Distributed coordinated wide-area control for electric power delivery systems

专利摘要:
Distributed controllers in an electric power delivery system obtain measurements and equipment status, calculate derived values, and determine lED state, and share such with other distributed controllers and coordination controllers. Distributed controllers and coordination controllers further refine measurements, equipment status, derived values, and lED state. Control of the electric power delivery system is coordinated among the distributed controllers and the coordination controllers.
公开号:ES2539301A2
申请号:ES201590027
申请日:2013-09-30
公开日:2015-06-29
发明作者:O. III SCHWEITZER Edmund；E. WHITEHEAD David；C. ZWEIGLE Gregary
申请人:Schweitzer Engineering Laboratories Inc；
IPC主号:

专利说明:

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DESCRIPTION
Coordinated wide area distributed control for electrical power supply systems
5
Technical field
The present disclosure refers to the coordinated distributed wide area control of electric power supply systems. More particularly, the present disclosure is
10 refers to exchange of measures, equipment states, derivative values, and FDI states between controllers. The disclosure also refers to the improvement of the measures, equipment states, derivative values, and FDI status among controllers.
15 Brief description of the drawings
Non-limiting and non-exhaustive embodiments of the disclosure are described, including various embodiments of the disclosure with reference to the figures, in which:
20 Figure 1 is a simplified single-line diagram of an electric power supply system.
Figure 2 is a simplified single-line diagram of an electric power supply system with coordinated distributed wide area control.
25 Figure 3 is an illustration of a communication system for coordinated distributed wide area control.
Figure 4 is a functional block diagram of a distributed controller.
30
Figure 5 is a functional block diagram of a coordination controller.
Figure 6 is a diagram of a communication package.
35 Figure 7 is a simplified single-line diagram of a system for communicating distributed controller conditions using a proxy.
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Figure 8 is a functional block diagram of a distributed controller proxy.
Fig. 9 illustrates a method of a distributed controller that provides a coordinated wide area distributed control 5 in accordance with one embodiment.
Figure 10 illustrates a procedure of a coordination controller that provides a distributed wide area control distributed in accordance with one embodiment.
10 Detailed Description
The embodiments of the disclosure will be better understood with reference to the drawings. It will be readily understood that the components of the disclosed embodiments, as generally described and illustrated in the figures herein, could be arranged and designed in a wide variety of different configurations. Therefore, the following detailed description of the embodiments of the disclosure systems and procedures is not intended to limit the scope of the disclosure, as claimed, but is merely representative of the possible embodiments of the disclosure. In addition, the stages of a procedure do not necessarily have to be executed in an order
20 specifically, or even sequentially, nor the stages should be executed only once, unless otherwise specified.
In some cases, well-known characteristics, structures or functions are not shown or described in detail. In addition, the features, structures, or operations described can be combined in any suitable manner in one or more embodiments. For example, throughout this specification, any reference to "an embodiment" or "the embodiment" means that a particular feature, structure or feature described in connection with the embodiment is included in at least one embodiment. Therefore, the quoted phrases, or variations thereof, as indicated throughout this report, do not necessarily refer to
30 always at the same realization.
Several aspects of the embodiments disclosed in this document can be implemented as software modules or components. As used herein, a software module or component may include any type of computer instruction or computer executable code located within a memory device that is operable in conjunction with appropriate hardware to implement the instructions.
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scheduled. A software module or component may comprise, for example, one
or more physical or logical blocks of computer instructions, which may be organized as a routine, program, object, element, data structure, etc., that performs one or more tasks or implements particular abstract data types.
In certain embodiments, a particular software module or component may comprise disparate instructions stored in different locations of a memory device, which together implement the described functionality of the module. In fact, a module or component can comprise a single instruction or many instructions, and can be distributed in several different code segments, between different programs, and through several memory devices. Some embodiments may be implemented in a distributed computing environment, where tasks are performed by a remote processing device connected through a communications network. In a distributed computing environment, software modules or components may be located on local and / or remote memory storage devices. In addition, the data is linked or left together in a database record can be resident in the same memory device, or through several memory devices, and can be joined in fields of a record in a database through a network.
The embodiments can be provided as a computer program product that includes a non-transient machine readable medium that has stored therein instructions that can be used to program a computer or other electronic device to perform the processes described in this document. The non-transient machine-readable medium may include, but is not imitated, hard drives, floppy disks, optical discs, CD-ROM, DVD-ROM, ROM, RAM, EPROM, EEPROM, magnetic or optical cards, status memory devices solid, or other types of machine-readable media suitable for storing electronic instructions. In some embodiments, the computer or other electronic device may include a processing device such as a microprocessor, microcontroller, logic circuitry, or the like. The processing device may further include one or more special purpose processing devices, such as a specific application interface circuit (ASIC), PAL, PLA, PLD, programmable gate array field (FPGA), or any other device adaptable or programmable.
Electricity generation and supply systems are designed to
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generate, transmit and distribute electrical energy to loads. Electricity generation and supply systems may include equipment such as: machines (electric generators, electric motors, and the like); power transformers, power transmission and distribution lines, circuit breakers, circuit breakers, buses, voltage regulators, capacitor banks, and the like. Such equipment can be monitored, controlled, automated and / or protected by intelligent electronic devices (IED) that receive information from the power supply system from the equipment, make decisions based on the information, and provide monitoring, control, protection outputs and / or equipment automation. In this specification, monitoring, control, protection and / or automation may in general be referred to as "control" unless otherwise specifically indicated.
In some embodiments, an IED may include, for example, remote terminal units, differential relays, distance relays, directional relays, power relays, overcurrent relays, voltage regulator controls, voltage relays, circuit breaker failure relays, relays of generator, motor relays, bay controllers, meters, recloser controls, governors, exciters, STATCOM controllers, static VAR compensator controllers (SVC), regulation changer load controllers (OLTC), and the like. In addition, in some embodiments, the IEDs can be communicatively connected through a network that includes, for example, multiplexers, routers, concentrates, gateways, firewalls, and / or circuit breakers to facilitate communications in the networks. Network and communications devices can also be integrated into an IED and / or be in communication with an IED. As used herein, an IED may include a single discrete IED or a system of multiple IEDs that operate together.
Figure 1 illustrates a simplified diagram of an example of an electric power supply system 100 consistent with the embodiments disclosed herein. The systems and procedures described in this document can be applied and / or implemented in the electric power supply system 100 illustrated in Figure 1. Although illustrated as a single-line diagram for simplicity purposes, an electric power supply system 100 also It can be configured as a three-phase power system. The electric power supply system 100 may include, among other things, electric generators 130 and 131, configured to generate an electric power output, which in some embodiments may be a sine waveform.
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Generators 130 and 131 may be selectively connected to the power supply system using circuit breakers or circuit breakers 111 and 171, respectively. Configuration transformers 114 and 115 may be configured to increase the output of electric generators 130 and 131 of higher sine waveforms. Buses 122 and 123 can distribute the sine waveform of higher voltage to a transmission line 120 between buses 122 and 123. A reduction transformer 146 can decrease the sine waveform voltage of bus 123 to a lower voltage suitable for the distribution of electrical energy on line 142. Distribution line 142 is more selectively connectable to bus 123 through a circuit breaker or switch 144, and can distribute electrical energy to a distribution bus 140. A load 141 (such such as a factory, residential load, motor, or the like) can be selectively connected to the distribution bus 140 using the circuit breaker or circuit breaker 170. It should be noted that additional transformers or other equipment can be used to further decrease a voltage of the distribution bus 140 to the load 141.
Several other equipment may be included in the electric power supply system. A switched capacitor bank ("SCB") 174 selectively connectable to the transmission bus 123 using the circuit breaker or circuit breaker 172 is also illustrated. Other equipment that may be included in the power supply system may include, for example, static VAR compensators , reactors, load regulation changers, voltage regulators, autotransformers and the like. Some of these are considered as included in the electric power system 100, such as, for example, changers of load regulations, which can be considered as part of the load 141. Generators 130 and 131 can be any generator capable of providing electric power to the electric power supply system, and may include, for example, synchronous generators, turbines (such as hydroelectric turbines, wind turbines, gas-powered, coal-powered, and the like), photovoltaic electric generators, tidal generators, wave power generators, and the like. Such generating machines may include components such as electronically coupled interfaces, for example, doubly fed induction machines, AC-DC / CC-AC coupled direct transfer devices, and the like. It should be noted that these are non-exhaustive lists, and other equipment, machines, and connected devices may be considered under this disclosure.
Typically, electric power supply systems have been reliable. However, there is the possibility of events that can drive the power supply systems
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electrical to an unstable state. Generally, instabilities include, for example, rotor angle instability, voltage collapse, frequency deviation, and instability due to the structural limitations of the electric power supply system. Rotor angle instability generally refers to a situation in which a rotating component of a large synchronous machine rotates out of step with another large synchronous machine. An initiating cause of rotor angle instability may be a short circuit that reduces the electrical load on the machine to the point that mechanical energy in the machine accelerates the rotor beyond a point of stability. Voltage collapse generally refers to loads that demand more power than the electric power supply system (or machines thereof) can offer. The voltage then decreases, which translates into additional current consumption. The resulting current levels may result in a greater voltage drop, and the effect continues until the generation is unable to supply the necessary reactive power. Large frequency deviations can be caused by transient imbalances between the supply and consumption of electrical energy. A last type of instability may be due to the structural limitations in the electric power supply system, including the power transfer capacity. An example is when thermal limitations result in lines that are taken out of service.
As mentioned earlier, modern electric power supply systems (which may include electric power generation systems, transmission systems, distribution systems and consumption systems) are controlled with FDI. Figure 1 illustrates several IED 160-167 that can be configured to control the one or more elements of the electrical power supply system 25. An IED can be any device based on the processor that controls the monitored equipment within an electrical power supply system (for example, system 100). FDI can obtain and / or derive a state of the electric power supply system. The status may include the status of the equipment, measurements, derived values, and the status of the FDI. In some embodiments, IEDs 160-167 may gather the status of the equipment of one or more pieces of the monitored equipment (for example, generator 130). The status of the equipment may be related to the status of the monitored equipment, and may include, for example, a circuit breaker
or open or closed circuit breaker, valve position, regulation position, equipment failure, rotor angle, rotor current, input power, automatic voltage regulator status, motor slippage , the setpoint of the power control, the generator exciter settings, and the like. In addition, IED 160-167 can receive measures related to machines or equipment controlled by sensors,
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transducers, actuators, and the like. The measurements may refer to a measured state of the machine or equipment, and may include, for example, voltage, current, temperature, pressure, density, infrared absorption, viscosity, speed, rotation speed, mass, and the like.
With the status and / or measurements of the equipment, the IEDs can be configured to obtain or calculate derived values. Such derived values may be any values derived or calculated from the measurements and / or the state of the equipment and may include, for example, power (real and reactive), magnitudes and angles of the voltages and currents, frequency, rate of change frequency, phasors, synchrophasors, fault distances, differentials, impedances, reactances, symmetric components, alpha components, Clarke components, alarms, and the like.
FDI can also determine a protection or controller condition using the equipment status, measurements, and / or derived values, applied to a model of equipment. The condition of the controller may include, for example, an IED protection status, automation, control or measurement elements, invasion timers, an overcurrent integration position, collection counts to allow a release of a trigger signal, and the like Although reference is made herein in terms of an IED model, the condition of the controller may be a control state of a protection element of an electromechanical relay, as described in more detail below.
IEDs can be used to control various aspects of the electric power supply system. For this purpose, they may include protection elements such as, for example, an instantaneous overcurrent element; an inverse time overcurrent element; a thermal element; a threshold of reactive power; an element of distance; a differential current element; a load delimitation element; an impedance characteristic; a characteristic of volts / Hz; a low voltage element; a directional element; a negative sequence current element; a loss of the excitation element; a negative sequence voltage element; an element of overvoltage; an earth fault element; a high impedance fault element; a low frequency element; an overfrequency element; and the like
In addition, FDI may include control elements, related to the equipment of the electric power supply system. Consequently, an IED can be
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configured as a reactive power controller, a capacitor bank controller, a transformer regulation change controller, an overexcitation generator limit controller, a governor controller, a power stabilizer controller, a reactor reactor bypass, a DC line controller, an inverter controller, and the like. It should be noted that a single FDI can include one
or more protection elements and / or control elements.
According to certain embodiments, IED 160-167 can issue control instructions to the monitored equipment to control various aspects related to the monitored equipment. Typical control actions can be described as being in one of two categories: namely, discontinuous control, and continuous control.
Discontinuous control actions can be described as the modification of a topology of the electric power supply system. Some examples of discontinuous control actions include: the opening of a circuit breaker that disconnects a generator with a rotor angle moving towards instability; the opening of a circuit breaker that eliminates the load that is causing a voltage to decrease towards a state of collapse; the opening of a circuit breaker to eliminate an asset when the asset, such as a line or a transformer, exceeds its safe operating limits; the opening of a circuit breaker that eliminates the load that is causing the system frequency to drop so that it exceeds the predefined operating limits; the insertion of the capacitance in derivation with the effect of the increase of the tension in an electric power line, so that the requirements of the reagent in a generator are not exceeded and, therefore, preventively preventing the generator from being removed from service by means of a reactive power control; the activation of a dynamic brake that counteracts the acceleration of a machine rotor.
Continuous control actions can be described as control actions that do not modify a topology of the electric power supply system. Examples of continuous control actions include: adjusting a point located on a governor to limit the output power of a synchronous machine, so that it does not exceed safe operating limits; simultaneously adjust the set points of other synchronous machines so that they pick up the new load; and adjusting a setpoint of a voltage regulation of an automatic voltage regulator, such that a voltage at a more distant point in the electrical system does not exceed its maximum or minimum voltage threshold.
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As mentioned earlier, FDI may include an FDI model that may include, for example, protection and / or control logic, characteristics of FDI, elements, thresholds, adjustments, and the like. The IED can apply the equipment status, measurements, and / or derived values with the IED model to determine a controller condition and / or control instructions. As described above, the control instructions may be continuous or discontinuous, and may include commands such as circuit breaker tripping, circuit breaker closing, opening or closing restorer, up regulation, down regulation, voltage excitation control, control of the Investor, and the like.
For example, an IED may include an inverse time overcurrent element, and may derive current quantities of a conductor from current measurements thereof. The IED can apply the current quantities to the inverse time overcurrent element to determine the time during which a current of a certain magnitude must persist before issuing an opening (or displacement) order to a circuit breaker. Accordingly, the IED may apply the equipment status, measurements, and / or derived values to an IED model to determine a condition of the controller and / or a control instruction.
An IED (for example, IED 160) may be in communication with a circuit breaker (for example, circuit breaker 111), and may be able to send an instruction to open and / or close the circuit breaker, thus connecting or disconnecting A part of an energy system. In another example, an IED may be in communication with a recloser and be able to control additional closing operations. In another example, an IED may be in communication with a voltage regulator and is capable of instructing the voltage regulator to adjust up or down. Information of the types mentioned above, or more generally, information or instructions that direct an IED or other device to perform a certain action, can generally be indicated as control instructions.
IED 160-167 can be communicatively linked to each other through a data communications network, and can also be communicatively linked to a central monitoring system, such as a monitoring and data acquisition control (SCADA) 182, and / or a wide area control and situation awareness system (WACSA) 180. In certain embodiments, the various components of the power generation and supply system 100 illustrated in Figure 1 may be
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configured to generate, transmit and / or receive GOOSE messages, or communicate using any other appropriate communication protocol. For example, an automation controller 168 can communicate certain control instructions to IED 163 through messages using a GOOSE communication protocol.
The illustrated embodiments are configured in a star topology, which has an automation controller 168 at its center, however, other topologies are also contemplated. For example, IED 160-167 can be communicatively coupled directly to the SCADA 182 system and / or to the WACSA 180 system. Certain IEDs, such as IED 163 and 164, can be in direct communication with each other to perform, for example, a differential line protection of the transmission line 120. The data communications network of the system 100 may use a variety of network technologies, and may comprise network devices such as modems, routers, firewalls, virtual private network servers, and the like. In addition, in some embodiments, IED 160-167 and other network devices (for example, one or more communication switches or the like) may be communicatively coupled to the communications network through a network communications interface.
In accordance with the embodiments described herein, IEDs 160-167 may be coupled in communication with several points in the power supply system 100. For example, IEDs 163 and 164 may monitor the conditions of the transmission line
120. The IED 160 may be configured to issue control instructions to the associated circuit breaker 111. IED 163 and 167 can monitor the conditions on buses 122 and 123. IED 161 can monitor and send control instructions to electric generator 130. IED 162 can monitor and send control instructions to transformer 114. IED 166 can control the operation of the circuit breaker 172 to connect or disconnect the SCB 174. The IED 165 may be in communication with the load center 141, and may be configured to measure the electrical energy in the load center. The IED 165 may be configured as a voltage regulator control for the regulation of the voltage at the load center 15 using a voltage regulator (not shown separately).
In certain embodiments, communication between and / or the operation of different IEDs 160-167 and / or higher level systems (for example, SCADA 182 or WACSA 180) can be facilitated by an automation controller 168. The control controller Automation 168 can also be referred to as a central IED, communication processor,
or access controller. In various embodiments, automation controller 168
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it can be performed as the SEL-2020, SEL-2030, SEL-2032, SEL-3332, SEL-3378, or SEL3530 available from Schweitzer Engineering Laboratories, Inc. of Pullman, WA, and also as described in US Pat. No. 5,680,324, in US Patent No. 7,630,863, and publication of US Patent Application No. 2009/0254655, all of which are incorporated herein by reference.
IEDs 160-167 can communicate a variety of types of information to the automation controller 168, including, but not limited to, operating conditions, status information and control over individual IEDs 160-167, event reports (eg, a failure), communication network information, network security events, and the like. In some embodiments, automation controller 168 may be directly connected to one or more pieces of monitored equipment (for example, electric generator 130 or circuit breakers 111, or 172).
The automation controller 168 may also include a local man-machine interface (HMI) 186. In some embodiments, the local HMI 186 may be located in the same substation as the automation controller 168. The local HMI 186 may be used to change the configuration, send control instructions, retrieve an event report (which may come from a specified IED), retrieve data, and the like. The automation controller 168 may also include a programmable logic controller accessible by local HMI 186.
The automation controller 168 may also be communicatively coupled to a common time source (for example, a clock) 188. In certain embodiments, the automation controller 168 may generate a time signal based on the common time source 188 that It can be distributed to connect communicatively with IED 160-167. Alternatively, IEDs can be connected individually to a common time source. On the basis of the time signal, several IED 160-167 can be configured to collect and / or calculate the operating conditions aligned in time, including, for example, synchrophasors, and to implement the control instructions in a manner coordinated in time. FDI can use the weather information to apply a timestamp to operating conditions and / or communications. In some embodiments, the WACSA 180 system can receive and process time-aligned data, and can coordinate synchronized time control actions at the highest level of the power generation and supply system 100. In other embodiments, automation controller 168 cannot receive
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a time signal, but a common time signal that can be distributed to IED 160-167.
Common time source 188 can also be used by automation controller 168 for time and data sealing information. Time synchronization can be useful for data organization, real-time decision making, as well as post-event analysis. Time synchronization can also be applied to network communications. Common time source 188 may be any time source that has an acceptable form of time synchronization, including, but not limited to, a temperature controlled temperature controlled crystal oscillator, rubidium and cesium oscillators with or without loops of digital phase coupling, microelectromechanical systems (MEMS), which transfer the resonant circuits from the electronics to the mechanical domains, or a Global Satellite Navigation System (GNSS), such as a global positioning system (GPS) with time decoding . In the absence of a discrete common time source 188, the automation controller 168 can serve as the common time source 188 by distributing a time synchronization signal.
As detailed above, the electrical power supply system 100 illustrated in Figure 1 includes local control and protection using IED 160-167, and wide area control using automation controller 168 and / or WACSA 180 and / or SCADA
182.
The present disclosure describes a wide area control system distributed and coordinated by an electric power supply system. Figure 1 illustrates and generally describes a control system for an electric power supply system, where protection and control is carried out locally by means of IED, the operating conditions are communicated to higher level data acquisition and control systems ( such as an automation controller, WACSA and SCADA), and higher level data acquisition and control systems communicate command instructions to IEDs. However, certain information may not be available for FDI to improve control of the power supply system, and certain information from FDI may not be available for higher level data control and acquisition systems for better control. of the power supply system.
Figure 2 illustrates a simplified single-line diagram of a power supply system
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electrical similar to that of figure 1, with a distributed control system coordinated wide area for protection, monitoring, automation and control thereof. In general, operating conditions and controller conditions are shared between distributed controllers and coordination controllers throughout the system, providing each controller with the necessary information to improve automation, protection and control of the electrical power supply system.
Figure 2 includes generators 130 and 131, transformers 114, 115, and 146, buses 122, 123, and 140, transmission line 120, load distribution line 142, load 141, SCB 174, and circuit breakers 111, 144, 170, 171 and 172. Figure 2 also illustrates that part of the equipment may be included in some regions 218 and 217 that may be geographically separated by long distances. The region 218 may include, among others, the generator 130, the transformer 114, the transmission bus 122 and one end of the transmission line 120, and several circuit breakers. Region 217 may include, among others, the other end of transmission line 120, transmission bus 123, transformers 115 and 146, distribution bus 140, generator 131, SCB 174, and various circuit breakers.
Various types of equipment can be controlled by distributed controllers 260
267. Distributed controllers can include the functions of IEDs as described above. That is, distributed controllers can generally obtain the status of the equipment and / or the measurements, derive or calculate values derived from them and determine the conditions of the controllers and control instructions by including the functionality of the IED. The functionality of the IED, as part of an integrated module, may include, for example, protection and / or control logic, characteristics of the IED, elements, thresholds, settings, and the like. Control instructions may include, as described above, commands such as circuit breaker tripping, circuit breaker closing, restoration opening or closing, up regulation, down regulation, excitation voltage control, inverter control, and the like.
As described above in relation to IED functionality, a distributed controller may include, as part of its IED module, an inverse time overcurrent element, and may derive current quantities of a conductor from the measurements of stream of it. The distributed controller can apply the magnitudes of the current to the inverse time overcurrent element to determine the time during which a current of a certain magnitude must persist before issuing an opening (or trip) order to a circuit breaker to protect the supply system
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electric power Consequently, the distributed controller can apply operating conditions to an IED module to determine a controller condition and a control instruction.
Figure 2 illustrates several examples of distributed controllers 260-267 for the control of the electric power supply system 200. The distributed controllers 260-267 can be in communication with the equipment of the electric power supply system 200, they can obtain the status of the equipment and measurements thereof, they can derive or calculate derived values, and apply them to their FDI module. For example, a distributed controller 261 may be in communication with the generator 130 to receive measurements thereof, such as currents, voltages, temperatures, turn signals, and the like, and to receive the status of the equipment thereof. , such as excitation voltages and the like. The distributed controller 261 can derive or calculate derived values such as the magnitude of the voltage and the angle, the magnitude of the current and the angle, the rotational position of the axis, the speed of the axis, the phase angle, the power angle , frequency, rate of change of frequency, and the like. Distributed controller 261 can apply some of the operating conditions to an IED module. For example, distributed controller 261 can request the calculated frequency from an overfrequency element, as part of the IED module, to determine if, and when, a control action must be taken (such as a change of open circuit breaker voltage, exciter , or similar), and then take that action.
Similarly, distributed controller 262 may be in communication with transformer 114, and may calculate or derive magnitudes and angles of current and voltage for high-side windings of the transformer, low-side windings, tertiary windings and the like from voltage and current measurements obtained, and oil temperatures can be obtained from transformer 114. Distributed controller 262 can apply such operating conditions, for example, an IED module to determine if transformer 114 must be taken out of service for certain conditions, such as insulation failure, oil temperature exceeding a threshold, and the like. The IED module may include, for example, a transverse fault element, an overload element, a differential element, a ground fault protection element, and the like.
The distributed controllers 263 and 264 may be in communication with the transmission line 120, and may obtain voltage and / or current measurements thereof, and
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it can derive or calculate magnitudes and / or angles of current and / or voltage, power flow, symmetric components, alpha components, Clarke components, and the like therefrom. Distributed controllers 263 and 264 may be configured to apply differential protection to transmission line 120 and, therefore, the IED module may include, for example, differential protection elements.
Distributed controller 265 may be in communication with a load center 141. In one embodiment, distributed controller 265 may be a meter configured for power measurement at load center 141. In this embodiment, the distributed controller may obtain the measures voltage and / or current 15, and derive or calculate, for example, the magnitudes and / or angles of voltage and / or current, power flow, symmetric components, alpha components, Clarke components, and the like of the same. The IED module of the distributed controller 265 may include measurement algorithms for measuring the flow of power to the load 141.
In another embodiment, the distributed controller 265 can be a voltage control regulator 20 in communication with a voltage regulator configured to regulate the voltage to the load 141. In this embodiment, the distributed controller 265 can obtain the voltage measurements, the current measurements, and the state of the voltage regulator (for example, the regulation position of the voltage regulator). The distributed controller 265 can then derive or calculate the magnitudes and / or angles of current and / or voltage in the voltage regulator, the magnitudes and / or angles of voltage and / or current 25 in a load center, the flow of power, symmetric components, alpha components, Clarke components, and the like. The distributed controller 265 may include an IED module that includes a voltage regulation module configured to control the electrical energy to be within a given voltage band at the load center 141. The distributed controller 265 can apply the state of the equipment, measurements, and values derived to the IED module to determine an appropriate regulation position or change of regulation for the voltage regulator. The distributed controller 265 can then issue a voltage change regulator change order depending on the determination.
The distributed controller 266 may be configured to control the electric power supply system 200 by the control of SCB 174. In this embodiment, the distributed controller 266 can obtain voltage measurements, current measurements and circuit breaker status (for example, from circuit breaker 172). The distributed controller 266
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it can then deduce or calculate magnitudes and / or angles of current and voltage, magnitudes and / or angles of voltage and / or current at a load center, real power, reactive power, symmetric components, alpha components, Clarke components, and the like same. The distributed controller 266 may include an IED module configured to control the reactive power in the electrical power supply system to be within an acceptable range by switching in the SCB 174 when the reactive power falls below a predetermined threshold. Distributed controller 266 can apply the status of the equipment, measurements, and derived values to the IED module to determine whether SCB 174. should be connected. Distributed controller 266 can then issue commands to circuit breaker 172 depending on the determination.
It should be noted that Figure 2 does not include an exhaustive list of examples of electrical power supply system equipment, nor does it include an exhaustive list of possible FDI modules to provide control of the machines or equipment of the electric power supply system . However, the concepts described in this document can be applied to various distributed controllers even if they are not specifically described in this document.
In addition, it should be noted that the IED module may include certain predetermined thresholds and other settings. For example, an inverse time overcurrent element may include settings for the particular system to which the element is applied. On the other hand, predetermined trip times can be set to match the fuse values. Voltage regulation may include adjustments corresponding to acceptable voltage levels. The generator protection elements may require corresponding settings in the protected generator. Similarly, the motor protection elements may require adjustments corresponding to the protected motor. According to this description, said predetermined thresholds and the configuration, together with any thresholds or configurations determined by the IEDs or the system, may be part of the IED module.
Figure 2 also provides an indication of certain electrical power supply system equipment that is included in the same geographic location or substation. For example, region 218 may include a generator 130, a circuit breaker 111, an elevator transformer 114, a bus 122, and part of the transmission line 120. Region 218 can be considered a generation substation. The region 217 may include a part of the transmission line 120, a bus 123, an elevator transformer 115, a
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reducing transformer 146, circuit breakers 144, 170, 171, and 172, an SCB 174, a generator 131, and a bus 140. Regions 218 and 217 may also include devices for protection, control, automation and / or measurement of the supply system electric power For example, region 218 may include distributed controllers 260-263. Region 217 may include distributed controllers 264, 266, and 267.
As described above in relation to Figure 1, electric power supply systems can be controlled using IEDs and higher level controllers, such as automation controllers, WACSA systems, SCADA systems, and the like. Figure 2 further illustrates the highest level controllers that are used to provide distributed distributed control to the electric power supply system.
200. Region 218 includes a station controller 280, and region 217 includes station controller 282. Station controller 280 may be in communication with distributed controllers 260-263. Station controller 282 may be in communication with distributed controllers 264, 266 and 267. Regional controller 290 may be in communication with station controllers 280 and 282, as well as with distributed controller 265. Centralized controller 295 may be in communication with the regional controller 290. Each of the higher level controllers (station controllers, regional controller (s), and centralized controller (s)) can be considered "coordination controllers" for the Purposes of this description.
Coordination controllers and distributed controllers are configured to allow rapid communication of status and controller conditions between distributed controllers and coordination controllers. With the status and controller conditions of other distributed controllers and / or other coordination controllers, each of the controllers is then more suitable to positively influence the distributed and coordinated control of the electric power supply system 200. As will be described. In more detail below, each controller uses the status and controller conditions that are received affecting their control instructions.
It should be noted that communication can take place along any path between any of the controllers - distributed controller or coordination controller. For example, the status and IED module from distributed controller 265 may be directly communicated with regional controller 290, and then distributed to centralized controller 295, and / or station controllers 280 and 282, which may
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distributed to distributed controllers 260-264 and 266-267. Also, state and controller conditions can flow from distributed controllers 260-264 and 266267 to distributed controller 265, regional controller 290 and centralized controller 295 using station controllers 280 and 282. As illustrated, the information may be shared directly between distributed controllers 263 and 264. However, state and controller conditions can also be shared between distributed controllers 263 and 264 through station controllers 280 and 282. As can be seen, there are multiple paths of communication for the distribution of information among the controllers.
Figure 3 illustrates an example of a communication system 300 for the distribution of information between the controllers. The communication system 300 of Figure 3 includes several coordination controllers 304, 306, 308, each in communication over a wide area network (WAN) 318 that may comprise one or more physical connections and protocols. Each coordination controller may be in communication with a number of distributed controllers. For example, coordination controller 304 is in communication with distributed controller 312 using LAN 310, coordination controller 306 is in communication with distributed controllers 314 using LAN 310, and coordination of controller 308 is in communication with controllers distributed 316 using LAN 310.
According to various embodiments of this document, each communication of any of the controllers may include a time stamp. On the other hand, the status of the equipment, and the measures may include time stamps. Status conditions may also include time stamps corresponding to a time in which the measurements were made or the status of the equipment was obtained. Moreover, certain distributed controllers may depend on a common time for sampling the electrical power supply system. Consequently, a common time reference can be distributed to the controllers in this document. In one embodiment, the common reference time may be made available to each of the controllers using WAN 318. Each coordination controller 304, 306, and 308 is configured to receive time signals. For example, as illustrated, coordination controller 304 includes an antenna 320 and is configured to receive a GNSS signal from a repeater or GNSS satellite 302. Coordination controller 304 may be configured to receive another time signal 321 from a source. external time 301. The external time source may comprise one or more VCTCXO, phase lock loop oscillators,
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time-blocking loop oscillators, rubidium oscillators, cesium oscillators, NIST emissions (for example, WWV and WWVB), and / or other devices capable of generating accurate time signals. In the illustrated embodiment, coordination controller 308 includes an antenna 320 configured to receive a GNSS signal from the GNSS repeater or satellite 302. As illustrated, coordination controller 306 does not directly receive an external time signal, however, from According to alternative embodiments, any number and variety of external time signals may be available for any of the time distribution devices.
According to one embodiment, WAN 318 comprises a SONET configured to embed a precision time reference in a header or upper portion of a SONET frame during transmission. Alternatively, a precision time reference can be transmitted using any number of time communication procedures including IRIG, NTP, SNTP protocols, synchronous transport protocols (STP), and / or IEEE 1588 protocols. According to various embodiments, including the transmission through SONET, a precision time reference can be separated and protected from the rest of the WAN network traffic, thus creating a secure time distribution infrastructure.
Distributed controllers 312, 314, and 316 can receive a common time signal from coordination controller 304. In another embodiment, distributed controllers 312, 314, and 316 can receive a common time signal from the repeater or GNSS 302 satellite. .
Figure 4 illustrates a simplified block diagram of a distributed controller 400 according to one embodiment. Each distributed controller module 400 is not required, but it depends on the specific embodiment. Distributed controller 400 includes a network interface 432 configured to communicate with a communication network. The distributed controller 400 also includes a time input 440, which can be used to receive a time signal. In certain embodiments, a common time reference may be received through the network interface 432 and, consequently, a separate time entry and / or GNSS 436 entry would not be necessary. An embodiment of this type may employ the IEEE 1588 protocol. Alternatively, a GNSS 436 input may be provided in addition to or instead of a time input 440.
A monitored machine or equipment interface 429 may be configured to receive
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information on the status of the equipment, and the output control instructions to a piece of monitored equipment, such as an electric generator, circuit breaker, voltage regulator control, or the like. According to certain embodiments, the monitored equipment interface 429 may be configured to interconnect with a variety of equipment in an electrical power supply system. In certain embodiments, the status information of the equipment and the control instructions can be communicated via the communications network interface 432.
A computer readable storage medium 426 may be the repository of one or more executable modules and / or instructions configured to implement any of the processes described herein. A data bus 442 can link the interface of the monitored equipment 429, input time 440, network interface 432, time signal input 436, and computer readable storage medium 426 to a processor 424.
The processor 424 may be configured to process the communications received through the network interface 432, the time input 440, the GNSS input 436, and / or the interface of the monitored equipment 429. The processor 424 may operate using any number of processing speeds and architectures. The processor 424 may be configured to perform various algorithms and calculations described herein using computer executable instructions stored in a computer readable storage medium 426. The processor 424 can be performed as a general purpose integrated circuit, a circuit Integrated application specific, an array of programmable field gates, and other programmable logic devices.
In certain embodiments, distributed controller 400 may include a sensor component.
420. In the illustrated embodiment, the sensor component 420 is configured to collect data from a portion of the power supply system (not shown) using a current transformer 402 and / or a voltage transformer 414. The voltage transformer 414 it can be configured to decrease the voltage (V) of the power system to a secondary voltage waveform 412 that has a magnitude that can be easily controlled and measured by the distributed controller 400. Similarly, the current transformer 402 can be configured to proportionally decrease the power system line current (I) in a secondary current waveform 404 that has a magnitude that can be easily monitored and measured by distributed controller 400. Although the signals are not illustrated separately, the signals voltage and current V and I can be secondary signals obtained from the
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Equipment instruments designed to obtain signals from primary equipment. For example, a secondary voltage signal V can be obtained from a potential transformer ("PT") in electrical communication with a conductor. A secondary current signal I can be obtained from a current transformer ("CT") in electrical communication with a conductor. Several other instruments can be used to obtain signals from electrical power supply systems including, for example, Rogowski coils, optical transformers, and the like. An analog to digital converter 418 can multiplex, display and / or digitize the filtered waveforms to form the corresponding digitized current and voltage signals. Similar values can also be received from other distributed controllers, station controllers, regional controllers or centralized controllers. The values can be in a digital format or another format.
As described above, certain embodiments may monitor the voltage at the terminals of one or more phases of electric power generated by an electric generator. The sensor component 420 may be configured to perform this task. In addition, the sensor component 420 may be configured to control a wide range of features associated with the monitored equipment, including the status of the equipment, temperature, frequency, pressure, density, infrared absorption, radiofrequency information, partial pressures, viscosity, speed, rotational speed, mass, circuit breaker status, valve status, automatic circuit breaker status, regulator status, meter readings, and the like.
The A / D converter 418 can be connected to the processor 424 via a bus 442, through which the digitized representations of the current and voltage signals can be transmitted to the processor 424. As described above, the processor 424 can be used to apply equipment status, measurements and derived values to an FDI module. The processor 424 can be used to determine and issue control instructions.
It should be noted that a separate device may be used instead of a sensor component to provide signals from the power supply system to the distributed controller 400. In fact, a separate device may be configured to obtain signals from the power supply system. (such as voltage and / or current signals), and create digitized representations of the signals (for example current and voltage signals), apply a timestamp and / or provide such information to the
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distributed controller 400. In addition, the separate device can be configured to provide the status of the equipment and / or measurements, such as the magnitudes and / or angles of voltage and / or current along with the time stamps to the distributed controller 400. In certain embodiments, the information that has been described as received from the sensor component 420 in turn is received from the communication network interface 432.
A monitored equipment interface 429 may be configured to receive status information, and output control instructions to a piece of monitored equipment. The monitored equipment interface 429 can be configured to issue control instructions to one or more pieces of the monitored equipment. According to some embodiments, the control instructions can also be issued through the network interface 432. The control instructions issued through the network interface 432 can be transmitted, for example, to other distributed controllers, controllers of coordination, FDI, or the like (not shown), which in turn can issue the control instruction to a piece of monitored equipment. Alternatively, the monitored piece of equipment can receive the control instruction directly through its own network interface.
The computer readable storage medium 426 may be the repository of one or more executable modules and / or instructions configured to apply certain functions described herein. For example, the computer readable storage medium 426 may include an IED module 450, which may include the modules and / or executable instructions for the IED model. As described above, the IED module may include protection algorithms, elements, parameters, timers, and the like. The FDI module 450 may include instructions to derive or calculate derived values, to obtain the status of the equipment, to obtain measurements, and the application thereof to the FDI module. In the application thereof, the IED module 450 can determine the controller conditions, control instructions, state to be communicated, state to store, and the like. Also as noted above, this type of control instructions may be communicated to the monitored equipment using the monitored equipment interface 429. The IED module may also include instructions to apply a time stamp to the status of the equipment when it is obtained, to the measurements, when obtained, at derived values and / or controller condition when they are obtained or corresponding when the relevant measures are obtained, to control the instructions when they are given, and the like.
The computer readable storage medium 426 may further include a storage module.
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distributed controller 460, which may be a repository of the modules and / or executable instructions configured to implement the distributed controller functionality of distributed controller 400. The distributed controller module 460 may include, among others, a status module 461 to process the status , a topology module 462, an evaluation module 463, a component model module 464, and a control module 465. Each module within the distributed controller module can use the status of the IED module 450, from the sensor component 420, from the monitored equipment interface 429, from the time of entry 440, and / or from other distributed controllers, the monitored equipment, or coordination controllers using network interface communications 432.
The status module 461 may include instructions for determining a state of the power supply system that may include the status of the monitored equipment and the condition of the controller. That is, the status may include data to define a status of the monitored equipment 25, for example, measurements (voltages, currents, etc.), the status of the equipment (open / closed circuit breaker, and the like), derived values, and / or controller condition. The measurements, the status of the equipment, and the values obtained can be received from the sensor component 420, from the communications network interface 432, or from the monitored equipment interface 429. The measurements can be received with the time stamps or they can be Issue a corresponding time stamp by using the time signal input 436, or the time received from the communication network interface 432, as described above. The protection or controller condition can be received from external IED devices using the sensor component 420, or the interface 432, or the monitored equipment interface 429. The status module 461 may also include instructions for obtaining this network status information. of the IED 450 module communication, and the IED 450 module can also include instructions for calculating a protection or controller condition. The status module 461 may include instructions for deriving said status information on the basis of a model from the component model module 464, which will be described in more detail below. The status module 461 may further include instructions for refining the information from the IED module 450 based on a model from the component model module 464. The status of the module 461 can refine the values using a filter, such as a filter. Low pass The status module 461 can redefine the values by comparing the values against the expected intervals and / or other recent measurements. When such values are not acceptable based on expected intervals and / or other recent measurements, the values may be indicated as potentially inaccurate. As described in more detail at
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Then, the communication module 470 may include instructions for sending information from the status module 461 to other distributed controllers and / or coordination controllers, and include the information with the indication that such information may be inaccurate.
The topology module 462 may include instructions for determining a topology of at least a part of the electrical power supply system. The topology module 462 may receive information regarding the topology of the electric power supply system from, for example, a user, other distributed controllers or coordination controllers, or the like. The topology information may be limited by the user to include a portion of the topology power of the power supply system. Topology module 462 may include instructions for modifying stored topology information based on status. For example, if the distributed controller receives information regarding the open or closed state of a circuit breaker, the topology module 462 can be configured to update its topology based on the information received on the open or closed state of the circuit breaker. In addition, the topology processor 462 may be configured to use values such as currents and / or voltages to determine the topology. For example, Kirchhoff's law can be used to determine the nodes of the topology are connected to which other nodes of the topology and, therefore, the topology can be updated using such information. Additional procedures for determining a topology are found in US Patent No. 7,856,327 entitled "State and Topology Processor" which names Edmund O. Schweitzer, Marcos A. Donolo, and Armando Guzman-Casillas as inventors, which is incorporated herein by reference in its entirety.
Evaluation module 463 includes instructions to indicate the proximity to limits, which may indicate the proximity of the IED module 450 of distributed controller 400 or another controller, such as an external IED (which may also include protection or condition of the controller and communicate it through the components of the sensor 420, or the communication network interface 432, or the monitored equipment interface 429) to reach a condition where a control instruction can be issued. The control may be related to a continuous or discontinuous control operation. A discontinuous control operation may change the topology of the power supply system or result in reaching a capacity limit of the equipment or a controller. For example, evaluation module 463 may use the status and information of the model as part of the IED module 450 to determine that a circuit breaker must be opened, due to a condition of
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overcurrent in a certain amount of time if the condition persists (and no other actions are taken to correct the overcurrent condition). In another example, evaluation module 463 may determine a time before a controller (such as a distributed controller or an external IED, which may also include protection or condition of the controller) issues a command to a synchronous machine to decrease the amount of reactive power produced by the synchronous machine due to the rotor field, reaching a thermal limit of excessive reactive power that is supplied by the synchronous machine. Such information may be communicated to other distributed controllers and / or coordination controllers using communication module 470 as described in more detail below.
Therefore, information on the actions to be taken in the future by the distributed controller 400 and / or a time before such actions are to be taken may be communicated to other distributed controllers and / or coordination controllers. The status modules and component model modules of other distributed controllers and / or coordination controllers could then use this information to determine the status and / or model of the electric power supply system. By providing this information to other distributed controllers and / or coordination controllers, error modeling and / or complexity thereof can be reduced.
The component model module 464 may include instructions for determining a model of the electric power supply system. The component model module 464 may include instructions for interpreting the status determined by the status module 461 and / or the topology determined by the topology module 462. In the protection, automation, control, and / or measurement of A power supply system, different information may be available for different devices. That is, the devices can be manufactured by different entities, including different settings or thresholds, and the like, and can, therefore, provide different information. The component model module 464 may include instructions to improve this different information. The component model module 464 may include instructions to provide an estimate when certain status information is not available. For example, if a measurement normally provided by a sensor is not available, the component model module 464 can use a state from the state module 461 and / or a topology of the topology module 462 to provide an estimate of the measurement that lack. In another example, if a distributed controller or an IED is not configured to provide a derived value, the component model module
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464 can use a state of state module 461 and / or a topology of topology module 462 to provide an estimate of the missing derived value. In another example, if a device status is not present, the component model module 464 may use a status of the status module 461 and / or a topology of the topology module 462 to provide an estimate of the status of the missing equipment. The component model module 464 may include instructions for supplying a time stamp with estimates. In addition, as with the status module 461, the component model module 464 may be configured to indicate the estimated information.
In addition, the component model module 464 may include instructions for determining an equipment model. The component model module 464 can model, for example, a protection algorithm of a device model (either an IED 450 or an external IED), and execute the protection algorithm with the same inputs (device status, measurements , and / or derived values provided from the distributed controller
or estimated by the component model module 464) as the protection algorithm would use. The component model module 464 can then use the execution to determine the state of the equipment model. Such status can be used by evaluation module 463.
The component model module 464 can also be used to calculate the future state. Accordingly, the component model module 464 may include a simulation motor of the load flow level and / or a simulation motor of the transient level. A load flow motor can be used to calculate the dynamics such as, for example, related to the voltage drop and the elimination of assets due to overload. The transient level simulation engine can be used for the calculation of dynamics such as, for example, related to rotor angle instability. These simulations can be applied to any measures initial state and / or controller conditions, received from status module 461, to determine a future state of the electric power supply system. Such a future state can be used by distributed controllers and / or coordination controllers to make control decisions before when such decisions would normally be made in systems where information is only available when measured. A prediction interval may be based on a packet transmission interval or a subset of intervals. Consequently, each time a new set of states and measurements is received, a simulation can provide another set of future status information, based on the new initialization information. As described in more detail below, the
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Component model module 464 can receive control instruction suggestions from other distributed controllers and / or coordination controllers. The component model module 464 can use such instructions in its determination of possible future states of the electric power supply system.
The control module 465 may include instructions for determining a control instruction based on the outputs of the component model module 464, the evaluation module 463, the topology module 462, the status module 461, and / or the IED module
450. The control instructions from the control module 465 may be conceived as control instructions to be taken for other distributed controllers and / or coordination controllers, and may be related to machines or equipment in communication with other distributed controllers. In some cases, the control instructions may only be informative or suggestive in nature in which the distributed controller that receives them is not required to perform the control instruction, but may use the suggested control instruction in coordination with its own determinations. and those of other controllers to determine if the control instruction will be carried out. That is, the distributed reception controller may use the suggested control instruction to determine a future state of the power supply system using its component model module, and use the result of its component model module to issue an instruction. Control your monitored equipment. In other cases, control instructions may be directive because actions are required. Differentiation between these cases can be included with the control instruction.
The communication module 470 may include instructions regarding the information communication of the IED module 450, the distributed controller module 460, the status module 461, the topology module 462, the evaluation module 463, the component model module 464, and / or control module 465 to other controllers. Communication module 470 may include instructions on the communication format according to a predetermined protocol. For example, distributed controllers and controllers can be configured to communicate according to the IEC 61850 protocol, in which the communication module 470 can be configured for format communications according to that protocol, receive communications according to that protocol, and set the information available to other modules. The communication module 470 can be configured with the subscribers with certain information, and headers of the format messages according to said subscription information. Communication module 470 can be configured for format communications
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according to a package structure, such as that illustrated in Figure 6 and described in more detail below.
It should be noted that the various modules of the distributed controller module 460 may be configured to use the status and / or controller conditions from other distributed controllers and / or in other coordination controllers. As described herein, the status and controller conditions can communicate between distributed controllers and / or coordination controllers, and are used within several of the modules thereof. For example, a distributed controller may use the topology determined by another controller distributed in its evaluation module to determine the lack of the status information thereof.
Figure 5 illustrates a functional block diagram of a coordination controller 500 in accordance with the present description. Not every 500 distributed controller module is required, but it depends on the specific embodiment. As described above in relation to Figure 2, distributed controllers may be in communication with the equipment of an electrical power supply system. Distributed controllers may communicate the information directly to other distributed controllers and / or coordination controllers such as station controller (s), regional controller (s), and / or centralized controller (s), such as the coordination controller 500. Each of the station, regional, and centralized controllers may perform similar functions, but include different levels of control and / or granularity of the data. For example, a regional controller may include a topology module that determines a topology of a portion of the power supply system monitored by each of the distributed controllers, which sends information to the particular regional controller, while station controllers may include a topology module that determines a topology of the power supply system monitored by each of the distributed controllers, which send information to the particular station controller.
Similar to the distributed controller 400 illustrated in Figure 4, the coordination controller 500 of Figure 5 may include a time signal input 536, a time input 540, a communications network interface 532, and a processor 524 The coordination controller 500 may not receive the measurements or the status of the equipment directly from a machine or equipment 30, so it may not include a monitored equipment interface. A data bus 542 can link a time input 540,
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532 network interface, 536 time signal input, and 526 computer readable storage medium with a 524 processor.
The computer-readable storage medium 526 may include modules similar to those of the distributed controller 400 of Figure 4. However, the computer-readable storage medium 526 may lack an IED module. The computer readable storage medium 526 may include a coordination controller module 560 which may be a repository of the modules and / or executable instructions configured to implement the coordinated controller functionality of the coordination controller 500. The coordination controller module 560 may include, among others, a status module 561, a topology module 562, an evaluation module 563, a component model module 564, and a control module 565. Each module within the coordination controller module 560 can use information from distributed controllers and / or other coordination controllers. For example, the modules within the coordination controller module 560 can use the conditions of the state controller and / or the controller communicated from the distributed controllers and / or other coordination controllers on the communication network interface 532. The modules within the 560 coordination controller module can also use time information from time input 540.
The status module 561 may include instructions for determining a state of the power supply system, which may include the status of the monitored equipment and the condition of the controller. That is, the status may include data to define a status of the monitored equipment, for example, measurements (voltages, currents, etc.), the status of the equipment (open / closed circuit breaker, and the like), derived values, and / or the condition of the controller, which can be provided to the coordination controller from distributed controllers. The status module 561 may include instructions for obtaining said status information from the communication module 570. The status module 561 may include instructions for deriving said status information on the basis of a model from the component model module 564, which It will be described in more detail below. The status module 561 may further include instructions for filtering the information of a model generated by the component model module 564. The status module 561 can refine the values using a filter 25, such as a low pass filter. The status module 561 can redefine the values by comparing the values with the expected intervals and / or other recent measurements. When such values are not acceptable based on expected intervals and / or other recent measurements, the
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Values can be indicated as potentially inaccurate. As described in more detail below, communication module 570 may include instructions for sending information from status module 561 to distributed controllers and / or other coordination controllers, and include information with the indication that such information It may be inaccurate.
Topology module 562 may include instructions for determining a topology of at least a portion of the electrical power supply system. The topology module 562 may receive information regarding the topology of the electric power supply system from, for example, a user, distributed controllers or other coordination controllers, or the like. The topology information may be limited by the user to include a part of the topology of the electric power supply system. Topology module 562 may include instructions for modifying stored topology information based on status. For example, if the distributed controller receives information regarding the open or closed state of a circuit breaker, the topology module 562 may be configured to update its topology based on the information received on the open or closed state of the circuit breaker. In addition, topology processor 562 may be configured to use values such as currents and / or voltages to determine the topology. For example, Kirchhoff's law can be used to determine the nodes of the topology that are connected to what other nodes of the topology and, therefore, the topology can be updated using such information. Additional procedures for determining a topology are found in US Patent No. 7,856,327 entitled "State and Topology Processor" which names Edmund O. Schweitzer, Marcos A. Donolo, and Armando Guzman-Casillas as inventors, which is incorporated herein by reference in its entirety.
The evaluation module 563 includes instructions to indicate the proximity to the limits, which may indicate how close an IED model (from, for example, a distributed controller, the component model module 564, or other coordination controller) It is towards the achievement of a condition where a control instruction can be issued. The control may be related to a continuous or discontinuous control operation. A discontinuous control operation may change the topology of the power supply system or result in reaching a capacity limit of the equipment or a controller. For example, evaluation module 563 can use a model of equipment and the state to determine that a control instruction will be issued to open a circuit breaker due to an overcurrent condition in a certain amount of time if the condition
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persists (and no other actions are taken to correct the overcurrent condition). In another example, evaluation module 563 may determine a time before a controller (such as a distributed controller) issues a command to a synchronous machine to decrease the amount of reactive power produced by the synchronous machine because the rotor field it reaches a thermal limit of excessive reactive power that is supplied by the synchronous machine. Such information may be communicated to distributed controllers and / or other coordination controllers using communication module 570 as described in more detail below.
Therefore, information on the actions to be taken in the future by a distributed controller and / or a time before such actions must be taken may be communicated to distributed controllers and / or other coordination controllers. The status modules and component model modules of distributed controllers and / or other coordination controllers could then use this information to determine a state and / or the model of the electric power supply system. By providing this information to distributed controllers and / or other coordination controllers, error modeling and / or complexity thereof can be reduced.
The component model of module 564 may include instructions for determining a model of the electric power supply system. The component model module 564 may include instructions for interpreting the status determined by status module 561 and / or the topology determined by module 562. In the protection, automation, control and / or measurement topology of a supply system Electric power, different information of different devices may be available. That is, the devices can be manufactured by different entities, include different settings or thresholds, and the like, and can, therefore, provide different information. The component model module 564 may include instructions to improve this different information. The component model module 564 may include instructions to provide an estimate when certain status information is not available. For example, if a measurement normally provided by a sensor is not available, component model module 564 can use a state from state module 561 and / or a topology of topology module 562 to provide an estimate of the measurement of missing equipment status. In another example, if a distributed controller or an IED is not configured to provide a derived value, component model module 564 can use a state of state module 561 and / or a topology of topology module 562 to provide an estimate. of the missing derivative value. In
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Another example, if a device status is not present, the component model module 564 may use a status from the status module 561 and / or a topology of the topology module 562 to provide an estimate of the status of the missing equipment. The component model module 564 may include instructions for supplying a time stamp with estimates.
In addition, the component model module 564 may include instructions for determining an equipment model. The component model module 564 can model, for example, a protection algorithm of a device model, and execute the protection algorithm using the same inputs (equipment status, measurements, and / or derived values provided from the controller distributed or estimated by the model module component 564) as the protection algorithm would use. The component model module 564 can then use the execution to determine the state of the equipment model. Such status can be used by evaluation module 563.
The component model module 564 can also be used to calculate the future state. Accordingly, the component model module 564 may include a simulation motor of the load flow level and / or a simulation motor of the transient level. A load flow motor can be used to calculate the dynamics, such as, for example, those related to the voltage drop and the elimination of assets due to overload. The transient level simulation engine can be used for the calculation of dynamics such as, for example, related to the instability of the rotor angle. These simulations can be applied to the initial state measures to determine a future state of the electric power supply system. Such a future state can be used by distributed controllers and / or coordination controllers to make control decisions before when such decisions would normally be made in systems where information is only available when measured. A prediction interval may be based on a packet transmission interval or a subset of intervals. Consequently, each time a new set of states and measurements is received, a simulation can provide another set of future status information, based on the new initialization information. As described in more detail below, the component model module 564 may receive suggestions for control instructions from other distributed controllers and / or coordination controllers. The component model module 564 can use these instructions in determining possible future states of the electric power supply system.
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The control module 565 may include instructions for determining a control instruction based on the outputs of the component model module 564, the evaluation module 563, the topology module 562, and / or the status module 561. The instructions for Control from control module 565 may be understood as control instructions for distributed controllers and / or other coordination controllers for issuance, and may be related to machines or equipment in communication with distributed controllers. In some cases, the control instructions may only be informative or suggestive in nature in which the distributed reception controller is not required to perform the control instruction, but may use the suggested control instruction in coordination with its own determinations and those of other controllers to determine if the control instruction will be carried out. That is, the distributed reception controller may use the suggested control instruction to determine a future state of the electric power supply system using its component model module and use the result of its component model module to issue a power instruction. Control your monitored equipment. In other cases, control instructions may be directive because they may require actions. Differentiation between these cases can be included with the control instruction.
The communication module 570 may include instructions on the communication of the information of the coordination controller module 560, the status module 561, the topology module 562, the evaluation module 563, the component model module 564, and / or the 565 control module to other controllers. Communication module 570 may include instructions on the communication format according to a predetermined protocol. For example, distributed controllers and controllers may be configured to communicate according to the IEC 61850 protocol, in which the communication module 570 may be configured for format communications according to that protocol, receive communications according to that protocol , and make its information available to other modules. The communication module 570 can be configured with the subscribers for certain information, and headers of the format messages according to that subscription information. The communication module 570 may be configured for format communications in accordance with a packet structure such as that illustrated in Figure 6 and is described in more detail below.
Top-level controllers can include information and modules that are more
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scarce than lower level controllers. For example, a central controller may include the topology and status information of the main power supply routes through a wide area, while the station controllers may include specific topology and status information for each driver and monitored equipment. within a particular substation.
In addition, lower level controllers may be configured to communicate less data to higher level controls. For example, a station controller may be configured not to send all measurements to regional or central controllers.
The distributed wide area coordinated control system can act to resolve instabilities in the electric power supply system. Control actions are taken by distributed controllers, as they are connected to the equipment, including circuit breakers, field limiters, capacitor banks, bypass reactors, general loads, motors, generators, and the like.
A source of management in terms of the necessary control actions is any of the controllers in the distributed wide area control system distributed: distributed controllers, station controllers, regional controllers or central controllers. The specific details on how these commands are communicated may be in accordance with any protocol useful for the communication of information of the electrical power supply system, such as, for example, IEC-61850, MirroredBits®, rapid operation protocol, and the like.
One form of communication control is through recipes. Recipes can be used to communicate a series of actions that specific teams must take at specific times. Such actions and associated times or delay times can be communicated from a coordination controller to distributed controllers. These communications may include the specific measures that must be taken along with the specific times to take these actions, or times to wait after taking the first or previous action. For more information regarding prescriptions, US publication numbers 2011/0035065, 2011/0035066, and 2011/0035076 are included in the patent applications, each of which is incorporated herein in its entirety.
Each controller, be it the distributed controller or the coordination controller, can
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collect the information that has been subscribed from the other controllers in the network. Consequently, a controller that subscribes to the information of another controller may be a subscription controller. It should be noted that any controller (distributed controller or coordination controller) can be a subscription controller on any other controller in communication with it. The controller can then combine this information with certain information, such as, for example, equipment status, measurements, derived values, status, models, and / or topology status information. The controller then performs the action, either based on a current system state or based on a prediction of the future system state.
Discontinuous and continuous control can be applied regularly through IED and / or distributed controllers. This disclosure brings new information, and devices to collect, distribute and simplify this new information, so that they can improve the performance of discontinuous and continuous control. The incorporation of the status and controller conditions can be used to predict the next states of the power system, which can make it possible for the distributed controllers in the distributed wide area control system distributed to take a cost control action lower and to do it in a more timely manner than is possible with existing procedures.
An additional control made possible by the distributed wide area coordinated control system is through indirect control. The status information and conditions of the controller can be measured and / or modeled using the distributed wide-area coordinated control system, and are used to correct a trajectory before measurements are taken, if such a correction provides a better means to control the feeding system that an existing discontinuous or continuous control action.
In one example, an IED module may be configured to eliminate a service transformer after the current levels through the transformer have exceeded a threshold for a certain period of time. The information and status conditions of the controller (through the status module, the evaluation module, the component model module, or other modules) can have information on that threshold and the time it is until the transformer leaves to disconnect Also, because the state and conditions of the regulator have been shared and synchronized over time, this makes it possible to determine if the current is transiently exceeding the threshold or if another control action can be taken to reduce the current. So he
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Distributed controller can coordinate an alternative control and can set a reference point of the IED module, in a way that avoids the elimination of the service transformer, while avoiding the transformer exceeding a safe operating limit. If the current is transiently higher than the threshold, then it may be sufficient to temporarily modify the setpoint, thus allowing the transformer to remain in service even though it had been removed from service if the setpoint had not been modified, then returns the reference point to its previous value once the transient has passed. This is a form of indirect control because the feeding system has been controlled, but without modifying its topology. In addition, a protection algorithm of the IED module itself has not received new inputs; It is just the set point that fits. Alternatively, if another control is required and is issued by the distributed coordinated wide area control system, then the setpoint is modified temporarily while the other control operates. The setpoint value can then be returned to its original value. For example, the other control can open a circuit breaker to eliminate load, so that the threshold is not exceeded. This may allow time for the other control to act and to avoid the elimination of load and transformer.
Communication between the controllers may be in accordance with a predetermined protocol (distributed controllers and / or coordination controllers). In one example, packet-based communication is used. A communication protocol may be particularly designed to define a package for communication of the status conditions and the controller. The protocol can be defined to avoid sending repeated information. Figure 6 illustrates an example of a package 600 for communication of the operating and controller conditions between the controllers of the present description.
As described above, each controller can determine the status conditions and the controller. This may include status information of a status module, topology information of a topology module, evaluation information of an evaluation module, model information from a component model module, and control information from a control module Consequently, package 600 is designed to include separate sections for each type of information.
Package 600 includes a header and a time stamp section 602 to include the header information, as well as a time stamp related to the information in the
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package. The header information may include communications network header information such as the destination address, the source address, and the like.
The packet 600 may also include a status section 604 for status information, which may include, for example, the status of the equipment, the measurements, the derived values, and / or the condition of the controller; a topology section 606 to obtain topology information; an evaluation section 608 for evaluation information; a model 610 section for model information; and a control section 612 for control information.
Each packet 600 does not need to contain each of the status sections 604, topology 606, evaluation 608, model 610, and control 612. Only the necessary information can be sent. The inclusion of a section may depend on whether the relevant information is required to be a section for communication.
Packages can be sent at regular intervals and / or upon request. Packages can be sent to subscription drivers. The dynamics of electric power supply systems can vary over a wide range of time scales. The dynamics of the electric power supply system can change at a sub-cycle speed, that is, faster than 60 times per second for a 60 Hz power supply system. But a lot of synchronous machine dynamics can change to a slower pace For example, a voltage controller may have a transient response of the order of one second and a governor may have a transient response of the order of tens of seconds. The dynamics of load control, such as bypass transformers in some cases is even slower, like, in the order of minutes. A packet transmission interval may depend on the type of phenomena under control. A typical update rate is 60 packets every second, each starting at the beginning of the second and then continuing at intervals of 1/60 seconds after that point, and they are repeated again at the beginning of the next second. The packet transmission time can be set by timing each controller which, as described above, can be shared by all devices in a distributed wide area coordinated system.
Although a particular package design is illustrated in Figure 6, this description is not limited to any particular package design. Any package design or communication protocol capable of communicating the information described in this document can be
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used.
The transmission of a device model can provide certain advantages in maintaining consistency and accuracy among various devices in an electrical power supply system. When a device parameter from a first is transmitted to a second device and incorporated into a device model generated by the second device, certain aspects (for example, consistency, compatibility, etc.) may arise. These problems can be avoided in a system where the devices transmit complete device models.
The wide area coordinated distributed control system for electric power supply systems of the present disclosure can be used in combination with various electric power supply systems. It is appreciated that electric power supply systems may include control devices of many types and functionalities, from different manufacturers, and the like. In fact, it has been observed that electric power supply systems may even include electromechanical protection devices. Protection and control devices, whether currently in use or for future execution, may not be able to, designed to, or configured, to provide information intended to be shared between controllers in accordance with the present disclosure. For example, IEDs may not be configured to share status, as well as controller conditions.
It should be noted that certain microprocessor-based FDI can be reprogrammed with instructions to derive and exchange information in accordance with this disclosure. For example, a firmware update that includes a distributed controller module or a coordination controller module may be possible for certain existing IEDs and automation controllers. In addition, future IED communications devices, automation controllers, and the like, can be designed with distributed controller modules and / or coordination controller modules in accordance with the present disclosure.
However, to facilitate the control of wide coordinated area distributed in an electrical power supply system with devices that do not derive and / or share information in accordance with this description, a proxy device is also disclosed to facilitate the derivation and exchange of information in accordance with this disclosure.
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Figure 7 illustrates a simplified single-line diagram of a portion of an electrical power supply system using an IED 263 and a proxy 702 in accordance with the disclosure. The power supply system may include a bus 122 and a transmission line 120 protected by an IED 263, which can obtain signals from the bus 122 and the transmission line 120. The IED can perform protection algorithms by means of the status of the equipment, measurements, derivative values, and an FDI model thereof. The IED 263 may operate the circuit breaker 710 to selectively disconnect the transmission line 120. The IED 263 may be configured to derive only certain values by its equipment model, and may be configured only to communicate certain information. For example, IED 263 may be configured to communicate voltage and current magnitudes and angles.
Proxy 702 can be configured to receive certain state of the equipment, measurements, and / or values derived from IED 263, and derived values are also derived or calculated, the condition of the controller, as well as the conditions of the controller (such as conditions of distributed controllers) of IED 263. Proxy 702 can also be configured to communicate the status, as well as the conditions of the controller to coordination controller 750. Proxy 702 can also be configured to receive status and / or controller conditions of other controllers through coordination controller 750.
Figure 8 illustrates a functional block diagram of proxy 702. Not all proxy modules 702 are required, but it depends on the specific embodiment. Proxy 702 includes a network interface 832 configured to communicate with a communication network and / or a coordination controller. Proxy 702 also includes a time input 840, which can be used to receive a time signal. In certain embodiments, a common time reference may be received through network interface 832, and, consequently, a separate time entry and / or a GNSS 836 entry would not be necessary. An embodiment of this type may employ the IEEE 1588 protocol. Alternatively, a time signal input 836 may be provided in addition to or instead of a time input 840.
An IED 802 interface may be configured to receive certain states of available equipment, measurements, derived values, and / or control instructions, and send certain status information and / or control instructions to an IED. In accordance with certain embodiments, the IED 802 interface can be configured to interface with a
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variety of FDI from an electric power supply system. In addition, according to another embodiment, an electromechanical relay can be used instead of an IED. In this embodiment, certain information can be obtained from the electric power supply system. For example, the same instruments used by the electromechanical relay (such as CT, PT, and the like) can provide information to proxy 702. In this case, proxy 702 may include a sensor component such as that illustrated in Figure 4.
A computer readable storage medium 826 may be the repository of one or more executable modules and / or instructions configured to implement any of the processes described in this document. A data bus 842 can link the IED 802 interface, the input time 840, the network interface 832, the time signal input 836, and the computer readable storage medium 826 with a processor 824.
The processor 824 may be configured to process the communications received through the network interface 832, the input time 840, the time signal input 836, and the IED 802 interface. The processor 824 can operate with any number of processing speeds and architectures. The processor 824 may be configured to perform various algorithms and calculations described herein using computer executable instructions stored in a computer readable storage medium 826. The processor 824 can be performed as a general purpose integrated circuit, an integrated circuit of specific application, a field programmable door array, and other programmable logic devices.
An IED 802 interface can be configured to receive status information, and issue control instructions to an IED. The IED 802 interface may be configured to issue control instructions to one or more IEDs. According to some embodiments, the control instructions may also be issued through the network interface 832. The control instructions issued through the network interface 832 may be transmitted, for example, to distributed controllers, coordination controllers, IED, or similar (not shown), which in turn can issue the control instruction to a piece of monitored equipment. Alternatively, the monitored piece of equipment can receive the control instruction directly through its own network interface. The control instructions may also include an instruction to modify the IED module 20 (for example, a setting or threshold thereof).
The computer readable storage medium 826 may be the deposit of one or more
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modules and / or executable instructions configured to apply certain functions described in this document. For example, the computer readable storage medium may include IED module 850, which may include the modules and / or executable instructions for the IED model 25. As described above, the IED model may include protection algorithms , elements, settings, thresholds, timers, and the like. The IED module 850 may include instructions to derive or calculate derived values, to obtain the status of the equipment, obtain measurements, and apply them to the equipment model. In applying them to the equipment model, the IED module 850 can determine control instructions to be made, status to be communicated, state of storage, and the like. Also as noted above, this type of control instructions may be communicated to the monitored equipment and / or to an IED through the IED 802 interface. The IED module may also include instructions for applying a time stamp for the status of the equipment. , when it is obtained, to the measures, when they are obtained, to the derived values and / or to the state of protection or controller when they are obtained, or corresponding when the measures that lead to them are obtained, to control the instructions that are given , and the like.
The IED module 850 can be obtained from a connected IED, it can be programmed at the set time, or it can be determined by proxy 702 based on observations of the information delivered from the IED and IED control instructions. Proxy 702 can include several default IED models that can be selected at the set time. For example, if the IED includes an overcurrent element, the proxy 702 may include several overcurrent elements to be selected, and the user can select the overcurrent unit most closely related to the overcurrent element of the IED. Alternatively, an IED module could be configured to select a predetermined IED model based on observations of the IED communications and / or control instructions. For example, the IED can communicate corresponding measurements and derived values with current quantities, and the corresponding control instructions with the opening of a circuit breaker. The IED module can observe the threshold (s) and durations (s) in which the subjects of the IED control the instructions for opening a circuit breaker, and use this information to select an appropriate overcurrent element from a plurality of overcurrent elements. Similarly, an IED can be a voltage regulator controller, and can communicate voltage measurements and issue regulation change commands. The IED module can select appropriate voltage bands according to the observed voltages and measured commands.
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The computer readable storage medium 826 may further include a distributed controller module 860, which may be a repository of modules and / or executable instructions configured to implement the distributed controller functionality of proxy 702. The distributed controller module 860 may include , among others, a status module 861, a topology module 862, an evaluation module 863, a component model module 864, and a control module 865. Each module within the distributed controller module can be similar to Similar models of Figure 4 described above.
The communication module 870 may include instructions on the communication of the information of the IED module 850, the distributed controller module 860, the status module 861, the topology module 862, the evaluation module 863, the component model module 864, and / or the 865 control module to other controllers, as described above. Communications module 870 may also include instructions regarding the communication of information to the IED. Since IED module 850 can be configured to receive certain information in a certain format from other IEDs and / or controllers, communication module 870 can be configured to obtain such information, format how the IED can wait to receive it, and send said information to the IED.
Figure 9 illustrates a method 900 of a distributed controller that provides a coordinated wide area distributed control for an electrical power supply system in accordance with one embodiment. It should be taken into account from the previous description that each distributed controller (or proxy) provides a distributed control to the associated equipment, where each one makes its own determination as to control the actions to be taken. However, the control is coordinated, because the state and controller conditions are communicated in coordination throughout the scope of the control actions.
Procedure 900 begins in 902 with a distributed controller that receives measurements and / or the status of the equipment, protection or condition of the controller from the monitored equipment 904. The procedure can seal the measurements in time. A distributed controller also receives a communication packet from a controller 906, such as another distributed controller or a coordination controller. As described above, the package may include status and controller conditions. That is, the package can include a time stamp, status information, topology information,
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evaluation information, model information, and / or control information associated with a particular controller or controllers.
The procedure can calculate the status of measurements and the status of equipment 908 from the monitored equipment. The state can be time stamping. Such status, as well as package information, may be used by the procedure to determine the refined state, topology, evaluation, model and suggested control instruction information 910. The information may be aligned in time using stamps. of time associated with it. That is, in one embodiment, the time stamps can be compared so that the state of the controller and the state distributed from the package are marked with the same time instant. The procedure can convey the determined state, topology, evaluation, model and / or suggested control instruction 912. As described above, the FDI module can be modified due to coordinated control instructions, for example, by modifying Temporarily a threshold, setting, or the like.
As described above, the status information can be refined in the various modules and determinations made in 910. The values and / or the derived status can be applied to a device model 914 and the procedure can determine and issue a control instruction 916 .
Figure 10 illustrates a procedure 1000 for a coordination controller that provides a coordinated distributed control over the entire area for an electrical power supply system in accordance with one embodiment. Procedure 1000 begins at 1002 and receives a packet from another controller 1004. As described herein, the packet can be received from a distributed controller and / or from another coordination controller. The procedure then determines the status conditions and the controller. For example, the procedure determines the status information, the topology information, the evaluation information, the model information, and / or the information of the suggested control instruction 1006. The procedure transmits the status information, the information of topology, evaluation information, model information, and / or suggested control instruction information 1008 to the subscribers who subscribe.
In a specific example that can be described in relation to Fig. 2, an electric power supply system 100 could lead to voltage collapse. A controller
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Distributed 261 receives the status of the equipment and the status measurements from the generator 130, which includes a voltage and a current at the terminals of the generator 130, as well as an excitation value and internal excitation setpoints of the generator 130. These states of the equipment and measurements, as well as the derived values and a condition of the controller 15 can be processed by the station controller 280. The station controller may include a status module, such as a status module 461 illustrated in the figure 4, configured to refine, filter, and correct the values as necessary. After processing, a component model module, such as the component model module 464 illustrated in Figure 4, can be applied by the station controller 280. The component model module applies a model of the automatic controller of generator voltage and determines that under the current conditions of this example the reagent requirements do not exceed those allowed by the generator excitation controller.
The information calculated by the station controller 280 can be communicated from the station controller 280 to the regional controller 290. According to some embodiments, the package structure illustrated in Figure 6 can be used to transmit the data. The information may include the status of the equipment, measurements (for example, voltage, excitation, current measurements), a state included in the device model (the internal state of the voltage regulator controller), and values derived from the generator frequency 130 , the real power, and the reactive power. The information communication topology of the station controller 280 to the regional controller 290 may indicate, among other things, that the generator is currently connected to the power system 200. The information regarding an evaluation may include an indication that the power supply reactive do not exceed your thresholds. The information may include information on a device model that may include the automatic voltage regulator model, sent as a set of parameterized differential equations. Control information may provide an indication that discontinuous controls are not required.
Simultaneously, distributed controller 265 receives the status measurements from load 141. Distributed controller 265 can refine, filter and correct the values as necessary, which can then be applied to the component model module 464 via distributed controller 265. The component model module can determine that the load is increasing according to a speed that is consistent with the historical assessments made by the distributed controller 265 and based on that speed predicts its power consumption. The model may include relevant information from
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the factors that influence the increase in the load, such as the effect of regulating the state of the transformer. The information relating to the load may be communicated to the regional controller 290. According to some embodiments, the information may be communicated using the package structure illustrated in Figure 6. The status information communicated to the regional controller 290 may include the equipment status, measurements (for example, voltage and current), values derived from load 141 (for example, frequency, actual power, and reactive power), and / or controller condition. The topology information may include an indication that the load 141 is currently connected to the power system 200 and the information regarding the way in which it is connected, since the load 141 may encompass a more complicated underlying section of the power system. The device model information may include a load model, sent as a function of the load voltage levels 141 and how the load is expected to increase over time.
Simultaneously, the distributed controller 263 receives the measurements of the line sensors associated with the transmission line 120. These measurements include the voltage and current of the transmission line 120. The measurements of the status of the IED module 451 will also be included. In this example, the IED is included with the distributed controller 263. In another embodiment, the IED is external to the distributed controller as shown in Figure 7, a proxy can be used, as shown in Figure 7. These measures they are processed by distributed controller 263, which may include a status module and a component model module 464. Information regarding a state can be communicated using a packet structure, such as the structure illustrated in Figure 6. The Information communicated to the station controller 280 may include status information, such as electrical measurements (e.g. voltage, current), equipment status based on the model (for example, the internal state of the IED module) and, values derived from the line (for example, frequency, real power and reactive power). The topology information may include an indication that the line is currently connected to power system 200. The control information may include an indication that discontinuous controls are not required.
Station controller 280 may receive information from distributed controller 261, distributed controller 263, and through regional controller 290, distributed controller 265. Station controller 280 may also receive information from distributed controller 260 and distributed controller 262. From the measures received 604, refined and corrected as necessary with the use of a module
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status associated with station controller 280; the topology information received can be processed with a topology module associated with a station controller 280; and the received model information can be processed by a model module associated with station controller 280. Station controller 280 can calculate a load flow calculation using a status module to determine the status values of lost equipment or measurements. The calculation of the load flow can also calculate the future states of the equipment and the measurements using a model and for a suitable period of time for the control of the voltage. According to some embodiments, the time frame may be of the order of tens of seconds to tens of minutes. The calculation can be based on the load model and status information, as received from distributed controller 265, generator models and status received from distributed controller 261, and the IED module and operating conditions of the IED received from the distributed controller 263. The model information cannot be received directly implemented in a model module associated with the station controller 280. However, such information may not include the most accurate model available, since It is not sent directly from a distributed source controller.
A control command can be sent based on an analysis of the measurements and status determinations. For example, a discontinuous control action can be implemented (for example, the elimination of transmission line 120), or the control action may comprise an adjustment of a power system operating condition (for example, it can be determined that the generator has reached its limit reactive power and, consequently, the generation can reduce its reactive power output). The control order is sent using a control field in a formatted data packet in accordance with Figure 6, or other suitable protocols, such as IEC 61850 GOOSE (Generic Object Oriented Substation Events) and / or a Mirroed Bits ® or similar. In one case, the control command is distributed to controller 265 for load elimination. In another case, the control command is a distributed controller connected to generator 131 (not shown) that instructs it to increase its reactive power production. In another case, the control command is for distributed controller 263 who instructs it to refrain from firing the timeline, if it is determined that such action is temporary enough not to compromise safety, or cause damage to the equipment.
or later instability. In another case, there is no need to issue a control command because anticipated behavior is expected. The differentiation between these responses can be based on how a given utility prefers to respond to
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specific system conditions.
In addition, according to certain embodiments, station controller 280 may communicate a simplified version of the model it contains and has received. Simplification involves collapsing sections of the load flow and other models into less complicated models. For example, it is possible to have a large collection of loads and combine them into a single load model. It is also possible to take a collection of lines and combine them in an equivalent Thevenin. According to some embodiments, the model and reduced status information associated with it can be communicated using a packet in the format illustrated in Figure 6. A status field may include the status, including the status of the equipment, the measurements, the derived values, and the condition of the controller according to the reduced model. A topology field can include information about the configuration of the power system in the reduced model. Evaluation field 608 may include evaluation information according to the model
15 reduced. The model field may include the reduced model. A control field may include control commands according to the reduced model.
The evaluation of the conditions of the continuous feeding system in a similar way, monitoring the state of the power system, communicating measurements, values
20 derivatives, controller condition, equipment status, topology, evaluation information, models and control. Monitoring and control continue while the power system is in a normal operating condition and in a condition that may require control actions.
25 Although specific embodiments and applications of the disclosure have been illustrated and described, it should be understood that the disclosure is not limited to the specific configurations and components described herein. Consequently, many changes can be made to the details of the embodiments described above without departing from the underlying principles of this disclosure. The scope of the present invention must, by
Therefore, determined only by the following claims.

权利要求:
Claims (26)
[1]
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one. A controller configured to implement coordinated control actions in an electrical power supply system, the controller comprising: a communications interface; a processor coupled in communication to the communications interface; and a non-transient computer readable storage medium comprising instructions that, when executed by the processor, allow the controller to: derive a first state of at least a portion of the power supply system based on an indication received through of the communications interface; calculate a first controller condition; determine a control action based on the first state and the first condition of the controller; and communicate the first state, the first condition of the controller, and the control action to a subscription controller through the network.
[2]
2. The controller of claim 1, wherein the instructions also allow the controller: to generate a component model based on the first state; and model a response of a component of the electric power supply system based on the component model; and on which the control action is based, at least in part, on the modeled response of the component.
[3]
3.  The controller of claim 2, wherein the component modeled by the component model comprises one of the controller, a subscription controller, an intelligent electronic device, and a load.
[4]
Four. The controller of claim 2, wherein the instructions further enable the controller to compare the first state in a condition of stability of the component model, and wherein the control action is configured to cause a transition from the first state to a second state that maintains the stability condition.
[5]
5.  The controller of claim 2, wherein the component model is configured to model a response of an instantaneous overcurrent element; an inverse time overcurrent element; a thermal element; a power control element

reactive; an element of distance; a differential current element; a load delimitation element; a characteristic impedance control element; a low voltage element; a directional element; a negative sequence current element; a loss of the excitation element; a negative sequence voltage element; a
5 overvoltage element; an earth fault element; a high impedance fault element; a low frequency element; and an overfrequency element.
[6]
6. The controller of claim 2, wherein the component model is configured to model a response from a reactive power controller, a controller
10 capacitor bank, a transformer regulation controller, an overexcitation generator limit controller, a governor controller, a power stabilizer system controller, a reactor bypass controller, a DC line controller, and a inverter controller
The controller of claim 2, wherein the instructions further allow the controller to transmit the component model to the subscription controller through the network.
[8]
8. The controller of claim 1, wherein the instructions also allow the controller to establish a time in which the control action must be taken.
[9]
9. The controller of claim 8, wherein the control action is configured to modify a topology of the at least a portion of the electrical power supply system.
25
[10]
10. The controller of claim 1, wherein the instructions further allow the controller to calculate a second state on the basis of one of: an input received through the communications interface, and a topology of the at least a portion of the power supply system.
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[11]
eleven.  The controller of claim 9, wherein the instructions further allow the controller to communicate the second state to the subscription controller.
[12]
12.  The controller of claim 1, wherein the instructions further enable the
35 controller calculate a second controller condition based on the information received from the subscription controller and determine a second control action based on the

Second condition of the controller.
[13]
13. The controller of claim 1, wherein the communications interface comprises
one of a network communications interface and a monitored equipment interface. 5
[14]
14. The controller of claim 1, wherein the controller comprises one of a distributed controller and a coordination controller.
[15]
15. The controller of claim 1, wherein the subscription controller comprises a coordination controller.
[16]
16. The controller of claim 1, wherein the control action is configured to temporarily modify an IED setpoint to accommodate a temporary increase in a current flow.
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[17]
17. A method for providing a coordinated distributed control to an electric power supply system, comprising: deriving a first state of at least a portion of the electric power supply system based on an indication received through an interface of communications;
20 calculate a first controller condition; determine a control action based on the first state and the first condition of the controller; communicate the first state, the first condition of the controller, and the control action to a subscription controller; and
25 implement the control action based on the first state and the first condition of the controller.
[18]
18. The method of claim 17, further comprising: generating a component model based on the first state; Y
30 model a response of a component of the electric power supply system based on the component model; and on which the determination of the control action is based, at least in part, on the modeled response of the component.
19. The method of claim 17, further comprising: determining a time delay associated with the control action; Y
5
10
fifteen
twenty
25
30
35

delay the implementation of the control action by time delay.
[20]
twenty.  The method of claim 17, wherein the control action is configured to modify a topology of the at least a portion of the electrical power supply system.
[21]
twenty-one.  The method of claim 17, further comprising: calculating a second state on the basis of one of: an input received through the communications interface, and a topology of the at least a portion of the electrical power supply system.
[22]
22  The method of claim 21, further comprising: communicating the second state to the subscription controller.
[23]
2. 3.  The method of claim 17, further comprising: calculating a second controller condition based on the information received from the subscription controller; and determine a second control action based on the second controller condition.
[24]
24. A controller configured to implement coordinated control actions in an electrical power supply system, comprising: a communications interface configured to allow communications with a network; a processor; a non-transient computer readable storage medium comprising: a status module configured to derive a first state of at least a portion of the electrical power supply system based on an indication received through the communications interface; a topology module configured to determine a topology of the at least a portion of the electrical power supply system based at least in part on the first state and the indication; an evaluation module configured to determine a stability assessment of the first state with respect to a stability condition; a component model module configured to generate a component model of at least one component of the electrical power supply system based, at least in part, on the first state; and a control module configured to determine a control action based on at least

partly on the basis of each of the first state, the topology of the at least a portion of the electric power supply system, the stability assessment, and a response of the at least one component based on the component model.
The controller of claim 24, wherein the control action is configured to cause a transition from the first state to a second state that maintains the stability condition.
[26]
26. The controller of claim 24, wherein the evaluation module is configured
10 to determine the stability assessment by comparing the first state in an expected range.
[27]
27. The controller of claim 24, wherein the evaluation module is
configured to determine the stability assessment by comparing the first state against a previous state.
[28]
28. The controller of claim 24, wherein the topology module is configured to determine the topology by comparing a previous state having a known topology with the first state.
twenty
[29]
29. The controller of claim 24, wherein the response of the at least one component based on the component model is determined using a possible control action, and the possible control action is selectively adopted based on the response of the less a component to the possible control action.
25

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同族专利:

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公开号 | 公开日

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WO2014055420A1|2014-04-10|

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US9383735B2|2016-07-05|

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BR112015007004A2|2017-12-12|

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AU2013327557A1|2015-03-12|

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MX2015002625A|2015-06-23|

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ES2539301R1|2016-05-13|

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US20140100702A1|2014-04-10|

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ES2539301B1|2017-02-21|

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