuator may include, for example, hydraulic push rods or electric push rods, used to generate mechanical movement to adjust the position of the main beam. Taking hydraulic push rods as an example, four sets of hydraulic push rods can be symmetrically arranged to form an "XY cross thrust array," achieving adjustment of the main beam in various directions. The guide mechanism may include, for example, guide rails or sliders, used to ensure the accurate movement direction of the actuator and prevent the actuator from deviating, thus affecting the adjustment effect of the main beam. The specific settings and connections of each part are not limited in this embodiment, as long as the main beam can be corrected when it deviates.

[0094] In this embodiment, an adjustment mechanism can be set on the blade mold. When the main beam shifts, the position of the main beam can be adjusted using the adjustment mechanism, thereby realizing automated adjustment of the main beam position and improving adjustment efficiency.

[0095] In some embodiments, after the fiber optic sensor is pre-embedded, the attenuation rate of the fiber optic sensor can be tested using an optical time-domain reflectometer (OTDR) to ensure that the overall loss of the fiber optic sensor is ≤0.25dB / km. The fiber optic sensor can also be subjected to thermo-pressure cycling tests, for example, to ensure that the drift of the optical signal parameters is ≤±0.1% after N consecutive cycles. N is an integer greater than 1, for example, N=20.

[0096] In some embodiments, if the actual offset of the main beam is greater than the preset offset, the main beam can be repositioned by means of overhead crane lifting to achieve global adjustment of the main beam.

[0097] In some embodiments, there can be multiple adjustment mechanisms, each located in a different position within the main mold. There can be multiple sets of fiber optic sensors, with each adjustment mechanism corresponding to the position of each set of fiber optic sensors. That is, an adjustment mechanism is installed at the location of each set of fiber optic sensors. Thus, when a shift in a certain position of the main beam is determined based on each set of fiber optic sensors, the adjustment mechanism at that position can be used for adjustment, achieving local adjustment of the main beam position. In other words, this embodiment can dynamically adjust different positions according to the shifts in different positions of the main beam, ensuring that the overall position of the main beam meets the quality requirements.

[0098] Taking the actual offset, which includes both the actual axial offset of the main beam in the main mold and the actual chordal offset of the main beam in the main mold, as an example, the above S130 may include the following steps:

[0099] A prompt message will be output if any of the following conditions are met:

[0100] The actual axial offset is greater than the reference axial offset;

[0101] The actual chord offset is greater than the reference chord offset.

[0102] The reference axial offset is the maximum axial offset of the main beam, and the reference chord offset is the maximum chord offset of the main beam. The magnitudes of the reference axial offset and reference chord offset can be set according to specific circumstances.

[0103] Whether it is the actual axial offset or the actual chordal offset, as long as either one is greater than the corresponding reference offset, the wind turbine blade main beam position detection equipment will output a prompt message to alert the user that the main beam has shifted. This allows for timely detection of main beam abnormalities and improves blade quality.

[0104] Figure 5 An exemplary schematic diagram of the actual position of the main beam is provided. The actual position of the main beam can be seen in solid box 302. During the layup process, the chordal direction of the main beam undergoes sliding offset, and the offset amount is greater than the reference chordal offset amount. At this time, the position detection device of the wind turbine blade main beam will output a prompt message to the user that the chordal direction of the main beam has slipped offset.

[0105] For example, the position detection device for the wind turbine blade main beam can also send the detection results of various positions of the main beam to a display screen for display. This display screen can be the display screen of the wind turbine blade main beam position detection device itself, or it can be a display screen independent of the wind turbine blade main beam position detection device. In the latter case, the wind turbine blade main beam position detection device can communicate with the display screen. Through the display screen, the user can more intuitively determine the offset area of ​​the main beam. For example, the wind turbine blade main beam position detection device can send the detection results of various positions of the main beam to the display screen for display via the SPI / I²C protocol. In practical applications, it is not limited to this protocol and other protocols can also be used for data transmission.

[0106] For example, for each blade, the offset rate of the main beam can be calculated, and then an offset rate curve can be plotted based on the offset rate of each blade, where the blades have the same model, size, and other parameters. Based on this offset rate curve, users can be guided to improve the quality of the blades. For example, if the main offset rate shows an upward trend, the lifting operation of the main beam, the dimensions of the main beam, the dimensions of the mold, etc., can be further checked for errors, thereby further improving the placement efficiency of the main beam and the quality of the blades.

[0107] Using the solution described in this application, the testing time for a single blade can be significantly shortened, thereby reducing the mold-keeping cycle and improving blade production efficiency. Furthermore, the accuracy of the main beam position greatly improves the stability of the web bonding gap during the bonding process, reducing defects such as excessive gaps, and thus lowering the maintenance cost of a single blade.

[0108] In this embodiment, by pre-embedding fiber optic sensors in the main mold, the fiber optic sensors can detect the displacement, strain, and other physical quantities of the main beam in real time by monitoring changes in optical signal parameters (such as intensity, phase, and wavelength) when the main beam is placed. This indirectly reflects its positioning status. When the main beam offset is determined, the offset position of the main beam can be adjusted accordingly, thereby improving detection efficiency, blade production efficiency, and blade quality.

[0109] It should be noted that the wind turbine blade main beam position detection method provided in this application embodiment can be executed by a wind turbine blade main beam position detection device, or a processing module within the wind turbine blade main beam position detection device for executing the wind turbine blade main beam position detection method. This application embodiment uses the wind turbine blade main beam position detection device executing the wind turbine blade main beam position detection method as an example to illustrate the wind turbine blade main beam position detection device provided in this application embodiment.

[0110] Figure 6 This is a schematic diagram of the structure of a wind turbine blade main beam position detection device provided in an embodiment of this application.

[0111] like Figure 6 As shown, the position detection device 600 for the main beam of the wind turbine blade may include:

[0112] The acquisition module 601 is used to acquire the optical signal parameters collected by the fiber optic sensor. The fiber optic sensor is embedded in the target position of the main mold of the wind turbine blade. The target position corresponds to the placement position of the main beam in the main mold.

[0113] The determination module 602 is used to determine the actual offset of the main beam in the main mold based on the optical signal parameters;

[0114] The output module 603 is used to output a prompt message when the actual offset is greater than the preset offset. The prompt message is used to indicate that the main beam has shifted in the main mold.

[0115] In this embodiment, optical signal parameters collected by a fiber optic sensor are acquired. The fiber optic sensor is pre-embedded at a target position in the main mold of the wind turbine blade, and the target position corresponds to the placement position of the main beam in the main mold. Based on the optical signal parameters, the actual offset of the main beam in the main mold is determined. If the actual offset is greater than a preset offset, a prompt message is output to indicate that the main beam has shifted within the main mold. By pre-embedding a fiber optic sensor in the main mold of the blade, the position of the main beam can be automatically detected and judged, improving detection efficiency and the accuracy of detection results. Moreover, the fiber optic sensor can be used in non-transparent molds, and even during the layup process, the fiber optic sensor can collect optical signal parameters, thereby enabling timely detection of main beam shifts and improving blade quality.

[0116] In some embodiments, the acquisition module 601 is further configured to acquire the blade model of the wind turbine blade and the process parameters of the main beam corresponding to the blade model in the main mold before acquiring the optical signal parameters collected by the fiber optic sensor. The process parameters include at least one of the following: the axial parameters and chordal parameters of the main beam in the main mold; the axial direction is the direction from the blade root to the blade tip, and the chordal direction is perpendicular to the axial direction.

[0117] The determination module 602 is also used to determine the target position of the fiber optic sensor pre-embedded in the main mold based on the process parameters.

[0118] In some embodiments, the optical signal parameters include wavelength offset;

[0119] Module 602 is specifically used for:

[0120] Based on the wavelength offset and the first correlation, the strain force of the main beam corresponding to the wavelength offset is determined. The first correlation is used to characterize the relationship between different wavelength offsets and the strain force and temperature of the main beam.

[0121] Based on the strain force of the main beam and the second correlation, the actual offset corresponding to the strain force of the main beam is determined. The second correlation is used to characterize the relationship between different strain forces of the main beam and the offset of the main beam.

[0122] In some embodiments, the sensing area of ​​the fiber optic sensor includes multiple materials, and the wavelength offset includes multiple values, with different wavelength offsets corresponding to different materials.

[0123] Module 602 is specifically used for:

[0124] Based on the relationship between wavelength offset and strain and temperature for different materials, the target wavelength offset of the material corresponding to the main beam is determined from each wavelength offset.

[0125] Based on the target wavelength offset and the first correlation with the target wavelength offset, the strain force of the main beam corresponding to the target wavelength offset is determined.

[0126] In some embodiments, the position detection device 600 for the wind turbine blade main beam may further include:

[0127] The generation module is used to generate a position adjustment command based on the difference between the actual offset and the preset offset when the actual offset is greater than the preset offset.

[0128] The drive module is used to drive the adjustment mechanism according to the position adjustment command. The adjustment mechanism adjusts the position of the main beam so that the offset of the main beam after adjustment is less than or equal to the preset offset. The adjustment mechanism is integrated into the main mold.

[0129] In some embodiments, the adjustment mechanism includes multiple components, the fiber optic sensor includes multiple components, each adjustment mechanism is located at a different position on the main mold, and each adjustment mechanism corresponds to the position of each fiber optic sensor.

[0130] In some embodiments, the actual offset includes the actual axial offset of the main beam in the main mold and the actual chordal offset of the main beam in the main mold.

[0131] Output module 603 is specifically used for:

[0132] A prompt message will be output if any of the following conditions are met:

[0133] The actual axial offset is greater than the reference axial offset;

[0134] The actual chord offset is greater than the reference chord offset.

[0135] Figure 7 This is a schematic diagram of a position detection device for a wind turbine blade main beam, provided in an embodiment of this application. This wind turbine blade main beam position detection device 700 can implement the position detection method for the wind turbine blade main beam in this embodiment.

[0136] like Figure 7 As shown, the position detection device 700 for the main beam of the wind turbine blade may include a processor 701 and a memory 702 storing computer program instructions.

[0137] Specifically, the processor 701 may include a central processing unit (CPU), an application-specific integrated circuit (ASIC), or one or more integrated circuits that can be configured to implement the embodiments of this application.

[0138] Memory 702 may include mass storage for data or instructions. For example, and not limitingly, memory 702 may include a hard disk drive (HDD), floppy disk drive, flash memory, optical disk, magneto-optical disk, magnetic tape, or Universal Serial Bus (USB) drive, or a combination of two or more of these. Where appropriate, memory 702 may include removable or non-removable (or fixed) media. Where appropriate, memory 702 may be internal or external to an integrated gateway disaster recovery device. In a particular embodiment, memory 702 is non-volatile solid-state memory. In a particular embodiment, memory 702 may include read-only memory (ROM), random access memory (RAM), disk storage media device, optical storage media device, flash memory device, electrical, optical, or other physical / tangible memory storage device. Thus, generally, memory 702 includes one or more tangible (non-transitory) computer-readable storage media (e.g., memory devices) encoded with software including computer-executable instructions, and when the software is executed (e.g., by one or more processors), it is operable to perform the operations described with reference to the method according to one aspect of this application.

[0139] The processor 701 reads and executes computer program instructions stored in the memory 702 to implement any of the wind turbine blade main beam position detection methods in the above embodiments.

[0140] In one example, the wind turbine blade main beam position detection device 700 may also include a communication interface 703 and a bus 704. For example, Figure 7 As shown, the processor 701, memory 702, and communication interface 703 are connected through bus 704 and complete communication with each other.

[0141] The communication interface 703 is mainly used to realize communication between various modules, devices, apparatuses and / or equipment in the embodiments of this application.

[0142] Bus 704 includes hardware, software, or both, that couples the components of the wind turbine blade main beam position detection device 700 together. For example, and not limitingly, the bus may include an Accelerated Graphics Port (AGP) or other graphics bus, an Enhanced Industry Standard Architecture (EISA) bus, a Front Side Bus (FSB), HyperTransport (HT) interconnect, an Industry Standard Architecture (ISA) bus, an Infinite Bandwidth Interconnect, a Low Pin Count (LPC) bus, a memory bus, a Microchannel Architecture (MCA) bus, a Peripheral Component Interconnect (PCI) bus, a PCI-Express (PCI-X) bus, a Serial Advanced Technology Attachment (SATA) bus, a Video Electronics Standards Association Local (VLB) bus, or other suitable buses, or combinations of two or more of these. Where appropriate, bus 704 may include one or more buses. Although specific buses are described and illustrated in embodiments of this application, any suitable bus or interconnect is contemplated herein.

[0143] The position detection device for the main beam of the wind turbine blade can execute the position detection method for the main beam of the wind turbine blade in the embodiments of this application, thereby achieving a combination of Figures 1 to 5 The method for detecting the position of the main beam of a wind turbine blade is described.

[0144] In addition, in conjunction with the wind turbine blade main beam position detection method in the above embodiments, this application also provides a readable storage medium for implementation. This readable storage medium stores a program or instructions; when executed by a processor, the program or instructions implement any of the wind turbine blade main beam position detection methods in the above embodiments.

[0145] This application also provides a chip, which includes a processor and a communication interface. The communication interface is coupled to the processor. The processor is used to run programs or instructions to implement the various processes of the above method embodiments and achieve the same technical effect. To avoid repetition, it will not be described again here.

[0146] It should be understood that the chip mentioned in the embodiments of this application may also be referred to as a system-on-a-chip, system chip, chip system, or system-on-a-chip, etc.

[0147] This application also provides a computer program product, which is stored in a storage medium. When executed by at least one processor, the computer program product can implement the various processes of the above method embodiments and achieve the same technical effect. To avoid repetition, it will not be described again here.

[0148] Although this application has been described with reference to preferred embodiments, various modifications can be made thereto and components can be replaced with equivalents without departing from the scope of this application. In particular, the technical features mentioned in the various embodiments can be combined in any manner, provided there is no structural conflict. This application is not limited to the specific embodiments disclosed herein, but includes all technical solutions falling within the scope of the claims.

Claims

1. A method of position detection of a wind turbine blade spar, characterized in that, The method comprises: obtaining an optical signal parameter collected by an optical fiber sensor, the optical fiber sensor being embedded in a target position of a main mold of the wind turbine blade, the target position corresponding to a placement position of the main beam in the main mold, the optical signal parameter comprising a wavelength shift, the sensing area of the optical fiber sensor comprising a plurality of materials, the wavelength shift comprising a plurality of wavelength shifts, different wavelength shifts corresponding to different materials; determining a target wavelength shift of the material of the main beam from the wavelength shifts according to the relationship between the wavelength shift corresponding to the different materials and the strain force and the temperature; determining a main beam strain force corresponding to the target wavelength shift according to the target wavelength shift and a first correlation relationship corresponding to the target wavelength shift, the first correlation relationship being used to represent the relationship between different wavelength shifts and the strain force and the temperature of the main beam; determining an actual shift corresponding to the main beam strain force according to the main beam strain force and a second correlation relationship, the second correlation relationship being used to represent the correlation relationship between different main beam strain forces and main beam shifts; the actual shift comprising an actual axial shift of the main beam in the main mold and an actual chordwise shift of the main beam in the main mold; outputting prompt information in the case that the actual shift is greater than a preset shift, the prompt information being used to indicate that the main beam has a shift in the main mold; in the case that the actual shift is greater than the preset shift, the method further comprises: generating a position adjustment instruction according to the difference between the actual shift and the preset shift; driving an adjustment mechanism according to the position adjustment instruction, adjusting the position of the main beam through the adjustment mechanism, so that the adjusted main beam shift is less than or equal to the preset shift, the adjustment mechanism being integrated in the main mold; the adjustment mechanism comprises a plurality of adjustment mechanisms, the optical fiber sensor comprises a plurality of optical fiber sensors, each adjustment mechanism corresponding to the position of each optical fiber sensor; the adjustment mechanism comprises a plurality of execution mechanisms, the plurality of execution mechanisms being symmetrically arranged at corresponding positions of the main beam and being used to respectively adjust the actual axial shift and the actual chordwise shift of the main beam.

2. The method of claim 1, wherein, Before the step of obtaining the optical signal parameter collected by the optical fiber sensor, the method further comprises: obtaining a blade model of the wind turbine blade and a process parameter of a main beam corresponding to the blade model in the main mold, the process parameter comprising at least one of the following: an axial parameter of the main beam in the main mold, a chordwise parameter; the axial direction is from the root to the tip, and the chordwise direction is perpendicular to the axial direction; determining the target position of the optical fiber sensor embedded in the main mold according to the process parameter.

3. The method according to any of claims 1-2, characterized in that, In the case that the actual shift is greater than the preset shift, the step of outputting prompt information comprises: outputting prompt information in the case that any of the following conditions is met: the actual axial shift is greater than a reference axial shift; the actual chordwise shift is greater than a reference chordwise shift.

4. A position detection device for a wind turbine blade spar, characterized in that ​ The acquisition module is configured to acquire an optical signal parameter collected by a fiber sensor, the fiber sensor is embedded in a target position of a main mold of the wind turbine blade, the target position corresponds to a placement position of the main beam in the main mold, the optical signal parameter includes a wavelength shift, the sensing area of the fiber sensor includes a plurality of materials, and the wavelength shift includes a plurality of wavelength shifts corresponding to different materials; The determination module is configured to determine a target wavelength shift of a material of the main beam from the wavelength shifts according to a relationship between the wavelength shifts corresponding to different materials and a strain force and a temperature; According to the target wavelength shift and a first correlation relationship corresponding to the target wavelength shift, a main beam strain force corresponding to the target wavelength shift is determined, the first correlation relationship is used to represent a relationship between different wavelength shifts and the strain force and the temperature of the main beam, according to the main beam strain force and a second correlation relationship, an actual shift corresponding to the main beam strain force is determined, the second correlation relationship is used to represent a correlation relationship between different main beam strain forces and main beam shifts, and the actual shift includes an actual axial shift of the main beam in the main mold and an actual chordwise shift of the main beam in the main mold. The output module is configured to output a prompt information when the actual shift is greater than a preset shift, and the prompt information is used to indicate that the main beam is offset in the main mold. The device further includes: The generation module is configured to generate a position adjustment instruction according to a difference between the actual shift and the preset shift when the actual shift is greater than the preset shift. The driving module is configured to drive an adjustment mechanism according to the position adjustment instruction, adjust the position of the main beam through the adjustment mechanism, so that the adjusted main beam shift is less than or equal to the preset shift, and the adjustment mechanism is integrated in the main mold. The adjustment mechanism includes a plurality of adjustment mechanisms, the fiber sensor includes a plurality of fiber sensors, each adjustment mechanism is located at a different position of the main mold, and each adjustment mechanism corresponds to the position of each fiber sensor. The adjustment mechanism includes a plurality of execution mechanisms, and the plurality of execution mechanisms are symmetrically arranged at corresponding positions of the main beam and are used to respectively adjust the actual axial shift and the actual chordwise shift of the main beam.

5. A position detection device for a wind turbine blade spar, characterized in that The device includes a processor and a memory, the memory stores programs or instructions executable on the processor, and the programs or instructions are executed by the processor to implement the steps of the method in any one of claims 1 to 3.

6. A readable storage medium characterized by, The readable storage medium stores programs or instructions, and the programs or instructions are executed by the processor to implement the steps of the method in any one of claims 1 to 3.

7. A computer program product, characterised in that, The computer program product is stored in a storage medium, and the computer program product is executed by at least one processor to implement the steps of the method in any one of claims 1 to 3.

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