Liquid level detection method and system, electronic device, and storage medium

Abstract

The application provides a liquid level detection method and system, electronic equipment and a storage medium, and the method is applied to a nuclear power plant liquid level detection system, the liquid level detection system comprises a liquid level detection device and a liquid storage cavity, the liquid level detection device comprises a fixed column, one optical fiber pressure sensor is arranged at each end of the fixed column, a plurality of optical fiber pressure sensors are arranged between the two optical fiber pressure sensors at the two ends of the fixed column, one end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity, and the liquid level detection method comprises the following steps: acquiring a plurality of pressure data through the plurality of optical fiber pressure sensors; determining at least one air pressure data and at least one liquid pressure data in the plurality of pressure data; correcting the liquid pressure data according to the air pressure data to obtain corrected liquid pressure data; and determining the liquid level height in the liquid storage cavity according to the corrected liquid pressure data. The application can improve the accuracy of nuclear power plant liquid level detection.

Description

Technical Field

[0001] This application relates to the field of liquid level detection, and more particularly to a liquid level detection method and system, electronic device and storage medium. Background Technology

[0002] Nuclear power plants contain numerous liquid storage facilities, including waste liquid collection pits and various storage tanks. Changes in the liquid levels within these facilities directly impact the safe operation of the nuclear power plant. Accurate liquid level detection not only ensures the normal operation of various equipment but also enables the timely detection of potential safety hazards such as liquid leaks, which is crucial for preventing nuclear accidents and ensuring environmental safety. Therefore, establishing a reliable liquid level detection system is a vital guarantee for the safe operation of nuclear power plants.

[0003] In related technologies, nuclear power plants primarily use ultrasonic level gauges and float-type level gauges for liquid level detection. Ultrasonic level gauges employ non-contact measurement, offering advantages such as convenient installation and maintenance. However, they are susceptible to interference from surface foam, leading to significant deviations in measurement results. While float-type level gauges are simple in structure and provide intuitive measurements, their readings become unstable when the liquid experiences violent fluctuations. Therefore, in the unique environment of nuclear power plants, various environmental factors can affect the measurement accuracy of existing level gauges, making it difficult to meet the requirements for safe operation of nuclear power plants. Summary of the Invention

[0004] This application aims to address at least one of the technical problems existing in the prior art. To this end, this application provides a liquid level detection method and system, electronic equipment, and storage medium, which can improve the accuracy of liquid level detection in nuclear power plants.

[0005] In a first aspect, embodiments of this application provide a method for detecting liquid level in a nuclear power plant. The method is applied to a liquid level detection system in a nuclear power plant. The liquid level detection system includes a liquid level detection device and a liquid storage cavity. The liquid level detection device includes a fixed column, with an optical fiber pressure sensor disposed at each end of the fixed column. Multiple optical fiber pressure sensors are disposed between the two optical fiber pressure sensors at the two ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. The liquid level detection method includes:

[0006] Multiple pressure data are acquired through the multiple fiber optic pressure sensors;

[0007] Among the plurality of pressure data, at least one air pressure data and at least one hydraulic pressure data are identified;

[0008] The hydraulic data is corrected based on the air pressure data to obtain the corrected hydraulic data;

[0009] The liquid level in the reservoir is determined based on the corrected hydraulic data.

[0010] In some embodiments, acquiring multiple pressure data points through the plurality of fiber optic pressure sensors specifically includes:

[0011] An incident light signal is emitted to the plurality of fiber optic pressure sensors to obtain the reflected light signal reflected from the plurality of fiber optic pressure sensors;

[0012] Each of the reflected light signals is subjected to spectral separation to obtain multiple monochromatic light wavelength signals;

[0013] The pressure data is obtained by performing waveform fitting and optical path phase demodulation on each of the monochromatic light wavelength signals.

[0014] In some embodiments, the step of performing waveform fitting and optical path phase demodulation on the plurality of monochromatic light wavelength signals to obtain the pressure data includes:

[0015] Peak identification is performed on the monochromatic waveform curve of each monochromatic light wavelength signal, and the monochromatic waveform curve is separated into multiple sub-waveform signals;

[0016] Each of the sub-waveform signals is subjected to amplitude truncation processing to obtain multiple amplitude-truncation processed sub-waveform signals;

[0017] The truncated sub-waveform signal is fitted to obtain multiple fitted sub-waveforms;

[0018] Calculate the corresponding target displacement value based on the optical path phase difference of each fitted sub-waveform;

[0019] The pressure data is calculated based on each of the target displacement values.

[0020] In some embodiments, the fiber optic pressure sensor includes an optical cavity pressure-sensing element and a temperature-sensing grating element, and the reflected light signal includes an optical cavity reflection signal and a grating reflection signal. After transmitting an incident light signal to the plurality of fiber optic pressure sensors to obtain the reflected light signals from the plurality of fiber optic pressure sensors, the method further includes:

[0021] The reflected signal of the grating is obtained through the temperature-sensing grating element;

[0022] The grating reflection signal is demodulated to obtain the target temperature data;

[0023] The pressure data is corrected based on the target temperature data to obtain the corrected pressure data.

[0024] In some embodiments, determining at least one pneumatic pressure data and at least one hydraulic pressure data among the plurality of pressure data includes:

[0025] Acquire the multiple pressure data points and sort them.

[0026] The pressure data that meets the preset air pressure characteristic conditions among the plurality of pressure data is determined as the air pressure data;

[0027] The hydraulic data is determined from the plurality of pressure data that is greater than the air pressure data and increases with depth.

[0028] In some embodiments, correcting the hydraulic data based on the air pressure data to obtain corrected hydraulic data includes:

[0029] Based on the air pressure data, determine the air pressure inside the liquid storage chamber;

[0030] The air pressure inside the liquid storage chamber is compared with the atmospheric pressure;

[0031] In response to the air pressure being greater than atmospheric pressure, the pressure difference between the air pressure data and atmospheric pressure is calculated;

[0032] The hydraulic data is corrected based on the pressure difference to obtain the corrected hydraulic data.

[0033] In some embodiments, calculating the liquid level height within the reservoir based on the hydraulic data includes:

[0034] Obtain the liquid density of the liquid inside the storage cavity;

[0035] Calculate the product of the liquid density and the gravitational acceleration constant;

[0036] The liquid level height is calculated by dividing the hydraulic data by the product of the liquid density value and the gravitational acceleration constant.

[0037] In some embodiments, when there are multiple hydraulic data points, after obtaining the liquid density of the liquid in the reservoir, the method further includes:

[0038] The fiber optic pressure sensor located at the bottom of the liquid is designated as the main measuring point, and the remaining fiber optic pressure sensors in the liquid are designated as liquid level calibration points.

[0039] Obtain the arrangement height difference between the main measuring point and each of the liquid level verification points;

[0040] Calculate the pressure difference between the hydraulic data corresponding to the main measuring point and the hydraulic data corresponding to each liquid level verification point;

[0041] The actual density value of the liquid is calculated based on each arrangement height difference and the corresponding pressure difference, and the liquid density is updated based on the actual density value of the liquid;

[0042] The liquid level height is recalculated based on the updated liquid density.

[0043] Secondly, embodiments of this application provide a liquid level detection system for a nuclear power plant, comprising:

[0044] A liquid level detection device includes a fixed column, with an optical fiber pressure sensor at each end of the fixed column, and multiple optical fiber pressure sensors disposed between the two optical fiber pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity.

[0045] A host computer, which is communicatively connected to the liquid level detection device, is used to acquire multiple pressure data through the multiple fiber optic pressure sensors; determine at least one air pressure data and at least one hydraulic data among the multiple pressure data; correct the hydraulic data based on the air pressure data to obtain corrected hydraulic data; and calculate the liquid level height in the storage cavity based on the corrected hydraulic data.

[0046] In some embodiments, the fiber optic pressure sensor includes an optical cavity pressure-sensing element and a temperature-sensing grating element; the optical cavity pressure-sensing element is used to measure pressure, and the temperature-sensing grating element is used to measure temperature.

[0047] In some embodiments, the optical cavity pressure sensing element is an all-quartz thin film.

[0048] Thirdly, embodiments of this application provide an electronic device, including: a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the nuclear power plant liquid level detection method as described in any one of the embodiments of the first aspect of this application.

[0049] Fourthly, embodiments of this application provide a computer-readable storage medium storing a program that is executed by a processor to implement the nuclear power plant liquid level detection method as described in any one of the embodiments of the first aspect of this application.

[0050] The nuclear power plant liquid level detection method according to the embodiments of this application has at least the following beneficial effects:

[0051] According to the embodiments of this application, a liquid level detection method for nuclear power plants is applied to a liquid level detection system in a power plant. The liquid level detection system includes a liquid level detection device and a liquid storage cavity. The liquid level detection device includes a fixed column, with a fiber optic pressure sensor installed at each end of the fixed column. Multiple fiber optic pressure sensors are installed between the two fiber optic pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. The liquid level detection method includes: acquiring multiple pressure data through multiple fiber optic pressure sensors; determining at least one air pressure data and at least one hydraulic pressure data among the multiple pressure data; correcting the hydraulic pressure data based on the air pressure data to obtain corrected hydraulic pressure data; and determining the liquid level height in the liquid storage cavity based on the corrected hydraulic pressure data.

[0052] This application achieves continuous and stable monitoring of liquid pressure by installing multiple fiber optic pressure sensors on a fixed column, which is vertically mounted within the liquid storage cavity. This avoids the measurement instability caused by liquid surface fluctuations in float-type level gauges. Based on the collected pressure data, air pressure and hydraulic pressure data are distinguished, thus avoiding the influence of surface foam and overcoming the measurement deviation caused by foam interference in ultrasonic level gauges. Next, by using air pressure data to correct the hydraulic data, the influence of air pressure changes within the storage cavity on the liquid level measurement is effectively eliminated, achieving accurate acquisition of the true hydraulic pressure. Finally, based on the corrected hydraulic data, the liquid level height within the storage cavity can be accurately calculated. This calculation process is unaffected by liquid fluctuations and foam, thus achieving precise liquid level measurement. Compared to existing float-type level gauges, which are susceptible to liquid surface fluctuations, and ultrasonic level gauges, which are susceptible to foam interference, the method provided in this application, based on fiber optic pressure sensing and air pressure correction mechanisms, can effectively overcome measurement interference caused by the special application environment of nuclear power plants, improving the accuracy of liquid level detection in nuclear power plants.

[0053] Additional aspects and advantages of this application will be set forth in part in the description which follows, and in part will be obvious from the description, or may be learned by practice of this application. Attached Figure Description

[0054] The above and / or additional aspects and advantages of this application will become apparent and readily understood from the description of the embodiments taken in conjunction with the following drawings, in which:

[0055] Figure 1 A flowchart of an optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0056] Figure 2 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0057] Figure 3A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0058] Figure 4 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0059] Figure 5 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0060] Figure 6 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0061] Figure 7 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0062] Figure 8 A flowchart of another optional nuclear power plant liquid level detection method provided for an embodiment of this application;

[0063] Figure 9 This is a schematic diagram of a nuclear power plant liquid level detection system provided in an embodiment of this application;

[0064] Figure 10 A schematic diagram of the fiber optic pressure sensor provided in an embodiment of this application;

[0065] Figure 11 This is a schematic diagram of the hardware structure of the electronic device provided in the embodiments of this application. Detailed Implementation

[0066] The embodiments of this application are described in detail below. Examples of the embodiments are shown in the accompanying drawings, wherein the same or similar reference numerals denote the same or similar elements or elements having the same or similar functions throughout. The embodiments described below with reference to the accompanying drawings are exemplary and are only used to explain this application, and should not be construed as limiting this application.

[0067] In the description of this application, "several" means one or more, "more than" means two or more, "greater than," "less than," "exceeding," etc. are understood to exclude the stated number, while "above," "below," "within," etc. are understood to include the stated number. Where "first" or "second" is mentioned, it is only for the purpose of distinguishing technical features and should not be construed as indicating or implying relative importance, or implicitly indicating the number of indicated technical features, or implicitly indicating the sequential relationship of the indicated technical features.

[0068] In the description of this application, it should be understood that the orientation descriptions, such as up, down, left, right, front, and back, are based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this application and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. Therefore, they should not be construed as limitations on this application.

[0069] In the description of this specification, the references to terms such as "one embodiment," "some embodiments," "illustrative embodiment," "example," "specific example," or "some examples," etc., indicate that a specific feature, structure, material, or characteristic described in connection with that embodiment or example is included in at least one embodiment or example of this application. In this specification, the illustrative expressions of the above terms do not necessarily refer to the same embodiment or example. Furthermore, the specific features, structures, materials, or characteristics described may be combined in any suitable manner in one or more embodiments or examples.

[0070] In the description of this application, it should be noted that, unless otherwise explicitly defined, terms such as "setting," "installation," and "connection" should be interpreted broadly. Those skilled in the art can reasonably determine the specific meaning of the above terms in this application based on the specific content of the technical solution. Furthermore, the identification of specific steps in the following text does not imply a limitation on the order of steps or execution logic. The execution order and logic between each step should be understood and inferred from the content described in the embodiments.

[0071] Nuclear power plants contain numerous liquid storage facilities, including waste liquid collection pits and various storage tanks. Changes in the liquid levels within these facilities directly impact the safe operation of the nuclear power plant. Accurate liquid level detection not only ensures the normal operation of various equipment but also enables the timely detection of potential safety hazards such as liquid leaks, which is crucial for preventing nuclear accidents and ensuring environmental safety. Therefore, establishing a reliable liquid level detection system is a vital guarantee for the safe operation of nuclear power plants.

[0072] In related technologies, nuclear power plants primarily use ultrasonic level gauges and float-type level gauges for liquid level detection. Ultrasonic level gauges employ non-contact measurement, measuring liquid level by emitting ultrasonic signals and receiving reflected signals, offering advantages such as convenient installation and maintenance. However, ultrasonic level gauges have the following problems in practical applications: First, due to the propagation characteristics of ultrasound, level gauges have a measurement blind zone, requiring the probe to be installed a certain distance above the blind zone, resulting in exposed installation, which not only affects aesthetics but also increases the risk of accidental contact. Second, when foam appears on the liquid surface, the ultrasonic signal is reflected from the foam layer, making it impossible to accurately measure the true liquid level and causing significant measurement deviations. Furthermore, in closed containers, when there is a significant temperature difference between the medium and the surrounding environment, condensation easily forms around the probe, further affecting measurement accuracy.

[0073] Float-type level gauges mainly consist of a float, a connecting rod, and an indicating device. They indicate the liquid level by the rise and fall of the float. Their structure is simple and the measurement is intuitive. However, this type of level gauge also has significant drawbacks: when the liquid fluctuates violently, the float will sway up and down, leading to unstable measurements; at the same time, the float surface is easily contaminated by the liquid, affecting the stability of buoyancy and thus reducing the accuracy and reliability of the measurement.

[0074] In summary, in the unique environment of nuclear power plants, various environmental factors such as liquid fluctuations and foaming can affect the measurement accuracy of existing level gauges. This is especially true when measuring special media such as waste liquids, where the uncertainty and variability of liquid density further complicate level detection. Therefore, existing technologies are insufficient to meet the accuracy requirements for level detection in the safe operation of nuclear power plants, necessitating a novel level detection solution that overcomes these challenges.

[0075] Based on this, this application proposes a liquid level detection method for nuclear power plants. By installing multiple fiber optic pressure sensors on a fixed column, which is vertically mounted within the liquid storage cavity, continuous and stable monitoring of liquid pressure can be achieved, avoiding the measurement instability caused by liquid surface fluctuations in float-type liquid level gauges. Then, based on the collected pressure data, air pressure data and hydraulic pressure data are distinguished, thus avoiding the influence of liquid surface foam and overcoming the measurement deviation caused by foam interference in ultrasonic liquid level gauges. Next, by using air pressure data to correct the hydraulic pressure data, the influence of air pressure changes within the liquid storage cavity on liquid level measurement can be effectively eliminated, achieving accurate acquisition of the actual hydraulic pressure. Finally, based on the corrected hydraulic pressure data, the liquid level height within the liquid storage cavity can be accurately calculated. This calculation process is unaffected by liquid fluctuations and foam, thus achieving precise liquid level measurement. Compared with existing float-type level gauges that are susceptible to liquid level fluctuations and ultrasonic level gauges that are susceptible to foam interference, the method provided in this application is based on fiber optic pressure sensing and air pressure correction mechanism, which can effectively overcome measurement interference caused by the special application environment of nuclear power plants and improve the accuracy of liquid level detection in nuclear power plants.

[0076] The method for detecting liquid levels in nuclear power plants proposed in this application will be explained in detail below.

[0077] Please see Figure 1 This invention provides a method for detecting liquid level in a nuclear power plant. The method is applied to a liquid level detection system in a nuclear power plant. The liquid level detection system includes a liquid level detection device and a liquid storage cavity. The liquid level detection device includes a fixed column, with an optical fiber pressure sensor installed at each end of the fixed column. Multiple optical fiber pressure sensors are installed between the two optical fiber pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. The method may include, but is not limited to, the following steps 101 to 104:

[0078] Step 101: Multiple pressure data are collected using multiple fiber optic pressure sensors.

[0079] Step 102: Among the multiple pressure data, determine at least one air pressure data and at least one hydraulic data.

[0080] Step 103: Correct the hydraulic data based on the air pressure data to obtain the corrected hydraulic data.

[0081] Step 104: Determine the liquid level height in the storage chamber based on the corrected hydraulic data.

[0082] Through steps 101 to 104, this embodiment of the application, by setting multiple fiber optic pressure sensors on a fixed column and vertically installing the fixed column within the liquid storage cavity, achieves continuous and stable monitoring of liquid pressure, avoiding the measurement instability problem caused by liquid surface fluctuations in float-type level gauges. Then, based on the collected pressure data, air pressure data and hydraulic pressure data are distinguished, thus avoiding the influence of liquid surface foam and overcoming the measurement deviation caused by foam interference in ultrasonic level gauges. Next, by using air pressure data to correct the hydraulic pressure data, the influence of air pressure changes within the liquid storage cavity on the liquid level measurement can be effectively eliminated, achieving accurate acquisition of the true hydraulic pressure. Finally, based on the corrected hydraulic pressure data, the liquid level height within the storage cavity can be accurately calculated. This calculation process is unaffected by liquid fluctuations and foam, thereby achieving precise liquid level measurement. Compared with existing float-type level gauges that are susceptible to liquid level fluctuations and ultrasonic level gauges that are susceptible to foam interference, the method provided in this application is based on fiber optic pressure sensing and air pressure correction mechanism, which can effectively overcome measurement interference caused by the special application environment of nuclear power plants and improve the accuracy of liquid level detection in nuclear power plants.

[0083] In step 101 of some embodiments, multiple fiber optic pressure sensors evenly arranged on the fixed column can collect pressure data at different heights within the liquid storage cavity in real time. Each fiber optic pressure sensor integrates an optical cavity pressure-sensing element. When pressure exists at the location of the fiber optic pressure sensor, the pressure acts on the optical cavity pressure-sensing element, causing deformation of the optical cavity. By detecting the change in the reflected light signal caused by this deformation, the pressure data at that location can be obtained. Since the multiple fiber optic pressure sensors are vertically distributed on the fixed column, pressure data at different heights within the liquid storage cavity can be acquired simultaneously.

[0084] Please see Figure 2 In some embodiments, step 101 may include, but is not limited to, steps 201 to 203.

[0085] Step 201: Transmit incident light signals to multiple fiber optic pressure sensors to obtain reflected light signals from the multiple fiber optic pressure sensors.

[0086] Step 202: Perform spectral separation on each reflected light signal to obtain multiple monochromatic light wavelength signals.

[0087] Step 203: Perform waveform fitting and optical path phase demodulation on each monochromatic light wavelength signal to obtain pressure data.

[0088] In step 201 of some embodiments, the demodulator can control the transmission of the incident light signal via optical fiber to each fiber optic pressure sensor, where it is reflected by the optical cavity pressure-sensing element inside the fiber optic pressure sensor. When the optical cavity pressure-sensing element is subjected to ambient pressure, it deforms, and this deformation changes the characteristics of the reflected light signal. Therefore, by acquiring the returned reflected light signal, the pressure information of the environment in which the optical cavity pressure-sensing element is located can be obtained.

[0089] Please see Figure 3 In some embodiments, the fiber optic pressure sensor includes an optical cavity pressure sensing element and a temperature sensing grating element, and the reflected light signal includes an optical cavity reflection signal and a grating reflection signal. After step 201, it may also include, but is not limited to, steps 301 to 303.

[0090] Step 301: Obtain the grating reflection signal through the temperature measuring grating element.

[0091] Step 302: Demodulate the grating reflection signal to obtain the target temperature data.

[0092] Step 303: Correct the pressure data based on the target temperature data to obtain the corrected pressure data.

[0093] In step 301 of some embodiments, after the incident light signal reaches the temperature-sensing grating element through the optical fiber, Bragg reflection occurs at a specific wavelength due to the periodic structure of the grating. This reflected light signal carries temperature information about the environment in which the temperature-sensing grating element is located. When the ambient temperature changes, it causes a change in the grating period, resulting in a shift in the center wavelength of the reflected light signal.

[0094] In step 302 of some embodiments, after receiving the grating reflection signal, the demodulator first filters the signal to remove noise. Then, it calculates the center wavelength shift of the grating reflection signal using a wavelength demodulation algorithm. Since there is a linear relationship between the wavelength shift of the grating and temperature change, the wavelength shift can be converted into actual temperature data based on a pre-calibrated temperature coefficient.

[0095] In step 303 of some embodiments, since the pressure response characteristics of the optical cavity pressure sensing element change with temperature, temperature compensation is required for the measured pressure data. Specifically, based on the acquired target temperature data and the temperature-pressure cross-sensitivity coefficient of the fiber optic pressure sensor, the pressure measurement error caused by temperature change is calculated, and this error is subtracted from the original pressure data to obtain pressure data free from temperature effects.

[0096] Through steps 301 to 303, this embodiment achieves temperature compensation for pressure measurement. Because the optical cavity pressure-sensing element and the temperature-sensing grating element are integrated into the same fiber optic pressure sensor, pressure and temperature data can be acquired simultaneously, and temperature compensation can be performed in a timely manner, effectively improving the accuracy of pressure measurement. This design overcomes the shortcomings of traditional pressure sensors that are susceptible to temperature influences, making the measurement results more reliable.

[0097] In step 202 of some embodiments, since the reflected light signal contains multiple light signals of different wavelengths, these light signals need to be separated. The demodulator performs wavelength separation on the reflected light signal using a spectral analyzer to obtain multiple monochromatic light signals with different center wavelengths. There is a corresponding relationship between the wavelength variation of these monochromatic light signals and the deformation of the optical cavity pressure sensing element.

[0098] In step 203 of some embodiments, the demodulator uses a Gaussian fitting algorithm to fit the waveform of the monochromatic light wavelength signal to obtain the wavelength shift. Then, according to the optical path phase demodulation algorithm, the wavelength shift is converted into the deformation of the optical cavity. Finally, based on the calibration relationship between the optical cavity deformation and pressure, the actual pressure data is calculated.

[0099] Please see Figure 4 In some embodiments, step 203 may include, but is not limited to, steps 401 to 405.

[0100] Step 401: Peak identification is performed on the monochromatic waveform curve of each monochromatic light wavelength signal, and the monochromatic waveform curve is separated into multiple sub-waveform signals.

[0101] Step 402: Perform amplitude truncation processing on each sub-waveform signal to obtain multiple truncation-processed sub-waveform signals.

[0102] Step 403: Fit the sub-waveform signal after the amplitude truncation process to obtain multiple fitted sub-waveforms.

[0103] Step 404: Calculate the corresponding target displacement value based on the optical path phase difference of each fitted sub-waveform.

[0104] Step 405: Calculate the pressure data based on each target displacement value.

[0105] In step 401 of some embodiments, since the waveform curve of the monochromatic light wavelength signal contains multiple peaks and troughs, these feature points need to be identified first. By setting an appropriate threshold and search window, each peak point on the waveform curve can be accurately located. Based on the identified peak points, the complete monochromatic waveform curve is separated into multiple independent sub-waveform signals, each sub-waveform signal corresponding to a complete fluctuation cycle.

[0106] In step 402 of some embodiments, in order to eliminate the influence of environmental noise and interference signals on the waveform, it is necessary to perform amplitude clipping on the separated sub-waveform signals. Specifically, by setting upper and lower clipping thresholds, the amplitude of signals exceeding the threshold range is limited, resulting in noise-suppressed sub-waveform signals. This clipping process can improve the accuracy of subsequent waveform fitting.

[0107] In step 403 of some embodiments, a Gaussian fitting algorithm is used to fit the truncated sub-waveform signal. By iteratively optimizing the fitting parameters, the error between the fitted curve and the actual sub-waveform signal is minimized, thereby obtaining a smooth and continuous fitted sub-waveform. These fitted sub-waveforms can accurately reflect the deformation characteristics of the optical cavity pressure sensing element.

[0108] In step 404 of some embodiments, based on the fiber optic grating sensing principle, the deformation of the optical cavity causes a change in the optical path phase of the reflected light signal. By calculating the optical path phase difference of each fitted sub-waveform and combining it with the calibration coefficient of the fiber optic pressure sensor, the actual displacement value of the optical cavity pressure sensing element, i.e., the target displacement value, can be obtained.

[0109] In step 405 of some embodiments, based on the defined functional relationship between the displacement of the optical cavity pressure-sensing element and the applied pressure, the actual pressure data can be calculated according to the target displacement value obtained in the preceding steps, combined with the pressure response characteristics of the fiber optic pressure sensor. The pressure data obtained by this method has high accuracy and reliability.

[0110] Through steps 401 to 405 above, this embodiment realizes the conversion process from optical signal to pressure data. This process, through signal processing steps such as waveform separation, amplitude clipping, and curve fitting, effectively improves the measurement accuracy of fiber optic pressure sensing, providing a reliable pressure data foundation for subsequent liquid level calculation.

[0111] Through steps 201 to 203, this embodiment achieves accurate measurement of pressure at different heights within the liquid storage cavity. Specifically, the acquisition of emitted and reflected light signals is performed by a demodulator; pressure sensing and optical signal modulation by the optical cavity pressure-sensing element are accomplished by a fiber optic pressure sensor; and spectral separation and signal demodulation are performed by the signal processing unit of the demodulator. This fiber optic sensing-based pressure measurement method features resistance to electromagnetic interference and high sensitivity, ensuring the accuracy of pressure data.

[0112] In step 102 of some embodiments, since both liquid and air exist simultaneously within the reservoir, some fiber optic pressure sensors may be submerged below the liquid surface while others are exposed to air. Therefore, the acquired pressure data includes both pneumatic and hydraulic pressure data. This embodiment distinguishes between pneumatic and hydraulic pressure data by analyzing the magnitude and trend of multiple pressure data. Specifically, fiber optic pressure sensors above the liquid surface are only affected by air pressure, resulting in relatively small and similar pressure data, which is pneumatic pressure data. Fiber optic pressure sensors below the liquid surface are affected by both hydrostatic pressure and the air pressure above them, resulting in significantly greater pressure data than pneumatic pressure data, which increases with depth; this pressure data is hydraulic pressure data.

[0113] Please see Figure 5 In some embodiments, step 102 may include, but is not limited to, steps 501 to 503.

[0114] Step 501: Obtain multiple pressure data points and sort them.

[0115] Step 502: Determine the pressure data that meets the preset pressure characteristic conditions from among the multiple pressure data as pressure data.

[0116] Step 503: The pressure data that is greater than the air pressure data and increases with depth among the multiple pressure data will be identified as hydraulic data.

[0117] In step 501 of some embodiments, it is necessary to first acquire pressure data collected by multiple fiber optic pressure sensors and sort these data according to their numerical values. For example, suppose there are 5 fiber optic pressure sensors arranged sequentially from bottom to top on a fixed column, and the pressure data they collect are: 120 kPa, 118 kPa, 102 kPa, 85 kPa, and 85 kPa. In this case, these pressure data are sorted from smallest to largest as: 85 kPa, 85 kPa, 102 kPa, 118 kPa, and 120 kPa.

[0118] In step 502 of some embodiments, this embodiment identifies air pressure data by setting preset air pressure characteristic conditions. These preset air pressure characteristic conditions may include: pressure data values ​​being similar and the smallest possible value. Specifically, if the difference between multiple pressure data points is less than a preset threshold (e.g., 1 kPa), these data points can be determined to be air pressure data. In the example above, it can be observed that the pressure values ​​measured by the two uppermost sensors are both 85 kPa, which are the same and the smallest. Therefore, these two data points can be determined to be air pressure data, indicating that the liquid level is below the position of the third sensor.

[0119] In step 503 of some embodiments, this embodiment defines hydraulic data as data that is greater than the determined air pressure data and whose pressure value increases with depth. This is because, according to the principle of fluid statics, the pressure in a liquid increases linearly with depth. In the example above, the pressure values ​​measured by the third to fifth sensors are 102 kPa, 118 kPa, and 120 kPa, respectively, all greater than the air pressure value of 85 kPa, and show an increasing trend with depth. Therefore, these three data points can be identified as hydraulic data.

[0120] Through steps 501 to 503, this embodiment achieves accurate differentiation between pneumatic and hydraulic data. This identification method based on the magnitude and trend of pressure values ​​not only determines the liquid level position but also provides a reliable data foundation for subsequent pneumatic pressure correction and liquid level calculation. For example, in the above example, it can be preliminarily determined that the liquid level position is between the second and third sensors, providing a reference for subsequent accurate liquid level calculation.

[0121] In step 103 of some embodiments, considering that the air pressure inside the liquid storage cavity may differ from atmospheric pressure, this difference can affect the accuracy of the liquid level measurement. Therefore, this embodiment uses the acquired air pressure data to correct the hydraulic data. When the air pressure inside the liquid storage cavity is detected to be greater than atmospheric pressure, it indicates the presence of additional air pressure influence, and this additional air pressure influence needs to be subtracted from the hydraulic data to obtain the true hydraulic data.

[0122] Please see Figure 6 In some embodiments, step 103 may include, but is not limited to, steps 601 to 604.

[0123] Step 601: Determine the air pressure inside the liquid storage chamber based on the air pressure data.

[0124] Step 602: Compare the air pressure inside the liquid storage chamber with the atmospheric pressure.

[0125] Step 603: In response to the air pressure being greater than atmospheric pressure, calculate the pressure difference between the air pressure data and atmospheric pressure.

[0126] Step 604: Correct the hydraulic data based on the air pressure difference to obtain the corrected hydraulic data.

[0127] In step 601 of some embodiments, when multiple air pressure data are acquired, the actual air pressure inside the liquid storage cavity needs to be determined through data processing. Since the air pressure inside the liquid storage cavity is equal everywhere on the same horizontal plane, the multiple air pressure data can be averaged to eliminate the influence of measurement errors. For example, if the acquired multiple air pressure data are 105 kPa, 104 kPa, and 106 kPa, the actual air pressure inside the liquid storage cavity can be calculated to be 105 kPa.

[0128] In step 602 of some embodiments, the liquid storage chamber, being a sealed space, may experience changes in internal air pressure due to factors such as temperature variations and gas release. Therefore, it is necessary to compare the determined air pressure with standard atmospheric pressure (101.325 kPa). The purpose of this step is to determine whether the liquid storage chamber is under positive pressure, i.e., whether the internal air pressure is greater than the external atmospheric pressure. When the liquid storage chamber is under positive pressure, this pressure difference will affect the liquid level measurement.

[0129] In step 603 of some embodiments, if the air pressure inside the liquid storage chamber is detected to be greater than atmospheric pressure, the excess pressure difference needs to be calculated. Following the previous example, if the air pressure inside the liquid storage chamber is 105 kPa, then the pressure difference is 105 kPa - 101.325 kPa = 3.675 kPa. This difference represents the excess air pressure inside the liquid storage chamber, which will be superimposed on the hydrostatic pressure of the liquid and affect the liquid level measurement.

[0130] In step 604 of some embodiments, since the hydraulic data includes both hydrostatic pressure and overhead air pressure, it is necessary to remove the excess air pressure influence. Specifically, the air pressure difference is subtracted from the hydraulic data to obtain the true hydrostatic pressure data. For example, if the hydraulic data at a certain location is 150 kPa and the air pressure difference is 3.675 kPa, then the corrected hydraulic data is 146.325 kPa. This correction process is based on Pascal's principle, that is, fluid pressure is equal in magnitude in all directions and pressures can be added together.

[0131] Through steps 601 to 604, this embodiment achieves pneumatic correction of hydraulic data. This correction mechanism takes into account the special characteristics of the liquid storage chamber as a sealed space, effectively eliminating the influence of air pressure changes on liquid level measurement. Especially in the nuclear power plant environment, where process procedures may cause pressure changes within the liquid storage chamber, this pneumatic correction mechanism helps improve the accuracy of liquid level measurement.

[0132] In step 104 of some embodiments, after obtaining the corrected hydraulic data, this embodiment calculates the liquid level height based on the principle of hydrostatics. Since there is a definite functional relationship between the hydrostatic pressure and the liquid level height, the actual liquid level height in the storage cavity can be obtained by substituting the corrected hydraulic data into the calculation formula. This pressure-based liquid level measurement method is unaffected by factors such as liquid surface fluctuations and foam, ensuring the accuracy and stability of the measurement results.

[0133] Please see Figure 7 In some embodiments, step 104 may include, but is not limited to, steps 701 to 703.

[0134] Step 701: Obtain the liquid density of the liquid inside the storage chamber.

[0135] Step 702: Calculate the product of the liquid density and the gravitational acceleration constant.

[0136] Step 703: Divide the hydraulic data by the product of the liquid density value and the gravitational acceleration constant to calculate the liquid level height.

[0137] In step 701 of some embodiments, it is necessary to first obtain the density value of the liquid within the storage chamber. In nuclear power plant applications, different types of liquids have different density characteristics. For example, the density of pure water is approximately 1000 kg / m³, while the density of waste liquid containing impurities may be higher. Accurately obtaining the liquid density is crucial for subsequent liquid level calculations, as deviations in the density value directly affect the accuracy of the liquid level calculation.

[0138] In step 702 of some embodiments, based on the principles of hydrostatics, the relationship between the hydrostatic pressure of the liquid and the liquid level can be expressed by the formula P = ρgh, where ρ is the liquid density and g is the acceleration due to gravity (approximately 9.81 m / s²). Therefore, it is necessary to first calculate the product of the liquid density and the acceleration due to gravity, ρg. For example, for pure water with a density of 1000 kg / m³, the calculated ρg = 9810 N / m³. This product represents the pressure increment generated per unit height of liquid column.

[0139] In step 703 of some embodiments, the liquid level height is obtained by dividing the corrected hydraulic data by ρg according to the basic equations of hydrostatics. For example, if the corrected hydraulic data at a certain measuring point is 19620 Pa and the liquid density is 1000 kg / m³, the liquid level height at that point can be calculated as h = 19620 / (1000 × 9.81) = 2 m.

[0140] Through steps 701 to 703, this embodiment achieves the conversion from pressure data to liquid level height based on the principle of hydrostatics. The advantage of this method lies in its clear calculation principle and explicit physical meaning; as long as the liquid density value is accurately obtained, high-precision liquid level measurement can be achieved. Especially in the complex application environment of nuclear power plants, this pressure-based liquid level calculation method has strong adaptability and reliability.

[0141] Please see Figure 8 In some embodiments, when there are multiple hydraulic data, steps 801 to 805 may be included after step 701.

[0142] Step 801: The fiber optic pressure sensor located at the bottom of the liquid is designated as the main measuring point, and the remaining fiber optic pressure sensors in the liquid are designated as liquid level calibration points.

[0143] Step 802: Obtain the height difference between the main measuring point and each liquid level calibration point.

[0144] Step 803: Calculate the pressure difference between the hydraulic data corresponding to the main measuring point and the hydraulic data corresponding to each liquid level verification point.

[0145] Step 804: Calculate the actual liquid density value based on the height difference of each arrangement and the corresponding pressure difference, and update the liquid density based on the actual liquid density value.

[0146] Step 805: Recalculate the liquid level height based on the updated liquid density.

[0147] In step 801 of some embodiments, this embodiment determines the role of the measuring points by analyzing the distribution pattern of hydraulic data. Since the hydrostatic pressure of the liquid increases with depth, the fiber optic pressure sensor located at the bottom measures the highest pressure value, thus determining it as the primary measuring point. Other fiber optic pressure sensors located in the liquid, due to their higher positions, measure relatively lower pressure values, and are therefore designated as liquid level calibration points. This method of allocating measuring points fully utilizes the advantages of multi-point measurement.

[0148] In step 802 of some embodiments, the arrangement height difference refers to the vertical distance between the main measuring point and each liquid level calibration point. This height difference is a physical parameter determined during the installation of the fixed column. For example, if a sensor is installed every 20cm on the fixed column, the arrangement height difference between adjacent sensors is 20cm, the height difference with the second sensor is 40cm, and so on. These known arrangement height differences provide important reference for subsequent calculations.

[0149] In step 803 of some embodiments, it is necessary to calculate the pressure difference between the main measuring point and each liquid level calibration point. According to the principles of fluid statics, this pressure difference is precisely the hydrostatic pressure of the liquid due to the height difference. For example, if the pressure measured at the main measuring point is 150 kPa and the pressure measured at a certain liquid level calibration point is 130 kPa, then the pressure difference between them is 20 kPa. There is a definite functional relationship between this pressure difference and the arrangement height difference.

[0150] In step 804 of some embodiments, based on the pressure formula ΔP=ρgΔh, where ΔP is the pressure difference and Δh is the height difference, the actual density value of the liquid ρ=ΔP / (gΔh) can be derived. A more accurate density value can be obtained by calculating using data from multiple measurement points. For example, if the pressure difference between two measurement points is 20 kPa and the height difference is 2 m, the actual density of the liquid can be calculated to be 1020 kg / m³, which may differ from the initially preset density value.

[0151] In step 805 of some embodiments, the updated actual liquid density value is used to recalculate the liquid level height using the formula P = ρgh. This density correction mechanism based on multi-point measurement can effectively handle situations where the liquid density changes, ensuring the accuracy of the liquid level calculation. For example, when changes in the impurity content in the waste liquid lead to a change in density, this system can still maintain high measurement accuracy.

[0152] Through steps 801 to 805, this embodiment achieves real-time correction of liquid density and accurate calculation of liquid level. This method fully utilizes the advantages of multi-point measurement, overcoming the influence of liquid density changes on liquid level measurement by calculating the actual liquid density in real time, thus making the measurement results more reliable.

[0153] Please see Figure 9 This application also provides a nuclear power plant liquid level detection system 900, which can implement the above-mentioned nuclear power plant liquid level detection method, including:

[0154] The liquid level detection device 910 includes a fixed column 99, with an optical fiber pressure sensor installed at each end of the fixed column. Multiple optical fiber pressure sensors are installed between the two optical fiber pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity.

[0155] The host computer 920 is communicatively connected to the liquid level detection device 910. It is used to collect multiple pressure data through multiple fiber optic pressure sensors; among the multiple pressure data, at least one air pressure data and at least one hydraulic data are determined; the hydraulic data is corrected based on the air pressure data to obtain the corrected hydraulic data; and the liquid level height in the storage cavity is calculated based on the corrected hydraulic data.

[0156] Specifically, the nuclear power plant liquid level detection system 900 includes a liquid level detection device 910 and a host computer 920. The liquid level detection device 910 includes a fixed column 99, with a fiber optic pressure sensor installed at each end of the fixed column 99. To achieve multi-point measurement, multiple fiber optic pressure sensors are also installed between the two fiber optic pressure sensors at both ends of the fixed column. This evenly distributed multi-point arrangement allows the system to acquire pressure data at different heights within the liquid storage cavity. During installation, one end of the liquid level detection device 910 is fixed to the bottom of the liquid storage cavity, while the other end extends outside the liquid storage cavity. This ensures that the measurement range covers the entire liquid storage cavity and facilitates equipment installation and maintenance.

[0157] The host computer 920 communicates with the liquid level detection device 910 and is responsible for data acquisition and processing. Specifically, the functions of the host computer 920 include: firstly, acquiring multiple pressure data through multiple fiber optic pressure sensors; then, analyzing the magnitude and trend of these pressure data to determine at least one air pressure data and at least one hydraulic data; next, using the air pressure data to correct the hydraulic data, eliminating the influence of air pressure changes in the liquid storage cavity, and obtaining corrected hydraulic data; finally, based on the corrected hydraulic data, combined with parameters such as liquid density and gravitational acceleration, calculating the actual liquid level height in the liquid storage cavity.

[0158] Through this system architecture design, this embodiment achieves accurate measurement of the liquid level in the storage chamber of a nuclear power plant. The system employs a combination of multi-point pressure measurement and data correction, which can address changes in liquid density while eliminating the influence of air pressure, providing a reliable liquid level monitoring method for the safe operation of nuclear power plants. The specific implementation method is the same as the aforementioned nuclear power plant liquid level detection method, and will not be repeated here.

[0159] Please see Figure 10 In some embodiments, the fiber optic pressure sensor 1000 includes an optical cavity pressure-sensing element 1010 and a temperature-sensing grating element 1020; specifically, the optical cavity pressure-sensing element 1010 is mainly used for measuring pressure. Its working principle is that when external pressure acts on the optical cavity pressure-sensing element, it causes deformation of the optical cavity. This deformation changes the geometry of the optical cavity, thereby causing a change in the reflected light signal. By detecting this change in the light signal, the actual pressure value acting on the fiber optic pressure sensor can be determined.

[0160] The temperature-sensing grating element 1020 is mainly used for temperature measurement. Its core is a fiber Bragg grating. When the ambient temperature changes, it causes a change in the grating period, resulting in a shift in the center wavelength of the reflected light signal. By detecting this wavelength shift, the temperature value at the location of the fiber optic pressure sensor can be accurately obtained.

[0161] This design, which integrates pressure and temperature measurement functions into the same sensor, enables simultaneous measurement of pressure and temperature. Furthermore, the measured temperature data can be used to compensate for the pressure measurement, eliminating the impact of temperature changes on pressure measurement and thus improving measurement accuracy.

[0162] In some embodiments, the optical cavity pressure sensing element 1010 is an all-quartz thin film.

[0163] Specifically, the all-quartz thin film exhibits excellent elastic deformation characteristics; when subjected to external pressure, the film undergoes minute but measurable deformation. Due to the excellent elastic limit of quartz, this deformation fully recovers after the pressure is removed, ensuring the repeatability of sensor measurements. Simultaneously, quartz possesses extremely low creep characteristics, maintaining stable deformation even under prolonged pressure, which is crucial for achieving long-term stable pressure measurements.

[0164] Furthermore, all-quartz materials offer the following advantages: First, their low coefficient of thermal expansion reduces the impact of ambient temperature changes on pressure measurements; second, quartz exhibits excellent chemical stability, allowing it to withstand the complex media environment of nuclear power plants; and third, the all-quartz structure, being identical to optical fiber material, enables excellent optical coupling and reduces optical signal transmission loss. These characteristics make all-quartz thin films ideal sensing element materials for fiber optic pressure sensors.

[0165] According to the embodiments of this application, a liquid level detection method for nuclear power plants is applied to a liquid level detection system in a power plant. The liquid level detection system includes a liquid level detection device and a liquid storage cavity. The liquid level detection device includes a fixed column, with a fiber optic pressure sensor installed at each end of the fixed column. Multiple fiber optic pressure sensors are installed between the two fiber optic pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. The liquid level detection method includes: acquiring multiple pressure data through multiple fiber optic pressure sensors; determining at least one air pressure data and at least one hydraulic pressure data among the multiple pressure data; correcting the hydraulic pressure data based on the air pressure data to obtain corrected hydraulic pressure data; and determining the liquid level height in the liquid storage cavity based on the corrected hydraulic pressure data.

[0166] This application achieves continuous and stable monitoring of liquid pressure by installing multiple fiber optic pressure sensors on a fixed column, which is vertically mounted within the liquid storage cavity. This avoids the measurement instability caused by liquid surface fluctuations in float-type level gauges. Based on the collected pressure data, air pressure and hydraulic pressure data are distinguished, thus avoiding the influence of surface foam and overcoming the measurement deviation caused by foam interference in ultrasonic level gauges. Next, by using air pressure data to correct the hydraulic data, the influence of air pressure changes within the storage cavity on the liquid level measurement is effectively eliminated, achieving accurate acquisition of the true hydraulic pressure. Finally, based on the corrected hydraulic data, the liquid level height within the storage cavity can be accurately calculated. This calculation process is unaffected by liquid fluctuations and foam, thus achieving precise liquid level measurement. Compared to existing float-type level gauges, which are susceptible to liquid surface fluctuations, and ultrasonic level gauges, which are susceptible to foam interference, the method provided in this application, based on fiber optic pressure sensing and air pressure correction mechanisms, can effectively overcome measurement interference caused by the special application environment of nuclear power plants, improving the accuracy of liquid level detection in nuclear power plants.

[0167] Reference Figure 11 , Figure 11 The hardware structure of an electronic device according to another embodiment is illustrated. The electronic device includes:

[0168] The processor 1101 can be implemented using a general-purpose CPU (Central Processing Unit), microprocessor, application-specific integrated circuit (ASIC), or one or more integrated circuits, and is used to execute relevant programs to implement the technical solutions provided in the embodiments of this application.

[0169] The memory 1102 can be implemented as a read-only memory (ROM), static storage device, dynamic storage device, or random access memory (RAM). The memory 1102 can store the operating system and other application programs. When the technical solutions provided in the embodiments of this specification are implemented through software or firmware, the relevant program code is stored in the memory 1102 and called and executed by the processor 1101 to execute the nuclear power plant liquid level detection method of the embodiments of this application.

[0170] Input / output interface 1103 is used to implement information input and output;

[0171] The communication interface 1104 is used to enable communication and interaction between this device and other devices. Communication can be achieved through wired means (such as USB, network cable, etc.) or wireless means (such as mobile network, Wi-Fi, Bluetooth, etc.).

[0172] Bus 1105 transmits information between various components of the device (e.g., processor 1101, memory 1102, input / output interface 1103, and communication interface 1104);

[0173] The processor 1101, memory 1102, input / output interface 1103 and communication interface 1104 are connected to each other within the device via bus 1105.

[0174] This application also provides a computer program product, which includes a computer program. A processor of a computer device reads and executes the computer program, causing the computer device to perform the aforementioned nuclear power plant liquid level detection method.

[0175] The terms “first,” “second,” “third,” “fourth,” etc. (if present) in this disclosure and the foregoing drawings are used to distinguish similar objects and are not necessarily used to describe a particular order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented, for example, in orders other than those illustrated or described herein. Furthermore, the terms “comprising” and “including,” and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that includes a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatuses.

[0176] It should be understood that in this disclosure, "at least one item" means one or more, and "more than one" means two or more. "And / or" is used to describe the relationship between related objects, indicating that three relationships can exist. For example, "A and / or B" can represent: only A exists, only B exists, and both A and B exist simultaneously, where A and B can be singular or plural. The character " / " generally indicates that the preceding and following related objects are in an "or" relationship. "At least one of the following" or similar expressions refer to any combination of these items, including any combination of single or plural items. For example, at least one of a, b, or c can represent: a, b, c, "a and b", "a and c", "b and c", or "a and b and c", where a, b, and c can be single or multiple.

[0177] It should be understood that in the description of the embodiments of this application, "multiple" means two or more, "greater than", "less than", "exceeding" etc. are understood to exclude the number itself, and "above", "below", "within" etc. are understood to include the number itself.

[0178] In the several embodiments provided in this disclosure, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be through some interfaces, indirect coupling or communication connection between apparatuses or units, and may be electrical, mechanical, or other forms.

[0179] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of this embodiment according to actual needs.

[0180] Furthermore, the functional units in the various embodiments of this disclosure can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0181] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this disclosure, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this disclosure. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0182] It should also be understood that the various implementation methods provided in this application can be combined arbitrarily to achieve different technical effects.

[0183] The above is a detailed description of the embodiments of this disclosure. However, this disclosure is not limited to the above embodiments. Those skilled in the art can make various equivalent modifications or substitutions without departing from the spirit of this disclosure. All such equivalent modifications or substitutions are included within the scope defined by the claims of this disclosure.

Claims

1. A method for detecting liquid level in a nuclear power plant, characterized in that, The method is applied to a liquid level detection system in a nuclear power plant. The liquid level detection system includes a liquid level detection device and a liquid storage cavity. The liquid level detection device includes a fixed column, with a fiber optic pressure sensor installed at each end of the fixed column. Multiple fiber optic pressure sensors are installed between the two fiber optic pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. The liquid level detection method includes: Multiple pressure data were collected using multiple fiber optic pressure sensors; Among multiple pressure data, identify at least one air pressure data and at least one hydraulic pressure data; The hydraulic data is corrected based on the air pressure data to obtain corrected hydraulic data, including: determining the air pressure in the reservoir cavity based on the air pressure data; wherein, when there are multiple air pressure data, the multiple air pressure data are averaged to determine the air pressure in the reservoir cavity; comparing the air pressure in the reservoir cavity with atmospheric pressure; in response to the air pressure being greater than atmospheric pressure, calculating the air pressure difference between the air pressure data and atmospheric pressure; and correcting the hydraulic data based on the air pressure difference to obtain corrected hydraulic data. Determining the liquid level height in the storage cavity based on the corrected hydraulic data includes: acquiring the liquid density of the liquid in the storage cavity; calculating the product of the liquid density and the gravitational acceleration constant; dividing the hydraulic data by the product of the liquid density value and the gravitational acceleration constant to calculate the liquid level height; and, when there are multiple hydraulic data points, further including: determining the fiber optic pressure sensor located at the bottom of the liquid as the main measuring point, and determining the remaining fiber optic pressure sensors in the liquid as liquid level calibration points; acquiring the arrangement height difference between the main measuring point and each liquid level calibration point; calculating the pressure difference between the hydraulic data corresponding to the main measuring point and the hydraulic data corresponding to each liquid level calibration point; calculating the actual liquid density value based on each arrangement height difference and the corresponding pressure difference; updating the liquid density based on the actual liquid density value; and recalculating the liquid level height based on the updated liquid density.

2. The method for detecting liquid level in a nuclear power plant according to claim 1, characterized in that, The multiple pressure data acquired through multiple fiber optic pressure sensors specifically include: An incident light signal is emitted to multiple fiber optic pressure sensors to obtain the reflected light signals from the multiple fiber optic pressure sensors. Each of the reflected light signals is subjected to spectral separation to obtain multiple monochromatic light wavelength signals; The pressure data is obtained by performing waveform fitting and optical path phase demodulation on each of the monochromatic light wavelength signals.

3. The method for detecting liquid level in a nuclear power plant according to claim 2, characterized in that, The step of performing waveform fitting and optical path phase demodulation on each of the monochromatic light wavelength signals to obtain the pressure data includes: Peak identification is performed on the monochromatic waveform curve of each monochromatic light wavelength signal, and the monochromatic waveform curve is separated into multiple sub-waveform signals; Each of the sub-waveform signals is subjected to amplitude truncation processing to obtain multiple amplitude-truncation processed sub-waveform signals; The truncated sub-waveform signal is fitted to obtain multiple fitted sub-waveforms; Calculate the corresponding target displacement value based on the optical path phase difference of each fitted sub-waveform; The pressure data is calculated based on each of the target displacement values.

4. The method for detecting liquid level in a nuclear power plant according to claim 2, characterized in that, The fiber optic pressure sensor includes an optical cavity pressure-sensing element and a temperature-sensing grating element. The reflected light signal includes an optical cavity reflection signal and a grating reflection signal. After transmitting an incident light signal to the plurality of fiber optic pressure sensors to obtain the reflected light signals from the plurality of fiber optic pressure sensors, the sensor further includes: The reflected signal of the grating is obtained through the temperature-sensing grating element; The grating reflection signal is demodulated to obtain the target temperature data; The pressure data is corrected based on the target temperature data to obtain the corrected pressure data.

5. The method for detecting liquid level in a nuclear power plant according to claim 1, characterized in that, The step of determining at least one air pressure data point and at least one hydraulic pressure data point from multiple pressure data points includes: Acquire multiple pressure data points and sort the multiple pressure data points; The pressure data that meets the preset air pressure characteristic conditions among multiple pressure data is determined as the air pressure data; The hydraulic data will be determined from among multiple pressure data that are greater than the air pressure data and increase with depth.

6. A liquid level detection system for a nuclear power plant, characterized in that, include: A liquid level detection device and a liquid storage cavity are provided. The liquid level detection device includes a fixed column, and an optical fiber pressure sensor is respectively provided at both ends of the fixed column. Multiple optical fiber pressure sensors are provided between the two optical fiber pressure sensors at both ends of the fixed column. One end of the liquid level detection device is fixed to the bottom of the liquid storage cavity, and the other end extends out of the liquid storage cavity. A host computer is communicatively connected to the liquid level detection device and is used to collect multiple pressure data through multiple fiber optic pressure sensors; among the multiple pressure data, at least one air pressure data and at least one hydraulic pressure data are identified. Correcting the hydraulic data based on the air pressure data to obtain corrected hydraulic data includes: determining the air pressure within the reservoir cavity based on the air pressure data; wherein, when there are multiple air pressure data points, averaging the multiple air pressure data points to determine the air pressure within the reservoir cavity; comparing the air pressure within the reservoir cavity with atmospheric pressure; calculating the pressure difference between the air pressure data and atmospheric pressure in response to the air pressure being greater than atmospheric pressure; correcting the hydraulic data based on the pressure difference to obtain corrected hydraulic data; and calculating the liquid level height within the reservoir cavity based on the corrected hydraulic data, including: obtaining the liquid density of the liquid within the reservoir cavity; and calculating the relationship between the liquid density and gravitational acceleration. The product of the pressure constant and the liquid density value is used to calculate the liquid level height. Furthermore, when there are multiple hydraulic data points, the method further includes: determining the fiber optic pressure sensor located at the bottom of the liquid as the main measuring point, and determining the remaining fiber optic pressure sensors in the liquid as liquid level calibration points; obtaining the arrangement height difference between the main measuring point and each liquid level calibration point; calculating the pressure difference between the hydraulic data corresponding to the main measuring point and the hydraulic data corresponding to each liquid level calibration point; calculating the actual liquid density value based on each arrangement height difference and the corresponding pressure difference; updating the liquid density based on the actual liquid density value; and recalculating the liquid level height based on the updated liquid density.

7. The nuclear power plant liquid level detection system according to claim 6, characterized in that, The fiber optic pressure sensor includes an optical cavity pressure-sensing element and a temperature-sensing grating element; the optical cavity pressure-sensing element is used to measure pressure, and the temperature-sensing grating element is used to measure temperature.

8. The nuclear power plant liquid level detection system according to claim 7, characterized in that, The optical cavity pressure sensing element is an all-quartz thin film.

9. An electronic device, characterized in that, include: The device includes a memory and a processor, wherein the memory stores a computer program, and the processor executes the computer program to implement the nuclear power plant liquid level detection method as described in any one of claims 1 to 5.

10. A computer-readable storage medium, characterized in that, The storage medium stores a program that is executed by a processor to implement the nuclear power plant liquid level detection method as described in any one of claims 1 to 5.

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