A photovoltaic module fault operation and maintenance method, device and equipment

Abstract

The application discloses a photovoltaic module fault operation and maintenance method, device and equipment, the photovoltaic module fault operation and maintenance method includes S1: collecting the visible light image and infrared thermal image of photovoltaic module;S2: according to infrared thermal image and visible light image respectively on photovoltaic module is carried out fault identification, obtains preliminary fault detection result;S3: according to preliminary fault detection result, determine selected photovoltaic module and non-selected photovoltaic module, and the fault handling priority of each photovoltaic module;S4: according to fault handling priority to each selected photovoltaic module carries out secondary fault detection, obtains secondary fault detection result;Secondary fault detection at least includes EL test;S5: according to secondary fault detection result, generates the maintenance strategy corresponding to each selected photovoltaic module.The application reduces the cost of high-precision detection of photovoltaic module faults on the basis of ensuring the accuracy and reliability of photovoltaic module fault detection, thereby greatly reducing the operation and maintenance cost of photovoltaic power station.

Description

Technical Field

[0001] This invention relates to the field of photovoltaic module operation and maintenance technology, and in particular to a photovoltaic module fault operation and maintenance method, apparatus and equipment. Background Technology

[0002] China's cumulative installed photovoltaic (PV) capacity has continued to grow since exceeding 140 million kilowatts in 2018. By 2025, the scale of existing power plants will cover both early centralized power plants and distributed projects, forming a pattern of "centralized + distributed" coexistence. Globally, existing PV power plants account for more than 50%, with China contributing nearly one-third of the global installed capacity. Modules from early power plants put into operation around 2010 have been running for more than 15 years, facing issues such as power degradation and material aging, leading to a year-on-year increase in operation and maintenance costs. Therefore, accurate fault location is a primary task in the future operation and maintenance technology of PV power plants.

[0003] Among existing fault detection methods, EL imaging detection technology based on the principle of crystalline silicon electroluminescence can detect microcracks, fragments, poor soldering, broken grids, etc. in photovoltaic cells, enabling deeper defect detection inside photovoltaic modules. Through IV detection, power attenuation testing, infrared imaging, and other methods, abnormal module power generation efficiency and local overheating problems can be evaluated, assisting in the judgment of encapsulation defects or cell damage. Visible light image recognition technology can be used to achieve automated detection of defects such as cracks and uneven color, improving detection efficiency and gradually replacing some manual operations.

[0004] High-precision equipment such as EL detectors require highly experienced and skilled inspectors. The high cost of using new equipment and diagnosing complex defects makes it difficult to widely deploy to regular inspectors. Infrared imaging and visible light image recognition technologies can only determine photovoltaic module faults from their appearance, and their detection results are insufficient compared to EL detectors.

[0005] Therefore, improving the accuracy of fault detection while minimizing the cost of fault detection is of great significance for the fault operation and maintenance of photovoltaic modules in photovoltaic power plants. Summary of the Invention

[0006] The purpose of this invention is to provide a method, apparatus, and equipment for the fault operation and maintenance of photovoltaic modules, which can improve the accuracy of fault detection while minimizing the cost of fault detection, thereby reducing the cost of fault operation and maintenance of photovoltaic modules.

[0007] To address the aforementioned technical problems, this invention provides a photovoltaic module fault operation and maintenance method, comprising:

[0008] S1: Acquire visible light and infrared thermal images of photovoltaic modules;

[0009] S2: Based on the infrared thermal image and the visible light image, the photovoltaic module is fault identified to obtain preliminary fault detection results;

[0010] S3: Based on the preliminary fault detection results, determine the selected photovoltaic modules and non-selected photovoltaic modules, and the fault handling priority of each photovoltaic module;

[0011] S4: Perform secondary fault detection on each of the selected photovoltaic modules to obtain secondary fault detection results; the secondary fault detection includes at least EL testing.

[0012] S5: Based on the secondary fault detection results, generate maintenance strategies corresponding to each selected photovoltaic module.

[0013] In an optional embodiment of this application, S3 includes:

[0014] S32: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level two;

[0015] S33: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault but there is an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level three;

[0016] S34: If the preliminary fault detection result of the photovoltaic module is that there is glass breakage and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module, and the fault handling priority is level four, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0017] S35: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and there is no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level five, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0018] S36: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault and no infrared light spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level six, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0019] S37: Determine the maintenance priority of each non-selected photovoltaic module and the secondary fault detection priority of each selected photovoltaic module in descending order of the fault handling priority from level one to level six.

[0020] In an optional embodiment of this application, when the non-selected photovoltaic module has a fault handling priority of level four, the maintenance strategy for the non-selected photovoltaic module is determined to be repair and periodic monitoring.

[0021] When the non-selected photovoltaic module has a fault handling priority of level five, the maintenance strategy for the non-selected photovoltaic module is determined to be shading removal; the shading removal includes at least one of cleaning, removing obstructions, or moving the module.

[0022] When the non-selected photovoltaic module has a fault handling priority of level six, or when the non-selected photovoltaic module has a fault handling priority of no need to handle.

[0023] In an optional embodiment of this application, S4 includes:

[0024] S41: Perform EL testing on the faulty cells in the hot spot area of ​​the selected photovoltaic module according to the fault handling priority, and obtain the EL test results corresponding to each faulty cell;

[0025] S42: Based on the EL test results, determine the safety operation and maintenance coefficient that characterizes the probability of safety hazards occurring in the selected photovoltaic module;

[0026] S43: Perform IV detection on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to the first set coefficient threshold to obtain the module degradation rate of the selected photovoltaic modules, and use the safety operation and maintenance coefficient and the module degradation rate as the secondary fault detection result of the selected photovoltaic modules.

[0027] In an optional embodiment of this application, S42 includes:

[0028] S421: Based on the EL test results, determine the fault safety impact coefficient corresponding to each faulty battery cell;

[0029] S422: Based on the safety operation and maintenance coefficient formula Determine the security operation and maintenance coefficient; wherein, The security operation and maintenance coefficient is... For the first The failure safety impact coefficient of the faulty battery cell; The total number of faulty cells on the same selected photovoltaic module; The probability of failure of the faulty battery cell is given by the following condition: , This is a constant coefficient for seasonal fires; This represents the probability of a fire. , This is the highest temperature of the hot spot at present; This is the critical temperature of the hot spot. This is a constant coefficient sensitive to fire temperature.

[0030] In an optional embodiment of this application, S421 includes:

[0031] S4211: If the EL test result of the faulty battery cell is that there is a local dark spot fault and / or a whole cell dark fault and / or a slight fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the first coefficient.

[0032] S4212: If the EL test result of the faulty battery cell is that there is a black edge fault and / or a back panel scratch fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the second coefficient.

[0033] S4213: If the EL test result of the faulty battery cell is that there is a medium fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the third coefficient.

[0034] S4214: If the EL test result of the faulty battery cell is that there is a black spot fault and / or a bright spot fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the fourth coefficient.

[0035] S4215: If the EL test result of the faulty battery cell is that there is a serious fragmentation fault and / or diode breakdown fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the fifth coefficient.

[0036] The first coefficient, the second coefficient, the third coefficient, the fourth coefficient, and the fifth coefficient increase sequentially.

[0037] In an optional embodiment of this application, S43 includes:

[0038] IV detection is performed on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to a first set coefficient threshold to obtain the module degradation rate;

[0039] Accordingly, S5 includes:

[0040] S51: When the safety operation and maintenance coefficient of the selected photovoltaic module is less than the first set coefficient threshold, the selected photovoltaic module is a Class D fault module, and the maintenance strategy is determined to be no action.

[0041] S52: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than the second set coefficient threshold, and the module attenuation rate is less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class C fault module, and the maintenance strategy is determined to be regular tracking and observation.

[0042] S53: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to the second set coefficient threshold, and the module attenuation rate is not less than the attenuation rate threshold, then the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module.

[0043] S54: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module attenuation rate is less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module.

[0044] S55: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module attenuation rate is not less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class A fault module, and the maintenance strategy is to recommend immediate replacement of the module.

[0045] In an optional embodiment of this application, when the selected photovoltaic module is determined to be a Class B or Class A fault module, the method further includes:

[0046] S501: Based on the initial annual power generation of the selected photovoltaic module, the module degradation rate, and the formula for the annual power generation loss value. Determine the current power generation loss value; among which, This represents the current power generation loss value. This refers to the initial annual power generation. The component attenuation rate;

[0047] S502: Based on the current power generation loss value, local annual equivalent hours, initial power, replacement module power, and the module replacement energy efficiency enhancement formula. ;in, Adding value to energy-efficient components The initial power, For the power of the replaced component, The local annual equivalent number of hours;

[0048] S503: Determine the annual return on investment (ROI) based on the energy efficiency gain from component replacement, the total cost of replacing a single component, and the annual ROI formula; wherein, Wherein, ROI is the annual return on investment, R is the local electricity price, and C is the total cost of replacing the single component.

[0049] A photovoltaic module fault operation and maintenance device, comprising:

[0050] The image acquisition module is used to acquire visible light and infrared thermal images of photovoltaic modules;

[0051] The preliminary detection module is used to identify faults in the photovoltaic module based on the infrared thermal image and the visible light image, respectively, and obtain preliminary fault detection results.

[0052] The component screening module is used to determine selected and non-selected photovoltaic modules and the fault handling priority of each photovoltaic module based on the preliminary fault detection results.

[0053] A secondary detection module is used to perform secondary fault detection on each of the selected photovoltaic modules and obtain secondary fault detection results; the secondary fault detection includes at least EL testing.

[0054] The strategy determination module is used to generate maintenance strategies corresponding to each selected photovoltaic module based on the secondary fault detection results.

[0055] A photovoltaic module fault operation and maintenance device, comprising:

[0056] Memory, used to store computer programs;

[0057] A processor is configured to execute the computer program to implement the steps of the photovoltaic module fault operation and maintenance method as described in any of the preceding claims.

[0058] This invention provides a photovoltaic module fault operation and maintenance method, apparatus, and equipment. The photovoltaic module fault operation and maintenance method includes: S1: acquiring visible light images and infrared thermal images of the photovoltaic module; S2: performing fault identification on the photovoltaic module based on the infrared thermal images and visible light images respectively, and obtaining preliminary fault detection results; S3: determining selected photovoltaic modules and non-selected photovoltaic modules, and the fault handling priority of the selected photovoltaic modules based on the preliminary fault detection results; S4: performing secondary fault detection on each selected photovoltaic module according to the fault handling priority, and obtaining secondary fault detection results; the secondary fault detection includes at least EL testing; S5: generating corresponding maintenance strategies for each selected photovoltaic module based on the secondary fault detection results.

[0059] This application acquires dual-light images (infrared thermal and visible light) of photovoltaic modules and uses these images to initially identify and screen for fault conditions. This process identifies selected photovoltaic modules requiring secondary fault detection, such as EL testing. Based on different fault conditions, the application prioritizes the secondary fault detection for each selected module, enabling more efficient EL testing and other inspections on faulty modules. This ensures accurate and reliable fault detection while minimizing the number of photovoltaic modules requiring EL testing, thereby reducing the cost of high-precision fault detection and significantly lowering the operation and maintenance costs of photovoltaic power plants. Attached Figure Description

[0060] To more clearly illustrate the technical solutions of the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0061] Figure 1 A flowchart illustrating the photovoltaic module fault operation and maintenance method provided in this application embodiment;

[0062] Figure 2 An EL image of a normal photovoltaic module;

[0063] Figure 3 EL image of the first type of fault in a photovoltaic module;

[0064] Figure 4 EL image of a second type of fault in a photovoltaic module;

[0065] Figure 5 EL image of the third type of fault in a photovoltaic module;

[0066] Figure 6 EL image of the fourth type of fault in a photovoltaic module;

[0067] Figure 7 EL image of the fifth type of fault in photovoltaic modules;

[0068] Figure 8 EL image of the sixth type of failure in photovoltaic modules;

[0069] Figure 9 EL image of the seventh type of fault in photovoltaic modules;

[0070] Figure 10 This is a structural block diagram of the photovoltaic module fault operation and maintenance device provided in the embodiments of this application. Detailed Implementation

[0071] The core of this invention is to provide a method, apparatus, and equipment for the operation and maintenance of photovoltaic modules, which can reduce the operation and maintenance costs of photovoltaic power plants while ensuring more accurate detection of photovoltaic module faults.

[0072] To enable those skilled in the art to better understand the present invention, the invention will be further described in detail below with reference to the accompanying drawings and specific embodiments. Obviously, the described embodiments are merely some embodiments of the present invention, and not all embodiments. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without creative effort are within the scope of protection of the present invention.

[0073] like Figure 1 As shown, Figure 1 This is a flowchart illustrating the photovoltaic module fault operation and maintenance method provided in the embodiments of this application.

[0074] In one specific embodiment of this application, the fault operation and maintenance method for the photovoltaic module may include:

[0075] S1: Acquire visible light and infrared thermal images of photovoltaic modules.

[0076] In this embodiment, the visible light and infrared thermal images of the photovoltaic modules can be obtained by a drone equipped with a visible light camera and an infrared camera, flying above each photovoltaic module within the photovoltaic power station. Therefore, the visible light and infrared thermal images collected at the same time are clearly dual-light images of the same photovoltaic module.

[0077] In addition, the drone should be equipped with a positioning device. Based on the drone's positioning data when each set of visible light images and infrared thermal images are collected, it can be determined which photovoltaic module each set of visible light images and infrared thermal images corresponds to.

[0078] S2: Based on infrared thermal images and visible light images, the photovoltaic modules are fault identified to obtain preliminary fault detection results;

[0079] The preliminary fault detection results in this embodiment include infrared fault identification results obtained by infrared fault identification from infrared thermal images and visible light fault identification results obtained by image identification from visible light images.

[0080] Among them, infrared fault identification based on infrared thermal images can yield identification results including the presence of infrared hot spots and the absence of infrared hot spots.

[0081] In photovoltaic (PV) modules, the temperature of hotspot areas is significantly higher than that of normal areas. Therefore, based on the temperature distribution of different regions on a PV module in an infrared thermal image, hotspot problems can be identified. Based on the shape of the hotspots, infrared hotspots can be broadly categorized into conventional infrared hotspots and infrared diode hotspots. Infrared diode hotspots are elongated, strip-shaped hotspots, typically formed when a string of cells fails. Conventional infrared hotspots, on the other hand, are hotspots other than infrared diode hotspots, also known as non-infrared diode hotspots. These hotspots do not have a specific shape and can be caused by the heating of a single PV cell or by the heating of multiple adjacent PV cells. If neither conventional nor infrared diode hotspots are found in the PV module based on the infrared thermal image, the infrared fault identification result for the PV module is "no infrared hotspots." Conversely, if either conventional or infrared diode hotspots are found, the infrared fault identification result is "infrared hotspots present."

[0082] Visible light fault identification results obtained from visible light images include glass breakage faults, occlusion faults, and no visible light faults.

[0083] Glass breakage faults refer to the presence of cracks or breaks in the front glass of a photovoltaic module; shading faults refer to areas of obstruction on the glass surface of a photovoltaic module, such as those caused by dust, bird droppings, vegetation, or shadows from immovable objects. If, through the identification of visible light images, it can be determined that there are neither glass breakage faults nor shading faults on the photovoltaic module, then the visible light fault identification result for the photovoltaic module is "no visible light fault".

[0084] S3: Based on the preliminary fault detection results, select the photovoltaic modules that need to undergo secondary fault detection, and determine the fault handling priority for each selected photovoltaic module.

[0085] Based on the above discussion, the fault identification and analysis results of photovoltaic modules using infrared thermal images and visible light images can be combined and referenced to preliminarily determine the fault conditions existing on the photovoltaic modules.

[0086] For example, if a photovoltaic module has both a glass breakage fault and an infrared hot spot in the same area, it is highly likely that the hot spot area was impacted or collided, causing the glass breakage and photovoltaic cell failure. The photovoltaic cell needs further secondary fault detection to determine a more accurate fault condition. However, if a photovoltaic module has both a shading fault and an infrared hot spot in the same area, it can be determined that the photovoltaic cell in the hot spot area is mainly heating up due to shading. Obviously, it is only necessary to remove the shading in the hot spot area, without the need for secondary fault detection.

[0087] Based on this, the process of screening photovoltaic modules that require secondary fault detection and determining the fault handling priority of each photovoltaic module in step S3 of this embodiment may include:

[0088] S31: If the preliminary fault detection result of the photovoltaic module is that there is glass breakage and infrared light spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level one.

[0089] S32: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level two.

[0090] S33: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault but there is an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level three.

[0091] S34: If the preliminary fault detection result of the photovoltaic module is that there is glass breakage and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module, and the fault handling priority is level four, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0092] S35: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and there is no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level five, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0093] S36: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level six, and a maintenance strategy for the non-selected photovoltaic module is generated.

[0094] S37: Determine the maintenance priority of each non-selected photovoltaic module and the secondary fault detection priority of each selected photovoltaic module in descending order of priority from level one to level six.

[0095] In this embodiment, photovoltaic modules with obvious glass damage in the visible light image and infrared hot spots at the glass damage location in the corresponding infrared thermal image are identified as first-level selected photovoltaic modules. These first-level selected photovoltaic modules are generally caused by external impacts, resulting in damage to the internal cells or failure of internal diodes, leading to localized heating and the generation of hot spots, which affects the power generation performance of the module itself and poses a risk of fire. Further secondary testing is required.

[0096] Photovoltaic modules with shading faults in visible light images and corresponding infrared hot spots in infrared thermal images are identified as secondary selected photovoltaic modules. These secondary selected photovoltaic modules are mainly due to bird droppings, vegetation shading, improper on-site equipment handling, and shadows from fixed objects causing shading areas that reduce output power. The shading will be consumed as load. If the shading time is too long, it will cause local heat generation and hot spots, which will affect the power generation performance of the module itself and pose a fire risk. The shading area of ​​the module needs to be shaded to remove the shading, and the module's internal structure needs to be inspected again to see if permanent damage has been formed.

[0097] Photovoltaic modules that show no obvious abnormalities in visible light images but have infrared hot spots in their corresponding infrared thermal images are classified as Level 3 selected photovoltaic modules. The hot spots in these Level 3 selected photovoltaic modules may be caused by unclear reasons such as cell mismatch, short circuit, or poor soldering inside the module, and further secondary testing is required.

[0098] Secondary testing was conducted on selected photovoltaic modules classified as Level 1, Level 2, and Level 3. These modules were primarily affected by internal cell failures caused by natural environmental factors, during the welding process, external impacts during module handling, human damage, and prolonged shading. Different types of defects have different causes and affect the module's power generation performance differently. Furthermore, different defect types generate heat that interacts with each other, requiring further fault assessment for these modules.

[0099] Further optionally, when a non-selected photovoltaic module is used and the fault handling priority is level four, the maintenance strategy for the non-selected photovoltaic module is determined to be repair and periodic monitoring; when a non-selected photovoltaic module is used and the fault handling priority is level five, the maintenance strategy for the non-selected photovoltaic module is determined to be shading removal treatment, which may include at least one of cleaning treatment, shading removal treatment, or module relocation treatment; when a non-selected photovoltaic module is used and the fault handling priority is level six, the non-selected photovoltaic module is used and the fault handling priority is no treatment required.

[0100] In this embodiment, photovoltaic modules with visible light image damage and no obstruction and corresponding infrared thermal image without hot spots are classified as level four unselected photovoltaic modules. The failure of these level four unselected photovoltaic modules may be due to uneven external temperature or stress causing microcracks in the surface glass of the module, but without causing damage to the internal cells. If the cracks are small, they can be repaired. If they cannot be repaired but do not affect the power generation of the module, they can be observed periodically.

[0101] Photovoltaic modules with obvious shading in visible light images but no obvious damage on the surface, and no obvious hot spots in infrared thermal images, are classified as Level 5 unselected photovoltaic modules. The unselected photovoltaic modules in this level are due to shading caused by bird droppings, vegetation, improper on-site equipment handling, shadows from fixed objects, etc. The shading area is short and does not form hot spots, but if the shading time is too long, it will cause local heating and generate hot spots, which will affect the power generation performance of the photovoltaic module itself and pose a fire risk. The shading area of ​​the module needs to be removed.

[0102] Photovoltaic modules with no obvious abnormalities in visible light images and no hot spots in corresponding infrared thermal images are classified as level six non-selected photovoltaic modules and are not subject to further processing.

[0103] It should be noted that the above prioritization of photovoltaic (PV) module fault handling for infrared and visible light faults refers to whether both infrared and visible light faults exist in the same area of ​​the PV module. For example, if one area of ​​a PV module only has an infrared hotspot without glass breakage, but another area of ​​the PV module has glass breakage, then the PV module should be classified as a secondary selected PV module.

[0104] Furthermore, when multiple faults exist in different areas on the same photovoltaic module, the photovoltaic module is classified according to the highest fault handling priority. For example, if a photovoltaic module has a glass breakage fault and a conventional infrared hot spot in one hot spot area, while another hot spot area has an infrared diode hot spot, then the photovoltaic module should be classified as a first-level module.

[0105] Based on the above discussion, the priority of fault handling for each photovoltaic module in this application is not necessarily divided according to the above scheme. In an optional embodiment of this application, five weighted indicators can be set according to the possible fault types of photovoltaic modules: glass breakage, shading fault, no visible light abnormality, infrared hot spot, and no infrared hot spot; and the characteristic value corresponding to each fault indicator can be determined according to the severity of the impact of each fault type on the normal operation of the entire photovoltaic module. And thus determine the first-level weight index matrix. Then, the weight values ​​of each indicator are calculated using the chromatographic analysis method. The calculation formula is: ;in, As shown in Tables 1 and 2 below, Table 1 is an example table of the elements of the first-level weight index matrix, and the data in the table are the eigenvalues. Table 2 is a table showing the normalized first-level weight index matrix after normalizing the elements of the first-level weight index matrix in Table 1. It also includes the weights obtained based on the normalized weight index calculations. The data in Table 2 other than the weight indexes are the normalized eigenvalues. .

[0106] Table 1. First-level weight index matrix

[0107]

[0108] Table 2. Normalized First-Level Weight Index Matrix:

[0109]

[0110] Based on the weight index values ​​in Table 2 above, the fault handling priority of each photovoltaic module can be determined as shown in Table 3 below.

[0111] Table 3. Grading Table for Photovoltaic Module Fault Assessment:

[0112]

[0113] Based on the above discussion, in practical applications, each fault type can be assigned an indicator element representing the importance or severity of the fault according to different actual needs, thereby achieving a more reasonable division of fault handling priorities for each photovoltaic module.

[0114] S4: Perform secondary fault detection on each selected photovoltaic module according to the fault handling priority, and obtain the secondary fault detection results; the secondary fault detection includes at least EL testing.

[0115] After selecting photovoltaic modules based on the infrared thermal images and visible light images, EL testing can be performed on the selected photovoltaic modules with high fault handling priority according to the fault handling priority corresponding to the category to which each selected photovoltaic module belongs. This will further clarify the more specific fault conditions of the selected photovoltaic modules and determine a more accurate and reasonable maintenance strategy.

[0116] S5: Based on the secondary fault detection results, generate maintenance strategies for each selected photovoltaic module.

[0117] The secondary fault detection results in this embodiment mainly represent the severity of the photovoltaic module's fault. For photovoltaic cells that have been identified as having faults such as damage, there are currently no other repair methods besides replacement. Therefore, this application uses EL testing to conduct a deeper level of detection on faulty cells in the hot spot area of ​​the photovoltaic module, thereby determining whether the current fault severity of the photovoltaic module has reached the point where replacement is necessary, and providing more accurate and reliable data for the operation and maintenance of the photovoltaic module.

[0118] In summary, this application acquires dual-light images (infrared thermal and visible light) of photovoltaic modules and uses these dual-light images to initially identify and screen for fault conditions. This identifies the photovoltaic modules that require secondary fault detection, such as EL testing. Based on different fault conditions, the application prioritizes the secondary fault detection for each selected photovoltaic module, thereby ensuring more efficient EL testing and other detection for faulty photovoltaic modules. While ensuring the accuracy and reliability of photovoltaic module fault detection, the application minimizes the number of photovoltaic modules requiring EL testing and other detections, thus reducing the cost of high-precision fault detection and significantly lowering the operation and maintenance costs of photovoltaic power plants.

[0119] Based on the above discussion, in an optional embodiment of this application, the process of performing secondary fault detection on selected photovoltaic modules may further include:

[0120] S41: Perform EL testing on the faulty cells in the hot spot area of ​​the selected photovoltaic module according to the fault handling priority, and obtain the EL test results corresponding to each faulty cell.

[0121] S42: Based on the EL test results, determine the safety operation and maintenance coefficient, which characterizes the probability of safety hazards occurring in the selected photovoltaic modules;

[0122] S43: Perform IV testing on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to the first set coefficient threshold to obtain the module degradation rate of the selected photovoltaic modules. Use the safety operation and maintenance coefficient and the module degradation rate as the secondary fault detection results of the selected photovoltaic modules.

[0123] It is understood that the EL testing process performed in this embodiment is implemented using the EL detection technology commonly used in the photovoltaic industry. The specific testing method can be performed in accordance with the conventional EL testing process, which will not be described in detail in this application.

[0124] Based on this, various types of faults in the faulty solar cells can be identified using EL test results, such as... Figures 2 to 9 As shown, Figure 2 The image shown is an EL image of a perfectly normal photovoltaic module as revealed by EL testing; while... Figure 3 The EL image shown contains three consecutive adjacent photovoltaic cells with backsheet scratches; Figure 4 As shown, in Figure 4 The EL image shown indicates that photovoltaic cells exhibit dark spot defects at multiple different locations. For example... Figure 5 As shown, in Figure 5 In the EL image shown, there is a row of photovoltaic cells with diode breakdown and short circuit faults; as Figure 6 As shown, in Figure 6 The EL image shown shows a bright spot fault in the output photovoltaic cell; as... Figure 7 As shown, in Figure 7 The EL image shown illustrates a black border defect in the photovoltaic cell; as... Figure 8 As shown, in Figure 8 The EL images shown depict minor, moderate, and severe fragmentation faults in photovoltaic cells, respectively. Figure 9 As shown, in Figure 9 The EL image shown illustrates a black sheet fault in the photovoltaic cell.

[0125] Based on the different probabilities of different types of faults that may cause safety hazards as determined by the EL test results of selected photovoltaic modules, a safety operation and maintenance coefficient is determined to characterize the probability of safety hazards caused by each selected photovoltaic module.

[0126] Optionally, the process of determining the security operation and maintenance coefficient based on the EL test results may include:

[0127] S421: Based on the EL test results, determine the fault safety impact coefficient corresponding to each faulty cell;

[0128] S422: Based on the safety operation and maintenance coefficient formula Determine the safety operation and maintenance coefficient; among which, For safety and maintenance coefficient, For the first The failure safety impact coefficient of a faulty battery cell; The total number of faulty cells on the same selected photovoltaic module; Let be the probability of failure of a faulty solar cell, satisfying . , This is a constant coefficient for seasonal fires; This represents the probability of a fire. , This is the highest temperature of the hot spot at present; This is the critical temperature of the hot spot. Fire temperature sensitivity constant coefficient.

[0129] It should be noted that the fault safety impact coefficient in this embodiment refers to the degree of influence of the fault type of the faulty solar cell on causing faults such as fires in the selected photovoltaic module in which it is located. In practical applications, a corresponding fault safety impact coefficient can be pre-set for each possible fault type of the faulty photovoltaic cell. Therefore, after EL testing, the corresponding fault safety impact coefficient can be directly determined based on the EL test results of each faulty solar cell. Specifically, this can include:

[0130] S4211: If the EL test result of the faulty battery cell is that there is a local dark spot fault and / or a whole cell dark fault and / or a slight fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the first coefficient.

[0131] S4212: If the EL test result of the faulty battery cell is that there is a black edge fault and / or a back panel scratch fault, the fault safety impact coefficient corresponding to the faulty battery cell shall be the second coefficient.

[0132] S4213: If the EL test result of the faulty cell is that there is a medium fragmentation fault, the fault safety impact coefficient corresponding to the faulty cell shall be the third coefficient.

[0133] S4214: If the EL test result of the faulty battery cell is that there is a black spot fault and / or a bright spot fault, the fault safety impact coefficient corresponding to the faulty battery cell shall be the fourth coefficient.

[0134] S4215: If the EL test result of the faulty cell is that there is a serious fragmentation fault and / or diode breakdown fault, the fault safety impact coefficient corresponding to the faulty cell shall be the fifth coefficient.

[0135] Among them, the first coefficient, the second coefficient, the third coefficient, the fourth coefficient, and the fifth coefficient increase in that order.

[0136] Further optionally, the first coefficient, second coefficient, third coefficient, fourth coefficient and fifth coefficient in this embodiment can be 1, 2, 3, 4 and 5 respectively; of course, in practical applications, other parameter coefficients that increase sequentially can also be used, and this embodiment does not specifically limit this.

[0137] Based on this, the formula for the safety operation and maintenance coefficient corresponding to the selected photovoltaic modules is... In this context, Ev represents the scenario risk level, which can be determined based on the environment in which the photovoltaic power station is located.

[0138] and ,and As a seasonal fire coefficient, if the current photovoltaic power station is located in the south, and the current season is summer or autumn with high temperatures and strong irradiance, then fires are more likely to occur. The possible value is 1.2; if the current season is spring or winter, the temperature is low and humid, and the irradiance is low, then a fire is unlikely to occur. The possible value is 0.8.

[0139] also, The probability of fire and satisfying ,in To select the highest current hot spot temperature in the hot spot region on the photovoltaic module, it can be determined based on the currently measured infrared thermal image; is the critical temperature of the hot spot, which can be taken as 150°C. is the fire temperature sensitivity constant coefficient. Through fitting historical fire data, k = 0.02 can be taken.

[0140] It should be noted that due to defects such as hidden cracks and fragments, the internal resistance of the faulty solar cell increases or the current is imbalanced, forming a local high-resistance heating point. The temperature is concentrated at the center of the damaged area, and the current density at the defect increases abnormally. When the temperature in the hot spot area exceeds ‌, the EVA film of the faulty solar cell begins to decompose and release combustible gases, the fire risk increases significantly, and the probability of fire occurrence > 50%. That is, when the temperature T in the hot spot area ≤ 100°C, the possibility of fire is in the safe range and there is no fire risk; when the temperature in the hot spot area is 100°C < T ≤ 150°C, the possibility of fire is in the warning range and needs to be processed in time; when the temperature in the hot spot area is in the dangerous range of T > 150°C‌, the fire probability > 50%, and it needs to be processed immediately and monitored in real time to prevent fire occurrence. Based on this, in this embodiment, the difference between the current highest hot spot temperature and the critical hot spot temperature in the hot spot area is used to determine the fire probability, ensuring the reliability of the calculated fire probability.

[0141] On the basis of determining the safety operation and maintenance coefficient corresponding to each selected photovoltaic module, in this embodiment, the selected photovoltaic modules with a safety operation and maintenance coefficient greater than or equal to the first set coefficient threshold are further screened for IV testing to obtain the module attenuation rate of the selected photovoltaic module. The specific process of this IV testing is the same as the process of obtaining the attenuation rate of a photovoltaic module through the conventional IV testing of a photovoltaic module currently, and this is not elaborated in detail in this embodiment.

[0142] As described above, the safety operation and maintenance coefficient in this embodiment is a data representing the probability of a selected photovoltaic module causing a safety hazard. Obviously, the larger this data is, the greater the probability of a selected photovoltaic module causing a safety hazard. Therefore, in this embodiment, the selected photovoltaic modules with a larger safety operation and maintenance coefficient are further evaluated from the perspective of energy loss, that is, through multiple evaluation data in different dimensions, to more reasonably determine whether the selected photovoltaic module should be replaced.

[0143] Based on this, for the selected photovoltaic modules with a safety operation and maintenance coefficient less than or equal to the first set coefficient threshold, their secondary fault detection can only perform EL testing, and the corresponding secondary fault detection results only include the safety operation and maintenance coefficient.

[0144] For the selected photovoltaic modules with a safety operation and maintenance coefficient greater than or equal to the first set coefficient threshold, their secondary fault detection can include EL testing and IV testing, and the corresponding secondary fault detection results include both the safety operation and maintenance coefficient and the module attenuation rate.

[0145] Based on this, the process of determining the maintenance strategy based on the secondary fault detection results of the selected photovoltaic modules may include:

[0146] S51: When the safety operation and maintenance coefficient of the selected photovoltaic module is less than or equal to the first set coefficient threshold, the selected photovoltaic module is a Class D fault module, and the maintenance strategy is determined to be no action.

[0147] S52: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than the second set coefficient threshold, and the module degradation rate is less than the degradation rate threshold, the selected photovoltaic module is determined to be a Class C fault module, and the maintenance strategy is determined to be regular tracking and observation.

[0148] S53: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to the second set coefficient threshold, and the module attenuation rate is not less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module.

[0149] S54: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module degradation rate is less than the degradation rate threshold, the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module.

[0150] S55: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module attenuation rate is not less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class A fault module, and the maintenance strategy is to recommend immediate replacement of the module.

[0151] This embodiment fully utilizes data from two different dimensions—the safety operation and maintenance coefficient and the module degradation rate—for each selected photovoltaic module to classify whether the selected photovoltaic module needs replacement into four different categories: A, B, C, and D. A category faulty module indicates that the photovoltaic module is both unsafe and has severe energy efficiency loss, and should be replaced immediately. A category B photovoltaic module indicates that the selected photovoltaic module is unsafe but has relatively low energy efficiency loss, or the selected photovoltaic module has certain safety hazards but high energy efficiency loss, and should be replaced, but not urgently. A category C faulty module indicates that the selected photovoltaic module has low energy efficiency loss but still has certain safety hazards, and still has value for continued use, but its safety needs to be closely monitored. A category D faulty module indicates that although the selected photovoltaic module has hot spot faults, it is relatively safe and has relatively low energy efficiency loss, and its overall performance is acceptable, so it does not need to be replaced.

[0152] Therefore, this application uses data from two different dimensions—safe operation and maintenance coefficient and component degradation rate—to provide a more reasonable maintenance strategy for faulty photovoltaic modules.

[0153] Based on this, in order to provide more comprehensive data support for users on whether to replace components; in another optional embodiment of this application, when determining whether the selected photovoltaic module is a Class B or Class A fault module, the following may also be included:

[0154] S501: Based on the initial annual power generation of the selected photovoltaic modules, the module degradation rate, and the formula for the annual power generation loss value. Determine the current power generation loss value; among which, This represents the current power generation loss value. This represents the initial annual power generation. For component attenuation rate;

[0155] S502: Based on the current power generation loss value, local annual equivalent hours, initial power, replacement module power, and the module replacement energy efficiency enhancement formula. ;in, Adding value to energy-efficient components For initial power, To replace the component power, The equivalent number of hours per year in the local area;

[0156] S503: Determine the annual return on investment (ROI) based on the energy efficiency gain from component replacement, the total cost of replacing a single component, and the annual ROI formula; where, Where ROI is the annual return on investment, R is the local electricity price, and C is the total cost of replacing a single component.

[0157] Among them, the total cost of replacing a single component meets the requirements. ; These are the unit price of new components, installation and labor costs, and the residual value of old components.

[0158] In this embodiment, the annual return on investment for replacing the selected photovoltaic modules that are recommended for replacement or recommended for immediate replacement is determined. This is equivalent to providing a further reference for the selected photovoltaic modules with faults from an economic perspective, so that users can use this as a benchmark to make more reasonable actual maintenance strategies.

[0159] Based on the above discussion, this application first uses visible light images and infrared thermal images to initially screen all photovoltaic modules with hot spot faults, selecting a portion of photovoltaic modules that require secondary fault detection. Then, based on EL testing of all selected photovoltaic modules and the determination of the safe operation and maintenance coefficient based on the EL test, further targeted IV testing is performed only on selected photovoltaic modules with higher safe operation and maintenance coefficients, thereby obtaining data on both the safe operation and maintenance coefficient and the module degradation rate at different temperatures. Based on the fault category classification using these two dimensions of data (safe operation and maintenance coefficient and module degradation rate), the annual return on investment is calculated for selected photovoltaic modules recommended for replacement or immediate replacement. This provides more comprehensive data for the selected photovoltaic modules that need replacement, facilitating more rational maintenance decisions by users.

[0160] The photovoltaic module fault operation and maintenance device provided in the embodiments of the present invention is described below. The photovoltaic module fault operation and maintenance device described below and the photovoltaic module fault operation and maintenance method described above can be referred to in correspondence.

[0161] Figure 10 The structural block diagram of the photovoltaic module fault operation and maintenance device provided in the embodiment of the present invention is shown below. Figure 10 The photovoltaic module fault operation and maintenance device may include:

[0162] Image acquisition module 100 is used to acquire visible light images and infrared thermal images of photovoltaic modules;

[0163] The preliminary detection module 200 is used to identify faults in the photovoltaic module based on the infrared thermal image and the visible light image, respectively, and obtain preliminary fault detection results.

[0164] The component screening module 300 is used to determine selected photovoltaic modules and non-selected photovoltaic modules, and the fault handling priority of each photovoltaic module, based on the preliminary fault detection results.

[0165] The secondary detection module 400 is used to perform secondary fault detection on each of the selected photovoltaic modules according to the fault handling priority, and obtain the secondary fault detection result; the secondary fault detection includes at least EL testing.

[0166] The strategy determination module 500 is used to generate corresponding maintenance strategies for each selected photovoltaic module based on the secondary fault detection results.

[0167] In an optional embodiment of this application, the component screening module 300 is specifically configured to: if the preliminary fault detection result of the photovoltaic module is that there is a glass breakage fault and an infrared spot, then determine that the photovoltaic module is a selected photovoltaic module and the fault handling priority is level one; if the preliminary fault detection result of the photovoltaic module is that there is a shading fault and an infrared spot, then determine that the photovoltaic module is a selected photovoltaic module and the fault handling priority is level two; if the preliminary fault detection result of the photovoltaic module is that there is no visible light fault but an infrared spot, then determine that the photovoltaic module is a selected photovoltaic module and the fault handling priority is level three; if the preliminary fault detection result of the photovoltaic module is that there is a glass breakage fault and no infrared spot, then determine that the photovoltaic module is a non-selected photovoltaic module. Furthermore, the fault handling priority is set to level four, and a maintenance strategy for the non-selected photovoltaic modules is generated. If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is set to level five, and a maintenance strategy for the non-selected photovoltaic module is generated. If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is set to level six, and a maintenance strategy for the non-selected photovoltaic module is generated. The maintenance handling priority for each non-selected photovoltaic module and the secondary fault detection priority for each selected photovoltaic module are determined in descending order of the fault handling priority from level one to level six.

[0168] In one optional embodiment of this application, the component screening module 300 is specifically configured to determine the maintenance strategy for the non-selected photovoltaic module as repair and periodic monitoring when the non-selected photovoltaic module has a fault handling priority of level four; determine the maintenance strategy for the non-selected photovoltaic module as cleaning when the non-selected photovoltaic module has a fault handling priority of level five; and determine the maintenance strategy for the non-selected photovoltaic module as cleaning when the non-selected photovoltaic module has a fault handling priority of level six.

[0169] In an optional embodiment of this application, the secondary detection module 400 is specifically used to perform EL testing on faulty cells in the hot spot area of ​​the selected photovoltaic module according to the fault handling priority, and obtain the EL test results corresponding to each faulty cell; determine the safety operation and maintenance coefficient characterizing the probability of safety hazards occurring in the selected photovoltaic module based on the EL test results; perform IV testing on the selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to a first set coefficient threshold, and obtain the module degradation rate of the selected photovoltaic module, using the safety operation and maintenance coefficient and the module degradation rate as the secondary fault detection results of the selected photovoltaic module.

[0170] In one optional embodiment of this application, the secondary detection module 400 is specifically used to determine the fault safety impact coefficient corresponding to each faulty battery cell based on the EL test results; and to determine the fault safety impact coefficient based on the safety operation and maintenance coefficient formula. Determine the safety operation and maintenance coefficient; among which, For safety and maintenance coefficient, For the first The failure safety impact coefficient of a faulty battery cell; The total number of faulty cells on the same selected photovoltaic module; Let be the probability of failure of a faulty solar cell, satisfying . , This is a constant coefficient for seasonal fires; This represents the probability of a fire. , This is the highest temperature of the hot spot at present; This is the critical temperature of the hot spot. This is a constant coefficient sensitive to fire temperature.

[0171] In an optional embodiment of this application, the secondary detection module 400 is specifically configured to: if the EL test result of the faulty battery cell indicates the presence of local dark spot fault and / or whole-cell dark cell fault and / or minor fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell is taken as a first coefficient; if the EL test result of the faulty battery cell indicates the presence of black edge fault and / or backplate scratch fault, then the fault safety impact coefficient corresponding to the faulty battery cell is taken as a second coefficient; if the EL test result of the faulty battery cell indicates the presence of moderate fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell is taken as a third coefficient; if the EL test result of the faulty battery cell indicates the presence of black cell fault and / or bright spot fault, then the fault safety impact coefficient corresponding to the faulty battery cell is taken as a fourth coefficient; if the EL test result of the faulty battery cell indicates the presence of severe fragmentation fault and / or diode breakdown fault, then the fault safety impact coefficient corresponding to the faulty battery cell is taken as a fifth coefficient; wherein, the first coefficient, second coefficient, third coefficient, fourth coefficient, and fifth coefficient increase sequentially.

[0172] In one optional embodiment of this application, the secondary detection module 400 is specifically used to perform IV detection on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to a first set coefficient threshold, so as to obtain the module degradation rate;

[0173] Accordingly, the strategy determination module 500 is specifically used as follows: if the safety operation and maintenance coefficient of the selected photovoltaic module is less than or equal to a first set coefficient threshold, then the selected photovoltaic module is identified as a Class D fault module, and the maintenance strategy is to take no action; if the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to a second set coefficient threshold, and the module's degradation rate is less than the degradation rate threshold, then the selected photovoltaic module is identified as a Class C fault module, and the maintenance strategy is to conduct periodic monitoring; if the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to the second set coefficient threshold, and the module's degradation rate is not less than the degradation rate threshold, then the selected photovoltaic module is identified as a Class B fault module, and the maintenance strategy is to recommend replacing the module; if the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold, and the module's degradation rate is less than the degradation rate threshold, then the selected photovoltaic module is identified as a Class B fault module, and the maintenance strategy is to recommend replacing the module; if the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold, and the module's degradation rate is not less than the degradation rate threshold, then the selected photovoltaic module is identified as a Class A fault module, and the maintenance strategy is to recommend immediate replacement of the module.

[0174] In an optional embodiment of this application, a rate of return calculation module is further included, used to calculate the rate of return based on the initial annual power generation, the module degradation rate, and the annual power generation loss value formula when the selected photovoltaic module is determined to be a Class B or Class A failure module. Determine the current power generation loss value; among which, This represents the current power generation loss value. This represents the initial annual power generation. The component degradation rate is calculated based on the current power generation loss, local annual equivalent hours, initial power, replacement component power, and the component replacement energy efficiency enhancement formula. ;in, Adding value to energy-efficient components For initial power, To replace the component power, The annual equivalent working hours are used in the local area; the annual return on investment (ROI) is determined based on the energy efficiency gain from component replacement, the total cost of replacing a single component, and the annual ROI formula; among which, Where ROI is the annual return on investment, R is the local electricity price, and C is the total cost of replacing a single component.

[0175] The photovoltaic module fault operation and maintenance device in this embodiment is used to implement the aforementioned photovoltaic module fault operation and maintenance method. Therefore, the specific implementation method of the photovoltaic module fault operation and maintenance device can be found in the embodiment section of the photovoltaic module fault operation and maintenance method above. The specific implementation method can be referred to the description of the corresponding embodiment, which will not be repeated here.

[0176] This application also provides an embodiment of a photovoltaic module fault operation and maintenance equipment, which may include:

[0177] Memory, used to store computer programs;

[0178] A processor is configured to execute the computer program to implement the steps of the photovoltaic module fault operation and maintenance method as described in any of the preceding claims.

[0179] The memory in this embodiment may include random access memory (RAM), main memory, read-only memory (ROM), electrically programmable ROM, electrically erasable programmable ROM, register, hard disk, removable disk, CD-ROM, or any other form of storage medium known in the art.

[0180] The steps of the photovoltaic module fault operation and maintenance method executed by the processor may include:

[0181] The process involves acquiring visible light and infrared thermal images of photovoltaic (PV) modules; identifying infrared and visible light faults in the PV modules based on the infrared thermal and visible light images, respectively, to obtain preliminary fault detection results; where infrared faults include at least conventional infrared hot spots and infrared diode hot spots; and visible light faults include at least glass breakage and shading faults; based on the preliminary fault detection results, selecting PV modules that require secondary fault detection, and prioritizing the fault handling for each selected PV module for secondary fault detection; where secondary fault detection includes at least EL testing; performing secondary fault detection on each selected PV module according to the fault handling priority, and obtaining secondary fault detection results; and determining the corresponding maintenance strategy for each selected PV module based on the secondary fault detection results.

[0182] It should be noted that, in this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that the elements inherent in a process, method, article, or apparatus that includes a list of elements are included. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes said element. Additionally, portions of the technical solutions provided in the embodiments of this application that are consistent with the implementation principles of corresponding technical solutions in the prior art have not been described in detail to avoid excessive elaboration.

[0183] This article uses specific examples to illustrate the principles and implementation methods of the present invention. The descriptions of the above embodiments are only for the purpose of helping to understand the method and core ideas of the present invention. It should be noted that those skilled in the art can make several improvements and modifications to the present invention without departing from the principles of the present invention, and these improvements and modifications also fall within the protection scope of the claims of the present invention.

Claims

1. A method for fault operation and maintenance of photovoltaic modules, characterized in that, include: S1: Acquire visible light and infrared thermal images of photovoltaic modules; S2: Based on the infrared thermal image and the visible light image, the photovoltaic module is fault identified to obtain preliminary fault detection results; S3: Based on the preliminary fault detection results, determine the selected photovoltaic modules and non-selected photovoltaic modules, and the fault handling priority of each photovoltaic module; S4: Perform secondary fault detection on each of the selected photovoltaic modules according to the fault handling priority, and obtain the secondary fault detection results; the secondary fault detection includes at least EL testing; S5: Based on the secondary fault detection results, generate maintenance strategies corresponding to each selected photovoltaic module.

2. The photovoltaic module fault operation and maintenance method as described in claim 1, characterized in that, S3 includes: S31: If the preliminary fault detection result of the photovoltaic module is that there is glass breakage and infrared light spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level one; S32: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level two; S33: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault but there is an infrared spot, then the photovoltaic module is determined to be the selected photovoltaic module and the fault handling priority is level three; S34: If the preliminary fault detection result of the photovoltaic module is that there is glass breakage and no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module, and the fault handling priority is level four, and a maintenance strategy for the non-selected photovoltaic module is generated. S35: If the preliminary fault detection result of the photovoltaic module is that there is a shading fault and there is no infrared spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level five, and a maintenance strategy for the non-selected photovoltaic module is generated. S36: If the preliminary fault detection result of the photovoltaic module is that there is no visible light fault and no infrared light spot, then the photovoltaic module is determined to be a non-selected photovoltaic module and the fault handling priority is level six, and a maintenance strategy for the non-selected photovoltaic module is generated. S37: Determine the maintenance priority of each non-selected photovoltaic module and the secondary fault detection priority of each selected photovoltaic module in descending order of the fault handling priority from level one to level six.

3. The photovoltaic module fault operation and maintenance method as described in claim 2, characterized in that, When the non-selected photovoltaic module has a fault handling priority of level four, the maintenance strategy for the non-selected photovoltaic module is determined to be repair and periodic monitoring. When the non-selected photovoltaic module has a fault handling priority of level five, the maintenance strategy for the non-selected photovoltaic module is determined to be shading removal; the shading removal includes at least one of cleaning, removing obstructions, or moving the module. When the non-selected photovoltaic module has a fault handling priority of level six, or when the non-selected photovoltaic module has a fault handling priority of no need to handle.

4. The photovoltaic module fault operation and maintenance method according to any one of claims 1 to 3, characterized in that, S4 includes: S41: Perform EL testing on the faulty cells in the hot spot area of ​​the selected photovoltaic module according to the fault handling priority, and obtain the EL test results corresponding to each faulty cell; S42: Based on the EL test results, determine the safety operation and maintenance coefficient that characterizes the probability of safety hazards occurring in the selected photovoltaic module; S43: Perform IV detection on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to the first set coefficient threshold to obtain the module degradation rate of the selected photovoltaic modules, and use the safety operation and maintenance coefficient and the module degradation rate as the secondary fault detection result of the selected photovoltaic modules.

5. The photovoltaic module fault operation and maintenance method as described in claim 4, characterized in that, S42 includes: S421: Based on the EL test results, determine the fault safety impact coefficient corresponding to each faulty battery cell; S422: Based on the safety operation and maintenance coefficient formula Determine the security operation and maintenance coefficient; wherein, The security operation and maintenance coefficient is... For the first The failure safety impact coefficient of the faulty battery cell; The total number of faulty cells on the same selected photovoltaic module; The probability of failure of the faulty battery cell is given by the following condition: , This is a constant coefficient for seasonal fires; This represents the probability of a fire. , This is the highest temperature of the hot spot at present; This is the critical temperature of the hot spot. This is a constant coefficient sensitive to fire temperature.

6. The photovoltaic module fault operation and maintenance method as described in claim 5, characterized in that, S421 includes: S4211: If the EL test result of the faulty battery cell is that there is a local dark spot fault and / or a whole cell dark fault and / or a slight fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the first coefficient. S4212: If the EL test result of the faulty battery cell is that there is a black edge fault and / or a back panel scratch fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the second coefficient. S4213: If the EL test result of the faulty battery cell is that there is a medium fragmentation fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the third coefficient. S4214: If the EL test result of the faulty battery cell is that there is a black spot fault and / or a bright spot fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the fourth coefficient. S4215: If the EL test result of the faulty battery cell is that there is a serious fragmentation fault and / or diode breakdown fault, then the fault safety impact coefficient corresponding to the faulty battery cell shall be the fifth coefficient. The first coefficient, the second coefficient, the third coefficient, the fourth coefficient, and the fifth coefficient increase sequentially.

7. The photovoltaic module fault operation and maintenance method as described in claim 5, characterized in that, S43 includes: IV detection is performed on selected photovoltaic modules whose safety operation and maintenance coefficient is greater than or equal to a first set coefficient threshold to obtain the module degradation rate; Accordingly, S5 includes: S51: When the safety operation and maintenance coefficient of the selected photovoltaic module is less than the first set coefficient threshold, the selected photovoltaic module is a Class D fault module, and the maintenance strategy is determined to be no action. S52: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to the second set coefficient threshold, and the module attenuation rate is less than the attenuation rate threshold, then the selected photovoltaic module is determined to be a Class C fault module, and the maintenance strategy is determined to be regular tracking and observation. S53: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than or equal to the first set coefficient threshold and less than or equal to the second set coefficient threshold, and the module attenuation rate is not less than the attenuation rate threshold, then the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module. S54: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module attenuation rate is less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class B fault module, and the maintenance strategy is to recommend replacing the module. S55: When the safety operation and maintenance coefficient of the selected photovoltaic module is greater than the second set coefficient threshold and the module attenuation rate is not less than the attenuation rate threshold, the selected photovoltaic module is determined to be a Class A fault module, and the maintenance strategy is to recommend immediate replacement of the module.

8. The photovoltaic module fault operation and maintenance method as described in claim 7, characterized in that, When the selected photovoltaic module is determined to be a Class B or Class A fault module, the method further includes: S501: Based on the initial annual power generation of the selected photovoltaic module, the module degradation rate, and the formula for the annual power generation loss value. Determine the current power generation loss value; among which, This represents the current power generation loss value. This refers to the initial annual power generation. The component attenuation rate; S502: Based on the current power generation loss value, local annual equivalent hours, initial power, replacement module power, and the module replacement energy efficiency enhancement formula. ;in, Adding value to energy-efficient components The initial power, For the power of the replaced component, The local annual equivalent number of hours; S503: Determine the annual return on investment (ROI) based on the energy efficiency gain from component replacement, the total cost of replacing a single component, and the annual ROI formula; wherein, Wherein, ROI is the annual return on investment, R is the local electricity price, and C is the total cost of replacing the single component.

9. A photovoltaic module fault operation and maintenance device, characterized in that, include: The image acquisition module is used to acquire visible light and infrared thermal images of photovoltaic modules; The preliminary detection module is used to identify faults in the photovoltaic module based on the infrared thermal image and the visible light image, respectively, and obtain preliminary fault detection results. The component screening module is used to determine selected and non-selected photovoltaic modules and the fault handling priority of each photovoltaic module based on the preliminary fault detection results. The secondary detection module is used to perform secondary fault detection on each of the selected photovoltaic modules according to the fault handling priority, and obtain the secondary fault detection results. The secondary fault detection includes at least EL testing; The strategy determination module is used to generate maintenance strategies corresponding to each selected photovoltaic module based on the secondary fault detection results.

10. A photovoltaic module fault operation and maintenance device, characterized in that, include: Memory, used to store computer programs; A processor is configured to execute the computer program to implement the steps of the photovoltaic module fault operation and maintenance method as described in any one of claims 1 to 8.

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