CN109375055B - Detection method, system and device of phasor measurement system and storage medium - Google Patents
Detection method, system and device of phasor measurement system and storage medium Download PDFInfo
- Publication number
- CN109375055B CN109375055B CN201811139270.5A CN201811139270A CN109375055B CN 109375055 B CN109375055 B CN 109375055B CN 201811139270 A CN201811139270 A CN 201811139270A CN 109375055 B CN109375055 B CN 109375055B
- Authority
- CN
- China
- Prior art keywords
- fault
- power grid
- nodes
- virtual
- scheme
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000005259 measurement Methods 0.000 title claims abstract description 95
- 238000001514 detection method Methods 0.000 title claims abstract description 92
- 238000012360 testing method Methods 0.000 claims abstract description 58
- 238000000034 method Methods 0.000 claims abstract description 33
- 238000004458 analytical method Methods 0.000 claims description 40
- 238000004590 computer program Methods 0.000 claims description 17
- 238000010586 diagram Methods 0.000 description 10
- 230000008569 process Effects 0.000 description 7
- 238000004422 calculation algorithm Methods 0.000 description 5
- 238000004891 communication Methods 0.000 description 5
- 230000006870 function Effects 0.000 description 5
- 230000009471 action Effects 0.000 description 3
- 230000008878 coupling Effects 0.000 description 3
- 238000010168 coupling process Methods 0.000 description 3
- 238000005859 coupling reaction Methods 0.000 description 3
- 238000013507 mapping Methods 0.000 description 3
- 238000012545 processing Methods 0.000 description 3
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000010998 test method Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 239000003990 capacitor Substances 0.000 description 1
- 238000000205 computational method Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000009977 dual effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000000737 periodic effect Effects 0.000 description 1
- 230000002093 peripheral effect Effects 0.000 description 1
- 230000009467 reduction Effects 0.000 description 1
- 230000035945 sensitivity Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
- G01R31/00—Arrangements for testing electric properties; Arrangements for locating electric faults; Arrangements for electrical testing characterised by what is being tested not provided for elsewhere
- G01R31/08—Locating faults in cables, transmission lines, or networks
- G01R31/081—Locating faults in cables, transmission lines, or networks according to type of conductors
- G01R31/086—Locating faults in cables, transmission lines, or networks according to type of conductors in power transmission or distribution networks, i.e. with interconnected conductors
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
- G01R31/00—Arrangements for testing electric properties; Arrangements for locating electric faults; Arrangements for electrical testing characterised by what is being tested not provided for elsewhere
- G01R31/08—Locating faults in cables, transmission lines, or networks
- G01R31/088—Aspects of digital computing
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
- Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
- Y04S10/00—Systems supporting electrical power generation, transmission or distribution
- Y04S10/50—Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications
- Y04S10/52—Outage or fault management, e.g. fault detection or location
Landscapes
- Physics & Mathematics (AREA)
- General Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Mathematical Physics (AREA)
- Theoretical Computer Science (AREA)
- Supply And Distribution Of Alternating Current (AREA)
Abstract
The invention provides a detection method, a system, a device and a storage medium of a phasor measurement system, wherein the method comprises the following steps: loading the power grid, and loading the measurement data of the typical load days in the database onto the power grid; according to the measurement data of the typical load day, setting a fault scheme for each line in the power grid; according to the power grid, the fault scheme and the virtual measurement units, testing the power grids with different numbers of virtual measurement units by using a phasor measurement system to obtain fault positions of the power grids; and comparing the fault position in the fault scheme with the output fault position to obtain a detection result. According to the invention, the detection accuracy of the phasor measurement system and the advantages and disadvantages of different phasor measurement systems are compared by comparing the fault position tested by the phasor measurement system with the fault position in the set fault scheme.
Description
Technical Field
The invention belongs to the technical field of power grid fault detection, and particularly relates to a detection method, a detection system, a detection device and a storage medium of a phasor measurement system.
Background
The large-scale interconnection of complex power networks requires that a power system has high stability, and years of operation experience of the power system shows that the rapid fault removal and the reduction of the impact of fault current on the system are always one of the most effective means for ensuring the safe and stable operation of the power system. Because the traditional backup protection has long action time and complex coordination, the safety and stability performance of a complex power system can be further improved by introducing wide-area information into a protection system (namely a wide-area protection system).
The wide area protection system not only can provide corresponding element protection, but also can ensure the safe and stable operation of the system. The basis of the precise action of Wide Area protection mainly depends on the Measurement accuracy of a Phasor Measurement Unit (PMU) and the accuracy of a Phasor Measurement System (WAMS). With the development of technology and the improvement of management level, the accuracy of PMU is greatly improved, and the PMU is not a difficulty for preventing the correct action of wide area protection. However, there are many types of phasor measurement systems, and there is no detection method or system to detect the accuracy of the phasor measurement system test.
Disclosure of Invention
In view of this, embodiments of the present invention provide a detection method, a detection system, a detection device and a storage medium for a phasor measurement system, so as to solve the problem that the prior art does not have a detection method or a detection system for detecting the accuracy of WAMS.
A first aspect of an embodiment of the present invention provides a detection method for a phasor measurement system, including:
loading a power grid and loading measurement data of typical load days in a database onto the power grid;
according to the measurement data of the typical load day, setting a fault scheme for each line in the power grid;
according to the power grid, the fault scheme and the virtual measurement units, fault positions of the power grid under different numbers of virtual measurement units are obtained through testing a phasor measurement system;
and comparing the fault position in the fault scheme with the obtained fault position to obtain the detection result of the phasor measurement system.
A second aspect of an embodiment of the present invention provides a detection system, including:
the parameter setting module is used for loading a power grid and loading measurement data of typical load days in a database onto the power grid;
the fault setting module is used for setting a fault scheme for each line in the power grid according to the measurement data of the typical load day;
the fault detection module is used for obtaining fault positions of the power grid under different numbers of virtual measurement units by testing the phasor measurement system according to the power grid, the fault scheme and the virtual measurement units;
and the fault analysis module is used for comparing the fault position in the fault scheme with the obtained fault position to obtain the detection result of the phasor measurement system.
A third aspect of the embodiments of the present invention provides a detection apparatus, including a memory, a processor, and a computer program stored in the memory and executable on the processor, where the processor implements the steps of the detection method of the phasor measurement system as described above when executing the computer program.
A fourth aspect of embodiments of the present invention provides a computer-readable storage medium storing a computer program which, when executed by a processor, implements the steps of the detection method of the phasor measurement system as described above.
Compared with the prior art, the embodiment of the invention has the following beneficial effects: the invention obtains the accuracy of WAMS detection by setting unified measurement data of a power grid and a typical load day, setting a fault scheme and comparing the fault position tested by the phasor measurement system with the fault position in the set fault scheme.
Drawings
In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the embodiments or drawings used in the prior art description, and obviously, the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a flow diagram of a detection method of a phasor measurement system provided by an embodiment of the present invention;
FIG. 2 is a flowchart illustrating an implementation of step S102 according to an embodiment of the present invention;
FIG. 3 is a schematic flow chart of the implementation of step S103 according to an embodiment of the present invention;
fig. 4 is a specific flowchart of a detection method of a phasor measurement system according to an embodiment of the present invention;
FIG. 5 is a schematic diagram of a structure of an IEEE 10 machine 39 node power grid model provided by an embodiment of the present invention;
FIG. 6 is a schematic diagram of a fault line AB dual ended configuration PMU provided by one embodiment of the present invention;
fig. 7 is a schematic diagram of a single-ended PMU configuration for fault line AB provided by an embodiment of the present invention;
fig. 8 is a schematic diagram of a fault line AB dual-end adjacent electrical node configuration PMU provided by one embodiment of the present invention;
fig. 9 is a schematic diagram of a single-ended adjacent electrical node configuration PMU for a fault line AB provided by one embodiment of the present invention;
fig. 10 is a schematic diagram of a fault line AB double end and adjacent electrical nodes provided by an embodiment of the present invention without PMUs;
FIG. 11 is a schematic structural diagram of a detection system provided in one embodiment of the present invention;
fig. 12 is a schematic diagram of a detection apparatus provided in an embodiment of the present invention.
Detailed Description
In the following description, for purposes of explanation and not limitation, specific details are set forth, such as particular system structures, techniques, etc. in order to provide a thorough understanding of the embodiments of the invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced in other embodiments that depart from these specific details. In other instances, detailed descriptions of well-known systems, devices, circuits, and methods are omitted so as not to obscure the description of the present invention with unnecessary detail.
The terms "comprises" and "comprising," as well as any other variations, in the description and claims of this invention and the drawings described above, are intended to mean "including but not limited to," and are intended to cover non-exclusive inclusions. For example, a process, method, or system, article, or apparatus that comprises a list of steps or elements is not limited to only those steps or elements listed, but may alternatively include other steps or elements not listed, or inherent to such process, method, article, or apparatus.
In order to explain the technical means of the present invention, the following description will be given by way of specific examples.
Example 1:
fig. 1 shows a flowchart of an implementation of a detection method of a phasor measurement system according to an embodiment of the present invention, and for convenience of description, only the relevant parts of the phasor measurement system according to the embodiment of the present invention are shown, which is detailed as follows:
as shown in fig. 1, a detection method of a phasor measurement system according to an embodiment of the present invention includes:
and step S101, loading the power grid, and loading the measurement data of the typical load days in the database onto the power grid.
In the present embodiment, step S101 is used for parameter setting and modification.
In this embodiment, first, a detection platform system is entered, after model parameters of an actual power grid or a virtual power grid are loaded, the system reads measurement data of a typical load day or virtual typical load data in a real-time database, periodically performs state estimation, loads the measurement data of the typical load day into the actual power grid, and loads the virtual typical load data into the virtual power grid.
In practical use:
actual grid: reading in the whole network measurement data of typical load days in an EMS (energy management system) real-time database of the periodic mapping of the actual power grid, and periodically carrying out state estimation.
Virtual power grid: reading in model parameters of the virtual power grid, periodically mapping virtual typical load data in an EMS real-time database, and periodically estimating the state of the virtual power grid.
The virtual power grid model refers to a classic power grid model which is built for testing, such as an IEEE 7 machine 26 node, an IEEE 10 machine 39 node and other power grid models. The measurement data of the typical load day can be the real daily load data of a certain year, and can also be the comprehensive average value of the load data of a plurality of years. The measurement data of the typical load day comprise target bus voltage measurement data, tidal current measurement data of peripheral power grid connecting lines, unit active output measurement data, unit reactive output measurement data and transformer substation capacitor switching condition measurement data; the virtual typical load data refers to load data of each node in a virtual power grid model and is set by detection personnel. The state estimation refers to identifying and eliminating bad data in the measurement number. Bad data is data that does not conform to reality, etc., for example: in summer, the outdoor temperature is continuously measured, the reading at a certain time point is minus 5 ℃, and the situation is practically impossible, so that the data is bad.
And S102, setting a fault scheme for each line in the power grid according to the measurement data of the typical load day.
In one embodiment of the invention, the type, time and position of the fault of each line in the power grid are set according to requirements.
In a specific application, the failure scheme is set up to be compared with the failure positions tested by the phasor test, the west-joker test.
Step S103, obtaining fault positions of the power grid under different numbers of virtual measurement units by testing the phasor measurement system according to the power grid, the fault scheme and the virtual measurement units; .
In this embodiment, the phasor measurement system is a multi-test code, a software system or a test device, and if the code is not externally connected to the detection system of the present invention, the code is externally connected to the test system of the present invention.
In this embodiment, the WAMS is tested by analyzing the power grid with different numbers of virtual measurement units set therein by using the WAMS to obtain the fault location of the power grid; the test for WAMS is actually a test for the computational method in WAMS.
And step S104, comparing the fault position in the fault scheme with the obtained fault position to obtain the detection result of the phasor measurement system.
In this embodiment, the main function is to output results and compare the quality of different phase measurement system WAMS systems or devices.
In specific application, if a single WAMS system or equipment is tested, a test system, a fault scheme, test fault types under different virtual PMU numbers, test numbers and successful fault positioning numbers are output firstly. If different WAMS systems or devices are compared, the test system and the fault scheme are output, and then the test fault types, the test number and the successful fault positioning number under different virtual PMU numbers are output in sequence.
When the total successful positioning number is consistent and the total number of the virtual PMUs in each successful positioning is less, the algorithm is better.
The relationship between the fault of positioning failure and the fault line type of the PMU can be analyzed: the detection weights of type 1 to type 5 are sequentially decreased. When PMU is configured at both ends of a fault line and fault positioning fails, the WAMS system is unqualified in detection; if the number of the output results of the WAMS in the independent fault test in the step S103 is zero, the detection of the WAMS system is unqualified; when the total successful positioning number is consistent, the more the number of the fault line types successfully positioned with high detection weight is, the better the calculation method is.
If the number of the output results of the WAMS in the independent fault test is zero and the number of the output results of the WAMS is consistent with the set fault positions, the WAMS algorithm is reported to be incorrect, and comparison information of the actual fault positions and the WAMS judgment positions is listed.
The above information can be output in the form of report or words.
As illustrated in fig. 2, in one embodiment of the invention: in step S102, setting a fault scheme for each line in the power grid, including:
step S201, setting the fault type, fault position and fault time of each line according to the measurement data of the typical load day;
and step S202, storing the fault type, the fault position and the fault time into a fault database.
In this embodiment, the failure types include: such as single-phase grounding short circuit, two-phase short circuit ungrounded, two-phase short circuit grounding, three-phase short circuit ungrounded, double-circuit parallel wiring overline short circuit grounding. Whether the double-circuit line overline short circuit is not grounded and whether the double-circuit line overline short circuit is grounded is determined by a power grid topological structure.
Failure time: the time when a certain fault occurs on a typical load day is set, and the fault duration is set.
Different fault forms are formed after the fault types and the fault time are set: such as: independent faults, namely the fault is far in electrical distance and does not belong to the same power flow section or the time interval is long; multiple faults: the combination of short electrical distance or different line faults of the same power flow section which occur at the same time; continuous failure: the combination of short electric distance or different line faults of the same power flow section which occur in sequence (the time interval is not more than 5 minutes).
All fault types, fault time, fault positions and fault forms are stored in a fault database.
Each line may have multiple failure scenarios, but before each test a certain set of failure scenarios must be selected for use.
As shown in fig. 3, in an embodiment of the present invention, the step S103 of obtaining the lower fault positions of the power grid at different numbers of virtual measurement units by testing the phasor measurement system according to the power grid, the fault scheme and the virtual measurement units includes:
step S301, calculating to obtain a number set of virtual measurement units to be set according to the number of nodes of the power grid, and setting the position of the virtual measurement unit corresponding to each number for each number in the number set in the power grid;
step S302, a set of fault schemes is selected from the fault database and stored in a detection analysis database;
step S303, according to the power grid, the selected fault scheme and the virtual measurement units, obtaining fault information of the power grid under the virtual measurement units corresponding to each quantity in the quantity set through a phasor measurement system, outputting fault positions, and storing the fault positions in a detection analysis database.
In an embodiment of the present invention, the step S301 of calculating a set of numbers of virtual measurement units to be set includes:
1) calculating the minimum value of the virtual measurement unit by using an enumeration method according to the number of the nodes of the power grid;
2) and obtaining a number set of virtual measurement units to be set according to the number of the nodes of the power grid and the minimum value of the virtual measurement units, wherein the maximum value in the number set of the virtual measurement units is the number of the nodes of the power grid minus 1.
In this embodiment, when an electrical node of a power grid of a known topology is n, m is necessarily less than n, when voltages, currents, frequencies, and power angles of m nodes are known, voltages, currents, frequencies, and power angles of the remaining n-m nodes can be solved, and when voltages, currents, frequencies, and power angles of only m-1 nodes are known, voltages, currents, frequencies, and power angles of n-m nodes cannot be solved, so that m is referred to as a minimum virtual Measurement unit pmu (phase Measurement unit) arrangement number. Each grid of known topology can compute the minimum virtual measurement unit PMU placement by enumeration or other methods.
In an embodiment of the present invention, step 1) in step S301 calculates a minimum value of a virtual measurement unit by using an enumeration method according to the number of nodes of the power grid, including:
(1) setting the number of nodes with known parameters in the power grid to be a preset value, and determining whether the number of nodes with known parameters is the current preset value, wherein the preset value is the number of nodes of the power grid minus 1, and the other nodes are nodes except the nodes with known parameters in the power grid.
(2) If the parameters of other nodes in the power grid can be obtained, subtracting 1 from the preset value, and determining whether the parameters of other nodes in the power grid can be obtained or not when the number of the nodes with known parameters is the current preset value until the parameters of other nodes in the power grid cannot be obtained.
(3) And when the parameters of other nodes in the power grid can be obtained, the corresponding minimum preset value is used as the minimum numerical value of the virtual measurement unit.
In this embodiment, calculating the minimum value of the virtual measurement unit is a process of one cycle trial.
The method mainly comprises the step that when an n-node network system of a testing phasor measurement system WAMS is provided with x virtual PMUs, and x is more than or equal to m and is less than n, the position of a fault can be accurately judged according to information provided by the virtual PMUs.
In an embodiment of the present invention, step S303 includes:
1) when the number of the virtual measuring units is the maximum value in the number set, obtaining the fault position of the power grid when the number of the set virtual measuring units is the maximum value, and storing the fault position in a detection analysis database;
2) the detection analysis database compares the output fault location with the fault location in the selected fault scheme to obtain the number of matched fault locations;
3) and if at least one of the fault location in the fault test and the fault position in the selected fault scheme is matched, removing the detected numerical value from the quantity set, and selecting the maximum numerical value from the quantity set from which the detected numerical value is removed until the matching quantity of the fault location in the fault test and the fault position in the selected fault scheme is 0, or until all the numerical values in the quantity set are completely detected.
In an embodiment of the present invention, the step S303 of 1) obtaining a fault location of the power grid when the number of the virtual measurement units is the maximum value in the number set, and storing the fault location in the detection and analysis database, includes:
if the set fault scheme is an independent fault, sequentially operating according to the set fault time, reading the information of the virtual measurement unit by the phasor measurement system in real time, and sequentially outputting fault location to a detection analysis database;
if the set fault scheme is multiple faults, sequentially operating according to the set fault time, reading the information of the virtual measurement units by the phasor measurement system in real time, and sequentially outputting fault location to a detection analysis database;
and if the set fault scheme is a continuous fault, sequentially operating according to the set fault time, reading the information of the virtual measurement units by the phasor measurement system in real time, and sequentially outputting fault location to a detection analysis database.
The specific test method is as follows:
and A, enabling x to be n, selecting a fault scheme by a tester, and storing the fault scheme in a detection analysis database.
B, enabling x to be x-1, judging whether x is not less than m, if x is less than m, interrupting the cycle, and entering the step (5); if not, entering the next link;
c, the set independent faults occur in sequence according to the set fault time, the WAMS reads x pieces of PMU information at any time and outputs fault positions to a detection analysis database in sequence;
d, multiple faults occur in sequence according to the set fault time, the WAMS reads x pieces of PMU information constantly and outputs fault positions to a detection analysis database in sequence,
e, the set continuous faults occur in sequence according to the set fault time, the WAMS reads x PMU information constantly and outputs fault positions to a detection analysis database in sequence,
f, detecting whether the WAMS output result is matched with the set fault position or not by the aid of the analysis database, and counting the matched number.
G, if at least one of the WAMS output results in the fault test is matched with the set fault position, returning to B to continue testing until x is less than m; if the number of the WAMS output results in the fault test is zero and the number of the WAMS output results in the set fault positions is zero, the circulation is interrupted, and the next step is carried out;
if different WAMS systems or devices are compared, the A-G tests are required to be respectively carried out on the premise of the same fault scheme.
As shown in the flowchart of fig. 4, after step S101, the method further includes:
and step S105, judging whether the external test system is accessed, and if so, detecting whether the external test system is correctly accessed.
In this embodiment, the phasor measurement system WAMS is a software system or a test equipment. If an external test system is connected, if WAMS software is input by a user for testing, testing whether voltage, current and active data of each virtual PMU access point can be accurately accessed after a configuration file provided by the user is read (the configuration file is the meaning represented by different variables in the software);
if the user inputs the WAMS equipment for testing, after a configuration file provided by the user is read in (the configuration file is a data information configuration method of the equipment), whether the communication protocols are matched is tested, and then whether the voltage, the current and the active data of each virtual PMU access point can be accurately accessed is tested.
And after the access test, if certain data of the virtual PMU access point has no signal or the communication protocols are not matched, stopping the test, rechecking the connection and configuration files and outputting error information. Whether the WAMS system or the WAMS equipment is detected, the detection of the WAMS core algorithm is finally carried out.
The virtual PMU is a PMU that simulates a load at an electrical node, and numerical fluctuation curves of voltage, current, and power of the load are known. For an actual power grid model, the virtual PMU simulates a PMU by using a load at a non-fault moment under a specified electrical node, a voltage and current numerical value fluctuation curve of the load is preset typical load daily measurement data of the node, and voltage, current, power angle and frequency fluctuation provided by the PMU at the fault moment are calculated by analysis before testing. For the virtual power grid model, the virtual PMU is the virtual load data of the node, and the numerical fluctuation curves of the voltage, the current, the power angle and the frequency of the load are all set in advance and stored in an EMS real-time database.
Taking a specific application scenario as an example, the embodiment adopts an IEEE 10 machine 39 node power grid model as shown in fig. 5, and explains for an example a virtual power grid:
the virtual typical load data refers to the load data of each node in the virtual power grid model and is set by detection personnel.
In this embodiment, it is detected that the WAMS server based on the integral mapping sensitivity algorithm needs to test whether the communication protocols are matched after reading the configuration file provided by the user, and then test the voltage, current, and active data of each virtual PMU access point, and then proceeds to the next step because the virtual PMU access points can be accurately accessed.
As shown in fig. 6-10, configuring the faulty line type classification of the PMU, wherein: ● denotes the electrical node configuring the PMU.
The partial fault settings of the present embodiment are as follows:
the fault line in the table is named as the A bus name-B bus name, the bus at the A end is the bus closer to the fault point, the starting time of faults 1 and 2 in the table is the same, multiple faults are formed, and the starting time of faults 18 and 19 forms continuous faults in 5 minutes.
As is known, the minimum PMU placement number of the IEEE 39 node system is 9, and as shown in fig. 5, ● is a bus of the minimum PMU placement.
The method mainly comprises the step of testing the WAMS system, when the 39 network system is provided with x virtual PMUs, and x is more than or equal to 9 and less than 39, the position of the fault can be accurately judged according to the information provided by the virtual PMUs.
The specific test method is as follows:
and A, initializing, and making x equal to 39, selecting a fault scheme by a tester, and storing the fault scheme in a detection analysis database.
B, enabling x to be 39-1, judging whether x is not less than 9, and if x is not less than 9, entering the step (5); if not, entering C;
c, the set independent faults occur in sequence according to the time set in the step (3), the WAMS reads x pieces of PMU information at any time and outputs fault positions to a detection analysis database in sequence;
d, multiple faults occur in sequence according to the time set in the step (3), the WAMS reads x pieces of PMU information constantly and outputs fault positions to a detection analysis database in sequence,
e, the continuous faults set by the step (3) occur in sequence, the WAMS reads x pieces of PMU information from time to time and outputs fault positions to a detection analysis database in sequence,
f, detecting whether the WAMS output result is matched with the set fault position or not by the aid of the analysis database, and counting the matched number.
G, if at least one of the WAMS output results in the fault test is matched with the set fault position, returning to the step B for continuous test, and if the number of the WAMS output results in the fault test matched with the set fault position is zero, interrupting circulation and entering the next step;
in this embodiment, when x is less than 9 which is the minimum PMU placement number, that is, x is equal to 8, the loop is interrupted to step (5);
if different WAMS systems or devices are compared, the A-G tests are required to be respectively carried out on the premise of the same fault scheme.
And comparing the phasor measurement system according to the output fault position and the set fault position.
It should be understood that the execution order of each process should be determined by its function and its inherent logic, and should not constitute any limitation on the implementation process of the embodiments of the present invention.
Example 2:
as shown in fig. 11, an embodiment of the present invention provides a detection system 100 for performing the method steps in the embodiment corresponding to fig. 1, which includes:
a parameter setting module 110, configured to load a power grid, and load measurement data of typical load days in a database onto the power grid;
a fault setting module 120, configured to set a fault scheme for each line in the power grid according to the measurement data of the typical load day;
a fault detection module 130, configured to obtain fault positions of the power grid under different numbers of virtual measurement units by testing the phasor measurement system according to the power grid, the fault scenario, and the virtual measurement units;
and the fault analysis module 140 is configured to compare the fault location in the fault scenario with the obtained fault location, and obtain a detection result of the phasor measurement system.
In one embodiment of the present invention, the fault setting module 120 includes:
the fault setting unit is used for setting the fault type, the fault position and the fault time of each line according to the measurement data of the typical load day;
and the fault storage unit is used for storing the fault type, the fault position and the fault time into a fault database.
In one embodiment of the present invention, the fault detection module 130 includes:
the virtual measurement unit setting unit is used for calculating to obtain a quantity set of virtual measurement units to be set according to the quantity of the nodes of the power grid, and setting the position of the virtual measurement unit corresponding to each quantity for each quantity in the quantity set in the power grid;
the fault selection unit is used for selecting a set of fault schemes from the fault database and storing the fault schemes in the detection analysis database;
and the fault detection unit is used for obtaining fault information of the power grid under the virtual measurement unit corresponding to each quantity in the quantity set by testing the phasor measurement system according to the power grid, the selected fault scheme and the virtual measurement unit, outputting a fault position and storing the fault position in a detection analysis database.
In one embodiment of the present invention, the virtual measurement unit setting unit includes:
the minimum value subunit for acquiring the number of the virtual measurement units is used for calculating the minimum value of the number of the virtual measurement units by using an enumeration method according to the number of the nodes of the power grid;
and acquiring a quantity set subunit of the virtual measurement units, which is used for obtaining a quantity set of the virtual measurement units to be set according to the quantity of the nodes of the power grid and the minimum value of the quantity of the virtual measurement units, wherein the maximum value in the quantity set of the virtual measurement units is the quantity of the nodes of the power grid minus 1.
In an embodiment of the present invention, the sub-unit for obtaining the minimum value of the number of the virtual measurement units is further configured to:
setting the number of nodes with known parameters in the power grid to be a preset value, and determining whether parameters of other nodes in the power grid can be obtained or not when the number of nodes with known parameters is the current preset value, wherein the preset value is obtained by subtracting 1 from the number of nodes in the power grid, and the other nodes are nodes except the nodes with known parameters in the power grid;
if the parameters of other nodes in the power grid can be obtained, subtracting 1 from a preset value, and determining whether the parameters of other nodes in the power grid can be obtained or not when the number of the nodes with known parameters is the current preset value until the parameters of other nodes in the power grid cannot be obtained;
and when the parameters of other nodes in the power grid can be obtained, the corresponding minimum preset value is used as the minimum numerical value of the virtual measurement unit.
In one embodiment of the present invention, a fault detection unit includes:
the fault position acquisition subunit is used for acquiring the fault position of the power grid when the number of the virtual measurement units is the maximum value in the number set, and storing the fault position in the detection analysis database;
the fault position comparison subunit is used for comparing the fault positioning output by the detection and analysis database with the fault positions in the selected fault scheme to obtain the number of matched fault positions;
and the result output subunit is used for removing the detected numerical value from the quantity set and selecting the maximum numerical value from the quantity set in which the detected numerical value is removed if at least one of the fault location in the fault test and the fault position in the selected fault scheme is matched, until the matching quantity of the fault location in the fault test and the fault position in the selected fault scheme is 0, or until all the numerical values in the quantity set are detected completely.
In one embodiment of the present invention, the acquiring a fault location subunit of a power grid includes:
the independent fault detection subsystem is used for sequentially operating the independent faults according to the set fault time if the set fault scheme is the independent fault, and the phasor measurement system reads the information of the virtual measurement unit in real time and sequentially outputs fault positioning to the detection analysis database;
the multiple fault detection subsystem is used for sequentially operating according to the set fault time if the set fault scheme is multiple faults, and the phasor measurement system reads the information of the virtual measurement unit in real time and sequentially outputs fault positioning to the detection analysis database;
and the continuous fault detection subsystem is used for sequentially operating according to the set fault time if the set fault scheme is a continuous fault, reading the information of the virtual measurement unit by the phasor measurement system in real time, and sequentially outputting fault location to the detection analysis database.
It is obvious to those skilled in the art that, for convenience and simplicity of description, the foregoing division of the functional modules is merely used as an example, and in practical applications, the foregoing functional allocation may be performed by different functional modules according to needs, that is, the internal structure of the detection system is divided into different functional modules to perform all or part of the above-described functions. Each functional module in the embodiments may be integrated in one processing unit, or each unit may exist alone physically, or two or more units are integrated in one unit, and the integrated module may be implemented in a form of hardware, or in a form of software functional unit. In addition, the specific names of the functional modules are only for the convenience of distinguishing from each other, and are not used to limit the protection scope of the present application. For the specific working process of the module in the detection system, reference may be made to the corresponding process in the foregoing method embodiment 1, which is not described herein again.
Example 3:
fig. 12 is a schematic diagram of a terminal device according to an embodiment of the present invention. The terminal device 61 of this embodiment includes: a processor 610, a memory 611, and a computer program 612 stored in said memory 611 and executable on said processor 610. The processor 610, when executing the computer program 612, implements the steps in the embodiments as described in embodiment 1, such as steps S101 to S104 shown in fig. 1. Alternatively, the processor 610, when executing the computer program 612, implements the functions of the modules/units in the system embodiments as described in embodiment 2, for example, the functions of the modules 110 to 140 shown in fig. 11.
The terminal device 61 refers to a terminal with data processing capability, and includes but is not limited to a computer, a workstation, a server, and even some Smart phones, palmtop computers, tablet computers, Personal Digital Assistants (PDAs), Smart televisions (Smart TVs), and the like with excellent performance. The terminal device is generally installed with an operating system, including but not limited to: windows operating system, LINUX operating system, Android (Android) operating system, Symbian operating system, Windows mobile operating system, and iOS operating system, among others. Specific examples of the terminal device 61 are listed in detail above, and those skilled in the art will appreciate that the terminal device is not limited to the listed examples.
The terminal device may include, but is not limited to, a processor 610, a memory 611. Those skilled in the art will appreciate that fig. 12 is only an example of the terminal device 61, and does not constitute a limitation to the terminal device 61, and may include more or less components than those shown, or combine some components, or different components, for example, the terminal device 61 may further include an input-output device, a network access device, a bus, etc.
The Processor 610 may be a Central Processing Unit (CPU), other general purpose Processor, a Digital Signal Processor (DSP), an Application Specific Integrated Circuit (ASIC), an off-the-shelf Programmable Gate Array (FPGA) or other Programmable logic device, discrete Gate or transistor logic, discrete hardware components, etc. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like.
The storage 611 may be an internal storage unit of the terminal device 61, such as a hard disk or a memory of the terminal device 61. The memory 611 may also be an external storage device of the terminal device 61, such as a plug-in hard disk, a Smart Media Card (SMC), a Secure Digital (SD) Card, a Flash memory Card (Flash Card), and the like, which are provided on the terminal device 61. Further, the memory 611 may also include both an internal storage unit and an external storage device of the terminal device 61. The memory 611 is used to store the computer programs and other programs and data required by the terminal device 61. The memory 611 may also be used to temporarily store data that has been output or is to be output.
Example 4:
an embodiment of the present invention further provides a computer-readable storage medium, where a computer program is stored, and when being executed by a processor, the computer program implements steps in each embodiment described in embodiment 1, for example, steps S101 to S104 shown in fig. 1. Alternatively, the computer program, when executed by a processor, implements the functionality of the various modules/units in the various system embodiments as described in embodiment 2, such as the functionality of modules 110 to 140 shown in fig. 11.
The computer program may be stored in a computer readable storage medium, which when executed by a processor, may implement the steps of the various method embodiments described above. Wherein the computer program comprises computer program code, which may be in source code form, object code form, an executable file or some intermediate form, etc. The computer-readable medium may include: any entity or device capable of carrying the computer program code, recording medium, usb disk, removable hard disk, magnetic disk, optical disk, computer Memory, Read-Only Memory (ROM), Random Access Memory (RAM), electrical carrier wave signals, telecommunications signals, software distribution medium, and the like.
In the above embodiments, the description of each embodiment has a respective emphasis, embodiments 1 to 4 may be arbitrarily combined, and new embodiments formed by the combination are also within the scope of the present application. For parts which are not described or illustrated in a certain embodiment, reference may be made to the description of other embodiments.
Those of ordinary skill in the art would appreciate that the elements and algorithm steps of the various embodiments described in connection with the embodiments disclosed herein may be implemented as electronic hardware, or combinations of computer software and electronic hardware. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the implementation. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present invention.
In the embodiments provided in the present invention, it should be understood that the disclosed terminal device and method can be implemented in other ways. For example, the above-described system/terminal device embodiments are merely illustrative, and for example, the division of the modules or units is only one logical division, and there may be other divisions in actual implementation, for example, multiple units or components may be combined or integrated into another system, or some features may be omitted, or not executed. In addition, the shown or discussed mutual coupling or direct coupling or communication connection may be an indirect coupling or communication connection through some interfaces, devices or units, and may be in an electrical, mechanical or other form.
The above-mentioned embodiments are only used for illustrating the technical solutions of the present invention, and not for limiting the same; although the present invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some technical features may be equivalently replaced; such modifications and substitutions do not substantially depart from the spirit and scope of the present invention, and are intended to be included within the scope thereof.
Claims (9)
1. A method for detecting a phasor measurement system, comprising: loading a power grid and loading measurement data of typical load days in a database onto the power grid; according to the measurement data of the typical load day, setting a fault scheme for each line in the power grid; according to the power grid, the fault scheme and the virtual measurement units, the fault positions of the power grid under different numbers of virtual measurement units are obtained by testing the phasor measurement system, and the method comprises the following steps: calculating to obtain a quantity set of virtual measurement units to be set according to the quantity of the nodes of the power grid, and setting the position of the virtual measurement unit corresponding to each quantity for each quantity in the quantity set in the power grid; selecting a set of fault schemes from the fault database and storing the fault schemes in a detection analysis database; according to the power grid, the selected fault scheme and the virtual measurement units, fault information of the power grid under the virtual measurement units corresponding to each quantity in the quantity set is obtained through testing a phasor measurement system, fault positions are output, and the fault positions are stored in a detection analysis database; and comparing the fault position in the fault scheme with the obtained fault position to obtain the detection result of the phasor measurement system.
2. The method for detecting a phasor measurement system according to claim 1, wherein said setting a fault scenario for each line in said power grid based on said measurement data of said typical load day comprises:
setting the fault type, the fault position and the fault time of each line according to the measurement data of the typical load day;
and storing the fault type, the fault position and the fault time into a fault database.
3. The method for detecting the phasor measurement system according to claim 1, wherein the step of calculating the number set of the virtual measurement units to be set according to the number of the nodes of the power grid comprises:
calculating the minimum value of the number of the virtual measurement units by using an enumeration method according to the number of the nodes of the power grid;
and obtaining a number set of virtual measurement units to be set according to the number of the nodes of the power grid and the minimum value of the number of the virtual measurement units, wherein the maximum value in the number set of the virtual measurement units is the number of the nodes of the power grid minus 1.
4. The method for detecting the phasor measurement system according to claim 3, wherein the calculating the minimum value of the number of virtual measurement units by using an enumeration method according to the number of nodes of the power grid comprises:
setting the number of nodes with known parameters in the power grid to be a preset value, and determining whether parameters of other nodes in the power grid can be obtained or not when the number of nodes with known parameters is the current preset value, wherein the preset value is obtained by subtracting 1 from the number of nodes in the power grid, and the other nodes are nodes except the nodes with known parameters in the power grid;
if the parameters of other nodes in the power grid can be obtained, subtracting 1 from a preset value, and determining whether the parameters of other nodes in the power grid can be obtained or not when the number of the nodes with known parameters is the current preset value until the parameters of other nodes in the power grid cannot be obtained;
and when the parameters of other nodes in the power grid can be obtained, the corresponding minimum preset value is used as the minimum numerical value of the virtual measurement unit.
5. The method for detecting the phasor measurement system according to claim 1, wherein the step of testing the fault information of the power grid under the virtual test unit corresponding to each quantity in the quantity set by using the phasor measurement system according to the power grid, the selected fault scheme and the virtual measurement unit, outputting a fault position, and storing the fault position in a detection analysis database comprises the steps of:
when the number of the virtual measurement units is the maximum value in the number set, acquiring the fault position of the power grid when the number of the set virtual measurement units is the maximum value, and storing the fault position in a detection analysis database;
the detection analysis database compares the output fault location with the selected fault location in the fault scheme to obtain the number of matched fault locations;
and if at least one of the fault location in the fault test and the fault position in the selected fault scheme is matched, removing the detected numerical value from the number set, and selecting the maximum numerical value from the number set from which the detected numerical value is removed until the matching number of the fault location in the fault test and the fault position in the selected fault scheme is 0 or all the numerical values in the number set are detected completely.
6. The method for detecting the phasor measurement system according to claim 5, wherein the step of obtaining the fault location of the power grid when the number of the virtual measurement units is the maximum value in the set of numbers and storing the fault location in the detection analysis database comprises:
if the set fault scheme is an independent fault, sequentially operating according to the set fault time, and reading the information of the virtual measurement unit by the phasor measurement system in real time and sequentially outputting fault location to a detection analysis database;
if the set fault scheme is multiple faults, sequentially operating according to the set fault time, reading the information of the virtual measurement units by the phasor measurement system in real time, and sequentially outputting fault location to a detection analysis database;
and if the set fault scheme is a continuous fault, sequentially operating according to the set fault time, reading the information of the virtual measurement units by the phasor measurement system in real time, and sequentially outputting fault location to a detection analysis database.
7. A detection system, comprising:
the parameter setting module is used for loading a power grid and loading measurement data of typical load days in the database onto the power grid;
the fault setting module is used for setting a fault scheme for each line in the power grid according to the measurement data of the typical load day;
the fault detection module is used for obtaining fault positions of the power grid under different numbers of virtual measurement units by testing the phasor measurement system according to the power grid, the fault scheme and the virtual measurement units, and comprises: calculating to obtain a quantity set of virtual measurement units to be set according to the quantity of the nodes of the power grid, and setting the position of the virtual measurement unit corresponding to each quantity for each quantity in the quantity set in the power grid; selecting a set of fault schemes from the fault database and storing the fault schemes in a detection analysis database; according to the power grid, the selected fault scheme and the virtual measurement units, fault information of the power grid under the virtual measurement units corresponding to each quantity in the quantity set is obtained through testing a phasor measurement system, fault positions are output, and the fault positions are stored in a detection analysis database;
and the fault analysis module is used for comparing the fault position in the fault scheme with the obtained fault position to obtain the detection result of the phasor measurement system.
8. A detection apparatus comprising a memory, a processor and a computer program stored in the memory and executable on the processor, the processor implementing the steps of the detection method of the phasor measurement system according to any one of claims 1 to 6 when executing the computer program.
9. A computer-readable storage medium, characterized in that the computer-readable storage medium stores a computer program which, when being executed by a processor, carries out the steps of the detection method of the phasor measurement system according to any one of claims 1 to 6.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201811139270.5A CN109375055B (en) | 2018-09-28 | 2018-09-28 | Detection method, system and device of phasor measurement system and storage medium |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201811139270.5A CN109375055B (en) | 2018-09-28 | 2018-09-28 | Detection method, system and device of phasor measurement system and storage medium |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN109375055A CN109375055A (en) | 2019-02-22 |
| CN109375055B true CN109375055B (en) | 2020-10-09 |
Family
ID=65402962
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201811139270.5A Active CN109375055B (en) | 2018-09-28 | 2018-09-28 | Detection method, system and device of phasor measurement system and storage medium |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN109375055B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110083542B (en) * | 2019-05-06 | 2023-11-07 | 百度在线网络技术（北京）有限公司 | Model testing method and device in recommendation system and electronic equipment |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101533061A (en) * | 2009-04-09 | 2009-09-16 | 浙江大学 | Large power transmission network fault locating method based on sparse PMU configuration |
| CN102540017A (en) * | 2012-02-08 | 2012-07-04 | 华北电力大学（保定） | Partition and segmentation on-line positioning method for small-current grounding faults |
| CN103150687A (en) * | 2013-03-22 | 2013-06-12 | 电子科技大学 | Electric network structure vulnerability real-time evaluation system |
| CN103323742A (en) * | 2013-05-31 | 2013-09-25 | 华北电力大学 | System and method for grid fault identification based on random point distribution PMU |
| CN104407275A (en) * | 2014-12-08 | 2015-03-11 | 华北电力大学 | Wide-area measurement system-based failure positioning system and method for power transmission lines of transformer substation |
| CN107238779A (en) * | 2017-05-18 | 2017-10-10 | 国网山东省电力公司电力科学研究院 | A kind of fault distance-finding method of active power distribution network |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20150073735A1 (en) * | 2013-09-11 | 2015-03-12 | King Fahd University Of Petroleum And Minerals | Method for adaptive fault location in power system networks |
-
2018
- 2018-09-28 CN CN201811139270.5A patent/CN109375055B/en active Active
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101533061A (en) * | 2009-04-09 | 2009-09-16 | 浙江大学 | Large power transmission network fault locating method based on sparse PMU configuration |
| CN102540017A (en) * | 2012-02-08 | 2012-07-04 | 华北电力大学（保定） | Partition and segmentation on-line positioning method for small-current grounding faults |
| CN103150687A (en) * | 2013-03-22 | 2013-06-12 | 电子科技大学 | Electric network structure vulnerability real-time evaluation system |
| CN103323742A (en) * | 2013-05-31 | 2013-09-25 | 华北电力大学 | System and method for grid fault identification based on random point distribution PMU |
| CN104407275A (en) * | 2014-12-08 | 2015-03-11 | 华北电力大学 | Wide-area measurement system-based failure positioning system and method for power transmission lines of transformer substation |
| CN107238779A (en) * | 2017-05-18 | 2017-10-10 | 国网山东省电力公司电力科学研究院 | A kind of fault distance-finding method of active power distribution network |
Non-Patent Citations (1)
| Title |
|---|
| 基于有限同步量测数据的电力系统故障检测、辨识与定位;施微 等;《电网技术》;20150430;第39卷(第4期);第1067-1074页 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN109375055A (en) | 2019-02-22 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Jamali et al. | A new fault location method for distribution networks using sparse measurements | |
| Farajollahi et al. | Location identification of distribution network events using synchrophasor data | |
| CN109270482B (en) | Online evaluation method for metering accuracy of voltage transformer and terminal equipment | |
| Ghaedi et al. | Transmission line fault location based on three-phase state estimation framework considering measurement chain error model | |
| Song et al. | Detection method for single-pole-grounded faulty feeder based on parameter identification in MVDC distribution grids | |
| CN109066650B (en) | Power system vulnerability assessment method and terminal equipment | |
| CN115935825A (en) | Power distribution network fault processing method and device based on digital twin model | |
| Dua et al. | A novel approach for configuration identification of distribution network utilizing μPMU data | |
| CN114512982A (en) | Power distribution network topology identification method and device and terminal equipment | |
| CN115912615A (en) | Power distribution network state evaluation method and system | |
| CN113590471B (en) | Communication terminal equipment simulation system and application method thereof | |
| CN109375055B (en) | Detection method, system and device of phasor measurement system and storage medium | |
| Lin et al. | A new fault location technique for three-terminal transmission grids using unsynchronized sampling | |
| CN114167132A (en) | Power consumption detection method and device of wireless terminal, electronic equipment and storage medium | |
| Ghaedi et al. | Modified WLS three-phase state estimation formulation for fault analysis considering measurement and parameter errors | |
| CN117074864A (en) | Method, system, equipment and medium for testing power consumption of transformer area side and detecting line loss | |
| CN112240992B (en) | Protection polarity verification method, device and equipment based on line empty charge transient current | |
| de Ávila Dilli et al. | Conductor break detection in distribution system through negative sequence voltage | |
| KR101243216B1 (en) | Control system for detecting a electric power chain in wide area | |
| CN113376564B (en) | Smart electric meter metering correction method and device based on data analysis and terminal | |
| CN115616412A (en) | Energy storage battery pack modeling method, device, equipment and readable storage medium | |
| CN114757496A (en) | Method and device for evaluating power supply reliability of power distribution network | |
| CN114139744A (en) | Abnormal photovoltaic group string branch identification method and device, electronic equipment and storage medium | |
| CN112698260A (en) | CVT voltage sag measurement error correction method and system | |
| CN111737875A (en) | Active power imbalance rate analysis and diagnosis method and system and computer equipment |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| EE01 | Entry into force of recordation of patent licensing contract |
Application publication date: 20190222 Assignee: Hebei Zhongxing Jineng Power Development Co.,Ltd. Technology Branch Assignor: STATE GRID HEBEI ENERGY TECHNOLOGY SERVICE Co.,Ltd. Contract record no.: X2022130000001 Denomination of invention: A detection method, system, device and storage medium of phasor measurement system Granted publication date: 20201009 License type: Common License Record date: 20220318 |
|
| EE01 | Entry into force of recordation of patent licensing contract |