Distributed load dispatching control method and system for power distribution control equipment

Abstract

The application discloses a distributed load scheduling control method and system for power distribution control equipment, and relates to the technical field of load scheduling control, which comprises the following steps: collecting electrical parameters of multiple power distribution branches, calculating an aging penalty factor based on a preset electrical life loss model; generating a state message containing the aging penalty factor and a local adjustable capacity margin, and broadcasting the state message to neighbor nodes in a peer-to-peer network; receiving the state message broadcasted by the neighbor nodes by the local power distribution branch to perform distributed negotiation, determining the target load distribution ratio of the local power distribution branch; and controlling the local power distribution branch to perform load scheduling control. The technical problems that the existing technology ignores the hidden aging differences of power distribution control equipment, causes load distribution imbalance between new and old equipment, accelerates the deterioration of old equipment, and causes uneven overall system life are solved, and the technical effects of improving the overall operation reliability of the power distribution system, the load distribution health balance between equipment, and the effective service life are achieved.

Description

Technical Field

[0001] This invention relates to the technical field of load scheduling and control, specifically to a distributed load scheduling and control method and system for power distribution control equipment. Background Technology

[0002] Current mainstream load dispatching strategies generally follow the principle of equal distribution based on real-time electrical quantities. That is, based on the real-time effective value of current, apparent power, or rated capacity margin of each branch, the output or load switching of each device is dynamically adjusted through proportional allocation algorithms (such as equal current ratio or equal power ratio). However, the current-only dispatching strategy completely ignores the differences in the lifespan of the power distribution control equipment itself. In actual operation, the historical operating conditions of each power distribution control device, such as the number of disconnections, the arcing time of fault interruption, and the amplitude of load inrush current, vary greatly, which directly affects the degree of electrical wear and erosion of the contact materials. This results in the actual remaining electrical lifespan of equipment of the same model and similar commissioning time being several times different. When the load is distributed proportionally based on rated capacity or real-time current, severely aged equipment is forced to bear load tasks that are disproportionate to its health status, falling into the reverse dispatching dilemma of "new equipment getting worn out and old equipment burning out". The status messages in the existing peer-to-peer network usually only contain instantaneous information such as current, voltage, power, and switch status, and cannot incorporate aging differences into the optimization objective, causing the negotiation result to lose the possibility of global optimization from the source. Furthermore, offline life assessment or regular maintenance and replacement strategies cannot dynamically adjust load distribution during operation to proactively delay aging, and cannot improve load imbalance at the system level.

[0003] Therefore, current technologies suffer from the technical problem of neglecting the implicit aging differences of power distribution control equipment, leading to an imbalance in load distribution between old and new equipment, accelerating the deterioration of old equipment, and causing an uneven lifespan of the overall system. Summary of the Invention

[0004] This application provides a distributed load scheduling and control method and system for power distribution control equipment, which solves the technical problems in the prior art that ignore the implicit aging differences of power distribution control equipment, causing load imbalance between new and old equipment, accelerating the deterioration of old equipment, and resulting in an uneven lifespan of the overall system. It achieves the technical effect of improving the overall operational reliability of the power distribution system, the balance of load distribution health among equipment, and the effective service life.

[0005] This application provides a distributed load scheduling control method for power distribution control equipment. The method includes: collecting electrical parameters of multiple power distribution branches; calculating an aging penalty factor based on a preset electrical lifetime loss model, wherein the aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment; generating a status message containing the aging penalty factor and a local adjustable capacity margin based on the aging penalty factor, and broadcasting the status message to neighboring nodes in the peer-to-peer network; receiving the status message broadcast by the neighboring nodes, performing distributed negotiation based on the locally stored aging penalty factor and the aging penalty factor in the received status message, and determining a local target load allocation ratio; and controlling the local power distribution branch to perform load scheduling control according to the target load allocation ratio.

[0006] In a possible implementation, the construction of the electrical life loss model includes: obtaining the cumulative allowable number of interruptions of the power distribution control equipment under nominal current and standard on / off conditions, and using the cumulative allowable number of interruptions as the baseline total electrical life; under the same nominal current conditions, measuring the single-interruption contact mass loss corresponding to different arcing durations, and establishing a first correspondence between the arcing duration and the single-interruption contact mass loss; under the same arcing duration conditions, measuring the single-interruption contact mass loss corresponding to different on / off currents, and establishing a second correspondence between the on / off current and the single-interruption contact mass loss; nonlinearly superimposing the first and second correspondences to generate a wear function characterizing the wear rate per unit time, and constructing an electrical life loss model for calculating the cumulative wear based on the wear function.

[0007] In a possible implementation, electrical parameters of multiple power distribution branches are collected, and an aging penalty factor is calculated based on a preset electrical life loss model. This includes: at the instant the power distribution branch performs a closing or opening operation, collecting the recovery voltage waveform and the current waveform flowing through the contacts; identifying the moment of arc generation and the moment of arc extinction based on the recovery voltage waveform and the current waveform, and calculating the time difference, which is recorded as the arc duration; extracting the effective value of the current within the arc duration from the current waveform; substituting the arc duration and the effective value of the current into the electrical life loss model to calculate the single wear increment corresponding to this operation; adding the single wear increment to the historical cumulative wear amount to obtain the updated current cumulative wear amount; and calculating the percentage of the current cumulative wear amount to the total reference electrical life as the aging penalty factor.

[0008] In a possible implementation, based on the aging penalty factor, a status message containing the aging penalty factor and the local adjustable capacity margin is generated, including: reading the rated current limit of the local distribution branch and the current real-time load power; calculating the difference between the full power corresponding to the rated current limit and the current real-time load power, and recording the difference as the initial adjustable capacity; determining whether the aging penalty factor exceeds a preset aging warning line; if the aging penalty factor exceeds the aging warning line, multiplying the initial adjustable capacity by a preset reduction factor, and recording the multiplication result as the local adjustable capacity margin; if the aging penalty factor does not exceed the aging warning line, directly recording the initial adjustable capacity as the local adjustable capacity margin; and encapsulating the aging penalty factor and the local adjustable capacity margin into a status message of a preset format.

[0009] In a possible implementation, the local distribution branch receives the status message broadcast by the neighboring node, and performs distributed negotiation based on the locally stored aging penalty factor and the aging penalty factor in the received status message. This includes: parsing the status message, extracting the aging penalty factor of the neighboring node and the local adjustable capacity margin of the neighboring node; summarizing the locally stored aging penalty factor and all extracted aging penalty factors to form a negotiation dataset; based on the negotiation dataset, gradually approaching the state point with the lowest total system wear through multiple rounds of iterative calculation; when the state point meets the preset convergence condition, stopping the iterative calculation, and recording the local load percentage value at this time as the target load allocation ratio.

[0010] In a possible implementation, based on the negotiated dataset, the system gradually approaches the state point with the lowest total wear through multiple rounds of iterative calculations. This includes: setting load weights for each power distribution control device according to the aging penalty factor in the negotiated dataset, wherein the larger the aging penalty factor value, the lower the load weight; simulating the allocation of the total load in the system based on the load weights and the local adjustable capacity margin in the negotiated dataset to generate a preliminary allocation scheme; determining whether the preliminary allocation scheme meets the preset system total power balance constraints and the upper limit constraints of each device's capacity; if not, adjusting the load weights and re-simulating the allocation until the constraints are met, and determining the allocation result when the constraints are met as the target load allocation ratio.

[0011] In a possible implementation, load scheduling control of the local power distribution branch is performed according to the target load allocation ratio, including: parsing the target load allocation ratio to obtain the corresponding expected load capacity value; collecting the current actual power value of the local power distribution branch and calculating the power difference between the expected load capacity value and the current actual power value; if the power difference is positive and exceeds a preset allowable error band, it is determined that the local power is in a power deficit state, a load takeover request message is sent to the neighboring node, and the corresponding capacity of the standby branch switch is closed according to the size of the power difference; if the power difference is negative and exceeds the preset allowable error band, it is determined that the local power is in a power surplus state, a load unloading command is generated according to the absolute value of the power difference, the disconnection operation of the local non-critical load branch is controlled, or a load transfer request message is sent to the neighboring node.

[0012] In a possible implementation, the method further includes convergence judgment: recording the target load allocation ratio of the current iteration, subtracting it from the target load allocation ratio of the previous iteration item by item to obtain the change in ratio for each item; calculating the sum of the absolute values ​​of all ratio changes, defining it as the convergence fluctuation value, and comparing the convergence fluctuation value with a preset convergence threshold; if the convergence fluctuation value is less than or equal to the convergence threshold, the negotiation is determined to be converged, and the current target load allocation ratio is locked; if the convergence fluctuation value is greater than the convergence threshold, the negotiation is determined to be unconverged, the current target load allocation ratio is retained as the historical allocation ratio for the next round of comparison, and the distributed negotiation is returned to be executed.

[0013] In a possible implementation, the method further includes handling abnormal nodes: monitoring the interval between neighboring nodes sending the status messages; if the interval between any neighboring node exceeds a preset heartbeat cycle, or if the aging penalty factor value in the received status message changes abruptly and exceeds a preset physical range, then in subsequent distributed negotiation steps, the status message data of this abnormal neighboring node is blocked.

[0014] This application also provides a distributed load scheduling control system for power distribution control equipment. The system includes: an aging penalty factor calculation module, used to collect electrical parameters of multiple power distribution branches and calculate an aging penalty factor based on a preset electrical lifetime loss model, wherein the aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment; a status message generation module, used to generate a status message containing the aging penalty factor and local adjustable capacity margin based on the aging penalty factor, and broadcast the status message to neighboring nodes in the peer-to-peer network; a load allocation ratio determination module, used for the local power distribution branch to receive the status message broadcast by the neighboring node, and to perform distributed negotiation based on the locally stored aging penalty factor and the aging penalty factor in the received status message to determine the local target load allocation ratio; and a load scheduling control module, used to control the local power distribution branch to perform load scheduling control according to the target load allocation ratio.

[0015] The proposed distributed load scheduling control method and system for power distribution control equipment involves collecting electrical parameters from multiple power distribution branches, calculating an aging penalty factor based on a pre-set electrical lifetime loss model, generating a status message containing the aging penalty factor and local adjustable capacity margin, and broadcasting it to neighboring nodes in a peer-to-peer network. Local power distribution branches receive the status messages broadcast by neighboring nodes and conduct distributed negotiation to determine the local target load allocation ratio. Finally, the system controls the local power distribution branches to perform load scheduling control. This solves the technical problems in existing technologies where ignoring the implicit aging differences of power distribution control equipment leads to load imbalance between new and old equipment, accelerates the deterioration of old equipment, and causes an overall uneven system lifespan. It achieves the technical effects of improving the overall operational reliability of the power distribution system, the balance of load distribution health among equipment, and the effective service life. Attached Figure Description

[0016] To more clearly illustrate the technical solutions of the embodiments of this disclosure, the accompanying drawings of the embodiments of this disclosure will be briefly described below. Flowcharts are used in this application to illustrate the operations performed by the system according to the embodiments of this application. It should be understood that the preceding or following operations are not necessarily performed precisely in sequence. Instead, various steps can be processed in reverse order or simultaneously as needed. Furthermore, other operations can be added to these processes, or one or more steps can be removed from these processes.

[0017] Figure 1 This is a schematic flowchart of a distributed load scheduling and control method for power distribution control equipment provided in an embodiment of this application.

[0018] Figure 2 This is a schematic diagram of the structure of a distributed load dispatching control system for power distribution control equipment provided in an embodiment of this application.

[0019] Figure labeling: Aging penalty factor calculation module 10, status message generation module 20, load distribution ratio determination module 30, load scheduling control module 40. Detailed Implementation

[0020] To further illustrate the technical means and effects adopted by the present invention in order to achieve the intended purpose, the following detailed description is provided in conjunction with the accompanying drawings and preferred embodiments, based on the specific implementation methods, structures, features and effects of the present invention.

[0021] This application provides a distributed load scheduling and control method for power distribution control equipment, which is applied to a peer-to-peer network system composed of multiple power distribution control equipment, each of which is used to manage at least one power distribution branch.

[0022] Preferably, the power distribution control equipment includes, but is not limited to, intelligent circuit breakers, solid-state power controllers, feeder terminal units, power distribution automation terminals, and intelligent load switches. These devices are capable of acquiring electrical quantities (current, voltage), performing on / off operations, and possessing data communication capabilities. A peer-to-peer network system refers to a communication topology formed by interconnecting multiple power distribution control devices through a network. There is no dedicated management node responsible for global calculations and command issuance; devices can directly exchange data, and each device only communicates with its directly connected adjacent devices (neighbor nodes). A power distribution branch refers to an independent electrical branch line that extends from the power distribution bus or an upstream power distribution node to supply power to a specific load area. For example, in a low-voltage distribution cabinet, multiple outgoing switches extend from the main incoming switch, and each outgoing switch and its downstream lines constitute a power distribution branch. In a data center cabinet, each output terminal and its downstream cabinet power supply line constitute a power distribution branch. In a power distribution network, a feeder extending from a certain bay of a ring network cabinet to a power distribution transformer constitutes a power distribution branch. One power distribution control device can manage one or more power distribution branches at the same time. For example, a multi-circuit intelligent circuit breaker can simultaneously control 4 or 8 outgoing branches, with each branch being monitored and controlled independently.

[0023] like Figure 1 As shown, the distributed load dispatch control method for power distribution control equipment includes: Step S100: Collect electrical parameters of multiple power distribution branches, and calculate the aging penalty factor based on a preset electrical life loss model. The aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment.

[0024] Step S100 further includes: obtaining the cumulative allowable number of interruptions of the power distribution control equipment under nominal current and standard on / off conditions, and using the cumulative allowable number of interruptions as the reference total electrical lifetime; under the same nominal current conditions, measuring the single-interruption contact mass loss corresponding to different arcing durations, and establishing a first correspondence between the arcing duration and the single-interruption contact mass loss; under the same arcing duration conditions, measuring the single-interruption contact mass loss corresponding to different on / off currents, and establishing a second correspondence between the on / off current and the single-interruption contact mass loss; nonlinearly superimposing the first and second correspondences to generate a wear function characterizing the wear rate per unit time, and constructing an electrical lifetime loss model for calculating the cumulative wear based on the wear function.

[0025] Preferably, the nominal current refers to the rated operating current value marked on the nameplate of the power distribution control equipment. For example, if a circuit breaker is marked with In=100A, then 100A is the nominal current of the equipment. The standard switching conditions refer to the operating conditions uniformly specified in the factory test or type test of the equipment. Specifically, these include the switching current being equal to the nominal current value, the power factor of the test circuit meeting the corresponding standard, the arcing time being the typical arcing time inherent to the equipment under the nominal current conditions, and the external conditions such as ambient temperature and air pressure being maintained at the benchmark values ​​specified in the product standard. Then, the cumulative number of permissible interruptions of the power distribution control equipment under the nominal current and standard switching conditions is obtained, that is, the cumulative number of switching operations that the equipment can withstand from a brand new state until the contact wear reaches the scrap limit. This data is given by the equipment manufacturer through type testing. For example, a certain model of circuit breaker can be interrupted 20,000 times under the condition of In=100A. The cumulative number of permissible interruptions is used as the total reference electrical life to determine the total operating quota of the brand new equipment throughout its entire life cycle.

[0026] Preferably, under the same nominal current conditions, the circuit parameters are artificially changed, such as changing the loop impedance or power factor, so that the arcing time generated by each breaking operation is different. For example, the arcing duration is set to 2ms, 4ms, 6ms, 8ms, and 10ms respectively, and multiple sets of tests are conducted. Before and after each breaking operation, the moving contact and the stationary contact are weighed with a precision balance (accuracy of 0.1mg level) and the mass difference before and after the operation is calculated to determine the amount of contact material ablation and evaporation caused by this switching operation, that is, the mass loss of the contact in a single breaking operation. Then, the first correspondence between the arcing duration and the mass loss of the contact in a single breaking operation is established. This correspondence grows non-linearly, that is, when the arcing time is doubled, the mass loss will increase several times. Under the same arcing duration, multiple sets of tests were conducted by varying the amplitude of the switching current, for example, setting the switching current to 0.2In, 0.4In, 0.6In, 0.8In, 1.0In, and 1.2In (In being the nominal current). The single-break contact mass loss corresponding to different switching currents was measured, establishing a second correspondence between the switching current and the single-break contact mass loss. This correspondence also exhibits non-linear growth, especially with a sharp increase in mass loss after the current exceeds the nominal value. Then, the first and second correspondences were non-linearly superimposed, treating the arcing duration and switching current as two independent variables and coupling them according to the arc energy equation to determine the arc energy. The arcing duration affects the upper limit of integration, while the effective value of the current affects the integration amplitude. The two correspondences were then coupled with the arc energy as the intermediate variable to obtain a wear function, which characterizes the wear rate per unit time, i.e., the contact wear amount per millisecond of arcing time. An electrical lifetime loss model for calculating cumulative wear is constructed based on the wear function. The arc duration and on / off current of each on / off operation are recorded and substituted into the wear function to calculate the wear amount of this operation. The wear amounts of all historical operations are added together to obtain the total cumulative wear amount. The total cumulative wear amount is divided by the total baseline electrical lifetime to obtain the lifetime consumption percentage, which is the aging penalty factor.

[0027] Furthermore, step S100 also includes: at the instant the power distribution branch performs a closing or opening operation, acquiring the recovery voltage waveform and the current waveform flowing through the contacts; based on the recovery voltage waveform and the current waveform, identifying the moment of arc generation and the moment of arc extinction and calculating the time difference, recording it as the arc duration; extracting the effective value of the current within the arc duration from the current waveform; substituting the arc duration and the effective value of the current into the electrical life loss model to calculate the single wear increment corresponding to this operation; accumulating the single wear increment with the historical cumulative wear amount to obtain the updated current cumulative wear amount; calculating the percentage of the current cumulative wear amount to the total reference electrical life as the aging penalty factor.

[0028] Preferably, the instant of closing or opening operation refers to the moment when the moving contact of the power distribution control equipment begins to move and separates from or contacts the stationary contact after receiving the execution command (opening operation) or (closing operation). At this moment, the recovery voltage waveform across the contact is acquired. That is, the curve of the voltage signal across the contact gap after the moving contact separates from the stationary contact during the opening operation, changing with time. Before the contact separates, the voltage across the contact is close to zero. At the instant of contact separation, an electric arc is generated in the contact gap, and the voltage drop across the arc column is the recovery voltage. Its amplitude is determined by the system power supply voltage, and its instantaneous value is... The current waveform changes sinusoidally with the AC voltage frequency cycle, directly reflecting the voltage change characteristics during arc combustion. The current waveform flowing through the contacts is then collected by a current transformer (CT) or Rogowski coil. This is the curve of the instantaneous current value flowing through the main circuit contacts of the power distribution control equipment over time within the same time period. For example, when a disturbance signal of contact action after the current crosses zero is detected or the rising edge of an operation command is received, waveform recording is started. Before the contacts separate, the current waveform is continuous and close to a sinusoidal waveform. After the contacts separate, high-frequency harmonic components are superimposed in the current waveform, resulting in waveform distortion.

[0029] Preferably, the arc generation moment refers to the instant when the arc plasma channel is first formed in the contact gap, corresponding to the instant when the moving contact and the stationary contact separate. In the closing operation, the arc generation moment corresponds to the moment just before the moving contact contacts the stationary contact, when a pre-breakdown arc is generated due to the breakdown of the electric field in the contact gap. The arc extinguishing moment refers to the instant when the arc plasma channel dissipates and the current is completely interrupted. In AC circuits, the arc usually extinguishes near the point where the current naturally crosses zero. The time difference is obtained by subtracting the sampling point number corresponding to the arc generation moment from the sampling point number corresponding to the arc extinguishing moment, multiplying by the sampling interval time (the reciprocal of the sampling period), and recording it as the arc duration.

[0030] Preferably, the arc duration is a continuous sampling interval from the sampling point at the moment of arc generation to the sampling point at the moment of arc extinction, i.e., all sampling points covered by the calculated arc duration. Based on the identified sampling point numbers at the moments of arc generation and extinction, current sampling data within this interval is extracted. All current sampling values ​​within this interval are read, and the root mean square (RMS) of the current waveform sampling value sequence is calculated to obtain the effective current value during the arcing period of this switching operation. This value is then used as an input variable and substituted into the electrical life loss model for calculation to obtain the contact material mass loss caused by this switching operation. Finally, the single wear increment is added to the historical cumulative wear amount to obtain the updated current cumulative wear amount. The historical cumulative wear amount refers to the total contact mass loss caused by all switching operations in the entire service history of the power distribution control equipment before this operation. Finally, the percentage of the current cumulative wear amount to the total baseline electrical life is calculated as an aging penalty factor; a larger value indicates more severe contact wear and a shorter remaining electrical life.

[0031] Step S200: Based on the aging penalty factor, generate a status message containing the aging penalty factor and the local adjustable capacity margin, and broadcast the status message to neighboring nodes in the peer network.

[0032] Step S200 further includes: reading the rated current limit and current real-time load power of the local power distribution branch; calculating the difference between the full power corresponding to the rated current limit and the current real-time load power, and recording the difference as the initial adjustable capacity; determining whether the aging penalty factor exceeds a preset aging warning line; if the aging penalty factor exceeds the aging warning line, multiplying the initial adjustable capacity by a preset reduction factor, and recording the multiplication result as the local adjustable capacity margin; if the aging penalty factor does not exceed the aging warning line, directly recording the initial adjustable capacity as the local adjustable capacity margin; and encapsulating the aging penalty factor and the local adjustable capacity margin into a status message of a preset format.

[0033] Preferably, based on the rated current of the power distribution control equipment itself, the current carrying capacity of the power distribution branch cables, and the setting value of the upstream protection device, the rated current limit of the local power distribution branch is read. This is the maximum allowable long-term operating current value specified in the design of the power distribution control equipment and the power distribution branches it manages. Then, using the installed voltage transformers and current transformers, the phase voltage and phase current of the branch are collected in real time. The active power is calculated and the instantaneous power is determined to obtain the actual active power value transmitted by the power distribution branch at the current moment, i.e., the current real-time load power. The full-rated power corresponding to the rated current limit refers to the maximum power value that the branch can carry under the rated current limit. The difference between the full-rated power corresponding to the rated current limit and the current real-time load power is calculated, and the difference is recorded as the initial adjustable capacity, representing how much additional power the branch can carry at the current moment without exceeding the rated limit. For example, if the current load power is 32.5kW and the full-rated power is 59.2kW, then the initial adjustable capacity = 59.2 - 32.5 = 26.7kW.

[0034] Preferably, the preset aging warning line is a percentage threshold set by system maintenance personnel or equipment manufacturers based on factors such as the remaining lifespan of the equipment to be maintained until the next planned maintenance, the inflection point of accelerated equipment wear, and system redundancy requirements. This threshold represents a level of wear on the equipment contacts that should limit its load-bearing capacity to delay further aging; for example, the preset aging warning line might be 30%. The current aging penalty factor value is compared to this warning line value. If the aging penalty factor exceeds the aging warning line, the initial adjustable capacity is multiplied by a preset reduction factor, where the reduction factor is a value between 0 and 1, determined based on the equipment's importance and safety margin. Pre-setting is required, for example, setting a reduction factor of 0.4. The multiplication result is recorded as the local adjustable capacity margin, which is the actual power value that the branch can use to handle additional loads after considering aging factors. For example, if the current aging penalty factor of a certain device is 35%, exceeding the warning line of 30%, then the calculation for this branch is executed. The local adjustable capacity margin = initial adjustable capacity × reduction factor = 26.7kW × 0.4 = 10.68kW. That is, the branch physically has 26.7kW of spare capacity, but due to severe equipment aging, the system will only report 10.68kW of available capacity during negotiation, actively reducing the possibility of being assigned more loads. If the aging penalty factor does not exceed the warning line, it means that the equipment is in good health, and the initial adjustable capacity is directly recorded as the local adjustable capacity margin. That is, the branch participates in the negotiation with its actual physical available capacity and can normally handle additional loads. Finally, the aging penalty factor and the local adjustable capacity margin are encapsulated into a status message in a preset format, including but not limited to message type, aging penalty factor, local adjustable capacity margin and message generation timestamp. The status message is then broadcast to neighboring nodes in the peer network to inform neighboring nodes of the current load-bearing capacity of this device and to transmit the aging status of this device.

[0035] In step S300, the local power distribution branch receives the status message broadcast by the neighboring node, and performs distributed negotiation based on the aging penalty factor stored locally and the aging penalty factor in the received status message to determine the local target load allocation ratio.

[0036] Step S300 further includes parsing the status message, extracting the aging penalty factor of the neighboring node and the local adjustable capacity margin of the neighboring node; summarizing the locally stored aging penalty factor and all extracted aging penalty factors to form a negotiation dataset; based on the negotiation dataset, gradually approaching the state point with the lowest total system wear through multiple rounds of iterative calculation; when the state point meets the preset convergence condition, stopping the iterative calculation, and recording the local load ratio value at this time as the target load allocation ratio.

[0037] Preferably, parsing status messages includes reading the message types of power distribution control equipment in the peer-to-peer network topology that have direct communication links with this device and are located adjacent to the physical electrical connection, extracting the aging penalty factor and local adjustable capacity margin of neighboring nodes, summarizing the locally stored aging penalty factor and all extracted aging penalty factors, that is, parsing the aging penalty factor values ​​of each neighboring device from the status messages sent by all neighboring nodes, forming a negotiation dataset containing the aging status information of all participating nodes required for this negotiation. The total system wear refers to the sum of the wear of the contacts of all power distribution control equipment participating in this negotiation. Since the cumulative wear of each equipment is different, when the total load is distributed to different equipment, the load borne by each equipment will lead to different additional wear rates. The minimum total system wear refers to finding a load distribution scheme that minimizes the total wear rate or cumulative wear increment of all equipment after bearing the corresponding load, under the premise of satisfying the capacity constraints of each equipment and the balance of the total system power. Multiple rounds of iterative calculations are performed. After each round, the result of this round is used as the input of the next round to gradually update the distribution ratio and gradually approach the state point of minimum total system wear. When the state point meets the preset convergence condition, that is, the sum of the absolute values ​​of the changes between two rounds of iteration is less than the preset threshold, the iterative calculation stops and the local load ratio value at this time is recorded as the target load distribution ratio.

[0038] Furthermore, step S300 also includes setting load weights for each power distribution control device according to the aging penalty factor in the negotiation dataset, wherein the larger the aging penalty factor value, the lower the load weight; simulating the allocation of the total load in the system based on the load weights and the local adjustable capacity margin in the negotiation dataset to generate a preliminary allocation scheme; determining whether the preliminary allocation scheme meets the preset system total power balance constraints and the upper limit constraints of each device capacity; if not, adjusting the load weights and re-simulating the allocation until the constraints are met, and determining the allocation result when the constraints are met as the target load allocation ratio.

[0039] Preferably, based on the aging penalty factor in the negotiated dataset, a load weight is assigned to each power distribution control device. This weight represents the proportion of the total load that a device can receive relative to other devices during the load allocation process. The direction of the load weight assignment is opposite to the direction of the aging penalty factor value; that is, devices with more severe aging are assigned smaller weight values ​​and bear less load in the allocation, while devices with less aging are assigned larger weight values ​​and bear more load in the allocation. Then, the calculated load weights of each device are used as the basic basis for allocation. The total load in the system is simulated and allocated in the calculator / processor memory. Specifically, when performing the simulated allocation, the capacity limit reported by each device needs to be considered simultaneously. Power exceeding the capacity margin cannot be allocated to any device; that is, the power allocated to the device is ≤ the adjustable capacity margin of the device. A preliminary allocation scheme is then generated. The system's total power balance constraint means that the sum of the power allocated to all devices must equal the total system load. The upper limit constraint for each device's capacity means that the power allocated to each device must not exceed the device's local adjustable capacity margin. The system determines whether the initial allocation scheme meets the preset system total power balance constraint and the upper limit constraint for each device. If not, the load weights are adjusted. For example, if the allocated power to a severely aged device exceeds its capacity margin, the weight of that device is further reduced. If an under-allocated device causes other devices to exceed their capacity, the weight of the device with larger remaining capacity is increased. If the total allocated power is less than the total load, the weight of the device with remaining capacity is increased, and the simulation allocation is repeated until the constraints are met. The allocation result when the constraints are met is determined as the target load allocation ratio.

[0040] Step S400: Control the local power distribution branch to perform load scheduling control according to the target load allocation ratio.

[0041] Step S400 further includes: parsing the target load allocation ratio to obtain the corresponding expected load capacity value; collecting the current actual power value of the local distribution branch and calculating the power difference between the expected load capacity value and the current actual power value; if the power difference is positive and exceeds a preset allowable error band, it is determined that the local area is in a power deficit state, a load takeover request message is sent to the neighboring node, and the corresponding capacity of the standby branch switch is closed according to the size of the power difference; if the power difference is negative and exceeds the preset allowable error band, it is determined that the local area is in a power surplus state, a load unloading command is generated according to the absolute value of the power difference, the disconnection operation of the local non-critical load branch is controlled, or a load transfer request message is sent to the neighboring node.

[0042] Preferably, the target load allocation ratio is analyzed to obtain the corresponding expected power carrying capacity value. This percentage value is multiplied by the total system load to calculate the absolute value of the active power that the equipment should carry. Then, the voltage and current transformers installed on the equipment are used to measure and calculate the actual active power value transmitted by the branch at the current moment. The power difference between the expected power carrying capacity value and the current actual power value is calculated. The sign and absolute value of this difference reflect the direction and magnitude of the deviation of the local branch from the target value. The allowable error band is a preset power deviation tolerance value used to prevent the equipment from frequently switching operations near the target value (i.e., preventing...). (To prevent oscillation), it is usually set to 1% to 3% of the total system load or 2% to 5% of the rated capacity of the equipment. If the power difference is positive and exceeds the preset allowable error range, it is determined that the local area is in a power deficit state, indicating that the equipment needs to increase the load it carries. It sends a load takeover request message to the neighboring node and closes the corresponding capacity of the standby branch switch according to the size of the power difference to perform a physical load increase operation. This includes sorting each standby branch in descending order of capacity, closing the branches whose capacity does not exceed the remaining deficit value in sequence, and sending a closing control signal to the switch operating mechanism of the corresponding branch to make the main contacts of the switch close, and the branch begins to transmit power. If the power difference is negative and exceeds the preset allowable error range, it indicates that the equipment needs to reduce its load. The local system is then considered to be in a power surplus state. Based on the absolute value of the power difference, a load unloading command is generated to cut off power to certain branches. This controls the disconnection of non-critical load branches or sends load transfer request messages to neighboring nodes. Non-critical load branches refer to those branches managed by the power distribution control equipment that can be preferentially disconnected based on their load importance level. The classification criteria typically include: essential loads such as fire protection, security, and emergency lighting, which cannot be disconnected; critical production equipment and core server loads, which should be avoided as much as possible; and general lighting, air conditioning, and ordinary sockets, which can be preferentially disconnected. For the selected non-critical load branch, the equipment sends a tripping control signal to its corresponding switch operating mechanism, causing the main contacts of the switch to open, stopping power supply to the branch, thus achieving load reduction. In addition to local load disconnection, some load can also be transferred to other equipment. If other equipment has a power deficit (i.e., the current actual power is lower than the expected value and is in a power deficit state), it can take over this portion of the load.

[0043] Furthermore, step S400 also includes recording the target load allocation ratio of the current iteration, subtracting it from the target load allocation ratio of the previous iteration item by item to obtain the change in ratio for each item; calculating the sum of the absolute values ​​of all ratio changes, defining it as the convergence fluctuation value, and comparing the convergence fluctuation value with a preset convergence threshold; if the convergence fluctuation value is less than or equal to the convergence threshold, it is determined that the negotiation has converged, and the current target load allocation ratio is locked; if the convergence fluctuation value is greater than the convergence threshold, it is determined that the negotiation has not converged, the current target load allocation ratio is retained as the historical allocation ratio for the next round of comparison, and the process returns to perform distributed negotiation.

[0044] Preferably, the load percentage of each device in this iteration is recorded, and the difference between each item and the target load allocation ratio of the previous iteration is calculated. That is, for each power distribution control device, the ratio value of this iteration is subtracted from the ratio value of the same device in the previous iteration to obtain the ratio change of each item for that device. Then, the absolute values ​​of the ratio changes of each device are summed to determine the convergence fluctuation value, which reflects the total magnitude of the ratio change. The larger the value, the more drastic the ratio adjustment of each device, and the less stable the system is. The smaller the value, the more gradual the ratio adjustment of each device, and the more stable the system is gradually becoming.

[0045] Preferably, the preset convergence threshold is a judgment value set based on the system's tolerance to load fluctuations, switching operation frequency limits, and control accuracy requirements. It is used to determine whether the allocation scheme is sufficiently stable. The convergence fluctuation value is compared with the preset convergence threshold. If the convergence fluctuation value is less than or equal to the convergence threshold, the local device determines that the distributed negotiation process can be terminated, and the current target load allocation ratio can be used as the final decision result. In this case, the negotiation is considered to have converged, and the current target load allocation ratio is locked. If the convergence fluctuation value is greater than the convergence threshold, it indicates that the total adjustment range of the ratio between the two iterations of each device is still large, and the allocation scheme is not yet stable. In this case, it is determined that the process has not converged. The current target load allocation ratio is retained as the historical allocation ratio for the next round of comparison, and the distributed negotiation is returned to be executed. A new round of weight allocation, simulated allocation, and constraint judgment is re-executed to generate a new target load allocation ratio. This process continues until the convergence fluctuation value is less than or equal to the convergence threshold.

[0046] Furthermore, step S400 also includes monitoring the interval between neighboring nodes sending the status messages; if the interval between any neighboring node exceeds a preset heartbeat cycle, or if the aging penalty factor value in the received status message changes abruptly and exceeds a preset physical range, then in the subsequent distributed negotiation steps, the status message data of this abnormal neighboring node is blocked.

[0047] Preferably, the interval between status messages sent by neighboring nodes is monitored by timers and counting logic within the device. This interval is the time difference between two consecutive status messages received by the local device from the same neighboring node. A neighboring node refers to a power distribution control device that has a direct communication link with the local device in the peer-to-peer network topology. The preset heartbeat period is a time length value set based on the agreed status message broadcast frequency in the peer-to-peer network and the maximum allowable delay of the communication network. It represents the maximum time interval at which the local device expects neighboring nodes to send status messages normally. The interval of any neighboring node is compared with the preset heartbeat period. If the actual interval at which a neighbor sends status messages is greater than this value, it indicates that the communication link is abnormal or that the neighboring node is faulty. Alternatively, if the aging penalty factor value of a neighboring node currently received by the local device changes abnormally compared to the aging penalty factor value sent by the neighboring node last time, and exceeds the reasonable range of aging penalty factor values ​​set according to the physical characteristics of the device, it is determined to be a sudden change. In subsequent distributed negotiation steps, the status message data of this abnormal neighboring node is masked, that is, the local device does not include any data of this abnormal neighboring node in the dataset.

[0048] In the above text, refer to Figure 1 A distributed load scheduling control method for power distribution control equipment according to embodiments of the present invention has been described in detail. Next, reference will be made to... Figure 2 A distributed load scheduling control system for power distribution control equipment according to an embodiment of the present invention is described.

[0049] The distributed load dispatching and control system for power distribution control equipment according to embodiments of the present invention addresses the technical problems in the prior art where neglecting the implicit aging differences of power distribution control equipment leads to imbalanced load distribution between new and old equipment, accelerates the deterioration of old equipment, and causes uneven overall system lifespan. It achieves the technical effects of improving the overall operational reliability of the power distribution system, the balance of load distribution health among equipment, and the effective service life. Figure 2 As shown, the distributed load scheduling control system for power distribution control equipment includes: an aging penalty factor calculation module 10, a status message generation module 20, a load allocation ratio determination module 30, and a load scheduling control module 40.

[0050] The aging penalty factor calculation module 10 is used to collect electrical parameters of multiple power distribution branches and calculate the aging penalty factor based on a preset electrical life loss model. The aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment.

[0051] The status message generation module 20 is used to generate a status message containing the aging penalty factor and the local adjustable capacity margin based on the aging penalty factor, and broadcast the status message to neighboring nodes in the peer network.

[0052] The load allocation ratio determination module 30 is used to receive the status message broadcast by the neighbor node in the local power distribution branch, and perform distributed negotiation based on the aging penalty factor stored locally and the aging penalty factor in the received status message to determine the local target load allocation ratio.

[0053] The load scheduling control module 40 is used to control the local power distribution branch to perform load scheduling control according to the target load allocation ratio.

[0054] The specific configuration of the aging penalty factor calculation module 10 will be described in detail below. The aging penalty factor calculation module 10 further includes: acquiring the cumulative allowable number of interruptions of the power distribution control equipment under nominal current and standard on / off conditions, and using the cumulative allowable number of interruptions as the baseline total electrical life; under the same nominal current conditions, measuring the single-interruption contact mass loss corresponding to different arcing durations, and establishing a first correspondence between the arcing duration and the single-interruption contact mass loss; under the same arcing duration conditions, measuring the single-interruption contact mass loss corresponding to different on / off currents, and establishing a second correspondence between the on / off current and the single-interruption contact mass loss; nonlinearly superimposing the first and second correspondences to generate a wear function characterizing the wear rate per unit time, and constructing an electrical life loss model for calculating the cumulative wear based on the wear function.

[0055] The specific configuration of the aging penalty factor calculation module 10 will be described in detail below. The aging penalty factor calculation module 10 further includes: at the instant the power distribution branch performs a closing or opening operation, acquiring the recovery voltage waveform at both ends of the contacts and the current waveform flowing through the contacts; based on the recovery voltage waveform and the current waveform, identifying the moment of arc generation and the moment of arc extinction and calculating the time difference, recording it as the arc duration; extracting the effective value of the current within the arc duration from the current waveform; substituting the arc duration and the effective value of the current into the electrical life loss model to calculate the single wear increment corresponding to this operation; accumulating the single wear increment with the historical cumulative wear amount to obtain the updated current cumulative wear amount; calculating the percentage of the current cumulative wear amount to the total reference electrical life as the aging penalty factor.

[0056] The specific configuration of the status message generation module 20 will be described in detail below. The status message generation module 20 further includes: reading the rated current limit of the local power distribution branch and the current real-time load power; calculating the difference between the full-capacity power corresponding to the rated current limit and the current real-time load power, and recording the difference as the initial adjustable capacity; determining whether the aging penalty factor exceeds a preset aging warning line; if the aging penalty factor exceeds the aging warning line, multiplying the initial adjustable capacity by a preset reduction coefficient, and recording the multiplication result as the local adjustable capacity margin; if the aging penalty factor does not exceed the aging warning line, directly recording the initial adjustable capacity as the local adjustable capacity margin; and encapsulating the aging penalty factor and the local adjustable capacity margin into a status message of a preset format.

[0057] The specific configuration of the load allocation ratio determination module 30 will be described in detail below. The load allocation ratio determination module 30 further includes: parsing the status message, extracting the aging penalty factor of neighboring nodes and the local adjustable capacity margin of neighboring nodes; summarizing the locally stored aging penalty factors and all extracted aging penalty factors to form a negotiation dataset; based on the negotiation dataset, gradually approaching the state point with the lowest total system wear through multiple rounds of iterative calculation; when the state point meets the preset convergence condition, stopping the iterative calculation, and recording the local corresponding load ratio value at this time as the target load allocation ratio.

[0058] The specific configuration of the load allocation ratio determination module 30 will be described in detail below. The load allocation ratio determination module 30 further includes: setting load weights for each power distribution control device based on the aging penalty factor in the negotiated dataset, wherein a larger aging penalty factor value results in a lower load weight; simulating the allocation of the total load within the system based on the load weights and the local adjustable capacity margin in the negotiated dataset to generate a preliminary allocation scheme; determining whether the preliminary allocation scheme meets the preset system total power balance constraints and the upper limit constraints of each device's capacity; if not, adjusting the load weights and re-simulating the allocation until the constraints are met, and determining the allocation result when the constraints are met as the target load allocation ratio.

[0059] The specific configuration of the load scheduling control module 40 will be described in detail below. The load scheduling control module 40 further includes: parsing the target load allocation ratio to obtain the corresponding expected power carrying capacity value; collecting the current actual power value of the local distribution branch and calculating the power difference between the expected power carrying capacity value and the current actual power value; if the power difference is positive and exceeds a preset allowable error band, it is determined that the local area is in a power deficit state, a load takeover request message is sent to neighboring nodes, and a backup branch switch of corresponding capacity is closed according to the magnitude of the power difference; if the power difference is negative and exceeds a preset allowable error band, it is determined that the local area is in a power surplus state, a load unloading command is generated according to the absolute value of the power difference, the disconnection operation of local non-critical load branches is controlled, or a load transfer request message is sent to neighboring nodes.

[0060] The specific configuration of the load scheduling control module 40 will be described in detail below. The load scheduling control module 40 further includes: recording the target load allocation ratio of the current iteration, subtracting it from the target load allocation ratio of the previous iteration item by item to obtain the change in ratio for each item; calculating the sum of the absolute values ​​of all ratio changes, defining it as the convergence fluctuation value, and comparing the convergence fluctuation value with a preset convergence threshold; if the convergence fluctuation value is less than or equal to the convergence threshold, it is determined that the negotiation has converged, and the current target load allocation ratio is locked; if the convergence fluctuation value is greater than the convergence threshold, it is determined that the negotiation has not converged, the current target load allocation ratio is retained as the historical allocation ratio for the next round of comparison, and the process returns to perform distributed negotiation.

[0061] The specific configuration of the load scheduling control module 40 will be described in detail below. The load scheduling control module 40 further includes: monitoring the interval between neighboring nodes sending the status messages; if the interval between any neighboring node exceeds a preset heartbeat period, or if the aging penalty factor value in the received status message changes abruptly and exceeds a preset physical range, then in the subsequent distributed negotiation steps, the status message data of this abnormal neighboring node will be blocked.

[0062] The distributed load scheduling and control system for power distribution control equipment provided in the embodiments of the present invention can execute the distributed load scheduling and control method for power distribution control equipment provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the method execution.

[0063] The above description is merely a preferred embodiment of the present invention and is not intended to limit the present invention in any way. Although the present invention has been disclosed above with reference to preferred embodiments, it is not intended to limit the present invention. Any person skilled in the art can make some modifications or alterations to the above-disclosed technical content to create equivalent embodiments without departing from the scope of the present invention. Any modifications, equivalent changes, and alterations made to the above embodiments based on the technical essence of the present invention without departing from the scope of the present invention shall still fall within the scope of the present invention.

Claims

1. A distributed load dispatch control method for power distribution control equipment, characterized in that, The method is applied to a peer-to-peer network system consisting of multiple power distribution control devices, each power distribution control device being used to manage at least one power distribution branch, and the method includes: Electrical parameters of multiple power distribution branches are collected, and an aging penalty factor is calculated based on a preset electrical life loss model. The aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment. Based on the aging penalty factor, a status message containing the aging penalty factor and the local adjustable capacity margin is generated, and the status message is broadcast to neighboring nodes in the peer network. The local distribution branch receives the status message broadcast by the neighboring node, and performs distributed negotiation based on the aging penalty factor stored locally and the aging penalty factor in the received status message to determine the local target load allocation ratio. According to the target load allocation ratio, control the local power distribution branch to perform load scheduling control.

2. The distributed load dispatch control method for power distribution control equipment as described in claim 1, characterized in that, The construction of the electrical lifetime loss model includes: Obtain the cumulative number of interruptions of the power distribution control equipment under nominal current and standard on / off conditions, and use the cumulative number of interruptions as the total reference electrical life. Under the same nominal current conditions, the mass loss of the single-break contact corresponding to different arc durations was measured to establish the first correspondence between the arc duration and the mass loss of the single-break contact. Under the same arc duration, the mass loss of the single breaking contact corresponding to different on-off currents was measured to establish a second correspondence between the on-off current and the mass loss of the single breaking contact. The first and second correspondences are nonlinearly superimposed to generate a wear function that characterizes the wear rate per unit time, and an electrical lifetime loss model for calculating the cumulative wear is constructed based on the wear function.

3. The distributed load dispatch control method for power distribution control equipment as described in claim 2, characterized in that, Electrical parameters of multiple power distribution branches are collected, and aging penalty factors are calculated based on a preset electrical lifetime loss model, including: At the instant the power distribution branch performs a closing or opening operation, the recovery voltage waveform across the contacts and the current waveform flowing through the contacts are collected. Based on the recovery voltage waveform and the current waveform, the moment of arc generation and the moment of arc extinction are identified and the time difference is calculated and recorded as the arc duration. Extract the effective value of the current during the arcing duration from the current waveform; Substitute the arc duration and the effective value of the current into the electrical lifetime loss model to calculate the single wear increment corresponding to this operation. The single wear increment is added to the historical cumulative wear amount to obtain the updated current cumulative wear amount; The percentage of the current cumulative wear amount relative to the total reference electrical life is calculated as the aging penalty factor.

4. The distributed load scheduling control method for power distribution control equipment as described in claim 1, characterized in that, Based on the aging penalty factor, a status message containing the aging penalty factor and the locally adjustable capacity margin is generated, including: Read the rated current limit and current real-time load power of the local power distribution branch; Calculate the difference between the full power corresponding to the rated current limit and the current real-time load power, and record the difference as the initial adjustable capacity; Determine whether the aging penalty factor exceeds the preset aging warning line; If the aging penalty factor exceeds the aging warning line, the initial adjustable capacity is multiplied by a preset reduction factor, and the multiplication result is recorded as the local adjustable capacity margin. If the aging penalty factor does not exceed the aging warning line, the initial adjustable capacity is directly recorded as the local adjustable capacity margin. The aging penalty factor and the locally adjustable capacity margin are encapsulated into a status message in a preset format.

5. The distributed load dispatch control method for power distribution control equipment as described in claim 1, characterized in that, The local distribution branch receives the status message broadcast by the neighboring node, and performs distributed negotiation based on the locally stored aging penalty factor and the aging penalty factor in the received status message, including: Parse the status message to extract the aging penalty factor of the neighboring node and the local adjustable capacity margin of the neighboring node. The locally stored aging penalty factors and all extracted aging penalty factors are aggregated to form a negotiated dataset; Based on the negotiated dataset, the system gradually approaches the state point with the lowest total wear through multiple rounds of iterative calculations. When the state point meets the preset convergence condition, the iterative calculation stops, and the local load percentage value at this time is recorded as the target load allocation ratio.

6. The distributed load scheduling control method for power distribution control equipment as described in claim 5, characterized in that, Based on the negotiated dataset, through multiple rounds of iterative calculations, the system gradually approaches the state point with the lowest total wear, including: Based on the aging penalty factor in the negotiated dataset, a load weight is set for each power distribution control device, wherein the larger the aging penalty factor value, the lower the load weight. Based on the load weight and the local adjustable capacity margin in the negotiated dataset, the total load in the system is simulated and allocated to generate a preliminary allocation scheme. Determine whether the preliminary allocation scheme meets the preset system total power balance constraints and the upper limit constraints of each device capacity; If the conditions are not met, the load weights are adjusted and the simulation is repeated until the constraints are met. The allocation result when the constraints are met is then determined as the target load allocation ratio.

7. The distributed load dispatch control method for power distribution control equipment as described in claim 1, characterized in that, According to the target load allocation ratio, control the local power distribution branch to perform load scheduling control, including: Analyze the target load allocation ratio to obtain the corresponding expected load capacity value; Collect the current actual power value of the local power distribution branch, and calculate the power difference between the expected carrying power value and the current actual power value; If the power difference is positive and exceeds the preset allowable error band, it is determined that the local area is in a power shortage state, a load takeover request message is sent to the neighboring node, and the corresponding capacity of the standby branch switch is closed according to the size of the power difference. If the power difference is negative and exceeds the preset allowable error band, the local area is determined to be in a power surplus state. According to the absolute value of the power difference, a load offloading command is generated to control the disconnection operation of local non-critical load branches, or a load transfer request message is sent to neighboring nodes.

8. The distributed load scheduling control method for power distribution control equipment as described in claim 1, characterized in that, The method also includes convergence determination: Record the target load allocation ratio of this iteration, and calculate the difference between each item and the target load allocation ratio of the previous iteration to obtain the change in the ratio of each item. The sum of the absolute values ​​of all proportional changes is calculated and defined as the convergence fluctuation value, which is then compared with a preset convergence threshold. If the convergence fluctuation value is less than or equal to the convergence threshold, then negotiation convergence is determined, and the current target load allocation ratio is locked. If the convergence fluctuation value is greater than the convergence threshold, it is determined that convergence has not occurred. The current target load allocation ratio is retained as the historical allocation ratio for the next round of comparison, and the process of distributed negotiation is returned.

9. The distributed load scheduling control method for power distribution control equipment as described in claim 1, characterized in that, The method also includes handling abnormal nodes: Monitor the interval at which neighboring nodes send the status messages; If the interval of any neighboring node exceeds the preset heartbeat cycle, or if the aging penalty factor value in the received status message changes abruptly and exceeds the preset physical range, then the status message data of this abnormal neighboring node will be blocked in the subsequent distributed negotiation steps.

10. A distributed load dispatching control system for power distribution control equipment, characterized in that, The system is used to implement the distributed load dispatch control method for power distribution control equipment according to any one of claims 1 to 9, the system comprising: The aging penalty factor calculation module is used to collect electrical parameters of multiple power distribution branches and calculate the aging penalty factor based on a preset electrical life loss model. The aging penalty factor can characterize the wear degree of the contacts of the power distribution control equipment. The status message generation module is used to generate a status message containing the aging penalty factor and the local adjustable capacity margin based on the aging penalty factor, and broadcast the status message to neighboring nodes in the peer network. The load allocation ratio determination module is used to receive the status message broadcast by the neighbor node in the local power distribution branch, and perform distributed negotiation based on the aging penalty factor stored locally and the aging penalty factor in the received status message to determine the local target load allocation ratio. The load scheduling control module is used to control the local power distribution branch to perform load scheduling control according to the target load allocation ratio.

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