KR102351644B1 - Apparatus for checking equipments of electrical substation in real time - Google Patents

Abstract

The present invention relates to a system capable of real-time digital monitoring of a substation facility and automatically detecting a failure risk.
An apparatus capable of real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention includes a sensor unit configured to measure data related to a state of the substation facility; an input/output unit configured to receive data measured by the sensor unit from the sensor unit; a communication unit configured to transmit and receive data to and from an external device; and a processor configured to control the input/output unit and the communication unit, wherein the sensor unit includes a gas pressure monitoring unit, an insulating flow rate monitoring unit, a moisture monitoring unit, a CT terminal monitoring unit, a protective relay monitoring unit, an arrester leakage current monitoring unit, and an internal transformer monitoring unit. It may include at least one of a sub and a digital input (DI).

Description

Real-time remote instantaneous inspection device for substation facilities {APPARATUS FOR CHECKING EQUIPMENTS OF ELECTRICAL SUBSTATION IN REAL TIME}

The present invention relates to a system capable of real-time digital monitoring of a substation facility and automatically detecting a failure risk.

A substation facility is a broad concept that refers to facilities necessary to power up and down for power efficiency, etc., and to support it in the process of transmitting power generated in a power plant through lines and distributing it to consumers, such as households. Substation facilities include peripheral voltage, in-house transformer, GIS (gas insulated switchgear), EBG (gas termination junction box), CT (current transformer) and protective relay.

It goes without saying that inspection of the facilities is required to safely operate these substation facilities that must handle hundreds of kV (kilovolts) of electricity, prevent human and material damage due to failure in advance, and protect the life of the facility. However, the actual inspection or failure risk detection of substation facilities is based on the arbitrary judgment of personnel and inspectors. Specifically, in the case of general equipment, regular inspections are performed 3 times/day for manned substations, 1 time/week for the circuit diagnosis team, and 1 time/3 years for main transformers. In addition, as a method, the inspector visits the sensor adjacent to the substation, inputs the sensor value manually, and determines the risk of failure by the inspector's judgment. This method has several problems as follows.

First, since real-time monitoring is not possible due to the regular inspection method depending on the manpower, there is a problem that a failure occurs despite the regular inspection. For example, transformer diagnosis requires expertise and is performed once every 3 years. Even if a good judgment is received during inspection, a failure can occur within 3 years before the next diagnosis. Equipment that undergoes short-term daily and weekly inspections is also experiencing significant breakdowns every year. Risk detection through real-time inspection is required to overcome the problem of failures despite regular inspections.

Second, it is difficult to ensure reliable analysis when measuring in a manual method or judging the risk by the inspector's arbitrary judgment from the measured data. For example, the occurrence of partial discharge may not be properly measured because the partial discharge measurement performed by the inspector through portable equipment is insufficient. The partial discharge waveform is detected in the acquired signal, but the risk of failure is detected by judging it as simple noise. You may not be able to do it. Therefore, measurement and failure risk diagnosis by an automated machine are required.

Third, there is a problem with safety issues in order to measure or collect data by manpower. For example, due to the risk that may occur from high voltage or gas, the data inside the facility cannot be directly measured and the reliability is indirectly measured from the outside. cases may occur. For this reason, there is a need for a system capable of installing an automated machine within a facility and collecting data remotely.

Finally, there is a problem in that the manpower consumed by performing the inspection by the inspector is quite large. This ultimately leads to a problem of operating costs.

An object of the present invention is to provide an apparatus and system for digitizing data and automatically collecting data in real time in a remote place and determining whether there is a risk in order to solve the problems of the prior art.

An apparatus capable of real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention includes: a sensor unit configured to measure data related to the state of the substation facility; an input/output unit configured to receive data measured by the sensor unit from the sensor unit; a communication unit configured to transmit and receive data to and from an external device; and a processor configured to control the input/output unit and the communication unit, wherein the sensor unit includes a gas pressure monitoring unit, an insulating flow rate monitoring unit, a moisture monitoring unit, a CT terminal monitoring unit, a protective relay monitoring unit, an arrester leakage current monitoring unit, and an in-house transformer monitoring unit. It may include at least one of a sub and a digital input (DI).

SF6 gas analyzer according to an embodiment of the present invention, the receiving unit configured to introduce a gas; a pressure reducing valve configured to adjust the pressure of the gas to be equal to the atmospheric pressure; a measuring unit configured to measure data regarding a state of the gas; a check valve to prevent backflow of gas; a pump that increases the pressure of the gas; and a discharge unit configured to discharge gas, and the measurement unit may include at least one of an SO2 meter, a purity meter, and a moisture meter.

According to the apparatus for real-time remote instantaneous inspection of substation facilities according to various embodiments of the present invention, instantaneous inspection of substation facilities can be automatically performed without having to rely on manpower. Furthermore, real-time and remote inspection is possible. Therefore, it is possible to overcome the problem of failure occurring despite regular inspection through real-time inspection.

In addition, since remote inspection is possible without an inspector, inspection can be performed even in a live state, and safety accidents of inspectors can be prevented at the same time. And also in risk judgment, because it is judged mechanically according to the standard value set with professionalism, it is possible to make a professional and reliable risk judgment, and furthermore, there is an effect that can improve the safety or lifespan of the equipment.

1 is a diagram showing the configuration of an apparatus for real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention.
2 is a diagram showing in detail the configuration of an apparatus for real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention.
3 is a diagram illustrating a state in which a user remotely performs an instantaneous inspection through a real-time remote instantaneous inspection apparatus for a substation facility according to an embodiment of the present invention.
4 is a diagram illustrating a pressure sensor and a hygrometer as a configuration of a sensor unit according to an embodiment of the present invention.
5 is a view showing a CT terminal monitoring unit according to an embodiment of the present invention.
6 is a view showing in detail the configuration of the arc discharge monitoring unit according to an embodiment of the present invention.
7 is a view showing the configuration of the EBG insulation state determination unit according to an embodiment of the present invention.
8 is a view showing in detail the configuration of the SF6 gas analyzer according to an embodiment of the present invention.

In order to clearly explain the present invention, parts irrelevant to the description are omitted, and the same reference numerals are assigned to the same or similar components throughout the specification.

Hereinafter, with reference to the accompanying drawings, embodiments of the present invention will be described in detail so that those of ordinary skill in the art can easily implement them. However, the present invention may be implemented in several different forms and is not limited to the embodiments described herein.

Hereinafter, data includes analog data, digital data, and DI (Digital Input), and is a broad concept encompassing all forms capable of delivering numerical and/or On/Off information regardless of the type of data signal. is called

In addition, arc discharge and partial discharge are both referred to as examples of discharge occurring within the facility, and the description of arc discharge does not exclude partial discharge, nor does the description of partial discharge exclude arc discharge. In addition, the configuration of the sensor or sensor units described as the type of the sensor unit is also disclosed as an example, and is not limited thereto.

1 is a diagram showing the configuration of an apparatus for real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention.

The apparatus 100 for real-time remote instantaneous inspection of a substation facility according to an embodiment may include a sensor unit 110 , an input/output unit 120 , a processor 130 , and a communication unit 140 . The substation facility real-time remote instantaneous inspection device measures and receives data on the state of the substation facility located remotely, determines whether the data exceeds the reference range and the degree of excess, and generates diagnostic information as diagnostic information; This can be transmitted, for example, to a SCADA or HMI device. In one embodiment, all or part of the substation facility real-time remote instantaneous inspection device may be in the form of a card configured on a PCB.

According to an embodiment, the sensor unit 110 may be configured to measure data related to the state of the substation facility. The sensor unit 110 is a gas pressure monitoring unit, insulation flow monitoring unit, moisture monitoring unit, CT terminal monitoring unit, protection relay monitoring unit, lightning arrester leakage current monitoring unit, in-house transformer monitoring unit, DI (Digital Input), arc discharge monitoring It may include a unit, an SF6 gas analysis unit, and the like. Each configuration of the sensor unit includes a sensor, and is installed adjacent to the substation facility to measure data related to the state of the substation facility. For example, an insulation flow monitoring unit is installed inside or outside the peripheral voltage to measure the insulation flow, or an arc discharge monitoring unit is installed inside the GIS to measure arc discharge or current inside the GIS.

According to an embodiment, the input/output unit 120 may be configured to receive data measured by the sensor unit from the sensor unit. The input/output unit may include a plurality of I/Os as I/Os to which data can be entered. For example, it may include ADC, photocoupler, RJ45, and the like.

According to an embodiment, the processor 130 may be configured to control the input/output unit and the communication unit. According to another embodiment, the processor 130 determines whether or not the data received by the input/output unit exceeds a reference range and the degree of excess, and based on whether or not the reference range is exceeded and the degree of excess, the processor 130 determines whether the diagnostic information is good, observed, or exceeded. It may be further configured to control the communication unit to generate one of the attention and transmit the diagnostic information to an external device. For example, it may be a CPU, an AP, or the like.

According to an embodiment, the communication unit 140 may transmit and receive data measured by the sensor unit and received by the input/output unit with an external device. According to another embodiment, the communication unit 140 may be further configured to transmit and receive information generated by the processor 130, for example, diagnostic information with an external device. The communication unit is a component capable of transmitting and receiving data and/or information with an external device, such as an HMI device, and may be a wired/wireless communication module or I/O. For example, when a real-time remote instantaneous inspection device for a substation facility is manufactured in the form of a PCB card and coupled with an HMI device, both terminals may function as the communication unit 140 .

2 is a diagram showing in detail the configuration of an apparatus for real-time remote instantaneous inspection of a substation facility according to an embodiment of the present invention. The substation facility real-time remote instantaneous inspection apparatus 100 according to an embodiment includes the sensor units 211, 212, 213_a, 213_b, 213_c, 214, 215, 216, 217_a, 217_b, 217_c, 218 installed adjacent to each substation facility. , 219) can receive data and transmit it to HMI. The substation facility real-time remote instantaneous inspection apparatus 100 according to an embodiment may be configured with a plurality of modules. Each module may include a sensor unit, an input/output unit, a processor, and a communication unit, and there may be modules equipped with only a part of them.

The sensor unit according to an embodiment may include various types, and each sensor unit may include at least one sensor. The sensor unit, for example, is a gas pressure monitoring unit that monitors the gas pressure of SF6 used in GIS, GCB, VCB, etc., an insulation flow monitoring unit regarding whether the insulating oil of the ambient pressure has an appropriate amount, and the inside of the ambient pressure device. Moisture monitoring unit that monitors whether moisture or humidity is appropriate, CT complex monitoring unit that detects overheating due to poor connection of CT (Current Transformer) terminals, Protection relay monitoring unit that monitors whether or not the protection relay is working properly, lightning arrester (LA) Lightning arrester leakage current monitoring unit monitoring leakage current, in-house transformer monitoring unit monitoring the status of in-house transformers, digital signals such as facility opening/closing, i.e., DI, GIS internal arc discharge or GIS or GIS signals that detect binary signals It may include an arc discharge monitoring unit that detects arc discharge of EBG for ambient pressure, and an SF6 gas analysis unit that can monitor SO2, purity, moisture, etc. in the gas of SF6 for GIS or gas transformer.

The input/output units 221 , 222 , 223 , 224 , 225 , 226 , and 227 according to an embodiment may include various types. For example, the input/output unit may include an ADC capable of receiving analog data and converting it into digital data, a photocoupler capable of converting a DI signal into digital data, an RJ45 receiving a digital signal, and the like. In an embodiment, which input/output unit is configured may be closely related to the configuration of the sensor unit. An input/output unit suitable for the type of data transmitted by the sensor unit may be configured. That is, for example, depending on whether the data is analog, DI, or digital, the input/output unit may be an ADC, a photocoupler, or an RJ45.

In addition, the communication method may be different depending on the signal type and the configuration and number of substation facilities. For example, each sensor may correspond to an input/output unit, or a protocol for transmitting data as one data by connecting multiple sensor units such as RS-485 communication method may be used. Alternatively, an RF cable may be used, or a POE method may be used.

In FIG. 2, for example, 211 may transmit information through an RF cable as an EBG arc discharge monitoring unit. 212 may transmit analog data such as AC voltage 3-phase harmonic, PT (Power Transformer) voltage 3-phase harmonic, DC voltage, etc. as a transformer monitoring unit. In this case, the 221 receiving the analog signal may be an ADC.

As another example, 213_a, 213_b, and 213_c include a voltage or current sensor as a CT terminal monitoring unit, and may transmit digital data. 222 for receiving digital data may be RJ45 or the like. Here, 213_a, 213_b, and 213c can be configured to measure the state of three phases, respectively, and communicate using the RS-485 method.

214 may be configured to transmit digital data through a current sensor as an arc discharge monitoring unit, and may be configured to transmit data in a POE manner by configuring a POE converter.

Reference numeral 215 denotes a lightning arrester leakage current monitoring unit, an insulation flow rate monitoring unit, or a moisture monitoring unit, and may be a sensor unit that transmits analog data of LA leakage current, insulation flow rate, or moisture information. 216 may be a DI, and 225 may be a photocoupler for receiving DI data.

217_a, 217_b, and 217_c are gas pressure monitoring units, and are configured to transmit digital data measured by the pressure sensor, and 226 to receive it may be configured as RJ45, and 217_a, 217_b, and 217_c are phases a, b, and c, respectively. can be measured and communicated by RS485 method.

218 may be configured to transmit the amount of current of the protection relay as digital data as a protection relay monitoring unit, and 227 may be configured as RJ-45 to receive data.

The configuration described above with respect to the sensor unit, the input/output unit, and the communication method has been described as an example, and is not limited thereto.

The processors 230 and 235 according to an embodiment may control the input/output unit and the communication unit or process data. In an embodiment, the processor may receive data directly from the input/output unit, or may receive data through the FPGAs 231 and 236 . A field programmable gate array (FPGA) is a semiconductor device that includes a designable logic device and a programmable internal circuit. Designable logic devices can be programmed to replicate the functions of basic logic gates, such as AND, OR, XOR, NOT, and more complex decoder or combination functions of computational functions. In general, since the initial development cost is lower than that of an application-specific semiconductor (ASIC), it has an advantage suitable for small-scale production. In FIG. 2 , the processors 230 and 235 are illustrated separately from the FPGAs 231 and 236 , but the processor may refer to including the FPGA.

3 is a diagram illustrating a state in which a user remotely performs an instantaneous inspection through a real-time remote instantaneous inspection apparatus for a substation facility according to an embodiment of the present invention. According to one embodiment, the user can remotely check the status of several substation facilities through HMI in real time, and determine whether the substation facilities are in good condition or need observation from the diagnostic information received from the substation facility real-time remote instantaneous inspection device. Or, it can be checked whether there is a risk of failure as a cautionary state.

Through real-time remote instantaneous inspection of substation facilities and HMI, it is possible to perform automatic and real-time remote inspection without relying on human resources. Ultimately, it is possible to prevent malfunctions in advance and reduce human and material damage through real-time inspection. In addition, since inspection is possible remotely without an inspector, inspection can be performed even in a live state, and safety accidents can be prevented at the same time. Reliable risk determination is possible, and furthermore, there is an effect that can improve the safety or lifespan of equipment.

4 is a diagram illustrating a pressure sensor and a hygrometer as a configuration of a sensor unit according to an embodiment of the present invention.

The gas pressure monitoring unit according to an embodiment of the present invention may include a pressure sensor 410 for measuring the SF6 gas pressure of the GIS or CGV or the spring pressure of the VCB. In the case of SF6, when it is -5% of the GIS maintenance appropriate pressure reference value, it is possible to generate cautionary diagnosis information. The diagnostic information of interest may include an alarm. The spring pressure can be configured to measure the appropriate pressure when V.I is ON/OFF, and the processor generates critical diagnostic information when it is ±3% or more of the appropriate pressure reference value.

The insulation flow rate monitoring unit according to an embodiment of the present invention may be configured to measure an insulation flow rate in the case of an ambient pressure device and to measure an insulation flow rate and pressure during operation in the case of an OLTC. In the case of the insulation flow rate of the peripheral voltage through the real-time remote instantaneous inspection device of the substation facility, the insulation flow rate inside the transformer can be displayed as an actual measured value, and diagnostic information of interest can be generated when it is less than 5% of the appropriate reference value by interlocking with the outside temperature. In the case of OLTC insulation flow rate, it is possible to generate cautionary diagnosis information when it is interlocked with the outside temperature, the transformer insulation oil rises, and the OLTC insulation oil drops 3% deviation.

The moisture monitoring unit according to an embodiment of the present invention may measure the moisture inside the mechanical protection device of the ambient pressure. It is for preventing malfunction due to moisture penetration inside the transformer mechanical protection device, and may include a hygrometer 420, and is configured to generate moisture penetration caution diagnostic information when the internal humidity of the device is 30% or more through a real-time remote instantaneous inspection device of a substation facility can be

5 is a view showing a CT terminal monitoring unit according to an embodiment of the present invention. The CT terminal monitoring unit can be configured in all CT terminal blocks of the substation facility, and is configured to monitor overheating when the cable connection is faulty.

The CT terminal monitoring unit 510 according to an embodiment of the present invention may monitor overheating by measuring a partial discharge voltage generated when a connection is defective. The arc sensor 512 is configured to measure the partial voltage. In an embodiment, the measured partial voltage data may be transmitted to the input/output device using the RF connector 514 . The substation facility real-time remote instantaneous inspection device may be configured to generate critical diagnostic information when the partial discharge voltage is 120uV or more.

The protective relay monitoring unit 510 according to an embodiment of the present invention may be installed in a 154, 23kV class protective relay. It may be configured to measure the CT secondary-side current and transmit it to the input/output unit. The substation facility real-time remote instantaneous inspection device may be configured to generate critical diagnostic information or display a fault current when outputting 4.5A or more. At this time, the location of the fault section can also be displayed.

The lightning arrester leakage current monitoring unit according to an embodiment of the present invention can be applied to the primary, secondary, and tertiary side of the peripheral voltage, T/L inlet, and GIS built-in type, and can be configured to measure the lightning arrester leakage current. Leakage current threshold can be set to 1mA for 765kV, 0.5mA for 345 and 154kV, and 0.3mA for 23kV, and the processor has an error of less than 10% compared to the reference value good, 10-20% observed, 20% In case of abnormality, diagnostic information may be generated with caution.

The on-site transformer monitoring unit according to an embodiment of the present invention may be configured so that the user can monitor the AC, DC voltage state by measuring and transmitting the AC and DC voltages of the on-site transformer. It monitors AC A, B, C, and N phase currents, and when a difference of 20% between the currents occurs or a 30% difference between the phases occurs, it is possible to generate important diagnostic information. Alternatively, it is possible to generate important diagnostic information when an overcurrent occurs in the AC power supply to the DC charger.

6 is a view showing in detail the configuration of the arc discharge monitoring unit according to an embodiment of the present invention.

In the arc discharge measurement method inside the GIS, in the past, a person carried a portable device and directly measured it. In addition, there was a problem in that accurate measurement was difficult because it was difficult to distinguish between a signal caused by an arc discharge and a signal caused by noise during measurement.

When the current is measured during arc discharge, all of the noise component, the capacitive current component and the resistive current component are detected. The noise component may be, for example, a cell phone frequency or the like, and the capacitive current component may be a glow discharge or the like. Among the detected signals, the resistive current component is a fault risk current, and detecting this resistive current component is the key to fault risk detection.

The arc discharge monitoring unit 600 according to an embodiment may include a current sensor 610 . The current sensor 610 may be configured such that only a resistive current passes, and a reactive current cannot pass through. The current sensor 610 may include, for example, a semiconductor integrator. Since the semiconductor integrator cumulatively adds current components (integration), the ineffective component, which is a sinusoidal wave component, is not accumulated, but only the resistive component is accumulated and detected. Therefore, such a current sensor can perform a function of detecting only the resistive current. Even if the receiver receives the current including all components, the noise component and the capacitive current component are not detected in the current sensor, and the current sensor can detect the corresponding component only when a resistive current is present.

Furthermore, arc discharge can be diagnosed in the following way.

1) Reference value:

2) Measure the measured value:

3) Fault risk current (resistive current):

4) Less than 5% = good, 5-10% = observation, more than 10% = caution

By electronically monitoring the arc discharge measuring device, more precise and specialized monitoring is possible compared to the existing method of regular inspection by personnel. In addition, since it is possible to monitor in real time, it is possible to reduce the consumption of manpower while further reducing the risk of equipment failure.

In addition, the arc discharge monitoring unit may be configured to enable POE communication by configuring a POE controller as shown in FIG. 6 .

Arc discharge monitoring unit can be applied to GIS internal arc discharge measurement, and can also be applied to determine the insulation status by measuring arc discharge of GIS or EBG for ambient voltage.

7 is a view showing the configuration of the EBG insulation state determination unit according to an embodiment of the present invention. The EBG insulation state determination unit 700 may include an arc sensor 710 and measure the arc discharge voltage/current of the EBG connection unit. Here, the arc sensor 710 may include the above-described current sensor 610 or an arc discharge monitoring unit. In addition, the EBG insulation state determination unit may include a signal processing module 720 .

8 is a view showing in detail the configuration of the SF6 gas analyzer according to an embodiment of the present invention.

SF6 is used as an insulator in gas insulation. When arc discharge occurs, SO2 is generated as a by-product from SF6 gas, which is SO2 generated by reacting SF6 with moisture. Therefore, the state of the insulating gas can be measured by directly detecting the SO2 component, measuring the purity of SF6, or measuring the amount of moisture that is changed according to the reaction.

In the method of analyzing the internal gas purity and moisture for GIS or gas transformer, conventionally, the substation facility is first put into a truce state and measured using a portable device, but the gas is slowly released to adjust the pressure to 1kg/cm2, and then the purity and Moisture and the like were measured. This is because the sensor that measures purity and moisture can measure only at 1 atmospheric pressure, that is, about 1 kg/cm2. In general, a GIS or gas transformer requires a pressure of 6kg/cm2 to achieve sufficient insulation effect. As a result, it was difficult to analyze the gas in a live state as far as the prior art is concerned.

The SF6 gas analyzer 800 according to an embodiment of the present invention includes a receiving part configured to introduce gas; a pressure reducing valve configured to adjust the pressure of the gas to be equal to the atmospheric pressure; a measuring unit configured to measure data regarding a state of the gas; a check valve to prevent backflow of gas; a pump that increases the pressure of the gas; and a discharge unit configured to discharge gas, and the measurement unit may include at least one of an SO2 meter 810 , a purity meter 820 , and a moisture meter 830 .

SF6 may be introduced into the SF6 gas analyzer through the receiver. The pressure reducing valve reduces the pressure of SF6 gas from 6kg/cm2 to 1kg/cm2. When the pressure control of the pressure reducing valve is not precise, it may further include a configuration capable of finely adjusting the internal pressure. Next, the state of the SF6 gas adjusted to the atmospheric pressure of 1 kg/cm 2 can be measured. At least one of SO2 measurement, purity measurement, and moisture measurement may be performed, and all may be sequentially performed. The measurement unit may include a gas chromatograph (GC). A step-up procedure is required to return the measured gas to the substation. Prior to increasing the pressure to 6 kg/cm 2 by the boosting pump, a check valve may be configured to prevent backflow of the boosted gas. Finally, the pressurized SF6 gas may be discharged through the discharge unit. Data measured by the measurement unit may be transmitted to the input/output unit.

According to an embodiment, the SF6 gas analyzer (gas analyzer) may be configured in the inspection window 840 of the GIS. In detail, it is configured in the inspection window of the GIS, and the receiving part is formed toward the inside of the GIS so that the gas inside the GIS can be introduced. Furthermore, the discharge unit may also be formed toward the inside of the GIS so that the SF6 gas passing through the gas analysis unit can be returned to the inside of the GIS.

In this configuration, there is no need to separately use portable equipment as in the prior art for gas analysis, and it is unnecessary to put the substation facility into a truce state in order to adjust the gas to atmospheric pressure. In other words, it is possible to check the gas even in the live wire state, which has the effect of real-time gas analysis of SF6.

In the substation facility real-time remote instantaneous inspection device according to an embodiment, the input/output unit is further configured to receive the insulating oil gas state data, and the processor includes C2H2, C2H4, C2H6, CH4, H2, and CO included in the insulating oil gas state data. It may be further configured to determine whether each of the data related to the reference range and the extent to which it is exceeded, and the diagnostic information to be generated for each of the data related to C2H2, C2H4, C2H6, CH4, H2, and CO.

In measuring and analyzing the gas contained in insulating oil such as ambient pressure, there is a problem in that it is difficult to detect the risk of failure due to the insufficient determination method in the prior art.

The substation facility real-time remote instantaneous inspection device receives data on C2H2, C2H4, C2H6, CH4, H2, and CO included in the insulating oil gas state, i.e., concentration, mass, mass ratio, volume ratio, etc., and checks whether each of the data exceeds the standard By judging the degree of excess, the risk of failure can be clearly detected by making a clear and reliable judgment. Diagnosis information is also generated for each of the data on C2H2, C2H4, C2H6, CH4, H2, and CO to determine whether each gas requires attention, so that the user can effectively understand the gas state of the insulating oil for each gas.

The following is an example of judging the failure risk for each gas.

1) C2H2

Cause: arc discharge point

Judgment: Good-less than 1.0, Observation-1.0-5.0, Caution-5.0 or more

2) Step 1 C2H4, Step 2 C2H6 (Compared to initial value)

Cause: Overheating of solid insulation, danger when C2H6 increases

Judgment: Good 20% or less, Observation 20-30%, Attention 30% or more

3) CH4 (compared to initial value)

Cause: Partial discharge in insulated ground

Judgment: Good - less than 10%, Observation - 10-20%, Caution - 20% or more

4) H2 (compared to initial value)

Cause: Local overheating due to poor circulation of insulating oil

Judgment: Good - less than 10%, Observation - 10-50%, Caution - More than -50%

5) C0

Cause: bad terminal connection, carbonization of insulating paper

Judgment: Good-less than 500, Observation-500-1,000, Caution-1,000 or more

Those skilled in the art to which the present invention pertains should understand that the present invention can be embodied in other specific forms without changing the technical spirit or essential characteristics thereof, so the embodiments described above are illustrative in all respects and not restrictive. only do The scope of the present invention is indicated by the following claims rather than the detailed description, and all changes or modifications derived from the meaning and scope of the claims and their equivalent concepts should be construed as being included in the scope of the present invention. .

100: substation facility real-time remote instantaneous inspection device
110: sensor unit
120, 221, 222, 223, 224, 225, 226, 227: input/output unit
130, 230, 235: Processor
140, 241, 242: communication department
231, 236: FPGA 410: pressure sensor
420: hygrometer 510: CT terminal monitoring unit
512: arc sensor 514: RF connector
600: arc discharge monitoring unit 610: current sensor
700: EBG insulation state determination unit 710: arc sensor
720: signal processing module 800: SF6 gas analysis device
810: SO2 meter 820: purity meter
830: moisture meter 840: inspection window

Claims (14)

In the device capable of real-time remote instantaneous inspection of substation facilities,
a sensor unit configured to measure data related to the state of the substation;
an input/output unit configured to receive the data measured by the sensor unit from the sensor unit;
a communication unit configured to transmit and receive the data to and from an external device; and
a processor configured to control the input/output unit and the communication unit;
The sensor unit includes an SF6 gas analysis unit,
The SF6 gas analysis unit,
A receiving part that is formed toward the inside of the GIS and configured to allow the gas inside the GIS to flow in;
a pressure reducing valve for reducing the pressure so that the pressure of the introduced gas becomes the same as atmospheric pressure;
a measuring unit configured to measure data regarding the state of the depressurized gas, and comprising at least one of an SO2 meter, a purity meter, and a moisture meter;
a boosting pump for boosting the pressure of the gas for which the data measurement has been completed;
a check valve for preventing a reverse flow of the pressurized gas; and
It is formed toward the inside of the GIS and includes a discharge unit for discharging the pressurized gas to the inside of the GIS,
An apparatus for performing an analysis of the gas in a live state of the GIS.
According to claim 1,
The input/output unit includes an analog-digital converter (ADC),
wherein the data comprises analog data.
3. The method of claim 2,
The input/output unit further includes RJ45,
wherein the data further comprises digital data.
4. The method of claim 3,
The RJ45 is further configured to receive the digital data via RS-485 communication.
5. The method of claim 4,
The input/output unit further includes a photocoupler,
The data further comprises DI.
6. The method of claim 5,
The processor is
Determining whether the data received by the input/output unit exceeds a reference range and the extent to which it is exceeded,
Based on whether or not the reference range is exceeded and the degree of excess, diagnostic information is generated as one of good, observation, or attention;
Further configured to control the communication unit to transmit the diagnostic information to the external device,
Device.
7. The method of claim 6,
The sensor unit further comprises an arc discharge monitoring unit,
The arc discharge monitoring unit includes a current sensor,
wherein the current sensor is configured to respond to a resistive current component.
8. The method of claim 7,
The arc discharge monitoring unit further comprises a POE (Power Over Ethernet) controller,
The input/output unit is further configured to receive data from the arc discharge monitoring unit through a POE method.
delete According to claim 1,
The SF6 gas analysis unit,
The device is configured in the inspection window of the GIS.
11. The method of claim 10,
The input/output unit is further configured to receive insulating oil gas state data,
The processor determines whether each of the data on C2H2, C2H4, C2H6, CH4, H2, and CO included in the insulating oil gas state data exceeds a reference range and the degree of exceeding,
and diagnostic information is generated for each of the data relating to C2H2, C2H4, C2H6, CH4, H2, and CO.
The receiving part is formed toward the inside of the GIS and configured to introduce the gas inside the GIS;
a pressure reducing valve for decompressing the introduced gas to have the same pressure as atmospheric pressure;
a measuring unit configured to measure data regarding a state of the depressurized gas;
a boosting pump for boosting the pressure of the gas for which the data measurement has been completed;
a check valve for preventing a reverse flow of the pressurized gas; and
It is formed toward the inside of the GIS and includes a discharge unit for discharging the pressurized gas into the GIS,
The measuring unit includes at least one of an SO2 meter, a purity meter, and a moisture meter,
SF6 gas analyzer to analyze the gas in the live state of the GIS.
13. The method of claim 12,
The SF6 gas analyzer,
SF6 gas analyzer configured in the inspection window of the GIS.

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