Power transmission line conductor aeolian vibration evaluation method, device and equipment and storage medium

Abstract

The invention relates to the technical field of wire operation and maintenance, in particular to a power transmission line wire aeolian vibration evaluation method, device and equipment and a storage medium. In order to solve the problem that the wind speed and wind direction characteristics of the environment where the wire is located are not considered differently by only depending on a vibration frequency evaluation mode in an existing power transmission line wire aeolian vibration evaluation method, the historical wind speed and wind direction data of the area where the power transmission line is located are analyzed, and a proposed aeolian vibration characteristic calculation method is combined. The vibration frequency of each year is accurately calculated and evaluated, and the fatigue damage degree of the lead and the service life of the lead are accurately evaluated. According to the method, the regional wind field change is considered, the fatigue damage of the wire is dynamically evaluated, and the defect that the influence of wind speed, wind direction, line direction and other factors on aeolian vibration is not considered in a traditional method is overcome.

Description

Technical Field

[0001] The present invention relates to the technical field of conductor operation and maintenance, and in particular to a method, device, equipment and storage medium for evaluating breeze vibration of transmission line conductors. Background Art

[0002] Breeze vibration refers to a high-frequency, low-amplitude vibration phenomenon caused by wind acting on transmission line conductors. Because the critical wind speed for breeze vibration is relatively low, it has a high probability of occurrence and a long duration during line operation. Consequently, over long periods of operation, the accumulated vibration energy can cause fatigue damage to the conductors, leading to breakage and stranding, impacting the safe and stable operation of the power grid.

[0003] Currently, wind-induced vibrations in power transmission line conductors are mostly addressed through detailed observations of the conductors using drones and other equipment. Repairs are then carried out immediately if damage, defects, or even broken conductors are detected. However, wind-induced conductor breakages often present no obvious signs, necessitating regular, meticulous inspections of all transmission lines, making targeted monitoring impossible. Summary of the Invention

[0004] In view of this, the present invention provides a method, device, equipment and storage medium for evaluating breeze vibration of transmission line conductors to solve the problem of being unable to perform targeted monitoring of transmission line conductors.

[0005] In a first aspect, the present invention provides a method for evaluating breeze vibration of a transmission line conductor, the method comprising: obtaining historical wind data of an area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, the historical wind data comprising historical wind speed and corresponding historical wind direction, the parameter data comprising the direction of the conductor; converting the historical wind speed based on the angle between the direction of the conductor and the historical wind direction, and determining the breeze vibration frequency corresponding to known wind data based on the converted historical wind speed; calculating the breeze vibration frequency when wind data is unknown based on a wind data sample determined based on a joint probability density distribution of the historical wind data; and evaluating the fatigue damage degree and remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown.

[0006] This invention addresses the problem that existing methods for assessing breeze vibration of transmission line conductors rely solely on the number of vibrations, failing to consider the wind speed and direction characteristics of the conductor's environment. By analyzing historical wind speed and direction data for the transmission line's region and combining it with a proposed method for calculating breeze vibration characteristics, this method accurately calculates and assesses the number of vibrations occurring each year, and accurately assesses the degree of conductor fatigue damage and conductor lifespan. This method considers regional wind field variations and dynamically assesses conductor fatigue damage, overcoming the drawback of traditional methods that fail to consider the impact of factors such as wind speed, wind direction, and line orientation on breeze vibration.

[0007] In an optional embodiment, the historical wind speed is converted based on the angle between the conductor direction and the historical wind direction, including: correcting the historical wind direction according to the relationship between the historical wind direction and a preset angle to obtain a corrected wind direction; determining the angle between the conductor direction and the historical wind direction according to the difference between the corrected wind direction and the conductor direction; and determining the converted historical wind speed according to the product of the sine value of the angle and the historical wind speed.

[0008] In the present invention, the wind direction is first corrected, and then the wind speed is converted based on the angle between the wind direction and the direction of the conductor, so that the converted historical wind speed can accurately describe the impact on the conductor.

[0009] In an optional embodiment, the parameter data also includes the conductor diameter, and the breeze vibration frequency corresponding to the known wind data is determined based on the converted historical wind speed, including: calculating the vibration damage frequency based on the conductor diameter and the breeze vibration wind speed; determining the breeze vibration frequency corresponding to different wind speeds based on the product of the vibration damage frequency and different preset thresholds; determining the breeze vibration frequency corresponding to the converted historical wind speed based on the converted historical wind speed and the breeze vibration frequencies corresponding to different wind speeds.

[0010] In an optional embodiment, before calculating the breeze vibration frequency when unknown wind data is obtained based on the wind data sample determined by the joint probability density distribution of historical wind data, the method further includes: calculating the wind speed probability density distribution based on the historical wind speed using the kernel density distribution method; dividing the wind speed intervals based on the historical wind speed, and screening the historical wind directions within each wind speed interval; calculating the wind direction probability density distribution based on the historical wind directions within each wind speed interval using the kernel density analysis method; and constructing a joint probability density distribution of wind speed and direction based on the wind speed probability density distribution and the wind direction probability density distribution.

[0011] In the present invention, by constructing the joint probability density distribution of wind speed and wind direction, a data basis is provided for determining the breeze vibration frequency when the wind data is unknown.

[0012] In an optional embodiment, the breeze vibration frequency when unknown wind data is calculated based on wind data samples determined based on the joint probability density distribution of historical wind data, including: determining the number of wind data samples within a preset time period based on the joint probability density distribution of historical wind data; obtaining the wind data within the preset time period based on the number of wind data samples using Monte Carlo simulation; and calculating the breeze vibration frequency within the preset time period based on the wind data within the preset time period.

[0013] In the present invention, for the breeze vibration frequency when the wind data is unknown, the joint probability density distribution of the calculated wind data is used, and the corresponding wind data is obtained by Monte Carlo simulation, thereby providing a data basis for the calculation of the breeze vibration frequency.

[0014] In an optional embodiment, the fatigue damage degree and the remaining life of the transmission line conductor to be evaluated are evaluated based on the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown, including: determining the breeze vibration frequency of the transmission line conductor to be evaluated during the operating time based on the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown; determining the fatigue damage degree of the transmission line conductor to be evaluated based on the ratio of the breeze vibration frequency during the operating time and the total number of breeze vibrations suffered; and determining the remaining life of the transmission line conductor to be evaluated based on the fatigue damage degree and the breeze vibration frequency when wind data is unknown.

[0015] In an optional embodiment, the breeze vibration frequency of the conductor of the transmission line to be evaluated during the operating time is determined based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown, including: when the operating time of the conductor of the transmission line to be evaluated includes the time with known wind data and the time with unknown wind data, the breeze vibration frequency of the conductor of the transmission line to be evaluated during the operating time is determined based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown; when the operating time of the conductor of the transmission line to be evaluated does not include the time with unknown wind data, the breeze vibration frequency of the conductor of the transmission line to be evaluated during the operating time is determined based on the breeze vibration frequency when the wind data is known.

[0016] In a second aspect, the present invention provides a device for evaluating breeze vibration of a transmission line conductor, the device comprising: a data acquisition module for acquiring historical wind data of an area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, the historical wind data comprising historical wind speed and corresponding historical wind direction, the parameter data comprising the direction of the conductor; a first frequency calculation module for converting the historical wind speed based on the angle between the direction of the conductor and the historical wind direction, and determining the breeze vibration frequency corresponding to known wind data based on the converted historical wind speed; a second frequency calculation module for calculating the breeze vibration frequency when wind data is unknown based on a wind data sample determined by a joint probability density distribution of the historical wind data; an evaluation module for evaluating the fatigue damage degree and the remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when wind data is known and the breeze frequency when wind data is unknown.

[0017] In a third aspect, the present invention provides a computer device comprising: a memory and a processor, the memory and the processor being communicatively connected to each other, the memory storing computer instructions, and the processor executing the method for evaluating breeze vibration of a transmission line conductor according to the first aspect or any corresponding embodiment thereof by executing the computer instructions.

[0018] In a fourth aspect, the present invention provides a computer-readable storage medium having computer instructions stored thereon, the computer instructions being used to enable a computer to execute the method for evaluating breeze vibration of a transmission line conductor according to the first aspect or any corresponding embodiment thereof.

[0019] In a fifth aspect, the present invention provides a computer program product comprising computer instructions for causing a computer to execute the method for evaluating breeze vibration of a transmission line conductor according to the first aspect or any corresponding embodiment thereof. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] In order to more clearly illustrate the specific embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the specific embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0021] Figure 1 1 is a flow chart of a method for evaluating breeze vibration of a transmission line conductor according to an embodiment of the present invention;

[0022] Figure 2 is a schematic diagram of wind speed probability density distribution according to an embodiment of the present invention;

[0023] Figure 3 132#-133# wind direction and line angle distribution diagram according to an embodiment of the present invention;

[0024] Figure 4 140#-141# wind direction and line angle distribution diagram according to an embodiment of the present invention;

[0025] Figure 5 132#-133# line vibration frequency diagram in 2011 according to an embodiment of the present invention;

[0026] Figure 6 is a structural block diagram of a device for evaluating breeze vibration of a transmission line conductor according to an embodiment of the present invention;

[0027] Figure 7 Schematic diagram of the hardware structure of a computer device according to an embodiment of the present invention. DETAILED DESCRIPTION

[0028] To make the purpose, technical solutions, and advantages of the embodiments of the present invention more clear, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without making creative efforts shall fall within the scope of protection of the present invention.

[0029] According to an embodiment of the present invention, an embodiment of a method for evaluating breeze vibration of a transmission line conductor is provided. It should be noted that the steps shown in the flowchart of the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases, the steps shown or described can be executed in an order different from that shown here.

[0030] In this embodiment, a method for evaluating breeze vibration of a transmission line conductor is provided, which can be used for electronic devices such as computers, mobile phones, tablet computers, etc. Figure 1 FIG. 1 is a flow chart of a method for evaluating breeze vibration of a transmission line conductor according to an embodiment of the present invention. Figure 1 As shown, the process includes the following steps:

[0031] Step S101: Acquire historical wind data of the area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, wherein the historical wind data includes historical wind speed and corresponding historical wind direction, and the parameter data includes conductor direction.

[0032] During the operation of the transmission line, breeze vibration is closely related to factors such as wind speed, wind direction, and the direction of the transmission line conductors. Among them, for different conductors, when the wind speed is within a specific range, a simple harmonic vibration form will be generated, forming a breeze vibration feature that causes the greatest damage to the conductors; when the wind speed is within a non-specific range, the breeze vibration will be significantly reduced. In terms of the influence of wind direction and the direction of the transmission line conductors, breeze vibration is most likely to occur when the wind direction is perpendicular to the conductors. It can be seen that the breeze vibration characteristics of the transmission line are extremely sensitive to the distribution characteristics of the wind in the area. Based on this discovery, this embodiment obtains historical wind data and the direction of the conductors in the area where the transmission line conductors to be evaluated are located when evaluating the breeze vibration of the transmission line conductors, providing a data basis for subsequent accurate evaluation.

[0033] Specifically, historical wind data for the area where the transmission line conductor to be evaluated is located can be obtained from climate data collected by meteorological observation stations. That is, this embodiment evaluates the transmission line conductors in the area where meteorological observation stations are located. The time span of the acquired historical wind data is no less than 10 years, and the data resolution is at least 1 hour average wind speed and direction. That is, at a certain moment, the acquired wind data includes wind speed and corresponding wind direction. Thus, the acquired wind data includes multiple pairs of wind speed and wind direction. As for parameter data, in addition to the conductor direction, parameters such as the conductor model, operating tension, span, and diameter can also be obtained to match with relevant data.

[0034] Step S102 converts the historical wind speed based on the angle between the conductor's orientation and the historical wind direction, and determines the corresponding breeze vibration frequency when wind data is known based on the converted historical wind speed. Specifically, when evaluating the breeze vibration experienced by the conductor, since breeze vibration is not only related to wind speed but also wind direction, under normal circumstances, when wind speeds reach 0-10 m / s, the conductor will experience breeze vibration. The vibration frequency is generally around 100 Hz. Breeze vibration is more pronounced between 5-10 m / s. Breeze vibration intensity is also highest when the wind direction is perpendicular to the conductor's orientation. Therefore, when evaluating the wind speed, it is necessary to convert the wind speed based on the wind direction to obtain the wind speed that actually affects the conductor when wind direction is taken into account. After determining the converted wind speed, the breeze vibration frequency is calculated based on this wind speed. The calculated breeze vibration frequency is determined based on the actual collected wind data and is therefore referred to as the breeze vibration frequency when wind data is known.

[0035] Step S103 , calculating the breeze vibration frequency when the wind data is unknown based on the wind data samples determined by the joint probability density distribution of the historical wind data.

[0036] Step S104 , evaluating the fatigue damage degree and the remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown.

[0037] When assessing the fatigue damage level of conductors based on breeze vibration frequency, it is necessary to obtain the breeze vibration frequency from the start of operation to the assessment time. However, when some transmission line conductors are first constructed and operated, meteorological observation points may not be deployed in the relevant areas, or data collected from meteorological observation points in a certain year may be missing, making it impossible to determine the breeze vibration frequency. Furthermore, when assessing the remaining life of a conductor, it is also necessary to determine the breeze vibration frequency in the future. However, due to the lack of wind data in the future, the breeze vibration frequency cannot be calculated.

[0038] Based on this, this embodiment determines the joint probability density distribution of wind speed and direction based on the acquired wind data, then determines a wind data sample when there is no wind data based on this joint probability density distribution of wind speed and direction. Based on this wind data sample, the corresponding breeze vibration frequency is calculated using the method of step S102 described above. Because this breeze vibration frequency is calculated based on inferred wind data, it is referred to as the breeze vibration frequency when there is unknown wind data. Thus, after obtaining the required breeze vibration frequency, the fatigue damage degree of the conductor can be evaluated based on the breeze vibration frequency from the start of operation to the evaluation time; and the remaining life of the conductor can be evaluated based on this fatigue damage degree and the breeze vibration frequency in the future period.

[0039] The method for evaluating breeze vibration of transmission line conductors provided by the present invention addresses the problem that existing methods for evaluating breeze vibration of transmission line conductors rely solely on the number of vibrations, without considering the wind speed and direction characteristics of the conductor's environment. By analyzing historical wind speed and direction data for the area where the transmission line is located and combining it with a proposed method for calculating breeze vibration characteristics, the method accurately calculates and evaluates the number of vibrations occurring each year, and accurately assesses the degree of conductor fatigue damage and conductor life. This method considers regional wind field changes and dynamically assesses conductor fatigue damage, overcoming the drawback of traditional methods that fail to consider the impact of factors such as wind speed, wind direction, and line orientation on breeze vibration.

[0040] In this embodiment, a method for evaluating breeze vibration of a transmission line conductor is provided, the method comprising the following steps:

[0041] Step S201: Obtain historical wind data of the area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated. The historical wind data includes historical wind speed and corresponding historical wind direction, and the parameter data includes the direction of the conductor. Figure 1 Step S101 of the illustrated embodiment will not be described in detail here.

[0042] Step S202 : converting the historical wind speed based on the angle between the direction of the conductor and the historical wind direction, and determining the breeze vibration frequency corresponding to the known wind data based on the converted historical wind speed.

[0043] Specifically, the above step S202 includes:

[0044] Step S2021, correct the historical wind direction according to the relationship between the historical wind direction and the preset angle to obtain the corrected wind direction; determine the angle between the conductor direction and the historical wind direction according to the difference between the corrected wind direction and the conductor direction; determine the converted historical wind speed according to the product of the sine value of the angle and the historical wind speed.

[0045] Specifically, the wind direction angle uses a circular system of 0° to 360°, but the wind blowing from below and above the transmission line at the same angle has the same impact; therefore, for the obtained wind direction (in this embodiment, the wind direction angle), first compare it with 180°. If it is greater than or equal to 180°, it is converted (i.e., corrected). Based on this, the corrected wind direction V d The calculation is done using the following formula:

[0046]

[0047] Where W represents the measured wind direction.

[0048] After adjusting for wind direction, the angle between the wind direction and the transmission line conductors needs to be further considered. If the difference between the two is used as the angle, when the difference is greater than 90°, the effect of wind direction on the conductors is the same as the corresponding angle less than 90°. Therefore, the specific angle is determined based on the relationship between the difference and 90°. Therefore, the angle between the conductor direction and the historical wind direction is calculated using the following formula:

[0049]

[0050] Where, l d The angle of the conductor alignment ranges from 0 to 179°, where 0° indicates a north-south transmission line and 90° indicates an east-west transmission line. θ is the angle between the wind direction and the conductor alignment.

[0051] Based on this angle, the converted historical wind speed is calculated using the following formula:

[0052] V=V0×sin(θ)

[0053] Where V0 represents the measured historical wind speed, and V represents the converted historical wind speed.

[0054] Step S2022, calculate the vibration damage frequency based on the conductor diameter and the breeze vibration wind speed; determine the breeze vibration frequency corresponding to different wind speeds based on the product of the vibration damage frequency and different preset thresholds; determine the breeze vibration frequency corresponding to the converted historical wind speed based on the converted historical wind speed and the breeze vibration frequencies corresponding to different wind speeds.

[0055] Specifically, the vibration damage frequency is calculated using the following formula:

[0056]

[0057] Where, S represents the Strouhal number, which is 0.2 in this embodiment, B represents the wire diameter, in m, V G The wind speed when breeze vibration occurs is 8m / s in this embodiment.

[0058] The breeze vibration frequency corresponding to different wind speeds is expressed by the following formula:

[0059]

[0060] Where N h Indicates the number of conductor vibrations per unit sample time, in ten thousand. dt is the time sample parameter. When the wind speed is the hourly average wind speed, it is set to 1. For other time interval average wind speeds, it is calculated by dividing the sampling interval by 3600 seconds. For a 10-minute average wind speed, dt is 600 / 3600 = 1 / 6.

[0061] Based on the breeze vibration frequencies corresponding to the above-mentioned different wind speeds, after determining the converted historical wind speed, determine which range it is in, and then determine the breeze vibration frequency corresponding to the converted historical wind speed based on the breeze vibration frequency calculation method of the corresponding range.

[0062] Step S203 , calculating the breeze vibration frequency when the wind data is unknown based on the wind data samples determined by the joint probability density distribution of the historical wind data.

[0063] Specifically, the joint probability density distribution of historical wind data is calculated using:

[0064] Step S231, based on the historical wind speed, uses the kernel density distribution method to calculate the wind speed probability density distribution. Specifically, when calculating the probability density distribution, the kernel density distribution performs weighted smoothing on each sample point using a kernel function based on the distribution of the sample points in the multidimensional space, thereby obtaining a probability density estimate for the entire space. In this embodiment, when calculating the wind speed probability density distribution, the wind speed data in the acquired historical wind data is used as the sample point, and the wind speed probability density distribution is expressed using the following formula:

[0065]

[0066] Where f(x) represents the probability density distribution of wind speed when the wind speed is x, n represents the total number of wind speed samples, and K is the kernel function, which uses the Gaussian kernel function, that is, x i is the wind speed sample size, and h is the wind speed sample segment spacing. In breeze vibration assessment, the sample segment spacing should be less than 1m / s.

[0067] Step S232: Divide the wind speed intervals based on the historical wind speeds, and filter the historical wind directions within each wind speed interval.

[0068] Step S233 , based on the historical wind directions in each wind speed interval, a kernel density analysis method is used to calculate the probability density distribution of the wind direction.

[0069] Among them, for the acquired wind data, at a certain moment, it not only includes wind speed data, but also wind direction data. Therefore, when calculating the probability density distribution of wind direction, it is necessary to consider the correspondence between wind speed and wind direction. Therefore, this embodiment first divides the wind speed into intervals. For example, it can be divided from 0.5-15m / s with 0.5m / s as the boundary, and wind speeds greater than 15m / s are statistically analyzed as 15m / s. Then the wind direction data corresponding to each wind speed interval is screened, and the wind direction data is used as a sample point. The probability density distribution of wind direction in any wind speed interval is expressed by the following formula:

[0070]

[0071] Where f(d) represents the probability density distribution of wind direction when the wind direction is d in the corresponding wind speed range, n x represents the total number of wind direction samples in the corresponding wind speed range, K is the kernel function, l is the wind direction sample segment spacing, in this embodiment, the wind direction is 10° as the spacing, the range is 0-350°, d i is the wind direction sample size.

[0072] Step S234: constructing a wind speed and wind direction joint probability density distribution based on the wind speed probability density distribution and the wind direction probability density distribution.

[0073] Specifically, the joint probability density distribution of wind speed and direction is expressed by the following formula:

[0074]

[0075] In this embodiment, the calculated joint probability distribution of wind speed and direction can be expressed as follows:

[0076] Table 1

[0077] Wind speed range 0° 10° 20° .... 330° 340° 350° 0-0.5m / s 0.5％ 1％ 1.3％ .... 0.2％ 0.3％ 0.1％ 0.5-1m / s 1％ 1％ 0.2％ .... 0.4％ 0.3％ 0.1％ .... .... .... .... .... .... .... .... 14-14.5m / s 0.1％ 0.3％ 0.2％ .... 1.2％ 0.6％ 0.2％ 14.5-15m / s 0.2％ 0.6％ 0.8％ .... 0.2％ 0.3％ 0.1％

[0078] Specifically, the above step S203 includes:

[0079] Step S2031, based on the joint probability density distribution of historical wind data, the number of wind data samples within a preset time period is determined. Specifically, for the breeze vibration frequency, the calculation is performed in units of years in this embodiment. Therefore, when determining the number of wind data samples, it is also in units of years, that is, the number of wind data samples within a year is determined based on the joint probability density distribution of historical wind data. At the same time, if the historical wind data obtained is hourly wind data, the number of wind data samples determined here is also in units of hours. That is, the number of wind data samples corresponding to any wind speed and wind direction combination within the year is calculated using the following formula:

[0080] V c (x,d)=f(x,d)×365×24

[0081] In step S2032, based on the number of wind data samples, Monte Carlo simulation is used to obtain wind data for a preset time period. Specifically, Monte Carlo simulation is a method for solving problems through random sampling. It simulates actual conditions through a large number of repeated random experiments based on a known probability distribution. In this embodiment, obtaining wind data using Monte Carlo simulation can be implemented according to the following process:

[0082] 1. Determine the sampling probability of each wind speed and direction combination.

[0083] Sum up the number of samples corresponding to all wind speeds and directions, then divide the number of samples corresponding to each wind speed and direction by the sum to obtain the sampling probability corresponding to each wind speed and direction combination.

[0084] 2. Conduct random sampling.

[0085] During each simulated random sampling, a random number generator is used to generate a random number r between 0 and 1. The random number r is then assigned to a specific wind speed and direction combination based on the sampling probability.

[0086] 3. Repeat sampling to generate a sequence.

[0087] Following this sampling method, a sample is taken for each time step in a year (e.g., one hour is a time step) to determine the wind speed and direction combination corresponding to that time step. This process is repeated until all time steps within the year have been sampled, ultimately generating an annual wind speed and direction data series that conforms to the proportional relationship between the number of samples in different wind speed and direction intervals (i.e., conforms to the joint probability distribution of wind speed and direction).

[0088] Step S2033 calculates the breeze vibration frequency within the preset time period based on the wind data within the preset time period. Specifically, after simulating the wind data within the preset time period, the breeze vibration frequency is calculated using the simulated wind data in the same manner as step S202 above. The specific calculation process is not repeated here.

[0089] Step S204 , evaluating the fatigue damage degree and the remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown.

[0090] Specifically, the above step S204 includes:

[0091] Step S2041 : determining the breeze vibration frequency of the transmission line conductor to be evaluated during the operating time according to the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown.

[0092] In an optional implementation manner, the above step S2041 includes:

[0093] Step a1: When the operating time of the transmission line conductor to be evaluated includes time with known wind data and time with unknown wind data, the breeze vibration frequency during the operating time of the transmission line conductor to be evaluated is determined based on the breeze vibration frequency during the known wind data and the breeze vibration frequency during the unknown wind data.

[0094] Step a2: when the operating time of the transmission line conductor to be evaluated does not include the time of unknown wind data, determining the breeze vibration frequency during the operating time of the transmission line conductor to be evaluated according to the breeze vibration frequency when the wind data is known.

[0095] Specifically, the above analysis shows that when some transmission line conductors were first constructed and operated, meteorological observation points were not yet deployed in the relevant areas, or data collected from meteorological observation points in a particular year was missing, making it impossible to determine the breeze vibration frequency. Therefore, when determining the breeze vibration frequency of the transmission line conductor to be evaluated during its operational time, it is necessary to determine whether all wind data has been acquired during this operational time. Then, based on the wind data acquisition status, the corresponding breeze vibration frequency can be calculated using steps a1 and a2 above.

[0096] For example, if the transmission line conductor to be evaluated was constructed and put into operation in 2005, but only wind data from 2010 to 2025 is available, the breeze vibration frequency of the transmission line conductor to be evaluated during its operational time needs to be determined based on the breeze vibration frequency corresponding to the wind data obtained from 2010 to 2025 and the breeze vibration frequency corresponding to the simulated wind data from 2005 to 2010. For another example, if the transmission line conductor to be evaluated was constructed and put into operation in 2010, and wind data from 2010 to 2025 is available, the breeze vibration frequency of the transmission line conductor to be evaluated during its operational time can be determined directly based on the breeze vibration frequency corresponding to the wind data obtained from 2010 to 2025.

[0097] In addition, when calculating the breeze vibration frequency, this embodiment calculates the corresponding breeze vibration frequency for each wind speed and wind direction combination. For multiple wind speed and wind direction combinations, the corresponding breeze vibration frequency is calculated using the following formula:

[0098]

[0099] Where i represents the i-th wind data sample, m is the total number of samples, and N hi is the number of breeze vibrations under the i-th wind data sample.

[0100] For multiple simulated wind data samples, the breeze vibration frequency is calculated using the following formula:

[0101]

[0102] Where j is the jth wind data sample obtained by simulation, p is the total number of samples, N qj is the number of breeze vibrations under the j-th simulated wind data sample.

[0103] Step S2042: Determine the fatigue damage degree of the transmission line conductor based on the ratio of the breeze vibration frequency during the operating time to the total number of breeze vibrations experienced. Specifically, if the breeze vibration frequency during the operating time includes the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown, the fatigue damage degree of the conductor is calculated using the following formula:

[0104]

[0105] Where N represents the total number of breeze vibrations experienced by the conductor according to the relevant conductor specifications; y represents the total number of years with unknown wind data. For example, if the transmission line conductor to be evaluated was constructed and put into operation in 2005, but only wind data from 2010 to 2025 is available, then y is taken as 5. In addition, if the breeze vibration frequency during the operating time only includes the breeze vibration frequency when the wind data is known, then

[0106] Step S2043: Determine the remaining life of the transmission line conductor to be evaluated based on the fatigue damage degree and the breeze vibration frequency when the wind data is unknown. Specifically, the remaining life is calculated using the following formula:

[0107]

[0108] As a specific application example of the embodiment of the present invention, Figure 5 As shown in FIG, the transmission line conductor breeze vibration assessment method is implemented using the following process:

[0109] (1) Collection of historical wind speed and direction data.

[0110] Collect historical meteorological data for the area where the transmission line conductors to be evaluated are located, including wind speed and direction data. The historical data should span at least 10 years, with a resolution of at least 1-hour average wind speed and direction. Collect data on the conductors to be evaluated, including conductor type, diameter, operating tension, span, and line orientation.

[0111] (2) Analysis of wind environment characteristics.

[0112] 1) Conduct probability density distribution analysis of historical wind speed data. Use the kernel density distribution method to calculate the probability density distribution of wind speed, which is expressed as follows:

[0113]

[0114] 2) Conduct a joint probability density analysis of historical wind speed and direction. First, divide the wind speed into 0.5-15m / s intervals, using 0.5m / s as the dividing line. Wind speeds greater than 15m / s are statistically analyzed as 15m / s. Filter the wind direction data within each wind speed interval and calculate the probability density distribution of wind direction under specific wind speed conditions using kernel density analysis. The calculation formula is as follows:

[0115]

[0116] 3) Calculate the joint probability density distribution function of wind speed and direction according to the following formula:

[0117]

[0118] (3) Calculation of breeze vibration characteristics and frequency.

[0119] Generally, when wind speeds reach 0-10 m / s, conductors will experience breeze vibration. The vibration frequency is generally around 100 Hz. Breeze vibration is more pronounced between 5-10 m / s. Breeze vibration intensity is greatest when the wind direction is perpendicular to the line's direction.

[0120] 1) The converted wind speed is calculated based on the angle between the line direction and the wind direction. The calculation formula is:

[0121] V=V0×sin(θ)

[0122] Where V0 is the wind speed, θ is the angle between the wind direction and the transmission line, and is calculated using the following formula:

[0123]

[0124] where l d The angle of the conductor is 0-179°, where the transmission line is in a north-south direction at 0° and in an east-west direction at 90°. d To correct the wind speed direction, the following formula can be used for calculation:

[0125]

[0126] Where W is the measured wind speed direction.

[0127] 2) Calculation of breeze vibration frequency, the calculation formula is as follows:

[0128]

[0129] Among them, N his the number of conductor vibrations per unit sample time, in ten thousand times. dt is the time sample parameter. When the wind speed is the hourly average wind speed, it is taken as 1. When the wind speed is the average wind speed at other time intervals, it is calculated by dividing the sampling time interval by 3600 seconds. For a 10-minute average wind speed, dt is taken as 600 / 3600=1 / 6. f is the vibration damage frequency. Where S is the Strouhal number, which is 0.2, B is the wire diameter (m), V G The wind speed when breeze vibration occurs is 8m / s.

[0130] (4) Conductor fatigue damage life assessment.

[0131] 1) In the fatigue life assessment of conductors, the number of conductor breeze vibrations is used as the core parameter, which consists of two parts: calculation of known wind speed data and estimation of unknown wind speed vibrations.

[0132] The number of vibrations with wind speed data is calculated by the following formula:

[0133]

[0134] Among them, i is the number of data samples, m is the total number of samples, N hi is the number of breeze vibrations under the i-th wind speed sample.

[0135] The number of future vibrations is in years. First, calculate the annual wind speed and direction data using the following formula based on the joint probability distribution table of wind speed and direction:

[0136] V c (x,d)=f(x,d)×365×24

[0137] The above formula is used to obtain the number of wind speed samples in different wind speed and wind direction ranges, and the annual wind speed and direction data are generated through Monte Carlo simulation. The number of breeze vibrations in the future year is further calculated. The number of breeze vibrations in the future year is calculated using the following formula:

[0138]

[0139] 2) Use breeze vibration times to assess the life of the conductor:

[0140] According to the relevant specifications of the conductor, the total number of breeze vibrations N that the conductor withstands is obtained, and the following fatigue life can be calculated:

[0141] Fatigue life of the wire: β=(N l +N w × y) / N. y is the number of years without wind speed data before the assessment time. For example, if the line was built in 2005 and the wind speed data is from 2010 to 2025, when calculating the fatigue damage degree, y is set to 5.

[0142] Estimated remaining service life of conductor: Y = (1-β) × N / N w This formula can be used to calculate the remaining fatigue life of a conductor. Based on this result, the frequency of inspections can be increased for lines nearing the end of their service life to detect line damage in advance and perform maintenance.

[0143] As a specific application example of the present invention, consider the 500kV transmission lines 132#-133# and 140#-141#, which were put into operation in 2010, as the transmission line conductors to be evaluated. A meteorological station with historical wind speed and direction data is located near the line area. The wind speed data is the hourly average wind speed. This method for evaluating breeze vibration of transmission line conductors is implemented using the following process:

[0144] Step 1: Collect historical wind speed and direction data.

[0145] Twenty years of wind speed and direction data were collected from meteorological stations around stations 132#-133# and 140#-141#. The data covers the period from January 1, 2004, to January 1, 2024. Hourly averages of wind speed and direction were used. Data was collected for the transmission line itself. The conductor model was LGJ-400 / 35, with a span of 483m. The two sections of the line ran northeast-southwest at a 50° angle to the north, and north-south at a 20° angle to the north.

[0146] Step 2: Analyze wind environment characteristics.

[0147] Based on the 20-year wind speed data collected, the probability density distribution of wind speed is calculated and analyzed to clarify the distribution characteristics of this area. The calculation results are as follows: Figure 2 shown.

[0148] Wind speeds were divided into different magnitudes, with 0.5 m / s as the dividing line, ranging from 0.5 to 15 m / s. Wind speeds greater than 15 m / s were statistically analyzed as 15 m / s. The joint probability distribution of wind speed and direction was then calculated, and a joint probability density distribution table was obtained. This table is shown in Table 2 below:

[0149] Table 2

[0150]

[0151]

[0152] Step 3: Calculate breeze vibration characteristics and frequency.

[0153] The direction of the evaluation line 132#-133# is 50°, i.e. d=50°, calculate the converted wind speed based on the historical wind direction data. First, make a direction correction to the measured wind direction data. Then calculate the angle θ between the line direction and the wind direction. Obtain the angle data between the line and the wind direction, as well as the distribution diagram. The angle distribution diagram corresponding to this line is as follows: Figure 3 Finally, the reduced wind speed of the conductor environment is calculated.

[0154] The direction of the evaluation line 140#-141# is 20°, i.e. d Equal to 20°, the converted wind speed is calculated based on historical wind direction data. Compared with the 50° route, the angle between the wind direction and the route is quite different. The angle distribution diagram corresponding to this route is as follows Figure 4 shown.

[0155] Step 4: Conductor fatigue damage life assessment.

[0156] Line 131#-132# was put into use in 2010. During the assessment of the conductor breeze vibration life, the line assessment period ended in January 2025. The existing breeze vibration times were calculated based on wind speed and direction data from 2010 to 2024 and the assessment calculation from 2024 to 2025.

[0157] The number of breeze vibrations with wind speed data from 2010 to 2024 is calculated. The vibration frequency chart for 2011 is as follows: Figure 5 The corresponding vibration times per year are shown in Table 3 below:

[0158] Table 3

[0159]

[0160] The year 2025 represents a sample of wind speeds and directions, calculated through the joint probability density of wind speeds and directions, used to estimate vibration frequency. As of the time of line assessment, the line had accumulated 1.6534 million light wind vibrations, and the fatigue ratio of the used conductors was β = 165.34 / 200 = 0.827.

[0161] Based on the joint probability density of wind speed and direction, the remaining life of the conductor is evaluated, that is, remaining life Y = (1-0.827) × 200 / 10.4 = 3.33 years.

[0162] Using this formula, the remaining fatigue life of the conductor is calculated to be approximately 3.33 years, indicating that the conductor on this line will begin to face a significant risk of breakage in early 2027. Based on this result, inspections can be increased for lines nearing the end of their service life to detect damage in advance.

[0163] Line 140#-141# was put into operation in 2010. During the conductor breeze vibration life assessment, the assessment period ended in January 2025. The current breeze vibration frequency was calculated based on wind speed and direction data from 2010 to 2024 and the assessment from 2024 to 2025. The line strikes a 20° angle, and the annual breeze vibration frequency is calculated as shown in Table 4 below:

[0164] Table 4

[0165]

[0166] As of the time of line assessment, the line had accumulated 561,200 breeze vibrations, and the fatigue ratio of the used conductors was β = 56.12 / 200 = 0.281.

[0167] Based on the joint probability density of wind speed and direction, the remaining life of the conductor is evaluated, that is, remaining life Y = (1-0.281) × 200 / 3.77 = 38.14 years.

[0168] Using this formula, we calculate the conductor's remaining fatigue life to be approximately 38.14 years, indicating an increased risk of line breakage due to fatigue damage caused by breeze vibration in 2063. This suggests that because the line's orientation is close to the dominant wind direction in the region, the probability of fatigue damage from breeze vibration is low.

[0169] In this paper, based on historical wind speed and direction data, the frequency of breeze-induced vibrations that have historically caused fatigue damage to transmission line conductors is assessed. Furthermore, by considering the influence of the angle between conductor orientation and wind direction on breeze vibration characteristics, a differential assessment of breeze vibration characteristics for conductors with different orientations within the same region is achieved. Furthermore, a joint probability density distribution function for wind speed and direction is established, taking into account historical wind speed and direction data. This function is used to predict the frequency of future breeze-induced fatigue damage to conductors, further enabling the prediction and assessment of conductor lifespan.

[0170] This embodiment also provides a device for evaluating breeze vibrations of power transmission line conductors. This device is used to implement the above-mentioned embodiments and preferred embodiments, and details already described will not be repeated. As used below, the term "module" may refer to a combination of software and / or hardware that implements a predetermined function. Although the devices described in the following embodiments are preferably implemented in software, implementation using hardware, or a combination of software and hardware, is also possible and contemplated.

[0171] This embodiment provides a device for evaluating the breeze vibration of a transmission line conductor. Figure 6 As shown, including:

[0172] A data acquisition module 61 is configured to acquire historical wind data of the area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, wherein the historical wind data includes historical wind speed and corresponding historical wind direction, and the parameter data includes the direction of the conductor;

[0173] A first frequency calculation module 62 is configured to convert the historical wind speed based on the angle between the direction of the conductor and the historical wind direction, and determine the breeze vibration frequency corresponding to the known wind data based on the converted historical wind speed;

[0174] A second frequency calculation module 63 is configured to calculate the breeze vibration frequency when the wind data is unknown based on the wind data sample determined by the joint probability density distribution of the historical wind data;

[0175] The evaluation module 64 is used to evaluate the fatigue damage degree and the remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown.

[0176] The further functional description of each of the above modules is the same as that of the above corresponding embodiments and will not be repeated here.

[0177] The embodiment of the present invention also provides a computer device having the above Figure 6 The transmission line conductor breeze vibration assessment device shown.

[0178] See also Figure 7 , Figure 7 is a structural diagram of a computer device provided by an optional embodiment of the present invention, such as Figure 7 As shown, the computer device includes: one or more processors 10, memory 20, and interfaces for connecting various components, including high-speed interfaces and low-speed interfaces. Various components utilize different buses to communicate with each other and can be installed on a common mainboard or installed in other ways as needed. The processor can process the instructions executed in the computer device, including instructions stored in the memory or on the memory to display the graphical information of the GUI on an external input / output device (such as, a display device coupled to the interface). In some optional embodiments, if necessary, multiple processors and / or multiple buses can be used together with multiple memories and multiple memories. Equally, multiple computer devices can be connected, and each device provides part of the necessary operations (for example, as a server array, a group of blade servers, or a multi-processor system). Figure 7 A processor 10 is taken as an example.

[0179] The processor 10 may be a central processing unit, a network processor, or a combination thereof. The processor 10 may further include a hardware chip. The hardware chip may be an application-specific integrated circuit, a programmable logic device, or a combination thereof. The programmable logic device may be a complex programmable logic device, a field programmable gate array, a general purpose array logic, or any combination thereof.

[0180] The memory 20 stores instructions that can be executed by at least one processor 10, so as to enable at least one processor 10 to execute the method shown in the above embodiment.

[0181] The memory 20 may include a program storage area and a data storage area, wherein the program storage area may store an operating system, an application required for at least one function; the data storage area may store data created based on the use of a computer device for displaying a small program landing page, etc. In addition, the memory 20 may include a high-speed random access memory, and may also include a non-transient memory, such as at least one disk storage device, a flash memory device, or other non-transient solid-state storage device. In some optional embodiments, the memory 20 may optionally include a memory remotely located relative to the processor 10, and these remote memories may be connected to the computer device via a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an intranet, a local area network, a mobile communication network, and a combination thereof.

[0182] The memory 20 may include a volatile memory, such as a random access memory; the memory may also include a non-volatile memory, such as a flash memory, a hard disk or a solid-state drive; the memory 20 may also include a combination of the above types of memory.

[0183] The computer device further includes a communication interface 30 for the computer device to communicate with other devices or a communication network.

[0184] The embodiment of the present invention also provides a computer-readable storage medium. The above-mentioned method according to the embodiment of the present invention can be implemented in hardware, firmware, or implemented as a computer code that can be recorded in a storage medium, or implemented as a computer code that is originally stored in a remote storage medium or a non-temporary machine-readable storage medium and downloaded through a network and will be stored in a local storage medium, so that the method described herein can be stored in such software processing on a storage medium using a general-purpose computer, a dedicated processor, or programmable or dedicated hardware. Among them, the storage medium can be a magnetic disk, an optical disk, a read-only storage memory, a random access memory, a flash memory, a hard disk or a solid-state drive, etc.; further, the storage medium can also include a combination of the above-mentioned types of memory. It can be understood that a computer, a processor, a microprocessor controller or programmable hardware includes a storage component that can store or receive software or computer code. When the software or computer code is accessed and executed by a computer, a processor or hardware, the method shown in the above embodiment is implemented.

[0185] A portion of the present invention may be applied as a computer program product, such as a computer program instruction, which, when executed by a computer, can call or provide the method and / or technical solution according to the present invention through the operation of the computer. Those skilled in the art should understand that the form in which the computer program instruction exists in a computer-readable medium includes, but is not limited to, a source file, an executable file, an installation package file, etc. Accordingly, the way in which the computer program instruction is executed by the computer includes, but is not limited to: the computer directly executes the instruction, or the computer compiles the instruction and then executes the corresponding compiled program, or the computer reads and executes the instruction, or the computer reads and installs the instruction and then executes the corresponding installed program. Here, the computer-readable medium may be any available computer-readable storage medium or communication medium that can be accessed by the computer.

[0186] Although the embodiments of the present invention have been described with reference to the accompanying drawings, those skilled in the art may make various modifications and variations without departing from the spirit and scope of the present invention. Such modifications and variations are all within the scope defined by the appended claims.

Claims

1. A method for evaluating breeze vibration of a transmission line conductor, characterized in that: The method comprises: Obtaining historical wind data of the area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, wherein the historical wind data includes historical wind speed and corresponding historical wind direction, and the parameter data includes the direction of the conductor; The historical wind speed is converted based on the angle between the conductor direction and the historical wind direction, and the breeze vibration frequency corresponding to the known wind data is determined based on the converted historical wind speed; Calculate the breeze vibration frequency when unknown wind data is obtained based on the wind data samples determined by the joint probability density distribution of historical wind data; The fatigue damage degree and remaining life of the transmission line conductor to be assessed are evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown.

2. The method according to claim 1, characterized in that The historical wind speed is converted based on the angle between the conductor direction and the historical wind direction, including: Correct the historical wind direction according to the relationship between the historical wind direction and the preset angle to obtain the corrected wind direction; Determine the angle between the conductor direction and the historical wind direction based on the difference between the corrected wind direction and the conductor direction; The converted historical wind speed is determined according to the product of the sine value of the angle and the historical wind speed.

3. The method according to claim 1, characterized in that The parameter data also includes the conductor diameter, and the breeze vibration frequency when the corresponding known wind data is determined based on the converted historical wind speed, including: Calculate the vibration damage frequency based on the conductor diameter and breeze vibration wind speed; The breeze vibration frequency corresponding to different wind speeds is determined based on the product of the vibration damage frequency and different preset thresholds; The breeze vibration frequency corresponding to the converted historical wind speed is determined based on the converted historical wind speed and the breeze vibration frequencies corresponding to different wind speeds.

4. The method according to claim 1, wherein Before calculating the breeze vibration frequency when unknown wind data is obtained based on the wind data samples determined by the joint probability density distribution of historical wind data, the method further includes: Based on the historical wind speed, the kernel density distribution method is used to calculate the probability density distribution of wind speed; Divide the wind speed range based on historical wind speed and filter the historical wind direction within each wind speed range; Based on the historical wind direction in each wind speed interval, the kernel density analysis method is used to calculate the probability density distribution of wind direction; A wind speed and wind direction joint probability density distribution is constructed based on the wind speed probability density distribution and the wind direction probability density distribution.

5. The method according to claim 1, wherein Calculate the breeze vibration frequency when unknown wind data is generated based on wind data samples determined by the joint probability density distribution of historical wind data, including: Determine the number of wind data samples within a preset time period based on the joint probability density distribution of historical wind data; Based on the number of wind data samples, using Monte Carlo simulation to obtain wind data within a preset time period; The breeze vibration frequency within the preset time period is calculated based on the wind data within the preset time period.

6. The method according to claim 1, characterized in that The fatigue damage degree and remaining life of the transmission line conductor to be assessed are evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown, including: Determine the breeze vibration frequency of the transmission line conductor to be evaluated during the operating time based on the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown; Determine the fatigue damage degree of the transmission line conductor to be assessed based on the ratio of the breeze vibration frequency during the operating time to the total number of breeze vibrations experienced; The remaining life of the transmission line conductor to be evaluated is determined according to the fatigue damage degree and the breeze vibration frequency when the wind data is unknown.

7. The method according to claim 6, characterized in that The breeze vibration frequency of the transmission line conductor to be evaluated during the operating time is determined based on the breeze vibration frequency when wind data is known and the breeze vibration frequency when wind data is unknown, including: When the operating time of the transmission line conductor to be evaluated includes the time with known wind data and the time with unknown wind data, the breeze vibration frequency of the transmission line conductor to be evaluated during the operating time is determined based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown; When the operating time of the transmission line conductor to be evaluated does not include the time with unknown wind data, the breeze vibration frequency during the operating time of the transmission line conductor to be evaluated is determined based on the breeze vibration frequency when the wind data is known.

8. A device for evaluating breeze vibration of a power transmission line conductor, characterized in that: The device comprises: A data acquisition module is used to obtain historical wind data of the area where the transmission line conductor to be evaluated is located and parameter data of the transmission line conductor to be evaluated, wherein the historical wind data includes historical wind speed and corresponding historical wind direction, and the parameter data includes the direction of the conductor; A first frequency calculation module is used to convert the historical wind speed based on the angle between the direction of the conductor and the historical wind direction, and determine the breeze vibration frequency corresponding to the known wind data based on the converted historical wind speed; A second frequency calculation module is used to calculate the breeze vibration frequency when the wind data is unknown based on the wind data sample determined by the joint probability density distribution of the historical wind data; The evaluation module is used to evaluate the fatigue damage degree and remaining life of the transmission line conductor to be evaluated based on the breeze vibration frequency when the wind data is known and the breeze vibration frequency when the wind data is unknown.

9. A computer device, characterized in that: include: A memory and a processor, wherein the memory and the processor are communicatively connected to each other, the memory stores computer instructions, and the processor executes the method for evaluating breeze vibration of a transmission line conductor according to any one of claims 1 to 7 by executing the computer instructions.

10. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a computer to execute the method for evaluating breeze vibration of a power transmission line conductor according to any one of claims 1 to 7.

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