CN112700144A - Transformer substation operation state risk assessment method, device, equipment and storage medium - Google Patents

Transformer substation operation state risk assessment method, device, equipment and storage medium Download PDF

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Publication number
CN112700144A
CN112700144A CN202011635219.0A CN202011635219A CN112700144A CN 112700144 A CN112700144 A CN 112700144A CN 202011635219 A CN202011635219 A CN 202011635219A CN 112700144 A CN112700144 A CN 112700144A
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transformer
distribution
data information
risk index
user
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CN112700144B (en
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陈永进
黄天敏
刘志勇
胡高峰
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Shaoguan Power Supply Bureau Guangdong Power Grid Co Ltd
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Shaoguan Power Supply Bureau Guangdong Power Grid Co Ltd
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    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q10/00—Administration; Management
    • G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
    • G06Q10/063—Operations research, analysis or management
    • G06Q10/0635—Risk analysis of enterprise or organisation activities
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
    • G06Q50/06—Electricity, gas or water supply
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00001—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by the display of information or by user interaction, e.g. supervisory control and data acquisition systems [SCADA] or graphical user interfaces [GUI]
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00002—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by monitoring
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00034—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving an electric power substation
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • 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
    • Y04S10/16—Electric power substations
    • 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

Abstract

The invention discloses a transformer substation operation state risk assessment method, a device, equipment and a storage medium. The method comprises the following steps: respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network; determining a risk index of the transformer according to the transformer data information; determining a feeder operation risk index according to the feeder data information; determining a risk index of the distribution transformer according to the data information of the distribution transformer; determining a user operation risk index according to the user data information; performing risk assessment on at least one of a transformer risk index, a feeder line operation risk index, a distribution transformer risk index and a user operation risk index; and if the evaluation result is abnormal, generating alarm information to prompt operating personnel. By the method, risk assessment can be performed on different devices in the power distribution network in real time.

Description

Transformer substation operation state risk assessment method, device, equipment and storage medium
Technical Field
The embodiment of the invention relates to the technical field of automatic control of a power distribution network, in particular to a method, a device, equipment and a storage medium for risk assessment of a running state of a transformer substation.
Background
The power distribution network is composed of a power distribution substation, a power distribution line, a power distribution transformer and electric equipment, is directly connected with a power transmission system and users, is a ring directly connected with the users in the power system, is responsible for directly supplying and distributing electric energy to the users, and has the characteristics of large equipment quantity, special operation mode and the like.
However, the existing power distribution network has the problems of single state monitoring and evaluation of each pair of equipment, incomplete fault handling and the like.
Disclosure of Invention
The embodiment of the invention provides a risk assessment method, a risk assessment device, equipment and a storage medium for an operation state of a transformer substation, which can carry out risk assessment on different equipment in a power distribution network in real time.
In a first aspect, an embodiment of the present invention provides a transformer substation operation state risk assessment method, including:
respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
determining a risk index of the transformer according to the transformer data information;
determining a feeder operation risk index according to the feeder data information;
determining a distribution transformer risk index according to the distribution transformer data information;
determining a user operation risk index according to the user data information;
performing risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index and the user operation risk index;
and if the evaluation result is abnormal, generating alarm information to prompt operating personnel.
In a second aspect, an embodiment of the present invention further provides a transformer substation operation state risk assessment apparatus, including:
the acquisition module is used for respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
the first determining module is used for determining a risk index of the transformer according to the transformer data information;
the second determining module is used for determining a feeder operation risk index according to the feeder data information;
the third determining module is used for determining the risk index of the distribution transformer according to the data information of the distribution transformer;
the fourth determining module is used for determining the user operation risk index according to the user data information;
the risk evaluation module is used for carrying out risk evaluation on at least one of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index;
and the alarm module is used for generating alarm information to prompt operating personnel if the evaluation result is abnormal.
In a third aspect, an embodiment of the present invention further provides a terminal device, including:
one or more processors;
storage means for storing one or more programs;
the one or more programs are executed by the one or more processors, so that the one or more processors are used for implementing the substation operation state risk assessment method in any embodiment of the invention.
In a fourth aspect, an embodiment of the present invention further provides a computer-readable storage medium, on which a computer program is stored, where the computer program, when executed by a processor, implements the transformer substation operating state risk assessment method according to any embodiment of the present invention.
The embodiment of the invention provides a method, a device, equipment and a storage medium for evaluating the risk of a running state of a transformer substation, which comprises the steps of firstly respectively acquiring data information of a transformer in the transformer substation, data information of a feeder line in a distribution network, data information of a distribution transformer in the distribution network and user data information of a user under the distribution transformer in the distribution network; then determining a risk index of the transformer according to the transformer data information; determining a feeder operation risk index according to the feeder data information; determining a distribution transformer risk index according to the distribution transformer data information; determining a user operation risk index according to the user data information; then, performing risk assessment on at least one of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index; and finally, if the evaluation result is abnormal, generating alarm information to prompt operating personnel. By means of the technical scheme, risk assessment can be carried out on different devices in the power distribution network in real time.
Drawings
Fig. 1 is a schematic flow chart of a transformer substation operation state risk assessment method according to an embodiment of the present invention;
fig. 2 is a schematic flowchart illustrating an example of a risk assessment method for an operating state of a substation according to a second embodiment of the present invention;
fig. 3 is a schematic diagram of an electrical relationship according to a second embodiment of the present invention;
fig. 4 is a schematic structural diagram of a risk assessment apparatus for an operating state of a transformer substation according to a third embodiment of the present invention;
fig. 5 is a schematic structural diagram of a terminal device according to a fourth embodiment of the present invention.
Detailed Description
Embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. While certain embodiments of the present invention are shown in the drawings, it should be understood that the present invention may be embodied in various forms and should not be construed as limited to the embodiments set forth herein, but rather are provided for a more thorough and complete understanding of the present disclosure. It should be understood that the drawings and the embodiments of the present invention are illustrative only and are not intended to limit the scope of the present invention.
It should be understood that the various steps recited in the method embodiments of the present invention may be performed in a different order and/or performed in parallel. Moreover, method embodiments may include additional steps and/or omit performing the illustrated steps. The scope of the invention is not limited in this respect.
The term "include" and variations thereof as used herein are open-ended, i.e., "including but not limited to". The term "based on" is "based, at least in part, on". The term "one embodiment" means "at least one embodiment"; the term "another embodiment" means "at least one additional embodiment"; the term "some embodiments" means "at least some embodiments". Relevant definitions for other terms will be given in the following description.
It should be noted that the terms "first", "second", and the like in the present invention are only used for distinguishing different devices, modules or units, and are not used for limiting the order or interdependence relationship of the functions performed by the devices, modules or units.
It is noted that references to "a", "an", and "the" modifications in the present invention are intended to be illustrative rather than limiting, and that those skilled in the art will recognize that reference to "one or more" unless the context clearly dictates otherwise.
The names of messages or information exchanged between devices in the embodiments of the present invention are for illustrative purposes only, and are not intended to limit the scope of the messages or information.
Example one
Fig. 1 is a schematic flow chart of risk assessment of an operating state of a substation according to an embodiment of the present invention, where the method is applicable to a situation of assessing states of different devices and objects in a power distribution network, and the method may be performed by a risk assessment apparatus of an operating state of a substation, where the apparatus may be implemented by software and/or hardware and is generally integrated on a terminal device, where the terminal device in this embodiment includes but is not limited to: a computer device.
As shown in fig. 1, a risk assessment of a substation operating state according to a first embodiment of the present invention includes the following steps:
s110, respectively obtaining transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network.
In this embodiment, the transformation transformer data information of the transformer in the substation may include: the transformer voltage deviation, the out-of-limit frequency percentage of the transformer voltage, the out-of-limit time ratio of the frequency, the operating oil temperature value and the service life of the transformer. The operating oil temperature value And the service life of the transformer can be acquired by a Supervisory Control And Data Acquisition (SCADA) system, And the transformation voltage deviation, the transformation voltage out-of-limit frequency percentage And the frequency out-of-limit time ratio are obtained by further calculation.
Specifically, the method for calculating the substation voltage deviation may be: and acquiring the operating voltage of the ith transformer in the transformer substation at the moment j from the SCADA system, and then acquiring the rated voltage of the ith transformer in the transformer substation. If j is 1,2 … N, the transformation voltage deviation of the ith transformer may be calculated as:
Figure BDA0002880978170000061
wherein ,UBTi-jRepresents the operating voltage of the ith transformer in the transformer substation at the moment j, UBNiIndicating the rated voltage of the ith transformer in the substation.
Specifically, the method for calculating the percentage of the out-of-limit frequency of the transformation voltage may be: acquiring n transformation voltage measurement values of an ith transformer of a transformer substation in unit time from an SCADA system, namely, indicating that the total measurement times are n, and selecting the transformation voltage measurement value obtained by the jth measurement, wherein j is 1 and 2 … n. Setting the upper limit value of the out-of-limit transformation voltage as UHThe lower limit value is setIs set to ULAnd determining the transformer voltage measured value which exceeds the upper limit value or is lower than the lower limit value in the n transformer voltage measured values as the out-of-limit transformer voltage, and calculating the percentage of the occurrence frequency of the out-of-limit transformer voltage measured value to the total measurement frequency, namely n to obtain the percentage of the out-of-limit frequency of the transformer voltage of the ith transformer. The specific calculation formula is as follows:
Figure BDA0002880978170000062
wherein ,nT-outIt may represent the number of occurrences of the out-of-limit transformer voltage measurement and n represents the total number of measurements of the transformer voltage. Wherein n isT-outThe calculation formula of (2) is as follows:
Figure BDA0002880978170000063
wherein ,UTf(j) May represent 0 or 1, UTf(j) Can be calculated according to the classification function, the calculation formula is as follows:
Figure BDA0002880978170000064
wherein ,Ure-Ti(j) Represents the measured value of the transformation voltage obtained by the j measurement, when Ure-Ti(j) Greater than UHThen U will beTf(j) Output is 1 when Ure-Ti(j) Greater than or equal to ULAnd is less than or equal to UHThen U will beTf(j) Output is 0 when Ure-Ti(j) Less than ULThen U will beTf(j) The output is-1.
Further, the upper limit frequency percentage of the transformation voltage and the lower limit frequency percentage of the transformation voltage can be calculated.
Specifically, the formula for calculating the percentage of the upper limit frequency of the transformation voltage is as follows:
Figure BDA0002880978170000071
wherein ,nout-upIndicating that more than U is measured in the measured values of the transformation voltageHThe calculation formula of the number of times of occurrence of the measured value of the transformation voltage is as follows:
Figure BDA0002880978170000072
specifically, the formula for calculating the lower limit frequency percentage of the transformation voltage is as follows:
Figure BDA0002880978170000073
wherein ,nout-lowIndicating that less than U is contained in the measured values of the transformation voltageLThe calculation formula of the number of times of occurrence of the measured value of the transformation voltage is as follows:
Figure BDA0002880978170000074
specifically, the way of calculating the frequency out-of-limit time ratio may be: n transformation frequency measurement values of the ith transformer of the transformer substation in unit time are obtained in the SCADA system, namely the total measurement times are n. And selecting the measured value of the power transformation frequency obtained by the j-th measurement, wherein j is 1 and 2 … n. Will not belong to [0.99f ]N，1.01fN]The measured value of the transformation frequency in the range is determined as the out-of-limit transformation frequency value, wherein fNIs the nominal frequency. Determining the percentage of the occurrence frequency of the out-of-limit transformation frequency value and the total measurement frequency n as the frequency out-of-limit time ratio of the ith transformer of the transformer substation, wherein the specific calculation formula is as follows:
Figure BDA0002880978170000075
wherein ,nfoRepresenting the number of occurrences of the out-of-limit transformer frequency value, ftiThe frequency out-of-limit time ratio of the ith transformer of the power station is shown.
In this embodiment, the feeder data information in the distribution network may include a line length value, a line service life, a line load rate distribution ratio, and a line loss rate distribution frequency ratio of the line. The line length value and the line service life can be obtained through an SCADA system, and the line load rate distribution condition proportion and the line loss rate distribution frequency proportion of the line need to be obtained through further calculation.
Specifically, the way of calculating the line load rate distribution ratio may be: the method comprises the steps of obtaining current of an ith line in a distribution network from an SCADA system, obtaining n current measurement values flowing through the ith line in unit time, namely representing that the total measurement times are n, and selecting a current measurement value obtained by the jth measurement, wherein j is 1 and 2 … n. The line load rate may include a light load rate, a heavy load rate, and an overload rate.
Specifically, the line load rate calculation formula for the ith line is as follows:
Figure BDA0002880978170000081
wherein ,Ii(j) Represents the current measurement value obtained from the j-th measurement, IiNIndicating the rated current of the ith line in the distribution network. If calculated RLThe value of (C) is [0, 20%]Within the interval, indicating the light load of the line, n isl(j) The jth number of the vector is 1, if RLThe value of (A) is not in the range of [0, 20%]Within the interval, n isl(j) The jth number of (a) is 0; if R isLThe value of (C) is [ 80%, 100%]Within the interval, indicating the line heavy load, n is seth(j) The jth value of the vector is 1 if RLThe value of (A) is not [ 80%, 100%]Within the interval, n ish(j) The jth numerical value of the vector takes 0; if R isLIf the value of (1) is greater than 100%, the line is overloaded and n is seto(j) The jth number of the vector takes a value of 1, otherwise the jth number takes a value of 0.
Respectively pass through formulas
Figure BDA0002880978170000082
And
Figure BDA0002880978170000083
respectively calculate Nl、Nh and No. wherein ,NlRepresenting the times of the light line load of the ith line in the distribution network; n is a radical ofhRepresenting the times of line overloading of the ith line in the distribution network; n is a radical ofoAnd the number of times of line overload of the ith line in the distribution network is represented.
The line load rate distribution situation occupation ratio of the ith line in the distribution network can be calculated through the following formula:
Figure BDA0002880978170000084
wherein ,LRLi-lLine light load distribution ratio, LR, representing ith line in distribution networkLi-hShowing line heavy load distribution ratio, LR, of ith line in distribution networkLi-oAnd the line overload distribution ratio of the ith line in the distribution network is shown.
Specifically, the way of calculating the line loss rate distribution frequency ratio may be: n active power measurement values of the current flowing through the ith line within a set time threshold value are obtained from the SCADA system, namely the total number of measurement is n, and the set time threshold value can be 24 hours. And selecting the active power measured value obtained by the j measurement, wherein j is 1 and 2 … n. Secondly, the line loss rate of the ith line can be calculated by the following formula:
Figure BDA0002880978170000091
wherein ,ΔPi(j) Represents the active power loss, P, obtained by the j measurement of the ith linei(j) And d, representing the active power measured value obtained by the jth measurement of the ith line, and delta representing the line loss rate of the jth measured value of the ith line. If delta exceeds the limit value deltalimitThen n ishThe value is 1, otherwise the value is 0, nhRepresents an n-dimensional vector composed of 0 and 1 elements.
It should be noted that the line loss rate distribution frequency ratio may include a line loss rate distribution frequency ratio of a heavy loss line and a line loss rate distribution frequency ratio of a non-heavy loss line. The specific calculation formula is as follows:
Figure BDA0002880978170000092
wherein ,Lloss-i-hLine loss rate distribution frequency ratio, L, representing heavy loss lineloss-i-nLine loss rate distribution frequency ratio, N, representing non-heavy loss linehThe line loss rate of the ith line exceeds a limit value deltalimitThe calculation formula of (c) is:
Figure BDA0002880978170000093
in this embodiment, the distribution transformer data information of the distribution transformer in the distribution network may include: the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase unbalance condition and the proportion of the qualified power factor condition. The service life of the distribution transformer can be obtained through an SCADA system, and distribution voltage deviation, the proportion of three-phase unbalance conditions and the proportion of power factor qualified conditions are obtained through further calculation.
Specifically, the manner of calculating the distribution voltage deviation may be: and acquiring the operating voltage of the ith distribution transformer in the power distribution network at the moment j from the SCADA system, and then acquiring the rated voltage of the ith distribution transformer in the power distribution network. Where j is 1,2 … N, the distribution voltage deviation is calculated as:
Figure BDA0002880978170000101
wherein ,UTi-jRepresents the operating voltage, U, of the ith distribution transformer in the distribution network at time jNiIndicating the rated voltage, δ U, of the ith distribution transformer in the distribution networkTiAnd the distribution voltage deviation of the ith distribution transformer in the distribution network is shown.
Specifically, the method for calculating the ratio of the three-phase imbalance conditions may be: the n three-phase current measurements of the ith distribution transformer within a set time threshold, i.e., representing a total number of measurements of n, are obtained from the SCADA system, and the set time threshold may be, for example, 24 hours. And selecting three-phase current measured values obtained by the j-th measurement, wherein j is 1 and 2 … n. Then, the three-phase unbalance of the ith distribution transformer can be calculated by the following formula:
Figure BDA0002880978170000102
wherein ,Ii-max(j) Representing the maximum phase current, I, of the three-phase current measurements taken at the jth distributori-min(j) And the minimum phase current in the three-phase current measured values obtained by the ith distributor in the jth measurement is shown. M if ε is [ 15%, 50%) and the time ratio is greater than 5%l(i) Value is 1, otherwise ml(i) The value is 0, if epsilon is greater than or equal to 50% and the time ratio is greater than 20%, then mh(i) Value is 1, otherwise mh(i) The value is 0. It should be noted that the time ratio is understood as the percentage of the duration value of epsilon fixed to a value to the set time threshold.
Wherein, the three-phase unbalance condition ratio may include a slight three-phase unbalance ratio and a serious three-phase unbalance ratio, and the formula for calculating the three-phase unbalance condition ratio is as follows:
Figure BDA0002880978170000111
wherein ,KDT-lRepresenting the proportion of slight three-phase unbalance, K, of the ith distributorDT-hRepresenting a severe three-phase imbalance ratio, M, of the ith distributorlThe number of times of occurrence of the measured value belonging to the slight three-phase current imbalance in the n times of measurement of the ith distributor is represented by the following calculation formula:
Figure BDA0002880978170000112
mlrepresents an n-dimensional vector composed of 0 and 1 elements; mhThe number of times of occurrence of the measured value belonging to the serious three-phase current imbalance in the n times of measurement of the ith distributor is represented by the formula
Figure BDA0002880978170000113
mhRepresents an n-dimensional vector composed of 0 and 1 elements.
Specifically, the calculation of the power factor qualification case ratio may be: n power measurements of the ith distribution transformer within a set time threshold, i.e., representing a total number of measurements n, are obtained from the SCADA system, and the set time threshold may be, for example, 24 hours. And selecting the power measurement value obtained by the j measurement, wherein j is 1 and 2 … n. It should be noted that the power measurement may include an active power measurement and a reactive power measurement. Then, the active power factor and the reactive power factor of the ith distribution transformer can be calculated by the following formulas:
Figure BDA0002880978170000114
wherein ,Pi(j) Representing the active power measurement, Q, of the ith distribution transformer measured for the jth timei(j) Represents the reactive power measurement value of the j th measurement of the ith distribution transformer,
Figure BDA0002880978170000115
represents the active power factor measured j times by the ith distribution transformer,
Figure BDA0002880978170000121
and the j measured reactive power factor of the ith distribution transformer is represented. If it is
Figure BDA0002880978170000122
If the active power factor is greater than the specified value, m isq(j) The value is 1, otherwise the value is 0; if it is
Figure BDA0002880978170000123
If it is greater than the specified reactive power factor value, mu(j) The value is 1, otherwise the value is 0.
The ratio of the qualified power factor condition may include a ratio of the qualified active power condition and a ratio of the qualified reactive power condition, and the specific calculation formula is as follows:
Figure BDA0002880978170000124
wherein ,PFDT-qThe percentage of qualified active power, PF, of the ith distributorDT-uM represents the ratio of qualified reactive power of the ith distributorqAnd the number of times of occurrence of qualified active power measured values in the n active power measured values of the ith distributor is represented by the following calculation formula:
Figure BDA0002880978170000125
mqrepresents an n-dimensional vector composed of 0 and 1 elements; muThe number of times of occurrence of qualified reactive power measured values in the n reactive power measured values of the ith distributor is represented by the following calculation formula:
Figure BDA0002880978170000126
murepresents an n-dimensional vector composed of 0 and 1 elements.
In this embodiment, the user data information of the user under the distribution transformer in the distribution network may include: subscriber voltage deviation and subscriber voltage off-limit frequency percentage. Wherein, the user voltage deviation and the user voltage out-of-limit frequency percentage need to be obtained through further calculation.
Specifically, the manner of calculating the user voltage deviation may be: the data information of all users under the distribution transformer is acquired from the SCADA system, and the data information of the users can be exemplarily
Figure BDA0002880978170000127
wherein ,CijThe j-th user under the ith distribution transformer in the distribution network can be represented, i is 1,2,3 … m, and j is 1,2,3 … n. And acquiring the user voltage of the j user in the ith distribution transformer in the distribution network and the rated voltage in the ith distribution transformer in the distribution network from the SCADA system. The distribution voltage deviation of the ith distribution transformer can be calculated as:
Figure BDA0002880978170000131
wherein ,UCi-jIndicating the subscriber voltage, U, of the j-th subscriber in the ith distribution transformer in the distribution networkCNiIndicating the rated voltage in the ith distribution transformer in the distribution network.
Specifically, the method for calculating the percentage of the out-of-limit frequency of the user voltage may be: acquiring n user voltage measured values of the ith user in the power distribution network in unit time from the SCADA system, namely, indicating that the total measurement times are n, and selecting the user voltage measured value obtained by the jth measurement, wherein j is 1 and 2 … n. Setting the upper limit value of the out-of-limit user voltage as UhThe lower limit value is set to UlAnd determining the user voltage measured value which exceeds the upper limit value or is lower than the lower limit value in the n user voltage measured values as the out-of-limit user voltage, and calculating the percentage of the times of the out-of-limit user voltage measured values to the total measurement times n to obtain the out-of-limit frequency percentage of the user voltage of the ith user. The specific calculation formula is as follows:
Figure BDA0002880978170000132
wherein ,nC-outRepresenting the number of occurrences of an out-of-limit subscriber voltage measurement, and n represents the total number of measurements of the subscriber voltage. Wherein n isC-outThe calculation formula of (2) is as follows:
Figure BDA0002880978170000133
wherein ,Ucf(j) May represent 0 or 1, Ucf(j) Can be calculated according to the classification function, the calculation formula is as follows:
Figure BDA0002880978170000134
wherein ,Ure-Ci(j) Representing the user voltage measurement from the jth measurement,when U is turnedre-Ci(j) Greater than UhThen U will becf(j) Output is 1 when Ure-Ci(j) Greater than or equal to UlAnd is less than or equal to UhThen U will becf(j) Output is 0 when Ure-Ci(j) Less than UlThen U will becf(j) The output is-1.
Specifically, the formula for calculating the percentage of the frequency of the user voltage exceeding the upper limit is as follows:
Figure BDA0002880978170000141
wherein ,nC-out-upIndicating that more than U is present in the measured subscriber voltage measurementhThe number of occurrences of the user voltage measurement is calculated by the formula:
Figure BDA0002880978170000142
specifically, the formula for calculating the lower limit frequency percentage of the user is as follows:
Figure BDA0002880978170000143
wherein ,nC-out-lowIndicating that less than U is measured in the measured user voltage measurement valuelThe number of occurrences of the user voltage measurement is calculated by the formula:
Figure BDA0002880978170000144
and S120, determining a risk index of the transformer according to the transformer data information.
In this embodiment, the risk index of the transformer may be a risk index of a transformer failure in the transformer substation.
Further, determining a risk index of the transformer according to the transformer data information includes: and carrying out weighted summation on the transformation voltage deviation, the transformation voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the operating oil temperature value and the transformer service life to obtain a transformer risk index.
Specifically, the transformer voltage deviation, the out-of-limit frequency percentage of the transformer voltage, the out-of-limit time ratio of the frequency, the operating oil temperature value and the service life are multiplied by the corresponding weight values and then added to obtain the risk index R of the transformerBTi. The corresponding weight values can be obtained according to a transformer index weight distribution table. R is as defined aboveBTiAnd representing the risk index of the transformation transformer of the ith transformer in the transformer substation.
Wherein, the risk index R of the transformerBTiThe calculation formula of (2) is as follows:
RBTi＝wbt1×YBTi+wbt2×TBTemp-i+wbt3×δUBTi+wbt4×UTi-out+wbt5×fti
wherein ,YBTiIndicating the service life of the ith transformer in the substation, wbt1Represents YBTiWeight of (1), TBTemp-iIndicating the operating oil temperature value, w, of the ith transformer in the substationbt2Represents TBTemp-iWeight of δ UBTiIndicating the variation voltage of the ith transformer in the substation, wbt3Represents δ UBTiWeight of U, UT-outRepresents the percentage of the out-of-limit frequency of the transformation voltage of the ith transformer in the transformer station, wbt4Represents UTi-outWeight of (f)tiRepresenting the ratio of the out-of-limit time of the frequency of the ith transformer in the substation, wbt5Denotes ftiThe weight of (c).
Wherein, the distribution table of index weight of transformer is shown as follows, the table includes wbt1、wbt2、wbt3、wbt4 and wbt5The weight value of (2).
Figure BDA0002880978170000151
TABLE 1
And S130, determining a feeder operation risk index according to the feeder data information.
In this embodiment, the feeder operation risk index may be a risk index of a line failure in the power distribution network.
Further, determining a feeder operation risk index according to the feeder data information includes: and carrying out weighted summation on the line length value, the line service life, the line load rate distribution ratio and the line loss rate distribution frequency ratio of the line to obtain a feeder line operation risk index.
Specifically, the feeder operation risk index R may be obtained by multiplying the length of the line, the service life of the line, the ratio of the load rate distribution of the line, the ratio of the line loss rate distribution frequency of the line, and the ratio of the line loss rate distribution frequency by the corresponding weight value, and then adding the multiplied ratiosLi. The weighted values corresponding to the above items can be obtained according to the line index weighted distribution table. R is as defined aboveLiAnd the feeder operation risk index of the ith line in the power distribution network is represented.
Wherein, the feeder line operation risk index R of the ith lineLiThe calculation formula of (2) is as follows:
RLi＝wl1×LLength-i+wl2×YLi+wl3×LRLi+wl4×LLoss-i
wherein ,LLength-iIndicating the length, w, of the ith line in the distribution networkl1Represents LLength-iWeight of (A), YLiIndicating the service life of the ith line in the distribution network, wl2Represents YLiWeight of (1), LRLiRepresenting the line load rate distribution ratio, w, of the ith line in the distribution networkl3Represents LRLiWeight of (1), LLoss-iRepresents the line loss rate distribution frequency ratio, w, of the ith line in the distribution networkl4Represents LLoss-iThe weight of (c).
Wherein, the line evaluation index weight distribution table is shown as follows, and the table comprises wl1、wl2、wl3 and wl4The weight value of (2).
Line evaluation index weight wl1 wl2 wl3 wl4
Weighted value 0.1 0.15 0.45 0.3
TABLE 2
And S140, determining the risk index of the distribution transformer according to the data information of the distribution transformer.
In this embodiment, the distribution transformer risk index may be a risk index of a distribution transformer in a distribution network that fails.
Further, determining a distribution transformer risk index based on the distribution transformer data information includes: and carrying out weighted summation on the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase unbalance condition and the proportion of the power factor qualified condition to obtain a risk index of the distribution transformer.
Specifically, the distribution transformer risk index R may be obtained by multiplying the distribution transformer service life, the distribution voltage deviation, the ratio of the three-phase imbalance condition and the ratio of the power factor qualification condition by the corresponding weight values, and adding the multiplication resultsTi. Wherein, the above mentioned each pairThe corresponding weight value can be obtained according to the distribution transformer evaluation index weight table. R is as defined aboveTiAnd (4) indicating the distribution transformer risk index of the ith distribution transformer in the distribution network.
Wherein the distribution transformer risk index RTiThe calculation formula of (2) is as follows:
RTi＝wt1×YTi+wt2×δUTi+wt3KDTi-l+wt4×PFDTi
wherein ,YTiShowing the service life of the ith distribution transformer in the distribution network, wt1Represents YTiWeight of δ UTiIndicating the distribution voltage deviation, w, of the ith distribution transformer in the distribution networkt2Represents δ UTiWeight of (1), KDTi-lRepresenting the proportion of the three-phase unbalance condition of the ith distribution transformer in the distribution network, wt3Represents KDTi-lWeight of, PFDTiRepresents the power factor qualification ratio, w, of the ith distribution transformer in the distribution networkt4Denotes PFDTiThe weight of (c).
Wherein, the distribution transformer evaluation index weight distribution table is shown as follows, the table comprises wt1、wt2、wt3 and wt4The weight value of (2).
Figure BDA0002880978170000171
TABLE 3
And S150, determining the user operation risk index according to the user data information.
In this embodiment, the user operation risk index may be a risk index of a voltage failure of all users under a distribution transformer in the distribution network.
Further, determining the user operation risk index according to the user data information includes: and carrying out weighted summation on the user voltage deviation and the user voltage out-of-limit frequency percentage to obtain a user operation risk index.
In particular, the subscriber voltages may be biased andmultiplying the percentage of the out-of-limit frequency of the user voltage by the corresponding weight value, and adding to obtain the user operation risk index RCij. The weighted values corresponding to the items can be obtained according to a user evaluation index weighted table. R is as defined aboveCijAnd the user operation risk index of the j user under the ith distribution transformer in the distribution network is represented.
Wherein, the user operation risk index R of the jth userCijThe calculation formula of (2) is as follows:
RCij＝wc1×δUCi+wc2×UCi-out
wherein ,δUCiIndicating the user voltage deviation, w, of the jth userc1Represents δ UCiWeight of U, UCi-outRepresents the percentage of the user voltage off-limit frequency, w, of the jth userc2Represents UCi-outThe weight of (c).
Wherein, the user evaluation index weight distribution table is shown in table 4, and the table includes wc1 and wc2The weight value of (2).
User evaluation index weight wc1 wc2
Weighted value 0.6 0.4
TABLE 4
And S160, performing risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index and the user operation risk index.
In this embodiment, any one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index, and the user operation risk index may be evaluated according to the evaluation index table. The evaluation index table is shown in table 5:
evaluation index RBTi RLi RTi RCij
Reference value 6 6 6 4
TABLE 5
Illustratively, R is calculated asBTiNot equal to reference value 6, then R is representedBTiThe result is abnormal; if R isCijIs not equal to the reference value 4, then R is representedCijThe result is abnormal.
Further, if the risk index R of the transformerBTiThe result is abnormal, and the transformation voltage deviation, the transformation voltage out-of-limit frequency percentage and the frequency out-of-limit time accounting in the transformation transformer data information can be further evaluated through a transformation transformer parameter evaluation tableAnd grading the ratio, the operating oil temperature value and the service life of the transformer.
The transformer parameter scoring table is shown in table 6, and corresponding expert scores can be obtained according to the specific numerical value correspondence table 6 of each parameter.
Figure BDA0002880978170000191
TABLE 6
Further, if the feeder line runs risk index RLiAnd if the result is abnormal, the feeder parameter scoring table can further score the line length value, the line service life, the line load rate distribution ratio and the line loss rate distribution frequency ratio of the line included in the feeder data information.
The feeder parameter scoring table is shown in table 7, and corresponding expert scores can be obtained according to the specific numerical values of the parameters corresponding to table 7.
Figure BDA0002880978170000192
Figure BDA0002880978170000201
TABLE 7
Further, if the distribution transformer risk index RTiAnd if the result is abnormal, the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase unbalance degree and the proportion of the qualified power factor in the data information of the distribution transformer can be further graded through a distribution transformer parameter grading table.
The distribution transformer parameter scoring table is shown in table 8, and corresponding expert scores can be obtained according to the specific numerical values of the parameters corresponding to table 8.
Figure BDA0002880978170000202
TABLE 8
Further, if the user runs risk index result RCijAnd if the user voltage is abnormal, the user voltage deviation and the percentage of the out-of-limit frequency of the user voltage included in the user data information can be further graded through a user voltage parameter grading table.
The user voltage parameter scoring table is shown in table 9, and the corresponding expert score can be obtained according to the specific numerical value correspondence table 9 of each parameter.
Figure BDA0002880978170000211
TABLE 9
And S170, if the evaluation result is abnormal, generating alarm information to prompt operating personnel.
If any one evaluation result of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index is abnormal, alarm information can be generated to prompt operation scheduling personnel to provide a corresponding reference solution.
The method for assessing the risk of the running state of the transformer substation, provided by the embodiment of the invention, comprises the steps of firstly respectively obtaining data information of a transformer in the transformer substation, data information of a feeder line in a distribution network, data information of a distribution transformer of the distribution transformer in the distribution network and user data information of a user under the distribution transformer in the distribution network; then determining a risk index of the transformer according to the transformer data information; determining a feeder operation risk index according to the feeder data information; determining a distribution transformer risk index according to the distribution transformer data information; determining a user operation risk index according to the user data information; then, performing risk assessment on at least one of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index; and finally, if the evaluation result is abnormal, generating alarm information to prompt operating personnel. By the method, the running states of the transformer substation, the distribution line, the distribution transformer and the user in the power distribution network can be analyzed in real time, and a corresponding reference solution is provided for operation scheduling personnel when the state of one part of the power distribution network is abnormal.
Example two
Fig. 2 is a schematic flowchart of an example of a risk assessment method for an operating state of a transformer substation according to a second embodiment of the present invention, and this embodiment exemplarily illustrates the risk assessment method for the operating state of the transformer substation on the basis of the first embodiment.
As shown in fig. 2, the data input part may include data collected in real time, data analyzed for power flow, and data input manually. The real-time data acquisition may include real-time acquisition of various data about transformers in a substation, real-time acquisition of various data about feeders in a power distribution network, real-time acquisition of various data about distribution transformers in the power distribution network, and real-time acquisition of various data about user voltages under the distribution transformers. The flow analysis data can include data obtained by processing part of bad data acquired by the grid structure flow, such as data acquisition loss of some monitoring points, and the data with obvious abnormality can be obtained by analyzing and processing abnormal data or missing data to obtain normal data. The manual input data may include data such as the operational age of the transformer, the oil temperature, and the length of the feeder.
After the data are obtained, risk assessment can be respectively carried out on the transformer substation, the feeder line, the distribution transformer and the user, namely the system risk of the transformer substation, the operation risk of the feeder line, the equipment risk of the distribution transformer and the power utilization risk of the user are assessed.
Further, the risk indexes evaluated when evaluating the system risk may include the transformer service life, the transformer voltage deviation, and the frequency statistical indexes may include the transformer voltage out-of-limit frequency percentage and the frequency out-of-limit time ratio. If the evaluation result is abnormal, an alarm in the preprocessing scheme can be executed to remind operation and maintenance personnel to conduct troubleshooting and maintenance.
Further, the risk indicators evaluated when evaluating the operation risk may include a ratio of current-carrying capacity, a line length, a line load rate, i.e., a line load rate distribution, and a ratio of line loss distribution, i.e., a line loss rate distribution frequency of the line. If the evaluation result is abnormal, the load transfer in the preprocessing scheme can be executed.
Further, the risk indicators evaluated in assessing the risk of the equipment may include defects, distribution transformer age, distribution voltage deviation, distribution voltage, power factor, and frequency statistics. The frequency statistical index can comprise a power factor qualification condition ratio and a three-phase unbalance condition ratio. If the evaluation result is abnormal, the load transfer in the preprocessing scheme can be executed.
Further, the risk indicators evaluated when evaluating the power utilization risk may include a user voltage deviation, a statistical indicator of the voltage occurrence frequency, i.e., a user voltage out-of-limit frequency percentage. If the evaluation result is abnormal, the voltage or frequency can be adjusted through the voltage regulating or frequency modulating device in the preprocessing scheme.
Fig. 3 is a schematic diagram of an electrical relationship according to a second embodiment of the present invention. As shown in fig. 3, the substation is connected to a distribution line, and a plurality of distribution transformers may be connected to the distribution line, and each distribution transformer may supply power to a plurality of users.
According to the transformer substation operation state risk assessment method provided by the embodiment of the invention, the risk state of the equipment is comprehensively assessed by acquiring data in the power distribution network detection equipment and some data manually input into the relevant equipment, setting corresponding consideration indexes according to different equipment, considering various factors influencing the normal operation of the equipment, and providing a corresponding solution for a dispatching operator to refer when the comprehensive assessment risk index of the relevant equipment is lower than a reference value.
EXAMPLE III
Fig. 4 is a schematic structural diagram of a risk assessment apparatus for an operating state of a substation according to a third embodiment of the present invention, where the apparatus is applicable to a situation of assessing states of different devices and objects in a power distribution network, where the apparatus may be implemented by software and/or hardware and is generally integrated on a terminal device.
As shown in fig. 4, the apparatus includes: an acquisition module 410, a first determination module 420, a second determination module 430, a third determination module 440, a fourth determination module 450, a risk assessment module 460, and an alarm module 470.
An obtaining module 410, configured to obtain transformer data information of a transformer in a transformer substation, feeder data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network, and user data information of a user under the distribution transformer in the distribution network, respectively;
a first determining module 420, configured to determine a risk index of the transformer according to the transformer data information;
a second determining module 430, configured to determine a feeder operation risk index according to the feeder data information;
a third determining module 440, configured to determine a distribution transformer risk index according to the distribution transformer data information;
a fourth determining module 450, configured to determine a user operation risk index according to the user data information;
a risk assessment module 460, configured to perform risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index, and the user operation risk index;
and the alarm module 470 is configured to generate alarm information to prompt an operator if the evaluation result is abnormal.
In this embodiment, the device first obtains, through an obtaining module, transformer data information of a transformer in a transformer substation, feeder data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network, and user data information of a user under the distribution transformer in the distribution network, respectively; secondly, determining a risk index of the transformer according to the transformer data information through a first determining module; determining a feeder operation risk index according to the feeder data information through a second determination module; determining a risk index of the distribution transformer according to the data information of the distribution transformer through a third determination module; determining a user operation risk index according to the user data information through a fourth determination module; then, performing risk assessment on at least one of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index through a risk assessment module; and finally, if the evaluation result is abnormal, an alarm message is generated through the alarm module to prompt operating personnel.
The embodiment provides a transformer substation operation state risk assessment device, which can analyze the operation states of a transformer substation transformer, a distribution line, a distribution transformer and a user in a power distribution network in real time and provide a corresponding reference solution for operation scheduling personnel when the state of a certain part of the power distribution network is abnormal.
Further, the transformer data information in the obtaining module 410 includes a transformation voltage deviation, a transformation voltage out-of-limit frequency percentage, a frequency out-of-limit time ratio, an operating oil temperature value and a transformer service life; the first determining module 420 is specifically configured to perform weighted summation on the transformer voltage deviation, the out-of-limit frequency percentage of the transformer voltage, the out-of-limit time ratio of the frequency, the operating oil temperature value, and the service life of the transformer, so as to obtain a risk index of the transformer.
On the basis of the above optimization, the first determining module 420 further includes a transformation voltage deviation calculating unit, and the transformation voltage deviation calculating unit is configured to calculate the transformation voltage deviation according to the following formula:
Figure BDA0002880978170000251
wherein ,UBTi-jRepresents the operating voltage of the ith transformer in the transformer substation at the moment j, UBNiIndicating the rated voltage of the ith transformer in the substation.
Further, the feeder data information in the obtaining module 410 includes a line length value, a line service life, a line load rate distribution ratio, and a line loss rate distribution frequency ratio of the line; the second determining module 430 is specifically configured to perform weighted summation on the line length value, the line service life, the line load rate distribution ratio, and the line loss rate distribution frequency ratio of the line, so as to obtain a feeder operation risk index.
Further, the data information of the electrical transformer in the obtaining module 410 includes the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase unbalance condition and the proportion of the power factor qualified condition; the third determining module 440 is specifically configured to perform weighted summation on the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase imbalance condition, and the proportion of the power factor qualified condition, so as to obtain a risk index of the distribution transformer.
On the basis of the above optimization, the third determining module 440 further includes a power factor qualification case ratio calculating unit, and the power factor qualification case ratio calculating unit is configured to calculate the power factor qualification case ratio according to the following formula:
Figure BDA0002880978170000261
wherein ,
Figure BDA0002880978170000262
the number of the qualified active powers is represented,
Figure BDA0002880978170000263
number of qualified reactive powers, mq and muAll represent m-dimensional vectors composed of 0 and 1 elements, n represents the total number of power measurements, and PFDT-qRepresenting the power factor qualification rate.
Further, the user data information in the obtaining module 410 includes user voltage deviation and user voltage out-of-limit frequency percentage; the fourth determining module 450 is specifically configured to perform weighted summation on the user voltage deviation and the user voltage out-of-limit frequency percentage, so as to obtain a user operation risk index.
The transformer substation operation state risk assessment device can execute the transformer substation operation state risk assessment method provided by any embodiment of the invention, and has corresponding functional modules and beneficial effects of the execution method.
Example four
Fig. 5 is a schematic structural diagram of a terminal device according to a fourth embodiment of the present invention. As shown in fig. 5, a terminal device provided in the fourth embodiment of the present invention includes: one or more processors 51 and storage 52; the number of the processors 51 in the terminal device may be one or more, and one processor 51 is taken as an example in fig. 5; storage 52 is used to store one or more programs; the one or more programs are executed by the one or more processors 51, so that the one or more processors 51 implement the substation operating state risk assessment method according to any one of the embodiments of the present invention.
The terminal device may further include: an input device 53 and an output device 54.
The processor 51, the storage device 52, the input device 53 and the output device 54 in the terminal equipment may be connected by a bus or other means, and the connection by the bus is exemplified in fig. 5.
The storage device 52 in the terminal device serves as a computer-readable storage medium, and may be configured to store one or more programs, which may be software programs, computer-executable programs, and modules, such as program instructions/modules corresponding to the substation operation state risk assessment method provided in the embodiment of the present invention (for example, the modules in the substation operation state risk assessment device shown in fig. 4 include a first determination module 420, a second determination module 430, a third determination module 440, a fourth determination module 440, and the like). The processor 51 executes various functional applications and data processing of the terminal device by running software programs, instructions and modules stored in the storage device 52, that is, implements the transformer substation operation state risk assessment method in the above method embodiment.
The storage device 52 may include a storage program area and a storage data area, wherein the storage program area may store an operating system, an application program required for at least one function; the storage data area may store data created according to the use of the terminal device, and the like. Further, the storage 52 may include high speed random access memory, and may also include non-volatile memory, such as at least one magnetic disk storage device, flash memory device, or other non-volatile solid state storage device. In some examples, the storage 52 may further include memory located remotely from the processor 51, which may be connected to the device over a network. Examples of such networks include, but are not limited to, the internet, intranets, local area networks, mobile communication networks, and combinations thereof.
The input device 53 may be used to receive input numeric or character information and generate key signal inputs related to user settings and function control of the terminal device. The output device 54 may include a display device such as a display screen.
And, when the one or more programs included in the above-mentioned terminal device are executed by the one or more processors 51, the programs perform the following operations:
respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
determining a risk index of the transformer according to the transformer data information;
determining a feeder operation risk index according to the feeder data information;
determining a distribution transformer risk index according to the distribution transformer data information;
determining a user operation risk index according to the user data information;
performing risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index and the user operation risk index;
and if the evaluation result is abnormal, generating alarm information to prompt operating personnel.
EXAMPLE five
An embodiment of the present invention provides a computer-readable storage medium, on which a computer program is stored, where the computer program is used, when executed by a processor, to execute a transformer substation operation state risk assessment method, where the method includes:
respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
determining a risk index of the transformer according to the transformer data information;
determining a feeder operation risk index according to the feeder data information;
determining a distribution transformer risk index according to the distribution transformer data information;
determining a user operation risk index according to the user data information;
performing risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index and the user operation risk index;
and if the evaluation result is abnormal, generating alarm information to prompt operating personnel.
Optionally, the program, when executed by the processor, may be further configured to execute the method for risk assessment of an operating state of a substation provided in any embodiment of the present invention.
Computer storage media for embodiments of the invention may employ any combination of one or more computer-readable media. The computer readable medium may be a computer readable signal medium or a computer readable storage medium. A computer readable storage medium may be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or any combination of the foregoing. More specific examples (a non-exhaustive list) of the computer readable storage medium would include the following: an electrical connection having one or more wires, a portable computer diskette, a hard disk, a Random Access Memory (RAM), a Read Only Memory (ROM), an Erasable Programmable Read Only Memory (EPROM), a flash Memory, an optical fiber, a portable CD-ROM, an optical storage device, a magnetic storage device, or any suitable combination of the foregoing. A computer readable storage medium may be any tangible medium that can contain, or store a program for use by or in connection with an instruction execution system, apparatus, or device.
A computer readable signal medium may include a propagated data signal with computer readable program code embodied therein, for example, in baseband or as part of a carrier wave. Such a propagated data signal may take a variety of forms, including, but not limited to: an electromagnetic signal, an optical signal, or any suitable combination of the foregoing. A computer readable signal medium may also be any computer readable medium that is not a computer readable storage medium and that can communicate, propagate, or transport a program for use by or in connection with an instruction execution system, apparatus, or device.
Program code embodied on a computer readable medium may be transmitted using any appropriate medium, including but not limited to: wireless, wire, fiber optic cable, Radio Frequency (RF), etc., or any suitable combination of the foregoing.
Computer program code for carrying out operations for aspects of the present invention may be written in any combination of one or more programming languages, including an object oriented programming language such as Java, Smalltalk, C + + or the like and conventional procedural programming languages, such as the "C" programming language or similar programming languages. The program code may execute entirely on the user's computer, partly on the user's computer, as a stand-alone software package, partly on the user's computer and partly on a remote computer or entirely on the remote computer or server. In the case of a remote computer, the remote computer may be connected to the user's computer through any type of network, including a Local Area Network (LAN) or a Wide Area Network (WAN), or the connection may be made to an external computer (for example, through the Internet using an Internet service provider).
It is to be noted that the foregoing is only illustrative of the preferred embodiments of the present invention and the technical principles employed. It will be understood by those skilled in the art that the present invention is not limited to the particular embodiments described herein, but is capable of various obvious changes, rearrangements and substitutions as will now become apparent to those skilled in the art without departing from the scope of the invention. Therefore, although the present invention has been described in greater detail by the above embodiments, the present invention is not limited to the above embodiments, and may include other equivalent embodiments without departing from the spirit of the present invention, and the scope of the present invention is determined by the scope of the appended claims.

Claims (10)

1. A risk assessment method for an operation state of a transformer substation is characterized by comprising the following steps:
respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
determining a risk index of the transformer according to the transformer data information;
determining a feeder operation risk index according to the feeder data information;
determining a distribution transformer risk index according to the distribution transformer data information;
determining a user operation risk index according to the user data information;
performing risk assessment on at least one of the transformer risk index, the feeder operation risk index, the distribution transformer risk index and the user operation risk index;
and if the evaluation result is abnormal, generating alarm information to prompt operating personnel.
2. The method of claim 1, wherein the transformer data information includes a transformation voltage deviation, a transformation voltage out-of-limit frequency percentage, a frequency out-of-limit time ratio, an operating oil temperature value, and a transformation transformer service life; the determining of the risk index of the transformer according to the transformer data information comprises:
and carrying out weighted summation on the transformation voltage deviation, the transformation voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the operating oil temperature value and the transformer service life to obtain a transformer risk index.
3. The method of claim 2, wherein the transformation voltage deviation is calculated according to the following equation:
Figure FDA0002880978160000011
wherein ,UBTi-jRepresents the operating voltage of the ith transformer in the transformer substation at the moment j, UBNiIndicating the rated voltage of the ith transformer in the substation.
4. The method of claim 1, wherein the feeder data information comprises a line length value, a line service life, a line load rate distribution ratio, and a line loss rate distribution frequency ratio of the line; the determining a feeder operation risk index according to the feeder data information includes:
and carrying out weighted summation on the line length value, the line service life, the line load rate distribution ratio and the line loss rate distribution frequency ratio of the line to obtain a feeder line operation risk index.
5. The method of claim 1, wherein the distribution transformer data information includes distribution transformer age, distribution voltage deviation, three-phase imbalance fraction, and power factor qualification fraction; determining a distribution transformer risk index according to the distribution transformer data information includes:
and carrying out weighted summation on the service life of the distribution transformer, the distribution voltage deviation, the proportion of the three-phase unbalance condition and the proportion of the power factor qualified condition to obtain a risk index of the distribution transformer.
6. The method of claim 5, wherein the power factor eligibility ratio is calculated according to the following equation:
Figure FDA0002880978160000021
wherein ,
Figure FDA0002880978160000022
the number of the qualified active powers is represented,
Figure FDA0002880978160000023
number of qualified reactive powers, mq and muAll represent m-dimensional vectors composed of 0 and 1 elements, n represents the total number of power measurements, and PFDT-qRepresenting the power factor qualification rate.
7. The method of claim 1, wherein the user data information includes a user voltage deviation and a user voltage off-limit frequency percentage; the determining the user operation risk index according to the user data information comprises:
and carrying out weighted summation on the user voltage deviation and the user voltage out-of-limit frequency percentage to obtain a user operation risk index.
8. A transformer substation operation state risk assessment device is characterized by comprising:
the acquisition module is used for respectively acquiring transformer data information of a transformer in the transformer substation, feeder line data information in a distribution network, distribution transformer data information of a distribution transformer in the distribution network and user data information of users under the distribution transformer in the distribution network;
the first determining module is used for determining a risk index of the transformer according to the transformer data information;
the second determining module is used for determining a feeder operation risk index according to the feeder data information;
the third determining module is used for determining the risk index of the distribution transformer according to the data information of the distribution transformer;
the fourth determining module is used for determining the user operation risk index according to the user data information;
the risk evaluation module is used for carrying out risk evaluation on at least one of the transformer risk index, the feeder line operation risk index, the distribution transformer risk index and the user operation risk index;
and the alarm module is used for generating alarm information to prompt operating personnel if the evaluation result is abnormal.
9. A terminal device, comprising:
one or more processors;
storage means for storing one or more programs;
the one or more programs are executed by the one or more processors such that the one or more processors are operable to perform a substation operating state risk assessment method of any of claims 1-7.
10. A computer-readable storage medium, on which a computer program is stored, which, when being executed by a processor, carries out a method of risk assessment of an operating state of a substation according to any one of claims 1 to 7.
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