Method for correcting recording time of monitoring unit, monitoring unit and photovoltaic system

Abstract

The invention provides a correction method for recording time of a monitoring unit, the monitoring unit and a photovoltaic system. The correction method comprises the following steps: acquiring actual illumination duration of the photovoltaic unit in at least two continuous days, position information of the photovoltaic unit and photovoltaic power generation data time recorded by the monitoring unit; obtaining a first theoretical illumination duration of at least two consecutive days based on the position information and the photovoltaic power generation data time; based on the actual illumination duration and the first theoretical illumination duration, the daily average timing deviation and the date offset between the actual date and the recorded date in the photovoltaic power generation data time are determined; the photovoltaic power generation data time is corrected based on the date offset and the daily average timing deviation, the problem of inaccurate time caused by unstable power supply is effectively solved, time correction is achieved through a software algorithm, frequent replacement of hardware equipment is not needed, the hardware cost and the maintenance workload are reduced, and the working efficiency is improved. And system downtime and potential risks caused by hardware replacement are reduced.

Description

Technical Field

[0001] This application belongs to the field of photovoltaic power generation technology, and in particular relates to a method for correcting the recording time of a monitoring unit, a monitoring unit, and a photovoltaic system. Background Technology

[0002] In photovoltaic (PV) systems, the real-time clock (RTC) in the monitoring unit provides a critical time reference for equipment operation, and its normal operation depends on a continuous power supply. However, PV power generation is intermittent; when there is no sunlight, the equipment may lose power, causing the RTC to stop and time to be lost. If the equipment is disconnected from the grid and cannot synchronize time, internal time calculations will be incorrect, affecting PV power generation data statistics and analysis, and reducing data availability. Currently, button batteries or supercapacitors are commonly used to power the RTC. However, button batteries have limited lifespan, take up space, and have high maintenance costs; while supercapacitors have high self-loss, are sensitive to temperature, and have complex circuits that increase costs. In other words, existing technologies for solving the power supply and time calibration problems of PV equipment RTC timing modules have many drawbacks. Summary of the Invention

[0003] In view of this, the embodiments of this application provide a method for correcting the recording time of a monitoring unit, a monitoring unit, and a photovoltaic system. It can correct the time by acquiring the actual sunshine duration, location information, and photovoltaic power generation data time, and through a series of calculations. This effectively overcomes the problem of inaccurate time caused by unstable power supply. Furthermore, the time correction is achieved through software algorithms, eliminating the need for frequent hardware replacements, reducing hardware costs and maintenance workload, and minimizing system downtime and potential risks caused by hardware replacements.

[0004] In a first aspect, embodiments of this application provide a method for correcting the recording time of a monitoring unit, wherein the monitoring unit is powered by a photovoltaic unit, comprising: The actual sunshine duration of the photovoltaic unit for at least two consecutive days, the location information of the photovoltaic unit, and the time of photovoltaic power generation data recorded by the monitoring unit are obtained. The first theoretical sunshine duration for at least two consecutive days is obtained based on the location information and the photovoltaic power generation data time. The daily average timing deviation and the date offset between the actual date and the recorded date in the photovoltaic power generation data time are determined based on the actual sunshine duration and the first theoretical sunshine duration. The photovoltaic power generation data time is corrected based on the date offset and the average daily timing deviation.

[0005] In some embodiments, the two consecutive days include: day N and day N+1, and determining the daily average timing deviation and the date offset between the actual date and the recorded date in the photovoltaic power generation data time based on the actual sunshine duration and the first theoretical sunshine duration includes: The trend of light duration variation is determined based on the first theoretical light duration on day N and the first theoretical light duration on day N+1. The actual date range is determined based on the trend of changes in illumination duration; Based on the calculation relationship between the actual illumination duration and the theoretical illumination duration, a target calculation relationship is obtained. The target calculation relationship is that the first ratio is equal to the second ratio. The first ratio is equal to the actual illumination duration of the Nth day divided by the actual illumination duration of the N+1th day. The second ratio is equal to the second theoretical illumination duration of the Nth day divided by the second theoretical illumination duration of the N+1th day. The second theoretical illumination duration is a variable based on the actual date. The actual date of day N is determined from the actual date range, so that the second ratio or the first ratio in the target calculation relationship is less than a preset threshold; The date offset is obtained based on the actual date and the recorded date, and the average daily timing deviation is obtained based on the actual date.

[0006] In some embodiments, determining the actual date range based on the trend of changes in illumination duration includes: Based on the trend of light duration variation and the preset mapping relationship, the actual time range is obtained, wherein the preset mapping relationship includes the correspondence between the trend of light duration variation and the actual time range.

[0007] In some embodiments, determining the actual date of day N from the actual date range to make the second ratio or the first ratio in the target calculation relationship less than a preset threshold includes: Obtain the initial actual date of day N within the range of actual dates; Determine the second theoretical illumination duration for the initial actual date, and determine the second theoretical illumination duration for day N+1 based on the initial actual date; If the second ratio between the second theoretical illumination duration of the initial actual date and the calculated second theoretical illumination duration of day N+1 is less than a preset threshold, the initial actual date is determined as the actual date of day N.

[0008] In some embodiments, the calculation relationship between the actual illumination duration and the theoretical illumination duration includes: ; in, This refers to the actual duration of sunlight. For theoretical illumination duration, This represents the average daily timing deviation. The target calculation relationship includes: ; in, This is the second theoretical illumination duration on day N. This is the second theoretical illumination duration on day N+1. This represents the actual duration of sunlight on day N. This represents the actual sunshine duration on day N+1.

[0009] In some embodiments, obtaining the average daily timing deviation based on the actual date includes: Calculate the third theoretical illumination duration corresponding to the actual date based on the actual date and the location information; Calculate the ratio between the actual illumination duration on day N and the third theoretical illumination duration; Subtract 1 from the calculated ratio to obtain the deviation value; The daily average timing deviation is obtained based on the deviation value.

[0010] In some embodiments, correcting the photovoltaic power generation data time based on the date offset and the average daily timing deviation includes: The date in the photovoltaic power generation data time is corrected based on the date offset; The cumulative timing deviation is obtained by multiplying the average daily timing deviation by the number of days between the recording date and the last correction date, and the timing time in the photovoltaic power generation data is corrected based on the cumulative timing deviation.

[0011] In some embodiments, the location information includes latitude information, and the step of obtaining the first theoretical sunshine duration for at least two consecutive days based on the location information and the photovoltaic power generation data time includes: The location information and the date of day N in the photovoltaic power generation data time are input into the theoretical sunshine duration calculation formula to obtain the first theoretical sunshine duration of day N. Similarly, the location information and the date of day N+1 in the photovoltaic power generation data time are input into the theoretical sunshine duration calculation formula to obtain the first theoretical sunshine duration of day N+1. The theoretical sunshine duration calculation formula includes: L(D) = 2 / 15·arccos(-tanφ·tanδ(D)), where φ is the latitude, the arccos result is in radians, D is the date, and L(D) is the theoretical sunshine duration.

[0012] In some embodiments, obtaining the actual sunshine duration of the photovoltaic unit for at least two consecutive days includes: Record the acquisition time when the photovoltaic unit collects illumination data; If the illumination data within a preset time period is determined to be greater than the illumination standard threshold, determine whether the time difference between the most recent recorded sunset time and the first acquisition time corresponding to the illumination data greater than the illumination standard threshold is less than the preset time threshold. If the time difference is less than the preset time threshold, the first collection time is determined to be sunrise time; Given a determined sunrise time, and if the illumination data within the preset duration is determined to be less than or equal to the illumination standard threshold, the time when the illumination data is collected at or less than or equal to the illumination standard threshold is determined as the sunset time. The actual duration of sunlight for one day is obtained based on the sunrise and sunset times, so as to obtain the actual duration of sunlight for two consecutive days.

[0013] In some embodiments, the method further includes: The time information of the recorded historical photovoltaic data is corrected based on the date offset and the average daily timing deviation.

[0014] Secondly, embodiments of this application provide a monitoring unit, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement any of the methods described above.

[0015] Thirdly, embodiments of this application provide a computer-readable storage medium storing a computer program that, when executed by a processor, implements any of the methods described above.

[0016] Fourthly, embodiments of this application provide a computer program product that, when run on a terminal device, causes a monitoring unit to execute any of the methods described above.

[0017] Fifthly, embodiments of this application provide a photovoltaic system, a photovoltaic unit, and the monitoring unit described in the second aspect, wherein the photovoltaic unit is used to supply power to the monitoring unit.

[0018] The beneficial effects of the embodiments in this application compared with the prior art are: This application provides a method for correcting the recording time of a monitoring unit. The method involves acquiring the actual sunshine duration of the photovoltaic unit for at least two consecutive days, the location information of the photovoltaic unit, and the photovoltaic power generation data time recorded by the monitoring unit. Based on the location information and the photovoltaic power generation data time, a first theoretical sunshine duration for the at least two consecutive days is obtained. Based on the actual sunshine duration and the first theoretical sunshine duration, a daily average timing deviation and a date offset between the actual date and the recorded date in the photovoltaic power generation data time are determined. Based on the date offset and the daily average timing deviation, the photovoltaic power generation data time is corrected. This method effectively overcomes the problem of inaccurate time caused by unstable power supply. Furthermore, time correction is achieved through software algorithms, eliminating the need for frequent hardware replacements, reducing hardware costs and maintenance workload, and minimizing system downtime and potential risks caused by hardware replacements. Attached Figure Description

[0019] To more clearly illustrate the technical solutions in the embodiments of this application, 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 this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0020] Figure 1 A schematic diagram illustrating the implementation process of a method for correcting the recording time of a monitoring unit provided for the purposes of this application; Figure 2 A schematic diagram illustrating the implementation process of step S103 provided in an embodiment of this application; Figure 3 This is a schematic diagram of the structure of the monitoring unit provided in an embodiment of this application. Detailed Implementation

[0021] In the following description, specific details such as particular system architectures and techniques are set forth for illustrative purposes and not for limitation, in order to provide a thorough understanding of the embodiments of this application. However, those skilled in the art will understand that this application may also be implemented in other embodiments without these specific details. In other instances, detailed descriptions of well-known systems, apparatuses, circuits, and methods have been omitted so as not to obscure the description of this application with unnecessary detail.

[0022] It should be understood that, when used in this application specification and the appended claims, the term "comprising" indicates the presence of the described features, integrals, steps, operations, elements and / or components, but does not exclude the presence or addition of one or more other features, integrals, steps, operations, elements, components and / or a collection thereof.

[0023] It should also be understood that the term “and / or” as used in this application specification and the appended claims means any combination of one or more of the associated listed items and all possible combinations, and includes such combinations.

[0024] As used in this application specification and the appended claims, the term "if" may be interpreted, depending on the context, as "when," "once," "in response to determination," or "in response to detection." Similarly, the phrases "if determined" or "if detected" may be interpreted, depending on the context, as "once determined," "in response to determination," "once detected," or "in response to detection."

[0025] Furthermore, in the description of this application and the appended claims, the terms "first," "second," "third," etc., are used only to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0026] References to "one embodiment" or "some embodiments" in this specification mean that one or more embodiments of this application include a specific feature, structure, or characteristic described in connection with that embodiment. Therefore, the phrases "in one embodiment," "in some embodiments," "in other embodiments," "in still other embodiments," etc., appearing in different parts of this specification do not necessarily refer to the same embodiment, but rather mean "one or more, but not all, embodiments," unless otherwise specifically emphasized.

[0027] Based on the problems in related technologies, this application provides a method for correcting the recording time of a monitoring unit, which can be applied to the monitoring unit, which can serve as an inverter in a photovoltaic unit. In this application embodiment, the photovoltaic system consists of photovoltaic modules (photovoltaic units), a monitoring unit, etc. The photovoltaic unit converts solar energy into electrical energy. The monitoring unit is an electronic module (such as an RTC chip) used to record the system's operating time, powered by the photovoltaic units. The photovoltaic units are responsible for converting solar energy into electrical energy, providing continuous power to the monitoring unit and ensuring its independent operation. When the photovoltaic units do not generate electricity, the monitoring unit will be powered off; since the recording time of the monitoring unit stops when the power is off, Figure 1 A schematic diagram illustrating the implementation process of a method for correcting the recording time of a monitoring unit provided for the purposes of this application is shown below. Figure 1 As shown, the methods for correcting the recording time of the monitoring unit include: Step S101: Obtain the actual sunshine duration of the photovoltaic unit for at least two consecutive days, the location information of the photovoltaic unit, and the time of photovoltaic power generation data recorded by the monitoring unit.

[0028] In this embodiment, the actual sunshine duration is the duration during which the sunlight intensity exceeds a preset threshold (e.g., from sunrise to sunset) within a day. Location information refers to the geographical location of the photovoltaic unit's installation (e.g., latitude and longitude), used to calculate the theoretical sunshine duration (sunshine duration varies at different latitudes). Photovoltaic power generation data time refers to the time information corresponding to the photovoltaic power generation-related data recorded by the monitoring unit. Time information may include: date and time.

[0029] In this embodiment, sunrise (sunlight > threshold) and sunset (sunlight ≤ threshold) times can be recorded using the electrical energy output from the photovoltaic unit, and the actual sunshine duration can be calculated using the sunrise and sunset times. Location information can be pre-stored in the system, and the current recorded date and time can be obtained through the monitoring unit to obtain the photovoltaic power generation data time.

[0030] Step S102: Based on the location information and the photovoltaic power generation data time, obtain the first theoretical sunshine duration for at least two consecutive days.

[0031] In this embodiment of the application, the first theoretical sunshine duration is the theoretical sunshine duration calculated by an astronomical algorithm based on the location information and the recorded date in the photovoltaic power generation data time.

[0032] In this embodiment of the application, the location information and the recording date of day N in the photovoltaic power generation data time can be input into the theoretical sunshine duration calculation formula to obtain the first theoretical sunshine duration of day N. Similarly, the location information and the recording date of day N+1 in the photovoltaic power generation data time can be input into the theoretical sunshine duration calculation formula to obtain the first theoretical sunshine duration of day N+1. The theoretical sunshine duration calculation formula includes: L(D) = 2 / 15·arccos(-tanφ·tanδ(D)), where φ is the latitude, the arccos result is in radians, D is the date, L(D) is the theoretical sunshine duration, and δ(D) is the declination angle. The declination angle can be calculated using the solar declination angle calculation model, which is as follows: ; Where D represents the accumulated days within the year, with January 1st having a value of 1 and December 31st having a value of 365.

[0033] Step S103: Determine the average daily timing deviation based on the actual sunshine duration and the first theoretical sunshine duration, and determine the date offset between the actual date and the recorded date in the photovoltaic power generation data time.

[0034] In this embodiment, the daily average timing deviation is the cumulative time error of the monitoring unit each day (e.g., 2 minutes fast / slow each day). The date offset is the difference between the actual date and the recorded date (e.g., the recorded date lags behind the actual date due to a power outage and restart of the monitoring unit).

[0035] In this embodiment of the application, the third theoretical illumination duration Lreal(Dreal1) corresponding to the actual date can be calculated based on the actual date and the location information; then, the calculated ratio between the actual illumination duration of the Nth day and the third theoretical illumination duration can be calculated. The calculated ratio is represented by the formula; subtracting 1 from the calculated ratio yields the deviation value, which can then be expressed as: Based on the aforementioned deviation value, the daily average timing deviation can be obtained. The above calculation process can be expressed by the following formula: ; in, This represents the average daily timing deviation. This represents the actual duration of sunlight on day N. This represents the third theoretical duration of illumination corresponding to the actual date.

[0036] In this embodiment, the actual date range can be inferred from the trend of sunshine duration changes (e.g., the sunshine duration gradually increases in summer). Based on the actual date range and the target calculation relationship, the actual date is obtained, and then the date offset between the actual date and the recorded date in the photovoltaic power generation data time is calculated. The actual date can be obtained by referring to steps S1031 to S1034, by subtracting the recorded date of day N from the actual date of day N to obtain the date offset. The date offset can be represented by ΔD, and can be calculated using... ,in, This is the actual date of day N. This is the record date for day N.

[0037] Step S104: Correct the photovoltaic power generation data time based on the date offset and the average daily timing deviation.

[0038] In this embodiment, the recorded date can be modified by the date offset, and the time can be adjusted by the daily average timing deviation. Date correction can be performed using the following formula: Dcal = Drtc(now) + ΔD, where Drtc(now) is the recorded date, and Dcal is the corrected date. Time correction can be performed using the following formula: Tcal = Trtc(now) + ΔT N, where N is the number of days between the recording date and the last correction date, Trtc(now) is the photovoltaic power generation data time, and Tcal is the correction time.

[0039] The method provided in this application embodiment obtains the actual sunshine duration of the photovoltaic unit for at least two consecutive days, the location information of the photovoltaic unit, and the photovoltaic power generation data time recorded by the monitoring unit; obtains the first theoretical sunshine duration for the at least two consecutive days based on the location information and the photovoltaic power generation data time; determines the daily average timing deviation and the date offset between the actual date and the recorded date in the photovoltaic power generation data time based on the actual sunshine duration and the first theoretical sunshine duration; and corrects the photovoltaic power generation data time based on the date offset and the daily average timing deviation. This effectively overcomes the problem of inaccurate time caused by unstable power supply, and the time correction is achieved through software algorithms, eliminating the need for frequent hardware replacements, reducing hardware costs and maintenance workload, and minimizing system downtime and potential risks caused by hardware replacements.

[0040] In some embodiments, the two consecutive days include: day N and day N+1. Day N and day N+1 are two consecutive observation periods used to calculate the trend of changes in daylight duration. Day N and day N+1 can be any two consecutive days defined by the user.

[0041] Figure 2 This application provides a schematic diagram of the implementation process of step S103, as shown in the embodiment. Figure 2 As shown, step S103 can be achieved through the following steps: Step S1031: Determine the trend of light duration variation based on the first theoretical light duration on day N and the first theoretical light duration on day N+1.

[0042] In this embodiment, the trend of sunshine duration changes according to the theoretical sunshine duration changing with the date (e.g., sunshine gradually increases in summer and gradually decreases in winter), which is determined by the Earth's revolution and seasonal changes.

[0043] In this embodiment of the application, the recording date and location information of day N can be input into the theoretical illumination duration calculation formula to calculate the first theoretical illumination duration L1, and the recording date and location information of day N+1 can be input into the theoretical illumination duration calculation formula to calculate the first theoretical illumination duration L2 of day N+1.

[0044] In this embodiment of the application, the theoretical illumination duration of day N+1 can be subtracted from the theoretical illumination duration of day N to obtain the trend of illumination duration change.

[0045] Step S1032: Determine the actual date range based on the trend of changes in illumination duration.

[0046] In the embodiments of the present application, the actual date range is an interval that may contain the real date inferred according to the changing trend of the light duration (for example, narrowing the date search range through a theoretical model).

[0047] In the embodiments of the present application, the actual time range can be obtained based on the changing trend of the light duration and a preset mapping relationship, where the preset mapping relationship includes: the correspondence between the changing trend of the light duration and the actual time range. The preset mapping relationship can be: when the changing trend of the light duration increases, the corresponding date is in the stage from the Spring Equinox to the Summer Solstice or from the Winter Solstice to the Spring Equinox; when the changing trend of the light duration decreases, the corresponding date is in the stage from the Summer Solstice to the Autumn Equinox or from the Autumn Equinox to the Winter Solstice.

[0048] Continuing with the above example, if L2 > L1, it is determined that the real date is in the stage from the Spring Equinox to the Summer Solstice or from the Winter Solstice to the Spring Equinox (increasing duration); if L2 < L1, it is determined that the real date is in the stage from the Summer Solstice to the Autumn Equinox or from the Autumn Equinox to the Winter Solstice (decreasing duration); at the same time, in combination with the verification of the changing rate of the light duration, the changing rate is the fastest around the Spring Equinox / Autumn Equinox and the slowest around the Summer Solstice / Winter Solstice, further narrowing the real date range.

[0049] Step S1033, obtaining a target calculation relationship based on the calculation relationship between the actual light duration and the theoretical light duration, where the target calculation relationship is that the first ratio is equal to the second ratio, the first ratio is equal to the actual light duration of the Nth day divided by the actual light duration of the (N + 1)th day, and the second ratio is equal to the second theoretical light duration of the Nth day divided by the second theoretical light duration of the (N + 1)th day, where the second theoretical light duration is a variable with the actual date.

[0050] In the embodiments of the present application, the target calculation relationship can be expressed as: ; where is the actual light duration of the Nth day divided by the actual light duration of the (N + 1)th day, is the second theoretical light duration of the Nth day divided by the second theoretical light duration of the (N + 1)th day, where the second theoretical light duration is a variable with the actual date, is the second theoretical light duration of the Nth day, is the second theoretical light duration of the (N + 1)th day, is the actual light duration of the Nth day, is the actual light duration of the (N + 1)th day.

[0051] In this embodiment, a calculation relationship between actual illumination duration and theoretical illumination duration can be established in advance. Then, the actual illumination duration on day N and the second theoretical illumination duration on day N are substituted into the calculation relationship to obtain the calculation relationship between the actual illumination duration on day N and the second theoretical illumination duration on day N. The calculation relationship between the actual illumination duration on day N and the second theoretical illumination duration on day N can be expressed as follows: ; Similarly, the calculation relationship between the actual illumination duration on day N+1 and the second theoretical illumination duration on day N+1 can be obtained. This relationship can be expressed as: ,in, , = +1, This is the actual date of day N.

[0052] The calculation relationships between the actual illumination duration on day N and the second theoretical illumination duration on day N, and between the actual illumination duration on day N+1 and the second theoretical illumination duration on day N+1, can both be converted into a calculation formula between ΔT and illumination duration. At this point, ΔT can be eliminated, thus obtaining the target calculation formula.

[0053] After obtaining the target calculation formula, because It can be represented by the actual date of day N+1, and the actual date of day N+1 can be obtained by adding 1 to the actual date of day N. Therefore, the calculation formula for this target only includes the actual date of day N, Dreal1.

[0054] Step S1034: Determine the actual date of day N from the actual date range, so that the second ratio or the first ratio in the target calculation relationship is less than a preset threshold.

[0055] In this embodiment of the application, an iterative algorithm (such as binary search) can be run to quickly locate dates that meet the threshold.

[0056] In this embodiment of the application, step S1034 can be implemented through the following steps: Step S341: Obtain the initial actual date of day N within the actual date range.

[0057] In this embodiment of the application, a date can be randomly selected from the actual date range as the Nth day. Alternatively, a date can be selected starting from the middle of the actual date range, or dates can be selected sequentially.

[0058] Step S342: Determine the second theoretical illumination duration for the initial actual date, and determine the second theoretical illumination duration for day N+1 based on the initial actual date.

[0059] In this embodiment of the application, the initial actual date can be input into the formula for calculating the theoretical illumination duration, thereby calculating the second theoretical illumination duration for the initial actual date, and the second theoretical illumination duration for the N+1th day can also be calculated.

[0060] Step S343: If the second ratio between the second theoretical illumination duration of the initial actual date and the calculated second theoretical illumination duration of day N+1 is less than a preset threshold, the initial actual date is determined as the actual date of day N.

[0061] In this embodiment, the preset threshold can be configured, for example, it can be configured to 0.01. If the second ratio between the second theoretical illumination duration of the initial actual date and the calculated second theoretical illumination duration of day N+1 is less than the preset threshold, the initial actual date is determined as the actual date of day N; if it is greater, the initial actual date of day N is selected again.

[0062] For example, calculation until ≤0.01, or ≤0.01. The initial actual date at this point is the actual date of day N.

[0063] In this embodiment, step-by-step verification and threshold filtering can be used to avoid traversing the entire actual date range and improve inference efficiency.

[0064] Step S1035: Obtain the date offset based on the actual date and the recorded date, and obtain the average daily timing deviation based on the actual date.

[0065] The method provided in this application eliminates the error of relying solely on single-day data by matching the theoretical sunshine duration ratio with the actual ratio, thus improving the accuracy of date inference. It eliminates the need to traverse the entire year's dates, requiring only a search within a narrowed range of actual dates, reducing computational complexity. Through this method, photovoltaic units can efficiently and accurately autonomously correct their dates in complex environments, providing a reliable time reference for energy management and data analysis.

[0066] In some embodiments, step S101 can be implemented by the following steps: Step S1011: Record the acquisition time when the photovoltaic unit acquires the illumination data.

[0067] In this embodiment of the application, when the photovoltaic unit has voltage, current and / or power, it is determined that the illumination data has been collected, and the collection time can be recorded at this time.

[0068] Step S1012: If the illumination data within a preset time period is determined to be greater than the illumination standard threshold, determine whether the time difference between the most recent recorded sunset time and the first acquisition time corresponding to the illumination data greater than the illumination standard threshold is less than the preset time threshold.

[0069] In this embodiment, the illumination standard threshold is used as a critical value to distinguish between "sunlight" and "no light." It can be calculated by taking the lowest average voltage of photovoltaic cells over multiple historical days as the illumination standard threshold. The time difference is the interval between sunset time and candidate sunrise time, used to verify the rationality of the sunrise judgment. The preset time threshold is the minimum allowable interval between sunrise time and the previous day's sunset time, used to exclude abnormal data. In this embodiment, the preset duration is used as a time window for analyzing illumination data to avoid noise interference from single-point data. Here, the preset time threshold can be 10 minutes.

[0070] In this embodiment of the application, since the photovoltaic unit will lose power after the last sunset, the time recorded at this time is the last sunset time. On the N+1th day, when the photovoltaic unit generates electricity at sunrise, the time will start from the last sunset time. Therefore, it is necessary to determine the time difference to avoid misjudgment caused by clouds blocking the sun.

[0071] Step S1013: If the time difference is less than the preset time threshold, determine the first collection time as sunrise time.

[0072] Step S1014: If the sunrise time is determined, and if the illumination data within the preset duration is less than or equal to the illumination standard threshold, the collection time of the illumination data less than or equal to the illumination standard threshold is determined as the sunset time.

[0073] Step S1015: Based on the sunrise time and sunset time, obtain the actual sunshine duration of a day to obtain the actual sunshine duration of two consecutive days.

[0074] The method provided in this application, through preset duration window statistics and continuous condition verification, filters out transient changes in illumination (such as light transmission through gaps in clouds), ensuring accurate sunrise / sunset times. Photovoltaic units can obtain actual illumination durations reliably and at low cost without external dependence, providing crucial data support for energy management and automated control.

[0075] In some embodiments, the method further includes: correcting the time information of the recorded historical photovoltaic data based on the date offset and the average daily timing deviation.

[0076] In this embodiment of the application, the timestamps of the recorded historical photovoltaic data can be recalibrated. Each time a time correction is completed, the timestamp calibration of the historical photovoltaic data will be automatically triggered to ensure that the historical photovoltaic data is consistent with the real time.

[0077] The following are specific examples. Example 1: This example uses a device located at 31° North latitude as an example to illustrate the calibration method of the present invention in detail. The specific steps are as follows: The observation point latitude φ=31° was obtained, and the current recording dates Drtc1 = 135 (5 / 15) and Drtc2 = 136 (5 / 16). Using the sunrise and sunset times stored on the device for two consecutive days, the consecutive recording dates are: Dn=137 and D... n+1 =138, meaning using the recorded date Dn=137, the theoretical sunshine duration L1 = 13 hours is calculated for Dn=137, and the theoretical sunshine duration L2 = 13 hours and 2 minutes for Dn=138. Since L2>L1, the actual date is determined to be in the transition from the vernal equinox to the summer solstice or from the winter solstice to the vernal equinox. Combining the regional sunshine variation characteristics (sunshine duration increases rapidly after the vernal equinox), the actual dates D1=140 (May 20) and D2=141 (May 21) are matched using the solar declination angle calculation model. The current RTC displays the date D=137 (May 17) and the time T=14:30. ΔTall = ΔT × n = 2 minutes / day × 2 days = +4 minutes, RTC time is 14:30, ΔD = 140 - 135 = 5 days, date calibration: Dcal = 137 + 5 (5 / 22); time calibration: Tcal = 14:30 - 4 = 14:26 (Note: ΔT being positive indicates that RTC is too fast, and the cumulative deviation needs to be subtracted; here the calibration logic is corrected: if it is too fast, subtract; if it is too slow, add).

[0078] The application provides another specific example of time calibration in the event of a power outage at night and the RTC being unable to function. This embodiment is based on the equipment and scenario of Embodiment 1, adding the condition of a power outage at night and the RTC being unable to operate. The specific calibration logic is as follows: After the photovoltaic equipment is powered on and resumes operation for 5 minutes due to sunlight, the system searches for the last data record, which is the sunrise and sunset time. The system considers the current time to be the sunrise time. If the sunset time deviates from the current time by 5 minutes, and the difference between the sunrise and sunset times is calculated to be >3 hours, meeting the threshold, it is considered that a complete day has passed, and the current time is fixedly increased by 8 hours. After meeting the condition of collecting valid data for two consecutive days, the subsequent calibration steps are the same as in Embodiment 1, completing the accurate correction of the RTC time, and also calibrating the timestamps of the photovoltaic power generation historical data.

[0079] It should be understood that the sequence number of each step in the above embodiments does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this application.

[0080] Figure 3 This is a schematic diagram of the monitoring unit provided in an embodiment of this application. Figure 3 As shown, the monitoring unit of this embodiment may include: at least one processor 30 ( Figure 3 Only one processor 30, memory 31, and computer program 32 stored in memory 31 and executable on at least one processor 30 are shown. When the processor 30 executes the computer program 32, it implements the steps in any of the above method embodiments, or the processor 30 executes the computer program 32 to implement the functions of each module / unit in the above device or system embodiments.

[0081] For example, computer program 32 may be divided into one or more modules / units, one or more of which are stored in memory 31 and executed by processor 30 to complete this application. One or more modules / units may be a series of computer program 32 instruction segments capable of performing a specific function, which describe the execution process of computer program 32 in monitoring unit.

[0082] This application also provides a computer-readable storage medium storing a computer program 32, which, when executed by a processor 30, implements the steps described in the above-described method embodiments.

[0083] This application provides a computer program product that, when run on a monitoring unit, enables the monitoring unit to perform the steps described in the above-described method embodiments.

[0084] 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, all or part of the processes in the methods of the above embodiments of this application can be implemented by a computer program 32 instructing related hardware. The computer program 32 can be stored in a computer-readable storage medium, and when executed by the processor 30, it can implement the steps of the various method embodiments described above. The computer program 32 includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include at least: any entity or device capable of carrying computer program code to a terminal, a recording medium, a computer memory, a read-only memory (ROM), a random access memory (RAM), an electrical carrier signal, a telecommunication signal, and a software distribution medium. Examples include USB flash drives, portable hard drives, magnetic disks, or optical disks.

[0085] Based on the foregoing embodiments, this application further provides a photovoltaic system, including: a photovoltaic unit and the unit in the above embodiments, wherein the photovoltaic unit is used to supply power to the monitoring unit. The monitoring unit and the photovoltaic unit can be two independent devices or integrated together; this application does not impose any limitation.

[0086] In the above embodiments, the descriptions of each embodiment have different focuses. For parts that are not described in detail or recorded in a certain embodiment, please refer to the relevant descriptions of other embodiments.

[0087] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, or a combination of computer software and electronic hardware. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this application.

[0088] In the embodiments provided in this application, it should be understood that the disclosed apparatus / network devices and methods can be implemented in other ways. For example, the apparatus / network device embodiments described above are merely illustrative. For instance, the division of modules or 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; the indirect coupling or communication connection between apparatuses or units may be electrical, mechanical, or other forms.

[0089] 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.

[0090] The above-described embodiments are only used to illustrate the technical solutions of this application, and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features. Such modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of this application, and should all be included within the protection scope of this application.

Claims

1. A method for correcting the recording time of a monitoring unit, characterized in that, The monitoring unit is powered by a photovoltaic unit, and the method includes: The actual sunshine duration of the photovoltaic unit for at least two consecutive days, the location information of the photovoltaic unit, and the time of photovoltaic power generation data recorded by the monitoring unit are obtained. The first theoretical sunshine duration for at least two consecutive days is obtained based on the location information and the photovoltaic power generation data time. The daily average timing deviation is determined based on the actual sunshine duration and the first theoretical sunshine duration, and the date offset between the actual date and the recorded date in the photovoltaic power generation data time is determined. The photovoltaic power generation data time is corrected based on the date offset and the average daily timing deviation.

2. The method according to claim 1, characterized in that, Two consecutive days include: day N and day N+1. The determination of the daily average timing deviation and the date offset between the actual date and the recorded date in the photovoltaic power generation data time, based on the actual sunshine duration and the first theoretical sunshine duration, includes: The trend of light duration variation is determined based on the first theoretical light duration on day N and the first theoretical light duration on day N+1. The actual date range is determined based on the trend of changes in illumination duration; Based on the calculation relationship between the actual illumination duration and the theoretical illumination duration, a target calculation relationship is obtained. The target calculation relationship is that the first ratio is equal to the second ratio. The first ratio is equal to the actual illumination duration of the Nth day divided by the actual illumination duration of the N+1th day. The second ratio is equal to the second theoretical illumination duration of the Nth day divided by the second theoretical illumination duration of the N+1th day. The second theoretical illumination duration is a variable based on the actual date. The actual date of day N is determined from the actual date range, so that the second ratio or the first ratio in the target calculation relationship is less than a preset threshold; The date offset is obtained based on the actual date and the recorded date, and the average daily timing deviation is obtained based on the actual date.

3. The method according to claim 2, characterized in that, Determining the actual date range based on the trend of changes in illumination duration includes: Based on the trend of light duration variation and the preset mapping relationship, the actual time range is obtained, wherein the preset mapping relationship includes the correspondence between the trend of light duration variation and the actual time range.

4. The method according to claim 2, characterized in that, Determining the actual date of day N from the actual date range, such that the second ratio or the first ratio in the target calculation relationship is less than a preset threshold, includes: Obtain the initial actual date of day N within the range of actual dates; Determine the second theoretical illumination duration for the initial actual date, and determine the second theoretical illumination duration for day N+1 based on the initial actual date; If the second ratio between the second theoretical illumination duration of the initial actual date and the calculated second theoretical illumination duration of day N+1 is less than a preset threshold, the initial actual date is determined as the actual date of day N.

5. The method according to claim 2, characterized in that, The method of obtaining the average daily timing deviation based on the actual date includes: Calculate the third theoretical illumination duration corresponding to the actual date based on the actual date and the location information; Calculate the ratio between the actual illumination duration on day N and the third theoretical illumination duration; Subtract 1 from the calculated ratio to obtain the deviation value; The daily average timing deviation is obtained based on the deviation value.

6. The method according to claim 1, characterized in that, The correction of the photovoltaic power generation data time based on the date offset and the average daily timing deviation includes: The date in the photovoltaic power generation data time is corrected based on the aforementioned date offset; The cumulative timing deviation is obtained by multiplying the average daily timing deviation by the number of days between the recording date and the last correction date, and the timing time in the photovoltaic power generation data is corrected based on the cumulative timing deviation.

7. The method according to claim 1, characterized in that, Obtaining the actual sunshine duration of the photovoltaic unit for at least two consecutive days includes: Record the acquisition time when the photovoltaic unit collects illumination data; If the illumination data within a preset time period is determined to be greater than the illumination standard threshold, determine whether the time difference between the most recent recorded sunset time and the first acquisition time corresponding to the illumination data greater than the illumination standard threshold is less than the preset time threshold. If the time difference is less than the preset time threshold, the first collection time is determined to be sunrise time; Given a determined sunrise time, and if the illumination data within the preset duration is determined to be less than or equal to the illumination standard threshold, the time when the illumination data is collected at or less than or equal to the illumination standard threshold is determined as the sunset time. The actual duration of sunlight for one day is obtained based on the sunrise and sunset times, so as to obtain the actual duration of sunlight for two consecutive days.

8. The method according to any one of claims 1 to 7, characterized in that, The method further includes: The time information of the recorded historical photovoltaic data is corrected based on the date offset and the average daily timing deviation.

9. A monitoring unit, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method as described in any one of claims 1 to 8.

10. A photovoltaic system, characterized in that, include: The photovoltaic unit and the monitoring unit as described in claim 9, wherein the photovoltaic unit is used to supply power to the monitoring unit.

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