A method and system for monitoring wind load of transmission line conductors

Abstract

The present invention relates to the technical field of transmission line detection, and provides a method and system for monitoring the wind load of transmission line conductors. The method includes: setting a Rayleigh scattering light signal demodulation device in the substation machine room, using the spare optical fiber in the optical fiber ground wire as the sensing medium, and dividing the transmission line into multiple monitoring units; collecting the vibration signals of each monitoring unit according to the Rayleigh backscattering principle; calculating the wind load data of the conductors of the transmission line according to the vibration signals; calculating the cumulative damage index of the conductors according to the wind load data; determining the corresponding early warning level value according to the cumulative damage index of the conductors; and monitoring the wind load data according to the magnitude of the early warning level value. The present invention can improve the safety and reliability of the transmission line.

Description

Technical Field

[0001] The present invention relates to the technical field of transmission line detection, and particularly to a method, a system and an electronic device for monitoring the wind load of transmission line conductors. Background Art

[0002] Nowadays, during the operation of transmission lines, the conductors are affected by wind loads. Therefore, monitoring wind loads is crucial for ensuring the safety and stability of the lines. Currently, the commonly used monitoring methods mainly include anemometers, strain gauges, cable tension sensors, etc. These devices estimate the wind loads borne by the conductors by collecting data such as wind speed, conductor strain and tension in real time, and combining meteorological models and empirical formulas. This method improves the safety of transmission lines to a certain extent and helps maintenance personnel to timely grasp the operating status of the lines.

[0003] However, traditional monitoring devices often rely on local data collection and cannot comprehensively reflect the wind load distribution of the entire transmission line. In addition, the maintenance and calibration requirements of the devices increase the operating costs, and in extreme weather conditions, the monitoring devices may malfunction, resulting in missing or inaccurate data. Summary of the Invention

[0004] The present invention aims at the technical problems existing in the prior art and provides a method, a system and an electronic device for monitoring the wind load of transmission line conductors, which can improve the safety and reliability of transmission lines.

[0005] The technical solution of the present invention for solving the above technical problems is as follows:

[0006] The present invention provides a method for monitoring the wind load of transmission line conductors, the method comprising:

[0007] Setting a Rayleigh scattering optical signal demodulation device in the substation computer room, using the spare optical fiber in the optical fiber ground wire as a sensing medium, and dividing the transmission line into multiple monitoring units;

[0008] Collecting the vibration signals of each of the monitoring units according to the Rayleigh backscattering principle;

[0009] Calculating the wind load data of the conductors of the transmission line according to the vibration signals;

[0010] Calculating the cumulative damage index of the conductors according to the wind load data;

[0011] Determining the corresponding early warning level value according to the cumulative damage index of the conductors;

[0012] Monitoring the wind load data according to the magnitude of the early warning level value.

[0013] Further, collecting the vibration signals of each of the monitoring units according to the Rayleigh backscattering principle includes:

[0014] Obtaining the spatial position, time, optical fiber attenuation signal coefficient, optical fiber sensitivity coefficient, and strain component of the monitoring unit;

[0015] Obtaining the incident optical power, vibration angular frequency, phase delay, and noise component of the incident light entering the monitoring unit;

[0016] Determining the vibration signal according to the correction coefficients of the strain component and the noise component, the spatial position, time, optical fiber attenuation signal coefficient, optical fiber sensitivity coefficient, strain component of the monitoring unit, and the incident optical power, vibration angular frequency, phase delay, and noise component of the incident light; and taking the vibration signal as the optical fiber vibration response intensity.

[0017] Further, calculating the wind load data of the conductors of the transmission line according to the vibration signal includes:

[0018] Obtaining the spatial correction function of the spatial position of the monitoring unit and the optical fiber length of the monitoring unit;

[0019] Obtaining the mass coefficient, damping coefficient, and stiffness coefficient for calculating the wind load data;

[0020] Processing the optical fiber vibration response intensity according to the spatial correction function and optical fiber length of the spatial position of the monitoring unit, and the mass coefficient, the damping coefficient, and the stiffness coefficient to obtain the wind load data of the conductors of the transmission line.

[0021] Further, calculating the cumulative damage index of the conductor according to the wind load data includes:

[0022] Obtaining the material constant corresponding to the material of the conductor and the temperature influence coefficient of the influence of the environmental temperature on the damage accumulation of the conductor;

[0023] Obtaining the measured wind load collected by the monitoring unit in each time period and the critical wind load of the material of the conductor;

[0024] Obtaining the acting duration of the wind load on the conductor in each time period and the reference duration of the preset standard;

[0025] Obtaining the weight coefficient characterizing the importance of each time period, and calculating the cumulative damage index of the conductor according to the weight coefficient, the acting duration, the reference duration, the measured wind load, the critical wind load, the material constant, and the temperature influence coefficient.

[0026] Further, determining a corresponding early warning level value according to the cumulative damage index of the wire includes:

[0027] Obtaining a benchmark threshold for evaluating the cumulative damage of the wire;

[0028] Obtaining the time-scale coefficient and daily variation coefficient of the cumulative damage of the wire;

[0029] Processing the benchmark threshold according to the time-scale coefficient, daily variation coefficient and cumulative damage index of the cumulative damage of the wire to determine the early warning level value.

[0030] Further, monitoring the wind load data according to the magnitude of the early warning level value includes:

[0031] When 0 ≤ W < 0.3, determining that the wind load data is in a normal state;

[0032] When 0.3 ≤ W < 0.6, determining that the wind load data is in a general early warning state;

[0033] When 0.6 ≤ W < 0.8, determining that the wind load data is in an important early warning state;

[0034] When W ≥ 0.8, determining that the wind load data is in a severe early warning state;

[0035] Wherein, W is the early warning level value.

[0036] Further, the method further includes:

[0037] Real-time displaying the full-line wind load distribution map, key-point wind load time-history curve, cumulative damage index change trend and early warning level status of the transmission line on the monitoring interface of the substation computer room.

[0038] The present invention also provides a transmission line wire wind load monitoring system, and the system includes:

[0039] A line division module, configured to set Rayleigh scattering light signal demodulation equipment in the substation computer room, use the spare optical fiber in the optical fiber ground wire as a sensing medium, and divide the transmission line into multiple monitoring units;

[0040] A data acquisition module, configured to acquire vibration signals of each of the monitoring units according to the Rayleigh backscattering principle;

[0041] A first calculation module, configured to calculate the wind load data of the wire of the transmission line according to the vibration signal;

[0042] A second calculation module, configured to calculate the cumulative damage index of the wire according to the wind load data;

[0043] A third calculation module, configured to determine a corresponding early warning level value according to the cumulative damage index of the wire;

[0044] A data monitoring module, configured to monitor the wind load data according to the magnitude of the early warning level value.

[0045] The beneficial effects of the present invention are as follows:

[0046] (1) The present invention adopts the distributed optical fiber sensing technology, using the spare optical fiber (optical fiber ground wire) as the sensing medium, enabling the transmission line to achieve continuous wind load monitoring throughout the entire line range, ensuring the comprehensiveness of monitoring. At the same time, optical fiber sensing has high sensitivity and resolution, capable of capturing real-time vibration information at different positions, visualizing the wind load conditions of the entire line, and improving the coverage breadth and accuracy of safety monitoring.

[0047] (2) By real-time monitoring the vibration signal and calculating the wind load and damage index, the present invention can continuously output accurate and real-time line wind load information. This real-time nature can not only effectively track the loading conditions of the line but also quickly respond in the event of sudden changes such as sharp wind speed changes, timely evaluate the risks of the line, ensure the efficient transmission and processing of early warning signals, and improve the dynamic safety management level of the transmission line.

[0048] (3) Through the calculation of the cumulative damage index, the present invention effectively records the damage conditions of the line under long-term wind load. It provides a scientific and quantitative basis for the health status of the line, helps to discover potential aging or damage trends, and provides decision-making support for equipment renewal and line reinforcement. Long-term cumulative monitoring can also predict possible fatigue failures of the line, thereby optimizing the line maintenance plan, extending the equipment life, and reducing the overall operation and maintenance costs.

[0049] In summary, through the distributed optical fiber sensing technology, the present invention realizes the comprehensive, real-time, and efficient monitoring of the wind load of the transmission line conductor, effectively improves the safe operation level and maintenance efficiency of the transmission line, and provides technical support for the intelligent development of the power grid system. Description of the Drawings

[0050] Figure 1 It is a scenario diagram of a method for monitoring the wind load of a transmission line conductor provided by the present invention;

[0051] Figure 2 It is a flowchart of a method for monitoring the wind load of a transmission line conductor provided by the present invention;

[0052] Figure 3 It is a schematic structural diagram of a system for monitoring the wind load of a transmission line conductor provided by the present invention;

[0053] Figure 4Schematic diagram of the hardware structure of a possible electronic device provided by the present invention. Detailed implementation manners

[0054] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described with reference to the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative efforts belong to the protection scope of the present invention.

[0055] Please refer to Figure 1 , Figure 1 Scene diagram of a method for monitoring the wind load of transmission line conductors provided by the present invention. As Figure 1 shown, the terminal and the server are connected through a network, for example, through a wired or wireless network connection, etc. Among them, the terminal may include, but is not limited to, portable terminals such as mobile phones and tablets installed with various network platform applications, as well as fixed terminals such as computers, inquiry machines, and advertising machines. Among them, the server provides various business services for users, including service push servers, user recommendation servers, etc.

[0056] It should be noted that Figure 1 the scene diagram of a method for monitoring the wind load of transmission line conductors shown is only an example. The terminal, server, and application scenarios described in the embodiments of the present invention are for more clearly explaining the technical solutions of the embodiments of the present invention, and do not limit the technical solutions provided by the embodiments of the present invention. Those skilled in the art know that with the evolution of the system and the emergence of new business scenarios, the technical solutions provided by the embodiments of the present invention are also applicable to similar technical problems.

[0057] Among them, the terminal can be used for:

[0058] Set Rayleigh scattering light signal demodulation equipment in the substation computer room, use the spare optical fiber in the optical fiber ground wire as the sensing medium, and divide the transmission line into multiple monitoring units;

[0059] Collect the vibration signals of each of the monitoring units according to the Rayleigh backscattering principle;

[0060] Calculate the wind load data of the conductors of the transmission line according to the vibration signals;

[0061] Calculate the cumulative damage index of the conductors according to the wind load data;

[0062] Determine the corresponding early warning level value according to the cumulative damage index of the conductors;

[0063] Monitor the wind load data according to the magnitude of the early warning level value.

[0064] Please refer to Figure 2 , which provides a flowchart of a method for monitoring the wind load of transmission line conductors according to the present invention, including the following steps:

[0065] Step 201: Set up a Rayleigh scattering optical signal demodulation device in the substation computer room, use the spare optical fiber in the optical fiber ground wire as the sensing medium, and divide the transmission line into multiple monitoring units.

[0066] Among them, Rayleigh scattering is a phenomenon in which an optical signal scatters due to the minute structural inhomogeneity of the optical fiber during transmission in the optical fiber. By demodulating the Rayleigh scattering signal, the minute changes in the vibration of the optical fiber can be analyzed, and then the vibration information at different positions along the length of the optical fiber can be obtained. The demodulation device is responsible for receiving, demodulating, and analyzing the Rayleigh scattering signal in the optical fiber to detect the vibration characteristics of the optical fiber. By centrally setting this device in the substation computer room, the Rayleigh scattering signal transmitted by the optical fiber of the optical fiber ground wire can be directly utilized to achieve remote monitoring, which is not only conducive to the centralized maintenance and management of the equipment, but also can avoid the impact on the line caused by on-site installation.

[0067] The optical fiber ground wire cable is an overhead ground wire containing optical fibers, which is widely used above the transmission line. It can not only be used as a ground wire to prevent lightning strikes, but also for data communication. Using the spare optical fiber in the optical fiber ground wire as the sensing medium does not require additional installation of other sensor devices on the transmission line. The change information of the vibration signal transmitted through this spare optical fiber can reflect the change of the external wind load on the conductor, thus effectively reducing the cost and maintenance difficulty of the system.

[0068] To achieve the wind load monitoring of the entire line, the entire transmission line is divided into several monitoring units, and the length of each unit is a fixed number of meters (the specific length is set according to application requirements). In each monitoring unit, by collecting and analyzing the vibration signal of this section of the optical fiber, the vibration information and wind load data at this position can be obtained.

[0069] This segmented monitoring method has the following advantages:

[0070] Precise positioning: Since each monitoring unit corresponds to a specific position on the line, the system can quickly locate the specific area affected by the wind load on the line according to the unit number.

[0071] Real-time distributed monitoring: The setting of multiple units enables the system to obtain the vibration signals at different positions in real time, forming a distributed wind load monitoring network.

[0072] Comprehensive coverage: Segmented monitoring covers the entire line, avoiding the monitoring blind spots that may occur in traditional point-type monitoring.

[0073] The present invention realizes full-line and distributed wind load monitoring without adding additional line equipment by centrally installing Rayleigh scattering demodulation equipment in the substation computer room and combining the sensing medium function of the spare optical fiber of the optical fiber ground wire. It not only reduces the complexity of line installation, but also improves the stability of data and the reliability of transmission, which is beneficial to the safety management of transmission lines and the optimization of operation and maintenance costs.

[0074] Step 202: According to the Rayleigh backscattering principle, collect the vibration signals of each of the monitoring units.

[0075] In some embodiments, step 202 may include:

[0076] Obtain the spatial position, time, optical fiber attenuation signal coefficient, optical fiber sensitivity coefficient, and strain component of the monitoring unit;

[0077] Obtain the incident optical power, vibration angular frequency, phase delay, and noise component of the incident light entering the monitoring unit;

[0078] Determine the vibration signal according to the correction coefficient for adjusting the strain component and the noise component, the spatial position, time, optical fiber attenuation signal coefficient, optical fiber sensitivity coefficient, strain component of the monitoring unit, and the incident optical power, vibration angular frequency, phase delay, and noise component of the incident light; and use the vibration signal as the optical fiber vibration response intensity.

[0079] In some embodiments, the optical fiber vibration response intensity can be expressed as:

[0080]

[0081] where R(x,t) is the optical fiber vibration response intensity, x is the spatial position, t is the time, α is the optical fiber sensitivity coefficient, β is the optical signal attenuation coefficient, P(t) is the incident optical power, ω is the vibration angular frequency, is the phase delay, ∈(x,t) is the strain component, η(x,t) is the noise component, and γ is the correction coefficient.

[0082] In specific implementation, the formula of the optical fiber vibration response intensity consists of two parts: the first part is the main signal component of the optical fiber response intensity, and the second part is the correction and compensation term for strain and noise. The overall model combines factors such as spatial position, time, incident optical power, and environmental noise to reflect the vibration response of the optical fiber under different conditions.

[0083] The first part: The main component of the optical fiber vibration response signal

[0084] α is the fiber optic sensitivity coefficient. This coefficient is used to quantify the sensitivity of the fiber optic to vibration signals, that is, the response intensity of the fiber optic to the same vibration under different environments. The higher the sensitivity, the more significant the impact of the change in the vibration signal on R(x,t).

[0085] exp(-βx) is the optical signal attenuation factor. This term represents the attenuation of the optical signal in the fiber optic in exponential form, where β is the attenuation coefficient, representing the influence of the fiber optic length x on the signal intensity. As the distance increases, the signal gradually attenuates. If the attenuation coefficient is high, the signal received in the fiber optic area far from the signal source is weaker.

[0086] is the integral response of the fiber optic vibration.

[0087] P(t) is the incident optical power, representing the intensity of the light entering the fiber optic. The higher the optical power, the stronger the signal intensity.

[0088] ω is the vibration angular frequency, reflecting the periodic characteristics of the vibration signal. By adjusting the angular frequency, signals of different frequencies can be obtained, so as to capture the responses of different characteristics of the fiber optic.

[0089] is the phase change term. Here is the spatial phase delay, which fine-tunes the responses at different positions to match the spatial distribution of the actual vibration.

[0090] This part of the integral processing of the vibration signal accumulates the signal intensity, so as to comprehensively quantify the fiber optic vibration within a certain period of time.

[0091] Second part: Compensation and correction terms for strain and noise

[0092] γ is the correction coefficient. This coefficient adjusts the compensation amounts for strain and noise according to the actual situation, so that the signal can more truly reflect the vibration under external conditions.

[0093] ∈(x,t) is the strain component, representing the strain of the fiber optic at position x. It reflects the response brought about by the deformation of the fiber optic caused by external loads (such as wind loads).

[0094] η(x,t) is the noise component, representing the inevitable noise in the signal. Noise usually comes from external environmental interference and electronic noise of the system itself, etc., and will affect the vibration signal.

[0095] is the combined response term. By taking the square root of the sum of the squares of the strain and the noise, the actual intensity of the corrected signal is obtained to ensure that the influences of the strain and the noise on the signal are reasonably considered.

[0096] The present invention provides a dynamic model for the vibration response of an optical fiber, considering the combined effects of optical fiber sensitivity, optical signal attenuation, external vibration frequency, spatial position change, and environmental strain and noise. Through this model, the vibration response intensity in the optical fiber can be calculated more precisely, providing a reliable data basis for subsequent wind load monitoring and risk assessment.

[0097] Step 203: Calculate the wind load data of the conductors of the transmission line according to the vibration signal.

[0098] In some embodiments, step 203 may include:

[0099] Obtain the spatial correction function of the spatial position of the monitoring unit and the optical fiber length of the monitoring unit;

[0100] Obtain the mass coefficient, damping coefficient, and stiffness coefficient for calculating the wind load data;

[0101] Process the optical fiber vibration response intensity according to the spatial correction function of the spatial position of the monitoring unit, the optical fiber length, the mass coefficient, the damping coefficient, and the stiffness coefficient to obtain the wind load data of the conductors of the transmission line.

[0102] In some embodiments, the wind load data of the conductors of the transmission line can be expressed as:

[0103]

[0104] where μ is the mass coefficient, θ(x) is the spatial correction function, λ is the damping coefficient, ξ is the stiffness coefficient, σ is the non-linear correction coefficient, R is the optical fiber vibration response intensity, and L is the optical fiber length of the monitoring unit.

[0105] In specific implementation, this formula is used to estimate the wind load of the transmission line at different positions x and times t. The accuracy of wind load estimation depends on the analysis of the optical fiber vibration response, that is, by measuring the vibration signal R and its change rate and acceleration, and combining different physical parameters, the force exerted by the wind on the line is deduced.

[0106] μ is the mass coefficient, which is used to adjust the unit measure of the wind load so that the estimated wind load conforms to the actual unit. This coefficient is determined based on the mass of the conductors of the transmission line and the physical characteristics of the vibration response it receives, ensuring that the calculation of the wind load conforms to the true physical response characteristics of the conductors.

[0107] θ(x) is a spatially varying correction function. Since the wind load is unevenly distributed along the transmission line and the wind loads on the conductors at different positions may vary, θ(x) can adjust the responses at different positions to make the wind load estimation more accurate. This function is usually related to the actual geometric layout of the line and topographical factors to capture the physical characteristics of the line at specific positions.

[0108] The second-order time derivative of the intensity of the fiber optic vibration response This term represents the acceleration of the intensity of the fiber optic vibration response and reflects the sharp changes in the line vibration signal. Generally, the greater the acceleration, the greater the wind load on the line may be. Therefore, more sensitive vibration information can be captured through the second derivative. After combining this term with the spatial correction function θ(x), it serves as the main part of the model for estimating the effect of dynamic wind loads on the conductors.

[0109] The damping coefficient λ and the first-order time derivative of the response intensity This term is used to characterize the energy dissipation characteristics of the system, that is, the energy loss generated by factors such as air resistance or conductor self-damping during the vibration of the line. The stronger the damping effect, the faster the vibration of the line decays, and the corresponding influence of the wind load will also decrease.

[0110] It is the velocity component of the intensity of the fiber optic vibration response and represents the rate of change of the vibration. The velocity component reflects the trend of the vibration change. Wind loads usually result in a higher vibration rate, and the damping term is used to estimate the influence of wind loads at different vibration velocities to ensure the adjustment of wind load estimation during drastic changes in vibration.

[0111] The stiffness coefficient ξ. This term is used to characterize the stiffness characteristics of the line material and reflects the ability of the conductor to resist deformation under the action of wind loads. The greater the stiffness coefficient, the more resistant the material is to deformation, and the corresponding effect of the wind load decreases.

[0112] R The intensity of the fiber optic vibration response itself represents the vibration state of the line at a certain position and time. Combining with the stiffness coefficient, the direct influence of wind loads on the conductor can be obtained. The greater the response intensity R, the greater the force on the conductor.

[0113] The non-linear correction coefficient. This coefficient is used to adjust the non-linear variation of wind loads, especially the variation amplitude of wind loads at different positions along the line. In the case of drastic variation of wind loads with position, the non-linear correction coefficient enables the model to more accurately reflect the load differences at different positions.

[0114] This item represents the oscillatory change along the line position. The sine function simulates the periodic change along the line, reflecting the distribution law of wind load on the line. L is the length of the monitoring unit. By taking the absolute value and processing with the exponential function, the load varying with position becomes smoother, closer to the actual stress situation of the line.

[0115] In the present invention, by combining the different order change rates (acceleration, velocity) of the optical fiber vibration response with physical parameters such as stiffness, damping, and mass, the dynamic response of each point on the transmission line under the action of wind load is simulated. The introduced spatial and nonlinear corrections make the estimated wind load more in line with the actual stress distribution of the transmission line.

[0116] Step 204: Calculate the cumulative damage index of the conductor according to the wind load data.

[0117] In some embodiments, step 204 may include:

[0118] Obtain the material constant corresponding to the material of the conductor and the temperature influence coefficient of the influence of environmental temperature on the damage accumulation of the conductor;

[0119] Obtain the measured wind load collected by the monitoring unit in each time period and the critical wind load of the material of the conductor;

[0120] Obtain the acting duration of the wind load on the conductor in each time period and the reference duration of the preset standard;

[0121] Obtain the weight coefficient characterizing the importance of each time period, and calculate the cumulative damage index of the conductor according to the weight coefficient, the acting duration, the reference duration, the measured wind load, the critical wind load, the material constant, and the temperature influence coefficient.

[0122] In some embodiments, the cumulative damage index is expressed as:

[0123]

[0124] where D is the cumulative damage index, ψ i is the weight coefficient, F i is the measured wind load in the i-th time period, F c is the critical wind load, m is the material constant, k is the temperature influence coefficient, T i is the acting duration of the wind load in the i-th time period, and T0 is the reference duration.

[0125] In the specific implementation, in this solution, the cumulative damage index D represents the damage accumulated by the transmission line conductors after being subjected to wind loads over multiple time periods. The larger the value, the more serious the cumulative damage of the line, and it may be close to or exceed the safe service life of the material. This index accumulates the damage amount for each period of time to obtain the total damage amount of the material or structure, and then evaluates the health status of the line.

[0126] ψ i is the weight coefficient, which is used to characterize the relative importance of the i-th monitoring time period. Different time periods may have different effects on damage due to factors such as environmental conditions and changes in line load. The weight coefficient can adjust the contribution of each time period to the cumulative damage. For example, when the wind speed fluctuates greatly or the environmental temperature is high during a certain period, the weight coefficient can be appropriately increased to more accurately reflect the damage effect of that period.

[0127] F i represents the actual wind load monitored during the i-th time period. It reflects the actual external force acting on the conductor during that time period. F c represents the critical wind load of the conductor material, that is, the maximum wind load that the material or structure can withstand under normal use conditions. Exceeding this critical value will cause excessive stress in the material, which may lead to damage or permanent deformation.

[0128] Wind load ratio is the core part of calculating the damage. When the measured wind load approaches or exceeds the critical wind load, the damage index increases significantly, indicating that the stress on the line is relatively high and has a greater impact on the cumulative damage.

[0129] The material constant m is an exponential parameter determined by the fatigue characteristics of the conductor material, which is used to characterize the damage accumulation law of the material under repeated loads. For different materials, the value of m is different and is usually obtained through experiments. The larger the material constant, the higher the sensitivity of the material to wind loads; for conductor materials, the value of m reflects the damage growth rate under different wind load ratios.

[0130] The temperature influence coefficient k characterizes the influence of environmental temperature on damage accumulation. At higher or lower temperatures, the mechanical properties of the material will change, thus affecting its damage rate. The higher or lower the temperature, the more likely the material is to suffer fatigue damage. The influence of different temperatures on the cumulative damage of the material is adjusted by k to ensure the accuracy of the calculation results.

[0131] T i represents the action duration of the i-th time period. The longer the action time of the wind load, the greater the cumulative damage to the conductor. T0 is the reference time constant, usually taking a standard time period value, which is used to normalize the damage of different time periods.

[0132] Temperature influence part In exponential function representation, the influence of temperature on damage accumulates gradually over time, and this cumulative effect is adjusted with temperature changes. This item is used to standardize the combined influencing factors of time and temperature, so that the damage values can be consistent in different monitoring periods.

[0133] This cumulative damage index formula combines factors such as wind load conditions, temperature, and material properties in each monitoring time period, so that the damage values in each time period have specific weights and adjustment factors when accumulated. The calculation of the cumulative damage index D provides a quantitative basis for evaluating the long-term reliability of transmission lines, performing regular maintenance, and predicting the line life, which helps to detect potential structural risks in advance and formulate reasonable maintenance and safety guarantee plans.

[0134] Step 205: Determine the corresponding early warning level value according to the cumulative damage index of the wire.

[0135] In some embodiments, step 205 may include:

[0136] Obtain a reference threshold for evaluating the cumulative damage of the wire;

[0137] Obtain the time scale coefficient and daily variation coefficient of the cumulative damage of the wire;

[0138] Process the reference threshold according to the time scale coefficient, daily variation coefficient, and cumulative damage index of the cumulative damage of the wire to determine the early warning level value.

[0139] In some embodiments, the early warning level value is expressed as:

[0140]

[0141] Where W is the early warning level value, ρ is the reference threshold, τ is the time scale coefficient, δ is the daily variation coefficient, and D is the cumulative damage index.

[0142] In specific implementation, W is the wind load early warning level calculated based on the current monitoring status, indicating the real-time safety status of the line. The higher the value, the greater the risk, the higher the early warning level, and the more attention needs to be paid and corresponding measures may be taken. By dynamically calculating W, the system can make a quick response according to the actual conditions of the line and environmental conditions.

[0143] ρ is the reference threshold of the early warning system, which is used to determine the basic level of the early warning level. This value is usually set according to the line safety design and risk management requirements, providing an initial reference standard for the early warning level value. In the formula, ρ plays a role in benchmarking the subsequent change items to ensure that the calculated early warning level meets the safety requirements of the line.

[0144] τ is the time scale coefficient. This coefficient controls the degree of influence of cumulative damage on the warning level. Generally, when the line bears wind load for a long time or experiences multiple high loads, the cumulative damage D will increase, resulting in an upward trend of W. By adjusting the value of τ, the weight of cumulative damage in the warning level calculation can be controlled, thereby affecting the change speed and amplitude of the warning level.

[0145] exp(-D) is the negative exponent of the cumulative damage index. As the cumulative damage D increases, the exponential value exp(-D) decreases, so 1 + τ·exp(-D) gradually approaches the reference value ρ, reflecting the gradual deterioration of the line safety condition. That is, when the cumulative damage increases, the warning level will gradually increase as the line damage increases.

[0146] δ is the daily variation coefficient. This coefficient is used to control the periodic fluctuation of the warning level with the daytime, so as to adapt to the change of wind load at different times of the day. By appropriately adjusting the value of δ, the influence of the difference in wind speed at different time periods on the warning level can be simulated.

[0147] is a daily periodic function. This item adopts the form of a cosine function with a period of 24 hours to reflect the variation law of daytime wind speed and wind load. For example, the wind speed is usually higher during the day and relatively lower at night. Incorporating the time period into the calculation can make the change of the warning level with time more in line with the actual environmental change situation.

[0148] The variation range of the item is between 1 - δ and 1 + δ, and it has a sine fluctuation with time t. In this way, the warning level can be higher during the day and lower at night, making the system more sensitive to the peak of daytime wind load, thereby improving the accuracy of the warning.

[0149] The present invention sets the basic warning level through the reference threshold, reflects the damage effect of long-term wind load through the cumulative damage index, and periodically adjusts the wind load characteristics in different time periods through the daily variation function and the time scale coefficient, so that the calculated warning level can comprehensively reflect the current safety state and potential risks of the line, thus facilitating the power grid system to take dynamic response measures.

[0150] Step 206, monitor the wind load data according to the magnitude of the warning level value.

[0151] In some embodiments, when 0 ≤ W < 0.3, it is determined that the wind load data is in a normal state; when 0.3 ≤ W < 0.6, it is determined that the wind load data is in a general warning state; when 0.6 ≤ W < 0.8, it is determined that the wind load data is in an important warning state; when W ≥ 0.8, it is determined that the wind load data is in a severe warning state, where W is the warning level value.

[0152] In some embodiments, the full-line wind load distribution map, the wind load time history curve at key points, the change trend of the cumulative damage index, and the warning level status of the transmission line are displayed in real time on the monitoring interface of the substation machine room.

[0153] This distribution map shows the wind load conditions at different positions on the entire transmission line, presenting the real-time wind load magnitudes borne by each monitoring unit (usually a line section divided at specific intervals) in a visual manner. The full-line wind load distribution map enables operation and maintenance personnel to intuitively see the load conditions in each area of the line, quickly identify areas with greater stress or abnormal sections. Through this distribution map, the system can timely locate the positions where wind loads are concentrated, which helps to conduct targeted inspections and maintenance, thus ensuring the safety of the line.

[0154] The wind load time history curve at key points is a graph showing the variation of wind load over time at specific positions (or multiple positions). This curve shows how the wind load at key positions fluctuates at different time points. The time history curve of wind load provides dynamic information on the change of wind load, helping operation and maintenance personnel analyze the fluctuation characteristics and trends of wind load over time. By observing these curves, the system can identify situations where the wind load changes violently in a short period, indicating possible sudden risks. The time history curve can also be used to judge the periodic change characteristics of wind load, thereby optimizing the operation strategy and maintenance plan of the line.

[0155] The change trend graph of the cumulative damage index shows the cumulative damage degree of the line under the long-term action of wind load. This index is obtained through a series of calculations, comprehensively considering factors such as the stress of the line material, temperature change, and vibration. The cumulative damage index is an important parameter reflecting the health status of the line. Its change trend graph shows the cumulative damage situation of the line during long-term operation, helping operation and maintenance personnel understand whether the line is within the safe operation range. If the damage index continues to rise and approaches the warning threshold, the system can issue a reminder in advance, prompting operation and maintenance personnel to take preventive measures, thereby extending the service life of the line and reducing the occurrence of potential failures.

[0156] The warning level status is a risk level generated based on real-time data and cumulative damage conditions, reflecting the current safety status of the line. The warning level is usually marked by colors, numbers, or words and is divided into multiple levels (such as low, medium, high) for easy identification. The warning level status provides the immediate safety level of the line through comprehensive analysis of real-time monitoring data. Through this grading system, operation and maintenance personnel can intuitively understand the real-time risk degree of the line, facilitating a quick response in a high-risk state. The warning level status helps to establish a rapid risk identification and response mechanism, improving the ability to respond to sudden wind load events.

[0157] Integrate and display the above information on the monitoring interface of the substation computer room, so that the operation and maintenance personnel can have a clear understanding of the wind load status, cumulative damage, and early warning status of the transmission line. This integrated monitoring method improves the comprehensiveness and real-time nature of monitoring, helps to promptly detect and respond to abnormal situations of the line, and ensures the safe and stable operation of the transmission line. At the same time, these visual information provides a scientific basis for maintenance decisions, improving the efficiency and reliability of operation management.

[0158] Please refer to Figure 3 , Figure 3 which is a schematic structural diagram of a transmission line conductor wind load monitoring system provided by the present invention.

[0159] As Figure 3 shown, a transmission line conductor wind load monitoring system proposed in an embodiment of the present invention includes:

[0160] A line division module 301, configured to set a Rayleigh scattering light signal demodulation device in the substation computer room, use the spare optical fiber in the optical fiber ground wire as a sensing medium, and divide the transmission line into multiple monitoring units;

[0161] A data acquisition module 302, configured to acquire vibration signals of each of the monitoring units according to the Rayleigh backscattering principle;

[0162] A first calculation module 303, configured to calculate wind load data of the conductors of the transmission line according to the vibration signals;

[0163] A second calculation module 304, configured to calculate a cumulative damage index of the conductors according to the wind load data;

[0164] A third calculation module 305, configured to determine a corresponding early warning level value according to the cumulative damage index of the conductors;

[0165] A data monitoring module 306, configured to monitor the wind load data according to the magnitude of the early warning level value.

[0166] Please refer to Figure 4 , Figure 4 which is a schematic diagram of an embodiment of an electronic device provided in an embodiment of the present invention. As Figure 4 shown, an electronic device 400 proposed in an embodiment of the present invention includes a memory 410, a processor 420, and a computer program 411 stored on the memory 410 and executable on the processor 420. When the processor 420 executes the computer program 411, the following steps are implemented:

[0167] Set a Rayleigh scattering light signal demodulation device in the substation computer room, use the spare optical fiber in the optical fiber ground wire as a sensing medium, and divide the transmission line into multiple monitoring units;

[0168] According to the Rayleigh backscattering principle, the vibration signals of each of the monitoring units are collected;

[0169] According to the vibration signals, the wind load data of the conductors of the transmission line are calculated;

[0170] According to the wind load data, the cumulative damage index of the conductors is calculated;

[0171] According to the cumulative damage index of the conductors, the corresponding early warning level value is determined;

[0172] According to the magnitude of the early warning level value, the wind load data are monitored.

[0173] It should be noted that in the above embodiments, the descriptions of the respective embodiments have their own emphases. For the parts not described in detail in a certain embodiment, reference may be made to the relevant descriptions of other embodiments.

[0174] Those skilled in the art should understand that the embodiments of the present invention may provide a method, a system, or a computer program product. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware aspects.

Claims

1. A method for monitoring wind load on a transmission line conductor, characterized in that: The method comprises: A Rayleigh scattered light signal demodulation device is installed in the substation room, and the spare optical fiber in the optical fiber ground wire is used as the sensing medium to divide the transmission line into multiple monitoring units; According to the Rayleigh backscattering principle, the vibration signal of each monitoring unit is collected, including: obtaining the spatial position, time, optical signal attenuation coefficient, optical fiber sensitivity coefficient, and strain component of the monitoring unit; obtaining the incident light power, vibration angular frequency, phase delay, and noise component of the incident light entering the monitoring unit; determining the vibration signal according to the correction coefficient of the strain component and the noise component, the spatial position, time, optical signal attenuation coefficient, optical fiber sensitivity coefficient, strain component of the monitoring unit, and the incident light power, vibration angular frequency, phase delay, and noise component of the incident light; and using the vibration signal as the optical fiber vibration response intensity, wherein the optical fiber vibration response intensity is expressed as: Among them, R(x,t) is the intensity of the optical fiber vibration response, x is the spatial position, t is the time, α is the optical fiber sensitivity coefficient, β is the optical signal attenuation coefficient, P(t) is the incident light power, ω is the vibration angular frequency, is the phase delay, ∈(x, t) is the strain component, η(x, t) is the noise component, and γ is the correction coefficient; Calculating the wind load data of the conductor of the transmission line according to the vibration signal includes: obtaining a spatial correction function of the spatial position of the monitoring unit and the optical fiber length of the monitoring unit; obtaining a mass coefficient, a damping coefficient and a stiffness coefficient for calculating the wind load data; processing the optical fiber vibration response intensity according to the spatial correction function of the spatial position of the monitoring unit and the optical fiber length, as well as the mass coefficient, the damping coefficient and the stiffness coefficient to obtain the wind load data of the conductor of the transmission line, wherein the wind load data of the conductor of the transmission line can be expressed as: Wherein, μ is the mass coefficient, θ(x) is the spatial correction function, λ is the damping coefficient, ξ is the stiffness coefficient, σ is the nonlinear correction coefficient, R is the optical fiber vibration response intensity, and L is the optical fiber length of the monitoring unit; Calculating the cumulative damage index of the conductor according to the wind load data includes: obtaining a material constant corresponding to the material of the conductor and a temperature influence coefficient of the influence of the ambient temperature on the accumulated damage of the conductor; obtaining the measured wind load collected by the monitoring unit in each time period and the critical wind load of the material of the conductor; obtaining the action time of the wind load on the conductor in each time period and a reference time of a preset standard; obtaining a weight coefficient representing the importance of each time period, and calculating the cumulative damage index of the conductor according to the weight coefficient, the action time, the reference time, the measured wind load, the critical wind load, the material constant and the temperature influence coefficient, wherein the cumulative damage index is expressed as: Where D is the cumulative damage index, ψ i is the weight coefficient, F i is the measured wind load in the ith period, F c is the critical wind load, m is the material constant, k is the temperature influence coefficient, T i is the duration of wind load action in the ith period, and T0 is the reference duration; Determining a corresponding warning level value according to the cumulative damage index of the conductor includes: obtaining a reference threshold value for evaluating the cumulative damage of the conductor; obtaining a time scale coefficient and a daily variation coefficient of the cumulative damage of the conductor; processing the reference threshold value according to the time scale coefficient, the daily variation coefficient and the cumulative damage index of the cumulative damage of the conductor to determine the warning level value, wherein the warning level value is expressed as: Among them, W is the warning level value, ρ is the benchmark threshold, τ is the time scale coefficient, δ is the daily variation coefficient, and D is the cumulative damage index; The wind load data is monitored according to the value of the warning level.

2. A method for monitoring wind load on a transmission line conductor according to claim 1, characterized in that: The monitoring of the wind load data according to the value of the warning level includes: When 0≤W<0.3, the wind load data is determined to be in a normal state; When 0.3≤W<0.6, the wind load data is determined to be in a general warning state; When 0.6≤W<0.8, the wind load data is determined to be in an important warning state; When W≥0.8, the wind load data is determined to be in a severe warning state; Wherein, W is the warning level value.

3. A method for monitoring wind load on a transmission line conductor according to claim 1 or 2, characterized in that: The method further comprises: The monitoring interface of the substation room displays in real time the wind load distribution diagram of the entire transmission line, the wind load time curve of key points, the cumulative damage index change trend and the warning level status.

4. A transmission line conductor wind load monitoring system, the system implementing the method according to claim 1, characterized in that: The system comprises: The line division module is used to set up Rayleigh scattered light signal demodulation equipment in the substation room, use the spare optical fiber in the optical fiber ground wire as the sensing medium, and divide the transmission line into multiple monitoring units; A data acquisition module, used for collecting the vibration signal of each monitoring unit according to the Rayleigh backscattering principle; A first calculation module, used to calculate wind load data of the conductor of the transmission line according to the vibration signal; A second calculation module, used to calculate the cumulative damage index of the conductor according to the wind load data; A third calculation module, used to determine a corresponding warning level value according to the cumulative damage index of the wire; The data monitoring module is used to monitor the wind load data according to the value of the warning level.

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