CN113532693A - Based on two SF6Meter-monitored power equipment temperature rise testing method - Google Patents
Based on two SF6Meter-monitored power equipment temperature rise testing method Download PDFInfo
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Abstract
The invention provides a method based on double SF6The temperature rise test method of the power equipment monitored by the meter comprises the following steps of S1 detecting SF to be detected6The A, B, C three phases of the electrical equipment are respectively provided with two SF6Pressure gauge, said two blocks SF6The pressure gauges are respectively a pressure gauge A with temperature compensation and a pressure gauge B without temperature compensation; s2 calculating A, B, C phases of SF by using pressure value p and temperature value t of pressure gauge A6Gas density value ρA、ρB、ρC(ii) a S3 using the current pressure value displayed by the pressure gauge B of A, B, C phase and SF combined with the step S26The gas density value calculates the current temperature value t of three phases of the equipment A, B, CVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C(ii) a S4 determines A, B, C the state of the three phases. The invention can find the heating defect of the equipment in time and accurately predict the real-time temperature of the equipment with the heating defect so as to reasonably and timely arrange the power failure elimination work.
Description
Technical Field
The invention relates to the technical field of power equipment safe operation monitoring, in particular to a double-SF-based monitoring system6A method for testing temperature rise of power equipment monitored by a meter.
Background
With the rapid development of power systems and the increasing voltage class, SF6Electrical equipment is increasingly being used by virtue of its excellent insulating and arc extinguishing properties.
SF6Operation of electrical equipment and deterioration of insulationHeat is generated later, and a large number of field tests and operation experiences show that temperature rise change and SF caused by heat effect6The health condition of the electrical equipment is closely related, is an important characterization of the equipment state, and has higher sensitivity to poor contact of the contact and initial insulation degradation defect. The thermal effect is utilized to detect the state of the equipment, a non-contact infrared thermal imaging method or various contact temperature sensor methods are generally adopted, the internal temperature is indirectly measured by detecting the temperature distribution of the outer surface of the equipment, and the internal temperature field distribution of the equipment and the equipment state information reflected by the internal temperature field distribution cannot be accurately mastered.
In view of this situation, it is necessary to develop a method capable of accurately grasping SF6A method for testing the internal temperature of an electrical device.
Disclosure of Invention
The technical problem to be solved by the present invention is to overcome the above-mentioned deficiencies of the prior art and to provide a dual SF-based solution6The method for testing the temperature rise of the power equipment monitored by the meter can find the heating defect of the equipment in time and accurately predict the real-time temperature of the equipment with the heating defect so as to reasonably and timely arrange the power failure elimination work. The technical scheme adopted by the invention for solving the technical problems is as follows: which comprises the following steps of,
s1 in the detection of SF6The A, B, C three phases of the electrical equipment are respectively provided with two SF6Pressure gauge, said two blocks SF6The pressure gauges are respectively a pressure gauge A with temperature compensation and a pressure gauge B without temperature compensation;
s2 calculating A, B, C phases of SF by using pressure value p and temperature value t of pressure gauge A6Gas density value ρA、ρB、ρC；
S3 using the current pressure value displayed by the pressure gauge B of A, B, C phase and SF combined with the step S26The gas density value calculates the current temperature value t of three phases of the equipment A, B, CVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C；
S4 determines A, B, C the state of the three phases.
Further, in step S1After the installation is completed, the SF to be detected is confirmed6Presence or absence of SF in electrical equipment6Gas leakage, if the indication of the pressure gauge A is unchanged, indicating that SF does not occur6Gas leakage, if the indication of the pressure gauge A changes, indicating the occurrence of SF6And if the gas leaks, checking the leakage point and repairing.
Further, in step S2, the pressure value P of the pressure gauge a and the compensated temperature value t corresponding thereto are substituted into the formula (1) to obtain SF6A gas density ρ;
p＝0.57×10-4ρt(1+B)-ρ2A (1)；
wherein, P is a pressure value, Mpa; t is a temperature value, K; rho is density, kg/m3。
Further, the coefficient A is obtained according to the formula (2), and the coefficient B is obtained according to the formula (3);
A＝0.75×10-4(1-0.727×10-3ρ) (2)；
B＝2.51×10-3ρ(1-0.846×10-3ρ) (3)；
rho is density, kg/m3。
Further, the compensated temperature value t of the pressure gauge a is 20+ 273.5-293.5K;
respectively measuring the pressure value P of a pressure gauge A in A, B, C phasesA、PBAnd PcSubstituting the compensated temperature value t into the formula (1) to obtain the SF corresponding to A, B, C6Gas density ρA、ρBAnd ρC；ρASF corresponding to A6Gas density, kg/m3，ρBIs SF corresponding to B6Gas density, kg/m3，ρCIs SF corresponding to C6Gas density, kg/m3。
Further, in step S3, the current pressure value P of the pressure gauge B is utilizedVertical and horizontal A、PVertical and horizontal B、PVertical and horizontal CAnd SF calculated at S26Gas density value ρA、ρB、ρCRespectively calculate outCurrent temperature t of prepared A, B, C three-phase equipmentVertical and horizontal A、tVertical and horizontal B、twC。
Further, in step S3, the pressure gauge B of phase a displays the current pressure value PVertical and horizontal AAnd SF obtained in step S26Gas density value ρASubstituting the formula (1) to calculate the current temperature t of the A-phase equipmentVertical and horizontal A(ii) a Displaying the current pressure value P of the pressure gauge B of the phase BVertical and horizontal BAnd SF obtained in step S26Gas density value ρBSubstituting the formula (1) to calculate the current temperature t of the B-phase equipmentVertical and horizontal B(ii) a Displaying the current pressure value P of the pressure gauge B of the C phaseVertical and horizontal CAnd SF obtained in step S26Gas density value ρCSubstituting the formula (1) to calculate the current temperature t of the C-phase equipmentVertical and horizontal C。
Further, in step S4, t is selectedVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal CThe lowest temperature of the two phases is the standard phase, and the other two phases are the phases to be compared.
Further, the judgment criterion of step S4 is to calculate the temperature difference between the phase to be compared and the standard phase, and determine the health status of the phase to be compared according to the temperature difference between the phase to be compared and the standard phase;
when the temperature difference is between 0K and 5K, the phase to be compared is in a normal state, and the equipment is normal and can continuously run at the moment;
when the temperature difference is 5K-10K, the phase to be compared is in an attention state, the inspection cycle of the phase to be compared is shortened, and monitoring is enhanced;
when the temperature difference is more than 10K, the phase to be compared is in an abnormal state, and at the moment, the monitoring is strengthened and the hidden danger processing work is timely carried out by combining with the power failure plan.
Further, the method also comprises a step S5, wherein the step S5 is to predict the temperature rise of the phase to be compared when the phase is in an abnormal state, and the prediction model is an ARIMA model based on time series analysis; the temperature detection data is a sequence which does not meet the stability condition, the difference order d in an ARIMA (p, d, q) model is determined after a plurality of differences, parameters p and q are determined according to an autocorrelation function ACF and a partial autocorrelation function PACF, and the specification that the attenuation after p order tends to zero and the attenuation after q order tends to zero in the ARIMA model order selection principle is combined.
The invention has the beneficial effects that:
the invention is realized by adding in SF6Two SF are respectively arranged on three phases of the electrical equipment A, B, C6Pressure gauge for effective detection of SF6The temperature rise condition of the electrical equipment is mastered, the temperature field distribution in the equipment and the equipment state information reflected by the temperature field distribution are mastered, and the real-time temperature of the equipment with heating defects is predicted, so that a power failure elimination plan is timely and reasonably arranged, the safety of the equipment and a power grid is ensured, and the power supply load loss is reduced to the maximum extent.
Drawings
FIG. 1 is a graph of pressure versus temperature without temperature compensation;
FIG. 2 is a schematic structural diagram of a pressure measurement instrument with temperature compensation function;
FIG. 3 is a graph of pressure versus temperature for temperature compensation;
FIG. 4 is a graph of measured temperature rise and predicted temperature rise for an embodiment of the present invention.
In fig. 2, 1 is a pressure detecting spring tube; 2 temperature compensation thermal bimetallic strip; 3 machine core and sector gear; 4 pointers.
Detailed Description
The present invention is further described in detail below with reference to examples, but the scope of the present invention is not limited thereto, and the scope of the invention is set forth in the claims.
The technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. The following description of at least one exemplary embodiment is merely illustrative in nature and is in no way intended to limit the application, its application, or uses. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of example embodiments according to the present application. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of stated features, steps, operations, devices, components, and/or combinations thereof, unless the context clearly indicates otherwise.
The relative arrangement of the components and steps, the numerical expressions, and numerical values set forth in these embodiments do not limit the scope of the present application unless specifically stated otherwise. Meanwhile, it should be understood that the sizes of the respective portions shown in the drawings are not drawn in an actual proportional relationship for the convenience of description. Techniques, methods, and apparatus known to those of ordinary skill in the relevant art may not be discussed in detail but are intended to be part of the specification where appropriate. In all examples shown and discussed herein, any particular value should be construed as merely illustrative, and not limiting. Thus, other examples of the exemplary embodiments may have different values. It should be noted that: like reference numbers and letters refer to like items in the following figures, and thus, once an item is defined in one figure, further discussion thereof is not required in subsequent figures.
The theoretical basis of the invention is as follows: from three state parameter relationships (p ═ ρ Rt, where R is a constant) of gas pressure-density-temperature (p- ρ -t), it can be seen that: when the ambient temperature is constant, the density changes in proportion to the change in pressure; when the ambient temperature changes and the density does not change, the pressure changes with the change of the temperature, as shown in fig. 1. According to SF6Physical characteristics of the gas, SF at a certain temperature in a closed container6The gas density may actually be represented by a pressure value. To maintain SF in a closed container6The gas pressure is not changed, and only the changed temperature is compensated. Currently SF6SF for electrical equipment6Gas (es)The pressure gauge is a pressure measurement instrument with a temperature compensation function, and is shown in figure 2. SF to be detected as described in the present invention6Two SF are respectively arranged on three phases of the circuit breaker A, B, C6A pressure gauge, wherein the pressure gauge A with temperature compensation is a pressure measurement instrument with temperature compensation function shown in figure 2 and is used for monitoring SF6Whether there is a leak of gas. It measures SF by means of a measuring element6The pressure of the gas, and then the SF is fed through a temperature compensation element of the pressure gauge6Converting the gas pressure into a pressure measurement at 20 deg.C, using the pressure measurement (P)20Value) represents SF6Gas density value. When SF6When the density of the gas is constant, P20The values do not change with temperature, see fig. 3.
The invention provides a method based on double SF6The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: which comprises the following steps of,
s1 in the detection of SF6The A, B, C three phases of the electrical equipment are respectively provided with two SF6Pressure gauge, said two blocks SF6The pressure gauges are respectively a pressure gauge A with temperature compensation and a pressure gauge B without temperature compensation; the whole electrical equipment is provided with six SF blocks6And a pressure gauge. Three pressure gauges A with temperature compensation and three pressure gauges B without temperature compensation are arranged in the pressure gauge.
In step S1, SF6Confirming the SF to be detected after the pressure gauge is installed6Presence or absence of SF in electrical equipment6Gas leakage in ensuring SF6Temperature rise detection and prediction can be carried out by using a subsequent method on the premise of no gas leakage; confirming whether SF exists in equipment to be detected or not by utilizing pressure change of pressure gauge A6Gas leakage, if the indication of the pressure gauge A is unchanged, indicating that SF does not occur6Gas leakage, if the indication of the pressure gauge A changes, indicating the occurrence of SF6If gas leaks, the leakage point is checked and repaired, and if gas leaks, the temperature rise test method cannot be used, and only the leakage point is checked and the repair is finished, so that SF is ensured6When the gas is not leaked, the subsequent steps are carried out. Pressure gaugeA is used for monitoring the internal SF of the equipment in real time6Whether gas leaks or not, and a pressure gauge B is used for monitoring the SF inside the equipment in real time6The pressure of the gas.
S2 calculating A, B, C phases of SF by using pressure value p and temperature value t of pressure gauge A6Gas density value ρA、ρB、ρC。
In S2, A, B, C phases of SF are calculated respectively by using the pressure value p and the temperature value t (20 ℃) of the pressure gauge A6Gas density value ρA、ρB、ρC，SF6When gas is not leaked ρA、ρB、ρCIs a constant value.
Specifically, in step S2, the pressure value P of the pressure gauge a and the compensated temperature value t corresponding thereto are substituted into equation (1) to obtain SF6A gas density ρ;
p＝0.57×10-4ρt(1+B)-ρ2A (1)；
wherein, P is a pressure value, Mpa; t is a temperature value, K; rho is density, kg/m3。
The coefficient A is obtained according to a formula (2), and the coefficient B is obtained according to a formula (3);
A＝0.75×10-4(1-0.727×10-3ρ) (2)；
B＝2.51×10-3ρ(1-0.846×10-3ρ) (3)；
rho is density, kg/m3。
Specifically, the compensation temperature of the pressure gauge a is 20 ℃, and the compensated temperature value t of the pressure gauge a is 20+ 273.5-293.5K;
respectively measuring the pressure value P of a pressure gauge A in A, B, C phasesA、PBAnd PcSubstituting the compensated temperature value t into the formula (1) to obtain the SF corresponding to A, B, C6Gas density ρA、ρBAnd ρC；ρASF corresponding to A6Gas density, kg/m3，ρBIs SF corresponding to B6Gas density, kg/m3，ρCIs C corresponds toSF of6Gas density, kg/m3。
S3 using the current pressure value displayed by the pressure gauge B of A, B, C phase and SF combined with the step S26The gas density value calculates the current temperature value t of three phases of the equipment A, B, CVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C。
In step S3, the current pressure value P of the pressure gauge B is usedVertical and horizontal A、PVertical and horizontal B、PVertical and horizontal CAnd SF calculated at S26Gas density value ρA、ρB、ρCRespectively calculating current temperature values t of A, B, C three-phase equipment of the equipmentVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C。
Displaying the current pressure value P of the pressure gauge BVertical and horizontalAnd SF obtained in step (3)6Substituting the gas density value rho into the formula (1) to calculate the current temperature tVertical and horizontalAnd at the current temperature tVertical and horizontalCharacterization of SF6The actual temperature inside the electrical device. In step S3, the current pressure value P displayed by the pressure gauge B of phase AVertical and horizontal AAnd SF obtained in step S26Gas density value ρASubstituting the formula (1) to calculate the current temperature t of the A-phase equipmentVertical and horizontal A(ii) a Displaying the current pressure value P of the pressure gauge B of the phase BVertical and horizontal BAnd SF obtained in step S26Gas density value ρBSubstituting the formula (1) to calculate the current temperature t of the B-phase equipmentVertical and horizontal B(ii) a Displaying the current pressure value P of the pressure gauge B of the C phaseVertical and horizontal CAnd SF obtained in step S26Gas density value ρCSubstituting the formula (1) to calculate the current temperature t of the C-phase equipmentVertical and horizontal C。
S4 determines A, B, C the state of the three phases.
In step S4, t is selected based on the device state determination method of interplanetary evidencesVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal CThe lowest temperature of the two phases is the standard phase, and the other two phases are the phases to be compared.
T is selected because the probability of A, B, C three-phase simultaneous overheating fault is basically zero in the operation process of the equipmentVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal CThe smallest of these is the standard phase and the other two are the phases to be compared.
And determining whether the phase to be compared is in a normal state, an attention state or an abnormal state by calculating the temperature difference value of the phase to be compared and the standard phase, and further differentiating and maintaining equipment in a targeted operation mode.
For SF in abnormal state6The real-time temperature of the electrical equipment is predicted so as to accurately and timely arrange power failure for defect elimination work and ensure that the loss of power supply load is reduced to the maximum extent.
Specifically, in consideration of the difference between the temperature rise caused by the high load when the device operates and the actual temperature rise caused by the difference between the device structure, the installation position, and the illumination, the determination criterion of step S4 is to calculate the temperature difference between the phase to be compared and the standard phase, and determine the health status of the phase to be compared according to the temperature difference between the phase to be compared and the standard phase;
when the temperature difference is between 0K and 5K, the phase to be compared is in a normal state, and the equipment is normal and can continuously run at the moment;
when the temperature difference is 5K-10K, the phase to be compared is in an attention state, the inspection cycle of the phase to be compared is shortened, and monitoring is enhanced;
when the temperature difference is more than 10K, the phases to be compared are in an abnormal state, and other means are adopted to enhance monitoring and combine a power failure plan to timely develop hidden danger treatment work.
Further comprising a step S5, wherein the step S5 is to predict the temperature rise of the phase to be compared when the phase is in an abnormal state,
the method used is temperature rise prediction based on time series analysis. For SF judged to be in abnormal state6And predicting the real-time temperature of the air charging equipment, wherein the prediction model is an ARIMA model based on time series analysis. The temperature detection data is a sequence which does not meet the stability condition, the difference order d in the ARIMA (p, d, q) model is determined after a plurality of differences,parameters p and q are determined according to an autocorrelation function ACF and a partial autocorrelation function PACF, and the specification that attenuation after p order tends to zero and attenuation after q order tends to zero in the ARIMA model order selection principle is combined.
The invention utilizes the measured SF without considering the temperature compensation of the pressure gauge6The gas pressure value and the calculated density value can be used for calculating the SF inside the equipment6The temperature value of the gas. According to the difference of fitting method and fitting accuracy, the relational expressions of different equation times and different forms can be obtained, and the invention adopts SF6The gas state parameter equation is a Betty-Bridgman state equation, and is shown in formula (1):
P＝0.57×10-4ρt(1+B)-ρ2A (1)；
wherein P is pressure, MPa; t is temperature, K; rho is density kg/m 3; the coefficients A, B are respectively
A＝0.75×10-4(1-0.727×10-3ρ) (2)；
B＝2.51×10-3ρ(1-0.846×10-3ρ) (3)；
The real-time temperature of equipment with heating defects is accurately predicted, a power failure maintenance plan is arranged in time through temperature prejudgment, the heating defects are eliminated in time, and power supply load loss can be reduced to the maximum extent.
Currently commonly used SF6The method for predicting the temperature rise of the electrical equipment mainly comprises a grey theory, a network analysis method, an extreme learning machine, a support vector machine and the like. The extreme learning machine has good short-term prediction effect but poor algorithm stability. The grey theory is suitable for predicting the increasing trend exponentially along with time, and the prediction result has deviation if the prediction quantity is not the prediction quantity changing exponentially. The sensitivity of the support vector machine to extreme values is prone to overfitting. Time series analysis as a mature prediction method has achieved good effects in the fields of wind speed prediction, haze prediction and power load prediction. The time sequence analysis not only recognizes the continuity of the development of things, but also fully considers the fluctuation caused by the influence of accidental factors, and depends on the sequence itselfThe time sequence and autocorrelation establish a prediction model, and the prediction precision is very high. Commonly used time series models are Moving Average (MA), Auto Regression (AR) and auto regressive differential moving average (ARIMA), where ARIMA is a linear or non-linear combination of MA and AR models plus the difference to historical data. The AR model is similar to the linear regression method, i.e., assuming that the data at time m +1 is a linear combination of historical data at time m before, y ═ β X. The MA model is then fit to the prediction data using the error of the historical data. The ARIMA model is applied to the fields of meteorology, medicine, traffic and the like, and has good effect, and the ARIMA model is applied to SF6In the aspect of temperature rise prediction of the electrical equipment, the real-time temperature of the equipment with heating defects can be accurately predicted, and equipment damage or power supply load loss caused by improper power failure and vacancy elimination planning arrangement is avoided. ARIMA model acknowledges the response X of a variable at time tiNot only the response X to the time t-1, t-2, t-3 …i-1，Xi-2，Xi-3…, and is related to the disturbance entering the system at times t-1, t-2, t-3 …. Three parameters of p-order AR, q-order MA and d-order difference are required to be set during ARIMA modeling, an autocorrelation function is adopted to determine a parameter p, a partial autocorrelation function is adopted to determine a parameter q, a parameter d is determined through the difference times, and parameter estimation can be carried out after the parameters of the ARIMA model are determined to obtain a predicted temperature rise curve.
The process of the present invention is illustrated below with reference to specific examples.
Example 1
(1) The field measurement equipment is SF6In the gas-filled circuit breaker, A, B-phase contacts are normally contacted, and C-phase contacts are abnormally contacted, through a resistance test of a conductive loop, the A-phase is 78 mu omega, the B-phase is 77 mu omega, and the C-phase is 165 mu omega, namely the calorific value of the C-phase is obviously greater than that of the A, B-phase after the same current flows. For the test requirement of the embodiment of the application, the resistance of the C-phase loop is artificially larger than those of the other two phases, and the heating value is increased after the loop resistance is larger.
(2) In the presence of SF to be detected6Two circuit breakers A, B, C are respectively arranged on three phasesSF6Pressure gauges, namely a pressure gauge A with temperature compensation and a pressure gauge B without temperature compensation. When the indication number of the pressure gauge A is unchanged, the fact that the equipment to be detected does not have SF is indicated6Gas leakage in ensuring SF6The temperature rise can be detected and predicted by using a subsequent method on the premise of no gas leakage. The readings of the pressure gauge A on the on-site monitoring three-phase equipment are unchanged, and subsequent detection can be carried out.
(3) Will PA、PB、PC、tA、tB、tCThe values of (c) are substituted into the equations (1) - (3), and the SF of A, B, C phases is calculated respectively6Gas density value ρA、ρB、ρCWhen SF6When gas is not leaked ρA、ρB、ρCIs a constant value.
PA＝0.622MPa；
PB＝0.621MPa
PC＝0.622MPa
TA＝20+273.5＝293.5K；
TB＝20+273.5＝293.5K
TC＝20+273.5＝293.5K
p＝0.57×10-4ρt(1+B)-ρ2A (1)
A＝0.75×10-4(1-0.727×10-3ρ) (2)
B＝2.51×10-3ρ(1-0.846×10-3ρ) (3)
Calculating to obtain rhoA≈40.1706kg/m3、ρB≈40.1702kg/m3、ρC≈40.1706kg/m3。
(4) Using the current pressure value P of the pressure gauge BVertical and horizontalAnd SF of step (3)6Gas density value ρA、ρB、ρCSubstituting formula (1) to respectively calculate current temperature values t of A, B, C three-phase equipmentVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C；
PVertical and horizontal A＝0.725MPa；
PVertical and horizontal B＝0.731MPa；
PVertical and horizontal C＝0.816MPa；
Find tVertical and horizontal A＝335.2896K、tVertical and horizontal B＝337.6775K、tVertical and horizontal C＝371.5024K。
Wherein t isVertical and horizontal A≤tVertical and horizontal B≤tVertical and horizontal C。
(5) T in current temperature of three-phase equipmentVertical and horizontal A335.2896K is the lowest temperature and is in normal operation state, so phase A is selected as the standard phase, B, C two phases are to-be-compared phases, and the temperature difference between B, C two phases and C phase is calculated as
tVertical and horizontal B-tVertical and horizontal A＝337.6775-335.2896＝2.3879K；
tVertical and horizontal C-tVertical and horizontal A＝371.5024-335.2896＝36.2128K。
(6) Determining that the phase B is in a normal state by calculating the temperature difference value between the phase to be compared and a standard phase, wherein the temperature difference value between the phase B and the phase A is between 0K and 5K, and considering the influence of other conditions such as illumination and the like; and (4) determining that the temperature difference value of the phase C and the phase A is more than 10K, determining that the phase C has an overheating defect, and adopting other means to enhance monitoring and combining a power failure plan to timely carry out hidden danger treatment work.
(7) And predicting the C-phase real-time temperature in an abnormal state so as to accurately and timely arrange power failure for defect elimination work and ensure that the loss of the power supply load is reduced to the maximum extent. Experimental data the temperature measurement data t of phase C in 3 months of 2020Vertical and horizontal CThe test was performed every 2 hours, and 186 cases of data were collected, of which the first 162 cases were used for training and the last 24 cases were used for testing.
The temperature detection data is a sequence which does not meet the stability condition, and the difference order d in the ARIMA (p, d, q) model is determined after a plurality of differences. For sample data, after two differential treatments, the stationarity requirement is met, so that the parameter d is determined to be 2. Parameters p and q in an ARIMA (p, d and q) model are determined according to an autocorrelation function ACF and a partial autocorrelation function PACF, and according to the stipulations that the attenuation after p orders tends to zero and the attenuation after q orders tends to zero in the ARIMA model order selection principle, the parameters p are determined to be 3, and q are determined to be 2.
After the ARIMA (3, 2) model is trained by using 162 cases of temperature detection data, 24 cases of temperature data are predicted and compared with actual detection data, and the result is shown in fig. 4, and it can be seen from fig. 4 that the predicted data is very close to the actual data and has higher prediction accuracy.
Claims (10)
1. Based on two SF6The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: which comprises the following steps of,
s1 in the detection of SF6The A, B, C three phases of the electrical equipment are respectively provided with two SF6Pressure gauge, said two blocks SF6The pressure gauges are respectively a pressure gauge A with temperature compensation and a pressure gauge B without temperature compensation;
s2 calculating A, B, C phases of SF by using pressure value P and temperature value T of pressure gauge A6Gas density value ρA、ρB、ρC；
S3 using the current pressure value displayed by the pressure gauge B of A, B, C phase and SF combined with the step S26The gas density value calculates the current temperature value t of three phases of the equipment A, B, CVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C；
S4 determines A, B, C the state of the three phases.
2. The dual SF-based system of claim 16The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: in step S1, after the installation is completed, the SF to be detected is confirmed6Presence or absence of SF in electrical equipment6Gas leakage, if the indication of the pressure gauge A is unchanged, indicating that SF does not occur6Gas leakage, if the indication of the pressure gauge A changes, indicating the occurrence of SF6And if the gas leaks, checking the leakage point and repairing.
3. According to claimA dual SF-based as set forth in claim 26The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: in step S2, the pressure value P of the pressure gauge a and the compensated temperature value t corresponding thereto are substituted into formula (1) to obtain SF6A gas density ρ;
p＝0.57×10-4ρt(1+B)-ρ2A (1)；
wherein, P is a pressure value, Mpa; t is a temperature value, K; rho is density, kg/m3。
4. A dual SF based as in claim 36The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: the coefficient A is obtained according to a formula (2), and the coefficient B is obtained according to a formula (3);
A＝0.75×10-4(1-0.727×10-3ρ) (2)；
B＝2.51×10-3ρ(1-0.846×10-3ρ) (3)；
rho is density, kg/m3。
5. A dual SF-based system as in claim 46The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: the compensated temperature value t of the pressure gauge A is 20+ 273.5-293.5K;
respectively measuring the pressure value P of a pressure gauge A in A, B, C phasesA、PBAnd PcSubstituting the compensated temperature value t into the formula (1) to obtain the SF corresponding to A, B, C6Gas density ρA、ρBAnd ρC；ρASF corresponding to A6Gas density, kg/m3，ρBIs SF corresponding to B6Gas density, kg/m3，ρCIs SF corresponding to C6Gas density, kg/m3。
6. A dual SF-based system as in claim 56The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: in step S3, pressure is usedCurrent pressure value P of Table BVertical and horizontal A、PVertical and horizontal B、PVertical and horizontal CAnd SF calculated at S26Gas density value ρA、ρB、ρCRespectively calculating current temperature values t of A, B, C three-phase equipment of the equipmentVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal C。
7. A dual SF-based system as in claim 66The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: in step S3, the current pressure value P displayed by the pressure gauge B of phase AVertical and horizontal AAnd SF obtained in step S26Gas density value ρASubstituting the formula (1) to calculate the current temperature t of the A-phase equipmentVertical and horizontal A(ii) a Displaying the current pressure value P of the pressure gauge B of the phase BVertical and horizontal BAnd SF obtained in step S26Gas density value ρBSubstituting the formula (1) to calculate the current temperature t of the B-phase equipmentVertical and horizontal B(ii) a Displaying the current pressure value P of the pressure gauge B of the C phaseVertical and horizontal CAnd SF obtained in step S26Gas density value ρCSubstituting the formula (1) to calculate the current temperature t of the C-phase equipmentVertical and horizontal C。
8. A dual SF-based system as in claim 76The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: in step S4, t is selectedVertical and horizontal A、tVertical and horizontal B、tVertical and horizontal CThe lowest temperature of the two phases is the standard phase, and the other two phases are the phases to be compared.
9. A dual SF based as in claim 86The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: the judgment standard of the step S4 is that the temperature difference value of the phase to be compared and the standard phase is calculated, and the health state of the phase to be compared is determined according to the temperature difference value of the phase to be compared and the standard phase;
when the temperature difference is between 0K and 5K, the phase to be compared is in a normal state, and the equipment is normal and can continuously run at the moment;
when the temperature difference is 5K-10K, the phase to be compared is in an attention state, the inspection cycle of the phase to be compared is shortened, and monitoring is enhanced;
when the temperature difference is more than 10K, the phase to be compared is in an abnormal state, and at the moment, the monitoring is strengthened and the hidden danger processing work is timely carried out by combining with the power failure plan.
10. A dual SF based as in claim 96The temperature rise test method of the power equipment monitored by the meter is characterized by comprising the following steps: the method further comprises a step S5, wherein the step S5 is to predict the temperature rise of the phase to be compared when the phase to be compared is in an abnormal state, and the prediction model is an ARIMA model based on time series analysis; the temperature detection data is a sequence which does not meet the stability condition, the difference order d in an ARIMA (p, d, q) model is determined after a plurality of differences, parameters p and q are determined according to an autocorrelation function ACF and a partial autocorrelation function PACF, and the specification that the attenuation after p order tends to zero and the attenuation after q order tends to zero in the ARIMA model order selection principle is combined.
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