Power transmission line space state detection method and system based on electric field sensing

Abstract

The invention relates to the technical field of power transmission line state monitoring, and particularly provides a power transmission line space state detection method and system based on electric field sensing, and the method comprises the steps: carrying out the calculation of a real-time position coefficient based on an induction voltage collected by an electric field sensor in real time through a voltage space parameter model and a target voltage, the target voltage is calculated through a voltage space parameter model according to an initial position coefficient of the wire and an initial induced voltage obtained by the electric field sensor, and a real-time first position coordinate of the wire is calculated according to a real-time position coefficient; the real-time first position coordinates and the initial first position coordinates are compared and analyzed, the space state of the wire is obtained, the space state is represented by a plurality of state parameters, and the state parameters comprise the sag change value, the windage yaw amplitude, the windage yaw angle and the galloping amplitude, so that the problem that in a space state detection mode in the related technology, the detection accuracy is poor is solved. The method solves the problems that the prior art needs to depend on special detection equipment, is high in system complexity, cannot synchronously detect the space state, and is poor in detection timeliness.

Description

Technical Field

[0001] This invention relates to the field of power transmission line condition monitoring technology, and in particular to a method and system for detecting the spatial condition of power transmission lines based on electric field sensing. Background Technology

[0002] Overhead transmission lines are prone to spatial anomalies such as sag changes, wind deflection, and galloping under complex geographical and meteorological conditions. These anomalies can potentially lead to accidents such as short circuits and insulation breakdowns, posing a serious threat to the safe and stable operation of the power grid. Therefore, real-time and accurate monitoring of the spatial condition of conductors is a crucial foundation for line condition assessment and fault early warning.

[0003] In related technologies, conductor spatial condition detection mainly relies on independent dedicated monitoring equipment such as image acquisition devices, tilt sensors, laser rangefinders, or distributed optical fibers. These methods generally suffer from drawbacks such as complex system structure, difficult installation and maintenance, and high cost. Moreover, they are mostly contact-based or short-range measurements, which are susceptible to interference from harsh environments, making it difficult to meet the needs of wide-area deployment and real-time online monitoring.

[0004] The spatial state detection methods in related technologies rely on dedicated detection equipment, resulting in high system complexity and poor detection timeliness due to the inability to detect spatial state synchronously. Currently, no effective solution has been proposed. Summary of the Invention

[0005] The electric field sensing-based method and system for detecting the spatial state of transmission lines provided by the present invention at least solves the problems of related technologies, which require dedicated detection equipment, have high system complexity, and cannot detect the spatial state synchronously, resulting in poor detection timeliness.

[0006] According to one aspect of the present invention, a method for detecting the spatial state of a transmission line based on electric field sensing is provided, comprising: calculating a real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, using a voltage space parameter model and a target voltage, wherein the target voltage is calculated using the voltage space parameter model based on the initial position coefficient of the conductor and the initial induced voltage obtained by the electric field sensor, the voltage space parameter model being used to characterize the calculation relationship between the position coefficient, the induced voltage, and the target voltage; calculating a real-time first position coordinate of the conductor based on the real-time position coefficient using a position coefficient formula and a spatial distance formula; comparing and analyzing the real-time first position coordinate with the initial first position coordinate of the conductor to obtain the spatial state of the conductor, wherein the spatial state is characterized by multiple state parameters, including sag variation value, wind deflection amplitude, wind deflection angle, and galloping amplitude.

[0007] As an optional approach, before calculating the real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, using a voltage space parameter model and a target voltage, the method further includes: obtaining the initial first position coordinates of the conductor and the second position coordinates of the electric field sensor when the conductor is in its initial position; calculating the initial distance parameter of the conductor in its initial position using a spatial distance formula based on the initial first position coordinates and the second position coordinates; obtaining the initial position coefficient based on the initial distance parameter and the position coefficient formula; and calculating the target voltage using the voltage space parameter model based on the initial position coefficient and the initial induced voltage collected by the electric field sensor, wherein the initial induced voltage is the induced voltage collected when the conductor is in its initial position.

[0008] As an optional approach, the initial distance parameters of the conductor at its initial position are calculated using a spatial distance formula based on the initial first position coordinates and the second position coordinates. This includes: obtaining the initial third position coordinates of the mirror source corresponding to the conductor using the mirror method based on the initial first position coordinates, wherein the mirror source is a point symmetrical to the conductor about the ground; and calculating the initial distance parameters using the spatial distance formula based on the initial first position coordinates, the second position coordinates, and the initial third position coordinates, wherein the distance parameters include the distance between conductors, the distance between the conductor and the mirror source, the distance between the conductor and the electric field sensor, and the distance between the mirror source and the electric field sensor.

[0009] As an optional approach, the initial position coefficients include an initial first position coefficient and an initial second position coefficient, and the position coefficient formulas include a first coefficient formula and a second coefficient formula. Before obtaining the initial position coefficients based on the initial distance parameter and the position coefficient formulas, the method further includes: constructing the first coefficient formula and the second coefficient formula based on Maxwell's equations and the method of images, wherein the calculation formula for the first coefficient formula is as follows:

[0010] ;

[0011] In the formula, U j Let J be the target voltage of the j-th phase conductor; H is the vacuum permittivity; jj’ D is the distance from the j-th phase conductor to the j'-th phase mirror source; jj’ R is the distance from the j-th phase conductor to the j'-th phase conductor; R is the conductor radius. P represents the linear charge density of the i-th phase conductor; jj’ It is the first position coefficient defining the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; j=1,2,3; j'=1,2,3;

[0012] The formula for calculating the second coefficient is as follows:

[0013] ;

[0014] In the formula, d represents the induced voltage obtained by the i-th electric field sensor; ij s is the distance from the i-th electric field sensor to the j-th phase conductor; ij P is the distance from the i-th electric field sensor to the j-th phase mirror charge source; eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor, i=1,2,3; j=1,2,3.

[0015] As an optional approach, before calculating the target voltage based on the initial position coefficient and the initial induced voltage obtained by the electric field sensor using the voltage space parameter model, the method further includes: constructing a voltage space parameter model based on the first coefficient formula and the second coefficient formula; the voltage space parameter model is as follows:

[0016] ;

[0017] In the formula, U j P represents the target voltage of the j-th phase conductor. jj’ It is the first position coefficient of the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; P eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor; The induced voltage is the result of processing by the i-th electric field sensor.

[0018] As an optional approach, the real-time first position coordinates and the initial first position coordinates are compared and analyzed to obtain the spatial state of the conductor. The spatial state is characterized by multiple state parameters, including sag change, wind deflection amplitude, wind deflection angle, and galloping amplitude. This includes: calculating the sag change based on the real-time and initial first position coordinates using a catenary model; calculating the wind deflection angle and amplitude based on the real-time and initial first position coordinates; calculating the galloping amplitude within a preset time using the standing wave equation of the conductor's spatial position and the initial first position coordinates; and determining that galloping has occurred if the galloping amplitude exceeds a set threshold within the preset time.

[0019] As an optional approach, before calculating the galloping amplitude within a preset time using the standing wave equation of the conductor's spatial position and the initial first position coordinates, the method further includes: constructing a spatial position expression for the conductor using the standing wave equation based on the conductor's galloping frequency, the conductor's initial galloping phase, and the conductor's galloping order, wherein the spatial position expression is as follows:

[0020] ; ;

[0021] In the formula, X g Represents the spatial position coordinates along the x-axis; Y g Indicates the spatial position coordinates along the Y-axis; a x,y This indicates the amplitude of the conductor's galloping in the horizontal and vertical directions; f x,y φ represents the frequency of the conductor's galloping in the horizontal and vertical directions. x,y This indicates the initial phase of the conductor's galloping in the horizontal and vertical directions; n x,y Indicates the galloping order of the conductor in the horizontal and vertical directions; L represents the half-span of the transmission line; X wind Indicates the wind deflection amplitude of the conductor; Y sag This represents the change in sag of the conductor.

[0022] As an optional approach, before constructing the spatial position expression of the conductor using the standing wave equation based on the conductor's galloping frequency, initial galloping phase, and galloping order, the method further includes: performing a fast Fourier transform on the ratio of induced voltages collected by different electric field sensors to obtain a frequency domain signal; taking the maximum peak point in the spectrum of the frequency domain signal as the galloping frequency; obtaining the initial galloping phase based on the phase angle of the point corresponding to the galloping frequency; and calculating and rounding the ratio of the galloping frequency to the theoretical fundamental frequency of the conductor to obtain the galloping order.

[0023] As an optional approach, the galloping amplitude within a preset time period is calculated using the standing wave equation of the conductor's spatial position and the initial first position coordinates. This includes calculating the instantaneous offset distance of the conductor based on the spatial position and the initial first position coordinates, using the following formula: In the formula, X represents the instantaneous offset distance of the conductor at time t; g Represents the spatial position coordinates along the x-axis; Y g X1 and Y1 represent the spatial position coordinates along the Y-axis; X1 and Y1 represent the initial first position coordinates of the conductor; based on the maximum instantaneous offset distance of the conductor within a preset time, the dancing amplitude is calculated using the following formula: In the formula, A is the amplitude of the dancing motion; R is the radius of the conductor.

[0024] According to another aspect of the present invention, a transmission line spatial state detection system based on electric field sensing is also provided, comprising: an electric field sensor, including a sensing module, a differential amplifier, and an analog-to-digital converter; wherein, the electric field sensor is configured with three or more; the sensing module is used to sense the voltage signal generated by the radiated electric field of the conductor; the differential amplifier receives the voltage signal, performs differential calculation and amplification processing on the voltage signal through the differential amplifier; the analog-to-digital converter converts the processed voltage signal into an induced voltage; a first calculation module, based on the induced voltage collected in real time by the electric field sensor, calculates a real-time position coefficient through a voltage space parameter model and a target voltage, wherein the target voltage... The voltage is calculated based on the initial position coefficient of the conductor and the initial induced voltage obtained by the electric field sensor, using the voltage space parameter model. The voltage space parameter model is used to characterize the calculation relationship between the position coefficient, the induced voltage, and the target voltage. The second calculation module is used to calculate the real-time first position coordinates of the conductor based on the real-time position coefficient, using the position coefficient formula and the spatial distance formula. The comparison and analysis module is used to compare and analyze the real-time first position coordinates and the initial first position coordinates to obtain the spatial state of the conductor. The spatial state is characterized by multiple state parameters, including sag change value, wind deflection amplitude, wind deflection angle, and galloping amplitude.

[0025] As an optional solution, the electric field sensor is a dual-probe electric field sensor, comprising: the dual-probe electric field sensor is installed on the transmission line tower of the conductor, and the dual-probe electric field sensor is arranged in a ring around the conductor for non-contact measurement of the induced voltage of the conductor; the dual-probe electric field sensor consists of two independent metal probes arranged based on the principle of capacitive coupling.

[0026] According to another aspect of the present invention, an electronic device is also provided, comprising: a processor, and a memory storing a program, characterized in that the program includes instructions that, when executed by the processor, cause the processor to perform the method according to any one of the preceding claims.

[0027] The present invention provides a method and system for detecting the spatial state of transmission lines based on electric field sensing. This method utilizes a conveniently installed electric field sensor to collect induced voltage in real time, constructing a voltage spatial parameter model representing the calculated relationship between the position coefficient, induced voltage, and target voltage. First, a fixed target voltage is calculated using the initial position coefficient and initial induced voltage of the conductor, avoiding redundant coupling solutions between voltage and spatial parameters. Then, the real-time position coefficient is calculated synchronously based on the real-time induced voltage and the model. Subsequently, the real-time first position coordinates of the conductor are further calculated from the real-time position coefficient using the position coefficient formula and the spatial distance formula. Finally, through comparative analysis of the real-time coordinates and the initial coordinates, multiple state parameters representing the spatial state of the conductor, such as sag change, wind deflection amplitude, wind deflection angle, and galloping amplitude, are output. This simplifies the spatial state detection logic and reduces redundant calculations, thus solving the problems of related technologies where spatial state detection methods rely on dedicated detection equipment, have high system complexity, and cannot synchronously detect spatial states, resulting in poor detection timeliness. This method achieves the technical effect of simple structure and timely conductor spatial state detection. Attached Figure Description

[0028] To more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the accompanying drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are merely some embodiments of the present invention, and those skilled in the art can obtain other embodiments based on these drawings without creative effort.

[0029] Figure 1 This is a flowchart of a method for detecting the spatial state of transmission lines based on electric field sensing, according to an embodiment of the present invention.

[0030] Figure 2 This is a schematic diagram of the distribution of electric field sensors on a pole according to an embodiment of the present invention.

[0031] Figure 3 This is a schematic diagram of a conductor sag on a tower according to an embodiment of the present invention.

[0032] Figure 4 This is a schematic diagram of the angle of wind deflection of the conductor according to an embodiment of the present invention.

[0033] Figure 5 This is a schematic diagram of the conductor dancing on the tower according to an embodiment of the present invention.

[0034] Figure 6 This is a schematic diagram of the distance between the conductor and the mirror source in an embodiment of the present invention.

[0035] Figure 7This is a schematic diagram showing the distance between the wire, the mirror source, and the voltage sensor in an embodiment of the present invention.

[0036] Figure 8 This is a schematic diagram showing the symmetry between the conductor and the mirror source about the ground in an embodiment of the present invention.

[0037] Figure 9 This is a schematic diagram of the structure of the electronic device created by this invention. Detailed Implementation

[0038] Embodiments of the present invention will now be described in more detail with reference to the accompanying drawings. While some embodiments of the present invention are shown in the drawings, it should be understood that the present invention can be implemented in various forms and should not be construed as limited to the embodiments set forth herein. Rather, these embodiments are provided to provide a more thorough and complete understanding of the present invention. It should be understood that the drawings and embodiments of the present invention are for illustrative purposes only and are not intended to limit the scope of protection of the present invention.

[0039] In related technologies, the spatial state of conductors is measured by tension sensors to measure sag changes, by inclinometers to measure wind deflection angles, and by vibration sensors to measure galloping amplitudes. Each sensor needs to be in direct contact with the conductor to collect the corresponding spatial state parameters. This approach has drawbacks such as large size, complex insulation structure, difficult installation and maintenance, and high cost. Furthermore, the need for direct contact with the conductor can easily interfere with the normal operation of the line.

[0040] To address the issues of reliance on dedicated detection equipment, high system complexity, and poor timeliness in spatial state detection methods in related technologies, this invention provides a method for detecting the spatial state of transmission lines based on electric field sensing. Figure 1 As shown, it includes:

[0041] Step S101: Based on the induced voltage collected in real time by the electric field sensor, the real-time position coefficient is calculated through the voltage space parameter model and the target voltage. The target voltage is calculated based on the initial position coefficient of the conductor and the initial induced voltage obtained by the electric field sensor through the voltage space parameter model. The voltage space parameter model is used to characterize the calculation relationship between the position coefficient, the induced voltage and the target voltage.

[0042] Step S102: Based on the real-time position coefficient, the real-time first position coordinates of the conductor are calculated using the position coefficient formula and the spatial distance formula.

[0043] Step S103: Compare and analyze the real-time first position coordinates and the initial first position coordinates to obtain the spatial state of the conductor. The spatial state is characterized by multiple state parameters, including sag change value, wind deflection amplitude, wind deflection angle and galloping amplitude.

[0044] The execution entity for the above steps can be the control device of the transmission line spatial state detection system. This control device includes a data processing module, a first calculation module, a second calculation module, and a comparison and analysis module. The electric field sensor and data processing module within the transmission line spatial state detection system complete the acquisition and preprocessing of real-time induced voltage. Based on the voltage spatial parameter model within the first calculation module, the real-time position coefficient is calculated. The real-time first position coordinates are calculated using the coefficient formula and spatial distance formula within the second calculation module. The comparison and analysis module uses the catenary model, standing wave equation, and other calculation formulas to compare and analyze the real-time first position coordinates with the initial first position coordinates to obtain the spatial state parameters of the conductor. This allows for precise online sensing of the conductor's spatial state solely through the acquisition of induced voltage.

[0045] Contact measurement involves direct sensing at a point, while non-contact measurement involves indirect sensing of a field. This embodiment uses an electric field sensor to collect induced voltage, eliminating the need to install multiple sensors on the conductor to collect various data points. This avoids interference with the original conductor structure, reduces installation and maintenance costs, and does not affect the normal operation of the line. Furthermore, the induced voltage is sensitive to minute displacements and vibrations of the conductor. Without the need for complex equipment to collect multiple data points, real-time spatial status can be obtained simply by analyzing the induced voltage collected by the voltage sensor using algorithms.

[0046] The real-time position coefficient is used to connect the induced voltage with the spatial position of the conductor. Changes in the spatial position of the conductor will alter its relative distance to the electric field sensor and the ground mirror source, thereby affecting the electric field distribution and the induced voltage of the electric field sensor. Therefore, by calculating the position coefficient through the real-time induced voltage, the real-time first position coordinates of the conductor can be indirectly obtained.

[0047] The target voltage serves as the voltage reference for the conductor during normal operation. The target voltage is set based on the conductor's initial state parameters to ensure the accuracy of real-time calculations. The initial state of the conductor is defined as when it is in a stable initial position without abnormal sag, wind deflection, or galloping. The initial first position coordinates of the conductor and the second position coordinates of the electric field sensor are obtained. These initial first and second position coordinates can be measured and calibrated during sensor installation.

[0048] The electric field sensor's sensing module continuously acquires the voltage signal of the radiated electric field from the conductor online. After differential amplification and analog-to-digital conversion, an analog voltage signal is obtained. This analog voltage signal is then converted into a calculable digital signal to obtain the real-time induced voltage. The real-time induced voltage and the calibrated target voltage are substituted into a voltage space parameter model to solve for the real-time position coefficient. This calculation process, based on a pre-defined mathematical model, requires no complex iterations, has high computational efficiency, and further ensures the real-time nature of the monitoring.

[0049] The real-time first position coordinates are the direct basis for judging the spatial state of the conductor. The sag change, wind deflection amplitude, wind deflection angle, and galloping amplitude are all changes in the real-time first position coordinates. Step S102 obtains the real-time first position coordinates of the conductor by analyzing the relationship between the real-time position coefficient and the spatial distance and coordinates, realizing the conversion from the real-time position coefficient to the real-time first position coordinates, and providing a data foundation for subsequent calculation of conductor spatial state parameters.

[0050] The real-time position coefficient is a function of the relative distance between the conductor and the sensor, the mirror source, and other conductors. The relative distance can be calculated from the real-time first position coordinates of the conductor, the second position coordinates of the sensor, and the real-time third position coordinates of the mirror source.

[0051] Substituting the real-time first and second position coordinates into the spatial distance formula yields the real-time distance parameter. Substituting this parameter into the position coefficient formula and combining it with the real-time position coefficient, the real-time three-dimensional coordinates of the conductor are obtained through numerical calculation. The equation system solution process is simple, computationally inexpensive, and meets the requirements for online real-time monitoring. Compared to visual monitoring methods, this embodiment uses electric field signals to invert the real-time first position coordinates, exhibiting strong anti-interference capabilities and a wider range of applicable scenarios.

[0052] This embodiment compares the real-time first position coordinates of the conductor with the initial first position coordinates, and combines the physical characteristic models of sag, wind deflection, and galloping to quantify and calculate the corresponding state parameters, enabling accurate determination of the conductor's spatial state. Based on the parameter quantification of the physical model and the state determination using thresholds, the real-time first position coordinate changes are transformed into state information that can be directly used for fault early warning, solving the problems of subjective and incomplete state determination in traditional monitoring.

[0053] like Figure 2 , Figure 3 As shown, the direction perpendicular to the ground is the y-axis, the direction parallel to the connection line between the two towers of the overhead transmission line is the z-axis, and the direction perpendicular to the z-axis and y-axis is the x-axis.

[0054] The sag change value is the offset of the conductor along the y-axis under the action of gravity. The catenary model can accurately describe the relationship between the conductor sag and the real-time first position coordinates. The sag change value can be used to determine whether the conductor has excessive sag due to factors such as temperature rise and icing, so as to avoid ground discharge accidents.

[0055] like Figure 4 As shown, wind deflection is the change in the coordinates of a conductor in the xy-plane under the influence of horizontal wind force. Wind deflection includes the magnitude and angle of wind deflection. The magnitude of wind deflection directly reflects the horizontal offset; the angle of wind deflection characterizes the degree of tilt caused by wind deflection. When the magnitude or angle of wind deflection exceeds a preset threshold, it can provide an early warning of a potential phase-to-phase short circuit in the conductor, providing a basis for decision-making in line operation and maintenance.

[0056] like Figure 5 As shown, conductor galloping is a low-frequency, high-amplitude vibration generated by icy conductors under wind load. The amplitude of the galloping directly determines the electrical safety distance between conductors and between conductors and ground objects. Accurately determining the galloping amplitude can provide real-time early warning of serious accidents such as phase-to-phase short circuits, ground discharges, and tripping. The galloping amplitude can be calculated by using the real-time first position coordinates of the conductors and the offset distance of the initial first position coordinates within a preset time, and the presence of risk can be determined based on the galloping amplitude.

[0057] This embodiment eliminates the need for additional sag monitors, wind deflection sensors, and galloping monitoring devices. All state parameters can be calculated using induced voltage, thus solving the problems of complexity and equipment redundancy in traditional monitoring methods. Furthermore, the calculation of all state parameters is based on objective physical laws and quantitative formulas, with clear judgment criteria, avoiding errors from subjective judgment. Online real-time analysis ensures timely state response, providing accurate and efficient technical support for transmission line fault early warning.

[0058] In summary, the electric field sensing-based spatial state detection method for transmission lines provided in this embodiment acquires induced voltage in real time by installing a convenient electric field sensor, and constructs a voltage spatial parameter model that characterizes the calculation relationship between the position coefficient, induced voltage, and target voltage. A fixed target voltage is calculated using the initial position coefficient of the conductor and the initial induced voltage, thus avoiding the repeated coupling and solution of voltage and spatial parameters.

[0059] The real-time position coefficient is calculated synchronously based on the real-time induced voltage and the model. Then, according to the position coefficient formula and the spatial distance formula, the real-time first position coordinates of the conductor are further calculated from the real-time position coefficient. Finally, by comparing and analyzing the real-time coordinates with the initial coordinates, multiple state parameters characterizing the conductor's spatial state, such as sag change, wind deflection amplitude, wind deflection angle, and galloping amplitude, are output. This simplifies the method of detecting the spatial state and reduces redundant calculations, thus solving the problems of complex and insufficient real-time performance in conductor spatial state monitoring methods in related technologies, achieving a simple structure and fast response speed.

[0060] As an optional approach, before calculating the real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, using a voltage space parameter model and the target voltage, the method further includes: obtaining the initial first position coordinates of the conductor and the second position coordinates of the electric field sensor when the conductor is in its initial position; calculating the initial distance parameter of the conductor when it is in its initial position using a spatial distance formula based on the initial first and second position coordinates; obtaining the initial position coefficient based on the initial distance parameter and the position coefficient formula; and calculating the target voltage using a voltage space parameter model based on the initial position coefficient and the initial induced voltage collected by the electric field sensor, wherein the initial induced voltage is the induced voltage collected when the conductor is in its initial position.

[0061] When the conductor is in an initial stable operating state without abnormal sag, wind deflection, or galloping, high-precision positioning equipment such as laser rangefinders and UAV 3D mapping are used to collect the initial first position coordinates (X) of key measuring points of the three-phase conductor. j0 ,Y j0 Z j0 (j0=1,2,3), where j0 corresponds to the three-phase conductors respectively. Key measuring points need to cover areas sensitive to spatial changes, such as the midpoint of the conductor span, tower connections, and the lowest point of sag, to ensure that the initial coordinates can fully reflect the initial spatial morphology of the conductor. Multi-point acquisition can avoid reference distortion caused by deviations from a single measuring point.

[0062] During installation, the electric field sensors measure and mark the second position coordinates for subsequent calculations. After installation, the second position coordinates (x, y, z) of each sensor are recorded by measuring at a fixed position. i ,y i ,z i (i=1,2,...,N), where i corresponds to N electric field sensors. Since the sensor positions are fixed after installation, this coordinate only needs to be collected and calibrated once after installation. Subsequent real-time monitoring does not require repeated measurements, significantly reducing maintenance costs and achieving a simple, convenient, and practical technical effect.

[0063] The initial distance parameter is calculated based on spatial geometric relationships to ensure that the coordinate information of the conductor can be transformed into distance characteristics that can be used to calculate the induced voltage. The spatial distance formula is a standard mathematical model for the distance between two points in three-dimensional space. Since the conductor remains essentially constant along the z-axis, the spatial distance does not need to be calculated with respect to z.

[0064] The derivation of the position coefficient formula strictly follows Maxwell's equations combined with the method of images to handle the influence of induced charges on the ground, ultimately forming an expression for the position coefficient formula, ensuring theoretical rigor and engineering computability. Substituting the initial distance parameters into the corresponding position coefficient formula, the initial position coefficient is obtained through numerical calculation.

[0065] With the conductor maintaining its initial stable position, the electric field sensor is activated to continuously collect the initial induced voltage generated on the sensor by the radiated electric field of the conductor. The collection time can ensure coverage of the instantaneous fluctuation period of the environmental electric field.

[0066] Substituting the initial induced voltage and initial position coefficient into the voltage space parameter model, and solving the system of equations using matrix inversion and matrix multiplication, the target voltage of the three-phase conductors is obtained. Once calibrated, the target voltage remains fixed during subsequent real-time monitoring, serving as a reference for retrieving the real-time position coefficient.

[0067] After installation, the electric field sensor only requires one reference calibration, and no repeated operation is needed during subsequent real-time monitoring. This avoids the cumbersome process of frequent calibration in traditional monitoring technologies, significantly reducing maintenance workload and costs. The calculation of position parameters is based on fundamental theories such as spatial geometry, Maxwell's equations, and the method of images, systematically eliminating sources of deviation such as installation errors, environmental noise, and calculation errors in contact-type detection equipment, providing a high-precision reference for subsequent real-time monitoring.

[0068] No additional dedicated monitoring equipment for sag, wind deflection, or galloping is required; multi-state integrated monitoring can be achieved using a single electric field sensing system. The sensor employs a non-contact installation method, eliminating direct contact with the conductor, making installation and maintenance convenient, and the device structure simple. The target voltage serves as a fixed reference parameter; subsequent real-time calculations only require inverting changes based on this reference, eliminating the need for repeated complex reference calculations. This significantly simplifies the real-time computation process and enables dynamic tracking of instantaneous spatial state changes in the conductor. This solves the problems of complexity and insufficient real-time performance in conductor spatial state monitoring methods in related technologies.

[0069] As an optional approach, the initial distance parameters of the conductor at its initial position are calculated using a spatial distance formula based on the initial first and second position coordinates. This includes: obtaining the initial third position coordinates of the mirror source corresponding to the conductor using the mirror method based on the initial first position coordinates, where the mirror source is the symmetrical point of the conductor about the ground; and calculating the initial distance parameters using the spatial distance formula based on the initial first, second, and initial third position coordinates. These distance parameters include the distance between conductors, the distance between the conductor and the mirror source, the distance between the conductor and the electric field sensor, and the distance between the mirror source and the electric field sensor.

[0070] Since the electric field distribution around the conductor is affected by its own position, interference from other conductors, and induced charges on the ground, using a mirror source to equivalently replace the influence of induced charges on the electric field around the conductor can avoid the calculation deviation of the electric field distribution caused by ignoring induced charges, making the subsequent correlation model between induced voltage and position coordinates more accurate. Therefore, the initial distance parameter for calculating the initial position coefficient is used to characterize the spatial positional relationship between the conductor, the electric field sensor, and the mirror source.

[0071] The earth can be considered an ideal conducting plane. According to the basic principle of the method of images, the induced charge generated by an overhead conductor in the earth can be equivalent to a mirror image source that is symmetrical to the conductor with respect to the ground. That is, the spatial position of the mirror image source is mirror-symmetrical to the conductor with respect to the ground, and the charge properties of the mirror image source are opposite to those of the conductor. The electric field distribution of the mirror image source is completely equivalent to the electric field generated by the induced charge in the earth. By treating it as a mirror image source, the calculation of the electric field can be simplified, while ensuring that the calculation results conform to the electric field distribution law described by Maxwell's equations.

[0072] The initial first position coordinates of the conductor are (X... j0 ,Y j0 Z j0 Since the mirror source and the conductor are symmetrical about the ground, the initial third position coordinates of the mirror source are (X... j0 ,-Y j0 Z j0 ).

[0073] Calculating the distances between conductors, between a conductor and its mirror source, between a conductor and an electric field sensor, and between a mirror source and an electric field sensor using spatial distance formulas provides comprehensive and accurate input data for subsequent position coefficient calculations based on electromagnetic theory. The initial first position coordinates of the j-th phase conductor are (X... j0 ,Y j0 Z j0 The second position coordinate is (x i ,y i ,z i The initial third position coordinates of the mirror source are (X... j'0 ,Y j'0 Zj'0 Calculate the initial distance parameters.

[0074] like Figure 6 As shown, the initial distance D between the conductors jj’0 Let be the initial distance between the key measuring points of the j-th phase conductor and the j'-th phase conductor (j'=1,2,3, j≠j'). The initial distance between the conductors is used to characterize the mutual electromagnetic coupling effect between the three phase conductors. Since the conductors remain basically unchanged along the z-axis, the expression for the initial distance between the first phase conductor and the second phase conductor can be: .

[0075] Initial distance d between the wire and the sensor ij0 Let be the initial distance between the i-th sensor and the key measuring point of the j-th phase conductor. The initial distance between the conductor and the voltage sensor directly determines the strength of the induced voltage; the closer the distance, the stronger the induced voltage. The expression for the initial distance between the conductor and the voltage sensor is: .

[0076] Initial distance H between the wire and the mirror source jj’0 Let be the initial distance between the key measuring points of the mirror source of the j-th phase conductor and the j'-th phase conductor. This initial distance is used to correct for the influence of induced ground charge on the conductor-to-ground voltage, ensuring the accuracy of the conductor voltage calculation. The expression for the initial distance between the conductor and the mirror source is: .

[0077] Initial distance s between mirror source and sensor ij0 Let be the initial distance between the i-th sensor and the key measuring point of the mirror source of the j-th phase conductor. The initial distance between the mirror source and the sensor is used to quantify the influence of the electric field of the mirror source on the induced voltage of the sensor, avoiding the calculation deviation of the induced voltage caused by ignoring the electric field of the mirror source; the expression for the initial distance between the mirror source and the sensor is: .

[0078] This embodiment completes the spatial location information through the mirror method and accurately quantifies the initial distance parameters using the spatial distance formula, providing a data foundation for setting the target voltage reference in the spatial state monitoring method of the conductor. At the same time, the electric field sensor is installed non-contactly, and with the accurate distance parameter calculation of this embodiment, there is no need for complex mechanical structures to be debugged on site, making installation and maintenance convenient and the device structure simple.

[0079] As an optional approach, the initial position coefficients include initial first position coefficients and initial second position coefficients. The position coefficient formulas include first coefficient formulas and second coefficient formulas. Before obtaining the initial position coefficients based on the initial distance parameters and position coefficient formulas, the method further includes: constructing first coefficient formulas and second coefficient formulas based on Maxwell's equations and the method of images. The calculation formula for the first coefficient formula is as follows:

[0080] ;

[0081] In the formula, U j Let J be the target voltage of the j-th phase conductor; H is the vacuum permittivity; jj’ D is the distance from the j-th phase conductor to the j'-th phase mirror source; jj’ Let R be the distance from the j-th phase conductor to the j'-th phase conductor, where the j'-th phase conductor is a conductor symmetrical about the ground to the mirror image source of the j'-th phase; R is the conductor radius. P represents the linear charge density of the i-th phase conductor; jj’ It is the first position coefficient of the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; j=1,2,3; j'=1,2,3.

[0082] The formula for calculating the second coefficient is as follows:

[0083] ;

[0084] In the formula, d represents the induced voltage obtained by the i-th electric field sensor; ij s is the distance from the i-th electric field sensor to the j-th phase conductor; ij P is the distance from the i-th electric field sensor to the j-th phase mirror charge source; eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor, i=1,2,3; j=1,2,3.

[0085] Maxwell's equations are the fundamental physical laws describing the interaction between electric and magnetic fields and electric charges and currents. The equation describing the electric field is: ,in, This represents the divergence of a vector field, where E is the electric field intensity. For charge density, Let be the vacuum permittivity. Based on this theorem, the quantitative relationship between the voltage at a point in space and the charge density and spatial distance can be derived through integration. The equation describing the electric field corresponds to the integral form as follows: Where S refers to any closed surface enclosing the charge. It represents the total amount of free charge enclosed by the closed surface S.

[0086] An overhead power transmission line can be considered as being enclosed within a closed, infinitely long cylinder, with its radiated electric field distribution being a quasi-electrostatic field. We can take a closed cylinder of length 1 and radius R as the Gaussian surface enclosing the conductor, and by integrating over the Gaussian surface, we obtain: , where ρ is the linear charge density of the conductor and R is the radius of the conductor.

[0087] Viewed from the center of the conductor along its direction, the electric field lines are distributed in a centrally divergent pattern. Therefore, the potential difference between two points in space can be expressed as: , where r1 and r2 are the two distances from which the electric field propagates.

[0088] Specifically, in a single-wire scenario, such as Figure 8 As shown, the ground is not ideally zero-charged; it contains induced charges on overhead conductors. In practical calculations, the induced charges on the ground need to be handled using the method of images in electromagnetism. The actual spatial electric field distribution is generated by the combined effect of the actual charge source and the image charge source.

[0089] In a single-conductor scenario, the potential at a point in space is calculated using the image method as follows: Where d1 is the distance between a point in space and the mirror source, and d2 is the distance between a point in space and the actual charge source, i.e., the wire detection point.

[0090] Furthermore, in the three-phase conductor scenario, for the sake of simplicity, only three electric field sensors are considered, such as... Figure 6 As shown, the conductor voltage can be expressed similarly using the method of images. Specifically, in the three-phase conductor scenario, the theoretical conductor voltage can be expressed as: From this formula, we can derive the expression for the first location coefficient characterizing the voltage correlation between the conductor and ground as follows: .

[0091] Furthermore, in the three-phase conductor scenario, for the sake of simplicity, only three electric field sensors are considered, such as... Figure 7 As shown, the induced voltage can be expressed similarly using the method of images. Specifically, in a three-phase conductor scenario, the induced voltages of the three sensors can be expressed as: From this equation, we can derive the expression for the second position coefficient, which characterizes the correlation of the sensor's induced voltage: .

[0092] The first and second coefficient formulas are used to quantify the relationship between spatial distance parameters and position coefficients. Both are derived based on Maxwell's equations and the method of images, without introducing subjective assumptions or simplifications. This ensures that the formulas accurately reflect the intrinsic relationship between electric field distribution and distance, voltage, and induced voltage, avoiding systematic errors caused by empirical formulas in related technologies.

[0093] In summary, the position coefficient formula developed in this step allows for the construction of a voltage-position correlation model solely through an electric field sensing system, eliminating the need for additional dedicated monitoring equipment for sag, wind deflection, and galloping, thus achieving integrated monitoring across multiple states. The non-contact sensor installation, combined with the precise calculations of the formula, eliminates the need for complex on-site debugging of mechanical structures or calibration procedures, making installation and maintenance convenient. The device has a simple structure, and its hardware costs are significantly reduced compared to contact-based monitoring equipment.

[0094] As an optional approach, before calculating the target voltage based on the initial position coefficient and the initial induced voltage obtained from the electric field sensor using a voltage space parameter model, the following steps are also included: constructing a voltage space parameter model based on the first coefficient formula and the second coefficient formula; the voltage space parameter model is as follows:

[0095] ;

[0096] In the formula, U j P represents the target voltage of the j-th phase conductor. jj’ It is the first position coefficient of the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; P eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor; The induced voltage is the result of processing by the i-th electric field sensor.

[0097] The voltage space parameter model establishes a direct quantitative correlation between the target voltage of the conductor and the initial position coefficient and the initial induced voltage by eliminating linear charge density. The first coefficient formula only establishes the relationship between the conductor voltage and linear charge density, and the second coefficient formula only establishes the relationship between the sensor induced voltage and linear charge density. Therefore, by simultaneously solving the first and second coefficient formulas and eliminating linear charge density, the voltage space parameter model can be constructed to obtain the correlation between the conductor voltage and the induced voltage.

[0098] The initial conductor voltage calculated by substituting the initial induced voltage and initial position coefficient into the voltage space parameter model is used as the calibrated target voltage, providing a parameter benchmark for subsequent calculation of the real-time position coefficient through real-time induced voltage.

[0099] As an optional approach, the real-time first position coordinates and the initial first position coordinates are compared and analyzed to obtain the spatial state of the conductor. The spatial state is characterized by multiple state parameters, including sag change, wind deflection amplitude, wind deflection angle, and galloping amplitude. These parameters include: calculating the sag change based on the real-time and initial first position coordinates using a catenary model; calculating the wind deflection angle and wind deflection amplitude based on the real-time and initial first position coordinates; calculating the galloping amplitude within a preset time using the standing wave equation of the conductor's spatial position and the initial first position coordinates; and determining that galloping has occurred if the galloping amplitude exceeds a set threshold within the preset time.

[0100] Because the spatial state of a conductor is represented by coordinates in different dimensions—including sag in the vertical direction, wind deflection in the horizontal direction, and galloping due to three-dimensional periodic variations—simple positional coordinate differences cannot directly reflect the degree of anomaly in the conductor's spatial state. Therefore, for the different physical characteristics of sag, wind deflection, and galloping, catenary models, spatial geometric formulas, and standing wave equations are adapted to calculate various state parameters. By quantifying parameters and using thresholds, objective discrimination of the spatial state can be achieved, avoiding misjudgments and omissions caused by subjective judgment or single-dimensional monitoring in related technologies, thus ensuring the accuracy of monitoring results and their engineering applicability.

[0101] like Figure 3 As shown, sag is the amount of vertical movement of a conductor along the x-axis under the influence of gravity. Changes in sag directly reflect the safe distance between the line and the ground. Calculating the sag value using the catenary model can accurately describe the relationship between the conductor along the x-axis and along the z-axis. The expression for the catenary model is: ,in, H is the real-time sag value; w is the horizontal tension of the conductor; cosh is the line load per unit length of the conductor, i.e., the weight of a unit conductor; z is the hyperbolic cosine function; and z is the distance between the detection point and the tower tip along the z-axis.

[0102] Obtain the initial natural sag data of the conductor, i.e., the initial first position coordinates (X1, Y1, Z1) of detection point A and the tower tip coordinates (X3, Y3, Z3), and derive the sag value y1(z1) of the conductor in the initial state. If a sag change occurs, the spatial parameters measured by the electric field sensor can be used to calculate the real-time first position coordinate change of detection point A' after time t, which is (X2, Y2, Z2). By combining the tower tip coordinates (X3, Y3, Z3), the new sag value y2(z2) after the sag change can be calculated. The sag change value is obtained by calculating the difference between y1(z1) and y2(z2), thus obtaining the sag change value Y of the monitoring point within time t. sag (t)=y2(z2)-y1(z1).

[0103] like Figure 4 The diagram shows a wind deflection model for one phase of an overhead conductor; the other two phases are modeled similarly. Conductor 1 represents the cross-section under normal conditions, and conductor 2 represents the cross-section under wind deflection conditions. After obtaining the initial first position coordinates (X1, Y1) of conductor 1 and the real-time first position coordinates (X2, Y2) of conductor 2, the wind deflection angle and magnitude are calculated using the following equations: ; Where θ represents the wind deflection angle of the conductor, and X wind This indicates the magnitude of wind deflection of the conductor.

[0104] Wind deflection only occurs in the XY plane perpendicular to the conductor, so it is only necessary to extract the x-axis and y-axis components from the real-time and initial coordinates for calculation, thereby simplifying the calculation process and ensuring real-time performance.

[0105] like Figure 5 As shown, the wind-induced galloping model of overhead conductors takes the second phase conductor as an example. Conductor galloping is a low-frequency (0.1~3Hz) high-amplitude line vibration caused by wind load under icing conditions. Conductor galloping generates standing waves on the line. The spatial position of the conductor when standing waves are generated can be described by the standing wave equation, and the galloping amplitude within a preset time is calculated based on the spatial position. The amplitude of conductor galloping is generally 5 to 300 times the conductor radius, so if the calculated galloping amplitude is greater than 5, it can be determined that conductor galloping has occurred.

[0106] As an optional approach, before calculating the galloping amplitude within a preset time using the standing wave equation of the conductor's spatial position and the initial first position coordinates, the method further includes: constructing a spatial position expression for the conductor using the standing wave equation based on the conductor's galloping frequency, initial phase of the conductor's galloping, and the order of the conductor's galloping, where the spatial position expression is as follows:

[0107] ; ;

[0108] In the formula, X g Represents the spatial position coordinates along the x-axis; Y g Indicates the spatial position coordinates along the Y-axis; a x,y This indicates the amplitude of the conductor's galloping in the horizontal and vertical directions; f x,y This indicates the frequency of the conductor's galloping in the horizontal and vertical directions; This indicates the initial phase of the conductor's galloping in the horizontal and vertical directions; n x,y Indicates the galloping order of the conductor in the horizontal and vertical directions; L represents the half-span of the transmission line; X wind Indicates the wind deflection amplitude of the conductor; Y sag This represents the change in sag of the conductor.

[0109] A standing wave is formed by the superposition of two traveling waves with the same frequency and opposite propagation directions. The standing wave equation includes the change of vibration over time and the distribution of vibration over the line span, which can simultaneously take into account the temporal dynamics and spatial distribution characteristics of galloping. The standing wave equation can accurately characterize the vibration offset of the conductor in the x-axis horizontal direction, y-axis direction and z-axis direction. The vibration offset along the z-axis of the conductor is basically unchanged and does not need to be calculated.

[0110] The spatial position coordinates are dynamic spatial coordinates for the conductor galloping scenario. They are based on the real-time first position coordinates and superimposed with the periodic offset of the conductor galloping. The spatial position coordinates are used to characterize the dynamic position changes of the conductor during galloping.

[0111] X g At time t, the conductor is at Z g The real-time coordinates along the x-axis at point a; x The difference in x-coordinate between the real-time first position coordinates and the initial first position coordinates; This is a time periodicity factor used to describe the change of vibration in the x-axis direction over time. This is a spatial periodicity factor used to describe vibrations along the x-axis and span Z. g The distribution of Z g ∈[0,2L].

[0112] Y g At time t, the conductor is at Z g The real-time coordinates along the y-axis at point a; y The difference between the real-time first position coordinates and the initial first position coordinates is the y-coordinate difference. This is a time periodicity factor used to describe the change of vibration along the y-axis over time.

[0113] The spatial position expression of the conductor transforms the periodic vibration characteristics of conductor galloping into a mathematical description of real-time spatial coordinates. Since conductor galloping is a low-frequency, large-amplitude three-dimensional periodic vibration of an icy conductor under wind load, simple discrete coordinate points cannot fully reflect the vibration law of the conductor, nor can they accurately calculate the maximum galloping amplitude within a preset time. Therefore, this embodiment integrates key vibration parameters such as galloping frequency, initial phase, and galloping order through the standing wave equation, constructing a spatial position expression that includes real-time first position coordinates, initial first position coordinates, and conductor offset. This transforms the physical process of conductor galloping into a mathematically calculable model, providing a foundation for subsequent accurate extraction of galloping amplitude and determination of galloping status, ensuring the rigor and accuracy of galloping monitoring.

[0114] As an alternative approach, before constructing the spatial position expression of the conductor based on the conductor's galloping frequency, initial galloping phase, and galloping order using the standing wave equation, the method further includes: performing a fast Fourier transform on the ratio of induced voltages collected by different electric field sensors to obtain a frequency domain signal; taking the maximum peak point in the spectrum of the frequency domain signal as the galloping frequency; obtaining the initial galloping phase based on the phase angle of the point corresponding to the galloping frequency; and calculating and rounding the ratio of the galloping frequency to the conductor's theoretical fundamental frequency to obtain the galloping order.

[0115] When a conductor gallops, the periodic change in its spatial position causes the induced voltages of each electric field sensor to fluctuate synchronously, with the fluctuation frequency matching the galloping frequency. Calculating the ratio of the induced voltages of different sensors can cancel out common-mode interference such as stray electric fields and power supply noise, yielding a pure signal that reflects only the galloping characteristics. Furthermore, a Fast Fourier Transform of the ratio of the sensor induced voltages can convert the time-domain voltage ratio signal into a frequency-domain signal, visually presenting the frequency distribution of the signal and facilitating the extraction of the galloping frequency.

[0116] The induced voltage at the sensing point can be determined using an electric field sensor. Based on this, the effect of conductor galloping on the induced voltage can be expressed by the following relationship: Where B represents the ratio of the induced voltages of different sensors; φ i φ represents the induced voltage of the i-th sensor; i’ This represents the induced voltage of any sensor other than the i-th sensor.

[0117] Perform a Fast Fourier Transform on the time-domain signal B(t) to obtain the frequency-domain signal. Find the peak point with the largest amplitude in the spectrum of the frequency-domain signal; this is the dancing frequency f. x,y In the standard galloping model (low-frequency, large-amplitude), the frequency f of the change in the ratio of the sensor-induced voltage to the conductor galloping frequency f0 is related to the frequency f0 of the conductor galloping. x,y Consistent. If the frequency f falls within the range of 0.1Hz to 3Hz, it is determined that dancing has occurred.

[0118] The initial phase of the galloping motion is a parameter used to describe the initial state of conductor vibration. It is directly related to the initial offset of the vibration in the spatial position expression, ensuring synchronization with the actual galloping state. In the frequency domain signal, the galloping frequency f is found. x,y The corresponding phase angle is the initial phase of the gobbling motion, and the formula for calculating the initial phase of the gobbling motion is: ,in, Let S(⋅) be the phase angle extraction function, and let S(⋅) represent the frequency domain signal obtained after the induced voltage ratio signal undergoes a fast Fourier transform. It represents angular frequency.

[0119] The galloping order is a parameter used to describe the standing wave distribution mode within the conductor span. The value of the galloping order determines the spatial distribution law of vibration in the spatial position expression. It is calculated in conjunction with the physical characteristics of the conductor. When calculating the galloping order, it is first necessary to calculate the theoretical fundamental frequency f of the conductor. theory The theoretical fundamental frequency is the natural vibration frequency of a conductor under its own tension and linear density. It is only related to the physical parameters of the conductor and can be obtained through initial calibration calculations. The formula for calculating the theoretical fundamental frequency is: Where L is the span, m is the conductor linear density, and T is the average tension of the conductor during operation.

[0120] The galloping order is obtained by calculating the ratio k of the galloping frequency to the theoretical fundamental frequency of the conductor, and rounding k to the nearest integer. The formula for calculating the ratio k is as follows: .

[0121] In engineering practice, only first- and second-order galloping is considered when determining the order of conductor galloping. Higher-order galloping has small amplitude and poses no real harm. If the galloping order is greater than or equal to 3 after rounding, it is judged as small-amplitude vibration and can be treated as no galloping.

[0122] In summary, this embodiment cancels common-mode interference by using the ratio of the induced voltages of different voltage sensors, thus avoiding the influence of environmental stray electric fields and power supply noise on the signal. At the same time, relying only on the induced voltage of existing electric field sensors, it can calculate galloping-related parameters without deploying dedicated equipment such as accelerometers and vibration sensors, thereby achieving the technical effect of reducing hardware costs and having a simple structure and low cost.

[0123] As an optional approach, the galloping amplitude within a preset time period is calculated using the standing wave equation of the conductor's spatial position and the initial first position coordinates. This includes calculating the instantaneous offset distance of the conductor based on its spatial position and the initial first position coordinates, using the following formula: In the formula, X1 represents the instantaneous offset distance of the conductor at time t; X1 and Y1 represent the initial first position coordinates of the conductor; based on the maximum instantaneous offset distance of the conductor within a preset time, the galloping amplitude is calculated using the following formula: In the formula, A is the amplitude of the dancing motion; R is the radius of the conductor.

[0124] The offset of the conductor's movement is concentrated in the XY plane perpendicular to the conductor. The instantaneous offset distance is the straight-line distance between the spatial position and the initial first position coordinates in the XY plane. Using the spatial distance formula, the offset distance that closely matches the physical reality can be calculated.

[0125] The preset time must cover at least one complete dance cycle, which can be determined based on the dance frequency f extracted in the early stage to ensure that the maximum offset is captured; the ratio of the maximum instantaneous offset distance of the conductor to the conductor radius R converts the instantaneous offset distance into a dimensionless index to avoid inconsistent judgment thresholds due to different conductor radii.

[0126] The instantaneous offset distance formula in this embodiment is based on the geometric relationship of the XY plane space, directly reflecting the actual offset without subjective simplification; the dancing amplitude is processed by the maximum value and normalization, which not only captures the maximum intensity, but also eliminates the difference in conductor specifications, and the judgment standard is unified, thereby achieving the technical effect of rigorous calculation logic and no theoretical error.

[0127] According to another aspect of the present invention, a transmission line spatial state detection system based on electric field sensing is also provided, comprising: an electric field sensor, including a sensing module, a differential amplifier, and an analog-to-digital converter; wherein, three or more electric field sensors are provided; the sensing module is used to sense the voltage signal generated by the radiated electric field of the conductor; the differential amplifier receives the voltage signal, performs differential calculation and amplification processing on the voltage signal through the differential amplifier; the analog-to-digital converter converts the processed voltage signal into an induced voltage; a first calculation module calculates the real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, through a voltage space parameter model and a target voltage, wherein... The target voltage is calculated using a voltage space parameter model based on the initial position coefficient of the conductor and the initial induced voltage obtained from the electric field sensor. This model characterizes the calculation relationship between the position coefficient, the induced voltage, and the target voltage. The second calculation module calculates the real-time first position coordinates of the conductor based on the real-time position coefficient using the position coefficient formula and the spatial distance formula. The comparison and analysis module compares and analyzes the real-time first position coordinates with the initial first position coordinates to obtain the spatial state of the conductor. This spatial state is characterized by multiple state parameters, including sag variation, wind deflection amplitude, wind deflection angle, and galloping amplitude.

[0128] The electric field sensor can be selected according to the on-site installation conditions, monitoring accuracy requirements, anti-interference level, and cost control requirements. Non-contact electric field sensor devices such as single-probe micro electric field sensors, optical electric field sensors, planar capacitive electric field sensors, and Rogowski coil electric field coupling sensors can be used. In this embodiment, a dual-probe electric field sensor is preferred, which has the advantages of low cost, fast response, and high stability.

[0129] Three or more electric field sensors are installed, evenly distributed on the transmission line towers, and maintained at a reasonable distance from the three-phase conductors to ensure moderate induced voltage intensity, avoiding both weak signals and physical collisions in case of conductor faults. After installation, the fixed position coordinates of the electric field sensors are calibrated using a total station, serving as the benchmark for subsequent spatial distance calculations. Using multiple electric field sensors ensures that, after filtering out measurement points with no signal and one of two measurement points with identical data when selecting induced voltages, at least three induced voltages are available to construct three sets of equations to solve for the three unknowns of the three-phase voltage.

[0130] After the differential amplifier outputs the voltage signal to the receiving induction module, it cancels common-mode interference through differential operation, and at the same time amplifies the weak voltage signal to a suitable amplitude, ensuring that the signal amplitude is within the range of the analog-to-digital converter, thus obtaining the differentially amplified analog voltage signal.

[0131] An analog-to-digital converter (ADC) converts the differentially amplified analog voltage signal into a digital signal, i.e., the induced voltage. ADCs can employ 16 bits or higher precision to ensure distortion-free conversion, and the digital signal accurately reproduces the variation patterns of the analog signal. The converted digital signal is then transmitted to subsequent computing modules, providing standardized and computable data input for these modules.

[0132] The first calculation module, based on the processed induced voltage, uses a voltage space parameter model and the target voltage to invert and obtain the real-time position coefficient. The target voltage within the first calculation module can be reused long-term after a single calibration, avoiding reference drift in real-time calculations.

[0133] Real-time position coefficients are used to characterize the spatial relationship between the conductor, sensor, and mirror source. The real-time position coefficients are input into the second calculation module, and combined with the position coefficient formula and spatial distance formula, the real-time first position coordinates of the conductor are obtained. This transforms the position coefficients into concrete spatial position data, providing a direct basis for subsequent comparative analysis.

[0134] The comparative analysis module compares and analyzes the real-time first position coordinates output by the second calculation module with the initial first position coordinates. Combined with the physical model in the calculation module, it quantifies the state parameters such as sag change value, wind deflection amplitude, wind deflection angle, and galloping amplitude, thereby achieving objective judgment of the conductor's spatial state.

[0135] The aforementioned data processing module, first calculation module, and second calculation module can be integrated and implemented using the same MCU (Microcontroller Unit) system, eliminating the need for separate sets of multiple computing units. This further simplifies the system hardware architecture, reduces equipment cost and size, and achieves the technical effect of simple structure and low cost.

[0136] The MCU system's internal non-volatile program storage space pre-stores voltage space parameter models, first coefficient formulas, second coefficient formulas, and spatial distance formulas for calculating position coefficients. It also has built-in supporting algorithm programs such as differential operations, filtering, and matrix solving. All models, formulas, and algorithms are written during the system's factory calibration phase and do not need to be repeatedly loaded during operation.

[0137] Through the integrated design described above, the MCU system only needs to use the induced voltage output by the electric field sensor as the sole input data source. It can then use the built-in fixed models, formulas and algorithms to achieve fully automated calculation of the entire process from induced voltage to conductor spatial state parameters without the need for an external host computer or additional computing equipment, thus ensuring the system's online and real-time operation capabilities.

[0138] As an optional solution, the electric field sensor is a dual-probe electric field sensor, which includes: the dual-probe electric field sensor is installed on the transmission line tower of the conductor, and the dual-probe electric field sensor is arranged in a ring around the conductor for non-contact measurement of the induced voltage of the conductor; the dual-probe electric field sensor consists of two independent metal probes arranged based on the principle of capacitive coupling.

[0139] Dual-probe electric field sensors do not require direct connection to wires, do not interfere with normal line operation, are easy to install and maintain, and reduce operation and maintenance costs; moreover, the dual-probe differential structure can effectively cancel stray electric field interference, with a high signal-to-noise ratio, and is suitable for complex environments such as mountainous areas and coastal areas.

[0140] like Figure 2 As shown, three or more dual-probe electric field sensors are fixedly installed on a pre-set bracket on the transmission line tower and are evenly arranged in a ring around the conductor to avoid missing electric field signals due to single-direction arrangement. This ensures that changes in conductor position in different directions can be accurately captured, providing comprehensive signal support for subsequent spatial position coordinate inversion.

[0141] Based on the principle of capacitive coupling, the dual-probe electric field sensor uses only air as the coupling medium to sense the power frequency electric field signal radiated by the sensing wire. It does not require additional power supply excitation and is a passive sensing method. It does not generate electromagnetic noise itself and avoids the interference of active sensors on the original electric field signal.

[0142] Two independent metal probes are symmetrically arranged. Stray electric fields in the environment will induce common-mode interference voltages with basically the same amplitude and phase on the two probes. After differential amplification and calculation by the data processing module, such common-mode interference can be completely canceled, and only the effective differential signal generated by the electric field of the conductor itself is retained, giving it excellent anti-interference ability.

[0143] An embodiment of the present invention also provides an electronic device, including: at least one processor; and a memory communicatively connected to the at least one processor. The memory stores a computer program executable by the at least one processor, which, when executed by the at least one processor, causes the electronic device to perform the method of the embodiment of the present invention.

[0144] refer to Figure 9The present invention will now describe a structural block diagram of an electronic device that can serve as an embodiment of the present invention, serving as an example of a hardware device applicable to various aspects of the present invention. The electronic device is intended to represent various forms of digital electronic computer devices, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processors, cellular phones, smartphones, wearable devices, and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the present invention described and / or claimed herein.

[0145] like Figure 9 As shown, the electronic device includes a computing unit 901, which can perform various appropriate actions and processes based on a computer program stored in a read-only memory (ROM) 902 or a computer program loaded into a random access memory (RAM) 903 from a storage unit 908. The RAM 903 may also store various programs and data required for the operation of the electronic device. The computing unit 901, ROM 902, and RAM 903 are interconnected via a bus 904. An input / output (I / O) interface 905 is also connected to the bus 904.

[0146] Multiple components in the electronic device are connected to I / O interface 905, including: input unit 906, output unit 907, storage unit 908, and communication unit 909. Input unit 906 can be any type of device capable of inputting information into the electronic device. Input unit 906 can receive input digital or character information and generate key signal inputs related to user settings and / or function control of the electronic device. Output unit 907 can be any type of device capable of presenting information and may include, but is not limited to, a display, speaker, video / audio output terminal, vibrator, and / or printer. Storage unit 908 may include, but is not limited to, disks and optical discs. Communication unit 909 allows the electronic device to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks, and may include, but is not limited to, modems, network cards, infrared communication devices, and / or wireless communication transceivers, such as Bluetooth devices, WiFi devices, WiMax devices, cellular communication devices, and / or the like.

[0147] The computing unit 901 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of the computing unit 901 include, but are not limited to, CPUs, graphics processing units (GPUs), various special-purpose artificial intelligence (AI) computing units, various computing units running machine learning model algorithms, digital signal processors (DSPs), and any suitable processor, controller, microcontroller, etc. The computing unit 901 performs the various methods and processes described above. For example, in some embodiments, the method embodiments of the present invention can be implemented as computer programs tangibly contained in a machine-readable medium, such as storage unit 908. In some embodiments, part or all of the computer program can be loaded and / or installed on an electronic device via ROM 902 and / or communication unit 909. In some embodiments, the computing unit 901 can be configured to perform the methods described above by any other suitable means (e.g., by means of firmware).

[0148] Computer programs for implementing the methods of embodiments of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor or controller of a general-purpose computer, special-purpose computer, or other programmable data processing apparatus, such that when executed by the processor or controller, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0149] In the context of embodiments of this invention, a machine-readable medium can be a tangible medium that may contain or store a program for use by or in conjunction with an instruction execution system, apparatus, or device. A machine-readable medium can be a machine-readable signal medium or a machine-readable storage medium. A machine-readable signal medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, or infrared systems, apparatus, or devices, or any suitable combination of the foregoing. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0150] It should be noted that the term "comprising" and its variations used in the embodiments of this invention are open-ended, meaning "including but not limited to". The term "based on" means "at least partially based on". The term "one embodiment" means "at least one embodiment"; the term "another embodiment" means "at least one additional embodiment"; the term "some embodiments" means "at least some embodiments". The modifications of "one" and "a plurality" mentioned in the embodiments of this invention are illustrative and not restrictive, and those skilled in the art should understand that unless explicitly indicated otherwise in the context, they should be understood as "one or more".

[0151] The user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, stored data, displayed data, etc.) involved in the embodiments of this invention are all information and data authorized by the user or fully authorized by all parties. Furthermore, the collection, use and processing of related data must comply with the relevant laws, regulations and standards of the relevant countries and regions, and corresponding operation entry points are provided for users to choose to authorize or refuse.

[0152] The steps described in the method embodiments provided by the present invention can be performed in different orders and / or in parallel. Furthermore, the method embodiments may include additional steps and / or omit the steps shown. The scope of protection of the present invention is not limited in this respect.

[0153] The term "embodiment" in this specification refers to a specific feature, structure, or characteristic described in connection with an embodiment that may be included in at least one embodiment of the invention. The appearance of this phrase in various places throughout the specification does not necessarily imply the same embodiment, nor does it imply independence or alternativeity from other embodiments. The various embodiments in this specification are described in a related manner, with reference to each other for similar or identical parts. In particular, for apparatus, device, and system embodiments, since they are substantially similar to method embodiments, the description is relatively simple, and relevant details are referred to in the description of the method embodiments.

[0154] The above-described embodiments are merely illustrative of several implementations of the present invention, and while the descriptions are specific and detailed, they should not be construed as limiting the scope of protection. It should be noted that those skilled in the art can make various modifications and improvements without departing from the inventive concept of the present invention, and these modifications and improvements all fall within the scope of protection of the present invention. Therefore, the scope of protection of the present invention should be determined by the appended claims.

Claims

1. A method for detecting the spatial state of a transmission line based on electric field sensing, characterized in that, include: Based on the induced voltage collected in real time by the electric field sensor, the real-time position coefficient is calculated through the voltage space parameter model and the target voltage. The target voltage is calculated based on the initial position coefficient of the conductor and the initial induced voltage obtained by the electric field sensor through the voltage space parameter model. The voltage space parameter model is used to characterize the calculation relationship between the position coefficient, the induced voltage and the target voltage. Based on the real-time position coefficient, the real-time first position coordinates of the conductor are calculated using the position coefficient formula and the spatial distance formula. The spatial state of the conductor is obtained by comparing and analyzing the real-time first position coordinates and the initial first position coordinates of the conductor. The spatial state is characterized by multiple state parameters, including sag change value, wind deflection amplitude, wind deflection angle and galloping amplitude.

2. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 1, characterized in that, Before calculating the real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, using the voltage space parameter model and the target voltage, the method further includes: With the conductor in its initial position, the initial first position coordinates and the second position coordinates of the electric field sensor are obtained; The initial distance parameter when the conductor is in the initial position is calculated using the spatial distance formula based on the initial first position coordinates and the second position coordinates. The initial position coefficient is obtained based on the initial distance parameter and the position coefficient formula; Based on the initial position coefficient and the initial induced voltage obtained by the electric field sensor, the target voltage is calculated using the voltage space parameter model, wherein the initial induced voltage is the induced voltage collected when the conductor is in the initial position.

3. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 2, characterized in that, The initial distance parameters of the conductor at its initial position are calculated using the spatial distance formula based on the initial first position coordinates and the second position coordinates, including: Based on the initial first position coordinates, the initial third position coordinates of the mirror source corresponding to the conductor are obtained by means of the mirror method, wherein the mirror source is the point symmetrical to the conductor about the ground. Based on the initial first position coordinates, the second position coordinates, and the initial third position coordinates, initial distance parameters are calculated using a spatial distance formula. The distance parameters include the distance between the conductors, the distance between the conductors and the mirror source, the distance between the conductors and the electric field sensor, and the distance between the mirror source and the electric field sensor.

4. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 2, characterized in that, The initial position coefficients include an initial first position coefficient and an initial second position coefficient, and the position coefficient formulas include a first coefficient formula and a second coefficient formula. Before obtaining the initial position coefficients based on the initial distance parameter and the position coefficient formulas, the method further includes: Based on Maxwell's equations and the method of images, the first coefficient formula and the second coefficient formula are constructed, wherein... The formula for calculating the first coefficient is as follows: ； In the formula, U j Let J be the target voltage of the j-th phase conductor; H is the vacuum permittivity; jj’ D is the distance from the j-th phase conductor to the j'-th phase mirror source; jj’ R is the distance from the j-th phase conductor to the j'-th phase conductor; R is the conductor radius. P represents the linear charge density of the i-th phase conductor; jj’ It is the first position coefficient defining the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; j=1,2,3; j'=1,2,3; The formula for calculating the second coefficient is as follows: ； In the formula, d represents the induced voltage obtained by the i-th electric field sensor; ij s is the distance from the i-th electric field sensor to the j-th phase conductor; ij P is the distance from the i-th electric field sensor to the j-th phase mirror charge source; eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor, i=1,2,3; j=1,2,3.

5. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 4, characterized in that, Before calculating the target voltage based on the initial position coefficient and the initial induced voltage obtained by the electric field sensor using the voltage space parameter model, the following steps are also included: Based on the first coefficient formula and the second coefficient formula, a voltage space parameter model is constructed; the voltage space parameter model is as follows: ； In the formula, U j P represents the target voltage of the j-th phase conductor. jj’ It is the first position coefficient of the voltage to ground of the j-th phase conductor under the influence of the j'-th phase conductor and its mirror source; P eij It is the second position coefficient of the induced voltage generated by the j-th phase conductor at the i-th electric field sensor; The induced voltage is the result of processing by the i-th electric field sensor.

6. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 1, characterized in that, By comparing and analyzing the real-time first position coordinates and the initial first position coordinates, the spatial state of the conductor is obtained. This spatial state is characterized by multiple state parameters, including sag variation, wind deflection amplitude, wind deflection angle, and galloping amplitude, among others. Based on the real-time first position coordinates and the initial first position coordinates, the sag change value is calculated using the catenary model of the conductor. Based on the real-time first position coordinates and the initial first position coordinates, the wind deflection angle and wind deflection amplitude of the conductor are calculated. The amplitude of the galloping motion within a preset time is calculated using the standing wave equation of the spatial position of the conductor and the initial first position coordinates. If the amplitude of the dancing motion exceeds a set threshold within a preset time period, it is determined that dancing has occurred.

7. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 6, characterized in that, Before calculating the galloping amplitude within a preset time using the standing wave equation of the conductor's spatial position and the initial first position coordinates, the method further includes: Based on the conductor's galloping frequency, initial phase of galloping, and galloping order, a spatial position expression for the conductor is constructed using the standing wave equation, wherein the spatial position expression is as follows: ； ； In the formula, X g Represents the spatial position coordinates along the x-axis; Y g Indicates the spatial position coordinates along the Y-axis; a x,y This indicates the amplitude of the conductor's galloping in the horizontal and vertical directions; f x,y φ represents the frequency of the conductor's galloping in the horizontal and vertical directions. x,y Indicates the initial phase of the dancing motion in the horizontal and vertical directions; n x,y Indicates the galloping order in the horizontal and vertical directions; L represents the half span of the transmission line; X wind Indicates the wind deflection amplitude of the conductor; Y sag This represents the change in sag of the conductor.

8. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 7, characterized in that, Before constructing the spatial position expression of the conductor using the standing wave equation based on the conductor's galloping frequency, initial phase of galloping, and galloping order, the method further includes: The ratio of the induced voltages collected by different electric field sensors is subjected to a fast Fourier transform to obtain the frequency domain signal. The maximum peak point in the spectrum of the frequency domain signal is taken as the dancing frequency; Based on the phase angle of the point corresponding to the dancing frequency, the initial phase of the dancing is obtained; The dancing order is obtained by calculating and rounding the ratio of the dancing frequency to the theoretical fundamental frequency of the conductor.

9. The method for detecting the spatial state of transmission lines based on electric field sensing according to claim 6, characterized in that, Using the standing wave equation of the conductor's spatial position and the initial first position coordinates, the galloping amplitude within a preset time period is calculated, including... Based on the spatial location and the initial first position coordinates, the instantaneous offset distance of the conductor is calculated using the following formula: ； In the formula, X g Represents the spatial position coordinates along the x-axis; Y g Represents the spatial position coordinates along the Y-axis; X1 and Y1 represent the instantaneous offset distance of the conductor at time t; X1 and Y1 represent the initial first position coordinates of the conductor. The galloping amplitude is calculated based on the maximum instantaneous offset distance of the conductor within a preset time period, using the following formula: ； In the formula, A is the amplitude of the dancing motion; R is the radius of the conductor.

10. A spatial state detection system for transmission lines based on electric field sensing, characterized in that, include: An electric field sensor includes a sensing module, a differential amplifier, and an analog-to-digital converter; wherein, the electric field sensor is configured to be three or more. The sensing module is used to sense the voltage signal generated by the radiated electric field of the conductor; the differential amplifier receives the voltage signal, performs differential calculation and amplification on the voltage signal through the differential amplifier; and the analog-to-digital converter converts the processed voltage signal into an induced voltage. The first calculation module calculates the real-time position coefficient based on the induced voltage collected in real time by the electric field sensor, through a voltage space parameter model and a target voltage. The target voltage is calculated based on the initial position coefficient of the conductor and the initial induced voltage obtained by the electric field sensor, through the voltage space parameter model. The voltage space parameter model is used to characterize the calculation relationship between the position coefficient, the induced voltage, and the target voltage. The second calculation module is used to calculate the real-time first position coordinates of the conductor based on the real-time position coefficient, the position coefficient formula, and the spatial distance formula. The comparison and analysis module is used to compare and analyze the real-time first position coordinates and the initial first position coordinates of the conductor to obtain the spatial state of the conductor. The spatial state is characterized by multiple state parameters, including sag change value, wind deflection amplitude, wind deflection angle and galloping amplitude.

11. The transmission line spatial state detection system based on electric field sensing according to claim 10, characterized in that, The electric field sensor is a dual-probe electric field sensor, comprising: The dual-probe electric field sensor is installed on the transmission line tower of the conductor, and the dual-probe electric field sensor is arranged in a ring around the conductor for non-contact measurement of the induced voltage of the conductor. The dual-probe electric field sensor consists of two independent metal probes arranged based on the principle of capacitive coupling.

12. An electronic device, comprising: A processor and a memory storing a program, characterized in that the program includes instructions that, when executed by the processor, cause the processor to perform the method according to any one of claims 1 to 9.

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