CN112700144B - 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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CN112700144B
CN112700144B CN202011635219.0A CN202011635219A CN112700144B CN 112700144 B CN112700144 B CN 112700144B CN 202011635219 A CN202011635219 A CN 202011635219A CN 112700144 B CN112700144 B CN 112700144B
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transformer
distribution
representing
line
risk index
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CN112700144A (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, device and equipment and a storage medium. The method comprises the following steps: respectively acquiring 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; determining a risk index of the transformer according to the transformer data information; determining a feeder operation risk index according to 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 a transformer risk index, a feeder line operation risk index, a distribution transformer risk index and a user operation risk index; if the evaluation result is abnormal, generating alarm information to prompt operators. By using 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 power distribution networks, in particular to a method, a device and equipment for evaluating the running state risk of a transformer substation and a storage medium.
Background
The distribution network consists of a distribution substation, a distribution line, a distribution transformer and electric equipment, is directly connected with a power generation and transmission system and a user, is a ring directly connected with the client in the power system, is responsible for directly supplying and distributing electric energy to the user, and has the characteristics of large equipment quantity, special operation mode and the like.
However, in the existing power distribution network, the state monitoring and evaluation of each pair of equipment is single, and the problems of imperfect fault processing and the like exist.
Disclosure of Invention
The embodiment of the invention provides a risk assessment method, a device, equipment and a storage medium for the running 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 risk assessment method for a running state of a substation, including:
respectively acquiring 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;
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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
if the evaluation result is abnormal, generating alarm information to prompt operators.
In a second aspect, an embodiment of the present invention further provides a risk assessment device for a running state of a substation, including:
the acquisition module is used for respectively acquiring the data information of the transformer in the transformer station, the data information of the feeder line in the distribution network, the data information of the distribution transformer in the distribution network and the user data information of the user 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 a risk index of the distribution transformer according to the distribution transformer data information;
a fourth determining module, configured to determine a user operation risk index according to the user data information;
the risk assessment module is used for carrying out risk assessment on at least one of the risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
and the alarm module is used for generating alarm information to prompt operators 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;
a 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 configured to implement the substation operation state risk assessment method according to any embodiment of the present 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, which when executed by a processor implements a substation operation state risk assessment method as provided in any embodiment of the present invention.
The embodiment of the invention provides a transformer substation running state risk assessment method, a device, equipment and a storage medium, which are used for respectively acquiring 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; 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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation; and finally, if the evaluation result is abnormal, generating alarm information to prompt an operator. By utilizing the technical scheme, risk assessment can be carried out on different equipment in the power distribution network in real time.
Drawings
Fig. 1 is a schematic flow chart of a risk assessment method for operating states of a transformer substation according to a first embodiment of the present invention;
Fig. 2 is an exemplary flowchart of a risk assessment method for operating states of a substation according to a second embodiment of the present invention;
FIG. 3 is a schematic diagram of a power relationship according to a second embodiment of the present invention;
fig. 4 is a schematic structural diagram of a risk assessment device for operating states 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 the invention is susceptible of embodiment in the drawings, it is to be understood that the invention may be embodied in various forms and should not be construed as limited to the embodiments set forth herein, but rather are provided to provide a more thorough and complete understanding of the present disclosure. It should be understood that the drawings and embodiments of the invention are for illustration purposes 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. Furthermore, 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 "including" and variations thereof as used herein are intended to be 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. Related definitions of other terms will be given in the description below.
It should be noted that the terms "first," "second," and the like herein are merely used for distinguishing between different devices, modules, or units and not for limiting the order or interdependence of the functions performed by such devices, modules, or units.
It should be noted that references to "one", "a plurality" and "a plurality" in this disclosure are intended to be illustrative rather than limiting, and those skilled in the art will appreciate that "one or more" is intended to be construed as "one or more" unless the context clearly indicates otherwise.
The names of messages or information interacted between the devices in the embodiments of the present invention are for illustrative purposes only and are not intended to limit the scope of such messages or information.
Example 1
Fig. 1 is a schematic flow chart of a risk assessment of operation state of a transformer substation, which is provided in an embodiment of the present invention, where the method may be 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 device of operation state of the transformer substation, where the device may be implemented by software and/or hardware and is generally integrated on a terminal device, and in this embodiment, the terminal device includes but is not limited to: a computer device.
As shown in fig. 1, a risk assessment for a running state of a transformer substation according to a first embodiment of the present invention includes the following steps:
s110, respectively acquiring data information of a transformer substation, feeder data information 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.
In this embodiment, the transformer data information of the transformer in the substation may include: the power transformation voltage deviation, the power transformation voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the operating oil temperature value and the service life of the power transformation transformer. The operating oil temperature value and the service life of the transformer can be obtained through a data acquisition and monitoring control system (Supervisory Control And Data Acquisition, SCADA), and the transformer voltage deviation, the transformer voltage out-of-limit frequency percentage and the frequency out-of-limit time ratio are required to be obtained through further calculation.
Specifically, the manner of calculating the transformation voltage deviation may be: and acquiring the operation 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. Wherein j=1, 2 … N, the calculation formula of the transformation voltage deviation of the ith transformer may be:
Figure BDA0002880978170000061
wherein ,UBTi-j Representing the operation voltage of the ith transformer in the transformer substation at the moment j, U BNi The rated voltage of the ith transformer in the transformer substation is shown.
Specifically, the mode of calculating the percentage of the out-of-limit frequency of the transformation voltage may be: and obtaining n transformer voltage measured values of an ith transformer of the transformer substation in unit time from the SCADA system, namely, representing the total measurement times as n, and selecting the obtained transformer voltage measured values of the jth measurement, wherein j=1, 2 … n. Setting the upper limit value of the out-of-limit transformer voltage to U H The lower limit value is set as U L And determining the power transformation voltage measured value exceeding the upper limit value or being lower than the lower limit value in the n power transformation voltage measured values as the out-of-limit power transformation voltage, and calculating the percentage of the frequency of occurrence of the out-of-limit power transformation voltage measured value to the total measured frequency, namely n, so as to obtain the out-of-limit frequency percentage of the power transformation voltage of the ith transformer. The specific calculation formula is as follows:
Figure BDA0002880978170000062
wherein ,nT-out The number of occurrences of the out-of-limit voltage measurement may be represented, and n represents the total number of measurements of the voltage. Wherein n is T-out The calculation formula of (2) is as follows:
Figure BDA0002880978170000063
wherein ,UTf (j) Can represent 0 or 1, U Tf (j) The calculation can be performed according to the classification function, and the calculation formula is as follows:
Figure BDA0002880978170000064
wherein ,Ure-Ti (j) Representing the measured value of the power transformation voltage obtained by the jth measurement, when U re-Ti (j) Greater than U H Then U is set Tf (j) Output is 1, when U re-Ti (j) Greater than or equal to U L And is less than or equal to U H Then U is set Tf (j) Output is 0, when U re-Ti (j) Less than U L Then U is set Tf (j) The output is-1.
Further, an upper frequency percentage of the transformation voltage and a lower frequency percentage of the transformation voltage may 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-up Indicating that the measured value of the measured transformer voltage is greater than U H The number of times of occurrence of the measured value of the transformer voltage is calculated as follows: />
Figure BDA0002880978170000072
Specifically, the formula for calculating the percentage of lower limit frequency of the transformation voltage is as follows:
Figure BDA0002880978170000073
wherein ,nout-low Indicating that the measured value of the measured transformation voltage is smaller than U L The number of times of occurrence of the measured value of the transformer voltage is calculated as follows: />
Figure BDA0002880978170000074
Specifically, the mode of calculating the frequency out-of-limit time ratio may be: acquisition of substation in unit time in SCADA system The n transformation frequency measured values of the i transformers represent that the total measurement frequency is n. And selecting a power transformation frequency measured value obtained by the jth measurement, wherein j=1, 2 … n. Will not be of [0.99f N ，1.01f N ]The variable frequency measurement value in the range is determined as an out-of-limit variable frequency value, wherein f N Is the rated frequency. The percentage of the frequency value occurrence times and the total measurement times n of the out-of-limit transformer is determined as the frequency out-of-limit time duty ratio of the ith transformer of the transformer substation, and the specific calculation formula is as follows:
Figure BDA0002880978170000075
wherein ,nfo Represents the number of times of occurrence of the out-of-limit transformation frequency value, f ti The frequency out-of-limit time duty of the i-th transformer of the power station is represented.
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 condition duty ratio, and a line loss rate distribution frequency duty 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 duty ratio and the line loss rate distribution frequency duty ratio of the line are required to be obtained through further calculation.
Specifically, the mode of calculating the distribution condition duty ratio of the line load rate may be: and acquiring the current of the ith line in the distribution network from the SCADA system, acquiring n current measurement values flowing through the ith line in unit time, namely, representing the total measurement times as n, and selecting the current measurement value obtained by the jth measurement, wherein j=1, 2 … n. The line load rate may include a light load rate, a heavy load rate, and an overload rate, among others.
Specifically, the calculation formula of the line load factor for the i-th line is:
Figure BDA0002880978170000081
wherein ,Ii (j) Representing the current measurement obtained by the jth measurement, I iN Indicating the rated current of the ith line in the distribution network. If R is calculated L Values of (2)In [0,20 ]]Within the interval, n is given when the line is lightly loaded l (j) The j-th number of the vector takes a value of 1, if R L The value of (2) is not in [0,20 ]]Within the interval n l (j) The j-th number of the number is 0; if R is L The value of the catalyst is 80%,100%]Within the interval, n is given when the line is overloaded h (j) The j-th numerical value of the vector takes 1, if R L The value of (2) is not in the range of 80%,100%]Within the interval n h (j) The j-th numerical value of the vector is 0; if R is L If the value of (2) is greater than 100%, then n will be the case if the line is overloaded o (j) The j-th number of the vector takes the value of 1, otherwise takes the value of 0.
Respectively through the formula
Figure BDA0002880978170000082
and />
Figure BDA0002880978170000083
Respectively calculate N l 、N h and No. wherein ,Nl The number of times that the ith line in the distribution network is lightly loaded is represented; n (N) h Representing the number of times that the ith line in the distribution network has line reload; n (N) o Indicating the number of times that the ith line in the distribution network has line overload.
The line load rate distribution condition duty ratio of the ith line in the distribution network can be calculated by the following formula:
Figure BDA0002880978170000084
wherein ,LRLi-l Representing the light load distribution condition duty ratio of the ith line in the distribution network, LR Li-h Representing the line overload distribution condition duty ratio of the ith line in the distribution network, LR Li-o And the line overload distribution condition of the ith line in the distribution network is represented.
Specifically, the mode of calculating the line loss rate distribution frequency duty ratio may be: n active power measurements of the current flowing through the ith line are taken from within the SCADA system within a set time threshold, i.e. representing a total number of measurements of n, the set time threshold may be, for example, 24 hours. The active power measurement obtained by the j-th measurement is selected, wherein j=1, 2 … n. Secondly, the line loss rate of the ith line can be calculated by the following formula:
Figure BDA0002880978170000091
wherein ,ΔPi (j) Representing the active power loss obtained by the jth measurement of the ith line, P i (j) The measured value of the active power obtained by the jth measurement of the ith line is represented, and delta represents the line loss rate of the jth measured value of the ith line. If delta exceeds the limit value delta limit Then n h The value is 1, otherwise, the value is 0, n h An n-dimensional vector representing the composition of elements 0, 1.
The line loss rate distribution frequency duty ratio may include a line loss rate distribution frequency duty ratio of a heavy loss line and a line loss rate distribution frequency duty ratio of a non-heavy loss line. The specific calculation formula is as follows:
Figure BDA0002880978170000092
wherein ,Lloss-i-h Representing the line loss rate distribution frequency duty ratio, L of a heavy loss line loss-i-n Representing the line loss rate distribution frequency duty ratio, N of a non-heavy loss line h Indicating that the line loss rate of the ith line exceeds a limit value delta limit The calculation formula is as follows:
Figure BDA0002880978170000093
/>
in this embodiment, the distribution transformer data information of the distribution transformer in the power distribution network may include: distribution transformer service life, distribution voltage deviation, three-phase imbalance condition duty ratio and power factor qualification condition duty ratio. The service life of the distribution transformer can be acquired through the SCADA system, and distribution voltage deviation, the three-phase imbalance condition duty ratio and the power factor qualification condition duty ratio are required to be 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. Wherein j=1, 2 … N, the calculation formula of the distribution voltage deviation is:
Figure BDA0002880978170000101
wherein ,UTi-j Representing the operation voltage of the ith distribution transformer in the distribution network at the moment j, U Ni Representing rated voltage of ith distribution transformer in distribution network, delta U Ti And (5) representing distribution voltage deviation of an ith distribution transformer in the distribution network.
Specifically, the way to calculate the three-phase imbalance condition duty ratio may be: n three-phase current measurement values of the ith distribution transformer within a set time threshold, that is, representing the total number of measurement n, are obtained from the SCADA system, and the set time threshold may be 24 hours, for example. The three-phase current measurement obtained by the jth measurement is selected, wherein j=1, 2 … n. Then, the three-phase imbalance of the i-th distribution transformer can be calculated by the following formula:
Figure BDA0002880978170000102
wherein ,Ii-max (j) Representing the maximum phase current in the three-phase current measurement value obtained by the ith distributor in the jth measurement, I i-min (j) Representing the minimum phase current in the three-phase current measurement value obtained by the ith distributor at the jth measurement. M is the value of ε in the [15%, 50%) interval and the time ratio is greater than 5% l (i) Take a value of 1, otherwise m l (i) Takes a value of 0, if epsilon is greater than or equal to 50% and the time ratio is greater than 20%, then m h (i) Take a value of 1, otherwise m h (i) The value is 0. The time ratio is understood to mean the duration value when ε is fixed to a value, which is the set timePercentage of the threshold.
Wherein, the three-phase imbalance condition duty ratio may include a slight three-phase imbalance duty ratio and a severe three-phase imbalance duty ratio, and the formula for calculating the three-phase imbalance condition duty ratio is:
Figure BDA0002880978170000111
wherein ,KDT-l Representing the slight three-phase imbalance duty cycle, K, of the ith distributor DT-h Representing the severe three-phase imbalance duty cycle, M, of the ith power distributor l The number of occurrences of the measurement value belonging to the slight three-phase current imbalance among the n measurements of the i-th distributor is represented by the calculation formula:
Figure BDA0002880978170000112
m l an n-dimensional vector representing the composition of elements 0 and 1; m is M h Representing the number of occurrences of a measurement value belonging to a serious three-phase current imbalance among n-time measurements of an i-th distributor, the calculation formula of which is +.>
Figure BDA0002880978170000113
m h An n-dimensional vector representing the composition of elements 0, 1.
Specifically, the manner of calculating the qualified power factor condition ratio may be: n power measurements of the i-th distribution transformer within a set time threshold, i.e. representing a total number of measurements of n, are obtained from within the SCADA system, the set time threshold may be, for example, 24 hours. The power measurement from the j-th measurement is selected, where j=1, 2 … n. It should be noted that the power measurement value may include an active power measurement value and a reactive power measurement value. Then, the active power factor and the reactive power factor of the i-th distribution transformer can be calculated by the following formula:
Figure BDA0002880978170000114
wherein ,Pi (j) Active power measurement value representing jth measurement of ith distribution transformer, Q i (j) Representing the jth measured reactive power measurement of the ith distribution transformer,
Figure BDA0002880978170000115
representing the active power factor of the jth measurement of the ith distribution transformer,/th>
Figure BDA0002880978170000121
The reactive power factor measured by the ith distribution transformer at the jth time is shown. If->
Figure BDA0002880978170000122
Greater than the specified value of the active power factor, m q (j) The value is 1, otherwise, the value is 0; if->
Figure BDA0002880978170000123
Greater than the reactive power factor specified value, then m u (j) The value is 1, otherwise, the value is 0.
The power factor qualified condition duty ratio may include an active power qualified condition duty ratio and a reactive power qualified condition duty ratio, and the specific calculation formula is as follows:
Figure BDA0002880978170000124
wherein ,PFDT-q Indicating the qualified active power condition of the ith distributor, PF DT-u Representing the duty ratio of reactive power of the ith distributor, M q The number of occurrences of the qualified active power measured value in the n active power measured values of the ith distributor is represented, and the calculation formula is as follows:
Figure BDA0002880978170000125
m q an n-dimensional vector representing the composition of elements 0 and 1; m is M u The number of times of occurrence of the qualified reactive power measured value in the n times of reactive power measured values of the ith distributor is represented, and the calculation formula is as follows:
Figure BDA0002880978170000126
m u an n-dimensional vector representing the composition of elements 0, 1 is represented.
In this embodiment, the user data information of the user under the distribution transformer in the power distribution network may include: user voltage deviation and user voltage percentage out of limit frequency. 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: acquiring data information of all users under the distribution transformer from the SCADA system, wherein the data information of the users can be
Figure BDA0002880978170000127
wherein ,Cij The j-th user under the i-th distribution transformer in the distribution network can be represented, i=1, 2,3 … m, j=1, 2,3 … n. And acquiring the user voltage of the jth user in the ith distribution transformer in the power distribution network and the rated voltage in the ith distribution transformer in the power distribution network from the SCADA system. The calculation formula of the distribution voltage deviation of the ith distribution transformer may be:
Figure BDA0002880978170000131
/>
wherein ,UCi-j User voltage representing the jth user in an ith distribution transformer in a distribution network, U CNi Indicating the rated voltage in the ith distribution transformer in the distribution network.
Specifically, the manner of calculating the percentage of the user voltage out-of-limit frequency may be: and obtaining n user voltage measurement values of the ith user in the power distribution network in unit time from the SCADA system, namely, representing the total measurement times as n, and selecting the user voltage measurement value obtained by the jth measurement, wherein j=1, 2 … n. Setting the upper limit value of the out-of-limit user voltage to U h The lower limit value is set as U l Determining a user voltage measurement exceeding an upper limit value or falling below a lower limit value of the n user voltage measurements as And calculating the percentage of the frequency of occurrence of the voltage measurement value of the out-of-limit user to the total measurement frequency n to obtain the user voltage out-of-limit frequency percentage of the ith user. The specific calculation formula is as follows:
Figure BDA0002880978170000132
wherein ,nC-out Representing the number of occurrences of out-of-limit user voltage measurements, n representing the total number of measurements of user voltage. Wherein n is C-out The calculation formula of (2) is as follows:
Figure BDA0002880978170000133
wherein ,Ucf (j) Can represent 0 or 1, U cf (j) The calculation can be performed according to the classification function, and the calculation formula is as follows:
Figure BDA0002880978170000134
wherein ,Ure-Ci (j) Representing the user voltage measurement value obtained by the jth measurement, when U re-Ci (j) Greater than U h Then U is set cf (j) Output is 1, when U re-Ci (j) Greater than or equal to U l And is less than or equal to U h Then U is set cf (j) Output is 0, when U re-Ci (j) Less than U l Then U is set cf (j) The output is-1.
Specifically, the formula for calculating the percentage of the upper limit frequency of the user voltage is as follows:
Figure BDA0002880978170000141
wherein ,nC-out-up Indicating that the measured value of the user voltage is greater than U h The number of occurrences of the user voltage measurement is calculated as:
Figure BDA0002880978170000142
specifically, the formula for calculating the percentage of lower limit frequency of the user is as follows:
Figure BDA0002880978170000143
wherein ,nC-out-low Indicating that the measured value of the measured user voltage is less than U l The number of occurrences of the user voltage measurement is calculated as:
Figure BDA0002880978170000144
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 in the substation in which the transformer fails.
Further, determining a risk index of the transformer according to the transformer data information includes: and carrying out weighted summation on the variable voltage deviation, the variable voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the operating oil temperature value and the service life of the variable transformer to obtain the risk index of the variable transformer.
Specifically, the risk index R of the transformer can be obtained by multiplying the power transformation voltage deviation, the power transformation voltage out-of-limit frequency percentage, the frequency out-of-limit time percentage, the operating oil temperature value and the weight value corresponding to the service life of the transformer BTi . The weight values corresponding to the above items can be obtained according to an index weight distribution table of the transformer. R is as described above BTi And the risk index of the transformer of the ith transformer in the transformer substation is represented.
Wherein, the risk index R of the transformer BTi The calculation formula of (2) is as follows:
R BTi ＝w bt1 ×Y BTi +w bt2 ×T BTemp-i +w bt3 ×δU BTi +w bt4 ×U Ti-out +w bt5 ×f ti
wherein ,YBTi Indicating the service life of the ith transformer in the transformer substation, w bt1 Represents Y BTi Weights, T BTemp-i Representing the operating oil temperature value, w, of an ith transformer in a transformer substation bt2 Representing T BTemp-i Weighting of δU BTi Representing the power transformation voltage deviation, w, of an ith transformer in a transformer substation bt3 Representing delta U BTi Weights of U T-out Representing the out-of-limit frequency percentage, w, of the transformation voltage of an ith transformer in a transformer substation bt4 Representing U Ti-out Weights f of (2) ti Representing the frequency out-of-limit time duty ratio, w, of an ith transformer in a transformer substation bt5 Represents f ti Is a weight of (2).
Wherein, the index weight distribution table of the transformer is shown as follows, and the table comprises w bt1 、w bt2 、w bt3 、w bt4 W bt5 Is a weight value of (a).
Figure BDA0002880978170000151
TABLE 1
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 in the distribution network failing.
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 input service life, the line load rate distribution condition duty ratio and the line loss rate distribution frequency duty ratio of the line to obtain a feeder operation risk index.
Specifically, the feeder operation risk index R can be obtained by multiplying the line length value, the line service life, the line load rate distribution condition duty ratio and the line loss rate distribution frequency duty ratio of the line by the corresponding weight values and then adding the multiplied values Li . The weight values corresponding to the above items can be obtained according to a line index weight distribution table. R is as described above Li And representing the feeder operation risk index of the ith line in the power distribution network.
Wherein, the feeder line operation risk index R of the ith line Li The calculation formula of (2) is as follows:
R Li ＝w l1 ×L Length-i +w l2 ×Y Li +w l3 ×LR Li +w l4 ×L Loss-i
wherein ,LLength-i Representing the length value, w, of the ith line in the distribution network l1 Represents L Length-i Weights of Y Li Representing the service life of the ith line in the power distribution network, w l2 Represents Y Li Weights, LR of Li Representing the distribution condition duty ratio, w of the i-th line in the power distribution network l3 Representation LR Li Weights, L Loss-i Representing the line loss rate distribution frequency duty ratio, w of the ith line in a power distribution network l4 Represents L Loss-i Is a weight of (2).
The line evaluation index weight distribution table is shown as follows, and w is included in the table l1 、w l2 、w l3 W l4 Is a weight value of (a).
Line evaluation index weight w l1 w l2 w l3 w l4
Weight value 0.1 0.15 0.45 0.3
TABLE 2
And S140, determining a distribution transformer risk index according to the distribution transformer data information.
In this embodiment, the risk index of the distribution transformer may be a risk index of a fault of the distribution transformer in the distribution network.
Further, 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, distribution voltage deviation, the three-phase imbalance condition duty ratio and the power factor qualification condition duty ratio to obtain the risk index of the distribution transformer.
Specifically, the distribution transformer risk index R can be obtained by multiplying the service life, distribution voltage deviation, three-phase imbalance condition duty ratio and power factor qualification condition duty ratio of the distribution transformer by corresponding weight values and then adding the multiplied weight values Ti . The weight values corresponding to the above items can be obtained according to a distribution transformer evaluation index weight table. R is as described above Ti And (5) representing the distribution transformer risk index of the ith distribution transformer in the distribution network.
Wherein, distribution transformer risk index R Ti The calculation formula of (2) is as follows:
R Ti ＝w t1 ×Y Ti +w t2 ×δU Ti +w t3 K DTi-l +w t4 ×PF DTi
wherein ,YTi Indicating the service life of the ith distribution transformer in the distribution network, w t1 Represents Y Ti Weighting of δU Ti Representing distribution voltage deviation, w, of i-th distribution transformer in distribution network t2 Representing delta U Ti Weights, K of (2) DTi-l Representing the three-phase unbalance condition duty ratio, w of an ith distribution transformer in a distribution network t3 Represent K DTi-l Weight, PF of DTi Representing the power factor qualification condition duty ratio, w of an ith distribution transformer in a distribution network t4 Representing PF DTi Is a weight of (2).
Wherein, the distribution transformer evaluation index weight distribution table is shown as follows, and the table comprises w t1 、w t2 、w t3 and wt4 Is a weight value of (a).
Figure BDA0002880978170000171
TABLE 3 Table 3
S150, determining a 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 failure of voltages of all users under a distribution transformer in the power distribution network.
Further, determining a 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.
Specifically, the user voltage deviation and the user voltage out-of-limit frequency percentage can be multiplied by the corresponding weight values and added to obtain the user operation risk index R Cij . The weight values corresponding to the above items can be obtained according to a user evaluation index weight table. R is as described above Cij And the user operation risk index of the jth user under the ith distribution transformer in the distribution network is represented.
Wherein the user operation risk index R of the jth user Cij The calculation formula of (2) is as follows:
R Cij ＝w c1 ×δU Ci +w c2 ×U Ci-out
wherein ,δUCi Representing the user voltage deviation, w, of the jth user c1 Representing delta U Ci Weights of U Ci-out Representing the percentage of user voltage out-of-limit frequency, w, of the jth user c2 Representing U Ci-out Is a weight of (2).
Wherein, the weight distribution table of the user evaluation index is shown in table 4, and comprises w c1 and wc2 Is a weight value of (a).
User evaluation index weight w c1 w c2
Weight value 0.6 0.4
TABLE 4 Table 4
And S160, performing risk assessment on at least one of the risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation.
In this embodiment, any one of the risk index of the transformer, the risk index of the feeder operation, the risk index of the distribution transformer, and the risk index of the user operation may be evaluated according to the evaluation index table. The evaluation index table is shown in table 5:
evaluation index R BTi R Li R Ti R Cij
Reference value 6 6 6 4
TABLE 5
Exemplary, when R is calculated BTi When the value is not equal to the reference value 6, R is represented by BTi Abnormal results; if R is Cij When the calculated value of (2) is not equal to the reference value 4, R is represented Cij The result is abnormal.
Further, if the risk index R of the transformer BTi And if the result is abnormal, the variable voltage deviation, the variable voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the running oil temperature value and the service life of the variable transformer, which are included in the variable transformer data information, can be further scored through a variable transformer parameter scoring table.
The transformer parameter scoring table is shown in table 6, and the corresponding expert scores can be obtained according to the specific numerical values of the parameters corresponding to table 6.
Figure BDA0002880978170000191
TABLE 6
Further, if the feeder operation risk index R Li And if the result is abnormal, the line length value, the line input service life, the line load rate distribution condition ratio and the line loss rate distribution frequency ratio of the line which are included in the feeder data information can be further scored through a feeder parameter scoring table.
The feeder parameter scoring table is shown in table 7, and the 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 R Ti And if the result is abnormal, the distribution transformer input service life, distribution voltage deviation, three-phase unbalance condition duty ratio and power factor qualification condition duty ratio contained in the distribution transformer data information can be further scored through a distribution transformer parameter scoring table.
The distribution transformer parameter scoring table is shown in table 8, and the 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 the risk index result R Cij For abnormality, the user voltage deviation and the user voltage out-of-limit frequency percentage included in the user data information may be further scored by a user voltage parameter scoring table.
The user voltage parameter scoring table is shown in table 9, and the corresponding expert scores can be obtained according to the specific numerical values of the parameters corresponding to table 9.
Figure BDA0002880978170000211
TABLE 9
S170, if the evaluation result is abnormal, generating alarm information to prompt an operator.
If any one of the evaluation results of the risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation is abnormal, alarm information can be generated to prompt operation scheduling personnel to provide a corresponding reference solution.
The first embodiment of the invention provides a risk assessment method for the running state of a transformer substation, which comprises the steps of firstly, respectively obtaining data information of a transformer substation, feeder data information 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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation; and finally, if the evaluation result is abnormal, generating alarm information to prompt an operator. By the method, the running states of the transformer, the distribution line, the distribution transformer and the user in the power distribution network can be analyzed in real time, and corresponding reference solutions are provided for operation scheduling personnel when a certain state of the power distribution network is abnormal.
Example two
Fig. 2 is a schematic flow chart of an example of a risk assessment method for operating states of a substation according to a second embodiment of the present invention, where the risk assessment method for operating states of a substation is described in an exemplary manner based on the first embodiment.
As shown in fig. 2, the data input part may include data collected in real time, data of power flow analysis, and manually input data. The real-time collection of data may include, among other things, collecting various data in the substation in real-time about the transformer, collecting various data in the distribution grid in real-time about the feeder, collecting various data in the distribution grid in real-time about the distribution transformer, and collecting various data in real-time about the customer voltage under the distribution transformer. The power flow analysis data can comprise data obtained by processing bad data acquired by partial grid splitting power flow, such as data acquisition missing of some monitoring points, and obvious abnormality of the data can be obtained by analyzing and processing abnormal data or missing data. The manual input data may include data on the operational age of the transformer, oil temperature, feeder length, etc.
After the data are obtained, risk assessment can be carried out on the transformer substation, the feeder line, the distribution transformer and the user respectively, namely, the system risk of the transformer substation is assessed, the operation risk of the feeder line is assessed, the equipment risk of the distribution transformer is assessed and the electricity consumption risk of the user is assessed.
Further, the risk index evaluated when evaluating the system risk may include the service life of the transformer, the deviation of the transformer voltage, and the frequency statistics index may include the percentage of frequency out of limit frequency of the transformer voltage and the percentage of time out of limit of frequency. And if the evaluation result is abnormal, an alarm in the preprocessing scheme can be executed to remind operation and maintenance personnel to check and overhaul.
Further, the risk index evaluated when evaluating the operation risk may include a current-carrying capacity, a line length, a line load rate, i.e. a line load rate distribution condition duty ratio, and a line loss distribution index, i.e. a line loss rate distribution frequency duty ratio of the line. And if the evaluation result is abnormal, load transfer in the preprocessing scheme can be executed.
Further, the risk indicators evaluated when evaluating the risk of the device may include defects, age of distribution transformer, distribution voltage deviation, distribution voltage, power factor, and frequency statistics. The frequency statistics may include a power factor qualification condition duty cycle and a three-phase imbalance condition duty cycle, among others. And if the evaluation result is abnormal, executing load transfer in the preprocessing scheme.
Further, the risk indicator evaluated when evaluating the electricity risk may include a user voltage deviation, a statistics of the frequency of voltage crossing, that is, a percentage of frequency of voltage crossing of the user. If the evaluation result is abnormal, the voltage or frequency can be adjusted by the voltage or frequency adjusting device in the preprocessing scheme.
Fig. 3 is a schematic diagram of a power relationship according to a second embodiment of the present invention. As shown in fig. 3, the transformer substation is connected to a distribution line, to which a plurality of distribution transformers may be connected, and under each distribution transformer, a plurality of users may be supplied with power.
According to the transformer substation running state risk assessment method provided by the embodiment of the invention, through acquiring data in the power distribution network detection equipment and manually inputting some data of related equipment, corresponding consideration indexes are set according to different equipment, various factors affecting the normal running of the equipment are considered, the equipment risk state is comprehensively assessed, and when the comprehensive assessment risk index of the related equipment is lower than a reference value, a corresponding solution is provided for dispatch operation personnel to refer to.
Example III
Fig. 4 is a schematic structural diagram of a risk assessment device for operating states of a substation according to a third embodiment of the present invention, where the device may be suitable for assessing states of different devices and objects in a power distribution network, and the device may be implemented by software and/or hardware and is generally integrated on a terminal device.
As shown in fig. 4, the apparatus includes: the acquisition module 410, the first determination module 420, the second determination module 430, the third determination module 440, the fourth determination module 450, the risk assessment module 460, and the alarm module 470.
The acquiring module 410 is configured to acquire transformer data information of a transformer in a 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 risk index of the distribution transformer 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 risk index of the transformer, the risk index of the feeder operation, the risk index of the distribution transformer, and the risk index of the user operation;
and the alarm module 470 is configured to generate alarm information to prompt an operator if the evaluation result is abnormal.
In the embodiment, the device firstly respectively acquires the data information of a transformer in a transformer substation, the data information of a feeder line in a distribution network, the data information of a distribution transformer in the distribution network and the user data information of a user under the distribution transformer in the distribution network through an acquisition module; 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 determining module; determining a risk index of the distribution transformer according to the distribution transformer data information through a third determining module; determining a user operation risk index according to the user data information through a fourth determining module; then, performing risk assessment on at least one of the risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation through a risk assessment module; and finally, generating alarm information to prompt an operator if the evaluation result is abnormal through an alarm module.
The embodiment provides a transformer substation operation state risk assessment device, which can analyze the operation states of a transformer substation, 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 a state of a certain place of the power distribution network is abnormal.
Further, the transformer data information in the obtaining module 410 includes a transformer voltage deviation, a transformer 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 percentage of the frequency of the transformer voltage out of limit, the frequency out of limit time, 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 for calculating a transformation voltage deviation according to the following formula:
Figure BDA0002880978170000251
wherein ,UBTi-j Representing the operation voltage of the ith transformer in the transformer substation at the moment j, U BNi The rated voltage of the ith transformer in the transformer substation is shown.
Further, the feeder data information in the acquisition module 410 includes a line length value, a line service life, a line load rate distribution condition duty ratio, and a line loss rate distribution frequency duty 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 condition duty ratio, and the line loss rate distribution frequency duty ratio of the line, so as to obtain a feeder operation risk index.
Further, the electrical transformer data information in the acquisition module 410 includes the service life of the distribution transformer, distribution voltage deviation, three-phase imbalance condition duty ratio and power factor qualification condition duty ratio; the third determining module 440 is specifically configured to weight and sum the service life of the distribution transformer, the distribution voltage deviation, the three-phase imbalance condition duty ratio, and the power factor qualification condition duty ratio, 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 qualified condition duty ratio calculating unit, where the power factor qualified condition duty ratio calculating unit is configured to calculate a power factor qualified condition duty ratio according to the following formula:
Figure BDA0002880978170000261
wherein ,
Figure BDA0002880978170000262
representing the number of qualified active power, +.>
Figure BDA0002880978170000263
Representing the number of qualified reactive power, m q and mu All represent m-dimensional vectors consisting of 0, 1 elements, n represents the total number of power measurements, PF DT-q Representing the power factor qualification condition duty cycle.
Further, the user data information in the acquisition module 410 includes a user voltage deviation and a 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 percentage of the user voltage out-of-limit frequency 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 the corresponding functional modules and beneficial effects of the execution method.
Example IV
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 a fourth embodiment of the present invention includes: one or more processors 51 and storage 52; the number of processors 51 in the terminal device may be one or more, one processor 51 being taken as an example in fig. 5; the storage device 52 is used for storing one or more programs; the one or more programs are executed by the one or more processors 51, such that the one or more processors 51 implement the substation operation 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 means 52, the input means 53 and the output means 54 in the terminal device may be connected by a bus or by other means, in fig. 5 by way of example.
The storage device 52 in the terminal device is used as a computer readable storage medium, and may be used to store one or more programs, which may be a software program, a computer executable program, and a module, where the program instructions/modules correspond to the substation operation state risk assessment method provided by 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 determining module 420, a second determining module 430, a third determining module 440, a fourth determining module 440, and so on). The processor 51 executes various functional applications of the terminal device and data processing by running software programs, instructions and modules stored in the storage 52, i.e. implements the substation operation state risk assessment method in the above-described method embodiment.
Storage device 52 may include a storage program area and a storage data area, wherein the storage program area may store an operating system, at least one application program required for functionality; the storage data area may store data created according to the use of the terminal device, etc. In addition, 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, storage 52 may further include memory located remotely from processor 51, which may be connected to the device via 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 means 53 may be used for receiving input numeric or character information and for generating 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 one or more programs included in the above-described 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 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;
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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
if the evaluation result is abnormal, generating alarm information to prompt operators.
Example five
A fifth embodiment of the present invention provides a computer-readable storage medium having stored thereon a computer program for executing a substation operation state risk assessment method when executed by a processor, the method comprising:
respectively acquiring 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;
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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
if the evaluation result is abnormal, generating alarm information to prompt operators.
Optionally, the program may be further configured to perform the substation operation state risk assessment method provided by any embodiment of the present invention when executed by the processor.
The computer storage media of embodiments of the invention may take the form of 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. The computer readable storage medium can be, for example, but not limited to, an electronic, magnetic, optical, electromagnetic, infrared, or semiconductor system, apparatus, or device, or a combination of any 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 (Random Access Memory, RAM), a Read-Only Memory (ROM), an erasable programmable Read-Only Memory (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.
The computer readable signal medium may include a propagated data signal with computer readable program code embodied therein, either in baseband or as part of a carrier wave. Such a propagated data signal may take many forms, including, but not limited to: electromagnetic signals, optical signals, or any suitable combination of the preceding. 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), and the like, or any suitable combination of the foregoing.
Computer program code for carrying out operations of the present invention may be written in one or more programming languages, including an object oriented programming language such as Java, smalltalk, C ++ 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 kind of network, including a Local Area Network (LAN) or a Wide Area Network (WAN), or may be connected to an external computer (for example, through the Internet using an Internet service provider).
Note that the above is only a preferred embodiment of the present invention and the technical principle applied. 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, while the invention has been described in connection with the above embodiments, the invention is not limited to the embodiments, but may be embodied in many other equivalent forms without departing from the spirit or scope of the invention, which is set forth in the following claims.

Claims (9)

1. A method for risk assessment of operating conditions of a substation, comprising:
respectively acquiring 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;
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 risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
if the evaluation result is abnormal, generating alarm information to prompt an operator;
the feeder line data information comprises a line length value, a line input service life, a line load rate distribution situation duty ratio and a line loss rate distribution frequency duty ratio of the line; the determining the feeder operation risk index according to the feeder data information comprises the following steps:
carrying out weighted summation on the line length value, the line input service life, the line load rate distribution condition duty ratio and the line loss rate distribution frequency duty ratio of the line to obtain a feeder operation risk index;
wherein, the risk index R of the transformer BTi The calculation formula of (2) is as follows:
R BTi ＝w bt1 ×Y BTi +w bt2 ×T BTemp-i +w bt3 ×δU BTi +w bt4 ×U Ti-out +w bt5 ×f ti
wherein ,YBTi Indicating the service life of the ith transformer in the transformer substation, w bt1 Represents Y BTi Weights, T BTemp-i Representing the operating oil temperature value, w, of an ith transformer in a transformer substation bt2 Representing T BTemp-i Weighting of δU BTi Representing the power transformation voltage deviation, w, of an ith transformer in a transformer substation bt3 Representing delta U BTi Weights of U Ti-out Representing the out-of-limit frequency percentage, w, of the transformation voltage of an ith transformer in a transformer substation bt4 Representing U Ti-out Weights f of (2) ti Representing the frequency out-of-limit time duty ratio, w, of an ith transformer in a transformer substation bt5 Represents f ti Weight of (2)Weighing;
wherein, the feeder line operation risk index R of the ith line Li The calculation formula of (2) is as follows:
R Li ＝w l1 ×L Length-i +w l2 ×Y Li +w l3 ×LR Li +w l4 ×L Loss-i
wherein ,LLength-i Representing the length value, w, of the ith line in the distribution network l1 Represents L Length-i Weights of Y Li Representing the service life of the ith line in the power distribution network, w l2 Represents Y Li Weights, LR of Li Representing the distribution condition duty ratio, w of the i-th line in the power distribution network l3 Representation LR Li Weights, L Loss-i Representing the line loss rate distribution frequency duty ratio, w of the ith line in a power distribution network l4 Represents L Loss-i Weights of (2);
wherein, distribution transformer risk index R Ti The calculation formula of (2) is as follows:
R Ti ＝w t1 ×Y Ti +w t2 ×δU Ti +w t3 K DTi-l +w t4 ×PF DTi
wherein ,YTi Indicating the service life of the ith distribution transformer in the distribution network, w t1 Represents Y Ti Weighting of δU Ti Representing distribution voltage deviation, w, of i-th distribution transformer in distribution network t2 Representing delta U Ti Weights, K of (2) DTi-l Representing the three-phase unbalance condition duty ratio, w of an ith distribution transformer in a distribution network t3 Represent K DTi-l Weight, PF of DTi Representing the power factor qualification condition duty ratio, w of an ith distribution transformer in a distribution network t4 Representing PF DTi Is a weight of (2).
2. The method of claim 1, wherein the transformer data information includes a transformer voltage deviation, a transformer voltage percentage off-limit frequency, a frequency off-limit time duty cycle, an operating oil temperature value, and a transformer life; the determining the risk index of the transformer according to the transformer data information comprises the following steps:
and carrying out weighted summation on the variable voltage deviation, the variable voltage out-of-limit frequency percentage, the frequency out-of-limit time ratio, the operating oil temperature value and the service life of the variable transformer to obtain the risk index of the variable transformer.
3. The method of claim 2, wherein the variable voltage deviation is calculated according to the formula:
Figure QLYQS_1
wherein ,UBTi-j Representing the operation voltage of the ith transformer in the transformer substation at the moment j, U BNi The rated voltage of the ith transformer in the transformer substation is shown.
4. The method of claim 1, wherein the distribution transformer data information includes distribution transformer age, distribution voltage deviation, three-phase imbalance condition duty cycle, and power factor qualification condition duty cycle; the determining a distribution transformer risk index according to the distribution transformer data information comprises the following steps:
And carrying out weighted summation on the service life of the distribution transformer, distribution voltage deviation, the three-phase imbalance condition duty ratio and the power factor qualification condition duty ratio to obtain the risk index of the distribution transformer.
5. The method of claim 4, wherein the power factor qualification rate is calculated according to the formula:
Figure QLYQS_2
wherein ,
Figure QLYQS_3
representing the number of qualified active power, +.>
Figure QLYQS_4
Representing the number of qualified reactive power, m q and mu All represent m-dimensional vectors consisting of 0, 1 elements, n represents the total number of power measurements, PF DT-q Representing the power factor qualification condition duty cycle.
6. The method of claim 1, wherein the user data information includes user voltage deviation and user voltage percentage out of limit frequency; the determining the user operation risk index according to the user data information comprises the following steps:
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.
7. A substation operation state risk assessment device, characterized by comprising:
the acquisition module is used for respectively acquiring the data information of the transformer in the transformer station, the data information of the feeder line in the distribution network, the data information of the distribution transformer in the distribution network and the user data information of the user 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 a risk index of the distribution transformer according to the distribution transformer data information;
a fourth determining module, configured to determine a user operation risk index according to the user data information;
the risk assessment module is used for carrying out risk assessment on at least one of the risk index of the transformer, the risk index of the feeder line operation, the risk index of the distribution transformer and the risk index of the user operation;
the alarm module is used for generating alarm information to prompt an operator if the evaluation result is abnormal;
the feeder line data information comprises a line length value, a line input service life, a line load rate distribution situation duty ratio and a line loss rate distribution frequency duty ratio of the line;
the second determining module is further configured to perform weighted summation on the line length value, the service life of the line, the distribution condition duty ratio of the line load rate, and the distribution frequency duty ratio of the line loss rate of the line, so as to obtain a feeder operation risk index;
Wherein, the risk index R of the transformer BTi The calculation formula of (2) is as follows:
R BTi ＝w bt1 ×Y BTi +w bt2 ×T BTemp-i +w bt3 ×δU BTi +w bt4 ×U Ti-out +w bt5 ×f ti
wherein ,YBTi Indicating the service life of the ith transformer in the transformer substation, w bt1 Represents Y BTi Weights, T BTemp-i Representing the operating oil temperature value, w, of an ith transformer in a transformer substation bt2 Representing T BTemp-i Weighting of δU BTi Representing the power transformation voltage deviation, w, of an ith transformer in a transformer substation bt3 Representing delta U BTi Weights of U Ti-out Representing the out-of-limit frequency percentage, w, of the transformation voltage of an ith transformer in a transformer substation bt4 Representing U Ti-out Weights f of (2) ti Representing the frequency out-of-limit time duty ratio, w, of an ith transformer in a transformer substation bt5 Represents f ti Weights of (2);
wherein, the feeder line operation risk index R of the ith line Li The calculation formula of (2) is as follows:
R Li ＝w l1 ×L Length-i +w l2 ×Y Li +w l3 ×LR Li +w l4 ×L Loss-i
wherein ,LLength-i Representing the length value, w, of the ith line in the distribution network l1 Represents L Length-i Weights of Y Li Representing the ith line in a power distribution networkThe service life of the line of the road, w l2 Represents Y Li Weights, LR of Li Representing the distribution condition duty ratio, w of the i-th line in the power distribution network l3 Representation LR Li Weights, L Loss-i Representing the line loss rate distribution frequency duty ratio, w of the ith line in a power distribution network l4 Represents L Loss-i Weights of (2);
wherein, distribution transformer risk index R Ti The calculation formula of (2) is as follows:
R Ti ＝w t1 ×Y Ti +w t2 ×δU Ti +w t3 K DTi-l +w t4 ×PF DTi
wherein ,YTi Indicating the service life of the ith distribution transformer in the distribution network, w t1 Represents Y Ti Weighting of δU Ti Representing distribution voltage deviation, w, of i-th distribution transformer in distribution network t2 Representing delta U Ti Weights, K of (2) DTi-l Representing the three-phase unbalance condition duty ratio, w of an ith distribution transformer in a distribution network t3 Represent K DTi-l Weight, PF of DTi Representing the power factor qualification condition duty ratio, w of an ith distribution transformer in a distribution network t4 Representing PF DTi Is a weight of (2).
8. A terminal device, comprising:
one or more processors;
a 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 configured to perform a substation operation state risk assessment method of any of claims 1-6.
9. A computer readable storage medium, on which a computer program is stored, characterized in that the program, when being executed by a processor, implements a substation operation state risk assessment method according to any one of claims 1-6.
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