US20140163884A1 - Method and system for the determination of wind speeds and incident radiation parameters of overhead power lines - Google Patents

Method and system for the determination of wind speeds and incident radiation parameters of overhead power lines Download PDF

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US20140163884A1
US20140163884A1 US13/709,474 US201213709474A US2014163884A1 US 20140163884 A1 US20140163884 A1 US 20140163884A1 US 201213709474 A US201213709474 A US 201213709474A US 2014163884 A1 US2014163884 A1 US 2014163884A1
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Prior art keywords
wind speed
conductor
frequency
span
power line
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Jean-Louis Lilien
Huu-Minh Nguyen
Bertrand Godard
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AMPACIMON SA
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Universite de Liege
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Priority to US13/709,474 priority Critical patent/US20140163884A1/en
Assigned to UNIVERSITE DE LIEGE reassignment UNIVERSITE DE LIEGE ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: GODARD, BERTRAND, LILIEN, JEAN-LOUIS, NGUYEN, HUU-MINH
Priority to EP13712178.6A priority patent/EP2929357B1/en
Priority to PCT/EP2013/055180 priority patent/WO2014090416A1/en
Priority to IN5979DEN2015 priority patent/IN2015DN05979A/en
Priority to SI201330539A priority patent/SI2929357T1/sl
Priority to CN201380064492.4A priority patent/CN104981699B/zh
Publication of US20140163884A1 publication Critical patent/US20140163884A1/en
Assigned to AMPACIMON S.A. reassignment AMPACIMON S.A. ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: UNIVERSITE DE LIEGE
Priority to US14/733,602 priority patent/US10317570B2/en
Priority to IL239310A priority patent/IL239310B/en
Abandoned legal-status Critical Current

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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01W—METEOROLOGY
    • G01W1/00—Meteorology
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/02—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring forces exerted by the fluid on solid bodies, e.g. anemometer
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01P—MEASURING LINEAR OR ANGULAR SPEED, ACCELERATION, DECELERATION, OR SHOCK; INDICATING PRESENCE, ABSENCE, OR DIRECTION, OF MOVEMENT
    • G01P5/00—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft
    • G01P5/10—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring thermal variables
    • G01P5/12—Measuring speed of fluids, e.g. of air stream; Measuring speed of bodies relative to fluids, e.g. of ship, of aircraft by measuring thermal variables using variation of resistance of a heated conductor
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06F—ELECTRIC DIGITAL DATA PROCESSING
    • G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02G—INSTALLATION OF ELECTRIC CABLES OR LINES, OR OF COMBINED OPTICAL AND ELECTRIC CABLES OR LINES
    • H02G1/00—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines
    • H02G1/02—Methods or apparatus specially adapted for installing, maintaining, repairing or dismantling electric cables or lines for overhead lines or cables
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02G—INSTALLATION OF ELECTRIC CABLES OR LINES, OR OF COMBINED OPTICAL AND ELECTRIC CABLES OR LINES
    • H02G7/00—Overhead installations of electric lines or cables
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S10/00—Systems supporting electrical power generation, transmission or distribution
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S10/00—Systems supporting electrical power generation, transmission or distribution
    • Y04S10/30—State monitoring, e.g. fault, temperature monitoring, insulator monitoring, corona discharge

Definitions

  • the present invention relates to a method and system for the determination of parameters related to the speed of wind that blows near an overhead electrical power line (single or bundle conductors).
  • such parameters include an effective perpendicular wind speed (hereinafter referred to as the “effective wind speed”), which is the speed that would have a wind blowing perpendicularly to the conductor axis and having the same cooling effect on the conductor as the actual wind.
  • the combination of solar radiation and albedo on power line conductor is hereinafter referred to as the “effective incident radiation”.
  • the device and method described in U.S. Pat. No. 8,184,015 can monitor the sag continuously on a power line span, without the need for external data, such as topological data, conductor or span data, weather data, or sagging conditions, which makes the invention unique.
  • the basic principle of that invention is the detection of mechanical dynamic properties of the power lines only based on mechanical frequencies detection from 0 to some tens of Hertz (Hz). Indeed, power lines in the field are always subject to movements and vibrations, which may be very small but detectable by their accelerations in both time and frequency domains.
  • the new method of the present invention can also be used by other devices equipped with accelerometers.
  • the ampacity of a conductor is that maximal constant electrical current which will meet the design, security and safety criteria (e.g. electrical clearance) of a particular line on which the conductor is used (see reference 5).
  • the method to evaluate ampacity from data are explained in many books (such as reference 1) and technical brochures from international organizations, such as The International Council on Large Electric Systems (CIGRE) publications (see references 2, 4 and 5), which use weather data as locally measured or simulated following international recommendations as explained, for example, in CIGRE (see reference 3) or The Institute of Electrical and Electronics Engineers (IEEE) publication of 2006 (see reference 10).
  • CIGRE The International Council on Large Electric Systems
  • a drawback of all these methods about weather conditions is that none of them is able to generate appropriate weather data which are actually to be used to calculate ampacity, which is a value linked to all critical spans of a power lines.
  • a critical span is a span for which there is a significant risk of potential clearance violation in any kind of weather situations.
  • the critical spans of a section may depend on span orientation, local screening effects, local obstacles (vegetation, buildings, roads, . . . ), etc. They have been defined at the design stage but may be reviewed by more modern techniques like Light Detection And Ranging (LIDAR) survey.
  • LIDAR Light Detection And Ranging
  • the wind speed has a dramatic impact on power line ampacity as it is the main variable responsible for cooling down the conductor, and hence for the sag value.
  • wind speed measurement is tricky for various reasons. First, it is not stationary as wind speed can vary significantly within minutes, and there may be wind gusts. Second, it also varies along the span (spatial coherence): wind vortices have a typical average size of several tens of meters (Simiu & Scanlan, 1996). Therefore, a typical span length of several hundreds of meters is subject to a variable wind speed along its length. Third, the wind speed also varies greatly vertically, as the conductor is fastened within the boundary layer, and as the span's lowest point is generally about 10 meters over the ground.
  • the wind speed may also vary due to local effects, such as screening from trees or buildings, altitude of the conductor which may change in a single span of more than 15 meters if only the sag is considered, but which may also be subject to difference of levels between end points of a span.
  • altitude near the ground may have huge effects as the conductor lies in an air layer located in the boundary conditions of wind speed variation due to the ground proximity.
  • a number of different methods which perform sag measurement are also known.
  • An example of tentative sag measurement consists in the optical detection of a target clamped on the monitored conductor by a camera fixed to a pylon (U.S. Pat. No. 6,205,867).
  • Other examples of such methods include measurement of the conductor temperature or tension or inclination of the span.
  • a conductor replica is sometimes attached to the tower to catch an assimilated conductor temperature without Joule effect.
  • U.S. Pat. Nos. 5,140,257 and 5,341,088 disclose a monitoring device whose housing is attached to the conductor. Some features are related to the measurement of wind speed and direction based on hot wire anemometers. The drawback of this device is that hot wires anemometer is extremely difficult to manage on a sensor attached to a conductor. Moreover, wind speed is deformed by the sensor itself as hot wire needs to be protected against corona.
  • U.S. Pat. Nos. 6,441,603 and 5,559,430 disclose a monitoring device for overhead power line rating but not attached to the conductor. It is a kind of conductor replica. The combined effect of wind, solar radiation, albedo, ambient temperature evaluation is based on the behavior of dedicated rods installed apart from the line. Drawback of such method is that the effect along the span was not taken into account and that such local measurement is not a good indication of what is actually the mean wind speed and global incident radiation along spans of several hundreds of meters with possible variable altitudes and different kind of wind action along the span. Moreover, there are obvious errors for replica compared to conductor emissivity and absorptivity and global incident radiation mean value along the span.
  • U.S. Pat. No. 4,728,887 discloses a monitoring device whose housing is adjacent to the overhead line. There is no information about how wind speed and its direction are taken into account to evaluate ampacity.
  • U.S. Pat. No. 5,933,355 discloses software to evaluate ampacity of power line. This has no relationship with wind speed measurement.
  • U.S. Pat. No. 6,205,867 discloses a power line sag monitor based on inclination measurement. There is no information about how wind speed and direction are taken into account to calculate ampacity.
  • PCT Application WO 2010/054072 is related to real time power line rating. It alleged the existence of a sensor about wind speed direction and amplitude but offered no explanation how these sensors are constituted.
  • PCT Application WO 2004/038891 and Norway Application N020024833 disclose a monitoring device whose housing is attached to the conductor.
  • the wind is measured by “a traditional wind gauge” and that such wind gauge “operates with an opening in the outer casing”.
  • Such traditional gauge has no relationship with the proposal of the inventors.
  • the drawback of such traditional gauge is that the sensor itself constitutes a perturbation in the local measurement and that low wind speed cannot be measured properly by such gauge.
  • European Patent Application EP 1.574.822 discloses a monitoring device whose housing is attached to the conductor. There is no information about how wind speed and direction are taken into account to evaluate ampacity.
  • Korean Patent Application KR20090050671 discloses a monitoring device whose housing is attached to the conductor.
  • a drawback of this device is that there is no way to properly determine the “effective wind speed” perpendicular to the conductor if they are less than 3 m/s, which are the basic cases for ampacity determination under critical conditions.
  • U.S. Patent Application Publication No. US 20120029871 A1 discloses a monitoring device whose housing is attached to the conductor.
  • a drawback of this device is that there is no explanation on how to evaluate the wind speed to consider for ampacity determination.
  • On a website of that system it is stated that “We also tasked the sensors to detect Aeolian vibration, which is an indication of wind blowing across the conductor, and ‘galloping.’ “(extracted from http://www.lindsey-usa.com/newProduct.php). But there is no explanation on how such link is done. It is well known from the literature that Aeolian vibration frequencies are linked to wind speed (see references 6, 8 and 9).
  • the present invention meets a need for a power line device and method overcoming at least some of the problems left open by prior art solutions.
  • the present invention is based on a power line sensor directly fixed on the power line conductor (or one of it in case of bundle conductors) and equipped with accelerometers outputs in several directions.
  • the present invention will use redundant information made available in all or part by these accelerometers.
  • An object of the present invention is to provide a method to measure “effective wind speed” acting on a power line span by using the combination of mechanical vibrations and movements/positions in two or three dimensions outputs through sensors in direct link with the power line conductor.
  • Another object of the present invention is also to provide a method to determine indirectly an “effective incident radiation” acting on a power line span by using the combination of mechanical vibrations and movements/positions in two or three dimensions outputs through sensors in direct link with the power line conductor.
  • the sensor must be located at any in-span position.
  • the device used to detect vibration may be based (but not necessarily) on U.S. Pat. No. 8,184,015, in which the device was used in the harsh environment constituted by the vicinity of a high voltage (tens to hundreds of kV) overhead power line.
  • the sensor must be equipped with accelerometers of significant sensitivity, typically able to detect accelerations near about maximum 100 micro-G in vertical, (longitudinal) and transversal directions (means minimum 2D, possibly 3D accelerometers).
  • FIG. 1 is a schematic diagram showing how the wind is acting on conductor including wind effect and mean swing angle ⁇ of power line span, wherein “transversal swing angle” is defined as tan( ⁇ ).
  • FIGS. 2 a and 2 b show the sag as deduced by oscillation sensor outputs (with its maximum value) ( FIG. 2 a ) and deduced conductor temperature ( FIG. 2 b ) together with ambient temperature (here measured in the vicinity of the power line span) during a one day time evolution.
  • sag is deduced by an oscillation sensor from U.S. Pat. No. 8,184,015 (with its maximum allowable value in dotted line).
  • the thin line represents deduced conductor temperature
  • the dotted line represents ambient temperature (here measured in the vicinity of the power line span).
  • FIGS. 3 a and 3 b show , on the same day, the deduced “effective incident radiation” power as detailed in the invention ( FIG. 3 a ) and the load current (bottom curve), the static rating (horizontal dotted line at 850 A) and the dynamic rating (thick line) as deduced from effective three weather data, two of them being determined by the invention ( FIG. 3 b ).
  • FIGS. 4 a and 4 b show, on the same day, the frequency detection as obtained by using the accelerometers detailed in the invention and tracking of Aeolian periods.
  • FIG. 4 a is a simultaneous view of typical time evolution of detected vibration frequencies and corresponding reinforced Aeolian period vibration frequency tracking according to the invention.
  • FIG. 4 b shows extracted Aeolian vibration tracking as detailed in the invention. Missing data around 12:00 during about 4 hours are due to the absence of detected Aeolian vibration during the corresponding period.
  • FIGS. 5 a and 5 b show, on the same day at time 12:00, the frequency-amplitude content of the measured signal by the accelerometers detailed in the invention.
  • FIGS. 6 a and 6 b show, on the same day at time 04:30, the frequency-amplitude content of the measured signal by the accelerometers detailed in the invention.
  • Typical frequency of “Type II” (Aeolian vibrations) as can be extracted from FIGS. 4 a and 4 b (reproduced in FIG. 6 a ) at measurement time of about 04:30 (vertical dotted line on the frequency-time figure).
  • FIG. 7 shows the values of power line conductor “transversal swing angle” as obtained using the accelerometer-based method detailed in the invention.
  • Swing angle (radians) of the power line span in this case a conductor of about 0.257 kg/m and a diameter of 12.5 mm
  • the value is extracted from transversal acceleration of the embedded corresponding accelerometer into the in-span power line sensor.
  • the mean swing angle is about 0.025 rd or 1.4°. Values below about 0.0025 radian are below the expected precision of the system and cannot be considered for use.
  • FIG. 8 shows the “effective wind speed” during the same day, as calculated according to the present invention.
  • the thick black part of the curve has been fully deduced from actually observed Aeolian vibrations in a range limited to wind speed lower than about 1.6 m/s (larger range are also possible).
  • the curve has been completed for larger wind speed, by the thick grey part of the curve deduced from transversal acceleration analysis as detailed in the invention.
  • the typical continuous wind speed value obtained as detailed in the invention.
  • the thick black line represents wind speed deduced from Aeolian vibrations during such periods, as deduced from FIG. 4 using the invention.
  • the thin cross line represents wind speed deduced from mean transversal acceleration, as deduced from FIG. 7 using the invention.
  • FIGS. 9 a - 9 d show a typical time evolution on 10 minutes of vertical and horizontal accelerations (Type I) during a buffeting period.
  • FIGS. 9 a and 9 c show transversal accelerations.
  • FIGS. 9 b and 9 d show vertical accelerations. The range of relative changes are similar in both directions.
  • FIGS. 10 a and 10 b show a typical growing up and decay of Aeolian vibrations (Type II) of about 10 minutes inside a global observation period of 50 minutes.
  • FIG. 10 a shows transversal accelerations and
  • FIG. 10 b shows vertical accelerations. Range of relative changes are very different with a clear dominance in vertical amplitudes.
  • the new method according to the present invention adds, in parallel with the thermal equilibrium equation (as described in detail, for example, in IEEE 2006 and reproduced in pages 15 to 17), a second independent equation to determine the most changeable (both in time and space) and most important weather variable for ampacity determination: the wind speed perpendicular component to the conductor axis averaged over the whole span, so called “effective wind speed”.
  • the required wind speed for ampacity determination is evaluated independently from the thermal equation by means of two independent methods (the results of which are being superimposed or complemented in some range of detected wind speeds). Those two methods determine the wind speed perpendicular component averaged over the span:
  • a sensor For a multiple-span section, a sensor has to be repeated on all critical spans along the section and the worst case is considered for ampacity evaluation.
  • a three-axis accelerometer assembly with a range of frequency comprised between 0 and about 100 Hz and a minimum sensitivity of 100 micro-G may detect ambient Aeolian vibrations, often existing at very low wind speed, preferably, comprised between 0.05 and about 7 m/s and, most preferably, between 0.2 and 3 m/s.
  • the accelerometers are able to detect basic oscillation modes of the power line. It is noted here that only the detection of Aeolian vibration frequency is needed. The vibration could be of very low amplitude.
  • An observed Aeolian vibration is obviously linked to a lock-in (as detailed in EPRI 2009) of the vortex shedding with one mode (sometimes a few modes in a very narrow band of frequencies) of vibration of the cable. That detectable frequency(ies) by the line monitoring device is the driving mode or the converted energy from the wind to the vibration in its dominant mode all over the span. Thus, it is representative of the dominant mean wind speed to consider all along the span for thermal convection heat exchange.
  • the “effective wind speed” for power line span may be deduced from vibrations analysis. This method is particularly valuable for very low wind speed, lower than about 7 m/s, most preferably lower than 3 m/s, which are the dramatic cases for ampacity determination.
  • f is the frequency of vibration (Hz) as extracted from step 2
  • S is the Strouhal number (dimensionless)
  • V is the perpendicular wind speed (m/s)
  • d is the conductor diameter (m).
  • the Strouhal number, for typical power line conductor is close to 0.185 and is dimensionless. (See Blevins 1990, Simiu et al., 1996, EPRI 2009).
  • FIG. 8 shows a typical output of “effective wind speed” using Aeolian vibration detection algorithm. In this case (one full day), the values have been completed by some transversal inclination (also obtained by accelerometers) during high wind speed periods.
  • the power line span swing angle (shown in FIG. 1 ) can be evaluated by considering the equilibrium per unit length between the weight of the conductor and the drag force F D of wind.
  • transversal swing angle is referred to as tan( ⁇ ) where ( ⁇ ) is the mean swing angle of the power line span, see FIG. 1 .
  • ⁇ is the linear density of conductor [kg/m] and g is the gravity constant [9.81 m/s 2 on earth].
  • d [m] is the diameter of the conductor
  • ⁇ air the air density [kg/m 3 ]
  • C D the drag coefficient [dimensionless].
  • transversal swing angle is also given by inclination of transversal axis t with gravity g, that value may be extracted from embedded accelerometers into the sensor installed on the power line conductor:
  • wind speed can be determined, using transversal acceleration g t [m/s 2 ].
  • Mean value of transversal acceleration is measured to evaluate mean wind speed acting on the conductor. That mean value is obtained on sample size range from about 5 to 20 minutes, most preferably around 10 minutes mean value is used.
  • Effective perpendicular wind speed (“effective wind speed”), the variable with the most influence on the RTTR/DLR is determined as described above: at low wind speeds using the Aeolian vibration and at higher wind speeds, if needed, using the “transversal swing angle” ( FIG. 1 ).
  • Ambient temperature (shown on FIG. 2 , right bottom curve) is determined based on an external or internal measurement in the monitoring sensor or located in general vicinity of the line. As ambient temperature varies little (compared to the other variables) over time, distance or altitude, a measurement performed even several kilometers away from the overhead line may be adequate.
  • the “effective incident radiation” (comprising direct solar radiation and environment's albedo along the span) ( FIG. 3 a ) is determined by using the sag measurement ( FIG. 2 b , upper curve)(which may be also obtained by accelerometers as explained in U.S. Pat. No. 8,184,015 which allows for calculating the sag without any external data) as follows:
  • thermal equilibrium equation (as detailed in IEEE 2006 and reproduced in appendix) and will need the load current in the line ( FIG. 3 right bottom)(deduced from load flow in the line which is either transmitted by the TSO or directly measured into a sensor installed on the power line) to quantify the Joule effect, the “effective wind speed” (determined in step 1), ambient temperature (determined in step 2), and the conductor average temperature over the span (which is a direct image of the measured sag in a single-span section, as they are bound to each other by a one-to-one relationship as detailed in reference 4); the “effective incident radiation” can then be calculated by solving the thermal equilibrium equation:
  • Equation (i) applies at low winds but is incorrect at high wind speeds. Equation (ii) applies at high wind speeds, being incorrect at low wind speeds. At any wind speed, the larger of the two calculated convection heat loss rates is used.
  • This radiation term includes solar heat, if any, and albedo.
  • V “effective wind speed” (m/s)
  • T c conductor temperature (° C.)
  • T a ambient air temperature (° C.)
  • This approach comprising redundant information (two measurements of the “effective wind speed”, plus the sag measurement), allows one to determine RTTR (real time thermal rating) with a precision not yet attained by any of the current methods and tools, as point measurement methods are corrected using the behavior of the overhead line itself and even approximations of the thermal model and its variables (emissivity, humidity for example) are compensated by the correction applied to the “effective incident radiation” using the sag measurement.
  • Such weather data can be evaluated on all critical spans of the line and help to compute ampacity for each case and select the worst case for the line.
  • Effective wind speed can be used for an even broader range of applications, like the determination of the wind dynamic pressure coefficient, or the conductor maximum swing angle, used for line design.
  • a side outputs of these measurement is the availability of past behavior (in both sag, lateral movement, “effective wind speed”, ampacity, . . . ) including long term behavior.

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US13/709,474 2012-12-10 2012-12-10 Method and system for the determination of wind speeds and incident radiation parameters of overhead power lines Abandoned US20140163884A1 (en)

Priority Applications (8)

Application Number Priority Date Filing Date Title
US13/709,474 US20140163884A1 (en) 2012-12-10 2012-12-10 Method and system for the determination of wind speeds and incident radiation parameters of overhead power lines
CN201380064492.4A CN104981699B (zh) 2012-12-10 2013-03-13 用于测量垂直风分量的方法和系统
SI201330539A SI2929357T1 (sl) 2012-12-10 2013-03-13 Postopek in sistem za merjenje pravokotne komponente vetra
PCT/EP2013/055180 WO2014090416A1 (en) 2012-12-10 2013-03-13 Method and system for measuring a perpendicular wind component
IN5979DEN2015 IN2015DN05979A (zh) 2012-12-10 2013-03-13
EP13712178.6A EP2929357B1 (en) 2012-12-10 2013-03-13 Method and system for measuring a perpendicular wind component
US14/733,602 US10317570B2 (en) 2012-12-10 2015-06-08 Method and system for measuring a perpendicular wind component
IL239310A IL239310B (en) 2012-12-10 2015-06-09 Method and system for measuring a vertical wind component

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US13/709,474 US20140163884A1 (en) 2012-12-10 2012-12-10 Method and system for the determination of wind speeds and incident radiation parameters of overhead power lines

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US20130205900A1 (en) * 2012-02-14 2013-08-15 Tollgrade Communications, Inc. Power line management system
CN104820108A (zh) * 2015-05-18 2015-08-05 中南大学 一种基于空间摆的机械式二维风速风向传感器
JP2016014548A (ja) * 2014-07-01 2016-01-28 富士通株式会社 携帯端末装置、風速を算出する方法およびプログラム
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