A three-phase load cooperative regulation method and system based on smart meter data

Abstract

The application provides a three-phase load cooperative regulation method and system based on smart meter data, and relates to the technical field of load regulation. The method comprises the following steps: collecting three-phase currents of corresponding users through each smart meter; calculating the positive sequence current effective value, negative sequence current effective value and negative sequence current of each three-phase current; combining the positive sequence current effective value and negative sequence current effective value corresponding to each three-phase current to obtain the line energy of the quantitative power distribution area imbalance degree; determining whether the line energy triggers the regulation process based on the gradient field theory, if yes, determining the adjustable negative sequence admittance of the user corresponding to each smart meter to quantify the compensation capacity of each user to the negative sequence current; taking the offset of the negative sequence current as the constraint, calculating the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part, and uploading the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part to the dispatching terminal; performing three-phase load cooperative regulation through the dispatching terminal, otherwise, returning to collect the three-phase current again.

Description

TECHNICAL FIELD

[0001] The present application relates to the technical field of load regulation, in particular to a three-phase load cooperative regulation method and system based on smart meter data. BACKGROUND

[0002] A smart meter is a device that uses digital technology to monitor, collect, and transmit data in real time for electrical equipment. It can not only monitor current, voltage, power, and other electrical data, but also perform remote control and data analysis, providing important support for energy management, load forecasting, and power system optimization. Three-phase load cooperative regulation refers to the process of balancing loads and optimizing energy efficiency in a three-phase power system by adjusting loads in different phases. Using data collected by smart meters, combined with intelligent control systems, the system can adjust the working state of each phase load in real time to ensure the balance of the three-phase system, avoid overload or imbalance, and improve the stability and efficiency of the power system.

[0003] Three-phase load cooperative regulation helps improve the stability of the power system, avoid damage to equipment and energy waste caused by three-phase imbalance. Through real-time data provided by smart meters, the system can accurately adjust the load, optimize power distribution, reduce power loss, and effectively reduce the operating pressure of electrical equipment, thereby prolonging the service life of the equipment, improving system reliability, and promoting energy saving and consumption reduction, meeting the needs of modern smart grids and green development.

[0004] However, existing technologies usually rely on static models or fixed rules for load regulation, fail to fully consider the real-time changes of negative sequence currents in the power network, ignore the cooperative effect between loads, and cannot dynamically adjust according to the real-time power consumption of users, resulting in low regulation efficiency and inability to achieve accurate control of load cooperation, affecting the overall energy efficiency and stability of the power grid. SUMMARY

[0005] In view of the above deficiencies of the prior art, the purpose of the embodiments of the present application is to provide a three-phase load cooperative regulation method based on smart meter data, which can solve the technical problems of the prior art that usually rely on static models or fixed rules for load regulation, fail to fully consider the real-time changes of negative sequence currents in the power network, ignore the cooperative effect between loads, cannot dynamically adjust according to the real-time power consumption of users, have low regulation efficiency, and cannot achieve accurate control of load cooperation, affecting the overall energy efficiency and stability of the power grid.

[0006] The first aspect of the embodiments of the present application proposes a three-phase load cooperative regulation method based on smart meter data, applied to a power regulation network, the power regulation network comprising a plurality of smart meters connected with a dispatching terminal, each smart meter being located in the same distribution area, and each smart meter corresponding to a user; the method comprises:

[0007] S1: collecting three-phase currents of respective users by each of the smart meters;

[0008] S2: calculating positive sequence current effective value, negative sequence current effective value and negative sequence current of each of the three-phase currents;

[0009] S3: combining the positive sequence current effective value and the negative sequence current effective value corresponding to each of the three-phase currents, and aggregating to obtain line energy quantifying the unbalance degree of the distribution area;

[0010] S4: determining whether the line energy triggers a regulation process based on the gradient field theory, if yes, proceeding to step S5, otherwise, returning to step S1;

[0011] S5: determining the adjustable negative sequence admittance of the user corresponding to each of the smart meters to quantify the compensation capability of each of the users to the negative sequence current;

[0012] S6: calculating the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part with the constraint of offsetting the negative sequence current, and uploading the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part to the dispatching terminal;

[0013] S7: performing three-phase load collaborative regulation through the dispatching terminal.

[0014] The second aspect of the embodiment of the application provides a three-phase load collaborative regulation system based on smart meter data, comprising a processor and a memory.

[0015] The memory stores programs or instructions executable on the processor, and the programs or instructions are executed by the processor to implement the steps of the three-phase load collaborative regulation method based on smart meter data as described in the first aspect.

[0016] The third aspect of the embodiment of the application provides a readable storage medium, and the readable storage medium stores programs or instructions, and the programs or instructions are executed by the processor to implement the steps of the three-phase load collaborative regulation method based on smart meter data as described in the first aspect.

[0017] The technical scheme provided by the embodiment of the application has at least the following beneficial effects:

[0018] In the embodiment of the present application, by collecting the three-phase current data of the user in real time, the negative sequence current and the positive sequence current effective value are calculated, and then the line energy is calculated to quantify the load imbalance degree of the power grid. Then, the gradient field theory is used to dynamically trigger the regulation process, accurately describe the trend and distribution of current change, and sensitively identify the small changes of the power grid imbalance. When the load imbalance degree is abnormal, the regulation measures are triggered in time, so as to avoid energy loss and equipment damage, and improve the stability and efficiency of the power grid. By accurately calculating the adjustable negative sequence admittance of the user, the compensation capacity of the user to the negative sequence current is quantified, and the load is adjusted in combination with the real-time data to completely offset the total negative sequence current as a strict constraint. The optimal compensation amount required by each user is calculated, so that the system can be dynamically adjusted according to the real-time change of the load and current. Then, the load imbalance of the power network is responded in real time, the line loss is effectively reduced, the load of the power grid is optimized, and the real-time regulation is improved, so as to improve the energy efficiency and stability of the power grid. BRIEF DESCRIPTION OF DRAWINGS

[0019] The accompanying drawings are included to provide a further understanding of the application and are incorporated in and constitute a part of this specification, illustrate embodiments of the application and together with the description serve to explain the principles of the application. In the drawings:

[0020] Figure 1 is a flowchart of a three-phase load collaborative regulation method based on smart meter data provided by an embodiment of the present application.

[0021] Figure 2 is a structural diagram of a power regulation network provided by an embodiment of the present application.

[0022] Figure 3 is a structural diagram of a three-phase load collaborative regulation system based on smart meter data provided by an embodiment of the present application. DETAILED DESCRIPTION

[0023] In order for those skilled in the art to better understand the technical solutions in the embodiments of the present application, the technical solutions of the present application will be described clearly and completely below with reference to the drawings. Obviously, the described embodiments are only a part of the embodiments of the present application, rather than all the embodiments. It should be understood that these descriptions are only exemplary and are not used to limit the scope of the present application. Based on the embodiments of the present application, all other embodiments obtained by those skilled in the art without creative labor should be within the scope of protection of the present application.

[0024] With reference to the accompanying drawings, the three-phase load cooperative regulation method based on smart meter data provided by the embodiments of the present application will be described in detail through specific examples and application scenarios.

[0025] Reference is made to the accompanying drawings Figure 1 , which shows a flowchart of a three-phase load cooperative regulation method based on smart meter data provided by the embodiments of the present application.

[0026] Reference is made to the accompanying drawings Figure 2 , which shows a structure diagram of a power regulation network.

[0027] The embodiments of the present application provide a three-phase load cooperative regulation method based on smart meter data, which is applied to a power regulation network. The power regulation network includes a plurality of smart meters connected with a dispatching terminal. Each smart meter is located in the same distribution area, and each smart meter corresponds to a user.

[0028] Among them, the distribution area refers to a region in the power system, which is composed of a plurality of power facilities (such as distribution transformers, switches, lines, etc.), and is responsible for distributing power to specific users. It is a management unit in the power network, mainly used for power distribution and dispatching in the region. Deploying multiple smart meters in the same distribution area and connecting them with the dispatching terminal can realize real-time power consumption data collection and load regulation for all users in the region. Since each smart meter corresponds to a user, the load condition of each user can be accurately monitored, and the load imbalance degree can be analyzed in real time and adjusted individually. Through centralized management and data aggregation, the dispatching terminal can quickly identify the imbalance state of the power grid, optimize power distribution, and improve the energy efficiency and system stability of the entire distribution area.

[0029] It can include the following steps:

[0030] S1: Collecting three-phase currents of corresponding users through each smart meter.

[0031] Among them, the three-phase current refers to the current of each phase in a three-phase alternating current system. The current of each phase has its own characteristics and values.

[0032] S2: Calculating the positive sequence current effective value, negative sequence current effective value and negative sequence current of each three-phase current.

[0033] The positive sequence current effective value refers to the part of the three-phase current in a three-phase alternating current system that represents normal power transmission, with a waveform and phase that conforms to the standard of three-phase electricity, corresponding to the load condition when the power grid is operating normally. The negative sequence current effective value refers to the part of the three-phase current caused by unbalanced load or fault in a three-phase current system. Negative sequence current often causes overheating of motors or equipment, affecting system stability. Negative sequence current is a component of three-phase current with opposite phase to positive sequence current, caused by unbalanced load or fault in the power grid, which does not participate in normal power transmission but can cause damage to equipment.

[0034] It should be noted that by calculating the positive sequence current effective value and negative sequence current effective value of each three-phase current, the proportion of normal current and unbalanced current in the power system can be accurately identified. The positive sequence current effective value reflects the power transmission under normal working conditions, while the negative sequence current effective value reflects the current fluctuation caused by unbalanced load or fault. Through these calculations, necessary basis can be provided for subsequent load regulation, which helps to improve the stability and efficiency of the system.

[0035] In one possible implementation, S2 is specifically:

[0036] The positive sequence current effective value, negative sequence current effective value and negative sequence current are calculated based on the symmetrical component method.

[0037] The symmetrical component method is a method for analyzing three-phase unbalanced current, which decomposes three-phase current into positive sequence component, negative sequence component and zero sequence component.

[0038] The calculation formula of the positive sequence current effective value is specifically:

[0039] .

[0040] .

[0041] The calculation formula of the negative sequence current effective value is specifically:

[0042] .

[0043] The calculation formula of the negative sequence current is specifically:

[0044] .

[0045] wherein, , and respectively represent the three-phase current corresponding to the positive sequence current effective value, negative sequence current effective value and negative sequence current collected by the kth smart meter, respectively represent the A-phase current phasor, the B-phase current phasor and the C-phase current phasor collected by the kth smart meter, represents rotating operator, represents the imaginary unit, represents the circular constant, represents the natural constant, and represents the modulo operation.

[0046] wherein, represents the three-phase current collected by the kth smart meter, which can be specifically in the form of a vector.

[0047] Specifically, the process utilizes the symmetrical component method to decompose the three-phase current into positive sequence current, negative sequence current and zero sequence current, which helps to analyze the load imbalance of the power grid. By calculating the positive sequence current effective value, the negative sequence current effective value and the negative sequence current, the imbalance degree of the power grid can be accurately quantified. The positive sequence current reflects the normal load condition, while the negative sequence current reveals the problems caused by load imbalance or faults. Efficient identification of imbalance in the power system provides accurate data support, thereby helping to optimize the regulation of the power grid, improve the stability and energy efficiency of the power system, reduce losses and improve dispatching response speed.

[0048] S3: Combine the positive sequence current effective value and the negative sequence current effective value corresponding to each three-phase current to aggregate the line energy quantifying the imbalance degree of the distribution area.

[0049] wherein, the line energy refers to the energy loss caused by the influence of factors such as wire resistance and load imbalance during the transmission of electricity. During the transmission of electric energy, heat will be generated due to resistance, resulting in a part of the electric energy being lost in the form of heat energy. The line energy is closely related to the load balance state of the power grid. When the load is unbalanced, the negative sequence current will increase the line loss, resulting in reduced efficiency. By combining the positive and negative sequence current effective values to aggregate the line energy quantifying the imbalance degree of the distribution area, the energy loss of the power grid can be accurately evaluated. This method can reflect the impact of load imbalance on the power system in real time, which helps to identify the line loss problems caused by imbalance.

[0050] In one possible implementation, S3 specifically includes:

[0051] S301: Determine the positive sequence active power of the user corresponding to each smart meter according to the positive sequence current effective value.

[0052] The positive sequence active power is the product of the square root of three, the rated line voltage of the distribution area, the positive sequence current effective value and the power factor of the corresponding smart meter.

[0053] The calculation formula of the positive sequence active power is specifically:

[0054] .

[0055] wherein, represents the positive sequence active power of the user corresponding to the kth smart meter, represents the rated line voltage of the distribution area, represents the positive sequence current effective value, represents the power factor of the user corresponding to the kth smart meter.

[0056] wherein, the power factor refers to the ratio of active power to apparent power in the power system, reflecting the phase relationship between current and voltage. Specifically, this positive sequence active power calculation method combines current effective value, power factor and rated line voltage of the distribution area, which can accurately evaluate the power consumption of each user.

[0057] S302: Calculate the user load contribution of each user based on the positive sequence active power, wherein the user load contribution is the ratio of the positive sequence active power corresponding to the user to the total positive sequence active power of the distribution area.

[0058] wherein, the total positive sequence active power of the distribution area is the result of cumulative summation of the positive sequence active power of each user corresponding to the smart meter.

[0059] S303: Calculate the line energy based on the user load contribution and the negative sequence current effective value.

[0060] The calculation formula of line energy is specifically:

[0061] .

[0062] wherein, represents the line energy, represents the resistance value of the main line of the distribution area, represents the user load contribution of the user corresponding to the kth smart meter, and N represents the total number of smart meters.

[0063] Specifically, this process first calculates the positive sequence active power of each user, and determines the load contribution of the user based on the power factor and current effective value, and then calculates the line energy based on the negative sequence current effective value. By aggregating the load contribution and current data of the user, the line loss of the distribution area can be accurately quantified. This method can dynamically reflect the influence of each user on the unbalanced state of the power grid, which helps to identify and optimize energy loss in the power grid, improve the energy efficiency and stability of the power system, timely adjust load distribution, reduce energy loss of the power grid and improve overall operation efficiency.

[0064] S4: Determine whether the line energy triggers the regulation process based on the gradient field theory, if yes, go to step S5, otherwise, return to step S1.

[0065] The gradient field theory is a theory in physics and mathematics that describes how a quantity (such as current, voltage, etc.) changes with position in space. By analyzing the gradient field of a physical quantity, the trend and distribution of the quantity at different positions can be revealed. In power systems, the gradient field theory can help analyze the spatial distribution of load imbalance or energy loss in the power grid, enabling more accurate regulation. Through the gradient field theory, real-time monitoring of energy loss in the power grid can be achieved, and the trend of these losses can be analyzed. When the line energy reaches a certain threshold, indicating that the system load imbalance needs to be adjusted, the gradient field theory can trigger the regulation process in time to avoid excessive loss. This method can sensitively perceive the imbalance state of the power grid and provide a basis for subsequent regulation, improving the intelligence and response speed of power dispatching.

[0066] In one possible implementation, the determination of whether the line energy triggers regulation based on the gradient field theory in S4 specifically includes:

[0067] S401: Calculate the time gradient and phase gradient of the line energy.

[0068] The calculation formula of the time gradient is: .

[0069] wherein, denotes the partial derivative, denotes the line energy at time t and denotes the line energy at time t+Δt, denotes a small time interval, denotes the time gradient.

[0070] The calculation formula of the phase gradient is: . . .

[0071] wherein, denotes the phase angle of denotes the phase angle of the negative sequence current of the kth smart meter, denotes the phase angle of the line energy of the kth smart meter, denotes the phase angle of the negative sequence current, denotes the line energy of the kth smart meter, denotes the phase gradient.

[0072] It should be noted that the process measures the speed of energy change over time and the influence of negative sequence current phase change on line energy by calculating the time gradient and phase gradient of line energy. The time gradient reflects the energy fluctuation caused by power grid load imbalance, while the phase gradient reveals the specific contribution of negative sequence current phase change to the system. Through the calculation of these two gradients, the changes in the state of the power grid can be accurately captured, helping to identify the dynamic changes of load imbalance in a timely manner and providing more accurate decision-making basis for power grid regulation.

[0073] S402: Determine the gradient potential difference that describes the synergistic effect between the time gradient and the phase gradient.

[0074] The calculation formula of the gradient potential difference is specifically:

[0075] .

[0076] .

[0077] wherein, denotes the included angle between the time gradient and the phase gradient, denotes the calculation of the included angle, denotes the gradient potential difference at time t, denotes the cosine function.

[0078] It should be noted that the gradient potential difference is obtained by calculating the synergistic effect between the time gradient and the phase gradient. The gradient potential difference combines the change amplitude of the time gradient and the phase gradient and the included angle information, reflecting the comprehensive change of the power grid imbalance state. By calculating the included angle with the cosine function, the combined effect of time change and phase change on line energy can be quantified. This method can accurately evaluate the dynamic effect of power grid load imbalance, thereby providing a reliable basis for the regulation process and improving the responsiveness and accuracy of power grid scheduling.

[0079] S403: Determine the critical gradient potential difference based on the historical sliding average of the time gradient and the phase gradient.

[0080] The calculation formula of the critical gradient potential difference is specifically:

[0081] .

[0082] wherein, denotes the critical gradient potential difference, and denote the historical sliding average of the time gradient and the phase gradient, respectively.

[0083] It should be noted that the process determines the critical gradient potential difference by calculating the time gradient and the historical sliding average of the phase gradient. The historical sliding average can smooth short-term fluctuations and reflect the long-term trend of the power grid load imbalance. The critical gradient potential difference is adjusted according to the actual operation of the power grid and is used as a reference value for triggering the regulation process. When the gradient potential difference exceeds the critical value, the system can be regulated to ensure the stability and energy efficiency of the power grid.

[0084] S404: In the case that the time derivative of the phase gradient is greater than zero and the gradient potential difference is greater than the critical gradient potential difference, it is determined that the line energy triggers the regulation process, otherwise it is determined that the line energy does not trigger the regulation process.

[0085] It should be noted that the triggering mechanism adopts a double dynamic criterion: the time derivative of the phase gradient indicates that the system imbalance is accelerating deterioration (dynamic change rate), and the gradient potential difference greater than the critical value quantifies the absolute severity of the current imbalance (static threshold). Both conditions must be met to trigger regulation, ensuring sensitivity to early deterioration (derivative criterion) and avoiding false actions on temporary fluctuations (energy criterion), forming an optimal triggering strategy that balances response speed and reliability. This design strictly follows the power system transient stability theory, in which the gradient field represents the driving force of the system away from equilibrium, and the critical potential difference corresponds to the boundary of the system stability domain.

[0086] Specifically, the process calculates the time gradient and phase gradient of the line energy, and combines them with the gradient potential difference of their synergistic effect to accurately determine whether the power grid load imbalance has reached the regulation threshold. The time gradient reflects the speed of energy change, and the phase gradient reveals the phase change of the negative sequence current. By calculating the synergistic effect, the imbalance dynamics in the power grid can be more sensitively captured. When the gradient potential difference exceeds the critical value, the system can trigger the regulation process. Real-time and accurate identification of the dynamic changes of the power grid imbalance, and intelligent regulation based on historical data, optimize the energy efficiency and stability of the power grid, reduce energy loss and improve system response speed.

[0087] S5: Determine the adjustable negative sequence admittance of each smart meter corresponding to the user, to quantify the compensation ability of each user to the negative sequence current.

[0088] Among them, the negative sequence admittance is the conduction ability of the load to the negative sequence current. The adjustable negative sequence admittance is an adjustable negative sequence admittance component designed for user load, which is used to offset the total negative sequence current of the system. By determining the adjustable negative sequence admittance, the compensation ability of each user to the negative sequence current can be quantified. Further, by adjusting the negative sequence admittance component of each user, the negative sequence current caused by load imbalance in the power grid can be effectively compensated, thereby reducing energy loss, optimizing power grid operation, and improving system stability and energy efficiency.

[0089] In a possible implementation, S5 specifically includes:

[0090] S501: determining a virtual negative sequence admittance established by the adjustable negative sequence admittance real part term, the adjustable negative sequence admittance imaginary part term, and the imaginary unit term.

[0091] S502: setting an amplitude constraint of the virtual negative sequence admittance.

[0092] S503: obtaining the adjustable negative sequence admittance in combination with the amplitude constraint and the virtual negative sequence admittance.

[0093] The formula form of the adjustable negative sequence admittance is specifically as follows:

[0094] .

[0095] .

[0096] wherein, and respectively represent the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part of the user corresponding to the kth smart meter, represents the imaginary unit, represents the reference admittance of the user corresponding to the kth smart meter, represents the rated line voltage of the distribution area, represents a preset regulation coefficient related to the load type, represents the adjustable negative sequence admittance of the user corresponding to the kth smart meter.

[0097] wherein the reference admittance is the equivalent admittance of the user load under the rated voltage. The process decomposes the compensation capacity of each user load into an independently controllable real part (active component) and an imaginary part (reactive component) by constructing a virtual negative sequence admittance model, and sets a differentiated regulation coefficient based on the load type (such as a residential area or an industrial park), thereby realizing precise compensation under the premise of ensuring safety.

[0098] It should be noted that a person skilled in the art can set the size of the preset regulation coefficient according to actual needs, which is not limited in the present application. For example, the preset regulation coefficient of a residential area can be set to 0.25, and the preset regulation coefficient of an industrial park can be set to 0.4.

[0099] S6: calculating the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part with the cancellation of the negative sequence current as a constraint, and uploading the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part to a dispatching terminal.

[0100] Wherein, the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part represent the actual response and energy loss of the electrical load to the negative sequence current respectively. Calculating the real part and the imaginary part of the adjustable negative sequence admittance helps to more accurately control the compensation ability of the negative sequence current. The adjustment of the real part and the imaginary part can be dynamically changed according to the real-time state of the power grid, and the electrical characteristics of the user load are accurately adjusted to effectively offset the negative sequence current. After uploading these information to the dispatching terminal, the load distribution of the power grid can be adjusted in time, the balance and energy efficiency of the power grid are improved, the system overload or imbalance is avoided, and the stability and efficiency of power supply are ensured.

[0101] In a possible implementation, S6 specifically includes:

[0102] S601: Superimpose the negative sequence current according to the number of smart meters to obtain the negative sequence current sum.

[0103] S602: Establish the correlation function and the constraint condition of the adjustable negative sequence admittance and the negative sequence current sum with the constraint of offsetting the negative sequence current.

[0104] Correlation function: .

[0105] Constraint condition: .

[0106] Wherein, represents the negative sequence current sum, represents the real part of .

[0107] S603: Solve the correlation function by using the linear algebra orthogonal projection method to obtain a closed-form solution including the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part that satisfies the constraint condition.

[0108] The formula form of the closed-form solution is specifically:

[0109]

[0110] Wherein, represents the conjugate vector of , represents the amplitude of , represents the sine function.

[0111] Wherein, the orthogonal projection method is a mathematical method for solving linear constraint optimization problems by projecting vectors to a specific subspace.

[0112] S604: Upload the adjustable negative sequence admittance real part and the adjustable negative sequence admittance imaginary part to the dispatching terminal.

[0113] It should be noted that the scheme establishes an optimization model with the goal of completely offsetting the system negative sequence current by aggregating the sum of the negative sequence currents of all users, and calculates the compensation amount (including real and imaginary parts) that each user needs to provide by using linear algebra orthogonal projection method. On the premise of ensuring the effectiveness of compensation (non-negative real part), fast and accurate distributed regulation is realized through closed-form solution, and finally the calculation results are uploaded to the dispatch terminal for execution. After compensation, the system negative sequence current is zero, and the constraint condition ensures the physical realizability of the compensation scheme, which not only solves the incomplete compensation problem of traditional methods, but also ensures the safe and stable operation of the power grid.

[0114] S7: Three-phase load collaborative regulation is performed through the dispatch terminal.

[0115] In one possible implementation, S7 specifically includes:

[0116] S701: In the dispatch terminal, commutation instructions are generated according to the size and sign of the adjustable negative sequence admittance real part.

[0117] S702: In the dispatch terminal, reactive compensation instructions are generated according to the size and sign of the adjustable negative sequence admittance imaginary part.

[0118] Optionally, the corresponding instructions can be generated through the DAS, i.e., the power distribution automation system. In addition, the generation can also be based on preset rules, and then encoded for execution.

[0119] S703: The commutation instructions are applied to the adjustable load, and the reactive compensation instructions are applied to the fixed load, to perform three-phase load collaborative regulation.

[0120] Among them, the adjustable load refers to a load with commutation capability (such as EV charging piles, intelligent home appliances, etc.), which can change the distribution of active power in three phases by switching the power supply phase line. Correspondingly, the fixed load refers to a load without commutation capability (such as lighting devices, air conditioners, resistance furnaces, etc.), but can change the reactive power by switching the reactive compensation device (such as capacitor banks / reactors).

[0121] The dispatch terminal intelligently analyzes the real and imaginary part information of the adjustable negative sequence admittance, and generates accurate commutation instructions and reactive compensation instructions respectively: the real part regulation is used to dynamically adjust the phase distribution of the three-phase load (such as transferring the load through intelligent commutation switches), and the imaginary part regulation is used to implement reactive compensation for fixed loads (such as switching capacitor banks), and the two work together to eliminate the amplitude and phase imbalance of the negative sequence current.

[0122] For example, assume that the calculated adjustable negative sequence admittance real part is , S denotes the admittance international unit, i.e., Siemens, then the active power to be transferred is That is, the phase switching instruction is to transfer 188W from the A phase to the B phase. Assuming that the calculated adjustable negative sequence admittance imaginary part is Then the required shunt reactor capacity is That is, the reactive power compensation instruction is to shunt 109 Var reactors.

[0123] In a possible implementation, after S7, further comprising:

[0124] The three-phase current is re-acquired at intervals for a preset time length.

[0125] It should be noted that the size of the preset time length can be set by the person skilled in the art according to actual needs, and the present application does not limit it.

[0126] In actual application, the scheme acquires the three-phase current data of the user in real time through the smart meter, accurately calculates the positive sequence and negative sequence current components by using the symmetrical component method, and then constructs a line energy model reflecting the unbalance degree of the power grid. Then, based on the gradient field theory, the energy change trend is dynamically monitored, when the system imbalance is detected to be deteriorated, the compensation capacity of each user is quantified by calculating the adjustable negative sequence admittance, the optimal compensation scheme is solved by using the orthogonal projection method, and finally the dispatching terminal cooperates to execute the phase switching and reactive power compensation instructions. The full-closed-loop automatic control from data acquisition to regulation and control execution is realized. And the response speed is significantly improved through the gradient field prediction mechanism, and the load is accurately coordinated and regulated by using the admittance decomposition strategy. Compared with the traditional method, the negative sequence current can be more effectively suppressed, the line loss can be reduced, and the operation efficiency and stability of the power grid can be improved.

[0127] In the embodiment of the present application, by real-time acquisition of the three-phase current data of the user, the negative sequence current and the positive sequence current effective value are calculated, and then the line energy is calculated to quantify the load unbalance degree of the power grid. Then, the gradient field theory is used to dynamically trigger the regulation and control process, accurately describe the trend and distribution of current change, and sensitively identify the slight change of the power grid imbalance. When the load unbalance degree is abnormal, the regulation and control measures are triggered in time, so as to avoid energy loss and equipment damage, and improve the stability and efficiency of the power grid. By accurately calculating the adjustable negative sequence admittance of the user, the compensation capacity of the user to the negative sequence current is quantified, and the load is adjusted in combination with real-time data to completely offset the total negative sequence current as a strict constraint. The optimal compensation amount required by each user is calculated, so that the system can be dynamically adjusted according to the real-time change of the load and current. Then, the load imbalance of the power network is responded in real time, the line loss is effectively reduced, the load of the power grid is optimized, and the real-time regulation and control of the power grid is improved. The power efficiency and stability of the power grid are improved.

[0128] The three-phase load cooperative regulation method based on smart meter data provided by the embodiment of the application can be executed by a three-phase load cooperative regulation device based on smart meter data. The three-phase load cooperative regulation device based on smart meter data provided by the embodiment of the application is taken as an example to execute the three-phase load cooperative regulation method based on smart meter data, and the three-phase load cooperative regulation device based on smart meter data provided by the embodiment of the application is described.

[0129] Referring to the accompanying drawings Figure 3 The accompanying drawings show a structure diagram of a three-phase load cooperative regulation system based on smart meter data provided by the embodiment of the application.

[0130] The embodiment of the application provides a three-phase load cooperative regulation system based on smart meter data 20, which comprises a processor 201 and a memory 202.

[0131] The memory 202 stores programs or instructions that can run on the processor 201. When the programs or instructions are executed by the processor 201, the steps of the three-phase load cooperative regulation method based on smart meter data described above are realized, and the same technical effects can be achieved. To avoid repetition, the application will not be described again.

[0132] It should be understood that the processor 201 in the embodiment of the application can be a central processing unit (CPU). The processor can also be other general-purpose processors, digital signal processors (DSP), application specific integrated circuits (ASIC), ready-to-program gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc. The general-purpose processor can be a microprocessor or any conventional processor.

[0133] It is also to be understood that the memory 202 in embodiments of the present application can be volatile or nonvolatile memory, or can include both volatile and nonvolatile memory. Nonvolatile memory can be read-only memory (ROM), programmable ROM (PROM), erasable programmable ROM (EPROM), electrically EPROM (EEPROM), or flash memory. Volatile memory can be random access memory (RAM), which is used as external cache. By way of example, and not limitation, many forms of random access memory can be used, such as static random access memory (SRAM), dynamic random access memory (DRAM), synchronous dynamic random access memory (SDRAM), double-data rate SDRAM (DDR SDRAM), enhanced SDRAM (ESDRAM), Synchlink DRAM (SLDRAM), and direct Rambus RAM (DR RAM).

[0134] The above-described embodiments can be implemented in whole or in part by software, hardware (e.g., circuitry), firmware, or any combination of the three. When implemented in software, the above-described embodiments can be implemented in the form of one or more computer programs that are stored in a computer-readable storage medium. The computer-readable storage medium stores one or more computer instructions or computer programs that, when loaded into a computer, cause the computer to perform the processes or functions described in the embodiments of the present application. The computer can be a general-purpose computer, a special-purpose computer, a computer network, or other programmable apparatus. The computer instructions can be stored in a computer-readable storage medium or transmitted from one computer-readable storage medium to another computer-readable storage medium, such as from a website, a computer, a server, or a data center to another website, computer, server, or data center, via a wired (e.g., infrared, wireless, microwave, etc.) manner. The computer-readable storage medium can be any available medium that can be accessed by a computer or a data storage device such as a server, data center, etc. that contains one or more collections of available media. The available media can be a magnetic medium (e.g., floppy disk, hard disk, magnetic tape), an optical medium (e.g., DVD), or a semiconductor medium. The semiconductor medium can be a solid-state disk.

[0135] It should be understood that the size of the sequence number of each process described above in various embodiments of the present application does not mean the order of execution, and the execution order of each process should be determined by its function and inherent logic, and should not constitute any limitation on the implementation process of the embodiments of the present application.

[0136] Those of ordinary skill in the art can realize that the units and algorithm steps of the examples described in conjunction with the embodiments disclosed herein can be realized in electronic hardware or a combination of computer software and electronic hardware. Whether the functions are realized 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 the present application.

[0137] Those skilled in the art can clearly understand that, for the convenience and brevity of description, the specific working processes of the above-described devices, apparatuses, and units can refer to the corresponding processes in the foregoing method embodiments, which will not be described here.

[0138] In several embodiments provided by the present application, it should be understood that the disclosed devices, apparatuses and methods can be implemented in other manners. For example, the embodiments of the apparatus described above are merely schematic. For example, the division of the units is only a logical function division. There can be another division manner for the actual implementation. For example, a plurality of units or components can be combined or integrated into another device, or some features can be ignored or not executed. In addition, the displayed or discussed mutual couplings or direct couplings or communication connections between different units, can be indirect couplings or communication connections through some interfaces, devices or units, and can be in electrical, mechanical or other forms.

[0139] The units described as separate components can or can not be physically separate, and the components shown as units can or can not be physical units, that is, can be located in one place, or can be distributed on a plurality of network units. Some or all of the units can be selected according to actual needs to achieve the purpose of the embodiment.

[0140] In addition, each functional unit in each embodiment of the present application can be integrated into a processing unit, or each unit can exist physically, or two or more units can be integrated into one unit.

[0141] If the functions are realized in the form of software function units and sold or used as independent products, they can be stored in a computer readable storage medium. Based on this understanding, the technical solutions of the present application or the part of the technical solutions that make essential contributions to the prior art can be embodied in the form of a software product. The computer software product is stored in a storage medium and includes a number of instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of the present application. The aforementioned storage medium includes: a U disk, a mobile hard disk, a read-only memory (ROM), a random access memory (RAM), a magnetic disk or an optical disk, and various media that can store program codes.

[0142] The embodiment of the present application provides a readable storage medium, which includes: a program or instructions stored on the readable storage medium, the program or instructions are executed by a processor to realize the steps of the three-phase load cooperative regulation method based on smart meter data described above, and the same technical effects can be achieved. To avoid repetition, the present application will not be described again.

[0143] It should be pointed out finally that the above embodiments are only used to illustrate the technical solutions of the embodiments of the present application, but not to limit them. Although the present application has been described in detail with reference to the foregoing embodiments, it should be understood by those skilled in the art that the technical solutions recorded in the foregoing embodiments can be modified, or some technical features can be replaced equivalently; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the spirit and scope of the technical solutions of the embodiments of the present application. Any changes or replacements that can be easily thought of by those skilled in the art within the technical scope disclosed by the present application should be covered within the protection scope of the present application.

Claims

1. A three-phase load cooperative regulation method based on smart meter data, characterized in that, The application is applied to a power regulation network, the power regulation network comprises a plurality of smart meters connected with a dispatch terminal, each of the smart meters is located in a same power distribution area, and each of the smart meters corresponds to a user; the method comprises the following steps: S1: collecting three-phase currents of corresponding users through each of the smart meters; S2: calculating positive sequence current effective values, negative sequence current effective values and negative sequence currents of each of the three-phase currents; S3: combining the positive sequence current effective values and the negative sequence current effective values corresponding to each of the three-phase currents, and aggregating to obtain line energy quantifying unbalance degree of the power distribution area; S4: determining whether the line energy triggers a regulation process based on gradient field theory, if yes, entering step S5, otherwise, returning to step S1; S5: determining adjustable negative sequence admittance of the user corresponding to each of the smart meters to quantify compensation capability of each of the users to the negative sequence current; S6: calculating real part of adjustable negative sequence admittance and imaginary part of adjustable negative sequence admittance with the negative sequence current as a constraint, and uploading the real part of adjustable negative sequence admittance and the imaginary part of adjustable negative sequence admittance to the dispatch terminal; S7: performing three-phase load collaborative regulation through the dispatch terminal; wherein, the real part of adjustable negative sequence admittance and the imaginary part of adjustable negative sequence admittance represent actual response and energy loss of electrical load to negative sequence current respectively; wherein, the S6 specifically comprises the following steps: S601: superimposing the negative sequence current according to the number of smart meters to obtain a negative sequence current sum; S602: establishing an associated function of the adjustable negative sequence admittance and the negative sequence current sum and a constraint condition with the negative sequence current as a constraint; S603: solving the associated function by linear algebra orthogonal projection method to obtain a closed-form solution including the real part of adjustable negative sequence admittance and the imaginary part of adjustable negative sequence admittance which satisfy the constraint condition; S604: uploading the real part of adjustable negative sequence admittance and the imaginary part of adjustable negative sequence admittance to the dispatch terminal.

2. The method of claim 1, wherein, The S2 specifically comprises the following steps: calculating the positive sequence current effective value, the negative sequence current effective value and the negative sequence current based on a symmetrical component method. 3.The method of claim 1, wherein, The S3 specifically comprises the following steps: S301: determining positive sequence active power of the user corresponding to each of the smart meters according to the positive sequence current effective value; S302: calculating user load contribution degree of each of the users based on the positive sequence active power, wherein the user load contribution degree is a ratio of the positive sequence active power corresponding to the user to total positive sequence active power of the power distribution area; S303: combining the user load contribution degree and the negative sequence current effective value to calculate the line energy.

4. The method of claim 1, wherein, The step of determining whether the line energy triggers a regulation based on gradient field theory in the S4 specifically comprises the following steps: S401: calculating time gradient and phase gradient of the line energy; S402: determining gradient potential difference describing collaborative effect between the time gradient and the phase gradient; S403: determining critical gradient potential difference based on historical sliding average values of the time gradient and the phase gradient; S404: In the case that the time derivative of the phase gradient is greater than zero and the gradient potential difference is greater than the critical gradient potential difference, it is determined that the line energy triggers the regulation process, otherwise, it is determined that the line energy does not trigger the regulation process.

5. The method of claim 1, wherein, The S5 specifically includes: S501: determining a virtual negative sequence admittance established by a tunable negative sequence admittance real part term, a tunable negative sequence admittance imaginary part term and an imaginary unit term; S502: setting an amplitude constraint of the virtual negative sequence admittance; S503: combining the amplitude constraint and the virtual negative sequence admittance to obtain the tunable negative sequence admittance.

6. The method of claim 1, wherein, The S7 specifically includes: S701: in the dispatching terminal, generating a commutation instruction according to the size and sign of the tunable negative sequence admittance real part; S702: in the dispatching terminal, generating a reactive compensation instruction according to the size and sign of the tunable negative sequence admittance imaginary part; S703: applying the commutation instruction to a tunable load and applying the reactive compensation instruction to a fixed load to perform three-phase load collaborative regulation.

7. The method of claim 6, wherein the method further comprises: After the S7, it further includes: Recollecting the three-phase current at intervals for a preset time length.

8. A three-phase load collaborative regulation system based on smart meter data, characterized in that, It includes: A processor and a memory; The memory stores programs or instructions executable on the processor, and the programs or instructions are executed by the processor to implement the steps of the three-phase load collaborative regulation method based on smart meter data according to any one of claims 1 to 7.

9. A readable storage medium, characterized by, The programs or instructions are stored on the readable storage medium, and the programs or instructions are executed by the processor to implement the steps of the three-phase load collaborative regulation method based on smart meter data according to any one of claims 1 to 7.

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