Method, device and equipment for identifying operation state of power system based on inertia and medium

Abstract

The invention provides a method and device for identifying the operation state of a power system based on inertia, electronic equipment and a storage medium, and the method comprises the steps: obtaining the current inertia level of the power system and the corresponding minimum inertia demands of all levels of the power system; and based on the current inertia level of the power system and the inertia requirements of the power system under all levels, determining a safety level coefficient corresponding to the power system. The operation state of the power system can be determined based on the inertia of the power system, and the safety of the power system is improved.

Description

[Technical field]

[0001] Embodiments of the present invention relate to the technical field of power grid operation, and in particular to a method, device, equipment and medium for identifying the operating status of a power system based on inertia. [Background technology]

[0003] In the low inertia scenario, large disturbances such as DC lockout and converter failure will cause the system frequency change rate and transient frequency deviation to change faster and larger, which can easily cause large-scale new energy to enter the low voltage or high voltage ride-through process, or even chain disconnection from the grid, thereby triggering the system's third line of safety defense automatic devices such as low-frequency load reduction and high-frequency machine cutting.

[0004] In summary, weak inertia has become a constraint on the low-carbon transformation of the power system. How to accurately identify the inertia of the power system and determine the operating status of the power system based on the inertia of the power system has become a technical problem that technical personnel in this field urgently need to solve. [Summary of the invention]

[0005] The embodiments of the present invention provide a method, device, equipment and medium for identifying the operating status of an electric power system based on inertia, which accurately identifies the inertia of the electric power system and determines the operating status of the electric power system based on the inertia of the electric power system, thereby improving the safety of power grid operation.

[0006] In a first aspect, the present application provides a method for identifying an operating state of an electric power system based on inertia, the method comprising:

[0007] Obtain the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system;

[0008] Based on the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system, a safety level coefficient corresponding to the power system is determined.

[0009] Through this application, the inertia of the power system can be accurately identified, and the operating status of the power system can be determined based on the inertia of the power system, thereby improving the safety of power grid operation.

[0010] One possible approach is that the minimum inertia requirements corresponding to all levels of the power system include: the minimum inertia requirements of the first level corresponding to a single fault of the power system, and the minimum inertia requirements of the second level corresponding to a serious fault of the power system;

[0011] In the step of determining the safety level coefficient corresponding to the power system based on the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system,

[0012] The safety level coefficient corresponding to the power system is determined by the following formula:

[0013]

[0014] I sd —Safety factor corresponding to the power system;

[0015] H sys —The current inertia level of the power system;

[0016] —Minimum inertia requirement for the first level corresponding to a single fault in the power system;

[0017] —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

[0018] One possible way is, in the step of obtaining the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system: the current inertia level of the power system is determined by the following method:

[0019]

[0020] Among them, H sys —The current inertia level of the power system;

[0021] N syn —Number of synchronous units in the power system;

[0022] N rgu —The number of new energy units that can provide virtual inertia in the power system;

[0023] H syn,i —Inertia of the ith synchronous unit;

[0024] H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control;

[0025] x i —Operation status of the ith synchronous unit;

[0026] y j —Operating status of the jth new energy unit.

[0027] One possible way is,

[0028] In the step of obtaining the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system, the minimum inertia requirement corresponding to the first level corresponding to a single fault of the power system is determined in the following manner:

[0029]

[0030] —Minimum inertia requirement corresponding to the first level of the power system;

[0031] ΔP1—the maximum N-1 fault power that may occur in the current system;

[0032] RoCoF sc,1 —Safety limit of the maximum frequency change rate corresponding to the first level fault of the power system;

[0033] Δf sc,1 —The maximum frequency deviation safety limit corresponding to the system under the first level fault;

[0034] α1—Safety factor of frequency change rate corresponding to the first level fault of the power system;

[0035] β1—The maximum allowable deviation coefficient of the rate corresponding to the first-level fault of the power system;

[0036] f d —Dead zone of primary frequency regulation in power system;

[0037] R s —Primary frequency regulation rate of power system;

[0038] D—equivalent damping coefficient of power system;

[0039] t c —Delay time of primary frequency regulation action of power system;

[0040] —The system frequency deviation corresponding to the primary frequency regulation action of the power system;

[0041] f0—power system frequency rating;

[0042] The minimum inertia requirement of the second level corresponding to a serious fault in the power system is determined as follows:

[0043]

[0044] —Minimum inertia requirement corresponding to the second level of the power system;

[0045] ΔP2—the maximum N-2 fault power that may occur in the current system;

[0046] RoCoF sc,2 —Safety limit of the maximum frequency change rate corresponding to the second level fault of the power system;

[0047] Δf sc,2—The maximum frequency deviation safety limit corresponding to the system under the second level fault;

[0048] α2—Safety factor of frequency change rate corresponding to the second-level fault of the power system;

[0049] β2—The maximum allowable deviation coefficient of the rate corresponding to the second-level fault of the power system;

[0050] f d —Dead zone of primary frequency regulation in power system;

[0051] R s —Primary frequency regulation rate of power system;

[0052] D—equivalent damping coefficient of power system;

[0053] ΔP s —Active power adjustment of emergency frequency control measures of power system;

[0054] t s —Action delay time of emergency control measures of power system frequency;

[0055] —The system frequency deviation corresponding to the primary frequency regulation action of the power system;

[0056] f0—power system frequency rating.

[0057] One possible approach is that the method further includes:

[0058] Obtain the inertia resources available in the power system, as well as the mapping relationship between the inertia resources available in the power system, the current inertia level of the power system and the reserve safety factor of the power system;

[0059] The reserve safety factor of the power system is determined based on the available inertia resource amount of the power system, the current inertia level of the power system and the mapping relationship.

[0060] In one possible manner, the method further includes: in the step of obtaining the amount of inertia resources available for the power system, the amount of inertia resources available for the power system is determined by using the following formula:

[0061]

[0062] —The amount of inertia resources available to the power system;

[0063] N syn —Number of synchronous units in the power system;

[0064] N rgu —The number of new energy units that can provide virtual inertia in the power system;

[0065] H syn,i —Inertia of the ith synchronous unit;

[0066] H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control;

[0067] K D —Power system synchronous torque coefficient;

[0068] K S —Power system load moment coefficient;

[0069] ζ min —The minimum allowed value of the power system damping ratio.

[0070] One possible way is that, based on the inertia resource amount available in the power system, the current inertia level of the power system, and the mapping relationship between the inertia resource amount available in the power system, the current inertia level of the power system and the reserve safety factor of the power system, in the step of determining the reserve safety factor of the power system, the mapping relationship between the inertia resource amount available in the power system, the current inertia level of the power system and the reserve safety factor of the power system is as follows:

[0071]

[0072]

[0073] K IRS ——Power system reserve safety factor;

[0074] —Amount of inertia resources available in the power system

[0075] H sys —The current inertia level of the power system;

[0076] —Minimum inertia requirement of power system;

[0077] —Minimum inertia requirement for the first level corresponding to a single fault in the power system;

[0078] —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

[0079] In a second aspect, the present application provides a device for identifying the operating state of a power system based on inertia, comprising:

[0080] Acquisition module: used to obtain the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system;

[0081] Determination module: used to determine the safety level coefficient corresponding to the power system based on the current inertia level of the power system and the inertia requirements of the power system at all levels.

[0082] In a third aspect, an embodiment of the present invention provides an electronic device, including:

[0083] at least one processor; and

[0084] at least one memory in communication with the processor, wherein:

[0085] The memory stores program instructions that can be executed by the processor, and the processor calls the program instructions to execute the method provided by the first aspect.

[0086] In a fourth aspect, an embodiment of the present invention provides a non-transitory computer-readable storage medium, wherein the non-transitory computer-readable storage medium stores computer instructions, and the computer instructions enable the computer to execute the method provided in the first aspect.

[0087] It should be understood that the second to fourth aspects of the embodiments of the present invention are consistent with the technical solutions of the first aspect of the embodiments of the present invention, and the beneficial effects achieved by each aspect and the corresponding feasible implementation methods are similar and will not be described in detail.

Brief Description of the Drawings

[0088] In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings required for use in the embodiments are briefly introduced below. Obviously, the drawings described below are only some embodiments of the embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0089] Figure 1 A flow chart of a method for identifying the operating status of a power system based on inertia provided in an embodiment of the present application;

[0090] Figure 2 A mapping relationship diagram of a power system safety level factor, a current inertia level, and the corresponding minimum inertia requirements at all levels of the power system shown in an exemplary embodiment provided in an embodiment of the present application;

[0091] Figure 3 A flow chart of another method for identifying the operating status of a power system based on inertia provided in an embodiment of the present application;

[0092] FIG4( a) is a topological diagram of a power system shown in an exemplary embodiment provided in an embodiment of the present application; FIG4( b ) is another example of the current inertia level range of the power system provided in an embodiment of the present application;

[0093] FIG5( a) is a topological diagram of a power system shown in an exemplary embodiment provided in an embodiment of the present application;

[0094] FIG5( b ) is a frequency response curve corresponding to FIG4( a );

[0095] Figure 6 A structural diagram of a device for identifying the operating status of a power system based on inertia provided in an embodiment of the present application; Figure 7 The figure is a schematic diagram of the structure of an electronic device according to an embodiment of the present invention. [Specific implementation method]

[0096] In order to better understand the technical solution of the embodiment of the present invention, the embodiment of the present invention is described in detail below with reference to the accompanying drawings.

[0097] It should be clear that the described embodiments are only part of the embodiments of the present invention, not all of them. Based on the embodiments in the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of the embodiments of the present invention.

[0098] The terms used in the embodiments of the present invention are only for the purpose of describing specific embodiments, and are not intended to limit the embodiments of the present invention. The singular forms "a", "said" and "the" used in the embodiments of the present invention and the appended claims are also intended to include plural forms, unless the context clearly indicates other meanings.

[0099] With the continuous depletion of fossil energy and increasingly stringent carbon emission requirements, the energy supply model based on traditional fossil energy has become difficult to adapt to the needs of low-carbon social development. Vigorously developing new energy has become an inevitable choice to achieve clean and low-carbon energy transformation.

[0100] The power system is different from the traditional fossil fuel power source. Asynchronous power sources (including but not limited to: wind power, photovoltaic, DC, battery energy storage) all need to rely on converters to interface with the grid. Therefore, conventional control methods cannot provide rotational inertia support for the grid after active disturbances, resulting in a significant drop in the system inertia level, which seriously reduces the system frequency regulation capability.

[0101] In view of this, the startup capacity of traditional power sources and the frequency regulation standby capacity will be further compressed. In low-inertia scenarios, large disturbances such as DC blocking and converter failure will cause the system frequency change rate and transient frequency deviation to change faster and larger, which can easily cause large-scale new energy to enter the low-voltage or high-voltage ride-through process, or even chain disconnection from the grid, thereby triggering the system's low-frequency load reduction and high-frequency machine cutting and other third-line safety defense automatic devices to operate.

[0102] In summary, weak inertia has become a constraint on the low-carbon transformation of the power system. How to accurately identify the inertia of the power system and determine the operating status of the power system based on the inertia of the power system has become a technical problem that technical personnel in this field urgently need to solve.

[0103] In order to solve the above problems, the present application provides a method, device, electronic device and storage medium for identifying the operating status of an electric power system based on inertia, so as to determine the operating status of the electric power system based on the inertia of the electric power system and improve the safety of the electric power system.

[0104] First, the terms used in this application will be described:

[0105] N-1 fault: refers to the situation where any independent component (generator, transmission line, transformer, etc.) among the N components of the power system fails and is removed, which should not cause power outages for users due to overload tripping of other lines, destroy the stability of the system, or cause accidents such as voltage collapse.

[0106] N-2 fault: refers to the situation where any two independent components (generators, transmission lines, transformers, etc.) among the N components of the power system fail and are removed, which should not cause power outages for users due to overload tripping of other lines, destroy the stability of the system, or cause accidents such as voltage collapse.

[0107] Secondly, refer to Figure 1 , a method for identifying the operating status of a power system based on inertia provided in an embodiment of the present application specifically includes the following steps:

[0108] S101: Obtaining the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system.

[0109] Exemplarily, in this step, the power system levels include: a first level corresponding to a single fault in the power system, and a second level corresponding to a serious fault in the power system.

[0110] That is, in this example, the minimum inertia requirement corresponding to all levels of the power system is the minimum inertia requirement corresponding to the first level of the power system and the minimum inertia requirement corresponding to the second level of the power system.

[0111] To obtain the current inertia level of the power system, the following formula can be used:

[0112]

[0113] Among them, H sys —The current inertia level of the power system;

[0114] N syn —Number of synchronous units in the power system;

[0115] H rgu —The number of new energy units that can provide virtual inertia in the power system;

[0116] H syn,i —Inertia of the ith synchronous unit;

[0117] H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control;

[0118] x i —Operation status of the ith synchronous unit;

[0119] y j —Operating status of the jth new energy unit.

[0120] It should be noted that in order to obtain the current inertia level of the power system, the parameters that need to be obtained for the power system include but are not limited to the overall load level, the rated capacity of various types of generator sets, the inertia constant, the operating status, the system frequency regulation rate and the system frequency safety control strategy.

[0121] The minimum inertia requirement for the first level corresponding to a single fault in the power system can be specifically calculated using the following formula:

[0122]

[0123] —Minimum inertia requirement corresponding to the first level of the power system

[0124] ΔP1—the maximum N-1 fault power that may occur in the current system;

[0125] RoCoF sc,1 —Safety limit of the maximum frequency change rate corresponding to the first level fault of the power system;

[0126] Δf sc,1 —The maximum frequency deviation safety limit corresponding to the system under the first level fault;

[0127] α1—Safety factor of frequency change rate corresponding to the first level fault of the power system;

[0128] β1—The maximum allowable deviation coefficient of the rate corresponding to the first-level fault of the power system;

[0129] f d —Dead zone of primary frequency regulation in power system;

[0130] R s —Primary frequency regulation rate of power system;

[0131] D—equivalent damping coefficient of power system;

[0132] t c —Delay time of primary frequency regulation action of power system;

[0133] —The system frequency deviation corresponding to the primary frequency regulation action of the power system;

[0134] Combined with the above definition of N-1 fault, in order to obtain ΔP2, that is, the maximum value of the primary frequency regulation rate of the power system under N-1 fault, it is necessary to determine the maximum safety allowed by the system frequency safety index under N-1 fault according to the power system operation scenario and power system frequency safety, combined with the requirements of the power grid frequency safety line, and estimate the primary frequency regulation rate of the power system under N-1 fault in combination with the measurement / operation mode data of SCADA, PMU / WAMS or PSASP / BPA.

[0135] The minimum inertia requirement for the second level corresponding to the serious fault of the second power system can be specifically calculated using the following formula:

[0136]

[0137] —Minimum inertia requirement for the second level corresponding to serious faults in the power system;

[0138] ΔP2—the maximum N-2 fault power that may occur in the current system;

[0139] RoCoF sc,2 —Safety limit of the maximum frequency change rate corresponding to the second level fault of the power system;

[0140] Δf sc,2 —The maximum frequency deviation safety limit corresponding to the system under the second level fault;

[0141] α2—Safety factor of frequency change rate corresponding to the second-level fault of the power system;

[0142] β2—The maximum allowable deviation coefficient of the rate corresponding to the second-level fault of the power system;

[0143] f d —Dead zone of primary frequency regulation in power system;

[0144] R s —Primary frequency regulation rate of power system;

[0145] D—equivalent damping coefficient of power system;

[0146] ΔP s —Active power adjustment of emergency frequency control measures of power system;

[0147] t s —Action delay time of emergency control measures of power system frequency;

[0148] —The system frequency deviation corresponding to the primary frequency regulation action of the power system;

[0149] f0—power system frequency rating.

[0150] Similarly, combined with the above definition of N-2 fault, in order to obtain ΔP2, that is, the maximum value of the power system frequency regulation rate under N-2 fault, it is necessary to determine the maximum safety allowed by the system frequency safety index under N-2 fault based on the power system operation scenario and power system frequency safety, combined with the power grid frequency safety line, and estimate the primary frequency regulation rate of the power system under N-2 fault in combination with SCADA, PMU / WAMS or PSASP / BPA and other measurement / operation mode data.

[0151] S102: Determine a safety level coefficient corresponding to the power system based on the current inertia level of the power system and the inertia requirements of the power system at all levels.

[0152] In combination with the above example, in step S101, the minimum inertia requirement corresponding to the first level corresponding to a single fault in the power system, the minimum inertia requirement corresponding to the second level corresponding to a serious fault in the power system, and the current inertia level of the power system are obtained. Specifically, the safety level coefficient corresponding to the power system can be determined using the following formula:

[0153]

[0154] I sd —Safety factor corresponding to the power system;

[0155] H sys —The current inertia level of the power system;

[0156] —Minimum inertia requirement for the first level corresponding to a single fault in the power system;

[0157] —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

[0158] The functional relationship between the safety factor corresponding to the power system and the minimum inertia requirement corresponding to the first level of the power system and the minimum inertia requirement corresponding to the second level of the power system is as follows: Figure 2 shown.

[0159] At this time, combined with the "three lines of defense" requirements for grid frequency safety, the power system state can be divided into three categories: unsafe, relatively safe, and absolutely safe based on the inertia operating state of the power system.

[0160] Furthermore, the minimum inertia requirement of the first level corresponding to a single fault in the power system is Minimum inertia requirement for the second level corresponding to severe power system failure Set as the boundary between the inertia unsafe state and the relatively safe state. If the current inertia level of the power system is as well as If it is less than It is unsafe. If it is greater than It means safety.

[0161] Through the above implementation, the safety of the power system can be quantitatively evaluated based on the inertia of the power system, the safety level of the power system can be intuitively determined, and the safety of the operation of the power system can be improved.

[0162] In addition, in some embodiments of the present application, in addition to intuitively assessing the safety level, in some other embodiments of the present application, it is also determined whether the inertia reserve of the power system is safe, referring to Figure 3 , specifically including the following steps:

[0163] S201: Obtain the amount of inertia resources available for the power system, and a mapping relationship between the amount of inertia resources available for the power system, the current inertia level of the power system, and the reserve safety factor of the power system.

[0164] The inertia resources available for the power system can be obtained by using the following formula:

[0165]

[0166] —The amount of inertia resources available to the power system;

[0167] N syn —Number of synchronous units in the power system;

[0168] N rgu —The number of new energy units that can provide virtual inertia in the power system;

[0169] H syn,i —Inertia of the ith synchronous unit;

[0170] H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control;

[0171] KD —Power system synchronous torque coefficient;

[0172] K S —Power system load moment coefficient;

[0173] ζ min —The minimum allowed value of the power system damping ratio.

[0174] S202: Determine a reserve safety factor of the power system based on the available inertia resource amount of the power system, the current inertia level of the power system and the mapping relationship.

[0175] Here, the power system reserve safety factor can represent whether the inertia reserve of the power system is sufficient under different operating scenarios.

[0176] Regarding the method for calculating the current inertia level of the power system, specific reference may be made to the aforementioned embodiment, which will not be described in detail here.

[0177] Specifically, the mapping relationship between the available inertia resource of the power system, the current inertia level of the power system and the reserve safety factor of the power system can be:

[0178]

[0179]

[0180] K IRS ——Power system reserve safety factor;

[0181] —Amount of inertia resources available in the power system

[0182] H sys —The current inertia level of the power system;

[0183] —Minimum inertia requirement of power system;

[0184] —Minimum inertia requirement for the first level corresponding to a single fault in the power system;

[0185] —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

[0186] In some scenarios, the current inertia level of the power system is determined by the amount of inertia resources available in the power system and This means that the power system has reserve inertia, K IRS ≥0; in some other situations, the power system does not have reserve inertia, in this case, K IRS ≤-1.

[0187] Therefore, the power system reserve safety factor can be used to determine whether the power system inertia reserve is safe, which helps power grid-related personnel to timely grasp the system inertia operating status and reserve conditions and formulate appropriate preventive measures in advance.

[0188] At the same time, with regard to the grid dispatching method, the aforementioned implementation method is helpful in assisting grid operation dispatching personnel to reasonably arrange the system operation mode and maintenance plan. At the grid planning level, it can be used to reasonably guide the capacity ratio and optimal layout of conventional power sources and virtual inertia resources, and assist in determining the access scale and control method of new energy, direct current, etc. that the planned grid can carry.

[0189] In order to further explain the previous embodiments of the present application, the following is a specific example:

[0190] A New England 39-node system was built in the power system simulation platform. G03, G04 and G08 in the England 39-node system were replaced with wind farms consisting of 160, 160 and 140 5MW wind turbines (W1, W2 and W3), respectively.

[0191] At the same time, the simulation parameters for the power system are set as follows:

[0192] The inertia resource of synchronous units available in the power system is 24470MW.s. At the same time, nodes 30, 31, 32, 33, 34, 35, 36, 37 and 39 are equipped with adjustable inertia resources. The inertia size of the adjustable virtual inertia resource available in the system is 42000MW.s. The network topology is shown in Figure 4(a).

[0193] In order to fully illustrate the proposed inertia sufficiency quantitative analysis method, the embodiment of the present invention constructs 5 operation scenarios, and the relevant descriptions of each scenario are as follows: Scenario—CJ1) Wind turbines W1, W2 and W3 do not provide inertia and primary frequency regulation control; Scenario—CJ2) Wind turbines W1, W2 and W3 all provide inertia and primary frequency regulation support control; Scenario—CJ3) Only consider wind turbine W3 with virtual inertia and primary frequency regulation control; Scenario—CJ4) Set the emergency control amount of 75MW frequency; Scenario—CJ5) Set the emergency control amount of 150MW frequency.

[0194] According to the steps of the present invention, the system inertia operation status and reserve status of the system in different operation scenarios can be obtained, as shown in Table 1. It can be seen from the table that the inertia safety analysis method comprehensively displays the inertia operation status related information of the system in different operation scenarios, including safety status and reserve status. For example, in the operation scenarios CJ3, CJ4 and CJ5, the inertia safety ratio Isd is lower than 0%, which indicates that the inertia level of the system in the above operation scenarios is unsafe, and relevant measures need to be taken to improve the system inertia level, such as reducing the system disturbance power, improving the system inertia level, optimizing the system frequency safety control measures, etc.; In addition, it can be seen from the table that in the operation scenario CJ3, the system inertia safety reserve coefficient KIRS is -92%. According to the above inertia reserve requirements, the system inertia reserve is insufficient in this scenario, and relevant measures need to be taken to improve the system inertia reserve level.

[0195] Table 1 Inertia operation status and reserve analysis results under various operation scenarios S1-S5

[0196]

[0197] In order to further verify the correctness of the proposed inertia safety analysis method, the system inertia level in each scenario is adjusted to Figure 4(b) shows the system inertia center frequency response curve under the corresponding inertia level. As can be seen from Figure 4(b), for the operation scenarios CJ3, CJ4 and CJ5, the lowest system frequency is 59.48, 59.49 and 59.49 Hz respectively, which are close to the safety threshold of 59.50 Hz specified by the system; while for the operation scenarios CJ1 and CJ2, the system frequency under active power disturbance has the lowest oCoF of about 0.49 Hz / s, which is consistent with the safety threshold of 0.5 Hz / s specified by the system. The simulation results further verify the reliability of the proposed inertia demand calculation method.

[0198] 5 , the present application provides a device for identifying the operating state of a power system based on inertia, comprising:

[0199] Acquisition module: used to obtain the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system;

[0200] Determination module: used to determine the safety level coefficient corresponding to the power system based on the current inertia level of the power system and the inertia requirements of the power system at all levels.

[0201] The inertia-based power system operating state identification device provided in the embodiment shown in FIG. 5 can be used to implement the embodiment of the present invention. Figure 1 The technical solution of the method embodiment shown, its implementation principle and technical effects can be further referred to the relevant description in the method embodiment.

[0202] Figure 6 FIG. 1 is a schematic diagram of the structure of an electronic device according to an embodiment of the present invention. Figure 6 As shown, the electronic device may include at least one processor; and at least one memory in communication with the processor, wherein: the memory stores program instructions executable by the processor, and the processor calls the program instructions to execute the embodiments of the present invention. Figure 1 The embodiment shown in FIG4 provides a method for identifying the operating status of a power system based on inertia.

[0203] Figure 6 A block diagram of an exemplary electronic device suitable for implementing an exemplary embodiment of the present invention is shown. Figure 6 The electronic device shown is only an example and should not bring any limitation to the functions and scope of use of the embodiments of the present invention.

[0204] like Figure 6 As shown, the electronic device is in the form of a general-purpose computing device. The components of the electronic device may include, but are not limited to: one or more processors 410, memory 430, and a communication bus 440 connecting different system components (including memory 430 and processing unit 410).

[0205] The communication bus 440 represents one or more of several types of bus structures, including a memory bus or memory controller, a peripheral bus, a graphics acceleration port, a processor or a local bus using any of a variety of bus structures. For example, these architectures include but are not limited to Industry Standard Architecture (ISA) bus, Micro Channel Architecture (MAC) bus, Enhanced ISA bus, Video Electronics Standards Association (VESA) local bus and Peripheral Component Interconnection (PCI) bus.

[0206] Electronic devices typically include a variety of computer system readable media. These media can be any available media that can be accessed by the electronic device, including volatile and non-volatile media, removable and non-removable media.

[0207] The memory 430 may include a computer system readable medium in the form of a volatile memory, such as a random access memory (RAM) and / or a cache memory. The electronic device may further include other removable / non-removable, volatile / non-volatile computer system storage media. The memory 430 may include at least one program product having a set (e.g., at least one) of program modules configured to perform the functions of various embodiments of the present invention.

[0208] A program / utility having a set (at least one) of program modules may be stored in memory 430, such program modules including, but not limited to, an operating system, one or more application programs, other program modules, and program data, each of which or some combination may include an implementation of a network environment. The program modules generally perform the functions and / or methods of the embodiments described in the embodiments of the present invention.

[0209] The processor 410 executes various functional applications and data processing by running the programs stored in the memory 430, such as implementing the embodiments of the present invention. Figure 1 The embodiment shown in FIG4 provides a method for identifying the operating status of an electric power system based on inertia.

[0210] An embodiment of the present invention provides a non-transitory computer-readable storage medium, wherein the non-transitory computer-readable storage medium stores computer instructions, wherein the computer instructions enable the computer to execute an embodiment of the present invention. Figure 1 The embodiment shown in FIG4 provides a method for identifying the operating status of a power system based on inertia.

[0211] The above-mentioned computer-readable storage medium can adopt any combination of one or more computer-readable media. The computer-readable medium can be a computer-readable signal medium or a computer-readable storage medium. The computer-readable storage medium can be, for example, - but not limited to - an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, device or device, or any combination of the above. More specific examples (non-exhaustive list) of computer-readable storage media include: an electrical connection with one or more wires, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ReadOnly Memory; hereinafter referred to as: ROM), an erasable programmable read-only memory (Erasable Programmable ReadOnly Memory; hereinafter referred to as: EPROM) or flash memory, optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the above. In this document, a computer-readable storage medium can be any tangible medium containing or storing a program, which can be used by an instruction execution system, device or device or used in combination with it.

[0212] Computer-readable signal media may include a data signal propagated in baseband or as part of a carrier wave, which carries a computer-readable program code. Such propagated data signals may take a variety of forms, including, but not limited to, electromagnetic signals, optical signals, or any suitable combination of the above. Computer-readable signal media may also be any computer-readable medium other than a computer-readable storage medium, which may send, propagate, or transmit a program for use by or in conjunction with an instruction execution system, apparatus, or device.

[0213] Program code embodied on a computer readable medium may be transmitted using any appropriate medium, including but not limited to wireless, wireline, optical fiber cable, RF, etc., or any suitable combination of the foregoing.

[0214] The computer program code for performing the operation of the embodiments of the present invention can be written in one or more programming languages ​​or a combination thereof, including object-oriented programming languages, such as Java, Smalltalk, C++, and conventional procedural programming languages, such as "C" language or similar programming languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as an independent software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In the case of a remote computer, the remote computer can be connected to the user's computer through any type of network, including a local area network (Local Area Network; hereinafter referred to as: LAN) or a wide area network (Wide Area Network; hereinafter referred to as: WAN), or can be connected to an external computer (for example, using an Internet service provider to connect through the Internet).

[0215] The above describes specific embodiments of the present invention. Other embodiments are within the scope of the appended claims. In some cases, the actions or steps recorded in the claims can be performed in an order different from that in the embodiments and still achieve the desired results. In addition, the processes depicted in the accompanying drawings do not necessarily require the specific order or continuous order shown to achieve the desired results. In some embodiments, multitasking and parallel processing are also possible or may be advantageous.

[0216] In the description of the embodiments of the present invention, the description with reference to the terms "one embodiment", "some embodiments", "example", "specific example", or "some examples" etc. means that the specific features, structures, materials or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the embodiments of the present invention. In the embodiments of the present invention, the schematic representations of the above terms do not necessarily refer to the same embodiments or examples. Moreover, the specific features, structures, materials or characteristics described may be combined in any one or more embodiments or examples in a suitable manner. In addition, those skilled in the art may combine and combine the different embodiments or examples described in the embodiments of the present invention and the features of the different embodiments or examples, without contradiction.

[0217] In addition, the terms "first" and "second" are used for descriptive purposes only and should not be understood as indicating or implying relative importance or implicitly indicating the number of the indicated technical features. Thus, a feature defined as "first" or "second" may explicitly or implicitly include at least one of the features. In the description of the embodiments of the present invention, the meaning of "plurality" is at least two, such as two, three, etc., unless otherwise clearly and specifically defined.

[0218] Any process or method description in a flowchart or otherwise described herein may be understood to represent a module, fragment or portion of code comprising one or more executable instructions for implementing the steps of a custom logical function or process, and the scope of the preferred implementation of the embodiments of the present invention includes alternative implementations in which functions may not be performed in the order shown or discussed, including performing functions in a substantially simultaneous manner or in reverse order depending on the functions involved, which should be understood by technicians in the technical field to which the embodiments of the present invention belong.

[0219] The word "if" as used herein may be interpreted as "at the time of" or "when" or "in response to determining" or "in response to detecting", depending on the context. Similarly, the phrases "if it is determined" or "if (stated condition or event) is detected" may be interpreted as "when it is determined" or "in response to determining" or "when detecting (stated condition or event)" or "in response to detecting (stated condition or event)", depending on the context.

[0220] It should be noted that the terminals involved in the embodiments of the present invention may include but are not limited to personal computers (Personal Computer; hereinafter referred to as: PC), personal digital assistants (Personal Digital Assistant; hereinafter referred to as: PDA), wireless handheld devices, tablet computers (Tablet Computer), mobile phones, MP3 players, MP4 players, etc.

[0221] In the several embodiments provided in the embodiments of the present invention, it should be understood that the disclosed systems, devices and methods can be implemented in other ways. For example, the device embodiments described above are only schematic. For example, the division of the units is only a logical function division. There may be other division methods in actual implementation. For example, multiple units or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the mutual coupling or direct coupling or communication connection shown or discussed can be through some interfaces, indirect coupling or communication connection of devices or units, which can be electrical, mechanical or other forms.

[0222] In addition, each functional unit in each embodiment of the present invention may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may be integrated into one unit. The above-mentioned integrated unit may be implemented in the form of hardware or in the form of hardware plus software functional units.

[0223] The above-mentioned integrated unit implemented in the form of a software functional unit can be stored in a computer-readable storage medium. The above-mentioned software functional unit is stored in a storage medium, including a number of instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) or a processor (Processor) to perform some steps of the method described in each embodiment of the present invention. The aforementioned storage medium includes: U disk, mobile hard disk, read-only memory (Read-Only Memory; hereinafter referred to as: ROM), random access memory (Random Access Memory; hereinafter referred to as: RAM), disk or optical disk and other media that can store program codes.

[0224] The above description is only a preferred embodiment of the embodiment of the present invention and is not intended to limit the embodiment of the present invention. Any modifications, equivalent substitutions, improvements, etc. made within the spirit and principles of the embodiment of the present invention should be included in the scope of protection of the embodiment of the present invention.

Claims

1. A method for identifying the operating status of a power system based on inertia, characterized in that: The method comprises: Obtain the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system; Based on the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system, a safety level coefficient corresponding to the power system is determined.

2. The method according to claim 1, characterized in that The minimum inertia requirements corresponding to all levels of the power system include: the minimum inertia requirements of the first level corresponding to a single fault of the power system, and the minimum inertia requirements of the second level corresponding to a serious fault of the power system; In the step of determining the safety level coefficient corresponding to the power system based on the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system, The safety level coefficient corresponding to the power system is determined by the following formula: I sd —Safety factor corresponding to the power system; H sys —The current inertia level of the power system; —Minimum inertia requirement for the first level corresponding to a single fault in the power system; —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

3. The method according to claim 2, characterized in that In the step of obtaining the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system: the current inertia level of the power system is determined by the following method: Among them, H sys —The current inertia level of the power system; N syn —Number of synchronous units in the power system; H rgu —The number of new energy units that can provide virtual inertia in the power system; H syn,i —Inertia of the ith synchronous unit; H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control; x i —Operation status of the ith synchronous unit; y j —Operating status of the jth new energy unit.

4. The method according to claim 2, characterized in that: In the step of obtaining the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system, the minimum inertia requirement corresponding to the first level corresponding to a single fault of the power system is determined in the following manner: —Minimum inertia requirement corresponding to the first level of the power system; ΔP1—the maximum N-1 fault power that may occur in the current system; RoCoF sc,1 —Safety limit of the maximum frequency change rate corresponding to the first level fault of the power system; Δf sc,1 —The maximum frequency deviation safety limit corresponding to the system under the first level fault; α1—Safety factor of frequency change rate corresponding to the first level fault of the power system; β1—The maximum allowable deviation coefficient of the rate corresponding to the first-level fault of the power system; f d —Dead zone of primary frequency regulation in power system; R s —Primary frequency regulation rate of power system; D—equivalent damping coefficient of power system; t c —Delay time of primary frequency regulation action of power system; —The system frequency deviation corresponding to the primary frequency regulation action of the power system; f0—power system frequency rating; The minimum inertia requirement corresponding to the second level corresponding to a serious fault in the power system is determined in the following manner: —Minimum inertia requirement corresponding to the second level of the power system; ΔP2—the maximum N-2 fault power that may occur in the current system; RoCoF sc,2 —Safety limit of the maximum frequency change rate corresponding to the second level fault of the power system; Δf sc,2 —The maximum frequency deviation safety limit corresponding to the system under the second level fault; α2—Safety factor of frequency change rate corresponding to the second-level fault of the power system; β2—The maximum allowable deviation coefficient of the rate corresponding to the second-level fault of the power system; f d —Dead zone of primary frequency regulation in power system; R s —Primary frequency regulation rate of power system; D—equivalent damping coefficient of power system; ΔP s —Active power adjustment of emergency frequency control measures of power system; t s —Action delay time of emergency control measures of power system frequency; —The system frequency deviation corresponding to the primary frequency regulation action of the power system; f0—power system frequency rating.

5. The method according to any one of claims 1 to 4, characterized in that: The method further comprises: Obtain the inertia resources available in the power system, as well as the mapping relationship between the inertia resources available in the power system, the current inertia level of the power system and the reserve safety factor of the power system; The reserve safety factor of the power system is determined based on the available inertia resource amount of the power system, the current inertia level of the power system and the mapping relationship.

6. The method according to claim 5, characterized in that The method further includes: in the step of obtaining the amount of inertia resources available for the power system, the amount of inertia resources available for the power system is determined by using the following formula: —The amount of inertia resources available to the power system; N syn —Number of synchronous units in the power system; N rgu —The number of new energy units that can provide virtual inertia in the power system; H syn,i —Inertia of the ith synchronous unit; H rgu,j —Simulated inertia size of the jth new energy unit with simulated inertia control; K D —Power system synchronous torque coefficient; K S —Power system load moment coefficient; ζ min —The minimum allowed value of the power system damping ratio.

7. The method according to claim 6, characterized in that In the step of determining the reserve safety factor of the power system based on the inertia resource amount available for the power system, the current inertia level of the power system, and the mapping relationship between the inertia resource amount available for the power system, the current inertia level of the power system, and the reserve safety factor of the power system, the mapping relationship between the inertia resource amount available for the power system, the current inertia level of the power system, and the reserve safety factor of the power system is as follows: K IRS ——Power system reserve safety factor; —The amount of inertia resources available to the power system; H sys —The current inertia level of the power system; —Minimum inertia requirement of power system; —Minimum inertia requirement for the first level corresponding to a single fault in the power system; —The minimum inertia requirement for the second level corresponding to a serious fault in the power system.

8. A device for identifying the operating status of a power system based on inertia, characterized in that: include: Acquisition module: used to obtain the current inertia level of the power system and the corresponding minimum inertia requirements at all levels of the power system; Determination module: used to determine the safety level coefficient corresponding to the power system based on the current inertia level of the power system and the inertia requirements of the power system at all levels.

9. An electronic device, characterized in that: include: at least one processor; as well as at least one memory in communication with the processor, wherein: The memory stores program instructions executable by the processor, and the processor can execute the method according to any one of claims 1 to 7 by calling the program instructions.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and the computer instructions enable the computer to execute the method according to any one of claims 1 to 7.

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