SYSTEM AND METHOD FOR DYNAMIC DETERMINATION OF MAXIMUM ELECTRIC CURRENT TRANSMISSION CAPACITIES

Abstract

This system (40) for dynamically determining maximum electric current transport capacities includes: means (44) for storing a model (54) of a network portion (10), a thermal equilibrium relation (56), limit operating temperatures and conduction parameters; and a receiver (46) of wind speed values ​​measured by anemometric stations (24, 26, 28, 30).It further includes a computer (48) programmed (62, 64, 66, 68) to: apply a wind propagation model (60) from at least one selected station to singular points of the network segment model (54), for the estimation of a wind speed value at each singular point; and calculate at least one maximum capacity value at each singular point from the thermal equilibrium relation (56), each limit operating temperature, each conduction parameter and meteorological parameters (58), taking into account said estimated wind speed value at each singular point in the thermal equilibrium relation (56).

Description

[0001] The present invention relates to a system for dynamically determining maximum electrical current transmission capacities for a portion of a high-voltage electrical transmission network. It also relates to a corresponding method and an electrical transmission installation incorporating such a system.

[0002] More specifically, it focuses on a system comprising: means for storing a model of the network segment, this model comprising singular points and at least one high-voltage electric current conducting line between these singular points, a predetermined thermal equilibrium relation, a limit operating temperature of each conducting line and conduction parameters of each conducting line, a computer, having access to the storage means, programmed to calculate at least one maximum capacity value at each singular point of the network segment model from the predetermined thermal equilibrium relation, each limit operating temperature, each conduction parameter and meteorological parameters.

[0003] The maximum current-carrying capacity of a high-voltage line, sometimes called "amperage," is the maximum permissible current intensity carried by that line, expressed in amperes. It is generally assumed that this maximum capacity is a constant whose value depends on the operating temperature limit, itself constant and calculated based on assumed constant geometric parameters of the high-voltage line and meteorological parameters. The relationship between the maximum current-carrying capacity and the operating temperature limit is then expressed as a thermal equilibrium equation providing a current value as a function of the temperature of the high-voltage line conductor, meteorological parameters, and intrinsic conductor data.For a static calculation of this maximum capacity, the meteorological parameters are chosen a priori as the most unfavorable possible in the environment of the high-voltage line to ensure that the resulting value calculated in this way constitutes a truly relevant limit with respect to the risks of exceeding the operating temperature limit. Consequently, the calculated maximum capacity is generally significantly suboptimal. Furthermore, because the meteorological parameters are chosen a priori, the actual risks of exceeding the operating temperature limit, although limited, are generally not controlled.

[0004] It is therefore increasingly common today to use dynamic determinations of maximum power transmission capacities for high-voltage lines, which involve replacing at least some of the adverse weather parameters with more realistic, locally based environmental data derived from measurements. This is notably the finding of the document entitled "Dynamic line rating systems for transmission lines: topical report," published by the US Department of Energy in April 2014.

[0005] One parameter identified as particularly important, notably in the document entitled "Guide for thermal rating calculations of overhead lines," published by the Cigré organization's "B2-Overhead Lines" study committee, WG B2.43, in December 2014, is wind speed, including its direction and magnitude. Its impact is very significant on the convective cooling of high-voltage lines and therefore on increasing their actual maximum electricity transmission capacity. Unfortunately, this parameter is generally considered difficult to measure locally, and many dynamic methods for determining the maximum capacity of overhead lines attempt to circumvent it.

[0006] A first solution, called CAT-1 and marketed by the company "The Valley Group - a Nexans company", plans to deploy different sensors on a portion of a high-voltage electrical current transmission network: mechanical tension sensors in the form of strain gauges, deployed on each high-voltage line of the considered network portion to estimate its sag, as defined in US patent 5,918,288, and net radiation sensors, deployed on the pylons of the considered network portion to measure environmental data including the impact of wind, as defined in US patent 5,559,430.

[0007] This first solution involves the installation of numerous sensors and significantly complicates the calculations of maximum capacities in the considered portion of the network.

[0008] A second solution, marketed by the company "Ampacimon," also involves deploying sensors on a section of a high-voltage power transmission network. More specifically, these sensors are deployed on each high-voltage line within the network section to measure its deflection using frequency analysis of vibrations, as described in patent application WO 2007 / 031435 A1. Wind sensors, as described in patent application WO 2014 / 090416 A1, can also be placed on the high-voltage lines.

[0009] This second solution also involves the installation of numerous sensors. Furthermore, if one wishes to do without wind sensors, it complicates the calculations of maximum capacities in the considered section of the network since they must then be done in two steps: first, use the predetermined thermal equilibrium relationship based on the assumptions of measured sag, measured electrical current and other known parameters to deduce an indirect estimate of the wind speed on each conductor line of the section of the network; then use the same predetermined thermal equilibrium relationship again based on the indirectly estimated wind speed and the other known parameters to deduce the maximum capacity of each conductor line of the section of the network.The article by Schell et al., entitled "Quantifying the limits of weather-based dynamic line rating methods" and published at the Cigré Canada Conference on Power Systems in Halifax in September 2011, outlines the basis of this complex two-step calculation. Another possibility, described in US document 2014 / 180616, uses wind to determine the ampacity.

[0010] It may therefore be desirable to provide a system for the dynamic determination of maximum electric current transport capacities which makes it possible to overcome at least some of the aforementioned problems and constraints.

[0011] Therefore, a system for dynamically determining maximum electrical current transmission capacities for a portion of a high-voltage electrical current transmission network is proposed, comprising: means for storing a model of the network segment, this model comprising singular points and at least one high-voltage electrical current conductor between these singular points, a predetermined thermal equilibrium relationship, a limit operating temperature of each conductor line and conduction parameters of each conductor line, a computer, having access to the storage means, programmed to calculate at least one maximum capacity value at each singular point of the network segment model from the predetermined thermal equilibrium relationship, each limit operating temperature, each conduction parameter and meteorological parameters, including, in addition, means for the computer to receive wind speed values ​​measured by a set of anemometric stations deployed around the section of the network, the computer then being programmed to: select at least one anemometric station from the set of anemometric stations, apply a wind propagation model from said at least one selected station to the singular points of the network portion model, for the estimation of a wind speed value at each singular point from the received wind speed values, and calculate said at least one maximum capacity at each singular point taking into account said estimated wind speed value at each singular point in the predetermined thermal equilibrium relation.

[0012] Thus, thanks to such a system, a direct estimation of wind speed at several critical points within the considered network segment is provided through the clever application of a propagation model that can be based on a limited number of anemometric sensors. This estimation is then judiciously used in the predetermined thermal equilibrium equation to optimize the calculation of the maximum capacities of the network segment. Many wind propagation models are known to those skilled in the art and can be used. From the simplest to the most sophisticated, depending on the desired performance, they all present surprising results for calculating the maximum electrical current transmission capacities at at least each singular point within a given network segment. These capacities can be more accurately estimated, often upwards, with a potentially limited sensor cost.

[0013] Optionally, the calculator is more specifically programmed to: determine a main wind direction from the received wind speed values, and select the anemometric station, called the leeward station, located furthest upstream in the determined main wind direction.

[0014] Also optional: The predetermined thermal equilibrium relationship is a mathematical equation balancing at least mathematical expressions of gains by Joule effect and solar energy with mathematical expressions of losses by convection and electromagnetic radiation, and the calculator is programmed to take into account said estimated wind speed value at each singular point in the mathematical expression of loss by convection.

[0015] Optionally, the calculator is also programmed to calculate a temperature value at at least one point in the network segment model for which a wind speed value has been estimated, from the predetermined thermal equilibrium relationship, a quantity of electric current carried by the conducting line containing that point in the network segment model, the conduction parameters of that conducting line and the meteorological parameters, taking into account said estimated wind speed value in the predetermined thermal equilibrium relationship.

[0016] Optionally, the calculator is also programmed to trigger the calculation of said at least one maximum capacity at each singular point provided that predetermined criteria of minimum wind speed value and consistency, between them, of the received wind speed values ​​are verified.

[0017] Also optional: The predetermined criterion for minimum wind speed value is defined as follows: the wind speed value provided by the downwind station must be greater in amplitude than a first threshold and each wind speed value provided by an anemometric station other than the downwind station must be greater in amplitude than a second threshold, the second threshold being less than the first threshold, the predetermined criterion for consistency, between them, of the received wind speed values ​​is defined as follows: the received wind speed values ​​being vectorial, the angular difference between the different directions of these vectorial values ​​must remain less than a third threshold and the difference in amplitude between the different norms of these vectorial values ​​must remain less than a fourth threshold.

[0018] Also proposed is an electrical transmission installation with dynamically determined maximum electrical current transmission capacities, comprising: a portion of a high-voltage electric current transmission network comprising local electrical substations and at least one high-voltage electric current transmission or distribution line carried by pylons between these local electrical substations, a set of anemometric stations deployed around the portion of the network, and a system for dynamically determining maximum electric current transport capacities according to the invention.

[0019] A method for dynamically determining maximum electric current transmission capacities for a portion of a high-voltage electric current transmission network is also proposed, comprising the following steps: establishment of a model of the network segment, this model comprising singular points and at least one high-voltage electrical current conductor line between these singular points, calculation of at least one maximum capacitance value at each singular point of the network segment model from a predetermined thermal equilibrium relationship, a limit operating temperature of each conductor line, conduction parameters of each conductor line and meteorological parameters, including the following steps: wind speed value measurements by a set of anemometric stations deployed around the portion of the network, selection of at least one anemometric station from the set of anemometric stations, application of a wind propagation model from said at least one selected station to the singular points of the portion of the network model, for the estimation of a wind speed value at each singular point from the received wind speed values, and calculation of said at least one maximum capacity at each singular point taking into account said estimated wind speed value at each singular point in the predetermined thermal equilibrium relation.

[0020] Optionally: Each conductor line is subject to a default capacity for carrying electric current; the calculation of said at least a maximum capacity at each singular point is triggered provided that predetermined criteria of minimum wind speed value and consistency, between them, of the measured wind speed values ​​are verified; and each default capacity is replaced by the smallest of the maximum capacities calculated at the singular points forming the ends of each respective conductor line, called the optimal capacity, if this optimal capacity is higher than the corresponding default capacity and if the predetermined criteria are verified.

[0021] Also optional: the calculation of said at least one maximum capacity at each singular point is triggered at a time T and established by time projection using the wind propagation model for a time T+H where H>0, between times T and T+H, the calculation of said at least one maximum capacity at each singular point is repeated and established by time projection for time T+H, and at time T+H, said at least one maximum capacity value retained at each singular point is the smallest of the corresponding maximum capacity values ​​calculated between times T and T+H.

[0022] The invention will be better understood with the aid of the following description, given solely by way of example and made with reference to the accompanying drawings in which: there figure 1 schematically represents the general structure of an electrical transmission installation with dynamically determined maximum electrical current transport capacities, according to one embodiment of the invention, the figure 2 illustrates the successive stages of a dynamic determination process for maximum electrical current transmission capacities implemented by the installation of the figure 1 .

[0023] The electrical transmission installation illustrated on the figure 1 includes a portion 10 of a high-voltage electric current transmission network comprising local electrical substations, at least one high-voltage electric current transmission or distribution line between these substations and pylons to support each transmission or distribution line between two substations.

[0024] In this example, network segment 10 comprises four local substations 12, 14, 16, and 18, each defined by the International Electrotechnical Commission (IEC) as "a part of an electrical network, located in the same place, comprising principally the terminations of transmission or distribution lines, electrical equipment, buildings, and, possibly, transformers." A local substation is therefore an element of the electrical transmission network used for both the transmission and distribution of electricity. It allows the voltage to be increased for transmission at high voltage and then reduced for consumption by users (residential or industrial).

[0025] It is possible to establish a model of this section of network 10, consisting of singular points and at least one high-voltage electrical current conductor between these singular points. The local electrical substations 12, 14, 16, and 18, located at the ends of electrical transmission or distribution lines, constitute singular points of section 10 of network. Other singular points can also be identified. For example, by requiring that each conductor between two singular points of the model be homogeneous in terms of operating temperature limit, cable cross-section, and / or straight alignment within + / - 10°, certain pylons of section 10 of network can also constitute singular points. Two such examples are illustrated on the... figure 1 . A first pylon forming a singular point 20 is thus located on a transmission or distribution line between local electrical stations 12 and 14 and a second pylon forming a singular point 22 is located on a transmission or distribution line between local electrical stations 14 and 16.

[0026] In the specific, non-limiting example of the figure 1 : local electrical substation 12 is electrically connected to local electrical substations 14 and 18 by transmission or distribution lines carried by pylons; local electrical substation 14 is electrically connected to local electrical substations 12, 16 and 18 by transmission or distribution lines carried by pylons; and local electrical substation 16 is electrically connected to local electrical substations 14 and 18 by transmission or distribution lines carried by pylons.

[0027] The model of network segment 10 illustrated on the figure 1 It thus comprises six singular points 12, 14, 16, 18, 20, 22 connected by seven homogeneous conducting lines L1 (between singular points 12 and 20), L2 (between singular points 20 and 14), L3 (between singular points 14 and 18), L4 (between singular points 14 and 22), L5 (between singular points 22 and 16), L6 (between singular points 16 and 18), and L7 (between singular points 18 and 12). Other conducting lines exiting the network segment 10 each have one end connected to one of the four local electrical substations 12, 14, 16, and 18. This is, of course, only a simple, non-limiting example provided for a good illustration of the invention.

[0028] The electrical transmission installation illustrated on the figure 1 It also includes a set of anemometric stations 24, 26, 28, and 30 deployed around the network segment 10 to measure wind speed values. Each wind speed value measured by any of the anemometric stations 24, 26, 28, and 30 includes a wind direction and a wind amplitude expressed, for example, in m / s. It is therefore a vector value. These stations can be positioned independently of the various singular points 12, 14, 16, 18, 20, and 22. They have means of transmitting the values ​​they measure, for example, via radio waves.

[0029] Finally, the electrical transmission installation illustrated on the figure 1 includes a system 40 for the dynamic determination of maximum electrical current transmission capacities for the network segment 10. These are the maximum capacities of each of the conductor lines, which apply in particular at their ends, that is to say at each singular point, and for each conductor line connected to each singular point, of the model of the network segment 10. This system 40, as schematically represented on the figure 1 , is for example installed in one of the local electrical substations, in this case substation 16. It could also be installed completely independently of the network portion 10. It is implemented in a computer system such as a conventional computer and includes a processing unit 42 associated in a conventional way with a memory 44 (for example RAM) for the storage of data files and computer programs.

[0030] The processing unit 42 includes a receiver 46 of the measured values ​​emitted by the anemometric stations 24, 26, 28, 30 and a calculator 48, for example a microprocessor, capable of processing the values ​​provided by the receiver 46.

[0031] Memory 44 is partitioned into a first area 50 for storing processing data and a second area 52 for storing computer programs. This partition is purely functional, chosen for a clear presentation of the system 40, but does not necessarily reflect the actual organization of memory 44.

[0032] The first storage area 50 includes, firstly, data 54 relating to the model, detailed above, of the network portion 10. This data includes identification and characterization parameters of singular points 12, 14, 16, 18, 20, 22 and homogeneous conducting lines L1, L2, L3, L4, L5, L6, L7, including, in addition to topological or geographical considerations, a limit operating temperature and conduction parameters for each conducting line.

[0033] The first storage zone 50 also includes data 56 relating to a predetermined thermal equilibrium relationship. This relationship is, for example, a mathematical equation balancing at least mathematical expressions of Joule heating and solar energy gains with mathematical expressions of convection and electromagnetic radiation losses. It may, in particular, be a relationship derived from the steady-state IEEE equation, defined in the document entitled "IEEE standard for calculating the current-temperature relationship of bare overhead conductors," published by the IEEE Power Engineering Society under reference IEEE Std 738™-2006, in January 2007. It may also be a relationship derived from the steady-state Cigré equation, defined in the document entitled "Thermal behaviour of overhead conductors," published by the Cigré organization's "B2-Overhead Lines" study committee, WG 22.12, in August 2002, or specified in the document "Guide for thermal rating calculations of overhead lines" cited above. It takes, for example, the general form: . P J + P S = P C + P R , Or P J is the thermal gain due to the Joule effect. P S the thermal gain from solar energy, P C heat loss by convection and P R Heat loss due to electromagnetic radiation. Refer to the documents cited above for detailed examples of each of these gains or losses.

[0034] The first storage zone 50 also contains data 58 relating to general meteorological parameters for the geographical area in which the network segment 10 is located. These parameters can be chosen a priori as the most unfavorable possible for the environment of the network segment 10. They may be based on zoning, statistical calculations, regular measurements, etc. For example, they include ambient temperature and sunshine values ​​that are dependent on location and season. It should be noted that some of the data 58 can alternatively be replaced or dynamically updated by values ​​provided to the computer 48 via the receiver 46. In particular, outdoor temperature values ​​at different points of the network segment 10 can be dynamically provided to the computer 48 for better processing by the latter through their inclusion in the predetermined thermal equilibrium relationship 56.

[0035] The first storage area 50 finally contains data 60 relating to a wind propagation model. Many propagation models, ranging from simple to sophisticated, are known. For example, it could be a proportional linear projection model in which the propagation speed is arbitrarily taken to be equal to the amplitude of the wind speed, while the direction of propagation, considered to be planar, is that of the wind. Such a model, particularly simple, is far from perfect, but it is already capable of providing good results for a dynamic estimation of the maximum capacities mentioned previously. It allows the construction of a history of wind speed values ​​for each point of the model 54 of the network segment 10, and in particular for each singular point. This history is progressively enriched as measurements are taken by the anemometric stations 24, 26, 28, and 30.

[0036] The second storage area 52 as illustrated on the figure 1 It functionally comprises four computer programs or four functions of the same computer program 62, 64, 66, 68. It should be noted that the computer programs 62, 64, 66, 68 are presented as distinct, but this distinction is purely functional. They could just as easily be grouped in all possible combinations into one or more software programs. Their functions could also be at least partially microprogrammed or micro-wired into dedicated integrated circuits. Thus, alternatively, the computer device implementing the processing unit 42 and its memory 44 could be replaced by an electronic device composed solely of digital circuits (without a computer program) to perform the same actions.

[0037] The first computer program 62 comprises lines of instructions for executing a selection of an anemometric station, called the leeward station, from among the available stations 24, 26, 28, 30, based on wind speed values ​​measured and transmitted to the microprocessor 48 via the receiver 46. A non-limiting example of the operation of this first program will be detailed with reference to the figure 2 Alternatively, and depending on the complexity of the wind propagation model chosen, such a program could select several anemometric stations from those available.

[0038] The second computer program 64 contains lines of instruction for applying the wind propagation model 60 from the downwind station to the singular points 12, 14, 16, 18, 20, 22 of the network segment model 54 10, for estimating successive wind speed values ​​at each singular point from successive wind speed values ​​measured by the downwind station. A non-limiting example of the operation of this second program will be detailed with reference to the figure 2 .

[0039] The third computer program 66 includes lines of instructions for performing the calculation of at least one maximum electrical current carrying capacity value at each singular point 12, 14, 16, 18, 20 and 22 of the model 54 of network segment 10 from: of the predetermined thermal equilibrium relation 56, of each operating limit temperature and of each network conduction parameter recorded with the model data 54 of the network portion 10, of the general meteorological parameters 58, and of possible meteorological parameters dynamically supplied to the computer 48, such as measured outside temperatures, taking into account, in the predetermined thermal equilibrium relation 56, the wind speed values ​​estimated at all singular points 12, 14, 16, 18, 20, 22 by execution of the second program 64.

[0040] More specifically, and in accordance with the teachings of the document "Guide for thermal rating calculations of overhead lines" cited above, wind speed values ​​can be taken into account in the mathematical expression for convection loss. P C of the expression P J + P S = P C + P R .

[0041] In the example of the figure 1 Two maximum capacitance values ​​can be calculated at singular point 12, one for conductor line L1 and the other for conductor line L7. Three maximum capacitance values ​​can be calculated at singular point 14, one for conductor line L2, one for conductor line L3, and the last for conductor line L4. Two maximum capacitance values ​​can be calculated at singular point 16, one for conductor line L5 and the other for conductor line L6. Three maximum capacitance values ​​can be calculated at singular point 18, one for conductor line L6, one for conductor line L3, and the last for conductor line L7. Two maximum capacitance values ​​can be calculated at singular point 20, one for conductor line L1 and the other for conductor line L2.Two maximum capacitance values ​​can be calculated at the singular point 22, one for the conducting line L4, the other for the conducting line L5.

[0042] The fourth computer program 68 includes lines of instructions for the optional execution of the calculation of an actual temperature value at each singular point 12, 14, 16, 18, 20 and 22 of the model 54 of the network portion 10 from: of the same predetermined thermal equilibrium relation 56, of a quantity of electric current actually carried by each conducting line and of each network conduction parameter recorded with the data of the model 54 of network segment 10, of the general meteorological parameters 58, and of possible meteorological parameters dynamically supplied to the computer 48, such as measured outside temperatures, taking into account, in the predetermined thermal equilibrium relation 56, the wind speed values ​​estimated at all singular points 12, 14, 16, 18, 20, 22 by execution of the second program 64.

[0043] A method for dynamically determining maximum electrical current transmission capacities in network segment 10, implemented by executing computer programs 62, 64, 66, 68 using microprocessor 48, will now be detailed with reference to the figure 2 .

[0044] During a preliminary step 100 of system preparation 40, the network segment 10 to which this dynamic determination of maximum capacities is to be applied is defined by its perimeter, the local electrical substations it contains, and the transmission or distribution lines between these substations. The set of anemometric stations deployed around the defined network segment 10 is also selected.

[0045] Advantageously, but without constraint or obligation, such a portion of network 10 exhibits one or more of the following characteristics: its geographical perimeter is not too extensive, so that it presents homogeneous geographical characteristics in terms of relief (it must remain relatively flat) and obstacles (they must be as few as possible), it constitutes an "electrical pocket": this means that it constitutes an autonomous zone responding to homogeneous local electrotechnical rules in terms of power supply, transport and supply of electricity, it is powered by a significant wind farm generating transport capacity demands that increase with wind strength: this is the whole point of the invention, being able to dynamically estimate upwards the maximum transport capacities of the network portion 10 as a function of wind speed.

[0046] In a subsequent step 102 of modeling the previously defined network segment 10, the model 54 of this network segment 10 is established and stored in memory 44 from a map of the local substations and the transmission or distribution lines it contains. This step 102 can be executed automatically using a computer program (not shown) specifically implemented in the system 40. It mainly involves determining the singular points of the model 54: these include all the local substations as well as certain pylons located at the ends of homogeneous sections of high-voltage lines in terms of straight alignment (an angular deviation of + / - 10% may, for example, be allowed), cable cross-sections, and operating temperature limits. This yields, for example, the model 54 illustrated in the figure 1 by the singular points 12, 14, 16, 18, 20, 22 and the homogeneous conducting lines L1, L2, L3, L4, L5, L6, L7.

[0047] During a parameterization step 104, which can occur before, during, or after steps 100 and 102, at least one minimum wind speed value (Vmin), one maximum wind speed variation (ΔVmax) between anemometric stations, and one maximum angular variation of wind direction (Δθmax) between anemometric stations are predetermined. The Vmin value defines a minimum wind speed below which it is not deemed necessary to run computer programs 66 and 68, or even computer program 64, thus imposing a first predetermined criterion that conditions the triggering of the calculation of the maximum electrical current transmission capacities at each singular point.The values ​​ΔV max and Δθ max define maximum values ​​for variations in measurements between anemometric stations, beyond which it is not deemed useful to execute computer programs 66 and 68, or even computer program 64. This imposes a second predetermined criterion for the consistency of these measurements, which conditions the triggering of the calculation of the maximum electrical current transmission capacities at each singular point. These criteria allow for optimal use of the process. figure 2 knowing that it provides good results when the wind speed measurements provided by the different anemometric stations are consistent with each other and when the measured wind exceeds a certain value to be determined specifically according to each context in which the invention is implemented.

[0048] Then, during a measurement step 106, each anemometer station 24, 26, 28, 30 locally measures a succession of wind speed values. Each measured value is vectorized and transmitted to the receiver 46 of the system 40.

[0049] In step 108, the microprocessor 48 of the system 40 triggers the execution of the first computer program 62. During this step, it determines a principal wind direction from the latest received wind speed values. This can be done in a manner known per se by calculating the angular mean of the wind directions measured by the different anemometric stations 24, 26, 28, 30. From this principal wind direction value, the microprocessor 48 determines the leeward anemometric station, that is, the one among stations 24, 26, 28, 30 that is located furthest upstream in the determined principal wind direction.

[0050] Step 108 is followed by a test 110 during which the trigger criteria for calculating the maximum electrical current transmission capacities at each singular point of the network segment 10 are verified. The first criterion, relating to the value Vmin, is broken down, for example, into two criteria based on thresholds Vmin[1] and Vmin[2] according to which the wind speed value provided by the downwind station must be greater in amplitude than Vmin[1], and each wind speed value provided by an anemometric station other than the downwind station must be greater in amplitude than Vmin[2], with Vmin[2] < Vmin[1]. For example, Vmin[1] = 5 m / s and Vmin[2] = 2 m / s could be chosen. The second criterion, of consistency, requires that the angular difference between the different directions of the measured vector values ​​remains less than Δθ max and the difference in amplitude between the different norms of the measured vector values ​​remains less than ΔV max.For example, a deviation of 10% around the average values ​​may be tolerated.

[0051] When these criteria are met, the process moves to the next step 112. Otherwise, it returns to step 106 for a new series of measurements.

[0052] During step 112, a time initialization is triggered by the microprocessor 48. A first time T is established, from which the dynamic calculation of maximum capacities by time projection using the wind propagation model 60 is initiated for a second time T+H, where H>0. From this second time, these calculated maximum capacities can, if necessary, be applied to the network segment 10. Considering Dmax as the maximum distance between the downwind station and the furthest singular point of the network segment 10, and given that Vmin [1] is the minimum speed measured at the output of step 110, to ensure that the wind speed at each singular point of the network segment 10 can be estimated by time projection at time T+H, it is preferable to ensure that H ≥ Dmax / Vmin [1]. Thus, H = 90 min is sufficient for a maximum distance of 27 km.

[0053] Furthermore, during this same step 112, a time index t, incrementable by steps of Δt between T and T+H, is initialized to t=T. For H = 90 min, we can, for example, choose Δt = 6 min.

[0054] In addition, since each conductor line is subject to a default capacity for the transport of electric current, for example determined according to the techniques known in the prior art, a default operational capacity can be associated with each of the singular points of the network portion 10 for each of the conductor lines to which it is connected.

[0055] Finally, for each singular point and each conducting line to which it is connected, a value C of maximum capacitance is initialized to infinity (+∞).

[0056] Step 112 is followed by a loop of steps 114, 116, 118, 120, 122, 124, 126, 128, 130 which is executed for at least each of the singular points of the model 54 of the network portion 10 and for each of the conducting lines to which it is connected.

[0057] Thus, for a singular point considered and for a conducting line considered to which it is connected, during step 114, carried out by execution of the second computer program 64, the wind propagation model is applied to at least one wind speed value measured by the leeward anemometric station during a period ending at time t to determine by time projection, if possible given the measured speeds and the distance between the leeward station and the singular point considered, a wind speed value at the singular point considered at time T+H.

[0058] Then, during a test step 116, the first trigger criterion for calculating the maximum electrical current transport capacity at the singular point considered and for the conducting line considered can again be checked on the basis of the wind speed value determined in step 114. For example, it must be greater in amplitude than V min [1],

[0059] If this is not the case, the process proceeds to a subsequent step 118 in which the maximum capacity at the singular point considered at time t is set to its default operational value. Then it proceeds to a step 120 of incrementing from t to t+Δt before returning to step 114.

[0060] If the wind speed value determined in step 114 satisfies the criterion of step 116, the process proceeds to step 122, which dynamically calculates the maximum electrical current-carrying capacity at the singular point considered for the conducting line. This is done by executing the third computer program 66, taking into account the wind speed value determined in step 114 in the predetermined thermal equilibrium equation 56, and also considering the properties of the conducting line. A maximum capacity value can then be calculated at time t for the time T+H.

[0061] The process then proceeds, if necessary, to an optional step 124 of dynamically calculating an actual temperature value at the specific point considered for the conductor line by executing the fourth computer program 68, taking into account the same parameters as in the previous step and the actual quantity of electrical current carried. This optional step can, for example, be used to validate the accuracy of the dynamic calculation of maximum capacities by comparing the estimated actual temperature values ​​with actual temperature measurements taken by sensors. More generally, this calculation step can be performed at any point along the network segment 10 equipped with a temperature sensor or any other means of evaluating cable temperature (directly or indirectly by measuring the cable's sag, mechanical tension, or vibration frequency, for example).

[0062] In a subsequent test step 126, the maximum capacity dynamically calculated in step 122 is compared to the default operational capacity of the considered singular point for the conductor line. If the dynamically calculated value is less than or equal to the default operational capacity, the latter is retained as the value calculated in step 122, and the process then returns to step 120 as long as the time index t is less than T+H.

[0063] If the dynamically calculated value is greater than the default operational capacity or if time T+H has been reached in step 126, the process proceeds to a subsequent step 128. During this step 128, the maximum capacity dynamically calculated in step 122 is compared to the value C. If it is greater, C remains unchanged; otherwise, C is replaced by this maximum capacity calculated at time t for time T+H during step 122.

[0064] Next, a test step 130 is performed on the time index t. If the latter is less than T+H, the process returns to step 120.

[0065] Otherwise, it proceeds to a final step 132 during which the last value of C is retained as the maximum electrical transmission capacity at time T+H at the singular point considered for the conductor line in question. This is, given step 128, the smallest of the dynamically calculated maximum capacity values ​​that passed the test in step 126. Furthermore, once the loop of steps 114 to 130 has been executed for at least each of the singular points of model 54 of network segment 10, the calculated maximum capacities may be revised downwards as follows: for each conductor line, the dynamically calculated maximum capacities for time T+H at its two ends are compared, and the lower value is ultimately retained at the two relevant singular points for the conductor line in question.Thus, each default capacity is replaced by the smallest of the maximum capacities calculated at the singular points forming the ends of each respective conducting line, called the optimal capacity, if this optimal capacity is higher than the corresponding default capacity and if the predetermined criteria indicated previously are verified.

[0066] It is then up to an operator of the network portion 10 to apply all or part of the optimal capacity values ​​from time t+H in order to respond to requests from electricity suppliers or consumers.

[0067] Following step 132, the process returns to step 106 for a new series of measurements.

[0068] It is clear that a dynamic system for determining maximum electrical current transmission capacities, such as the one described above, allows for the simple and clever integration of wind speed measurements to obtain a more favorable estimate of these maximum capacities. Given that the cooling effect of wind is accompanied by an increasing electricity generation capacity when the relevant section of the grid is connected to a wind farm, it is particularly in this context that the invention demonstrates its best results.

[0069] It should also be noted that the invention is not limited to the embodiment described above.

[0070] In particular, the topology of the network portion under consideration can be completely arbitrary, that of the figure 1 having been chosen for illustrative purposes only because of its simplicity.

[0071] Furthermore, anemometric stations 24, 26, 28, and 30 have been illustrated as being arranged independently of network segment 10, but they could also be installed in at least some of the local electrical substations, particularly those located on the periphery of the network segment (which is the case for the four substations illustrated on the figure 1 ).

[0072] Furthermore, the linear projection wind propagation model 60, taken as an advantageous example, could be replaced by any other known model, the adaptation of the invention to a known propagation model other than the one presented previously being within the reach of a person skilled in the art.

[0073] Furthermore, the detailed procedure is also described in reference to the figure 2 can be implemented in a large number of variations that it is impossible to list exhaustively; only the following general steps must necessarily be implemented: establishment of a model of the network segment, this model being made up of singular points and at least one high-voltage electrical current conductor line between these singular points, measurements of wind speed values ​​by a set of anemometric stations deployed around the network segment, selection of at least one anemometric station from the set of anemometric stations, application of a wind propagation model from said at least one selected station to the singular points of the network segment model, for the estimation of a wind speed value at each singular point from the received wind speed values, and calculation of at least one maximum capacity value at each singular point of the network segment model from a predetermined thermal equilibrium relationship, a limit operating temperature of each conductor line,of conduction parameters of each conducting line and meteorological parameters, taking into account the estimated wind speed value at each singular point in the predetermined thermal equilibrium relationship.

[0074] It should be noted in particular that maximum capacity calculations can be performed for points in the network segment model other than singular points, notably along at least part of the conducting lines.

[0075] It will be more generally apparent to a person skilled in the art that various modifications can be made to the embodiment described above, in light of the instruction just disclosed to them. In the claims that follow, the terms used shall not be interpreted as limiting the claims to the embodiment set forth in this description, but shall be interpreted to include all equivalents that the claims aim to cover by virtue of their formulation and whose prediction is within the grasp of a person skilled in the art by applying their general knowledge to the implementation of the instruction just disclosed to them.

Claims

1. A system (40) for dynamically determining maximum electric current carrying capacities relative to a portion (10) of a high-voltage electric current transmission network, comprising: - means (44) for storing a model (54) of the network portion, this model (54) comprising singular points (12, 14, 16, 18, 20, 22) and at least one high-voltage electric current-carrying line (L1, L2, L3, L4, L5, L6, L7) between these singular points, a predetermined thermal equilibrium relationship (56), an operating limit temperature of each current-carrying line and conduction parameters of each current-carrying line, - a computer (48), having access to the storing means (44), programmed (62, 64, 66, 68) to calculate at least one maximum capacity value at each singular point (12, 14, 16, 18, 20, 22) of the model (54) of the network portion on the basis of the predetermined thermal equilibrium relationship (56), of each operating limit temperature, of each conduction parameter and of weather parameters (58), characterized in that it further comprises means (46) for receiving, by the computer (48), wind speed values measured by a set of wind measurement stations deployed around the network portion, and in that the computer (48) is programmed to: - select at least one wind measurement station in the set of wind measurement stations, - apply a model (60) of wind propagation from said at least one selected station towards the singular points (12, 14, 16, 18, 20, 22) of the model (54) of the network portion, in order to estimate a wind speed value at each singular point on the basis of the wind speed values received, and - calculate said at least one maximum capacity at each singular point taking into account said wind speed value estimated at each singular point in the predetermined thermal equilibrium relationship (56).

2. The system (40) for dynamically determining maximum electric current carrying capacities as claimed in claim 1, wherein the computer (48) is more precisely programmed (62) to: - determine a main wind direction on the basis of the wind speed values received, and - select the wind measurement station, referred to as the leeward station, located the furthest upstream in the main wind direction determined.

3. The system (40) for dynamically determining maximum electric current carrying capacities as claimed in claim 1 or 2, wherein: - the predetermined thermal equilibrium relationship (56) is a mathematical equation that balances at least mathematical expressions of gains via the Joule effect and solar energy with mathematical expressions of losses via convection and electromagnetic radiation, and - the computer (48) is programmed (66, 68) to take into account said wind speed value estimated at each singular point in the mathematical expression of loss via convection.

4. The system (40) for dynamically determining maximum electric current carrying capacities as claimed in any of claims 1 to 3, wherein the computer (48) is further programmed (68) to calculate a temperature value in at least one point of the model (54) of the network portion for which a wind speed value has been estimated, on the basis of the predetermined thermal equilibrium relationship (56), a quantity of electric current carried by the current-carrying line comprising this point of the model (54) of the network portion, the conduction parameters of this current-carrying line and weather parameters (58), taking into account said estimated wind speed value in the predetermined thermal equilibrium relationship (56).

5. The system (40) for dynamically determining maximum electric current carrying capacities as claimed in any of claims 1 to 4, wherein the computer (48) is programmed to trigger the calculation of said at least one maximum capacity at each singular point with the conditions that predetermined criteria of a minimum value for the wind speed and coherency, between them, of the wind speed values received are upheld.

6. The system (40) for dynamically determining maximum electric current carrying capacities as claimed in claim 5, wherein: - the predetermined criterion for the minimum value of the wind speed is defined in the following way: the wind speed value supplied by the leeward station must be greater in amplitude than a first threshold and each wind speed value supplied by a wind measurement station other than the leeward station must be greater in amplitude than a second threshold, with the second threshold being less than the first threshold, - the predetermined criterion of coherency, between them, of the wind speed values received is defined in the following way: as the wind speed values received are vectorial, the angular difference between the various directions of these vector values must remain less than a third threshold and the difference in amplitude between the various norms of these vector values must remain less than a fourth threshold.

7. An electric transmission installation with dynamic determination of maximum electric current carrying capacities, comprising: - a portion (10) of a high-voltage electric current transmission network comprising local electrical substations (12, 14, 16, 18) and at least one high-voltage electric current distribution or transmission line carried by pylons (20, 22) between these local electrical substations, - a set of wind measurement stations (24, 26, 28, 30) deployed around the network portion (10), and - a system (40) for dynamically determining maximum electric current carrying capacities as claimed in any of claims 1 to 6.

8. A method for dynamically determining maximum electric current carrying capacities relative to a portion (10) of a high-voltage electric current transmission network, comprising the following steps: - establishing (102) a model (54) of the network portion (10), this model (54) comprising singular points (12, 14, 16, 18, 20, 22) and at least one high-voltage electric current-carrying line (L1, L2, L3, L4, L5, L6, L7) between these singular points, - calculating (114, 116, 118, 120, 122, 124, 126, 128, 130, 132) at least one maximum capacity value at each singular point (12, 14, 16, 18, 20, 22) of the model (54) of the network portion (10) on the basis of a predetermined thermal equilibrium relationship (56), an operating limit temperature of each current-carrying line (L1, L2, L3, L4, L5, L6, L7), conduction parameters of each current-carrying line (L1, L2, L3, L4, L5, L6, L7) and weather parameters (58), characterized in that it further comprises the following steps: - measuring (106) wind speed values by a set of wind measurement stations (24, 26, 28, 30) deployed around the network portion (10), - selecting (108) at least one wind measurement station in the set of wind measurement stations (24, 26, 28, 30), - applying (114) a model (60) of wind propagation from said at least one selected station towards the singular points (12, 14, 16, 18, 20, 22) of the model (54) of the network portion (10), in order to estimate a wind speed value at each singular point on the basis of the wind speed values received, and - calculating (114, 116, 118, 120, 122, 124, 126, 128, 130, 132) said at least one maximum capacity at each singular point taking into account said wind speed value estimated at each singular point in the predetermined thermal equilibrium relationship (56).

9. The method for dynamically determining maximum electric current carrying capacities as claimed in claim 8, wherein: - each current-carrying line (L1, L2, L3, L4, L5, L6, L7) is subjected to an electric current carrying default capacity, - the calculating (114, 116, 118, 120, 122, 124, 126, 128, 130, 132) of said at least one maximum capacity at each singular point is triggered (112) with the condition (110) that predetermined criteria of a minimum value for the wind speed and coherency, between them, of the wind speed values measured are upheld, and - each default capacity is replaced (128, 132) with the smallest of the maximum capacities calculated at the singular points forming the ends of each respective current-carrying line, referred to as optimum capacity, if this optimum capacity is higher than the corresponding default capacity and if the predetermined criteria are upheld.

10. The method for dynamically determining maximum electric current carrying capacities as claimed in claim 9, wherein: - the calculating (114, 116, 118, 120, 122, 124, 126, 128, 130, 132) of said at least one maximum capacity at each singular point is triggered (112) at an instant T and established by time projection (114) using the model (60) of wind propagation for an instant T+H where H>0, - between the instants T and T+H, the calculating (114, 116, 118, 120, 122, 124, 126, 128, 130, 132) of said at least one maximum capacity at each singular point is repeated and established by time projection for the instant T+H, and - at the instant T+H, said at least one maximum capacity value retained at each singular point is the smallest of the corresponding maximum capacity values calculated between the instants T and T+H.