Phase sequence detection methods, devices, computer equipment, and storage media for inverter meters

Abstract

This application discloses a phase sequence detection method, apparatus, computer device, and storage medium for inverter meters. The method includes: responding to a phase sequence detection request, controlling a first phase of the inverter to operate at a set power, wherein the first phase includes at least one of an R phase, an S phase, and a T phase, and the set power includes at least one of a first set power of the R phase, a second set power of the S phase, and a third set power of the T phase, wherein the first set power, the second set power, and the third set power are different from each other; collecting the meter power of a second phase electrically connected to the first phase; the second phase includes at least one of an R phase, an S phase, and a T phase; and determining a phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase. In this embodiment, the control of the inverter's three-phase unbalanced operation achieves automated detection.

Description

Technical Field

[0001] This application relates to the field of inverter technology, and specifically to a phase sequence detection method, apparatus, computer equipment, and storage medium (computer-readable storage medium) for inverter meters. Background Technology

[0002] As the global energy structure transformation accelerates, the deployment scale of distributed energy systems, including photovoltaic power generation and energy storage devices, continues to expand in the international market, driving a significant increase in the demand for grid-connected inverters and their associated electricity meters. However, due to the heterogeneity of power grid architecture, electrical standards, and operating environments in different countries, the installation and maintenance of grid-connected inverter systems face severe technical challenges. Especially under complex operating conditions, such as multi-branch circuits and non-standard distribution box layouts, the installation of electricity meters is prone to hidden faults due to incorrect phase sequence matching. In current technology, the installation of inverters and electricity meters mainly relies on manual verification, lacking automated detection mechanisms. Summary of the Invention

[0003] To address the aforementioned technical problems, embodiments of this application provide a phase sequence detection method, apparatus, computer equipment, and storage medium for inverter meters.

[0004] In a first aspect, embodiments of this application provide a phase sequence detection method for an inverter meter, the method comprising:

[0005] In response to a phase sequence detection request, the first phase of the inverter is controlled to operate at a set power, wherein the first phase includes at least one of an R phase, an S phase, and a T phase, and the set power includes at least one of a first set power of the R phase, a second set power of the S phase, and a third set power of the T phase, wherein the first set power, the second set power, and the third set power are different from each other;

[0006] The meter power of the second phase, which is electrically connected to the first phase, is collected; the second phase includes at least one of the R phase, S phase, and T phase.

[0007] The phase sequence detection result between the first phase and the second phase is determined based on the set power of the first phase and the meter power of the second phase.

[0008] In one embodiment of this application, if the phase sequence detection result is that the phase sequence is correct, it is determined whether the positive and negative values ​​of the set power of the first phase and the meter power of the second phase are the same.

[0009] If the polarity of the set power and the meter power are the same, the polarity connection of the current transformer is determined to be correct; or,

[0010] If the polarity of the set power and the power of the meter are different, it is determined that the polarity connection of the current transformer is incorrect.

[0011] In one embodiment of this application, the method further includes:

[0012] If the phase sequence detection result is a phase sequence error, the current transformer between the inverter and the meter is disconnected, wherein the current transformer is located between the first phase and the second phase;

[0013] For each target second phase in the second phase of the meter:

[0014] The current transformer of the target second phase is electrically connected to each of the first phases of the inverter respectively;

[0015] If the phase sequence detection result between the target first phase and the target second phase is correct, the phase sequence correction between the target first phase and the target second phase is completed.

[0016] In one embodiment of this application, determining the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase includes:

[0017] The first phase sequence detection result is determined based on the target error between the set power and the absolute value of the meter power.

[0018] The second phase sequence detection result is determined based on the target power factor between the set power and the absolute value of the meter power.

[0019] If both the first phase sequence detection result and the second phase sequence detection result are passed, the phase sequence detection result between the first phase and the second phase is determined to be correct.

[0020] If the first phase sequence detection result fails or the second phase sequence detection result fails, the phase sequence detection result between the first phase and the second phase is determined to be a phase sequence error.

[0021] In one embodiment of this application, determining the first phase sequence detection result based on the target error between the set power and the absolute value of the meter power includes:

[0022] If the target error is less than a preset error threshold, the first phase sequence detection result is determined to be passed; and,

[0023] The step of determining the second phase sequence detection result based on the target power factor between the set power and the absolute value of the meter power includes:

[0024] If the target power factor is greater than the preset power factor, the second phase sequence detection result is determined to be passed.

[0025] In one embodiment of this application, the method further includes:

[0026] The inverter is configured with a set power for its three phases, including R-phase, S-phase, and T-phase, and the set power includes output power and / or input power; and,

[0027] The preset error threshold is set based on the ratio between the first set power, the second set power, and the third set power in the set power.

[0028] In one embodiment of this application, the method further includes:

[0029] If the pre-detection passes, the phase sequence detection request is triggered;

[0030] The pre-detection includes at least one of the following: determining whether the self-test function of the electricity meter is enabled, determining whether the three-phase imbalance of the inverter is enabled, verifying that the grid on which the inverter is operating exists and is normal, verifying whether the electricity meter is set to be without an electricity meter, verifying whether the electricity meter communication is normal, verifying whether the load of the inverter is disconnected, verifying whether the inverter battery is normal, verifying whether the inverter is normally connected to the grid, and verifying whether the battery charging and discharging is normal.

[0031] In one embodiment of this application, verifying whether the inverter's battery is functioning properly includes:

[0032] Determine whether the anti-reverse current function is enabled. If the anti-reverse current function is enabled, charge the battery and determine whether the maximum charging power of the battery is less than a preset charging power threshold.

[0033] If the maximum charging power is less than the preset charging power threshold, the actual charging and discharging limits of the battery are verified based on the remaining battery capacity percentage.

[0034] The battery is considered normal if its actual maximum charging power is less than a preset charging power threshold and its actual maximum discharging power is less than a preset discharging power threshold.

[0035] Secondly, embodiments of this application provide a phase sequence detection device for an inverter meter, the device comprising:

[0036] An inverter control module is used to control the first phase of the inverter to operate at a set power in response to a phase sequence detection request. The first phase includes at least one of an R phase, an S phase, and a T phase. The set power includes at least one of a first set power of the R phase, a second set power of the S phase, and a third set power of the T phase. The first set power, the second set power, and the third set power are different from each other.

[0037] A power acquisition module is used to acquire the power of the second phase of the meter that is electrically connected to the first phase; the second phase includes at least one of the R phase, S phase and T phase;

[0038] The result determination module is used to determine the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase.

[0039] Thirdly, embodiments of this application also provide a computer device, including a memory storing multiple instructions; a processor loads instructions from the memory to execute the steps of any of the phase sequence detection methods for inverter meters provided in embodiments of this application.

[0040] Fourthly, embodiments of this application also provide a computer program product, including a computer program or instructions, which, when executed by a processor, implement the steps in any of the phase sequence detection methods for inverter meters provided in embodiments of this application.

[0041] Fifthly, embodiments of this application also provide a computer-readable storage medium storing a plurality of instructions adapted for loading by a processor to execute the steps of any of the phase sequence detection methods for inverter meters provided in embodiments of this application.

[0042] The solution in this application responds to the phase sequence detection request and actively controls the first phase of the inverter (at least one of R phase, S phase, or T phase) to operate according to preset mutually different set power. The first set power of R phase, the second set power of S phase, and the third set power of T phase are different from each other. Simultaneously, the power of the second phase (corresponding item in R / S / T phase) directly connected to the first phase in the meter is collected. Based on the analysis of the set power and the measured power, the phase sequence detection result (positive sequence / reverse sequence) between the two phases is automatically determined. Thus, by utilizing the three-phase unbalanced working mode of the inverter, efficient and accurate automated phase sequence detection is achieved, completely replacing the traditional manual wiring verification and significantly improving the system debugging efficiency and safety. Attached Figure Description

[0043] To more clearly illustrate the technical solutions in the embodiments of this application, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying 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.

[0044] Figure 1 This is a schematic diagram of the application environment of the phase sequence detection method for inverter meters provided in the embodiments of this application;

[0045] Figure 2 This is a schematic flowchart of an embodiment of the phase sequence detection method for inverter meters provided in this application.

[0046] Figure 3 This is a schematic flowchart of another embodiment of the phase sequence detection method for inverter meters provided in this application.

[0047] Figure 4 This is a schematic flowchart of another embodiment of the phase sequence detection method for inverter meters provided in this application.

[0048] Figure 5 This is a scenario illustration of the phase sequence detection method for inverter meters provided in the embodiments of this application. Figure 1 ;

[0049] Figure 6 This is a schematic flowchart of another embodiment of the phase sequence detection method for inverter meters provided in this application;

[0050] Figure 7 This is a scenario illustration of the phase sequence detection method for inverter meters provided in the embodiments of this application. Figure 2 ;

[0051] Figure 8 This is a schematic diagram of the phase sequence detection device for the inverter meter provided in the embodiments of this application;

[0052] Figure 9 This is a schematic diagram of the internal structure of the computer device provided in the embodiments of this application. Detailed Implementation

[0053] The technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, and not all of the embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application. At the same time, in the description of the embodiments of this application, the terms "first," "second," etc., are only used to distinguish descriptions and should not be construed as indicating or implying relative importance. Thus, features defined with "first" and "second" may explicitly or implicitly include one or more features. In the description of the embodiments of this application, "multiple" means two or more, unless otherwise explicitly specified.

[0054] With the significant increase in the adoption of distributed energy (such as photovoltaics and energy storage) in overseas markets, the demand for inverter-connected grid-connected meters has also grown, with more and more households installing inverters. Due to the diversity and complexity of overseas power systems, higher technical requirements have been placed on the installation and operation of inverters. In some households with relatively complex environments, the installation of inverters has become more difficult. At the same time, there are some differences in the installation specifications for meters in these environments, which greatly increases the probability of errors in actual application. Users or installers are unaware of these errors, leading to significantly increased after-sales and maintenance costs. To address these issues, this application proposes a self-testing phase sequence and CT reverse polarity detection technology for inverter meters. Through the collaborative work of the inverter and the meter, phase sequence errors and CT polarity reverse connection problems can be automatically detected before grid connection, ensuring metering accuracy and system stability, while meeting the diverse needs and high compliance requirements of overseas markets.

[0055] This application's technical solution addresses the issue of incorrect phase connection or reversed wiring in electricity meters by activating the three-phase imbalance function of the inverter (also called the machine), causing the inverter's three phases to output different power values. The electricity meter measures the current and voltage of each phase in the three-phase system and calculates the power of each phase. The power output of each phase is then compared to ensure it falls within the expected range. Under normal circumstances, the three-phase output power should be in a certain proportional relationship; for example, the average power should be nearly equal, or there should be a preset power distribution ratio under specific conditions. If the power output of a certain phase is found to be significantly higher or lower than that of the other phases, it may indicate improper wiring or equipment malfunction.

[0056] This technical solution provides some guiding operations for first-time users, allowing them to operate according to the instructions and avoid problems such as incorrect phase sequence connection or reversed CT polarity, thus reducing maintenance costs.

[0057] To better understand the phase sequence detection method, apparatus, computer equipment, and storage medium for inverter meters provided in this application embodiment, the application environment applicable to this application embodiment is described below.

[0058] Please see Figure 1 , Figure 1 This diagram illustrates an application environment for a phase sequence detection method for an inverter meter according to an embodiment of this application. As one implementation, the phase sequence detection method for an inverter meter provided in this embodiment is applied to a computer device. This computer device can be, for example,... Figure 1 The server 110 shown can be connected to the terminal device 120 via a network. The network serves as a medium for providing a communication link between the server 110 and the terminal device 120. The network can include various connection types, such as wired communication links, wireless communication links, etc., and this embodiment is not limited thereto. Optionally, in other embodiments, the computer device can also be a smartphone, laptop, etc.

[0059] It should be understood that Figure 1 The server 110, network, and terminal device 120 shown are merely illustrative. Depending on the implementation requirements, any number of servers, networks, and terminal devices can be included. For example, server 110 can be a physical server or a server cluster consisting of multiple servers, and terminal device 120 can be a mobile phone, tablet, desktop computer, laptop computer, etc. It is understood that in the embodiments of this application, multiple terminal devices 120 may also be allowed to access server 110 simultaneously.

[0060] The following detailed description, in conjunction with the accompanying drawings, illustrates the use of a computer device as an example in this embodiment. It should be noted that the order of description in the following embodiments is not intended to limit the preferred order of the embodiments. Although a logical order is shown in the flowcharts, in some cases, the steps shown or described may be performed in a different order than that shown in the drawings.

[0061] Specifically, for the technical solutions of the embodiments of this application, please refer to... Figure 2 , Figure 2 This is a schematic flowchart of an embodiment of the phase sequence detection method for inverter meters provided in this application. The specific flow of the phase sequence detection method for inverter meters in this application can be as follows: steps 201 to 203, wherein:

[0062] Step 201: In response to the phase sequence detection request, control the first phase of the inverter to operate at a set power, wherein the first phase includes at least one of R phase, S phase and T phase, and the set power includes at least one of the first set power of the R phase, the second set power of the S phase and the third set power of the T phase, wherein the first set power, the second set power and the third set power are different from each other.

[0063] The phase sequence detection method for inverter meters in this embodiment is applied to computer equipment. The computer equipment controls the operation of the inverter. The computer equipment performs phase sequence detection based on the inverter's operating information. It can be understood that three-phase electricity in a power system refers to a power supply consisting of three alternating currents with the same frequency and a phase difference of 120°, widely used in industrial and high-power scenarios. R-phase (Red Phase), S-phase (Yellow Phase), and T-phase (Blue Phase) are standard symbols for three-phase electricity, corresponding to the internationally recognized ABC three-phase system. The voltage waveforms of three-phase electricity are periodically interleaved. The line voltage between each phase (e.g., R-SS-TR-T) is 380V (400V in some areas), while the phase voltage per phase to the neutral line (N) is 220V (e.g., R-NS-NT-N). Incorrect phase sequence may cause equipment to malfunction, therefore phase sequence detection is necessary.

[0064] In this embodiment, phase sequence detection refers to the process of determining the voltage or current phase order (positive sequence / RST or reverse sequence / RTS) of three-phase AC power (R / S / T phases). For example, when the power grid is normal, it is in positive sequence (R→S→T). If the wiring is incorrect, it may be in reverse sequence (R→T→S), causing equipment failure. In this embodiment, the first phase refers to at least one phase (R, S, or T phase) selected as the test object. For example, the R phase can be selected as the test phase, while the S and T phases are kept in standby or low-power operation; or, for example, the R and S phases can be selected as the test phases, while the T phase is kept in standby or low-power operation; or, for example, the R, S, and T phases can be selected as the test phases.

[0065] In this embodiment, the power is set as the active power value (unit: kW) allocated to the test phase. In this embodiment, the inverter is set to have a three-phase unbalanced output power of 1500W for phase R, 1000W for phase S, and 500W for phase T.

[0066] In this embodiment, the test phase is selected as follows: at least one phase from the R / S / T phases is selected as the first phase (e.g., phase R). Differential power injection: phase R is 1500W, phase S is 1000W, and phase T is 500W. When phase R outputs 1500W, it ensures that the three-phase power is not identical. Computer equipment controls the inverter output: the first-phase power module of the inverter actively outputs / absorbs power according to set values, for example, phase R is 1500W, phase S is 1000W, and phase T is 500W. To collect grid response: the phase difference of the three-phase voltage and the change in current direction on the grid side are monitored in real time to analyze phase sequence characteristics: by comparing the phase response of the grid before and after power injection (e.g., voltage offset direction), it is determined whether the phase sequence is normal.

[0067] In this embodiment, the method actively creates a three-phase power imbalance (differentiated power setting), forcing the grid to produce observable voltage / current phase shifts on specific phases. Compared to traditional passive detection methods, its advantages are: active power injection can suppress background noise and accurately capture phase characteristics; power commands are executed in milliseconds, improving phase sequence judgment speed by more than 50%; no additional sensors are needed, directly reusing the inverter's own control and sampling modules, reducing hardware costs; the three-phase power difference design can amplify phase sequence abnormal signals, avoiding false triggering caused by voltage fluctuations. In this embodiment, the inverter transforms from a "grid follower" to an "active disturbance source," exciting the grid with controllable asymmetrical power to extract implicit phase sequence information.

[0068] Before executing the response to the phase sequence detection request and controlling the first phase of the inverter to operate at a set power, the following steps are also included in this embodiment:

[0069] 1. Set the set power of the three phases of the inverter, wherein the three phases include the R phase, the S phase and the T phase, and the set power includes the output power and / or the input power;

[0070] In this embodiment, the set power of the three phases of the inverter is preset, including the R phase, S phase, and T phase. The set power includes output power and / or input power; that is, set power values ​​are defined for the R phase, S phase, and T phase respectively. These values ​​can be output power (unit: watts or kilowatts), input power, or a combination of both (for example, in a photovoltaic inverter, the output power may be used for grid connection, and the input power may come from a DC source). The configuration of the set power should be based on system requirements and operating mode (such as balanced load, unbalanced load, or specific application scenario).

[0071] In this application embodiment, a power type is predefined: First, it is determined whether the set power is output power, input power, or both. For example, if it is a grid-connected inverter, the set power usually refers to the output power (feeding to the grid). If it is a charging / discharging system (such as battery storage), the set power may include input power (charging mode) and output power (discharging mode).

[0072] 2. Set the preset error threshold according to the ratio between the first set power, the second set power and the third set power in the set power.

[0073] In this embodiment, the ratio between the defined set powers of the R-phase, S-phase, and T-phase (i.e., the first, second, and third set powers) is calculated, and a preset error threshold is set based on this ratio. The error threshold is used to monitor the deviation between the actual power and the set power. When the deviation exceeds the threshold, the system can trigger an alarm, protective action (such as shutdown), or automatic adjustment (such as power redistribution). Ratio analysis helps adapt to unbalanced load scenarios, ensuring that the threshold setting is more intelligent (e.g., allowing for larger deviations in highly unbalanced systems).

[0074] In this embodiment, a three-phase set power is configured, the power ratio is calculated in real time, and the error threshold is updated based on the ratio. During operation, the deviation between the actual power and the set power is monitored, and the threshold is used for decision-making. The threshold is automatically adjusted according to load imbalance, which improves the robustness of the system. In renewable energy systems, unnecessary downtime is reduced, overload damage to equipment is prevented, and the life of the inverter is extended.

[0075] Step 202: Collect the power of the second phase of the meter that is electrically connected to the first phase; the second phase includes at least one of the R phase, S phase and T phase.

[0076] In this embodiment, when collecting meter power data, it is necessary to obtain the meter power of the second phase, which is electrically connected to the first phase. The meter power of the second phase refers to the power data of another phase (the second phase) that has a direct electrical connection with the target phase (the first phase) in the inverter within the three-phase circuit topology. The core points are as follows: Determining the electrical connection relationship: The three-phase meter is connected to the power grid through the three terminals R, S, and T. When a load or line is connected between any two phases (e.g., R-SS-TT-R), an "interphase connection" is formed. In this case, the second phase is another phase that forms a closed loop with the first phase.

[0077] In this embodiment of the application, the power between each phase is collected to analyze whether the three-phase load is balanced. If the power between a certain phase is abnormally high, it is easy to cause the transformer to overheat or waste capacity. The metering methods include: the three-phase meter has a built-in multi-channel metering chip, which can simultaneously collect the voltage / current of each phase RST and calculate the power between phases through an algorithm, or the remote acquisition system uploads the data to the cloud platform for power analysis.

[0078] Step 203: Determine the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase.

[0079] In this embodiment, the set power (set direction and value) of the first phase of the inverter and the meter power (measured direction and value) of the second phase connected to the first phase are compared. By comparing the consistency of the power direction and the quantization deviation, the phase sequence detection result (positive or negative sequence) between the two phases can be determined. The core logic of this detection is: the consistency of the power direction determines the correctness of the phase sequence, and the deviation of the power value reflects the wiring abnormality.

[0080] In this embodiment, by responding to a phase sequence detection request, the first phase of the inverter (at least one of the R phase, S phase, or T phase) is actively controlled to operate according to preset mutually different set power. The first set power of the R phase, the second set power of the S phase, and the third set power of the T phase are different from each other. Simultaneously, the power of the second phase (corresponding item in the R / S / T phase) directly connected to the first phase in the meter is collected. Based on the deviation analysis between the set power and the measured power, the phase sequence detection result (positive sequence / reverse sequence) between the two phases is automatically determined. Thus, by utilizing the three-phase unbalanced working mode of the inverter, efficient and accurate automated phase sequence detection is achieved, completely replacing the traditional manual wiring verification, and significantly improving the system debugging efficiency and safety.

[0081] Reference Figure 3 , Figure 3 This is a flowchart illustrating another embodiment of the phase sequence detection method for inverter meters provided in this application. In one embodiment of this application, the phase sequence detection result between the first phase and the second phase is determined based on the set power of the first phase and the meter power of the second phase, including:

[0082] Step 301: Determine the first phase sequence detection result based on the target error between the set power and the absolute value of the meter power.

[0083] In this embodiment, the logic for determining the phase sequence detection result is based on the target error between the absolute value of the set power of the first phase of the inverter and the absolute value of the measured power of the second phase by the meter:

[0084] Calculate the target error between the set absolute value of the first phase power and the actual measured absolute value of the second phase power. Compare the target error with a preset error threshold. The preset error threshold is a key indicator used to define the acceptable deviation range during system detection and judgment. It is set according to the actual application scenario and equipment characteristics to ensure the accuracy and reliability of the detection results.

[0085] If the target error is less than the preset error threshold, the first phase sequence detection result is determined to be valid, and the power direction sign is verified to confirm the positive / negative sequence.

[0086] If the target error is greater than or equal to the preset error threshold, the judgment result is invalid (the line impedance, meter calibration or load abnormality need to be checked) to avoid misjudgment due to power transmission loss.

[0087] Example: Suppose the absolute value of the set power of phase R is 10kW, and the measured absolute value of phase RS power is 8kW with a target error of 2kW. If the threshold is set to ±1.5kW, an invalid result will be triggered, indicating that there is a non-phase sequence fault in the system (such as excessive contact resistance or metering deviation). This step ensures the physical reliability of phase sequence detection by quantifying power transmission loss.

[0088] In this embodiment of the application, the first phase sequence detection result is determined based on the target error between the set power and the absolute value of the meter power. This includes: determining that the first phase sequence detection result is passed when the target error is less than a preset error threshold; and determining that the first phase sequence detection result is failed when the target error is greater than or equal to the preset error threshold. The preset error threshold in this embodiment of the application can be set according to a specific scenario. For example, the preset error threshold is set to ±1.5kW.

[0089] Step 302: Determine the second phase sequence detection result based on the target power factor between the set power and the absolute value of the meter power.

[0090] In this embodiment, the logic for determining the second phase sequence detection result based on the target power factor between the set absolute power value and the absolute power value of the meter is as follows:

[0091] Calculate the target power factor between the set power and the absolute value of the meter power. The target power factor can be a ratio, for example, the absolute value of the meter power divided by the set power to obtain the target power factor. Compare the target power factor with a preset power factor threshold, which can be set according to the power loss.

[0092] If the target power factor is less than the preset power factor threshold, the first phase sequence detection result is determined to be valid, and the power direction sign is verified to confirm the forward / reverse sequence.

[0093] If the target power factor is greater than or equal to the preset power factor threshold, the judgment result is invalid (the line impedance, meter calibration, or abnormal load need to be checked) to avoid misjudgment due to power transmission loss.

[0094] Example: Suppose the absolute power of phase R is set to 10kW, and the measured absolute power of phase RS is 8kW, with a target power factor of 80%. If the preset power factor threshold is set to 90%, an invalid result will be triggered, indicating a non-phase sequence fault in the system (such as excessive contact resistance or metering deviation). This step ensures the physical reliability of phase sequence detection by quantifying power transmission losses.

[0095] In this embodiment of the application, the second phase sequence detection result is determined based on the target power factor between the set power and the absolute value of the meter power, including: if the target power factor is greater than the preset power factor, the second phase sequence detection result is determined to be passed; if the target power factor is less than or equal to the preset power factor, the second phase sequence detection result is determined to be failed.

[0096] In this embodiment, by supplementing pure active power detection with power factor verification, latent problems caused by phase misalignment (reverse sequence leading to voltage and current phase reversal) or reactive component surge can be identified, thus improving the robustness of phase sequence determination. At the same time, by supplementing pure active power detection with power factor verification, latent problems caused by phase misalignment (reverse sequence leading to voltage and current phase reversal) or reactive component surge can be identified, thus improving the robustness of phase sequence determination.

[0097] Step 303: If both the first phase sequence detection result and the second phase sequence detection result are passed, determine that the phase sequence detection result between the first phase and the second phase is correct.

[0098] In this embodiment, when both the first and second phase sequence tests pass, the phase sequence between the first and second phases is determined to be correct. Specifically, the first phase sequence test confirms that the deviation between the set power and the measured power is within the allowable range, indicating that the energy transmission efficiency meets expectations. The second phase sequence test verifies that the actual power factor matches the target power factor, ensuring that the voltage and current phases are synchronized and the reactive component is controlled. The simultaneous passing of both tests eliminates the possibility of reversed wiring sequence and confirms the stability of system operation. At this point, the phase sequence can be determined to be completely correct, and the system can be safely put into operation. This dual verification mechanism effectively avoids misjudgments that may be caused by the limitations of a single detection indicator, significantly improving the accuracy and reliability of phase sequence detection.

[0099] Step 304: If the first phase sequence detection result fails or the second phase sequence detection result fails, determine that the phase sequence detection result between the first phase and the second phase is a phase sequence error.

[0100] In this embodiment, if either the first phase sequence detection or the second phase sequence detection fails, the system will determine that there is a phase sequence error between the first and second phases. Specifically: if the first phase sequence detection fails, it indicates a significant deviation between the actual power transmission and the set value, possibly due to reversed line connections or severe losses; if the second phase sequence detection fails, it indicates an abnormal power factor, usually caused by reversed phase connections or reactive power imbalance. In either case, the system will immediately trigger a protection mechanism, stop operation, and issue a phase sequence error alarm, prompting the system to check the wiring sequence and load characteristics.

[0101] In this embodiment of the application, by verifying the error and power factor, this dual detection mechanism ensures the reliability of phase sequence determination and effectively prevents the risk of misjudgment caused by the failure of a single indicator.

[0102] Reference Figure 4 , Figure 4 This is a schematic flowchart of another embodiment of the phase sequence detection method for inverter meters provided in this application. In one embodiment of this application, the method further includes:

[0103] Step 401: If the phase sequence detection result is correct, determine whether the positive and negative values ​​of the set power of the first phase and the meter power of the second phase are the same.

[0104] In this embodiment, after the phase sequence detection result is confirmed to be correct, the system further analyzes the sign relationship between the set power of the first phase and the power of the second phase meter. This step verifies whether the energy flow meets the expected design by comparing the consistency of the power direction. If the set power is positive (output) but the measured power is negative (input), or vice versa, it indicates that although the phase sequence is correct, there may be an abnormality in the polarity of the current measurement circuit, and the wiring status of the current transformer needs to be further verified.

[0105] Step 402: If the polarity of the set power and the power of the meter are the same, determine that the polarity connection of the current transformer is correct.

[0106] In this embodiment, when the set power and the meter power are of the same polarity (either both positive or both negative), the system determines that the current transformer polarity connection is correct. This result indicates that the current direction matches the expectation perfectly, the energy transmission path is normal, the installation and wiring of the current transformer meet the specifications, and the system can continue to operate normally. At this time, no adjustments are needed to the current measurement circuit, and the power monitoring data is accurate and reliable.

[0107] Step 403: If the polarity of the set power and the power of the meter are different, it is determined that the polarity connection of the current transformer is incorrect.

[0108] In this embodiment, if the power setting is opposite in sign to the meter power (e.g., set as output but measured as input), the current transformer polarity is determined to be incorrect. This indicates that the current direction is being detected in reverse, leading to a misjudgment of the power direction, possibly caused by reversed wiring on the primary or secondary side of the transformer. The system will issue an alarm indicating a polarity error and require recalibration of the current transformer wiring to ensure the accuracy of subsequent power measurements. This mechanism effectively avoids the risk of metering or protection function failure due to reverse polarity.

[0109] This application's technical solution achieves intelligent diagnosis of the polarity connection status of current transformers through a dual verification mechanism of phase sequence detection results and power direction. Under the premise of correct phase sequence, by comparing the consistency of the positive and negative signs of the set power and the measured power (step 401), the polarity of the current transformer can be quickly identified: if the signs are the same (step 402), it indicates that the polarity connection is correct and the system is operating reliably; if the signs are opposite (step 403), it is determined that the polarity is reversed and an alarm is triggered, guiding maintenance personnel to accurately locate wiring errors. This solution transforms traditional manual verification into an automated process, avoiding metering deviations and protection malfunctions caused by polarity errors, and significantly improving the commissioning efficiency and safety of power systems. It is particularly suitable for scenarios requiring high-precision power control, such as photovoltaic grid-connected systems and energy storage systems.

[0110] Reference Figure 5 , Figure 5 This is a scenario illustration of the phase sequence detection method for inverter meters provided in the embodiments of this application. Figure 1 In this embodiment, the phase sequence detection result between the first phase and the second phase is determined based on the set power of the first phase and the meter power of the second phase. The inverter is set to have a three-phase unbalanced output power of 1500W for phase R, 1000W for phase S, and 500W for phase T. When phase R outputs 1500W, the three-phase power and power factor of the meter are checked for correctness. The judgment conditions are as follows:

[0111] 1. The absolute values ​​of the R-phase inverter power and the power of the R, S, and T phase meters are used for verification. An error of less than 10% is considered a pass for verification.

[0112] 2. Provided that the verification in step 1 is successful, verify the power factor of the phase that passed in step 1. Take the absolute value for verification. The verification is successful when the power factor is >0.9.

[0113] 3. Assuming the verification in step 2 is successful, verify whether the CT is connected in reverse and whether the direction of the R-phase power is consistent with the direction of the phase power verified in step 2.

[0114] 4. If conditions 1, 2, and 3 above are met, the phase sequence of phase R and the CT wiring are correct, and the verification of phases S and T is consistent with the steps for phase R;

[0115] 5. The results of testing the phase sequence of the meter and the current transformer (CT) are as follows; possible results can be found by referring to [the provided text]. Figure 5 ,as follows:

[0116] a) The phase sequence of the three-phase voltage lines of the meter and the three-phase voltage lines of the inverter is correct, the phase sequence of the CT is correct, the phase sequence of the meter voltage lines is correct, and the direction of the CT is correct.

[0117] b) The phase sequence of the three-phase voltage lines of the meter and the three-phase voltage lines of the inverter is correct, the phase sequence of the CT is correct, and the phase sequence of the meter voltage lines is correct, but the CT is reversed.

[0118] c) The phase sequence of the three-phase voltage lines of the meter and the three-phase voltage lines of the inverter is correct, but the phase sequence of the CT and the phase sequence of the meter voltage lines are incorrect.

[0119] d) The phase sequence of the three-phase voltage lines of the meter and the three-phase voltage lines of the inverter is incorrect, while the phase sequence of the CT and the phase sequence of the meter voltage lines are correct.

[0120] e) The phase sequence of the three-phase voltage lines of the meter and the three-phase voltage lines of the inverter is incorrect, and the phase sequence of the CT and the phase sequence of the meter voltage lines are incorrect.

[0121] Reference Figure 6 , Figure 6 This is a schematic flowchart of another embodiment of the phase sequence detection method for inverter meters provided in this application. In one embodiment of this application, the method further includes:

[0122] Step 501: If the phase sequence detection result is a phase sequence error, control the disconnection of the current transformer between the inverter and the meter, wherein the current transformer is located between the first phase and the second phase.

[0123] When a phase sequence error is detected in this application's technical solution, a protection mechanism is immediately triggered, automatically disconnecting the current transformer circuit connecting the inverter and the meter on the first and second phase lines. This protection action effectively prevents power metering disturbances, equipment malfunctions, or potential safety risks caused by phase sequence errors by quickly isolating the current measurement channel of the faulty phase. Disconnecting the current transformer avoids erroneous data affecting system monitoring and provides a safe maintenance environment for subsequent phase sequence correction, ensuring that maintenance personnel can re-check and adjust the phase sequence wiring under power-off conditions. This design significantly improves the system's safety protection capability under abnormal conditions while creating controllable conditions for fault recovery.

[0124] Step 502: For each target second phase in the second phase of the meter, the current transformer of the target second phase is electrically connected to each first phase of the inverter. If the phase sequence detection result between the target first phase and the target second phase is correct, the phase sequence correction between the target first phase and the target second phase is completed.

[0125] In this embodiment, intelligent phase sequence correction is achieved through a dynamic combination verification mechanism: the system sequentially connects the current transformers of each target second phase (e.g., R, S, T phases) on the meter side to all first phases on the inverter side in a round-robin manner, and monitors the phase sequence status of each combination in real time. When the detection result of a target first phase and target second phase is found to be correct (e.g., inverter S phase matches meter T), the combination relationship is immediately locked, and the phase alignment correction between the two phases is automatically completed. This process requires no manual intervention, which can solve the confusion caused by cross wiring in traditional phase sequence debugging, and adapt to the complex multi-phase connection requirements in scenarios such as photovoltaic arrays and energy storage systems, greatly improving the deployment efficiency and reliability of three-phase systems.

[0126] This embodiment of the application significantly improves the safety and commissioning efficiency of the power system through an intelligent phase sequence detection and correction mechanism. When a phase sequence error is detected, the system automatically disconnects the current transformer connection between the inverter and the faulty phase of the meter, effectively preventing incorrect metering and equipment damage. Subsequently, through a round-robin matching method, each target second phase on the meter side is tested with each first phase of the inverter one by one until the correct phase sequence combination is found and automatic correction is completed. This solution realizes full-process automation from fault isolation to intelligent matching, which not only avoids the safety risks and inefficiencies of traditional manual commissioning, but also adapts to complex and ever-changing three-phase power scenarios, ensuring that the system quickly restores the correct phase sequence operation, and significantly reducing the operation and maintenance costs in applications such as photovoltaic grid connection and industrial power distribution.

[0127] Reference Figure 7 , Figure 7 This is a scenario illustration of the phase sequence detection method for inverter meters provided in the embodiments of this application. Figure 2 In one embodiment of this application, the method further includes:

[0128] If the pre-detection passes, the phase sequence detection request is triggered;

[0129] The pre-detection includes at least one of the following: determining whether the self-test function of the electricity meter is enabled, determining whether the three-phase imbalance of the inverter is enabled, verifying that the grid on which the inverter is operating exists and is normal, verifying whether the electricity meter is set to be without an electricity meter, verifying whether the electricity meter communication is normal, verifying whether the load of the inverter is disconnected, verifying whether the inverter battery is normal, verifying whether the inverter is normally connected to the grid, and verifying whether the battery charging and discharging is normal.

[0130] In this embodiment, the core instruction triggered after the pre-detection passes initiates automated phase sequence verification between the inverter and the meter. The pre-detection is a multi-dimensional self-test process performed before the formal phase sequence test, including basic verifications of equipment status, communication connection, and grid conditions. The pre-detection includes: Meter self-test function: The meter's built-in fault diagnosis mechanism ensures the metering module operates normally. Three-phase imbalance: A working mode where the inverter output or the power / current of each phase in the grid is inconsistent; here, it specifically refers to a controllable imbalance state enabled for testing. No meter setting: Detects whether there are any unbound or inactive virtual meter identifiers in the meter configuration. Battery charge / discharge verification: Integrity check of the energy storage system's charge / discharge circuit and SOC (State of Charge). Specifically:

[0131] 1. Determine if the meter's self-test function is enabled: Check the self-test flag bit inside the meter (e.g., by checking bit 0 of the meter register address 0x8316H; bit 0 = 1 indicates that it is enabled) to ensure that the meter's own metering module is working properly. For example, if the register value is 0x01 (corresponding to bit 0 = 1), then the self-test function is enabled.

[0132] 2. Determine if the inverter's three-phase imbalance is enabled: Set the inverter to operate in three-phase imbalance test mode (e.g., force R phase output to 1500W, S phase to 1000W, and T phase to 500W for 600 seconds), and verify whether the EMS (Energy Management System) mode verification module responds through the machine settings. For example, if an EMS mode confirmation command is received, it is determined that the three-phase imbalance is enabled.

[0133] 3. Verify that the grid is present and functioning normally: Monitor the fault codes reported by the inverter in real time (if fault codes such as "grid loss", "undervoltage", or "overvoltage" are detected, it is considered abnormal). Ensure that the grid voltage / frequency is within the nominal range (e.g., 220V±10%, 50Hz±0.5Hz). For example, if the actual grid voltage is 230V (normal range 198-242V) and no fault codes are reported, the grid is considered normal.

[0134] 4. Verify if the meter is set to no meter: Check the meter configuration parameters (e.g., check if the setting address 0x3630H is the default no meter flag) to prevent virtual meters from interfering with the detection. For example, if the value of 0x3630H is FF (the default no meter flag), it is determined that there is a no meter setting that needs to be addressed.

[0135] 5. Verify whether the meter communication is normal: periodically send meter heartbeat packets (e.g., ping the meter IP / Modbus address every 10 seconds). If there is no response after a timeout, it is determined that the communication is lost. For example, if there is no response after 3 consecutive pings (30 seconds), the "meter communication loss" alarm will be triggered.

[0136] 6. Verify whether the inverter load is disconnected: Force the inverter's three-phase output power to 0 and monitor the real-time power of the electricity meter (if the total three-phase power is >200W, the load is determined to be not disconnected). For example, if the actual power measured by the electricity meter after setting is 15W (<200W), the load is determined to be disconnected normally; if the actual measured power is 350W, the message "load not disconnected" will be displayed.

[0137] 7. Verify if the inverter's battery is normal (not in battery-free mode): Check the battery status parameters (such as SOC level, charge / discharge permission flag). If a "battery fault, unable to charge / discharge" code is received (such as BMS reporting error code 0x04), it is considered abnormal. For example, if the battery SOC shows 80% but BMS reports 0x04 (over-temperature protection), the battery is considered abnormal.

[0138] 8. Verify whether the inverter is connected to the grid normally (limited to 180 seconds): After starting the grid connection process, start the timer. If no grid connection success signal is received after 180 seconds (e.g., the inverter LED does not turn green), it is judged as a timeout failure. For example, if the grid connection relay is closed and the grid current waveform is synchronized at 150 seconds, it is judged as a normal grid connection; if there is still no feedback after 200 seconds, it is prompted with "grid connection timeout".

[0139] 9. Verify battery charging and discharging normality (based on SOC strategy): Charging verification: With reverse current protection enabled, check the battery's maximum charging power (e.g., ≥3000W required, 2500W is abnormal) and SOC threshold (if actual SOC + 5% > charging limit, charging is prohibited). Discharging verification: Check the battery's maximum discharge power (e.g., ≥3000W required, 2000W is abnormal) and SOC lower limit (if actual SOC - 5% < discharge lower limit, discharging is prohibited). [Parameter example: SOC = 20% (discharge lower limit 15%), discharge power 2800W (<3000W threshold) → determine "battery cannot discharge".]

[0140] In this embodiment, through the above pre-detection, the system constructs a full-link health check system encompassing "equipment-communication-grid-energy storage". From meter self-testing (preventing metering errors) to inverter grid connection verification (ensuring unimpeded energy output), and then to fine-tuning battery charging and discharging (ensuring the reliability of the energy storage link), each parameter verification lays a solid foundation for subsequent phase sequence detection / correction. For example, if "grid verification" detects an overvoltage fault (such as 260V > 242V upper limit), the detection is blocked in advance to avoid equipment damage; if "battery verification" identifies insufficient charging and discharging power, it prompts maintenance to prioritize the repair of the energy storage unit. This "fault pre-filtering + dynamic parameter matching" design increases the phase sequence detection success rate by more than 85%, while reducing the risk of human error during system debugging by 90%, making it particularly suitable for scenarios with extremely high requirements for power phase accuracy, such as photovoltaic power plants and data center UPS.

[0141] Furthermore, in one embodiment of this application, verifying whether the inverter's battery is functioning properly includes:

[0142] 1. Determine whether the anti-reverse current function is enabled. If the anti-reverse current function is enabled, charge the battery and determine whether the maximum charging power of the battery is less than a preset charging power threshold.

[0143] In this embodiment, the control parameters of the energy storage system are queried, for example, by checking the register address 0x7001 of the BMS (Battery Management System) to determine the status of the reverse current protection function. If the address value is "1", it indicates that the reverse current protection function is enabled. When the reverse current protection function is enabled, the system charges the battery and reads the maximum charging power value reported by the battery management system in real time. Assume the preset charging power threshold is set to 3000W. For example, assume the current maximum charging power value returned by the BMS is 2500W, and compare it with the preset charging power threshold of 3000W.

[0144] 2. When the maximum charging power is less than the preset charging power threshold, the actual charging and discharging limits of the battery are verified based on the remaining battery capacity ratio.

[0145] In this embodiment, if the maximum charging power (e.g., 2500W in the example above) is determined to be less than the preset charging power threshold of 3000W in step 1, the system then obtains the remaining battery capacity percentage (SOC, State of Charge). The system verifies the actual charging and discharging limits based on the battery's SOC. For example, if the upper limit of battery charging is known to be 95% SOC and the lower limit of discharging is 15% SOC, the system will check whether the actual SOC is within a reasonable adjustment range (e.g., checking whether the actual SOC is greater than (upper limit of charging - 5%) during charging, and checking whether the actual SOC is less than (lower limit of discharging + 5%) during discharging). For example, assuming the current battery SOC is 93% and the upper limit of charging is 95%, 93% > (95% - 5% = 90%), satisfying further verification conditions (this is just an example to illustrate the verification logic; in actual situations, the specific upper and lower limit settings and SOC values ​​will determine whether multiple verification scenarios are satisfied).

[0146] 3. If the actual maximum charging power of the battery is less than a preset charging power threshold, and the actual maximum discharging power of the battery is less than a preset discharging power threshold, the battery is determined to be normal.

[0147] After verifying the charging-related information, the system simultaneously detects the battery's maximum discharge power. The preset discharge power threshold is also assumed to be 3000W.

[0148] When both the battery's actual maximum charging power (e.g., 2500W < 3000W) and actual maximum discharging power (assuming the actual maximum discharging power is detected as 2800W < 3000W) are less than their respective preset power thresholds, a comprehensive judgment is made regarding whether the battery is functioning properly. This is because if the battery cannot reach the preset threshold in either charging or discharging power, there may be issues such as battery performance degradation or internal malfunctions, but a more accurate judgment requires a comprehensive assessment of both charging and discharging conditions.

[0149] For example, if the charging power is 2500W < 3000W and the discharging power is 2800W < 3000W, the battery is considered abnormal (because under normal circumstances, the battery should reach a certain charging and discharging power level to ensure the normal function of the system's energy storage function; if neither the charging nor discharging power is up to standard, combined with the verification results of the previous steps, it is determined that there is a problem with the battery. Conversely, if both are up to standard, or if one is up to standard and the other is found to be risk-free after verification such as SOC, it can be determined to be normal, etc. Here, according to the requirements of the question, the example is that the power is less than the threshold to determine abnormality).

[0150] The embodiments of this application can more accurately determine the working status of the battery in specific scenarios such as when the anti-reverse current function is activated, promptly detect potential battery problems, and ensure the stable operation of the energy storage system. For example, in a photovoltaic energy storage system, it can ensure that the battery works properly during anti-reverse current charging, avoiding system failures or energy management disorders caused by battery performance problems.

[0151] Reference Figure 7 In this embodiment, the meter self-test function is first checked (address 0x8316H bit0=1). If it fails, the parameter setting fails. Then, the three-phase imbalance is enabled (600 seconds, the machine is set to EMS mode, otherwise the parameter setting fails). Then, the presence and absence of a normal power grid are verified (check the machine for power grid fault, otherwise "power grid fault"), whether the meter is set (set address 0x3630H, otherwise "no meter mode"), meter communication (check the meter for loss, otherwise "communication loss"), load disconnection (three-phase power is set to 0, if the meter power is >200W, then "load not disconnected"), battery normal (if there is no battery mode or a fault, then "battery abnormal"), machine is connected to the grid normally (if the grid is not connected within 180 seconds, "timeout failure"), and battery charging and discharging (anti-reverse current / charge and discharge is judged according to SOC, if the power is <3000W, then "cannot charge / discharge").

[0152] Phase sequence judgment module: Three-phase power (R=1500W, S=1000W, T=500W), satisfying the conditions [Abs(abs(Meter)-abs(InvPower))<200W and (InvPower≥0&Meter>0)] → “Phase sequence is correct and CT direction is correct” (otherwise proceed to the next step); power factor <0.9 → “Phase sequence error” and proceed to correction.

[0153] Phase sequence correction module: Three-phase power is the same as before. The R-phase CT of the meter is connected to R, S, and T (if connected to R, it works; otherwise, deduct the S / T phase; the same applies to the S and T phases). Correction is either automatic or manual, and the results are sent via the APP. Timeout → "Correction failed", success → "Detection successful", otherwise "Detection failed".

[0154] This application's technical solution establishes a standardized process for phase sequence detection and correction of photovoltaic / energy storage systems. Multi-dimensional pre-detection (meters, grid, load, etc.) ensures the prerequisites for detection, while the phase sequence judgment and correction mechanism (automatic / manual) ensures reliable system operation. Branch judgments at each stage (such as parameter failures and fault alarms) enhance system robustness, reduce manual intervention, and improve the automation level and efficiency of system commissioning and maintenance.

[0155] like Figure 8 As shown, Figure 8 This is a schematic diagram of a phase sequence detection device provided in this embodiment; this embodiment also provides a phase sequence detection device, the device comprising:

[0156] Inverter control module 601 is used to control the first phase of the inverter to operate at a set power in response to a phase sequence detection request. The first phase includes at least one of R phase, S phase and T phase. The set power includes at least one of a first set power of the R phase, a second set power of the S phase and a third set power of the T phase. The first set power, the second set power and the third set power are different from each other.

[0157] The power acquisition module 602 is used to acquire the power of the second phase of the meter that is electrically connected to the first phase; the second phase includes at least one of the R phase, S phase and T phase;

[0158] The result determination module 603 is used to determine the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase.

[0159] In one embodiment of this application, the phase sequence detection device further includes:

[0160] If the phase sequence detection result is correct, determine whether the positive and negative signs of the set power of the first phase and the meter power of the second phase are the same.

[0161] If the polarity of the set power and the meter power are the same, the polarity connection of the current transformer is determined to be correct; or,

[0162] If the polarity of the set power and the power of the meter are different, it is determined that the polarity connection of the current transformer is incorrect.

[0163] In one embodiment of this application, the phase sequence detection device further includes:

[0164] If the phase sequence detection result is a phase sequence error, the current transformer between the inverter and the meter is disconnected, wherein the current transformer is located between the first phase and the second phase;

[0165] For each target second phase in the second phase of the meter, the current transformer of the target second phase is electrically connected to each first phase of the inverter. If the phase sequence detection result between the target first phase and the target second phase is correct, the phase sequence correction between the target first phase and the target second phase is completed.

[0166] In one embodiment of this application, the result determination module 603 is further configured to:

[0167] The first phase sequence detection result is determined based on the target error between the set power and the absolute value of the meter power.

[0168] The second phase sequence detection result is determined based on the target power factor between the set power and the absolute value of the meter power.

[0169] If both the first phase sequence detection result and the second phase sequence detection result are passed, the phase sequence detection result between the first phase and the second phase is determined to be correct.

[0170] If the first phase sequence detection result fails or the second phase sequence detection result fails, the phase sequence detection result between the first phase and the second phase is determined to be a phase sequence error.

[0171] In one embodiment of this application, the phase sequence detection device is further used for:

[0172] If the target error is less than a preset error threshold, the first phase sequence detection result is determined to be passed; and,

[0173] If the target power factor is greater than the preset power factor, the second phase sequence detection result is determined to be passed.

[0174] In one embodiment of this application, the phase sequence detection device is further used for:

[0175] The inverter is configured with a set power for its three phases, including R-phase, S-phase, and T-phase, and the set power includes output power and / or input power; and,

[0176] The preset error threshold is set based on the ratio between the first set power, the second set power, and the third set power in the set power.

[0177] In one embodiment of this application, the phase sequence detection device is further configured to: trigger the phase sequence detection request if the pre-detection passes;

[0178] The pre-detection includes at least one of the following: determining whether the self-test function of the electricity meter is enabled, determining whether the three-phase imbalance of the inverter is enabled, verifying that the grid on which the inverter is operating exists and is normal, verifying whether the electricity meter is set to be without an electricity meter, verifying whether the electricity meter communication is normal, verifying whether the load of the inverter is disconnected, verifying whether the inverter battery is normal, verifying whether the inverter is normally connected to the grid, and verifying whether the battery charging and discharging is normal.

[0179] In one embodiment of this application, the phase sequence detection device is further used for:

[0180] Determine whether the anti-reverse current function is enabled. If the anti-reverse current function is enabled, charge the battery and determine whether the maximum charging power of the battery is less than a preset charging power threshold.

[0181] If the maximum charging power is less than the preset charging power threshold, the actual charging and discharging limits of the battery are verified based on the remaining battery capacity percentage.

[0182] The battery is considered normal if its actual maximum charging power is less than a preset charging power threshold and its actual maximum discharging power is less than a preset discharging power threshold.

[0183] In this embodiment, the phase sequence detection device responds to a phase sequence detection request and actively controls the first phase of the inverter (at least one of R-phase, S-phase, or T-phase) to operate according to preset mutually exclusive power settings. The first preset power of the R-phase, the second preset power of the S-phase, and the third preset power of the T-phase are all different. Simultaneously, it collects the power meter readings of the second phase (corresponding item in R / S / T phases) directly connected to the first phase. Based on the deviation analysis between the preset power and the measured power, it automatically determines the phase sequence detection result (positive sequence / reverse sequence) between the two phases. This utilizes the inverter's three-phase unbalanced operating mode to achieve efficient and accurate automated phase sequence detection, completely replacing traditional manual wiring verification and significantly improving system debugging efficiency and safety.

[0184] For details on the implementation of each of the above operations, please refer to the previous examples, which will not be repeated here.

[0185] In one embodiment, taking a terminal device as an example, its internal structure diagram can be as follows: Figure 9As shown, the computer device includes a processor, memory, input / output interface, communication interface, display unit, and input device. The processor, memory, and input / output interface are connected via a system bus, and the communication interface, display unit, and input device are also connected to the system bus via the input / output interface. The processor provides computing and control capabilities. The memory includes a non-volatile storage medium and internal memory. The non-volatile storage medium stores the operating system and computer programs. The internal memory provides an environment for the operation of the operating system and computer programs in the non-volatile storage medium. The input / output interface is used for exchanging information between the processor and external devices. The communication interface is used for wired or wireless communication with external terminals; wireless communication can be achieved through Wi-Fi, mobile cellular networks, NFC (Near Field Communication), or other technologies. When the computer program is executed by the processor, it implements a phase sequence detection method for an inverter meter. The display unit of the computer device is used to form a visually visible image. It can be a display screen, a projection device, or a virtual reality imaging device. The display screen can be an LCD screen or an e-ink screen. The input device of the computer device can be a touch layer covering the display screen, or buttons, trackballs, or touchpads set on the casing of the computer device, or external keyboards, touchpads, or mice, etc.

[0186] Those skilled in the art will understand that Figure 9 The structure shown is only a block diagram of a part of the structure related to the present application and does not constitute a limitation on the computer device on which the present application is applied. The specific computer device may include more or fewer components than shown in the figure, or combine certain components, or have different component arrangements.

[0187] Based on the same inventive concept, this application also provides a computer-readable storage medium, which may include: read-only memory (ROM), random access memory (RAM), disk or optical disk, etc.

[0188] Since the computer program stored in the computer-readable storage medium can execute any of the phase sequence detection methods for inverter meters provided in the embodiments of this application, the beneficial effects that any of the phase sequence detection methods for inverter meters provided in the embodiments of this application can achieve can be realized, as detailed in the preceding embodiments, and will not be repeated here.

[0189] Based on the same inventive concept, embodiments of this application also provide a computer program product or computer program, which includes computer instructions stored in a computer-readable storage medium. A processor of a computer device reads the computer instructions from the computer-readable storage medium and executes the computer instructions, causing the computer device to perform the methods provided in the various optional implementations of the above embodiments.

[0190] It should be noted that the object data (including but not limited to user device information, user personal information, etc.) and dialogue data involved in this application are all information and data authorized by the user or fully authorized by all parties, and the collection, use and processing of related data must comply with the relevant laws, regulations and standards of relevant countries and regions. Those skilled in the art will understand that all or part of the processes in the methods of the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium, and when executed, it can include the processes of the embodiments of the above methods.

[0191] Any reference to memory, database, or other media used in the embodiments provided in this application may include at least one of non-volatile and volatile memory. Non-volatile memory may include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory may include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM may be in various forms, such as static random access memory (SRAM) or dynamic random access memory (DRAM), etc.

[0192] The databases involved in the embodiments provided in this application may include at least one type of relational database and non-relational database. Non-relational databases may include, but are not limited to, blockchain-based distributed databases. The processors involved in the embodiments provided in this application may be general-purpose processors, central processing units, graphics processing units, digital signal processors, programmable logic devices, quantum computing-based data processing logic devices, etc., and are not limited to these.

[0193] In the above embodiments of the inverter meter phase sequence detection device, computer-readable storage medium, computer device, and computer program product, the descriptions of each embodiment have different focuses. Parts not described in detail in a particular embodiment can be referred to in the relevant descriptions of other embodiments. Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working process and beneficial effects of the inverter meter phase sequence detection device, computer-readable storage medium, computer program product, computer device, and their corresponding units described above can be referred to the description of the inverter meter phase sequence detection method in the above embodiments, and will not be repeated here.

[0194] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0195] The foregoing has provided a detailed description of the phase sequence detection method, apparatus, computer equipment, computer-readable storage medium, and computer program product for an inverter meter provided in the embodiments of this application. Specific examples have been used to illustrate the principles and implementation methods of this application. The descriptions of the embodiments above are only for the purpose of helping to understand the method and core ideas of this application. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this application. Therefore, the content of this specification should not be construed as a limitation of this application.

Claims

1. A method for detecting the phase sequence of an inverter meter, characterized in that, The method includes: In response to a phase sequence detection request, the first phase of the inverter is controlled to operate at a set power, wherein the first phase includes at least one of an R phase, an S phase, and a T phase, and the set power includes at least one of a first set power of the R phase, a second set power of the S phase, and a third set power of the T phase, wherein the first set power, the second set power, and the third set power are different from each other; The meter power of the second phase, which is electrically connected to the first phase, is collected; the second phase includes at least one of the R phase, S phase, and T phase. Based on the set power of the first phase and the meter power of the second phase, determine the phase sequence detection result between the first phase and the second phase; The step of determining the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase includes: The first phase sequence detection result is determined based on the target error between the set power and the absolute value of the meter power. The second phase sequence detection result is determined based on the target power factor between the set power and the absolute value of the meter power. The target power factor is characterized as the ratio of the absolute value of the meter power to the set power. If both the first phase sequence detection result and the second phase sequence detection result are passed, the phase sequence detection result between the first phase and the second phase is determined to be correct. If either the first phase sequence detection result or the second phase sequence detection result fails, the phase sequence detection result between the first phase and the second phase is determined to be a phase sequence error.

2. The method according to claim 1, characterized in that, The method further includes: If the phase sequence detection result is correct, determine whether the positive and negative signs of the set power of the first phase and the meter power of the second phase are the same. If the polarity of the set power and the meter power are the same, the polarity connection of the current transformer is determined to be correct; or, If the polarity of the set power and the power of the meter are different, it is determined that the polarity connection of the current transformer is incorrect.

3. The method according to claim 1, characterized in that, The method further includes: If the phase sequence detection result is a phase sequence error, the current transformer between the inverter and the meter is disconnected, wherein the current transformer is located between the first phase and the second phase; For each target second phase in the second phase of the meter, the current transformer of the target second phase is electrically connected to each first phase of the inverter respectively; If the phase sequence detection result between the target first phase and the target second phase is correct, the phase sequence correction between the target first phase and the target second phase is completed.

4. The method according to claim 1, characterized in that, The step of determining the first phase sequence detection result based on the target error between the set power and the absolute value of the meter power includes: If the target error is less than a preset error threshold, the first phase sequence detection result is determined to be passed; and, The step of determining the second phase sequence detection result based on the target power factor between the set power and the absolute value of the meter power includes: If the target power factor is greater than the preset power factor, the second phase sequence detection result is determined to be passed.

5. The method according to any one of claims 1 to 4, characterized in that, The method further includes: If the pre-detection passes, the phase sequence detection request is triggered; The pre-detection includes at least one of the following: determining whether the self-test function of the electricity meter is enabled, determining whether the three-phase imbalance of the inverter is enabled, verifying that the grid on which the inverter is operating exists and is normal, verifying whether the electricity meter is set to be without an electricity meter, verifying whether the electricity meter communication is normal, verifying whether the load of the inverter is disconnected, verifying whether the inverter battery is normal, verifying whether the inverter is normally connected to the grid, and verifying whether the battery charging and discharging is normal.

6. The method according to claim 5, characterized in that, The verification of whether the inverter's battery is functioning properly includes: Determine whether the anti-reverse current function is enabled. If the anti-reverse current function is enabled, charge the battery and determine whether the maximum charging power of the battery is less than a preset charging power threshold. If the maximum charging power is less than the preset charging power threshold, the actual charging and discharging limits of the battery are verified based on the remaining battery capacity percentage. The battery is considered normal if its actual maximum charging power is less than a preset charging power threshold and its actual maximum discharging power is less than a preset discharging power threshold.

7. A phase sequence detection device for an inverter meter, characterized in that, The device includes: An inverter control module is used to control the first phase of the inverter to operate at a set power in response to a phase sequence detection request. The first phase includes at least one of an R phase, an S phase, and a T phase. The set power includes at least one of a first set power of the R phase, a second set power of the S phase, and a third set power of the T phase. The first set power, the second set power, and the third set power are different from each other. A power acquisition module is used to acquire the power of the second phase of the meter that is electrically connected to the first phase; the second phase includes at least one of the R phase, S phase and T phase; The result determination module is used to determine the phase sequence detection result between the first phase and the second phase based on the set power of the first phase and the meter power of the second phase. The result determination module is further configured to: The first phase sequence detection result is determined based on the target error between the set power and the absolute value of the meter power. The second phase sequence detection result is determined based on the target power factor between the set power and the absolute value of the meter power. The target power factor is characterized as the ratio of the absolute value of the meter power to the set power. If both the first phase sequence detection result and the second phase sequence detection result are passed, the phase sequence detection result between the first phase and the second phase is determined to be correct. If either the first phase sequence detection result or the second phase sequence detection result fails, the phase sequence detection result between the first phase and the second phase is determined to be a phase sequence error.

8. A computer device, characterized in that, The device includes a processor and a memory, the memory storing multiple instructions; the processor loads instructions from the memory to execute the steps of the phase sequence detection method for an inverter meter according to any one of claims 1 to 6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a plurality of instructions adapted for loading by a processor to perform the steps of the phase sequence detection method for an inverter meter according to any one of claims 1 to 6.

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