WO2013065469A1 - Système et procédé de stabilisation de circuiterie - Google Patents

Système et procédé de stabilisation de circuiterie Download PDF

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Publication number
WO2013065469A1
WO2013065469A1 PCT/JP2012/076378 JP2012076378W WO2013065469A1 WO 2013065469 A1 WO2013065469 A1 WO 2013065469A1 JP 2012076378 W JP2012076378 W JP 2012076378W WO 2013065469 A1 WO2013065469 A1 WO 2013065469A1
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WO
WIPO (PCT)
Prior art keywords
facility
stabilization
malfunctioning
information
power
Prior art date
Application number
PCT/JP2012/076378
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English (en)
Japanese (ja)
Inventor
英佑 黒田
佐藤　康生
渡辺　雅浩
大一郎 河原
弘一 原
Original Assignee
株式会社 日立製作所
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Publication of WO2013065469A1 publication Critical patent/WO2013065469A1/fr

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    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/04—Circuit arrangements for ac mains or ac distribution networks for connecting networks of the same frequency but supplied from different sources
    • H02J3/06—Controlling transfer of power between connected networks; Controlling sharing of load between connected networks
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00002—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by monitoring
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00004—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by the power network being locally controlled
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00034—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving an electric power substation
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00036—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving switches, relays or circuit breakers
    • H02J13/0004—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving switches, relays or circuit breakers involved in a protection system
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/001—Methods to deal with contingencies, e.g. abnormalities, faults or failures
    • H02J3/0012—Contingency detection
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02H—EMERGENCY PROTECTIVE CIRCUIT ARRANGEMENTS
    • H02H7/00—Emergency protective circuit arrangements specially adapted for specific types of electric machines or apparatus or for sectionalised protection of cable or line systems, and effecting automatic switching in the event of an undesired change from normal working conditions
    • H02H7/26—Sectionalised protection of cable or line systems, e.g. for disconnecting a section on which a short-circuit, earth fault, or arc discharge has occured
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2310/00—The network for supplying or distributing electric power characterised by its spatial reach or by the load
    • H02J2310/10—The network having a local or delimited stationary reach
    • H02J2310/12—The local stationary network supplying a household or a building
    • H02J2310/14—The load or loads being home appliances
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B70/00—Technologies for an efficient end-user side electric power management and consumption
    • Y02B70/30—Systems integrating technologies related to power network operation and communication or information technologies for improving the carbon footprint of the management of residential or tertiary loads, i.e. smart grids as climate change mitigation technology in the buildings sector, including also the last stages of power distribution and the control, monitoring or operating management systems at local level
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B70/00—Technologies for an efficient end-user side electric power management and consumption
    • Y02B70/30—Systems integrating technologies related to power network operation and communication or information technologies for improving the carbon footprint of the management of residential or tertiary loads, i.e. smart grids as climate change mitigation technology in the buildings sector, including also the last stages of power distribution and the control, monitoring or operating management systems at local level
    • Y02B70/3225—Demand response systems, e.g. load shedding, peak shaving
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/20—End-user application control systems
    • Y04S20/221—General power management systems
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/20—End-user application control systems
    • Y04S20/222—Demand response systems, e.g. load shedding, peak shaving
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/20—End-user application control systems
    • Y04S20/242—Home appliances

Definitions

  • the present invention relates to a system stabilization system and a system stabilization method.
  • Stable power supply is required for power systems for supplying power generated by power plants to various consumers such as general households and commercial facilities. Therefore, in the system that controls the power system, a list of assumed accidents and system stabilization control methods that stabilize the assumed accidents is created in advance, and when an assumed accident actually occurs, The system stabilization control prepared in advance is executed. Therefore, even when an assumed accident occurs, the system can be quickly stabilized and power supply can be continued.
  • the power system is divided into a plurality of areas in advance, and terminal stations are arranged in the respective areas.
  • Each terminal station monitors whether an accident has occurred based on system data such as voltage and frequency, and if an accident has been detected, performs an operation to stabilize the system and outputs a control command (Patent Document) 1).
  • the power system can be stabilized quickly by executing the system stabilization control.
  • the system stabilization control prepared in advance.
  • a failure may occur for some reason in other equipment belonging to the same system as the work target equipment
  • the prepared system stabilization control may not be able to cope with the failure. In other words, in a situation where the resistance to an assumed accident is reduced due to a disaster or work, when an assumed accident occurs, it may be difficult to respond to the assumed accident.
  • a system configuration capable of handling an assumed accident is called a healthy system.
  • a system configuration that cannot cope with an assumed accident is referred to as an unhealthy system in this specification.
  • the system stabilization system provides information for acquiring observation information in the power system, a plurality of predetermined accident lists and disaster information determined in advance as predetermined information related to the power system.
  • a malfunctioning facility determination unit for determining a malfunctioning facility that is predicted not to operate normally
  • a stability determination unit that determines whether or not a predetermined stabilization measure prepared in advance for stabilizing the system is involved, and if it is determined that a malfunctioning facility is related to a stabilization measure
  • a power system based on a determination result by a divided region determination unit and a divided region determination unit that determines a divided region for dividing a system into an unsound system including a malfunctioning facility and a healthy system that does not include a malfunctioning facility
  • a control command transmission unit for transmitting a predetermined device contained in the power system control instructions for dividing into a sound system and unhealthy lineages.
  • the stability determination unit can determine whether the malfunctioning facility is related to a predetermined stabilization measure and is stable with respect to a preset accident.
  • the control command transmission unit further includes a determination result presentation unit for presenting the determination result by the divided region determination unit to the user, and after confirming the user's selection with respect to the determination result presented by the determination result presentation unit, Can also be transmitted to a predetermined device.
  • the present invention stops the influence of the unforeseen accident in the unhealthy system, and the failure in the unhealthy system spreads to other healthy systems, resulting in a wide range of failures. Can be prevented in advance.
  • An example of disaster prediction information is shown. It is the schematic of a system
  • FIG. 1 is an explanatory diagram showing an overall outline of the present embodiment.
  • FIG. 1 is prepared to help understanding and implementation of the present invention, and the scope of the present invention is not limited to the configuration example shown in FIG.
  • the grid stabilization system 1 is a system for stabilizing the power grid 2.
  • the power system 2 includes a plurality of facilities N1 to N4 such as a transformer, a track, a generator, and a customer facility. Further, as described in the embodiments described later, the power system 2 includes a plurality of sensor devices 170, a plurality of switches 180, a plurality of communication devices 190, and the like.
  • the system stabilization system 1 can be configured from a single computer, or can be configured by linking a plurality of computers.
  • the system stabilization system 1 has, as its functions, for example, an information acquisition unit 1A, a malfunctioning equipment determination unit 1B, a stability determination unit 1C, a divided region determination unit 1D, a determination result presentation unit 1E, and a control command transmission. Part 1F is provided.
  • the information acquisition unit 1A is a function for acquiring predetermined information related to the power system 2.
  • the predetermined information includes sensor information (for example, track power flow data) from the sensor device 170, information indicating the configuration change of the facility, and information for predicting the occurrence of a disaster, as will be apparent from examples described later.
  • the information acquisition unit 1A may acquire all of these pieces of information as predetermined information, or may acquire at least one of the pieces of information.
  • the malfunctioning facility determination unit 1B is a function that is predicted to possibly not operate normally among the plurality of facilities N1 to N4 included in the power system 2 based on the predetermined information acquired by the information acquisition unit 1A. This is a function for determining the defective facility N2. In FIG. 1, for convenience of explanation, it is assumed that the facility N2 is a malfunctioning facility.
  • the other facilities N1 to N3 are sound facilities that have no problem.
  • a malfunctioning facility is a facility that has been determined not to operate normally or to have a higher possibility of normal operation than a predetermined value due to a disaster or maintenance inspection. For example, if a signal from a sensor device installed near a certain facility is interrupted or shows an abnormal value, that facility may be affected or possibly affected. Can think. Even if the facility is actually operating normally, if the possibility that the facility will not operate normally exceeds a certain value, it is determined as a malfunctioning facility. This is to maintain the ability to deal with contingencies that may occur at the next moment.
  • the stability determination unit 1 ⁇ / b> C is a function that determines whether the malfunctioning facility N ⁇ b> 2 is related to a predetermined stabilization measure prepared in advance to stabilize the power system 2.
  • the stabilization measure is a method for stabilizing the power system based on a predetermined safety standard such as the so-called “N-1 standard”.
  • the N-1 standard is a safety standard in which even if one of the N facilities breaks down, the power supply is maintained by the remaining N-1 facilities. Measures for stabilizing the power system 2 are prepared for each of the assumed accidents. Equipment that can be used for stabilization measures is referred to herein as stabilization equipment.
  • the stability determination unit 1C is a function for determining whether a malfunctioning facility corresponds to a stabilization facility. When it is determined that the malfunctioning facility is the stabilization facility, the system configuration including the malfunctioning facility can be considered to have low stability (unstable). This is because, when a certain accident occurs, there is a possibility that the stabilization measure corresponding to the assumption accident cannot be executed.
  • the division area determination unit 1D is a function for dividing the power system 2 into a plurality of areas (system configurations).
  • the divided area determination unit 1D includes the power system 2 including the unhealthy system including the malfunctioning facility and the malfunctioning facility. The division area for dividing into no healthy system is determined.
  • the cut C1 and the cut C2 shown on the upper side of FIG. 1 indicate boundary lines for dividing into an unhealthy area that is one divided area and a healthy area that is the other divided area.
  • the unhealthy system includes the malfunctioning facility N2 and the normal facility N3, and the healthy system includes the other normal facilities N1 and N4.
  • the normal facility N3 is an important facility such as a hospital or a fire department. Therefore, it is not preferable to include the normal equipment N3 in the unhealthy system. This is because when an assumed accident occurs, normal supply of power may not be possible in an unhealthy system. Therefore, the divided region determination unit 1D can separate the unhealthy system and the healthy system so that the important facility N3 is not included in the unhealthy system. That is, in the present embodiment, as a constraint condition, “pre-set important equipment N3 belongs to a healthy system” is set.
  • the determination result presentation unit 1E is a function for presenting the determination result by the divided region determination unit 1D to the user.
  • the user is, for example, a system operator who operates the power system 2.
  • the determination result presented to the user includes the configuration after the division of the power system 2 and the like.
  • the determination result presentation unit 1E presents the determination result to the user by displaying the determination result on the display device 11 (described later in FIG. 2) or the like.
  • the user can confirm the determination result and give a predetermined instruction to the system stabilization system 1.
  • the predetermined instruction includes, for example, selection for dividing the power system, correction instruction for dividing the power system, approval for dividing the power system, and the like.
  • the control command transmission unit 1F creates a control command for dividing the power system 2 into a healthy system and an unhealthy system based on the determination result by the divided region determination unit 1D, and the control command is included in the power system 2 This is a function for transmitting to a predetermined device.
  • a predetermined device is a switch 180 (described later in FIG. 2).
  • the unhealthy system can be automatically disconnected from the power system 2 by remotely operating the predetermined switch 180.
  • predetermined information related to the power system 2 is collected, it is determined whether there is a malfunctioning facility based on the information, and stability is determined when a malfunctioning facility is found.
  • the predetermined information can include observation information in the power system, a plurality of presumed accident lists and disaster information determined in advance. Furthermore, in this embodiment, when it determines with it being a malfunctioning installation, before the assumption accident relevant to the malfunctioning installation generate
  • a control command is transmitted to the predetermined
  • the system configuration (unhealthy system) whose feasibility of implementing a predetermined stabilization measure has been reduced due to a disaster or maintenance work, etc. is separated from other healthy system configurations in advance, so that Sex can be maintained.
  • this embodiment will be described in more detail.
  • the system stabilization system 10 corresponds to the system stabilization system 1 of FIG. 1
  • the power system 100 corresponds to the power system 2 of FIG. 1.
  • steps S1 and S2 correspond to the information acquisition unit 1A of FIG.
  • Step S3 corresponds to the malfunctioning facility determination unit 1B in FIG. 1
  • step S5 corresponds to the stability determination unit 1C in FIG. 1
  • steps S6 and S7 correspond to the divided region determination unit 1D in FIG.
  • step S8 corresponds to the determination result presentation unit 1E in FIG. 1
  • step S9 corresponds to the control command transmission unit 1F in FIG.
  • the power system 100 and the system stabilization system 10 are communicably connected via a communication network 300.
  • the configuration of the power system 100 will be described.
  • the power system 100 includes a plurality of divided systems 110 and 111. In FIG. 2, two divided systems 110 and 111 are shown, but the power system 100 may have three or more divided systems.
  • the divided systems 110 and 111 are connected via a connection configuration 112.
  • Each of the divided systems 100 and 111 includes, for example, a node (bus) 150, a power source 120, a load 140, a transformer 130, a line 160, a sensor 170, a switch 180, and a communication device 190. Yes.
  • FIG. 2 The configuration shown in FIG. 2 is an example for explanation, and actually, a plurality of power supplies 120, loads 140, and the like can be provided in each of the divided systems 110 and 111. Further, it is only necessary that at least one sensor 170 and one switch 180 are provided on the line 160.
  • the power source 120 is configured, for example, as a solar power generation device, a solar thermal power generation device, a geothermal power generation device, a wind power generation device, a thermal power plant, a hydropower plant, etc., and supplies power to the node 150.
  • the transformer 130 is provided between the node 150 and the node 150 and adjusts the voltage and the like.
  • the load 140 using the electric power supplied from the node 150 is, for example, each consumer such as a general household, a commercial facility, a factory, a hospital, a police station, a fire department, a public office, and the like.
  • Line 160 connects the nodes.
  • the sensor 170 as the “sensor device” measures the value of the current flowing through the line 160, the voltage value, and the like, and transmits these measured values to the system stabilization system 10 as sensor information.
  • the switch 180 as a “predetermined device” connects and disconnects the nodes 150 by opening and closing the line 160.
  • the communication device 190 is provided between the sensor 170 and the switch 180 and the communication network 300.
  • the sensor 170 and the switch 180 are connected to the communication network 300 via the communication device 190, and communicate with the system stabilization system 10 via the communication network 300.
  • connection configuration 112 electrically connects the divided systems 110 and 111 through one or a plurality of paths.
  • Each path can include, for example, a line 160, a sensor 170, a switch 180, and a communication device 190.
  • the node 150 of the one divided system 110 and the node 150 of the other divided system 111 are connected via one or more paths of the connection configuration 112.
  • the communication device 190 in the divided system (110, 111) is connected to the communication interface (I / F in the figure) 15 of the system stabilization system 10 via the communication network 300.
  • sensor information 310A and control information 310B which will be described later, are transmitted and received between the sensor 170 and switch 180 in each of the divided systems 110 and 111 and the system stabilization system 10.
  • FIG. 4 shows a schematic configuration example of sensor information 310 ⁇ / b> A and control information 310 ⁇ / b> B transmitted and received between the sensor 170 and switch 180 and the system stabilization system 10.
  • the sensor information 310 ⁇ / b> A is transmitted from the sensor 170 of the power system 100 to the system stabilization system 10.
  • the sensor information 310A includes, for example, a track current P 311, a unique number (ID in the figure) 312 for identifying the sensor 170, and a time stamp 313.
  • the track current P included in the sensor information 310 ⁇ / b> A is a current for each time section flowing through the track 160 connecting the nodes 150.
  • the track current is measured by the sensor 170.
  • the system stabilization system 10 transmits the control information 310 ⁇ / b> B toward the switch 180 on the line 160.
  • the control information 310B includes, for example, a control command 314, unique information 315 for identifying the switch 180, and a time stamp 316.
  • a unique number is set in advance in the switch 180, and the system stabilization system 10 knows in advance the unique number of each switch 180 on each line 160.
  • the sensors 170 and the system stabilization system 10 are connected to a time server (not shown) via the communication network 300. Therefore, the internal time of each sensor 170 and the time in the system stabilization system 10 are synchronized.
  • the system stabilization system 10 includes, for example, a display device 11, an input device 12, a microprocessor 13, a memory 14, a communication interface 15, various databases (an equipment database 21, a system database 22, a divided area database 23, a divided area).
  • a result database 24 and a program database 25) are provided, which are connected to the bus line 41.
  • the display device 11 is configured as a display device, for example. Instead of the display device or together with the display device, a configuration using a printer device, an audio output device, or the like may be used.
  • the input device 12 may be configured to include at least one of a keyboard switch, a pointing device such as a mouse, a touch panel, and a voice instruction device.
  • the microprocessor (CPU: Central Processing Unit) 13 reads a predetermined computer program from the program database 25 and executes it.
  • the microprocessor 13 may be configured as one or a plurality of semiconductor chips, or may be configured as a computer device such as a calculation server.
  • the memory 14 is configured as a RAM (Random Access Memory), for example, and stores a computer program read from the program database 25, and stores calculation result data and image data necessary for each process.
  • the screen data stored in the memory 14 is sent to the display device 11 and displayed. An example of the displayed screen will be described later.
  • the communication interface 15 includes a circuit and a communication protocol for connecting to the communication network 300.
  • the system stabilization system 10 can include, for example, an equipment database 21, a system database 22, a divided region database 23, a division result database 24, a program database 25, and the like. Details of these databases will be described later.
  • the contents stored in the program database 25 will be described with reference to FIG.
  • the program database 25 stores, for example, a malfunctioning facility determination program CP11, an assumed accident stability determination program CP12, and a divided area calculation program CP13.
  • the microprocessor 13 executes each computer program to find a malfunctioning facility, evaluate the stability of the malfunctioning facility, analyze an optimal divided area, and present the analysis result to the user. To do.
  • the system stabilization system 10 is provided with four databases (an equipment database 21, a system database 22, a divided region database 23, and a division result database 24).
  • an equipment database 21 for example, a system configuration (not shown), an assumed accident countermeasure list 21T1 (see FIG. 22), and a restricted equipment list 21T2 (see FIG. 26) are stored as equipment data D1.
  • the system configuration, the assumed accident countermeasure list 21T1 and the restricted equipment list 21T2 are transmitted from the system management server 320 to the system stabilization system 10 via the communication network 300.
  • the system configuration is information indicating the configuration of the power system 100.
  • the arrangement and connection configuration of the power source 120, the transformer 130, the load 140, the node 150, the line 160, the sensor 170, the switch 180, and the communication device 190 are stored. .
  • the anti-accident countermeasure list 21T1 stores stabilization countermeasures for the probable accident.
  • the operator of the electric power system 100 sets in advance an accident that may occur and measures to maintain a stable power supply when the accident occurs.
  • the stabilization measure is control that disconnects equipment in which an accident such as a ground fault or a short circuit has occurred, or disconnects the power supply 120 or the load 140 from the node 150. That is, the stabilization measure is a series of control processes for responding to an accident using the equipment included in the power system 100. Equipment used for stabilization measures is called stabilization equipment.
  • the restricted equipment list 21T2 for example, a list of important loads such as hospitals, communication base equipment, fire departments, city halls, substations, and / or hubs on power transmission is stored.
  • sensor information tables 22T1 and 22T1A (refer to FIG. 8; unless specifically distinguished between the tables 22T1 and 22T1A, they are referred to as the sensor information table 22T1) and a line capacity table 22T2 ( 13) and facility configuration change information 22T3 (see FIG. 15) are stored.
  • the sensor information 310A is transmitted from the sensor 170 to the system stabilization system 10 via the communication device 190 and the communication network 300 as described in FIG.
  • the sensor information table 22T1 stores the received sensor information 310A.
  • the line capacity table 22T2 and the equipment configuration change information 22T3 are transmitted from the system management server 320 to the system stabilization system 10 via the communication network 300.
  • the line capacity information 22T2 stores capacity information for each line 160.
  • the equipment configuration change information 22T3 stores information related to a change in the equipment configuration of the power system 100.
  • the system operator arranges and connects the power supply 120, transformer 130, load 140, node 150, line 160, sensor 170, switch 180, and communication device 190 in the power system 100 via the system management server 320. Can be set for each time section.
  • the divided area database 23 includes, for example, a malfunction facility list (not shown), an assumed accident stability determination list 23T1 (see FIG. 23), a divided area list (not shown), and a switch as the divided area data D3.
  • An action list (not shown) can be stored.
  • the malfunction facility list is created by the malfunction facility determination program CP11.
  • the malfunctioning facility determination program CP11 determines whether or not there is a malfunctioning facility based on the system data, and registers the facility determined to be a malfunctioning facility in the malfunctioning facility list.
  • the divided area list is created by the divided area calculation program CP13.
  • the divided area calculation program CP13 calculates all the cuts to be divided based on the system configuration, the malfunctioning facility list, and the assumed accident stability determination list 23T1, and registers the calculated cuts in the divided area list.
  • the assumed accident stability determination list 23T1 is created by the assumed accident stability determination program CP12.
  • the assumed accident stability determination list 23T1 stores whether or not the accident is stable when an assumed accident occurs in an electric power system (unhealthy system) including a malfunctioning facility. The system operator can determine what types of accidents can occur.
  • the switch operation list stores the operations of the switch 180 for dividing the power system 100. That is, information indicating how to control the switching state of which switch 180 in order to divide the power system 100 along the calculated cut is stored in the switch operation list.
  • the division result database 24 as the division result database 24, for example, data indicating the supply and demand balance of each divided area (see FIG. 31) and data indicating changes in the assumed accident countermeasure list before and after the division (see FIG. 32) Is remembered.
  • the supply and demand balance of the divided area is obtained as a calculation result of the divided area calculation program CP13.
  • the data indicating the balance between supply and demand in each divided area stores data indicating the balance change between the power generation amount and the load amount in each divided area. For example, when the power generation amount and the load amount are unbalanced in a divided area, the frequency varies in the divided area. Therefore, the data indicating the supply and demand balance of the divided areas includes data indicating the time change of the frequency.
  • the list of anticipated accident countermeasures stores a list of stabilization measures for the presumed accident before the split and a list of stabilization measures for the postulated accident.
  • the flowchart in FIG. 5 shows the entire system stabilization process performed by the system stabilization system 10.
  • the system stabilization system 10 receives and stores the facility data D1 (S1), and then receives and stores the system data D2 (S2).
  • the system stabilization system 10 determines a malfunctioning facility by processing the system data D2 by the malfunctioning facility determination program CP11 (S3). Further, the system stabilization system 10 creates and stores a malfunctioning equipment list, and displays the malfunctioning equipment list on the display device 11 (S3).
  • the system stabilization system 10 repeatedly performs the following step S5 and step S6 for all assumed accidents (S4).
  • the system stabilization system 10 determines whether the malfunctioning facility is stable against the assumed accident by the assumed accident stability determination program CP12 (S5).
  • a malfunctioning facility is stable with respect to an assumed accident is a case where a stable power supply can be maintained even if an assumption accident related to the malfunctioning facility occurs.
  • the malfunctioning facility is unstable when there is a possibility that stable power supply cannot be performed when an assumed accident related to the malfunctioning facility occurs.
  • the system stabilization system 10 calculates and stores the divided area by the divided area calculation program CP13 (S6).
  • the system stabilization system 10 calculates the optimum divided area by the divided area calculation program CP13 and stores the calculation result (S7).
  • the system stabilization system 10 creates a screen (to be described later with reference to FIG. 30) relating to the optimum divided area and presents it to the system operator.
  • the system stabilization system 10 After confirming the approval, selection or instruction of the system operator, the system stabilization system 10 creates a control command (control information 310B) for generating an optimal divided area and transmits it to a predetermined switch 180. (S8).
  • the predetermined switch 180 is a switch necessary for disconnecting the unhealthy system from the power system 100 along the selected cut.
  • step S1 the equipment data D1 is acquired and stored in the equipment database 21.
  • the system stabilization system 10 receives the system configuration of the power system 100, the assumed accident countermeasure list (FIG. 22), and the restricted equipment list (FIG. 26) from, for example, the system management server 320 and writes them to the memory 14, and the equipment database 21 To remember.
  • FIG. 22 shows an example of the assumed accident countermeasure list 21T1.
  • This list 21T1 manages safety measures for responding to an assumed accident.
  • the assumed accident countermeasure list 21T1 manages, for example, an assumed accident number 21T1C1, an assumed accident content 21T1C2, and a stabilization countermeasure content 21T1C3.
  • the content of the assumed accident 21T1C2 stores the place where the assumed accident occurred and the aspect of the assumed accident.
  • the content 21T1C3 of the stabilization measure stores information for specifying the stabilization facility for coping with the assumed accident and the operation of the stabilization facility.
  • 3 ⁇ 4LG three-phase four-wire ground fault
  • the line 160 can be stabilized by opening and removing.
  • FIG. 26 shows an example of the restricted equipment list 21T2.
  • the constrained equipment list 21T2 manages constraining conditions that are taken into account when determining the divided areas. For example, the node 150 having an important facility needs to be included in a healthy system.
  • the restricted equipment list 21T2 manages, for example, the equipment number 21T2C1, the restricted equipment name 21T2C2, the node 21T2C3 to which the restricted equipment is connected, and the restricted equipment position (installation location) 21T2C4. .
  • Constraint equipment is important equipment that should continue to supply power even in the event of a disaster or failure, such as a hospital, fire department, substation, or communication base station.
  • step S2 system data D2 is acquired.
  • the system stabilization system 10 receives sensor information 22T1 (FIGS. 8 and 11), facility configuration change information 22T3 (FIG. 15), and line capacity information 22T2 (FIG. 13) from each sensor 190 and the system management server 320. And stored in the system database 22.
  • FIG. 8 shows an example of the sensor information table 22T1.
  • the sensor information table 22T1 manages the sensor information collected from the sensor 170.
  • the sensor information table 22T1 manages, for example, the time 22T1C1, the line power flow P 22T1C2, the data reception status 22T1C3, and the information 22T1C4 related to the loss.
  • the line power flow P 22T1C2 manages the identification number for identifying the line, the value of the power flow at the start node of the line, and the value of the power flow at the terminal node of the line in association with each other.
  • the data reception status 22T1C3 the state of the line power flow P received from the sensor 170 (whether or not it has been received) is recorded.
  • the missing information 22T1C4 a determination value indicating whether or not equipment loss has occurred is recorded based on the value of the reception status 22T1C3.
  • FIG. 11 shows another example 22T1A of the sensor information table.
  • the sensor information table 22T1A includes abnormality information 22T1C5 indicating abnormality of the sensor information, instead of the missing information 22T1C4 of the table 22T1 illustrated in FIG.
  • the data reception status 22T1C3 stores a value indicating whether or not an abnormality has been found in the value of the line power flow P as the state of the line power flow P received from the sensor 170.
  • the abnormality information 22T1C5 a determination value indicating whether an abnormality has occurred in the facility is recorded based on the value of the reception state 22T1C3.
  • the sensor information table 22T1 in FIG. 8 is used to determine that equipment has been lost when sensor information has not been continuously acquired for a predetermined time or more.
  • the sensor information table 22T1A in FIG. 11 is used to determine that an abnormality has occurred in the facility when an abnormality has occurred in the sensor information for a predetermined time or longer.
  • a case where both the table 22T1 shown in FIG. 8 and the table 22T1A shown in FIG. 11 are provided will be described, but a configuration including only one of them may be used.
  • FIG. 15 shows an example of the equipment configuration change information 22T3.
  • the facility configuration change information 22T3 manages the state of each facility in the power system 100.
  • the equipment configuration change information 22T3 manages the equipment state (22T3C2) every predetermined time (22T3C1). In the example shown in FIG. 15, it is recorded in the first row that the line 160 is stopped from 14:30:30.
  • the malfunctioning facility determination program CP11 determines whether or not there is a malfunctioning facility, stores the result, and displays the result. There are a plurality of methods for determining a malfunctioning facility as described below. Therefore, with reference to FIG. 6, FIG. 10, FIG. 14, and FIG. A configuration including all of the following determination methods, or a configuration including any one or more determination methods among them may be employed. Any configuration is included in the scope of the present invention.
  • the first malfunctioning equipment determination method determines the presence of a malfunctioning facility based on the lack of sensor information.
  • the malfunctioning facility determination program CP11 receives sensor information (line power flow P) from the sensor 170 and stores it in the system database 22 (S10).
  • the determination program CP11 determines whether data loss continues for a predetermined time or more (S20). When the data loss continues (S20: YES), the determination program CP11 specifies and stores the position of the sensor 170 where the data loss occurs (S30). The determination program CP11 specifies equipment near the sensor 170 in which data loss occurs (S40), determines that the specified equipment is a malfunctioning equipment, and stores it in the divided region database 23 (S50). ). Information regarding the malfunctioning equipment stored in step S50 can also be output on the screen.
  • a relay device 340 may be used as shown in FIG.
  • the relay device 340 can receive sensor information from the plurality of sensors 170, aggregate the sensor information, and transmit the collected sensor information to the system stabilization system 10.
  • step S20 for example, if sensor information cannot be received for 5 minutes or more in a measurement period of 30 seconds, it is determined that data loss has occurred.
  • the reason why the determination threshold (predetermined time) is set to 5 minutes is that if the predetermined time is set short, for example, 30 seconds, a normal communication error may be erroneously determined as data loss.
  • the determination program CP11 determines that a malfunctioning facility has occurred.
  • FIG. 9 shows an example where a data loss 200 occurs on the line 160.
  • FIG. 9 shows that the sensor information from the sensor 170 provided on one of the plurality of lines 160 and 161 connecting the first divided system 110 and the second divided system 111 exceeds a predetermined time. The state which does not reach the system stabilization system 10 is shown. The position 200 of the sensor 170 that cannot receive the sensor information (data of the line power flow P) is indicated by X in FIG.
  • the third divided system 113 is connected to the second divided system 111 via the second connection configuration 114. Further, the configuration of FIG. 9 will be described. From the node 152 of the second divided system 111 to the node 150 of the first divided system 110, the power of the line tidal current P0 flows through the line 160. From the node 153 of the second divided system 111 toward the node 151 of the first divided system 110, the power of the line power flow P1 flows through the line 161. From the node 156 of the third divided system 113 to the node 154 of the second divided system 111, the power of the line power flow P2 flows through the line 162. From the node 155 of the second divided system 111 to the node 157 of the third divided system 113, the power of the line power P3 flows through the line 163.
  • the second malfunctioning equipment determination method determines that a malfunctioning facility has occurred when the sensor information from the sensor 170 indicates an abnormal value for a predetermined time or more.
  • the determination program CP11 receives the sensor information (track current P) from the sensor 170, stores it in the system database 22 (S11), and determines whether the abnormal value continues in the sensor information data (S21).
  • the determination program CP11 specifies and stores the position of the sensor 170 outputting the abnormal value (S31).
  • the determination program CP11 specifies equipment in the vicinity of the sensor 170 indicating an abnormal value (S41), determines that the equipment is a malfunctioning equipment, and stores it in the divided region database 23 (S51). As described with reference to FIG. 6, information on equipment determined to be malfunctioning equipment can be output to the screen and presented to the user.
  • Whether or not the value of the line power flow P included in the sensor information is abnormal is determined by comparing with the value of the line capacity table 22T2 shown in FIG. When the value of the line power flow P included in the sensor information exceeds the value of the line capacity defined in the table 22T2, it is determined that the data is an abnormal value.
  • the predetermined time for determining whether or not the data abnormal value continues is set to a value of about 2 minutes when the measurement cycle is 30 seconds, for example. For example, it is considered that it is not necessary to execute control for stabilizing the power system when abnormality occurs in the data for a short time of about 30 seconds.
  • FIG. 12 shows an example in which an abnormal data value occurs on the line 160 due to a certain equipment 210.
  • the third malfunctioning equipment determination method will be described.
  • the equipment configuration is changed due to maintenance work or the like, the equipment to be changed is determined to be a malfunctioning equipment.
  • the determination program CP11 receives the equipment configuration change information from the system management server 320 and stores it in the system database 22 (S12).
  • the determination program CP11 identifies the facility to be changed based on the facility configuration change information (S22), determines that the facility to be changed is a malfunctioning facility, and stores it in the divided region database 23 (S32). Information regarding equipment determined to be malfunctioning equipment can also be presented to the user via a screen.
  • FIG. 16 shows an example when a stop 201 occurs on the line 160.
  • a fourth malfunctioning equipment determination method will be described.
  • a malfunctioning facility is determined based on information for predicting the occurrence of a disaster.
  • the system stabilization system 10 can receive disaster prediction information from the disaster prediction server 330 via the communication network 300.
  • the disaster prediction server 330 predicts when and where a disaster such as a typhoon or an earthquake occurs, and transmits the prediction result to the system stabilization system 10.
  • the determination program CP11 receives the disaster prediction information from the disaster prediction server 330 and stores it in the system database 22 (S13). The determination program CP11 determines whether the facilities of the power system 100 exist within the geographical range where the occurrence of a disaster is predicted (S23). The determination program CP11 identifies the facility in the area where the occurrence of the disaster is predicted, determines that the facility is a malfunctioning facility, and stores it in the divided region database 23 (S33). Similarly to the above, information regarding equipment determined to be malfunctioning equipment can be output to the screen.
  • FIG. 19 shows an example of the disaster prediction information 330T1.
  • the disaster prediction information 330T1 manages, for example, information 330T1C1 related to facilities that may be damaged and information 330T1C2 related to disasters that are predicted to occur.
  • the information 330T1C1 related to the facilities that may be damaged includes, for example, information for identifying the track, information for identifying the start and end nodes of the track, and location information for the facility.
  • the disaster-related information 330T1C2 can include, for example, location information of an area where a disaster is predicted and an occurrence probability within a predetermined time from the current time.
  • the information 330T1C2 may include the type of disaster and the degree of damage caused by the disaster. In FIG. 19, as shown in the first row, it is recorded that a disaster occurs with a probability of 50% within a predetermined time (for example, 1 hour) from now on the line 160.
  • FIG. 20 is an example in the case where a disaster is predicted near the track 160.
  • a circle indicated by a dotted line indicates an area 202 where a disaster is predicted to occur.
  • the assumed accident stability determination program CP12 determines the stability (whether stable) for each assumed accident described in the assumed accident countermeasure list 21T1 of the equipment database 21 for the malfunctioning equipment detected by the malfunctioning equipment judgment program CP11. To do.
  • the assumed accident stability determination program CP12 determines whether the assumed accident countermeasures described in the assumed accident countermeasure list 21T1 are stable for the malfunctioning equipment (S5). If stable, the process returns to step S4. If unstable, the process proceeds to step S6.
  • step S5 in FIG. 5 is a flowchart of processing for determining stability (whether stable or not) against an assumed accident.
  • the assumed accident stability determination program CP12 reads the stabilization equipment for dealing with the assumed accident described in the assumed accident countermeasure list 21T1 (S100).
  • the assumed accident stability determination program CP12 compares the stabilization equipment read in step S100 with the malfunctioning equipment determined in step S3 (S200).
  • the assumed accident stability determination program CP12 determines whether or not the accident is stable based on the comparison result, and stores the determination result (S300).
  • FIG. 23 is an example of an assumed accident stability determination list 23T1 that stores a result of determining whether or not the accident is stable.
  • the assumed accident stability determination list 23T1 includes, for example, an assumed accident number 23T1C1, an assumed accident content 23T1C2, a stabilization measure content 23T1C3, information 23T1C4 for identifying a malfunctioning facility, a malfunctioning facility and a stabilization facility, And a match flag 23T1C5 for judging whether or not match.
  • the content of the assumed accident 23T1C2 stores the location of the assumed accident and the aspect (situation) of the assumed accident.
  • Stabilization countermeasure content 21T1C stores information for identifying a stabilization facility to be used for stabilizing a system in response to an assumed accident, and the operation of the stabilization facility.
  • the malfunctioning equipment matches any stabilization equipment, the malfunctioning equipment is determined to be unstable with respect to the assumed accident. On the other hand, when the malfunctioning facility does not match any of the stabilization facilities, it is determined that the malfunctioning facility is stable against the assumed accident.
  • step S6 The divided area calculation program CP13 calculates and stores the divided areas. Details of step S6 will be described with reference to the flowchart of FIG.
  • the divided area calculation program CP13 reads malfunctioning equipment, normal equipment, and line power flow P from the memory 14 (S200), and detects all cuts that can divide the malfunctioning equipment and normal equipment (S210).
  • a cut is a boundary between regions for dividing a system configuration including a malfunctioning facility and a system configuration including only normal facilities. That is, in step S210, all the division patterns for separating the unhealthy system from the power system are extracted.
  • the divided area calculation program CP13 extracts a cut including the restricted equipment from the detected cuts (S220).
  • the divided area calculation program CP13 calculates the fence current ( ⁇ P) for each cut, determines the cut that minimizes the fence current, and stores it in the memory 14 (S230).
  • Three lines 160, 161, 162 are provided between the divided system 110 and the divided system 111.
  • the line flow of the line 160 is P1
  • the line flow of the line 161 is P2
  • the line flow of the line 162 is P3.
  • the direction of the tidal current for example, the direction from the divided system 110 to the divided system 111 can be positive, and the reverse tidal current can be treated as negative.
  • the line tide P1 can be defined as a positive tide
  • the line tide P2 and the line tide P3 can each be defined as a negative tide.
  • the fence power flow ⁇ P is obtained as the sum of P1, ( ⁇ P2), and ( ⁇ P3).
  • FIG. 28 another example of calculating the fence tide will be described.
  • FIG. 29 a description will be given of how to extract a cut for dividing an unhealthy system including a malfunctioning facility from an electric power system.
  • the node N2 is a malfunctioning facility
  • the node N3 is a restriction facility
  • the nodes N1 and N4 are normal facilities.
  • the divided area calculation program CP13 extracts all the cuts C1 to C4 that divide the malfunctioning facility N2 and the normal facilities N1, N3, and N4.
  • the first cut C1 separates the system configuration (unhealthy system) including only the malfunctioning facility N2 from the system configuration (sound system) including the normal facilities N1, N3, and N4.
  • the second cut C2 separates the unhealthy system including the malfunctioning facility N2 and the normal facility N3 from the healthy system including the normal facilities N1 and N4.
  • the third cut C3 separates the unhealthy system including the malfunctioning facility N2 and the normal facility N1 from the healthy system including the normal facilities N3 and N4.
  • the fourth cut C4 separates the unhealthy system including the malfunctioning facility N2 and the normal facilities N1 and N3 from the healthy system including only the normal facility N4.
  • the second cut C2 and the fourth cut C4 include the restricted facility N3 that should be preferentially supplied with power even in the case of an assumed accident. ing. Since the unsound system has a reduced ability to cope with an assumed accident, it is not preferable in terms of stable power supply that the restricted facility N3 is included in the unsound system. Therefore, among the four cuts C1 to C4, only the cuts C1 and C3 in which the constraint facility N3 is included in the healthy system are selection candidates.
  • step S7 the divided area calculated in step S6 is read from the memory 14, and one optimum divided area is calculated and stored by the divided area calculation program CP13.
  • the process for calculating the optimum divided area will be described with reference to the flowchart of FIG.
  • the divided area calculation program CP13 acquires a cut that minimizes the fence tide ⁇ P (S300), and determines a cut that minimizes the fence tide ⁇ P as a divided area list in the divided area database 23. (S310).
  • the system stabilization system 10 creates various data (image data, numerical data, etc.) about the plan for dividing the unhealthy system and the healthy system, and displays the data on the display device 11.
  • FIG. 30 shows a screen G10 showing the division result (division schedule).
  • the screen G10 includes, for example, a first display area G110 that displays the system status, a second display area G120 that displays the supply and demand balance, the line tide, the stability, and the fence tide, and a third display that schematically shows the system configuration. Region G130.
  • the status (the line where the sensor information is missing and the time when it is determined to be missing), the control method implemented for improvement (the command for dividing the line 161, and the division Time).
  • the power generation amount ⁇ G [MW], the load amount ⁇ L [MW], and the power flow P [p. u. ], Frequency f [Hz] as an index of stability, and fence current flow are displayed for each divided region.
  • the system configuration is schematically displayed.
  • the system stabilization system 10 may transmit and display the screen G10 to a terminal existing outside the system stabilization system 10.
  • the screen can be displayed on a console terminal configured separately from the system stabilization system 10 or a mobile phone.
  • FIG. 31 is a screen G121 showing a time-series change in system status and frequency deviation.
  • the system status the status (the line where the sensor information is missing and the time when the sensor information is determined to be missing) and the control method implemented for improvement (the division command for the line 161) , The time of division).
  • the time series change of the frequency deviation is displayed in the lower part of the screen G121. If such a display screen G121 is presented to the user, the user can intuitively understand the state of the power system, and usability is improved.
  • the system stabilizing system 10 Based on the divided area list obtained by the divided area calculation program CP13, the system stabilizing system 10 creates a control command for operating each predetermined switch 180. The system stabilization system 10 transmits a control command to each predetermined switch 180 to operate.
  • FIG. 32 shows a screen G20 showing a comparison between the state G210 before dividing the power system and the state G220 after dividing the power system.
  • This embodiment configured as described above has the following effects.
  • a malfunctioning facility when a malfunctioning facility is detected (when determined), an unhealthy system including the malfunctioning facility can be separated from the power system 100.
  • produces in an unhealthy system after that, it can prevent beforehand that the malfunction which arises in an unhealthy system spreads to a healthy system, and a failure spreads.
  • the unhealthy system which is a part of the power system, is separated from the power system before the occurrence of the assumed accident, thereby maintaining the ability to cope with the assumed accident for many remaining system configurations. And the reliability of the power system can be improved.
  • the system configuration having the equipment determined to be malfunctioning is disconnected from the power system 100 even if the power is currently supplied normally.
  • a distributed power source such as a photovoltaic power generator or a gas turbine generator
  • the unsound system can continue as an independent system. That is, the distributed power supply in the unhealthy system is permitted to operate independently, and the power from the distributed power supply is supplied to the load in the unhealthy system.
  • the power supply stability (frequency change) in each divided region is calculated and displayed on the screens of FIGS. 30 and 31. Thereby, the user can select the optimal cut (optimum division
  • the second embodiment will be described with reference to FIGS.
  • This embodiment corresponds to a modification of the first embodiment. Therefore, the difference from the first embodiment will be mainly described.
  • the facility is stable or unstable by comparing the malfunctioning facility with the stabilization facility described in the assumed accident countermeasure list.
  • the degree of stability against an assumed accident of a system configuration having a malfunctioning facility is calculated using the system online information, and it is determined whether it is stable or unstable.
  • the system state that changes from moment to moment is ignored, and the malfunctioning facility and the stabilization facility (the stabilization facility described in the assumed accident countermeasure list for the most severe system state assumed) are used. A stability determination was made only by comparison.
  • the system state that changes from moment to moment is monitored online, and when a malfunctioning facility occurs, it is determined each time whether or not a countermeasure for the assumed accident calculated in the current system state is necessary.
  • a countermeasure for the assumed accident calculated in the current system state is necessary.
  • the loss refers to a social economic loss caused by a power outage by a customer, which can occur, for example, as a countermeasure against an assumed accident.
  • FIG. 33 shows the overall configuration of this embodiment.
  • the system stabilization system 10A of the present embodiment further includes a stability calculation database 26, a measurement database 27, and a calculation result database 28, as compared with the system stabilization system 10 shown in FIG.
  • the program database 25A of the present embodiment further includes a state estimation program CP14, a power flow calculation program CP15, and a stability calculation program CP16.
  • the program database 25A of the present embodiment does not include the assumed accident stability determination program CP12.
  • the stability calculation database 26 stores a tidal current calculation value, a line constant Z necessary for state estimation, and a sensor error as the stability calculation data D5.
  • the database 26 stores a generator model and constants necessary for the stability calculation, a control system model and constants, and an assumed accident condition.
  • the measurement database 27 as the measurement data D6, the node voltage V for each time section of the power system 100, the current I of the line, the active power P, the reactive power Q, the active power P such as a load and power generation, the reactive power Q, etc. Information is stored.
  • the calculation result database 28 stores a state estimation result, a tidal current calculation result, and a stability calculation result as calculation result data D7.
  • the online information of the power system 100 is stored in the measurement database 27 at a constant cycle (for example, at a cycle of 30 seconds).
  • the online information is transmitted from the power system 100 via the communication network 300 through the communication interface 15.
  • the system stabilization system 10A determines the malfunctioning facility by calculating the system data D2 by the malfunctioning facility determination program CP11 (S3), creates and stores the malfunctioning facility list, and stores the malfunctioning facility list. It is displayed on the display device 11 (S3).
  • the system stabilization system 10A receives the measurement data D6 and executes the state estimation program CP14 to obtain the node voltage V and the line current for each time section of the power system 100.
  • Information such as I, active power P, reactive power Q, active power P such as load and power generation, and reactive power Q is stored in the stability calculation database 26.
  • the state estimation calculation is a calculation for determining a plausible system state in a specific time section by determining and removing the presence or absence of abnormal data based on the measurement data D6, the facility data D1, and the system data D2.
  • the abnormal data is, for example, data that is clearly separated from neighboring data due to a communication failure or the like.
  • the system stabilization system 10A inputs the state estimation result of the calculation result data D7, the facility data D1, and the system data D2, and calculates the power flow state of the system using the power flow calculation program CP15, and each transmission line of the system. And the voltage and phase angle of each bus are stored in the calculation result database 28 as a tidal current calculation result (S3A).
  • the system stabilization system 10A receives the power flow calculation result of the calculation result data D7, the facility data D1, the system data D2, and the stability calculation data D5, obtains the stability of the system using the stability calculation program CP16, and makes each assumption Whether or not the accident is stable is stored in the calculation result database 28 (S5A).
  • the stability calculation is a method for calculating the stability against a power system accident, for example, one or more of voltage stability calculation, frequency stability calculation, and transient stability calculation. .
  • the stability calculation method is performed according to various stability calculation methods described in PRABHA KUNDUR, The EPRI Power System Engineering Series, Power System Stability and Control, EPRI, (1994).
  • the stability calculation (S5A) corresponds to the stability determination S5 for the assumed accident in the system stabilization process shown in FIG. If the stability is determined to be unstable, a divided region for system stabilization processing is calculated (S6). For all assumed accidents, the stability calculation corresponding to the following step S5 and step S6 are repeatedly executed (S4). The subsequent steps are the same as in the first embodiment. As described above, by calculating the stability based on the online information, it is possible to perform the optimum stability determination in accordance with the state of the system.
  • this invention is not limited to the Example mentioned above.
  • a person skilled in the art can make various additions and changes within the scope of the present invention. For example, if the unhealthy system disconnected from the power system is continuously monitored and it can be determined that the malfunctioning equipment has returned to normal equipment, a control command is output to a predetermined switch, and the system configuration that was unhealthy Can be reconnected to the power grid. For example, when the sensor information can be received normally, when the abnormal value of the sensor information disappears, when the maintenance work is completed and the state of the equipment is restored normally, the predicted disaster does not occur In such a case, the unhealthy system may be returned to the power system.

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Abstract

Selon l'invention, une unité d'acquisition d'informations (1A) acquiert des informations prédéterminées relatives à une circuiterie électrique (2). Une unité de détermination d'équipements fonctionnellement défectueux (1B) identifie des équipements fonctionnellement défectueux en fonction des informations prédéterminées. Une unité de détermination de stabilité (1C) détermine si l'équipement fonctionnellement défectueux est lié à une mesure de stabilisation. Une unité de détermination de zones de division (1D) détermine des zones de division afin de diviser la circuiterie électrique en une circuiterie en mauvais état qui comprend l'équipement fonctionnellement défectueux et une circuiterie en bon état qui ne comprend pas l'équipement fonctionnellement défectueux. Une unité de transmission d'instruction de commande (1F) transmet à un appareil prédéterminé, inclus dans la circuiterie électrique, une instruction de commande afin de diviser la circuiterie électrique en une circuiterie en bon état et une circuiterie en mauvais état. Grâce à ces agencements, s'il se produit un problème touchant un équipement dans la circuiterie électrique, une structure de la circuiterie comprenant l'équipement dans lequel le problème s'est produit peut être isolée avant que ne se produise l'un quelconque d'accidents prévisibles, ce qui assure la fiabilité de la circuiterie électrique.
PCT/JP2012/076378 2011-10-31 2012-10-12 Système et procédé de stabilisation de circuiterie WO2013065469A1 (fr)

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JP7159940B2 (ja) * 2019-03-27 2022-10-25 株式会社デンソー 中継装置
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CN116760190A (zh) * 2023-08-11 2023-09-15 深圳市银河通信科技有限公司 一种多线路互保的智能控制系统
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