Method and system for evaluating influence of new energy access on line loss health degree

Abstract

The invention provides a method and system for evaluating the influence of new energy access on the line loss health degree, and the method comprises the steps: obtaining the actual measurement data of new energy equipment; connecting a power grid with the new energy equipment, and constructing a power grid simulation model after the new energy equipment is accessed to a photovoltaic area in the power grid; calculating the theoretical line loss of the power grid simulation model by using a theoretical line loss calculation method based on the measured data and the power grid simulation model; based on the measured data, calculating the line loss of the photovoltaic transformer area before the new energy equipment is connected to the photovoltaic transformer area; and based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic transformer area before the new energy equipment is accessed to the photovoltaic transformer area, determining the influence on the line loss health degree of the power grid after the new energy equipment is accessed to the photovoltaic transformer area. The power grid simulation model is combined with historical data for calculation, the line loss of the photovoltaic transformer area is calculated, and the line loss health degree is accurately predicted.

Description

Technical Field

[0001] The present invention belongs to the field of electric power technology, and specifically relates to a method and system for evaluating the impact of new energy access on line loss health. Background Art

[0002] As the leading factor in the transformation of terminal energy consumption patterns, the transformation of distribution networks has a far-reaching impact. With the advancement of the construction of new power systems, distribution networks are gradually transforming from a power network that simply receives and distributes electric energy to users to a power network that integrates source, grid, load and storage and is flexibly coupled with the upper power grid. Its functions in promoting the nearby consumption of distributed power sources and carrying new loads are becoming increasingly prominent.

[0003] The existing technology uses automatic simulation methods to generate distribution network characteristics such as distributed power output and load fluctuations, which can be used as data samples for subsequent distribution network investment planning. However, the predicted line loss health proposed by this method is not accurate enough, resulting in less than ideal results when planning the power grid. Summary of the invention

[0004] In order to overcome the above-mentioned deficiencies of the prior art, in a first aspect, the present invention proposes a method for evaluating the impact of new energy access on line loss health, comprising:

[0005] Obtain measured data of new energy equipment;

[0006] Connecting the power grid to the new energy equipment to construct a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; calculating the theoretical line loss of the power grid simulation model based on the measured data and the power grid simulation model using a theoretical line loss calculation method;

[0007] Based on the measured data, calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area;

[0008] Based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, the impact of the new energy equipment on the line loss health of the power grid after being connected to the photovoltaic area is determined.

[0009] Preferably, the determining the influence of the new energy equipment on the line loss health of the power grid after the new energy equipment is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area includes:

[0010] Evaluate the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, and determine the area state evaluation value after the new energy equipment is connected to the photovoltaic area based on the matching degree;

[0011] Based on the power grid simulation model, multiple indicators in the power grid simulation model are established; the multiple indicators include: collection indicators, cost control indicators, line loss indicators, and equipment event indicators;

[0012] Based on the substation status evaluation value and multiple indicators in the power grid simulation model, the health status score of the substation is determined; based on the health status score, the impact of the new energy equipment on the line loss health of the power grid after being connected to the photovoltaic substation is determined.

[0013] Preferably, determining the health status score of the substation based on the substation status evaluation value and multiple indicators in the power grid simulation model includes:

[0014] Based on the substation status evaluation value, respectively determine the index scores of the collection index, the fee control index, the line loss index, and the equipment event index;

[0015] A weighted operation is performed on the weights and index scores of the collection indicators, the weights and index scores of the fee control indicators, the weights and index scores of the line loss indicators, and the weights and index scores of the equipment event indicators to determine the health status score of the substation.

[0016] Preferably, the calculating of the theoretical line loss of the power grid simulation model based on the measured data and the power grid simulation model using a theoretical line loss calculation method comprises:

[0017] Based on the measured data and the grid simulation model, a correction coefficient of the photovoltaic area power ratio is determined using a theoretical line loss calculation method, and the power loss of the first area is calculated using a voltage drop method;

[0018] The theoretical line loss in the power grid simulation model is calculated by multiplying the correction coefficient of the photovoltaic area power proportion by the first area loss power calculated by the voltage drop method;

[0019] The theoretical line loss includes: voltage division line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, proportion of line loss rates of 10Kv and below, proportion of high line loss and proportion of high loss in photovoltaic areas.

[0020] Preferably, the theoretical line loss calculation method includes: forward-backward power flow method and pressure drop method;

[0021] The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes:

[0022] Based on the power grid simulation model, the power loss in the second substation is calculated by using the forward-backward power flow method;

[0023] The ratio of the power loss in the second area calculated by the forward-backward power flow method to the power loss in the first area calculated by the voltage drop method is determined as the correction coefficient of the proportion of electricity in the photovoltaic area.

[0024] Preferably, the theoretical line loss calculation method includes: Newton interpolation method;

[0025] The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes:

[0026] Based on the measured data and the power grid simulation model, determine the historical photovoltaic area power share at the historical time point and the correction coefficient of the historical photovoltaic area power share, and determine the real-time photovoltaic area power share;

[0027] Based on the historical photovoltaic area electricity proportion and the correction coefficient of the historical photovoltaic area electricity proportion, a mapping relationship between the photovoltaic area electricity proportion and the correction coefficient of the photovoltaic area electricity proportion is established by Newton interpolation method;

[0028] The real-time photovoltaic area electricity proportion is brought into the mapping relationship to determine the correction coefficient of the photovoltaic area electricity proportion.

[0029] Preferably, the process of determining the real-time photovoltaic area electricity proportion includes:

[0030] Based on the measured data and the power grid simulation model, the total amount of online electricity of photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment are obtained;

[0031] Based on the total amount of online electricity of the photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment, calculate the real-time photovoltaic area electricity proportion;

[0032] The real-time photovoltaic area power proportion is calculated as follows:

[0033]

[0034] Where Rj is the real-time photovoltaic power generation ratio, P GF,j is the total amount of grid-connected electricity consumed by photovoltaic users at the jth moment, P SD,j It is the power supply of the first-end assessment table in the power grid at the jth moment.

[0035] Preferably, the formula for calculating the power loss in the first station area using the voltage drop method is as follows:

[0036]

[0037] In the above formula, ΔPi is the power loss in the first station area calculated by the voltage drop method, P G is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U 0 is the voltage of the transformer port of the power grid simulation model, I 0 is the distribution port current of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the photovoltaic user-side electric energy meter in the measured data, cosψ 0 is the power factor of the power distribution port of the power grid simulation model, cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

[0038] Preferably, based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation, and the calculation formula is as follows:

[0039]

[0040] In the above formula: ΔP cl,y is the photovoltaic power loss calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

[0041] In a second aspect, the present invention also proposes a system for evaluating the impact of new energy access on line loss health, including:

[0042] An acquisition module is used to obtain measured data of new energy equipment;

[0043] A theoretical line loss calculation module is used to connect the power grid with the new energy equipment and construct a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; based on the measured data and the power grid simulation model, the theoretical line loss of the power grid simulation model is calculated using a theoretical line loss calculation method;

[0044] A line loss calculation module of a photovoltaic area, used for calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area based on the measured data;

[0045] The line loss health impact determination module is used to determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area.

[0046] Preferably, the line loss health impact determination module includes:

[0047] The sub-module of the status evaluation value of the substation is used to evaluate the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic substation before the new energy equipment is connected to the photovoltaic substation, and determine the substation status evaluation value after the new energy equipment is connected to the photovoltaic substation based on the matching degree;

[0048] An indicator establishment submodule is used to establish multiple indicators in the power grid simulation model based on the power grid simulation model; the multiple indicators include: collection indicators, cost control indicators, line loss indicators, and equipment event indicators;

[0049] The line loss health impact determination submodule is used to determine the health status score of the substation based on the substation status evaluation value and multiple indicators in the power grid simulation model; based on the health status score, determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic substation.

[0050] Preferably, the line loss health impact determination submodule includes:

[0051] An indicator score determination unit, configured to determine the indicator scores of the collection indicator, the fee control indicator, the line loss indicator, and the device event indicator, respectively, based on the substation status evaluation value;

[0052] The health status score determination unit is used to perform weighted calculation on the weights and index scores of the collection indicators, the weights and index scores of the fee control indicators, the weights and index scores of the line loss indicators, and the weights and index scores of the equipment event indicators to determine the health status score of the substation.

[0053] Preferably, the theoretical line loss calculation module includes:

[0054] The first area power loss calculation submodule is used to determine the correction coefficient of the photovoltaic area power proportion based on the measured data and the power grid simulation model using the theoretical line loss calculation method, and calculate the first area power loss using the voltage drop method;

[0055] A theoretical line loss calculation submodule, used to calculate the theoretical line loss in the power grid simulation model by multiplying the correction coefficient of the photovoltaic area power proportion by the first area loss power calculated by the voltage drop method;

[0056] The theoretical line loss includes: voltage division line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, proportion of line loss rates of 10Kv and below, proportion of high line loss and proportion of high loss in photovoltaic areas.

[0057] Preferably, the theoretical line loss calculation method includes: forward-backward power flow method and pressure drop method;

[0058] The first area power loss calculation submodule includes:

[0059] A second substation power loss calculation unit, configured to calculate the second substation power loss by using the forward-backward power flow method based on the power grid simulation model;

[0060] The first correction coefficient determination unit is used to determine the ratio of the second area power loss calculated by the forward-backward power flow method to the first area power loss calculated by the voltage drop method as the correction coefficient of the photovoltaic area power proportion.

[0061] Preferably, the theoretical line loss calculation method further includes: Newton interpolation method;

[0062] The first area power loss calculation submodule also includes:

[0063] A real-time photovoltaic area power proportion determination unit is used to determine the historical photovoltaic area power proportion and the correction coefficient of the historical photovoltaic area power proportion at the historical time point based on the measured data and the power grid simulation model, and determine the real-time photovoltaic area power proportion;

[0064] A mapping relationship establishing unit, used to establish a mapping relationship between the photovoltaic area electricity proportion and the correction coefficient of the photovoltaic area electricity proportion through Newton interpolation method based on the historical photovoltaic area electricity proportion and the correction coefficient of the historical photovoltaic area electricity proportion;

[0065] The second correction coefficient determination unit is used to bring the real-time photovoltaic area power proportion into the mapping relationship to determine the correction coefficient of the photovoltaic area power proportion.

[0066] Preferably, the real-time photovoltaic area electricity proportion determination unit includes:

[0067] A power supply acquisition subunit, used to acquire the total amount of online power of photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment based on the measured data and the power grid simulation model;

[0068] A real-time photovoltaic area power proportion calculation subunit is used to calculate the real-time photovoltaic area power proportion based on the total online power of the photovoltaic user at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment;

[0069] The real-time photovoltaic area power proportion is calculated as follows:

[0070]

[0071] Where Rj is the real-time photovoltaic power generation ratio, P GF,j is the total amount of grid-connected electricity consumed by photovoltaic users at the jth moment, P SD,j It is the power supply of the first-end assessment table in the power grid at the jth moment.

[0072] Preferably, the formula for calculating the power loss in the first station area using the voltage drop method is as follows:

[0073]

[0074] In the above formula, ΔP i is the power loss in the first station area calculated by the voltage drop method, P G is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U 0 is the voltage of the transformer port of the power grid simulation model, I 0 is the distribution port current of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the photovoltaic user-side electric energy meter in the measured data, cosψ 0 is the power factor of the power distribution port of the power grid simulation model, cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

[0075] Preferably, based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation, and the calculation formula is as follows:

[0076]

[0077] In the above formula: ΔP cl,y is the photovoltaic power loss calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

[0078] In a third aspect, the present invention application further proposes an electronic device, comprising: at least one processor and a memory; the memory and the processor are connected via a bus;

[0079] The memory is used to store one or more programs;

[0080] When the one or more programs are executed by the at least one processor, the method for evaluating the impact of new energy access on line loss health is implemented.

[0081] In a fourth aspect, the present invention application further proposes a readable storage medium having an execution program stored thereon, and when the execution program is executed, the method for evaluating the impact of new energy access on line loss health is implemented.

[0082] Compared with the closest prior art, the present invention has the following beneficial effects:

[0083] The present invention provides a method and system for evaluating the impact of new energy access on line loss health, the method comprising: obtaining measured data of new energy equipment; connecting the power grid to the new energy equipment, and constructing a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; based on the measured data and the power grid simulation model, using a theoretical line loss calculation method, calculating the theoretical line loss of the power grid simulation model; based on the measured data, calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area; based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, determining the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area. The power grid simulation model is combined with historical data to calculate the line loss of the photovoltaic area, and the accurate prediction of the line loss health is achieved, so that the power grid operator can accurately dispatch and optimize in advance, and the power grid planning effect is ideal. BRIEF DESCRIPTION OF THE DRAWINGS

[0084] Figure 1 A flow chart of a method for evaluating the impact of new energy access on line loss health provided by the present invention;

[0085] Figure 2 An architecture diagram of an evaluation system for the impact of new energy access on line loss health provided by the present invention;

[0086] Figure 3 The health status evaluation system of the substation area provided by the present invention application;

[0087] Figure 4 A flowchart of a specific use case of a method for evaluating the impact of new energy access on line loss health provided by the present invention Figure 1 ;

[0088] Figure 5 A flowchart of a specific use case of a method for evaluating the impact of new energy access on line loss health provided by the present invention Figure 2 ;

[0089] Figure 6 A comparison diagram of a traditional distribution network and the smart distribution network of the present invention;

[0090] Figure 7 A schematic diagram of the operation of an electronic device provided in the present invention application. DETAILED DESCRIPTION

[0091] The specific implementation methods of the present invention are further described in detail below with reference to the accompanying drawings.

[0092] Embodiment 1:

[0093] like Figure 1 As shown, the present invention proposes a method for evaluating the impact of new energy access on line loss health, comprising the following steps:

[0094] Step 1: Obtain measured data of new energy equipment;

[0095] Step 2: Connect the power grid to the new energy device, and construct a power grid simulation model after the new energy device is connected to the photovoltaic area in the power grid; based on the measured data and the power grid simulation model, calculate the theoretical line loss of the power grid simulation model using a theoretical line loss calculation method;

[0096] Step 3: Based on the measured data, calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area;

[0097] Step 4: Based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area.

[0098] For example, in step 1: testing the new energy equipment to obtain actual measured data of the new energy equipment;

[0099] For example, in step 2: based on the measured data of the new energy equipment obtained in step 1 and the constructed power grid simulation model, the theoretical line loss of the power grid simulation model is calculated using a theoretical line loss calculation method, including:

[0100] Based on the measured data and the grid simulation model, a correction coefficient of the photovoltaic area power ratio is determined using a theoretical line loss calculation method, and the power loss of the first area is calculated using a voltage drop method;

[0101] The theoretical line loss in the power grid simulation model is calculated by multiplying the correction coefficient of the photovoltaic area power proportion by the first area loss power calculated by the voltage drop method;

[0102] Among them, the theoretical line loss may include: voltage-dividing line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, 10Kv (kilovolt) and below line loss rate proportion, high line loss proportion and high loss proportion of photovoltaic stations.

[0103] The voltage division line loss rate statistics can include the voltage division line loss rates of 0.4kV, 10kV, and 35kV, and the voltage division line loss rate can be displayed in the form of a line graph;

[0104] The year-on-year change of line loss index units is calculated to show the year-on-year change of line loss rate in the selected area of ​​GIS (Geographic Information System, Geographic Information System or Geo-Information system, GIS) map;

[0105] Monthly line loss monitoring rate for the same period, which shows the line loss monitoring rate for the area selected by GIS map;

[0106] Line loss rate ranking, its statistics and display are calculated to show the corresponding provincial, municipal and county rankings of each unit;

[0107] The proportion of line loss rates of 0.4kV, 10kV, and 35kV are calculated and displayed in the corresponding proportion of line loss rates in the selected area of ​​the GIS map by year, month, and day;

[0108] The proportion of high-loss line losses is calculated and displayed by year, month, and day to show the proportion of high-loss distribution line losses in the selected area on the GIS map;

[0109] The proportion of high losses in photovoltaic substations is calculated and displayed in the selected area of ​​the GIS map by year, month and day.

[0110] As mentioned above, when calculating the theoretical line loss, the theoretical line loss calculation method is determined mainly by matching the power grid simulation model with the measured data. The theoretical line loss calculation method includes: forward-backward power flow method and voltage drop method;

[0111] The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes:

[0112] Based on the power grid simulation model, the power loss in the second substation is calculated by using the forward-backward power flow method;

[0113] The ratio of the power loss in the second area calculated by the forward-backward power flow method to the power loss in the first area calculated by the voltage drop method is determined as the correction coefficient of the proportion of electricity in the photovoltaic area.

[0114] The formula for calculating the power loss in the first station area using the voltage drop method is as follows:

[0115]

[0116] In the above formula, ΔP i is the power loss in the first station area calculated by the voltage drop method, PG is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U 0 is the voltage of the transformer port of the power grid simulation model, I 0 is the distribution port current of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the photovoltaic user-side electric energy meter in the measured data, cosψ 0 is the power factor of the power distribution port of the power grid simulation model, cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

[0117] In the above, based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation, and the calculation formula is as follows:

[0118]

[0119] In the above formula: ΔP cl,y is the photovoltaic power loss calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

[0120] After calculating the theoretical line loss of the power grid simulation model, proceed to step 3;

[0121] For example, in step 3: based on the measured data, calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area;

[0122] The measured data can be used to directly calculate the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area according to the known technology, and then enter step 4;

[0123] For example, in step 4: determining the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area may include:

[0124] Evaluate the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, and determine the area state evaluation value after the new energy equipment is connected to the photovoltaic area based on the matching degree;

[0125] Based on the power grid simulation model, multiple indicators in the power grid simulation model are established; the multiple indicators include: collection indicators, cost control indicators, line loss indicators, and equipment event indicators;

[0126] Based on the substation status evaluation value and multiple indicators in the power grid simulation model, the health status score of the substation is determined; based on the health status score, the impact of the new energy equipment on the line loss health of the power grid after being connected to the photovoltaic substation is determined.

[0127] By using multiple indicators to determine the health status score of the substation, we can evaluate the impact of new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic substation from multiple aspects.

[0128] In the above, the step of determining the health status score of the substation based on the substation status evaluation value and multiple indicators in the power grid simulation model includes:

[0129] Based on the substation status evaluation value, respectively determine the index scores of the collection index, the fee control index, the line loss index, and the equipment event index;

[0130] A weighted operation is performed on the weights and index scores of the collection indicators, the weights and index scores of the fee control indicators, the weights and index scores of the line loss indicators, and the weights and index scores of the equipment event indicators to determine the health status score of the substation.

[0131] In addition, the present invention calculates theoretical line losses based on the power grid simulation model. It can generate a high-loss component management library for transmission lines, main transformers, distribution lines, and low-voltage substations that have multiple high losses in the power grid. It can also automatically generate visual GIS charts of new energy access and return scale by zone, voltage, component, and substation. Combined with historical data, the present invention studies and deduces the impact of output changes on line losses in different zones after the access of new energy equipment, conducts health monitoring and management of the entire power grid process, and provides strong support for the operation and management of new energy equipment after grid connection.

[0132] Embodiment 2:

[0133] The difference from the first embodiment is that the method for determining the correction coefficient in the present embodiment is different, and the rest is the same as the first embodiment. Specifically, it can be as follows:

[0134] The theoretical line loss calculation method includes: Newton interpolation method;

[0135] The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes:

[0136] Based on the measured data and the power grid simulation model, determine the historical photovoltaic area power share at the historical time point and the correction coefficient of the historical photovoltaic area power share, and determine the real-time photovoltaic area power share;

[0137] Based on the historical photovoltaic area electricity proportion and the correction coefficient of the historical photovoltaic area electricity proportion, a mapping relationship between the photovoltaic area electricity proportion and the correction coefficient of the photovoltaic area electricity proportion is established by Newton interpolation method;

[0138] The real-time photovoltaic area electricity proportion is brought into the mapping relationship to determine the correction coefficient of the photovoltaic area electricity proportion.

[0139] The process of determining the real-time photovoltaic area power proportion may include:

[0140] Based on the measured data and the power grid simulation model, the total amount of online electricity of photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment are obtained;

[0141] Among them, the first-end assessment table is the first-end electricity meter in the power grid.

[0142] Based on the total amount of online electricity of the photovoltaic user at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment, calculate the real-time photovoltaic area electricity proportion;

[0143] The real-time photovoltaic area power proportion is calculated as follows:

[0144]

[0145] Where Rj is the real-time photovoltaic power generation ratio, P GF,j is the total amount of grid-connected electricity consumed by photovoltaic users at the jth moment, P SD,j It is the power supply of the first-end assessment table in the power grid at the jth moment.

[0146] The main methods used are: Based on the historical data of many days, a regression model between the proportion of photovoltaic grid-connected electricity and the correction coefficient is established through the Newton interpolation method, and the mapping relationship between the proportion of photovoltaic grid-connected electricity and the correction coefficient is determined. Then, the correction coefficient Ki of the real-time photovoltaic area electricity proportion can be calculated based on the mapping relationship. The proportion of new energy grid-connected electricity Rj at the jth moment is calculated, and the value of the correction coefficient Ki is calculated through the mapping relationship between Rj and Ki; the correction coefficient Ki is multiplied by the area loss power calculated by the voltage drop method to obtain the theoretical line loss value of the distributed photovoltaic area. The theoretical line loss value is calculated based on the number of electricity meters in the area, and the zero line loss is considered.

[0147] The theoretical line loss calculation method of the present invention is adopted to calculate the proportion Rj of photovoltaic grid-connected electricity at each time point, select the Ki value according to the established mapping relationship, and then use Ki to multiply the area loss power calculated by the voltage drop method after photovoltaic removal at the corresponding time to quantify the power loss at each time point, and calculate the theoretical line loss value of the photovoltaic area.

[0148] The theoretical line loss rate of the substation area calculated by the method of Example 2 of the present invention is compared with the theoretical line loss rate of the substation area obtained by the forward-backward power flow method in Example 1, and the line loss rate deviation is calculated. The comparison results are as follows

[0149] As shown in Table 1;

[0150]

[0151] Table 1: Comparison of method results

[0152] As can be seen from Table 1, the present invention calculates the theoretical line loss in the power grid simulation model, and the deviation between the two groups of methods is within 10%. The theoretical line loss calculated by the two methods can provide strong support for the operation and management of new energy after grid connection.

[0153] To ensure the stable operation of the power grid and the effective use of new energy equipment, it is crucial to accurately predict the access of new energy equipment. Through accurate prediction, power grid operators can dispatch and optimize in advance to ensure the balance and stability of the power grid.

[0154] Embodiment 3:

[0155] like Figure 2 As shown, the present invention application also proposes an evaluation system for the impact of new energy access on line loss health, including:

[0156] An acquisition module is used to obtain measured data of new energy equipment;

[0157] A theoretical line loss calculation module is used to connect the power grid with the new energy equipment and construct a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; based on the measured data and the power grid simulation model, the theoretical line loss of the power grid simulation model is calculated using a theoretical line loss calculation method;

[0158] A line loss calculation module of a photovoltaic area, used for calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area based on the measured data;

[0159] The line loss health impact determination module is used to determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area.

[0160] Furthermore, the line loss health impact determination module includes:

[0161] The sub-module of the status evaluation value of the substation is used to evaluate the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic substation before the new energy equipment is connected to the photovoltaic substation, and determine the substation status evaluation value after the new energy equipment is connected to the photovoltaic substation based on the matching degree;

[0162] The indicator establishment submodule is used to establish multiple indicators in the power grid simulation model based on the power grid simulation model; Figure 3 As shown, the multiple indicators include: collection indicators, cost control indicators, line loss indicators, and equipment event indicators;

[0163] The line loss health impact determination submodule is used to determine the health status score of the substation based on the substation status evaluation value and multiple indicators in the power grid simulation model; based on the health status score, determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic substation.

[0164] Furthermore, the line loss health impact determination submodule includes:

[0165] An indicator score determination unit, configured to determine the indicator scores of the collection indicator, the fee control indicator, the line loss indicator, and the device event indicator, respectively, based on the substation status evaluation value;

[0166] The health status score determination unit is used to perform weighted calculation on the weights and index scores of the collection indicators, the weights and index scores of the fee control indicators, the weights and index scores of the line loss indicators, and the weights and index scores of the equipment event indicators to determine the health status score of the substation.

[0167] Furthermore, the theoretical line loss calculation module includes:

[0168] The first area power loss calculation submodule is used to determine the correction coefficient of the photovoltaic area power proportion based on the measured data and the power grid simulation model using the theoretical line loss calculation method, and calculate the first area power loss using the voltage drop method;

[0169] A theoretical line loss calculation submodule, used to calculate the theoretical line loss in the power grid simulation model by multiplying the correction coefficient of the photovoltaic area power proportion by the first area loss power calculated by the voltage drop method;

[0170] The theoretical line loss includes: voltage division line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, proportion of line loss rates of 10Kv and below, proportion of high line loss and proportion of high loss in photovoltaic areas.

[0171] Furthermore, the theoretical line loss calculation method includes: forward-backward power flow method and voltage drop method;

[0172] The first area power loss calculation submodule includes:

[0173] A second substation power loss calculation unit, configured to calculate the second substation power loss by using the forward-backward power flow method based on the power grid simulation model;

[0174] The first correction coefficient determination unit is used to determine the ratio of the second area power loss calculated by the forward-backward power flow method to the first area power loss calculated by the voltage drop method as the correction coefficient of the photovoltaic area power proportion.

[0175] Furthermore, the formula for calculating the power loss in the first substation using the voltage drop method is as follows:

[0176]

[0177] In the above formula, ΔP i is the power loss in the first station area calculated by the voltage drop method, P G is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U 0 is the voltage of the transformer port of the power grid simulation model, I 0 is the current of the distribution port of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the photovoltaic user-side electric energy meter in the measured data, cosψ 0 is the power factor of the power distribution port of the power grid simulation model, cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

[0178] Furthermore, based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation, and the calculation formula is as follows:

[0179]

[0180] In the above formula: ΔP cl,y is the photovoltaic area loss power calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

[0181] Embodiment 4:

[0182] The difference from the third embodiment is that: firstly, the theoretical line loss calculation method in the present embodiment further includes: Newton interpolation method;

[0183] In a second aspect, in this embodiment, the first area power loss calculation submodule further includes:

[0184] A real-time photovoltaic area power proportion determination unit is used to determine the historical photovoltaic area power proportion and the correction coefficient of the historical photovoltaic area power proportion at the historical time point based on the measured data and the power grid simulation model, and determine the real-time photovoltaic area power proportion;

[0185] A mapping relationship establishing unit, used to establish a mapping relationship between the photovoltaic area electricity proportion and the correction coefficient of the photovoltaic area electricity proportion through Newton interpolation method based on the historical photovoltaic area electricity proportion and the correction coefficient of the historical photovoltaic area electricity proportion;

[0186] The second correction coefficient determination unit is used to bring the real-time photovoltaic area power proportion into the mapping relationship to determine the correction coefficient of the photovoltaic area power proportion.

[0187] Furthermore, the real-time photovoltaic area electricity proportion determination unit includes:

[0188] A power supply acquisition subunit, used to acquire the total amount of online power of photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment based on the measured data and the power grid simulation model;

[0189] A real-time photovoltaic area power proportion calculation subunit is used to calculate the real-time photovoltaic area power proportion based on the total online power of the photovoltaic user at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment;

[0190] The real-time photovoltaic area power proportion is calculated as follows:

[0191]

[0192] Where Rj is the real-time photovoltaic power generation ratio, P GF,j is the total amount of grid-connected electricity consumed by photovoltaic users at the jth moment, P SD,j is the power supply of the head-end assessment table in the power grid at the jth moment, and Rj is set to 0 when the sampling time is in the time period of 20:00 to 8:00.

[0193] Embodiment 5:

[0194] like Figure 4 , Figure 5As shown, this embodiment provides a specific use case of a method for evaluating the impact of new energy access on line loss health, including the following steps:

[0195] Step 1: First, obtain the measured data of new energy equipment;

[0196] Step 2: Construct a grid simulation model after the new energy equipment is connected, and calculate the theoretical line loss of the grid simulation model;

[0197] Step 3: Calculate the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area;

[0198] Step 4: Calculate the impact of new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area.

[0199] In step 2, include:

[0200] Step 2.1, using the measured data and the grid simulation model, using the theoretical line loss calculation method, determining the correction coefficient of the photovoltaic area power share, and using the voltage drop method to calculate the power loss of the first area;

[0201] Step 2.2, multiplying the correction coefficient of the photovoltaic area power ratio by the first area loss power calculated by the voltage drop method to calculate the theoretical line loss in the power grid simulation model;

[0202] Among them, the theoretical line loss can include: voltage division line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, 10Kv and below line loss rate proportion, high line loss proportion and high loss proportion of photovoltaic stations.

[0203] When calculating the theoretical line loss, the power grid simulation model and the measured data are matched to determine the theoretical line loss calculation method, which includes: forward-backward power flow method and voltage drop method;

[0204] Based on the measured data and the grid simulation model, the correction coefficient of the photovoltaic area power ratio is determined using the theoretical line loss calculation method, including:

[0205] According to the power grid simulation model, the power loss in the second area is calculated using the forward-backward power flow method; then the ratio of the power loss in the second area calculated using the forward-backward power flow method to the power loss in the first area calculated using the voltage drop method is determined as the correction coefficient for the proportion of electricity in the photovoltaic area.

[0206] The formula for calculating the power loss in the first area using the voltage drop method is as follows:

[0207]

[0208] In the above formula, ΔP i is the power loss in the first station area calculated by the voltage drop method, PG is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U 0 is the voltage of the transformer port of the power grid simulation model, I 0 is the distribution port current of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the photovoltaic user-side electric energy meter in the measured data, cosψ 0 is the power factor of the power distribution port of the power grid simulation model, cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

[0209] As mentioned above, the forward-backward power flow method is used to calculate the power loss in the second substation area. The calculation formula is as follows:

[0210]

[0211] In the above formula: ΔP cl,y is the photovoltaic power loss calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

[0212] The calculation formula of the correction coefficient Ki value is as follows:

[0213]

[0214] In the above formula: ΔP i is the photovoltaic power loss calculated by the voltage drop method, i∈[1,2,…,96], ΔP cl,y This is the power loss in the photovoltaic area calculated by the forward-backward power flow method.

[0215] In step 3, the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area is calculated based on the measured data;

[0216] In step 4, the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area is evaluated, and based on the matching degree, the evaluation value of the photovoltaic area state after the new energy equipment is connected to the photovoltaic area is determined;

[0217] like Figure 6 As shown in the figure, compared with the traditional distribution network, the smart distribution network has several main characteristics, and multiple indicators in the power grid simulation model are determined to form a health status evaluation system for the substation area;

[0218] Among them, the main characteristics of smart distribution networks include the following:

[0219] (1) More secure and reliable power supply capability. The smart distribution network has higher equipment redundancy and system margin in terms of safety and reliability. Based on its strong and flexible grid structure, it ensures the normal power supply to important users while minimizing the impact on the power grid and users.

[0220] (2) High-quality power quality and good interaction. In view of the current development of V2G technology and electric meters, advanced monitoring technology for power quality management and reactive power compensation technology are used to meet users' requirements for high-quality power quality. At the same time, the communication and transmission of real-time power consumption information between households and networks are enhanced, so as to optimize the power consumption mode and reasonably implement peak shaving and valley filling to improve the power efficiency of the power grid.

[0221] (3) More low-carbon and environmentally friendly, the smart distribution network can support the rational grid connection of high-penetration distributed power generation and energy storage devices, realize the utilization of traditional fossil energy and reduce pollution emissions, while improving the flexibility of grid operation.

[0222] (4) Higher economic efficiency: Smart distribution networks can monitor the real-time status of equipment online and perform maintenance on equipment to extend its service life and reduce investment costs. In addition, through reasonable power flow control and network reconstruction, grid losses can be reduced.

[0223] According to the main characteristics of the smart distribution network, multiple indicators in the power grid simulation model are determined as follows:

[0224] (1) Collection indicators, that is, the user's collection data is used as the analysis indicator, which includes the number of successful collections and the number of consecutive unsuccessful collections. The period is the previous 7 days. If there is no collection item execution failure during scoring, the corresponding model algorithm will not be scored.

[0225] (2) Cost control indicators, i.e. user-level indicators, are historical success rate indicators and real-time success rate indicators. The model is used to calculate the score only when the cost control command fails to execute. The historical indicators use 60 days of data. If there is no cost control command execution failure on the day before the score, the corresponding model algorithm score is not performed.

[0226] (3) Line loss indicators are divided into substation-level indicators and user-level indicators. User-level indicators are divided into power consumption fluctuation indicators, collection success number indicators, and power consumption change rate indicators; substation-level indicators are divided into line loss rate fluctuation indicators and line loss rate indicators. When the line loss is in the normal range, no model evaluation calculation is performed. When the line loss is abnormal, a score is given based on the user's power change rate and the abnormal event of the user's power meter.

[0227] (4) Equipment event indicators are divided into station-level indicators and user-level indicators. The station-level indicators are terminal event level indicators, terminal historical event number indicators, and terminal historical event time indicators; the user-level indicators are user time level indicators, user historical event number indicators, and user historical event occurrence time indicators.

[0228] Establish multiple indicators in the power grid simulation model; multiple indicators, including: collection indicators, cost control indicators, line loss indicators, equipment event indicators;

[0229] Afterwards, the weights of the indicators are flexibly set through configuration, and the comprehensive score of the substation is obtained by weighted calculation of the four evaluation indicators.

[0230] The health status score of the substation is determined based on multiple indicators; based on the health status score, the impact of new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic substation is determined.

[0231] To conduct a comprehensive evaluation of the current operating status of the power grid, the first step is to mine data information on different factors that can reflect its operating status, that is, the main characteristics of the smart distribution network; the second step is to build an indicator system that can scientifically, systematically and comprehensively reflect its operating status. Therefore, firstly, the characteristics of the smart distribution network, the difference and connection with the traditional distribution network, and the various factors affecting the operating status of the smart distribution network are analyzed; secondly, the evaluation indicators are selected according to the indicator selection principle, so as to establish an indicator system for comprehensive evaluation of the health status of the smart distribution network;

[0232] Taking into account the integrity and feasibility of the data collected in the substations, and in order to improve the role of the application in benchmarking against the same industry and assist substation managers in their management work, the comprehensive score of the substation is determined in the form of T+1 day, that is, the comprehensive score of the substation on the day is obtained using the data of the previous day.

[0233] Afterwards, the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area is evaluated, and the evaluation value of the photovoltaic area status after the new energy equipment is connected to the photovoltaic area is determined according to the matching degree;

[0234] Finally, the health status score of the substation is determined based on the substation status evaluation value and the four indicators in the power grid simulation model; based on the health status score, the impact of new energy equipment on the line loss health of the power grid after being connected to the photovoltaic substation is determined.

[0235] Directed processing is performed on substations with low status evaluation values, and the results are analyzed for users with the lowest scores in the comprehensive evaluation to verify the rationality and practicality of the invented method. Considering the development situation of the power grid such as distribution network planning and source-load-storage development, the year-on-year change of theoretical line loss is generated by calculation, and the year-on-year change of line loss rate in the selected area is displayed on the GIS map;

[0236] The method of the present invention is as follows: first, connecting the power grid structure with the distributed energy system; second, building a distributed energy system power grid model; third, using the distributed energy system to calculate the line loss rate statistics of the voltage distribution, the year-on-year change of the line loss index unit, the monthly line loss monitoring rate, the line loss rate ranking statistics and display, the proportion of line loss rate of 10Kv and below, the proportion of high line loss and the proportion of high loss in the substation area by using the theoretical line loss calculation method, wherein the theoretical line loss calculation method includes two calculation methods: the forward-backward flow method and the algorithm of the present invention; fourth, the distributed energy system monitors the health of the calculated data and performs analysis and evaluation.

[0237] As the leading factor in the transformation of terminal energy consumption patterns, the transformation of distribution networks has a far-reaching impact. With the advancement of the construction of new power systems, distribution networks are gradually transforming from a power network that simply receives and distributes electric energy to users to a power network that integrates source, grid, load and storage and is flexibly coupled with the upper power grid. Its functions in promoting the nearby consumption of distributed power sources and carrying new loads are becoming increasingly prominent.

[0238] In view of the above characteristics, the present invention can fully consider the influence of high-proportion distributed power sources and multi-load access, and optimize and upgrade the method and model of the present invention in the synchronous line loss system.

[0239] Embodiment 6:

[0240] like Figure 7 As shown, the present invention also provides an electronic device, which may be a computer device, a single-chip device, an intelligent mobile device, etc. The electronic device in this embodiment may include a processor, a memory, a transceiver component, etc. The memory, the processor, and the transceiver component are connected via a bus; the memory may be used to store an execution program, and an exemplary execution program may include instructions; the processor is used to execute the instructions stored in the memory. The memory may also be used to store data, which may be called and / or modified when the instructions are executed.

[0241] The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc. It is the computing core and control core of the terminal, which is suitable for implementing one or more instructions, and is specifically suitable for loading and executing one or more instructions in a storage medium to implement corresponding method flows or corresponding functions, so as to implement the steps of a method for evaluating the impact of new energy access on line loss health in the above-mentioned embodiment.

[0242] Embodiment 7:

[0243] Based on the same inventive concept, the present invention also provides a readable storage medium, specifically an electronic device readable storage medium (Memory), which is a memory device in the electronic device for storing programs and data. It can be understood that the storage medium here can include both built-in storage media in the electronic device and, of course, extended storage media supported by the electronic device. The storage medium provides a storage space, which stores the operating system of the terminal. In addition, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more execution programs (including program codes). It should be noted that the storage medium here can be a high-speed RAM memory or a non-volatile memory, such as at least one disk memory. The processor loads and executes one or more instructions stored in the storage medium, which can implement the steps of a method for evaluating the impact of new energy access on line loss health in the above embodiment.

[0244] Those skilled in the art will appreciate that the embodiments of the present invention application can be provided as methods, systems, or computer program products. Therefore, the present invention application can adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present invention application can adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that contain computer-usable program code.

[0245] The present invention application is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to the embodiments of the present invention application. It should be understood that each process and / or block in the flowchart and / or block diagram, as well as the combination of the processes and / or blocks in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to generate a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0246] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0247] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process in the computer or other programmable device. Figure 1 A process or multiple processes and / or boxes Figure 1 The steps for the functions specified in one or more boxes.

[0248] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention application rather than to limit its protection scope. Although the present invention application is described in detail with reference to the above embodiments, ordinary technicians in the relevant field should understand that after reading the present invention application, those skilled in the art can still make various changes, modifications or equivalent substitutions to the specific implementation methods of the application, but these changes, modifications or equivalent substitutions are all within the protection scope of the claims to be approved.

Claims

1. A method for evaluating the impact of new energy access on line loss health, characterized in that: include: Obtain measured data of new energy equipment; Connecting the power grid to the new energy equipment to construct a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; calculating the theoretical line loss of the power grid simulation model based on the measured data and the power grid simulation model using a theoretical line loss calculation method; Based on the measured data, calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area; Based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, the impact of the new energy equipment on the line loss health of the power grid after being connected to the photovoltaic area is determined.

2. The method according to claim 1, characterized in that The determining the influence of the new energy equipment on the line loss health of the power grid after the new energy equipment is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area includes: Evaluate the matching degree between the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area, and determine the area state evaluation value after the new energy equipment is connected to the photovoltaic area based on the matching degree; Based on the power grid simulation model, multiple indicators in the power grid simulation model are established; the multiple indicators include: collection indicators, cost control indicators, line loss indicators, and equipment event indicators; Based on the substation status evaluation value and multiple indicators in the power grid simulation model, the health status score of the substation is determined; based on the health status score, the impact of the new energy equipment on the line loss health of the power grid after being connected to the photovoltaic substation is determined.

3. The method according to claim 2, characterized in that The step of determining the health status score of the substation based on the substation status evaluation value and multiple indicators in the power grid simulation model includes: Based on the substation status evaluation value, respectively determine the index scores of the collection index, the fee control index, the line loss index, and the equipment event index; A weighted operation is performed on the weights and index scores of the collection indicators, the weights and index scores of the fee control indicators, the weights and index scores of the line loss indicators, and the weights and index scores of the equipment event indicators to determine the health status score of the substation.

4. The method according to claim 1, characterized in that: The calculating of the theoretical line loss of the power grid simulation model based on the measured data and the power grid simulation model by using a theoretical line loss calculation method comprises: Based on the measured data and the grid simulation model, a correction coefficient of the photovoltaic area power ratio is determined using a theoretical line loss calculation method, and the power loss of the first area is calculated using a voltage drop method; The theoretical line loss in the power grid simulation model is calculated by multiplying the correction coefficient of the photovoltaic area power proportion by the first area loss power calculated by the voltage drop method; The theoretical line loss includes: voltage division line loss rate statistics, year-on-year changes in line loss index units, monthly line loss monitoring rate, line loss rate ranking, proportion of line loss rates of 10Kv and below, proportion of high line loss and proportion of high loss in photovoltaic areas.

5. The method according to claim 4, characterized in that The theoretical line loss calculation method includes: forward-backward power flow method and pressure drop method; The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes: Based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation area; The ratio of the power loss in the second area calculated by the forward-backward power flow method to the power loss in the first area calculated by the voltage drop method is determined as the correction coefficient of the proportion of electricity in the photovoltaic area.

6. The method according to claim 4, characterized in that The theoretical line loss calculation method includes: Newton interpolation method; The method of determining the correction coefficient of the proportion of electricity in the photovoltaic area based on the measured data and the power grid simulation model and using a theoretical line loss calculation method includes: Based on the measured data and the power grid simulation model, determine the historical photovoltaic area power share at the historical time point and the correction coefficient of the historical photovoltaic area power share, and determine the real-time photovoltaic area power share; Based on the historical photovoltaic area electricity proportion and the correction coefficient of the historical photovoltaic area electricity proportion, a mapping relationship between the photovoltaic area electricity proportion and the correction coefficient of the photovoltaic area electricity proportion is established by Newton interpolation method; The real-time photovoltaic area electricity proportion is brought into the mapping relationship to determine the correction coefficient of the photovoltaic area electricity proportion.

7. The method according to claim 6, characterized in that The process of determining the real-time photovoltaic area power proportion includes: Based on the measured data and the power grid simulation model, the total amount of online electricity of photovoltaic users at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment are obtained; Based on the total amount of online electricity of the photovoltaic user at the jth moment and the power supply of the head-end assessment table in the power grid at the jth moment, calculate the real-time photovoltaic area electricity proportion; The real-time photovoltaic area power proportion is calculated as follows: Where Rj is the real-time photovoltaic power generation ratio, P GF,j is the total amount of grid-connected electricity consumed by photovoltaic users at the jth moment, P SD,j It is the power supply of the first-end assessment table in the power grid at the jth moment.

8. The method according to claim 4, characterized in that The formula for calculating the power loss in the first station area using the voltage drop method is as follows: In the above formula, ΔP i is the power loss in the first station area calculated by the voltage drop method, P G is the photovoltaic area input power, P L is the power used by all users in the photovoltaic area, U0 is the voltage at the distribution port of the power grid simulation model, I0 is the current at the distribution port of the power grid simulation model, n is the number of photovoltaic users, i is the i-th photovoltaic user, and U i is the voltage measured by the photovoltaic user-side electric energy meter in the measured data, I i is the current measured by the PV user-side electric energy meter in the measured data, cosψ0 is the power factor of the distribution port of the power grid simulation model, and cosψ i Measure the power factor for the electric energy meter on the grid simulation model side.

9. The method according to claim 5, characterized in that Based on the power grid simulation model, the forward-backward power flow method is used to calculate the power loss in the second substation, and the calculation formula is as follows: In the above formula: ΔP cl,y is the photovoltaic area loss power calculated by the forward-backward power flow method, m is the total number of nodes in the power grid simulation model, and I yz is the branch current from node z to node y in the power grid simulation model, R yz is the branch resistance from node z to node y in the power grid simulation model, where z and y are different nodes.

10. A system for evaluating the impact of new energy access on line loss health, characterized in that: include: An acquisition module is used to obtain measured data of new energy equipment; A theoretical line loss calculation module is used to connect the power grid with the new energy equipment and construct a power grid simulation model after the new energy equipment is connected to the photovoltaic area in the power grid; based on the measured data and the power grid simulation model, the theoretical line loss of the power grid simulation model is calculated using a theoretical line loss calculation method; A line loss calculation module of a photovoltaic area, used for calculating the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area based on the measured data; The line loss health impact determination module is used to determine the impact of the new energy equipment on the line loss health of the power grid after it is connected to the photovoltaic area based on the theoretical line loss of the power grid simulation model and the line loss of the photovoltaic area before the new energy equipment is connected to the photovoltaic area.

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