CN114372232B - Transformer area phase sequence topology identification method and system based on voltage sequence similarity transmission - Google Patents

Transformer area phase sequence topology identification method and system based on voltage sequence similarity transmission Download PDF

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CN114372232B
CN114372232B CN202210285241.XA CN202210285241A CN114372232B CN 114372232 B CN114372232 B CN 114372232B CN 202210285241 A CN202210285241 A CN 202210285241A CN 114372232 B CN114372232 B CN 114372232B
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CN114372232A (en
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谭金兴
陈曦
吴秋明
朱永江
利万庆
蔡惠敏
吴晓婷
罗筱筠
李键欣
黄桂荣
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Zhaoqing Power Supply Bureau of Guangdong Power Grid Co Ltd
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R29/00—Arrangements for measuring or indicating electric quantities not covered by groups G01R19/00 - G01R27/00
    • G01R29/18—Indicating phase sequence; Indicating synchronism
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
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Abstract

The invention relates to the technical field of distribution transformation phase sequence identification, and discloses a station area phase sequence topology identification method and a system based on voltage sequence similarity transmission, wherein the method comprises the steps of calculating fluctuation standard deviations of voltage sequence data of all user electric meters, arranging the user electric meters according to the size relationship of the fluctuation standard deviations, determining a phase line to which the user electric meters belong according to impedance value fluctuation standard deviations of multiple periods of time, selecting an initial table from an identified phase line electric meter set, calculating Pearson correlation coefficients of the initial table and the user electric meters with the rest undetermined home phase lines so as to determine a temporary phase line, using the temporary phase line as the phase line to which the corresponding user electric meters belong if the temporary phase line meets a preset correlation coefficient condition, calculating correlation coefficients of the user electric meters with the rest determined home phase lines so as to determine the home phase lines of all the electric meters, and a phase sequence topology identification result of the station area is obtained, and the accuracy of phase sequence topology identification is improved.

Description

Transformer area phase sequence topology identification method and system based on voltage sequence similarity transmission
Technical Field
The invention relates to the technical field of distribution transformation phase sequence identification, in particular to a station area phase sequence topology identification method and system based on voltage sequence similarity transmission.
Background
At present, the problems of line loss of a transformer area, three-phase unbalance treatment, transformer area connection relation, fault positioning, emergency repair and power restoration and the like are difficult to solve fundamentally due to the fact that the topological relation of the transformer area of a low-voltage power distribution network is not clear, and therefore economic benefits and service quality of power supply enterprises are seriously affected. Therefore, the accurate table area topological relation information is obtained, and the method has very important value for power supply enterprises and users.
In the traditional technology, the topological relation of the transformer area is time-consuming and labor-consuming by means of manual on-site investigation, and the correctness of topological information cannot be guaranteed, the topological relation of the transformer area is combed by means of the transmission and receiving modes of electrical information through the installation of terminal equipment, the investment of a power grid is increased, and meanwhile, the pressure of front-line operation and maintenance is increased.
With the popularization of the intelligent electric meter, a large amount of electricity consumption data are accumulated for a power grid company, and at present, the voltage data of each node of a low-voltage transformer area can reflect the associated information of the physical topology of the low-voltage transformer area. The discrimination processing of different phase sequence electric meters with similar voltage data characteristics and electrical distances of different phase sequence electric meters is a difficult point of phase sequence identification of the single-phase electric meters in the low-voltage distribution area, so that the accuracy of a phase sequence topology identification result is influenced.
Disclosure of Invention
The invention provides a station area phase sequence topology identification method and system based on voltage sequence similarity transmission, and solves the technical problem of poor accuracy of phase sequence topology identification.
In view of this, the first aspect of the present invention provides a phase sequence topology identification method for a station area based on voltage sequence similarity transmission, including the following steps:
s1, collecting power data respectively corresponding to a distribution transformer low-voltage bus, a distribution transformer low-voltage outgoing line and a user ammeter of a target transformer area at the same moment in preset time, wherein the power data comprise voltage time sequence data, active power time sequence data and reactive power time sequence data;
s2, calculating fluctuation standard deviations of voltage time sequence data of all the user electric meters, and arranging the corresponding user electric meters according to the size relation of the fluctuation standard deviations in an ascending order to obtain a user electric meter arrangement set;
s3, traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking the voltage of a node where the electric meter is located as a downstream node, constructing a voltage longitudinal component drop equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node, thereby obtaining a multi-period voltage longitudinal component drop equation set, calculating an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component drop equation set, calculating an impedance value fluctuation standard deviation of multiple periods, and determining the phase line to which the user electric meter belongs based on the multi-period impedance value fluctuation standard deviation;
s4, moving the user electric meter with the determined home phase line to the pre-established identified phase line electric meter set,
judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set, if so, moving the user electric meter with the undetermined home phase line to a pre-established first phase line electric meter set to be identified, and executing the next step;
s5, selecting user electric meters with different phase lines from the identified phase line electric meter set as initial tables of the corresponding phase lines, and calculating the Pearson correlation coefficient of the voltage time sequence data of the user electric meters in the pre-established first phase line electric meter set to be identified and each initial table to obtain the phase line of the initial table with the maximum Pearson correlation coefficient as the temporary phase line of the corresponding user electric meter;
s6, judging whether the Pearson correlation coefficient meets a preset correlation coefficient condition, if so, taking the temporary phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined phase line to the pre-established identified phase line electric meter set;
s7, judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set or not, and if so, moving the user electric meter with the undetermined home phase line to a pre-established second phase line electric meter set to be identified;
and S8, determining a correlation coefficient between each user electric meter to be identified in the pre-established second phase line electric meter set to be identified and the voltage time sequence data of each user electric meter in the pre-established identified phase line electric meter set to use the phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficient as the phase line to which the corresponding phase line electric meter to be identified belongs until the phase line of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified is identified.
Preferably, step S2 is preceded by: preprocessing the voltage time sequence data, and specifically comprises the following steps:
s10, acquiring time periods with data loss in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter, and performing merging and collecting processing on the time periods with data loss in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter to obtain a data loss time period set;
and S11, removing corresponding time intervals in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter according to the data missing time interval set, and arranging the voltage data of all the reserved time intervals according to the sequence from large to small of the three-phase unbalance of the distribution transformer low-voltage bus, so as to obtain the preprocessed voltage time sequence data.
Preferably, step S3 specifically includes:
sequentially traversing each user electric meter in the user electric meter arrangement set, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking the voltage of a node where the electric meter is located as a downstream node, and constructing a voltage longitudinal component descending equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node as follows:
Figure 331284DEST_PATH_IMAGE001
formula 1
In formula 1, U1 t、P1 t、Q1 tVoltage, active power and reactive power of a head end node 1 of each phase line of the distribution transformer low-voltage outgoing line at the moment t are respectively measured; u shape2 tRepresenting the voltage of the node 2 where the electricity meter is located at the time t; rt、XtRespectively representing the resistance and reactance between node 1 and node 2; delta U1 tRepresents the voltage difference from node 1 to node 2;
order to
Figure 899669DEST_PATH_IMAGE002
，
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，
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，
Then the system of voltage longitudinal component drop equations is simplified as:
Figure 475509DEST_PATH_IMAGE005
formula 2
Establishing a multi-period voltage longitudinal component drop equation according to the formula 2 as follows:
Figure 418058DEST_PATH_IMAGE006
formula 3
In the formula 3, the first step is,
Figure 918309DEST_PATH_IMAGE007
，
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，
Figure 873813DEST_PATH_IMAGE009
，
Figure 775211DEST_PATH_IMAGE010
，
Figure 762758DEST_PATH_IMAGE011
，
Figure 987066DEST_PATH_IMAGE012
at time t
Figure 376459DEST_PATH_IMAGE013
Phase twolA voltage drop equation coefficient matrix from a head end node 1 of the return line to a node 2 of the user electric meter m,
Figure 723127DEST_PATH_IMAGE014
at time t
Figure 135654DEST_PATH_IMAGE013
Phase twolThe impedance vector from the head end node 1 of the return line to the node 2 of the user meter m,
Figure 960390DEST_PATH_IMAGE015
at time t
Figure 204290DEST_PATH_IMAGE013
Phase twolThe voltage drop longitudinal component vector from the head end node 1 of the return line to the node 2 of the user electric meter M, M is the total number of the user electric meters in the transformer area,
Figure 659542DEST_PATH_IMAGE013
for a certain phase in the phase sequence A, B, C,Lin order to match and change the number of low-voltage outgoing lines,Tthe number of the binary equation sets;Nfloor (-) is a floor rounding function for the total number of data periods;
substituting the power data of the user electric meter m at the time t into the formula 3 to obtain 3LThe multi-period voltage longitudinal component drop equation system is as follows:
Figure 621682DEST_PATH_IMAGE016
formula 4
Is pair (3)L)×TSolving the multiple-time-interval voltage longitudinal component drop equation to obtain a corresponding equation solution, and constructing (3 inL)×TDimensional impedance matrixZ m Comprises the following steps:
Figure 250109DEST_PATH_IMAGE017
formula 5
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，
Figure 977598DEST_PATH_IMAGE019
，
Figure 364717DEST_PATH_IMAGE020
Are respectively shown inTPhase line of time interval A, B, C phaseLThe impedance value of the user electric meter m;
calculating the standard deviation of the impedance fluctuation of the user electric meter m and each phase line, and recording the standard deviation as
Figure 531256DEST_PATH_IMAGE021
，
Figure 687431DEST_PATH_IMAGE022
，…，
Figure 546803DEST_PATH_IMAGE023
，…，
Figure 217956DEST_PATH_IMAGE024
The standard deviation of the impedance fluctuation is formed into a standard deviation vector of,
Figure 391448DEST_PATH_IMAGE025
in the formula (I), the compound is shown in the specification,
Figure 464446DEST_PATH_IMAGE021
，
Figure 432402DEST_PATH_IMAGE022
，…，
Figure 590851DEST_PATH_IMAGE023
，…，
Figure 36876DEST_PATH_IMAGE024
are respectively an impedance matrixZ m The standard deviation of the row vector of (a);
and determining the minimum value of the standard deviation of the impedance fluctuation according to the standard deviation vector, and determining the phase line corresponding to the minimum value as the phase line to which the user ammeter m belongs.
Preferably, step S4 is preceded by:
s400, constructing an identified phase line electric meter set, wherein the initial state of the identified phase line electric meter set is an empty set, and the identified phase line electric meter set is divided into three electric meter sub-sets, and the electric meter sub-sets comprise an A-phase electric meter sub-set, a B-phase electric meter sub-set and a C-phase electric meter sub-set;
step S4 specifically includes: s401, moving the corresponding user electric meters to the electric meter subset with the same phase line according to the home phase line, judging whether the user electric meters with undetermined home phase line exist in the user electric meter arrangement set, if so, moving the user electric meters with undetermined home phase line to a pre-established first phase line electric meter set to be identified, and executing the step S5.
Preferably, step S5 specifically includes:
s501, respectively proposing a corresponding preset number of user electric meters from the phase A electric meter subset, the phase B electric meter subset and the phase C electric meter subset in the identified phase line electric meter subset as a starting meter subset of a corresponding phase line;
s502, extracting A phase, B phase and A phase from the initial table set based on different phase linesOne user electric meter corresponding to the C phase is used as an initial meter of the corresponding phase line, so that three initial meters are obtained, and voltage time sequence data of the three initial meters form a matrix VupThe matrix VupDimension of (3)TThe matrix VupEach element of (1) representsLVoltage time sequence data of an initial table corresponding to the phase line;
s503, forming a matrix V by voltage time sequence data of all the user electric meters in the pre-established first phase line electric meter set to be identifieddownThe matrix VdownDimension of 3 keyX，XFor the total number of meters of the pre-established first phase line meter set to be identified, the matrix VdownEach element of (d) represents voltage timing data of the g-th electricity meter, and a matrix V is calculatedupAnd matrix VdownThe correlation coefficient matrix R of (a) is:
Figure 229960DEST_PATH_IMAGE026
formula 6
In the formula (6), the first and second polymers,
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，
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，
Figure 329525DEST_PATH_IMAGE029
respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownThe pearson correlation coefficient of the voltage timing data of the user electric meter of the first row and the first column in the first column,
Figure 377115DEST_PATH_IMAGE030
，
Figure 686874DEST_PATH_IMAGE031
，
Figure 819915DEST_PATH_IMAGE032
respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownTo (1)XIn line and at firstXPearson correlation coefficient of voltage timing data of the user electric meters of the column;
s504, the first row element of the correlation coefficient matrix R
Figure 873321DEST_PATH_IMAGE027
，
Figure 775418DEST_PATH_IMAGE033
，…，
Figure 318395DEST_PATH_IMAGE030
The elements in the second row and the elements in the third row of the matrix R are correspondingly arranged according to the element sequence after the elements in the first row are arranged, and the matrix R1 is obtained;
and S505, selecting the largest Pearson correlation coefficient in the column vectors from the 1 st column of the matrix R1, acquiring the phase line of the row corresponding to the largest Pearson correlation coefficient, and taking the phase line as the temporary phase line of the corresponding user electric meter.
Preferably, step S6 specifically includes:
traversing each user ammeter with the determined tentative phase line, searching the last user ammeter in the corresponding phase line subset from the pre-established first phase line ammeter set to be identified as a reference ammeter, and calculating a correlation coefficient of voltage time sequence data of the user ammeter with the tentative phase line and the reference ammeter with the corresponding phase line, and recording the correlation coefficient as r1Calculating the correlation coefficient of the reference ammeter and the previous ammeter on the same phase line, and recording as r2Calculating a correlation coefficient r1And the correlation coefficient r2Is recorded as the difference of the correlation coefficientΔr, judging whether the correlation coefficient difference is smaller than a preset correlation coefficient threshold value, if so, taking the tentative phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined phase line to the pre-established identified phase line electric meter set; if the judgment is no, marking the corresponding user electric meter as the undetermined home phase lineThe user electricity meter of (1).
Preferably, step S8 is followed by:
and S9, outputting the phase sequence topology recognition result of the user electric meter of the target station area according to the mapping relation of the user electric meter and the corresponding attributive phase line.
In a second aspect, the present invention further provides a station phase sequence topology identification system based on voltage sequence similarity transmission, including the following steps:
the data acquisition module is used for acquiring power data respectively corresponding to a distribution transformer low-voltage bus, a distribution transformer low-voltage outgoing line and a user ammeter of a target transformer area at the same moment in preset time, wherein the power data comprises voltage time sequence data, active power time sequence data and reactive power time sequence data;
the calculation module is used for calculating fluctuation standard deviations of voltage time sequence data of all the user electric meters and arranging the corresponding user electric meters according to the magnitude relation of the fluctuation standard deviations in an ascending order to obtain a user electric meter arrangement set;
the first home phase line determining module is used for traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each return phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking the voltage of a node where the electric meter is located as a downstream node, constructing a voltage longitudinal component descending equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node so as to obtain a multi-period voltage longitudinal component descending equation set, calculating an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component descending equation set, calculating an impedance value fluctuation standard deviation of multiple periods, and determining the phase line to which the user electric meter belongs based on the multi-period impedance value fluctuation standard deviation;
the first judgment module is used for moving the user electric meters with the determined home phase lines to a pre-established identified phase line electric meter set, judging whether the user electric meters with the undetermined home phase lines exist in the user electric meter arrangement set, and if the judgment is yes, moving the user electric meters with the undetermined home phase lines to a pre-established first phase line electric meter set to be identified;
the temporary phase line determining module is used for selecting user electric meters with different phase lines from the identified phase line electric meter set as corresponding initial phase line tables, and calculating the Pearson correlation coefficient of the voltage time sequence data of the user electric meters in the pre-established first phase line electric meter set to each initial table so as to obtain the phase line of the initial table with the maximum Pearson correlation coefficient as the temporary phase line of the corresponding user electric meter;
the second judgment module is used for judging whether the Pearson correlation coefficient meets a preset correlation coefficient condition or not, if so, the temporary phase line is used as the phase line to which the corresponding user electric meter belongs, and the user electric meter with the determined phase line to which the user electric meter belongs is moved to the pre-established identified phase line electric meter set;
the third judging module is used for judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set or not, and if so, moving the user electric meter with the undetermined home phase line to a pre-established second phase line electric meter set to be identified;
and the second attribution phase line determining module is used for determining the correlation coefficient of the voltage time sequence data of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified and each user electric meter in the pre-established identified phase line electric meter set to determine the phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficient as the corresponding phase line to which the phase line electric meter to be identified belongs until the phase line of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified is identified.
According to the technical scheme, the invention has the following advantages:
the invention utilizes the voltage similarity transfer characteristic, respectively corresponding voltage time sequence data of a distribution transformer low-voltage bus, a distribution transformer low-voltage outlet wire and a user electric meter at the same time in a preset time in a target station area are collected, fluctuation standard deviations of the voltage time sequence data of all the user electric meters are calculated, the user electric meters are arranged according to the size relationship of the fluctuation standard deviations to determine the upstream and downstream connection relationship of the electric meters, the impedance value between the user electric meter and the head end node of each phase line of each loop of the outlet wire is calculated, the phase line to which the user electric meter belongs is determined according to the fluctuation standard deviations of the impedance values in multiple time periods, then the user electric meters with different phase lines are selected from the identified phase line set as the initial table of the corresponding phase line, the Pearson correlation coefficient of the initial table and the user electric meters with the remained undetermined phase lines is calculated, the phase line of the initial table with the largest Pearson correlation coefficient is taken as the temporary phase line of the corresponding user electric meter, if the temporary phase line meets the preset correlation coefficient condition, the temporary phase line is used as the phase line to which the corresponding user electric meter belongs, then the correlation coefficient between the user electric meters which are not determined to belong to the phase line and the user electric meters with other determined to belong to the phase lines is calculated, the phase line of the identified phase line electric meter corresponding to the maximum value of the determined correlation coefficient is used as the phase line to which the corresponding phase line electric meter to be identified belongs, so that the belonging phase lines of all the electric meters are determined, the phase sequence topology identification result of the station area is obtained, and the accuracy of phase sequence topology identification is improved.
Drawings
Fig. 1 is a flowchart of a station phase sequence topology identification method based on voltage sequence similarity transmission according to an embodiment of the present invention;
fig. 2 is a schematic structural diagram of a station phase sequence topology identification system based on voltage sequence similarity transmission according to an embodiment of the present invention.
Detailed Description
In order to make the technical solutions of the present invention better understood, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
For easy understanding, referring to fig. 1, the method for identifying the phase sequence topology of the station area based on the voltage sequence similarity transmission provided by the present invention includes the following steps:
and S1, acquiring power data corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter of the target platform area at the same moment in preset time, wherein the power data comprise voltage time sequence data, active power time sequence data and reactive power time sequence data.
It is understood that the collection frequency and period may be preset, and the power data is collected based on the collection frequency and period, and the power data is time-sequenced.
And S2, calculating fluctuation standard deviations of the voltage time sequence data of all the user electric meters, and arranging the corresponding user electric meters according to the size relation of the fluctuation standard deviations in an ascending order to obtain a user electric meter arrangement set.
S3, traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking the voltage of a node where the electric meter is located as a downstream node, constructing a voltage longitudinal component descending equation set between the two nodes based on electric power data respectively corresponding to the upstream node and the downstream node, thereby obtaining a multi-period voltage longitudinal component descending equation set, calculating an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component descending equation set, calculating an impedance value fluctuation standard deviation of the multi-period, and determining the phase line to which the user electric meter belongs based on the multi-period impedance value fluctuation standard deviation.
S4, moving the user electric meter with the determined home phase line to the pre-established identified phase line electric meter set,
and judging whether the user electric meters with undetermined home phase lines exist in the user electric meter arrangement set, if so, moving the user electric meters with undetermined home phase lines to a pre-established first phase line electric meter set to be identified, and executing the next step.
And S5, selecting user electric meters with different phase lines from the identified phase line electric meter set as initial tables of corresponding phase lines, and calculating the Pearson correlation coefficient of the voltage time sequence data of the user electric meters in the first phase line electric meter set to be identified and each initial table, which is established in advance, so as to obtain the phase line of the initial table with the maximum Pearson correlation coefficient as the tentative phase line of the corresponding user electric meter.
And S6, judging whether the Pearson correlation coefficient meets a preset correlation coefficient condition, if so, taking the temporary phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined phase line to a pre-established identified phase line electric meter set.
And S7, judging whether the user electric meters with undetermined home phase lines exist in the user electric meter arrangement set, and if so, moving the user electric meters with undetermined home phase lines to a pre-established second phase line electric meter set to be identified.
And S8, determining a correlation coefficient of voltage time sequence data of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified and each user electric meter in the pre-established identified phase line electric meter set to use the phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficient as the phase line to which the corresponding phase line electric meter to be identified belongs until the phase line of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified is identified.
The invention provides a station area phase sequence topology identification method based on voltage sequence similarity transmission, which utilizes the voltage similarity transmission characteristics to calculate the fluctuation standard deviation of the voltage time sequence data of all user electric meters by acquiring the voltage time sequence data respectively corresponding to a distribution low-voltage bus, a distribution low-voltage outgoing line and the user electric meters at the same moment in preset time in a target station area, and arranges the user electric meters according to the size relationship of the fluctuation standard deviation to determine the upstream and downstream connection relationship of the electric meters, calculates the impedance value between the user electric meters and the head end node of each phase line of each outgoing line, determines the phase line to which the user electric meters belong according to the fluctuation standard deviation of the impedance values in multiple periods, selects the user electric meters with different phase lines from the identified electric meter phase line set as the initial table of the corresponding phase line, calculates the Pearson correlation coefficient between the initial table and the user electric meters with the rest undetermined phase lines, and if the tentative phase line meets a preset correlation coefficient condition, the tentative phase line is used as the phase line to which the corresponding user electric meter belongs, correlation coefficients of the remaining user electric meters not determined to belong to the phase line and other user electric meters determined to belong are calculated, and the phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficients is determined to be used as the phase line to which the corresponding phase line electric meter to be identified belongs, so that the phase line to which all the electric meters belong is determined, the phase sequence topology identification result of the station area is obtained, and the accuracy of phase sequence topology identification is improved.
The following is a detailed description of the station phase sequence topology identification method based on voltage sequence similarity transfer provided in this embodiment.
In a specific example, step S2 is preceded by: preprocessing voltage time sequence data, which specifically comprises the following steps:
s10, acquiring time periods with data loss in voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter, and performing merging and set processing on the time periods with data loss in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter to obtain a data loss time period set;
and S11, removing corresponding time intervals in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter according to the data missing time interval set, and arranging the voltage data of all the reserved time intervals according to the sequence from large to small of the three-phase unbalance of the distribution transformer low-voltage bus, so as to obtain the preprocessed voltage time sequence data.
Specifically, a time period with data missing in voltage time sequence data of the distribution and transformation low-voltage bus is represented by a set alpha 1, a time period with data missing in voltage time sequence data of the distribution and transformation low-voltage outlet line is represented by a set alpha 2, and a time period with data missing in voltage time sequence data of the user electric meter is represented by a set alpha 3, wherein the data missing means that no data exists in an acquisition time period, the set alpha = alpha 1-alpha 2-U alpha 3 is taken, data with the time period alpha in voltage curves of the distribution and transformation low-voltage bus, the distribution and transformation low-voltage outlet line and the user electric meter are respectively eliminated, and the screened data are reserved to rearrange all time period data in the order of the three-phase unbalance of the distribution and transformation low-voltage bus from large to small.
In a specific example, step S3 specifically includes:
s301, traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking the voltage of a node where the electric meter is located as a downstream node, and constructing a voltage longitudinal component descending equation set between the two nodes based on electric power data respectively corresponding to the upstream node and the downstream node as follows:
Figure 673153DEST_PATH_IMAGE034
formula 1
In formula 1, U1 t、P1 t、Q1 tVoltage, active power and reactive power of a head end node 1 of each phase line of the distribution transformer low-voltage outgoing line at the moment t are respectively; u shape2 tRepresenting the voltage of the node 2 where the electricity meter is located at the time t; rt、XtRespectively representing the resistance and reactance between node 1 and node 2; delta U1 tRepresents the voltage difference from node 1 to node 2;
s302, order
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，
Figure 286854DEST_PATH_IMAGE003
，
Figure 938415DEST_PATH_IMAGE004
，
Then the system of voltage longitudinal component drop equations is simplified as:
Figure 46048DEST_PATH_IMAGE005
formula 2
S303, establishing a multi-period voltage longitudinal component drop equation set according to the formula 2 as follows:
Figure 506504DEST_PATH_IMAGE006
formula 3
In the formula 3, the first step is,
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，
Figure 205656DEST_PATH_IMAGE008
，
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，
Figure 468327DEST_PATH_IMAGE010
，
Figure 199523DEST_PATH_IMAGE011
，
Figure 458466DEST_PATH_IMAGE012
at time t
Figure 9533DEST_PATH_IMAGE013
Phase onelA voltage drop equation coefficient matrix from a head end node 1 of the return line to a node 2 of the user electric meter m,
Figure 12124DEST_PATH_IMAGE014
at time t
Figure 597826DEST_PATH_IMAGE013
Phase twolThe impedance vector from the head end node 1 of the return line to the node 2 of the user meter m,
Figure 824408DEST_PATH_IMAGE015
at time t
Figure 66033DEST_PATH_IMAGE013
Phase twolThe voltage drop longitudinal component vector from the first end node 1 of the return line to the node 2 of the user electric meter M, M is the total number of the user electric meters in the transformer area,
Figure 669053DEST_PATH_IMAGE013
for a phase in phase sequence A, B, C,Lin order to match and change the number of low-voltage outgoing lines,Tthe number of the equation sets is two;Nfloor (-) is a floor rounding function for the total number of data periods;
s304, substituting the power data of the user electric meter m at the time t into the formula 3 to obtain 3 indexesLThe multi-period voltage longitudinal component drop equation system is as follows:
Figure 123910DEST_PATH_IMAGE036
formula 4
S305, pair (3 pieces)L)×TSolving the multiple-time-interval voltage longitudinal component drop equation to obtain a corresponding equation solution, and constructing (3 inL)×TDimensional impedance matrixZ m Comprises the following steps:
Figure 724656DEST_PATH_IMAGE037
formula 5
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，
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，
Figure 155003DEST_PATH_IMAGE020
Are respectively shown inTPhase line of time interval A, B, C phaseLThe impedance value of the user electric meter m;
s306, calculating the standard deviation of the impedance fluctuation of the user ammeter m and each phase line, and recording the standard deviation as
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，
Figure 939605DEST_PATH_IMAGE022
，…，
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，…，
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The standard deviation of the impedance fluctuation is formed into a standard deviation vector of,
Figure 976197DEST_PATH_IMAGE038
in the formula (I), the compound is shown in the specification,
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，
Figure 162645DEST_PATH_IMAGE022
，…，
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，…，
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are respectively an impedance matrixZ m The standard deviation of the row vector of (a);
and S307, determining the minimum value of the impedance fluctuation standard deviation according to the standard deviation vector, and determining the phase line corresponding to the minimum value as the phase line to which the user ammeter m belongs.
In a specific example, step S4 is preceded by:
s400, constructing an identified phase line ammeter set, wherein the initial state of the identified phase line ammeter set is an empty set, and the identified phase line ammeter set is divided into three ammeter sub-sets, and the ammeter sub-sets comprise an A-phase ammeter sub-set, a B-phase ammeter sub-set and a C-phase ammeter sub-set;
step S4 specifically includes: s401, moving the corresponding user electric meters to the electric meter subset with the same phase line according to the home phase line, judging whether the user electric meters with undetermined home phase line exist in the user electric meter arrangement set, if so, moving the user electric meters with undetermined home phase line to a pre-established first phase line electric meter set to be identified, and executing the step S5.
In a specific example, step S5 specifically includes:
s501, respectively proposing a corresponding preset number of user electric meters from an A-phase electric meter subset, a B-phase electric meter subset and a C-phase electric meter subset in the identified phase line electric meter subset as a corresponding phase line starting meter subset;
in a general example, the first 3 user meters in the phase a, B and C meter subsets are taken as the starting meter set for the corresponding phase line.
S502, based on different phase lines, extracting a user electric meter corresponding to the phase A, the phase B and the phase C respectively from the initial table set to serve as an initial table of the corresponding phase line, so as to obtain three initial tables, and forming a matrix V by voltage time sequence data of the three initial tablesupThe matrix VupDimension of (3)TThe matrix VupEach element of (1) representsLVoltage time sequence data of an initial table corresponding to the phase line;
in a general example, the last user electric meter corresponding to each of the phases a, B and C is extracted from the starting table set as the starting table of the corresponding phase line.
S503, forming a matrix V by voltage time sequence data of all the user electric meters in the pre-established first phase line electric meter set to be identifieddownThe matrix VdownDimension of 3 keyX，XMatrix V for the pre-established total number of electric meters of the first phase line electric meter set to be identifieddownEach element of (a) represents voltage timing data of the g-th electric meter, and a matrix V is calculatedupAnd matrix VdownThe correlation coefficient matrix R of (a) is:
Figure 535879DEST_PATH_IMAGE026
formula 6
In the formula (6), the first and second polymers,
Figure 760187DEST_PATH_IMAGE027
，
Figure 149580DEST_PATH_IMAGE028
，
Figure 433931DEST_PATH_IMAGE029
respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownThe pearson correlation coefficient of the voltage timing data of the user meter of the first row and the first column in the second row,
Figure 643195DEST_PATH_IMAGE030
，
Figure 671194DEST_PATH_IMAGE031
，
Figure 915094DEST_PATH_IMAGE032
respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownTo (1)XIn line and at firstXPearson correlation coefficient of voltage timing data of the user electric meters of the column;
s504, the first row element of the correlation coefficient matrix R
Figure 370346DEST_PATH_IMAGE027
，
Figure 332486DEST_PATH_IMAGE033
，…，
Figure 898596DEST_PATH_IMAGE030
The elements in the second row and the elements in the third row of the matrix R are correspondingly arranged according to the element sequence after the elements in the first row are arranged, and the matrix R1 is obtained;
and S505, selecting the largest Pearson correlation coefficient in the column vectors from the 1 st column of the matrix R1, acquiring the phase line of the row corresponding to the largest Pearson correlation coefficient, and taking the phase line as the temporary phase line of the corresponding user electric meter.
In a specific example, step S6 specifically includes:
traversing each user electric meter with the determined tentative phase line, and searching out a corresponding phase line subset from a pre-established first phase line electric meter set to be identifiedThe last user electric meter in the combination is used as a reference electric meter, and the correlation coefficient of the voltage time sequence data of the user electric meter with the temporary phase line and the reference electric meter with the corresponding phase line is calculated and recorded as r1Calculating the correlation coefficient of the reference ammeter and the previous ammeter on the same phase line, and recording as r2Calculating a correlation coefficient r1And the correlation coefficient r2Is recorded as the difference of the correlation coefficientΔr, judging whether the correlation coefficient difference is smaller than a preset correlation coefficient threshold value, if so, taking a temporary phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined attributive phase line to a pre-established identified phase line electric meter set; if the judgment is no, marking the corresponding user electric meter as the user electric meter of which the home phase line is not determined.
In a specific example, step S8 is followed by:
and S9, outputting the phase sequence topology recognition result of the user electric meter of the target station area according to the mapping relation of the user electric meter and the corresponding attributive phase line.
The above is a detailed description of an embodiment of the station phase sequence topology identification method based on voltage sequence similarity transmission provided by the present invention, and the following is a detailed description of an embodiment of the station phase sequence topology identification system based on voltage sequence similarity transmission provided by the present invention.
For convenience of understanding, referring to fig. 2, the present invention further provides a station phase sequence topology identification system based on voltage sequence similarity transmission, including the following steps:
the data acquisition module 100 is configured to acquire power data corresponding to a distribution transformer low-voltage bus, a distribution transformer low-voltage outgoing line and a user electric meter of a target station area at the same time within a preset time, where the power data includes voltage time sequence data, active power time sequence data and reactive power time sequence data;
the calculating module 200 is used for calculating fluctuation standard deviations of voltage time sequence data of all the user electric meters, and arranging the corresponding user electric meters according to an ascending order according to the size relation of the fluctuation standard deviations to obtain a user electric meter arrangement set;
the first home phase line determining module 300 is configured to sequentially traverse each user electric meter in the user electric meter arrangement set, use a head end node of each return phase line of the distribution transformer low-voltage outgoing line as an upstream node, use a voltage of a node where the electric meter is located as a downstream node, construct a voltage longitudinal component drop equation set between the upstream node and the downstream node based on power data corresponding to the upstream node and the downstream node, respectively, thereby obtaining a multi-period voltage longitudinal component drop equation set, calculate an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component drop equation set, calculate an impedance value fluctuation standard deviation of the multi-period, and determine a phase line to which the user electric meter belongs based on the multi-period impedance value fluctuation standard deviation;
the first judging module 400 is configured to move the user electric meters with the determined home phase line to a pre-established identified phase line electric meter set, judge whether there are user electric meters with undetermined home phase lines in the user electric meter arrangement set, and if yes, move the user electric meters with the undetermined home phase line to a pre-established first phase line electric meter set to be identified;
the tentative phase line determining module 500 is configured to select a user electric meter with different phase lines from the identified phase line electric meter set as an initial table of the corresponding phase line, and calculate a pearson correlation coefficient of voltage timing sequence data between the user electric meter in the first phase line electric meter set to be identified and each initial table, which is established in advance, so as to obtain a phase line of the initial table with the largest pearson correlation coefficient as the tentative phase line of the corresponding user electric meter;
a second determining module 600, configured to determine whether the pearson correlation coefficient meets a preset correlation coefficient condition, if so, use the tentative phase line as the phase line to which the corresponding user electric meter belongs, and move the user electric meter with the determined phase line to a pre-established identified phase line electric meter set;
a third determining module 700, configured to determine whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set, and if so, move the user electric meter with the undetermined home phase line to a second pre-established phase line electric meter set to be identified;
and a second home phase line determining module 800, configured to determine a correlation coefficient between each to-be-identified user electric meter in the pre-established second to-be-identified phase line electric meter set and voltage timing data of each user electric meter in the pre-established identified phase line electric meter set, and to use a phase line of the identified phase line electric meter corresponding to the maximum value of the determined correlation coefficient as a phase line to which the corresponding to-be-identified phase line electric meter belongs, until the phase line of each to-be-identified user electric meter in the pre-established second to-be-identified phase line electric meter set is identified.
It is clear to those skilled in the art that, for convenience and brevity of description, the specific working processes of the above-described systems, apparatuses and units may refer to the corresponding processes in the foregoing method embodiments, and are not described herein again.
In the embodiments provided in the present invention, it should be understood that the disclosed apparatus and method may be implemented in other ways. For example, the above-described apparatus embodiments are merely illustrative, and for example, a division of a unit is merely a logical division, and an actual implementation may have another division, for example, a plurality of 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.
Units described as separate parts may or may not be physically separate, and parts displayed as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the units can be selected according to actual needs to achieve the purpose of the solution of the embodiment.
In addition, functional units in the embodiments of the present invention may be integrated into one processing unit, or each unit may exist alone physically, or two or more units are integrated into one unit. The integrated unit can be realized in a form of hardware, and can also be realized in a form of a software functional unit.
The above examples are only intended to illustrate the technical solution of the present invention, and not to limit it; 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; and such modifications or substitutions do not depart from the spirit and scope of the corresponding technical solutions of the embodiments of the present invention.

Claims (7)

1. The station area phase sequence topology identification method based on voltage sequence similarity transmission is characterized by comprising the following steps of:
s1, collecting power data respectively corresponding to a distribution transformer low-voltage bus, a distribution transformer low-voltage outgoing line and a user ammeter of a target transformer area at the same moment in preset time, wherein the power data comprise voltage time sequence data, active power time sequence data and reactive power time sequence data;
s2, calculating fluctuation standard deviations of voltage time sequence data of all the user electric meters, and arranging the corresponding user electric meters according to the size relation of the fluctuation standard deviations in an ascending order to obtain a user electric meter arrangement set;
s3, traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking a node where the electric meter is located as a downstream node, constructing a voltage longitudinal component drop equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node, thereby obtaining a multi-period voltage longitudinal component drop equation set, calculating an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component drop equation set, calculating an impedance value fluctuation standard deviation of multiple periods, and determining the phase line to which the user electric meter belongs based on the impedance value fluctuation standard deviation of multiple periods;
s4, moving the user electric meter with the determined home phase line to the pre-established identified phase line electric meter set,
judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set, if so, moving the user electric meter with the undetermined home phase line to a pre-established first phase line electric meter set to be identified, and executing the next step;
s5, selecting user electric meters with different phase lines from the identified phase line electric meter set as initial tables of corresponding phase lines, and calculating the Pearson correlation coefficient of the voltage time sequence data of the user electric meters in the pre-established first phase line electric meter set to be identified and each initial table so as to obtain the phase line of the initial table with the maximum Pearson correlation coefficient as the tentative phase line of the corresponding user electric meter;
s6, judging whether the Pearson correlation coefficient meets a preset correlation coefficient condition, if so, taking the temporary phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined phase line to the pre-established identified phase line electric meter set;
s7, judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set or not, and if so, moving the user electric meter with the undetermined home phase line to a pre-established second phase line electric meter set to be identified;
s8, calculating a correlation coefficient between each user electric meter to be identified in the pre-established second phase line electric meter set to be identified and the voltage time sequence data of each user electric meter in the pre-established identified phase line electric meter set, and determining a phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficient as a phase line to which the corresponding phase line electric meter to be identified belongs until the phase line of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified is identified;
step S3 specifically includes:
sequentially traversing each user electric meter in the user electric meter arrangement set, taking a head end node of each phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking a node where the electric meter is located as a downstream node, and constructing a voltage longitudinal component descending equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node as follows:
Figure 718384DEST_PATH_IMAGE001
formula 1
In formula 1, U1 t、P1 t、Q1 tVoltage, active power and reactive power of a head end node 1 of each phase line of the distribution transformer low-voltage outgoing line at the moment t are respectively measured; u shape2 tRepresenting the voltage of the node 2 where the electricity meter is located at the time t; rt、XtRespectively representing the resistance and reactance between node 1 and node 2; delta U1 tRepresents the voltage difference from node 1 to node 2 at time t;
order to
Figure 184001DEST_PATH_IMAGE002
，
Then the system of voltage longitudinal component drop equations is simplified as:
Figure 442944DEST_PATH_IMAGE003
formula 2
Establishing a multi-period voltage longitudinal component drop equation according to the formula 2 as follows:
Figure 259590DEST_PATH_IMAGE004
formula 3
In the formula 3, the first step is,
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，
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，
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，
Figure 50511DEST_PATH_IMAGE008
，
Figure 653531DEST_PATH_IMAGE009
，
Figure 356389DEST_PATH_IMAGE010
at time t
Figure 691556DEST_PATH_IMAGE011
Phase twolA voltage drop equation coefficient matrix from a head end node 1 of the return line to a node 2 of the user electric meter m,
Figure 482794DEST_PATH_IMAGE012
at time t
Figure 623925DEST_PATH_IMAGE011
Phase onelThe impedance vector from the head end node 1 of the return line to the node 2 of the user meter m,
Figure 184220DEST_PATH_IMAGE013
at time t
Figure 690287DEST_PATH_IMAGE011
Phase twolThe voltage drop longitudinal component vector from the head end node 1 of the return line to the node 2 of the user electric meter M, M is the total number of the user electric meters in the transformer area,
Figure 968822DEST_PATH_IMAGE011
for a phase in phase sequence A, B, C,Lin order to match and change the number of low-voltage outgoing lines,Tthe number of the binary equation sets;Nfloor (-) is a floor rounding function for the total number of data periods;
substituting the power data of the user electric meter m at the time t into the formula 3 to obtain 3 indexesLThe multi-period voltage longitudinal component drop equation system is as follows:
Figure 851327DEST_PATH_IMAGE014
formula 4
Is pair (3)L)×TSolving the multiple-time-interval voltage longitudinal component drop equation to obtain a corresponding equation solution, and constructing (3 inL)×TDimensional impedance matrixZ m Comprises the following steps:
Figure 266128DEST_PATH_IMAGE015
formula 5
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，
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，
Figure 191862DEST_PATH_IMAGE018
Are respectively shown inTPhase line of time interval A, B, C phaseLThe impedance value of the user electric meter m;
calculating the standard deviation of the impedance fluctuation of the user electric meter m and each phase line, and recording the standard deviation as
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，
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，…，
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，…，
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The standard deviation of the impedance fluctuation is formed into a standard deviation vector of,
Figure DEST_PATH_IMAGE023
in the formula (I), the compound is shown in the specification,
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，
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，…，
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，…，
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are respectively an impedance matrixZ m The standard deviation of the row vector of (a);
and determining the minimum value of the standard deviation of the impedance fluctuation according to the standard deviation vector, and determining the phase line corresponding to the minimum value as the phase line to which the user ammeter m belongs.
2. The method for identifying the phase sequence topology of the station area based on the voltage sequence similarity transmission according to claim 1, wherein the step S2 is preceded by: preprocessing the voltage time sequence data, and specifically comprises the following steps:
s10, acquiring data missing time periods in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter, and performing a taking and combining process on the data missing time periods in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter to obtain a data missing time period set;
and S11, removing corresponding time intervals in the voltage time sequence data respectively corresponding to the distribution transformer low-voltage bus, the distribution transformer low-voltage outgoing line and the user electric meter according to the data missing time interval set, and arranging the voltage data of all the reserved time intervals according to the sequence from large to small of the three-phase unbalance of the distribution transformer low-voltage bus, so as to obtain the preprocessed voltage time sequence data.
3. The method for identifying the phase sequence topology of the transformer area based on voltage sequence similarity transmission according to claim 1, wherein step S4 is preceded by:
s400, constructing an identified phase line electric meter set, wherein the initial state of the identified phase line electric meter set is an empty set, and the identified phase line electric meter set is divided into three electric meter sub-sets, and the electric meter sub-sets comprise an A-phase electric meter sub-set, a B-phase electric meter sub-set and a C-phase electric meter sub-set;
step S4 specifically includes: s401, moving the corresponding user electric meters to the electric meter subset with the same phase line according to the home phase line, judging whether the user electric meters with undetermined home phase line exist in the user electric meter arrangement set, if so, moving the user electric meters with undetermined home phase line to a pre-established first phase line electric meter set to be identified, and executing the step S5.
4. The method for identifying the phase sequence topology of the transformer area based on the voltage sequence similarity transmission as claimed in claim 3, wherein the step S5 specifically comprises:
s501, respectively proposing a corresponding preset number of user electric meters from the phase A electric meter subset, the phase B electric meter subset and the phase C electric meter subset in the identified phase line electric meter subset as a starting meter subset of a corresponding phase line;
s502, based on different phase lines, extracting one user electric meter corresponding to the phase A, the phase B and the phase C respectively from the initial table set to serve as an initial table of the corresponding phase line, so as to obtain three initial tables, and forming a matrix V by voltage time sequence data of the three initial tablesupThe matrix VupDimension of (3)TThe matrix VupEach element of (1) representsLVoltage time sequence data of an initial table corresponding to the phase line;
s503, forming a matrix V by voltage time sequence data of all the user electric meters in the pre-established first phase line electric meter set to be identifieddownThe matrix VdownDimension of 3 keyX，XFor the pre-established total number of meters of the first phase line meter set to be identified,matrix VdownEach element of (d) represents voltage timing data of the g-th electricity meter, and a matrix V is calculatedupSum matrix VdownThe correlation coefficient matrix R of (a) is:
Figure 276403DEST_PATH_IMAGE028
formula 6
In the formula (6), the first and second polymers,
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，
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，
Figure 322222DEST_PATH_IMAGE031
respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownThe pearson correlation coefficient of the voltage timing data of the user electric meter of the first row and the first column in the first column,
Figure 420628DEST_PATH_IMAGE032
，
Figure DEST_PATH_IMAGE033
，
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respectively represent a matrix VupVoltage timing data of the first, second and third rows of the matrix VdownTo (1)XIn line and at firstXPearson correlation coefficient of voltage timing data of the user electric meters of the column;
s504, the first row element of the correlation coefficient matrix R
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，
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，…，
Figure 790320DEST_PATH_IMAGE032
The elements in the second row and the elements in the third row of the matrix R are correspondingly arranged according to the element sequence after the elements in the first row are arranged, and the matrix R1 is obtained;
and S505, selecting the largest Pearson correlation coefficient in the column vectors from the 1 st column of the matrix R1, acquiring the phase line of the row corresponding to the largest Pearson correlation coefficient, and taking the phase line as the temporary phase line of the corresponding user electric meter.
5. The method for identifying the phase sequence topology of the transformer area based on the voltage sequence similarity transmission as claimed in claim 4, wherein the step S6 specifically comprises:
traversing each user ammeter with the determined tentative phase line, searching the last user ammeter in the corresponding phase line subset from the pre-established first phase line ammeter set to be identified as a reference ammeter, and calculating a correlation coefficient of voltage time sequence data of the user ammeter with the tentative phase line and the reference ammeter with the corresponding phase line, and recording the correlation coefficient as r1Calculating the correlation coefficient of the reference ammeter and the previous ammeter on the same phase line, and recording as r2Calculating a correlation coefficient r1And the correlation coefficient r2Is recorded as the difference of the correlation coefficientΔr, judging whether the correlation coefficient difference is smaller than a preset correlation coefficient threshold value, if so, taking the temporary phase line as the phase line to which the corresponding user electric meter belongs, and moving the user electric meter with the determined attributive phase line to the pre-established identified phase line electric meter set; if the judgment is no, marking the corresponding user electric meter as the user electric meter of which the home phase line is not determined.
6. The method for identifying the phase sequence topology of the transformer area based on the voltage sequence similarity transmission of claim 5, wherein the step S8 is followed by further comprising:
and S9, outputting the phase sequence topology recognition result of the user electric meter of the target station area according to the mapping relation of the user electric meter and the corresponding attributive phase line.
7. The station area phase sequence topology identification system based on voltage sequence similarity transmission is characterized by comprising the following steps of:
the data acquisition module is used for acquiring power data respectively corresponding to a distribution transformer low-voltage bus, a distribution transformer low-voltage outgoing line and a user ammeter of a target transformer area at the same moment in preset time, wherein the power data comprises voltage time sequence data, active power time sequence data and reactive power time sequence data;
the calculation module is used for calculating fluctuation standard deviations of voltage time sequence data of all the user electric meters and arranging the corresponding user electric meters according to the magnitude relation of the fluctuation standard deviations in an ascending order to obtain a user electric meter arrangement set;
the first home phase line determining module is used for traversing each user electric meter in the user electric meter arrangement set in sequence, taking a head end node of each return phase line of a distribution transformer low-voltage outgoing line as an upstream node, taking a node where the electric meter is located as a downstream node, constructing a voltage longitudinal component descending equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node, so as to obtain a multi-period voltage longitudinal component descending equation set, calculating an impedance value between the upstream node and the downstream node based on the multi-period voltage longitudinal component descending equation set, calculating an impedance value fluctuation standard deviation of multiple periods, and determining the phase line to which the user electric meter belongs based on the multi-period impedance value fluctuation standard deviation;
the first home phase line determining module is specifically configured to sequentially traverse each user electric meter in the user electric meter arrangement set, take a head end node of each return phase line of the distribution transformer low-voltage outgoing line as an upstream node, take a node where the electric meter is located as a downstream node, and construct a voltage longitudinal component drop equation set between the two nodes based on the electric power data respectively corresponding to the upstream node and the downstream node as follows:
Figure 8812DEST_PATH_IMAGE001
formula 1
In formula 1, U1 t、P1 t、Q1 tVoltage, active power and reactive power of a head end node 1 of each phase line of the distribution transformer low-voltage outgoing line at the moment t are respectively measured; u shape2 tRepresenting the voltage of the node 2 where the electricity meter is located at the time t; rt、XtRespectively representing the resistance and reactance between node 1 and node 2; delta U1 tRepresents the voltage difference from node 1 to node 2 at time t;
order to
Figure 805867DEST_PATH_IMAGE036
，
Then the system of voltage longitudinal component drop equations is simplified as:
Figure 477019DEST_PATH_IMAGE003
formula 2
The multi-period voltage longitudinal component drop equation set is established according to the formula 2 as follows:
Figure 712829DEST_PATH_IMAGE004
formula 3
In the formula 3, the first step is,
Figure 785827DEST_PATH_IMAGE037
，
Figure 753783DEST_PATH_IMAGE038
，
Figure 912232DEST_PATH_IMAGE039
，
Figure 420573DEST_PATH_IMAGE040
，
Figure 613657DEST_PATH_IMAGE009
，
Figure 752515DEST_PATH_IMAGE041
at time t
Figure 395330DEST_PATH_IMAGE011
Phase twolA voltage drop equation coefficient matrix from a head end node 1 of the return line to a node 2 of the user electric meter m,
Figure 707363DEST_PATH_IMAGE042
at time t
Figure 754953DEST_PATH_IMAGE011
Phase twolThe impedance vector from the head end node 1 of the return line to the node 2 of the user meter m,
Figure 64712DEST_PATH_IMAGE043
at time t
Figure 197753DEST_PATH_IMAGE011
Phase twolThe voltage drop longitudinal component vector from the first end node 1 of the return line to the node 2 of the user electric meter M, M is the total number of the user electric meters in the transformer area,
Figure 313476DEST_PATH_IMAGE011
for a certain phase in the phase sequence A, B, C,Lin order to distribute the number of low-voltage outgoing lines,Tthe number of the binary equation sets;Nfloor (-) is a floor rounding function for the total number of data periods;
substituting the power data of the user electric meter m at the time t into the formula 3 to obtain 3 indexesLThe system of the multi-period voltage longitudinal component drop equation is as follows:
Figure 153256DEST_PATH_IMAGE014
formula 4
Is pair (3)L)×TMultiple multi-period voltage longitudinal component drop equationSolving is carried out, corresponding equation solution is obtained, and (3 in a database) is constructed based on the equation solutionL)×TDimensional impedance matrixZ m Comprises the following steps:
Figure DEST_PATH_IMAGE044
formula 5
Figure 758550DEST_PATH_IMAGE045
，
Figure 113308DEST_PATH_IMAGE046
，
Figure 970406DEST_PATH_IMAGE047
Are respectively shown inTPhase line of time interval A, B, C phaseLThe impedance value of the user electric meter m;
calculating the standard deviation of the impedance fluctuation of the user electric meter m and each phase line, and recording the standard deviation as
Figure 729939DEST_PATH_IMAGE048
，
Figure 443817DEST_PATH_IMAGE049
，…，
Figure 489133DEST_PATH_IMAGE050
，…，
Figure 946659DEST_PATH_IMAGE051
The standard deviation of the impedance fluctuation is formed into a standard deviation vector of,
Figure 557769DEST_PATH_IMAGE052
in the formula (I), the compound is shown in the specification,
Figure 708128DEST_PATH_IMAGE053
，
Figure 975161DEST_PATH_IMAGE054
，…，
Figure 970799DEST_PATH_IMAGE055
，…，
Figure 701995DEST_PATH_IMAGE056
are respectively an impedance matrixZ m The standard deviation of the row vector of (a);
determining the minimum value of the impedance fluctuation standard deviation according to the standard deviation vector, and determining the phase line corresponding to the minimum value as the phase line to which the user ammeter m belongs;
the first judgment module is used for moving the user electric meters with the determined home phase lines to a pre-established identified phase line electric meter set, judging whether the user electric meters with the undetermined home phase lines exist in the user electric meter arrangement set, and if the judgment is yes, moving the user electric meters with the undetermined home phase lines to a pre-established first phase line electric meter set to be identified;
the temporary phase line determining module is used for selecting user electric meters with different phase lines from the identified phase line electric meter set as corresponding initial phase line tables, and calculating the Pearson correlation coefficient of the voltage time sequence data of the user electric meters in the pre-established first phase line electric meter set to each initial table so as to obtain the phase line of the initial table with the maximum Pearson correlation coefficient as the temporary phase line of the corresponding user electric meter;
the second judgment module is used for judging whether the Pearson correlation coefficient meets a preset correlation coefficient condition or not, if so, the temporary phase line is used as the phase line to which the corresponding user electric meter belongs, and the user electric meter with the determined phase line to which the user electric meter belongs is moved to the pre-established identified phase line electric meter set;
the third judging module is used for judging whether a user electric meter with an undetermined home phase line exists in the user electric meter arrangement set or not, and if so, moving the user electric meter with the undetermined home phase line to a pre-established second phase line electric meter set to be identified;
and the second attribution phase line determining module is used for calculating a correlation coefficient of voltage time sequence data of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified and each user electric meter in the pre-established identified phase line electric meter set, determining a phase line of the identified phase line electric meter corresponding to the maximum value of the correlation coefficient as a phase line to which the corresponding phase line electric meter to be identified belongs until the phase line of each user electric meter to be identified in the pre-established second phase line electric meter set to be identified is identified.
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