MONITORING INSTALLATION FOR A PORTION OF A HIGH-VOLTAGE ELECTRICAL TRANSMISSION NETWORK

Abstract

This monitoring installation for a portion of a high-voltage power transmission network comprises: several local substations (10, 12, 14, 16) for connecting high-voltage lines (l1, l2, l3, l4, l5), each local substation implementing a first communication protocol dedicated to internal communication between the electrical devices (18, 20, 22, 24) it contains; at least one remote monitoring site (28, 30, 32) connected to each of the local substations by a remote control network (26) implementing a second communication protocol dedicated to this remote control. One of the local substations (10, 12, 14, 16), referred to as the main substation (12), includes additional automated monitoring equipment (34) configured to receive, process, and transmit data conforming to the first communication protocol.This main electrical substation (12) is connected to each of the other local electrical substations (10, 14, 16) by an additional monitoring network (36), separate from the remote control network (26), implementing the first communication protocol.

Description

[0001] The present invention relates to a monitoring installation for a portion of a high-voltage electrical current transmission network.

[0002] More specifically, it relates to an installation comprising: several local electrical substations for connecting high-voltage lines, each located at a plurality of nodes in the network portion, each local electrical substation being electrically connected to at least one end of the high-voltage line and implementing a first communication protocol dedicated to internal communication between the electrical devices it contains, and at least one remote monitoring site connected to each of the local electrical substations by a remote control network implementing a second communication protocol dedicated to this remote control.

[0003] Remote control involves the transmission of remote control data from the remote monitoring site(s) to each local substation, and of remote signaling and telemetry data from the local substations to the remote monitoring site(s), enabling operator-controlled management of the network segment's status. Specifically, each local substation has an automated mechanism for detecting when at least one local maximum current transmission capacity is exceeded on the high-voltage line(s) connected to it. By transmitting this information to the remote monitoring site(s), not only automated local management of such exceedances is possible, but also more comprehensive action on the network segment, for example, to trigger production reductions, consumption load shedding, or high-voltage line outages.Documents EP1830450 and EP2840675 disclose this prior art.

[0004] Unfortunately, with this type of infrastructure, it is not possible to have all the information available at each local electrical substation on the network segment available at a remote site. The resulting actions are therefore limited.

[0005] Furthermore, certain decisions made in the event of network congestion, for example during production or consumption peaks, have significant consequences and may require a high level of responsiveness from the operators of the monitoring site(s). The risks of non-compliant actions or actions that do not optimally utilize the actual capacity of the network segment are therefore increased.

[0006] It may therefore be desirable to provide a monitoring installation for a portion of the high-voltage electrical current transmission network which makes it possible to overcome at least some of the aforementioned problems and constraints.

[0007] Therefore, a monitoring system for a portion of a high-voltage electrical transmission network is proposed, comprising: several local electrical substations for connecting high-voltage lines, each located at a plurality of nodes in the network portion, each local electrical substation being electrically connected to at least one end of a high-voltage line and implementing a first communication protocol dedicated to internal communication between the electrical devices it contains, at least one remote monitoring site connected to each of the local electrical substations by a remote control network implementing a second communication protocol dedicated to this remote control, in which: One of the local electrical substations, called the main electrical substation, includes additional automated monitoring means configured to receive, process and transmit data in accordance with the first communication protocol; this main electrical substation is connected to each of the other local electrical substations by an additional monitoring network, separate from the remote control network, implementing the first communication protocol.

[0008] Thus, thanks to such an installation, all information encoded according to the first communication protocol and initially intended for internal exchanges within each local electrical substation, invisible from the remote monitoring site, is advantageously exploited on a network. By directing this information to one of the local electrical substations, which is itself configured to receive, process, and transmit data encoded according to this first protocol, and by equipping this substation with additional automated monitoring capabilities, the monitoring of the network segment is strengthened and improved.

[0009] Optionally, the additional monitoring means for the main electrical substation include: means for storing a model of the network portion, this model comprising singular points and at least one high-voltage electric current conducting line between these singular points, a predetermined thermal equilibrium relationship, a limit operating temperature of each conducting line and conduction parameters of each conducting line, a computer, having access to the storage means, programmed for a dynamic determination of maximum optimized electric current transport capacities in the high-voltage lines of the network portion from the predetermined thermal equilibrium relationship, each limit operating temperature, each network conduction parameter and meteorological parameters, and means for transmitting the maximum optimized capacities to the respective local electrical substations concerned in accordance with the first communication protocol.

[0010] Optionally, each local electrical substation also includes: a local monitoring mechanism for exceeding at least one local maximum capacity value, and an additional local monitoring automaton associated with local memory and configured to: receive and store in local memory each optimized maximum capacity value relating to a high-voltage line one end of which is electrically connected to that local electrical substation, compare each received and stored optimized maximum capacity value to said at least one local maximum capacity value, and replace the local monitoring mechanism with an optimized monitoring mechanism for exceeding at least one optimized maximum capacity value stored in local memory under certain predetermined conditions.

[0011] Also optional: Each local substation includes a gateway configured to transcode remote control data conforming to the second communication protocol into remote control signals usable internally by each local substation and to transcode remote signaling and telemetry signals emitted internally by each local substation into remote signaling and telemetry data conforming to the second communication protocol. Each gateway includes additional means for transcoding data conforming to the second communication protocol into data conforming to the first communication protocol, a communication port with the electrical devices in the local substation in which it is installed, and a port for accessing the supplementary monitoring network. Each gateway is configured to transmit to the main substation, via the supplementary monitoring network,at least a portion of the remote control, remote signaling and telemetry data transcoded according to the first communication protocol with other data originating from the electrical devices contained in the local electrical substation in which it is installed.

[0012] Optionally, the additional local monitoring PLC for each local electrical substation and its associated local memory are also implemented in the gateway of that local electrical substation.

[0013] Optionally, additional automated monitoring means are also implemented in the gateway of the main electrical substation.

[0014] Optionally, the main electrical substation also includes automated means for detecting, locating and processing faults in the network portion from data transmitted by each gateway via the additional monitoring network.

[0015] Optionally, the main electrical substation also includes automated means of managing congestion in the network portion based on data transmitted by each gateway via the additional monitoring network; this management includes issuing requests for modulated production reductions, consumption shedding, or interruptions of transit on high-voltage lines.

[0016] Optionally, automated means for detecting, locating and processing faults, as well as automated means for managing congestion, are also implemented in the additional monitoring means of the main electrical substation.

[0017] Also optional: The first communication protocol complies with the IEC 61850 standard, and the second communication protocol complies with the IEC 60870-5 standard, specifically IEC 60870-5-104.

[0018] 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 a monitoring installation for a portion of a high-voltage electrical current transmission network, according to an embodiment of the invention, the figure 2 schematically represents the general structure of automated additional monitoring equipment located in one of the local electrical substations of the installation. figure 1 , there figure 3 schematically and partially represents a local electrical substation structure of the installation of the figure 1 , and the figure 4 illustrates the successive stages of a monitoring process implemented by the installation of the figure 1 .

[0019] The installation is schematically illustrated on the figure 1 It comprises several local electrical substations forming the nodes of a portion of a high-voltage power transmission network. Each local substation is electrically connected to at least one end of the high-voltage line in that portion of the network. Each high-voltage line is a power transmission or distribution line and extends from one local substation to another in the network portion, supported by pylons.

[0020] In this specific, non-limiting example, network segment 10 comprises four local substations 10, 12, 14, and 16, 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 current 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).The relative arrangement of the four local electrical substations 10, 12, 14, and 16 is arbitrary and does not correspond to the illustration in which they are aligned for convenience. They form the four vertices of an arbitrary quadrilateral, each side of which may measure several kilometers or even tens of kilometers.

[0021] In this particular, non-limiting example, the network portion includes a high-voltage line L1 extending between substation 10 and substation 12, a high-voltage line L2 extending between substation 12 and substation 14, a high-voltage line L3 extending between substation 14 and substation 16, a high-voltage line L4 extending between substation 16 and substation 10, and a high-voltage line L5 extending between substation 12 and substation 16.

[0022] Local substation 10 comprises a number of electrical devices, symbolized by reference 18. These devices are known in themselves and will not be described in detail. They are interconnected and managed locally using a dedicated primary communication protocol, generally one conforming to IEC 61850. Similarly: local substation 12 comprises a number of electrical devices, symbolized by reference 20, interconnected and managed locally using the same primary communication protocol; local substation 14 comprises a number of electrical devices, symbolized by reference 22, interconnected and managed locally using the same primary communication protocol; and local substation 16 comprises a number of electrical devices, symbolized by reference 24, interconnected and managed locally using the same primary communication protocol.

[0023] The installation is schematically illustrated on the figure 1 Furthermore, it includes at least one remote monitoring site connected to each of the local electrical substations 10, 12, 14, and 16 by a remote control network 26 implementing a second communication protocol dedicated to this remote control. This may be a communication protocol conforming to the IEC 60870-5 standard, in particular IEC 60870-5-104. Three remote sites 28, 30, and 32 are shown as an example in a two-level tree structure. A general remote monitoring site 28 communicates with two secondary remote monitoring sites 30 and 32, which are themselves directly connected to local electrical substations. The secondary remote monitoring site 30 is thus in direct communication with the local electrical stations 10, 12 and 14 of the illustrated network portion while the secondary remote monitoring site 32 is in direct communication with the local electrical station 16, these communications being in accordance with the second protocol for remote control.

[0024] According to the invention, additional monitoring is provided by one of the local electrical substations, in this case substation 12, which includes automated additional monitoring means 34 configured to receive, process, and transmit data conforming to the first communication protocol. These means 34 may take the form of a computer. More generally, they include a computer associated with means for storing processing data and computer programs. For this reason, substation 12 is designated as the main electrical substation. It is connected to each of the other local electrical substations 10, 14, and 16 by an additional monitoring network 36, separate from the remote control network 26, implementing the first communication protocol.

[0025] Thus, each local substation is equipped with a gateway comprising an access port P1 to the supplementary monitoring network 36, enabling exchanges compliant with the first communication protocol between local substations, and an access port P2 to the remote control network 26, enabling exchanges compliant with the second communication protocol between the remote monitoring sites 28, 30, 32 and each local substation. The main substation 12 may include a second access port P1 to the supplementary monitoring network 36 for its automated supplementary monitoring equipment 34. Alternatively, this equipment may also access the supplementary monitoring network 36 via the same access port P1 as the electrical devices 20.

[0026] The automated means of additional monitoring 34 of the main station 12 are functionally detailed on the figure 2 according to one possible embodiment of the invention. More specifically, they are designed to: dynamic determination and management of maximum optimized electric current transport capacities relating to the network portion under consideration, automated detection, localization and processing of faults in the network portion from data transmitted via the supplementary monitoring network 36, and automated management of congestion in the network portion from data also transmitted via the supplementary monitoring network 36, this management including the issuing of requests for modulated production reductions, consumption shedding or interruptions of transits on high voltage line.

[0027] Advantageously but optionally, they perform the dynamic determination of maximum optimized capacities from wind speed values ​​that they regularly receive in real time, for example from measurements taken by a set of anemometric stations deployed around the portion of the network.

[0028] These means 34 are implemented in a computer system such as a conventional computer and therefore include a processing unit 38 associated with a memory 40 (for example, RAM memory) for the storage of data files and computer programs.

[0029] The processing unit 38 includes an interface 42 conforming to the first communication protocol and suitable for connection to one of the access ports P1 of the main electrical substation 12. It also optionally includes a receiver 44 of wind speed values ​​supplied regularly (for example by radio waves) and a computer 46, for example a microprocessor, suitable for processing the values ​​supplied by the interface 42 and the receiver 44.

[0030] Memory 40 is partitioned into a first area 48 for storing processing data and a second area 50 for storing computer programs. This partition is purely functional, chosen for a clear presentation of the means 34, but does not necessarily reflect the actual organization of memory 40.

[0031] The first storage area 48 initially contains data 52 relating to a model of the considered network segment. This model includes singular points, notably the nodes constituted by the local electrical substations 10, 12, 14, and 16, and at least one high-voltage electrical current conductor between these singular points. This data includes identification and characterization parameters for the singular points and conductors of the model, including, in addition to topological or geographical considerations, a maximum operating temperature and conduction parameters for each conductor.

[0032] The first storage area 48 also includes data 54 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 entitled "Guide for thermal rating calculations of overhead lines", published by the "B2-overhead lines" study committee of the Cigré organization, WG B2.43, in December 2014. 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.

[0033] The first storage area 48 also includes data 56 relating to general meteorological parameters for the geographical area in which the network segment under consideration is located. These parameters can be chosen a priori as the most unfavorable possible for the environment of the network segment. They may be based on zoning, statistical calculations, regular measurements, etc. They include, for example, ambient temperature and sunshine values ​​that vary depending on the location and season.

[0034] The first storage area 48 optionally includes data 58 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 optimized capacities mentioned previously. It allows the construction of a history of wind speed values ​​for each point of the model 52 of the network segment, and in particular for each singular point. This history is progressively enriched as wind speed measurements are taken.

[0035] The second storage area 50 as illustrated on the figure 1 It functionally comprises four computer programs or four functions of the same computer program 60, 62, 64, 66. It should be noted that the computer programs 60, 62, 64, 66 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, as an alternative, the computer device implementing the processing unit 38 and its memory 40 could be replaced by an electronic device composed solely of digital circuits (without a computer program) to perform the same actions.

[0036] The first computer program 60 includes lines of instruction for applying the wind propagation model 58 from at least one of the anemometric stations from which the wind speed measurements are taken to the singular points of the network segment model 52, for estimating successive wind speed values ​​at each singular point from successive measured wind speed values. A non-limiting example of the operation of this first program will be detailed with reference to the figure 4 .

[0037] The second computer program 62 includes lines of instructions for performing the calculation of at least one optimized maximum electrical current transmission capacity value at each singular point of the network segment model 54, and in particular at each node of the network segment, from: of the predetermined thermal equilibrium relation 54, of each operating limit temperature and of each network conduction parameter recorded with the model data 52 of the network portion, and of the general meteorological parameters 56, taking into account, in the predetermined thermal equilibrium relation 54, the wind speed values ​​estimated at all singular points by execution of the first program 60.

[0038] 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 .

[0039] In the example of the figure 1 Two optimized maximum capacity values ​​can be calculated at the singular point of local substation 10: one for high-voltage line L1 and the other for high-voltage line L4. Three optimized maximum capacity values ​​can be calculated at the singular point of local substation 12: one for high-voltage line L1, one for high-voltage line L2, and the last for high-voltage line L5. Two optimized maximum capacity values ​​can be calculated at the singular point of local substation 14: one for high-voltage line L2 and the other for high-voltage line L3. Three optimized maximum capacity values ​​can be calculated at the singular point of local substation 16: one for high-voltage line L3, one for high-voltage line L4, and the last for high-voltage line L5.

[0040] The computer 46 is then configured to transmit the maximum optimized capacities to the respective local electrical substations concerned via its interface 42, the access port P1 of the main electrical substation 12 and the additional monitoring network 36, in accordance with the first communication protocol.

[0041] The third computer program 64 includes lines of instructions for performing automated fault detection, localization and processing in the network portion from data transmitted via the supplementary monitoring network 36.

[0042] The fourth computer program 66 includes lines of instructions for performing automated management of a network portion congestion from data transmitted via the additional monitoring network 36.

[0043] The elements, useful for understanding the invention, of any of the local electrical substations 10, 12, 14, 16 are illustrated on the figure 3 Position 10 is specifically used as an example.

[0044] It includes all 18 electrical devices as well as a gateway 68 configured to allow data exchange with the remote control network 26.

[0045] The gateway 68 thus includes the access port P2 through which it receives remote control data TC transmitted by the remote site 30 and transmits remote signaling data TS or telemetry data TM to this remote site 30, all such data conforming to the second communication protocol. It also includes a first transcoder 70 for transcoding the remote control data TC into remote control signals usable internally by the local electrical substation 10 and for transcoding remote signaling or telemetry signals transmitted internally by the electrical devices 18 into remote signaling data TS or telemetry data TM. Furthermore, it includes at least three electronic interface cards 72 with the electrical devices 18 for exchanging remote control, remote signaling, and telemetry signals with them.

[0046] Furthermore, gateway 68 includes port P1 for accessing the supplementary monitoring network 36, through which it exchanges data conforming to the first communication protocol. It also includes a port 74 for communication with electrical devices 18 according to this same first communication protocol, as well as a second transcoder 76 for transcoding TC, TS, and TM data conforming to the second communication protocol into data conforming to the first communication protocol. It is thus configured to transmit to the main electrical substation 12, via the supplementary monitoring network 36, at least a portion of the TC remote control, TS remote signaling, and TM telemetry data transcoded according to the first communication protocol, along with other data from the electrical devices 18.

[0047] Finally, gateway 68 includes an additional local monitoring system 78, for example a computer device, comprising an automaton 80 associated with a local memory 82 and which can replace, at least temporarily, a local monitoring mechanism which will now be detailed.

[0048] The electrical devices 18 of the local substation 10 include a high-voltage line monitoring device 84 and a high-voltage line monitoring device 86, as well as other devices 88, 90, etc., which will not be detailed as they are quite standard in a local substation. All these devices can exchange data with the gateway 68 via port 74 and a dedicated communication bus.

[0049] Device 84 implements the local monitoring mechanism by including a high-voltage line protection controller 92 associated with a memory 94 that stores a predefined local maximum capacity value, statically indicating an overload value that must not be exceeded. This value may depend on the season or other parameters. This controller 92 is designed, by applying certain locally predefined rules or upon receiving specific remote control signals, to trigger certain high-voltage line protection actions on line L1 under certain pre-established circumstances. These actions may include, in particular, a line interruption on line L1. More generally, the controller 92 is designed to exchange remote control, remote signaling, and telemetry signals with the three interface electronic boards 72.

[0050] Device 86 implements the local monitoring mechanism in the same way, comprising a high-voltage line protection controller 96 associated with a memory 98 that stores a predefined local maximum capacity value, statically indicating an overload value that must not be exceeded. This value may depend on the season or other parameters. This controller 96 is designed, by applying certain locally predefined rules or upon receiving specific remote control signals, to trigger certain high-voltage line protection actions on line L4 under certain pre-established circumstances. These actions may include, in particular, a line interruption on line L4. More generally, the controller 96 is also designed to exchange remote control, remote signaling, and telemetry signals with the three interface electronic boards 72.

[0051] The local supplementary monitoring unit 80 is configured to receive and store in local memory 82 any optimized maximum capacity value calculated by the automated supplementary monitoring means 34 of the main substation 12 for the high-voltage line L1 or L4. It is further configured to compare each received and stored optimized maximum capacity value in local memory 82 with the corresponding local maximum capacity value stored in memory 94 or 98. Finally, it is configured to replace the local monitoring mechanism 92, 96 with an optimized monitoring mechanism for exceeding the optimized maximum capacity values ​​stored in local memory 82 for lines L1 and L4 under certain predetermined conditions. These conditions are, for example, defined based on constraints related to the measurements from which the optimized maximum capacities were calculated (minimum wind speeds, measurement consistency, etc.).), on a confidence index relating to the maximum optimized capacities received, or on any other classic consideration left to the discretion of the person skilled in the art.

[0052] Local electrical substations 14 and 16 are structured in the same way as the one described above. As for the main electrical substation 12, it also includes the automated supplementary monitoring means 34, which can be implemented in the same computer system as the one implementing the local supplementary monitoring system 78. Alternatively, they can be implemented in a dedicated computer system outside the gateway 68, connected to port 74 via a communication bus or to its own access port P1 as illustrated in the diagram. figure 1 .

[0053] On the figure 4, a non-limiting example of the operation of the automated additional monitoring means 34 of the main electrical substation 12 is illustrated.

[0054] During a data collection step 100, the interface 42 conforming to the first communication protocol and the receiver 44 receive and provide to the computer 46 all the data necessary for the processing mentioned previously: wind speed values ​​provided by anemometric stations for a real-time estimation of wind speeds at the nodes of the portion of the network under consideration, TC remote control, TS remote signaling or TM telemetry data transcoded into data conforming to the first communication protocol, from each of the local electrical substations 10, 14 and 16 via the supplementary monitoring network 36, or provided internally in the main electrical substation 12, data from electrical devices 18, 20, 22, 24, conforming to the first communication protocol and passing through the supplementary monitoring network 36 with regard to electrical devices 18, 22 and 24 of local electrical substations 10, 14 and 16.

[0055] This data collection step runs in a loop as long as the automated additional monitoring means 34 remain operational and in use.

[0056] It enables the execution of step 102, which calculates optimized maximum capacity values ​​for each of the high-voltage lines L1 to L5, by running the first and second computer programs 60 and 62. As a non-limiting example, this step 102 can begin with the selection of a leeward anemometer station: a principal wind direction is determined from the latest received wind speed values, for example, by calculating the angular mean of the wind directions measured by the different anemometer stations. Then, the leeward anemometer station is selected, i.e., the one located furthest upstream in the determined principal wind direction. Next, under certain minimum speed conditions and consistency between the provided values, the wind speeds at each desired point of the network segment are estimated by time projection using the wind propagation model 58.Next, these wind speeds are used to calculate the maximum capacity values ​​optimized by running computer program 62. At the end of this step, the values ​​obtained are respectively transmitted to the local supplementary monitoring systems 78 of the local electrical substations concerned via the supplementary monitoring network 36.

[0057] In a subsequent step 104, they are applied locally as needed, either remotely via automated supplementary monitoring equipment 34 of the main electrical substation 12, or via local management of systems 78 (particularly in the event of a failure of the supplementary monitoring network 36). It is within the capabilities of a person skilled in the art to program the equipment 34 or the systems 78 so that the application of the optimized maximum capacities replaces the local maximum capacities stored in memory 94, 98, or so that the return to these local maximum capacities occurs intelligently without abrupt transitions.

[0058] Data collection step 100 also enables step 106, which involves detecting, locating, and correcting faults in the network segment by executing the third computer program 64. Many of the methods, implemented using algorithms and software, are already well-known and will not be detailed. The results of this step can be transmitted to remote monitoring sites 28, 30, and 32 during a subsequent step 108 or processed directly by the computer 46 and / or the PLCs 80.

[0059] The data collection step 100 also enables the implementation of step 110, which involves the automated management of one or more network congestions by executing the fourth computer program 66. In cooperation with the optimized maximum capacity management of steps 102 and 104, the computer 46 is programmed to decide on specific actions to resolve a detected congestion. Such actions can be transmitted via the supplementary monitoring network 36 and executed locally during a subsequent step 112: requests for production reductions, consumption load shedding, or transmission interruptions on certain high-voltage lines. In particular, production reduction requests can be modulated into partial reductions that are strictly necessary and sufficient to eliminate temporary constraints through intelligent maximum capacity management of the high-voltage lines.

[0060] Steps 104, 108 and 112 are followed by a step 114 of the end of operation of the additional automated monitoring means 34 of the main electrical substation 12 when they are no longer in use or operational.

[0061] It is clear that an installation such as the one described above allows for improved monitoring of a portion of a high-voltage electrical current transmission network, so as to allow its operation at full capacity without the need for reinforcement of the transmission network.

[0062] It should also be noted that the invention is not limited to the embodiment described above. Indeed, it will be apparent to those skilled in the art that various modifications can be made to the embodiment described above, in light of the information just disclosed. The claims define the protection sought.

Claims

1. A facility for monitoring a portion of a high-voltage electrical power transmission network comprising: - several local electrical substations (10, 12, 14, 16) for connection of high voltage lines (L1, L2, L3, L4, L5), located at each of a plurality of nodes of the network portion, each local electrical substation being electrically connected to at least one high voltage line end and implementing a first communication protocol dedicated to internal communication between electrical devices (18, 20, 22, 24) that it contains, - at least one remote monitoring site (28, 30, 32) connected to each of the local electrical substations (10, 12, 14, 16) by a remote control network (26) implementing a second communication protocol dedicated to this remote control, characterized in that: - one of the local electrical substations (10, 12, 14, 16), called the main electrical substation (12), comprises additional automated monitoring means (34) configured to receive, process and transmit data conforming with the first communication protocol for dynamically managing the network portion, - this main electrical substation (12) is connected to each of the other local electrical substations (10, 14, 16) by an additional monitoring network (36), distinct from the remote control network (26), implementing the first communication protocol.

2. The monitoring facility as claimed in claim 1, wherein the additional monitoring means (34) of the main electrical substation (12) comprise: - means (48) for storing a model (52) of the network portion, this model containing singular points and at least one high-voltage electrical power conducting line between these singular points, a predetermined thermal equilibrium relation (54), a limit operating temperature for each conducting line and conduction parameters for each conducting line, - a computer (46) with access to the storing means (48), programmed (60, 62) for dynamic determination of optimized maximum capacities for electrical power transmission in high-voltage lines (L1, L2, L3, L4, L5) in the network portion starting from the predetermined thermal equilibrium relation (54), each limit operating temperature, each network conduction parameter and meteorological parameters (56), and - means (42, 46) for transmission of the optimized maximum capacities to the respectively concerned local electrical substations (10, 12, 14, 16) in accordance with the first communication protocol.

3. The monitoring facility as claimed in claim 2, wherein each local electrical substation (10, 12, 14, 16) comprises: - a mechanism (92, 94, 96, 98) for local monitoring when at least one local maximum capacity value is exceeded, and - a programmable logic controller (80) for additional local monitoring associated with a local memory (82) and configured to: • receive and store each optimized maximum capacity value related to a high-voltage line, one end of which is electrically connected to this local electrical substation, in local memory (82), • compare each received and stored optimized maximum capacity value with said at least one local maximum capacity value, and • replace the local monitoring mechanism (92, 94, 96, 98) by a mechanism for optimized monitoring of exceedance of at least one optimized maximum capacity value stored in local memory (82) under specific predetermined conditions.

4. The monitoring facility as claimed in any one of claims 1 to 3, wherein: - each local electrical substation (10, 12, 14, 16) comprises a gateway (68) configured (70) to transcode remote control (TC) data conforming with the second communication protocol into remote control signals that can be used internally by each local electrical substation and to transcode remote signalling (TS) and remote measurement (TM) signals transmitted internally by each local electrical substation into remote signalling and remote measurement data conforming with the second communication protocol, - each gateway (68) comprises additional means (76) for transcoding data (TC, TS, TM) conforming with the second communication protocol into data conforming with the first communication protocol, a communication port (74) with the electrical devices contained in the local electrical substation in which it is installed and an access port (P1) to the additional monitoring network (36), and - each gateway (68) is configured to transmit at least some of the remote control (TC), remote signaling (TS) and remote measurement (TM) data transcoded according to the first communication protocol with other data originating from the electrical devices contained in the local electrical substation in which it is installed, to the main electrical substation (12) through the additional monitoring network (36).

5. The monitoring facility as claimed in claims 3 and 4, wherein the programmable logic controller (80) for additional local monitoring in each local electrical substation and its associated local memory (82) are implemented in the gateway (68) of this local electrical substation.

6. The monitoring facility as claimed in claim 4 or 5, wherein the additional automated monitoring means (34) are implemented in the gateway (68) of the main electrical substation (12).

7. The monitoring facility as claimed in any one of claims 4 to 6, wherein the main electrical substation (12) comprises automated means (46, 64) for detection, positioning and processing of faults in the network portion starting from data transmitted by each gateway (64) through the additional monitoring network (36).

8. The monitoring facility as claimed in any one of claims 4 to 6, wherein the main electrical substation (12) comprises automated means (46, 66) for management of congestion of the network portion starting from data transmitted by each gateway (64) through the additional monitoring network (36), this management including emission of requests for modulated production curtailment, consumption load shedding or transit interruptions on high-voltage line.

9. The monitoring facility as claimed in claims 7 and 8, wherein the automated means (46, 64) for detection, positioning and processing of faults and the automated means (46, 66) for management of congestion are implemented in the additional monitoring means (34) of the main electrical substation (12).

10. The monitoring facility as claimed in any one of claims 1 to 9, wherein: - the first communication protocol complies with a first standard, and - the second communication protocol complies with a second standard different from the first standard.