A yard primary frequency control method considering autonomous response of network construction type equipment

Abstract

The application discloses a kind of station primary frequency modulation control methods considering network type equipment autonomous response, belong to new energy power generation system operation control technical field, this method first constructs and completes accuracy check to two area SFR system frequency response analytical model of hybrid network with new energy station;Through grid-connected point measuring device, real-time acquisition power grid frequency is calculated station real-time frequency deviation;With VSG virtual inertia, virtual damping and filter parameters, quantitatively solve network disturbance instantaneous autonomous active response power;With the margin ratio after correction generates dynamic allocation coefficient, splits station primary frequency modulation total power instruction and respectively issues to two types of units to execute regulation.The application fully releases network inertia damping support capacity of unit, activates network unit idle frequency modulation capacity;Support SFR model can accurately characterize system frequency dynamic whole process, provide theoretical support for the calculation and optimization of frequency modulation control strategy.

Description

Technical Field

[0001] This invention belongs to the field of operation and control technology of new energy power generation systems, and specifically relates to a primary frequency regulation control method for power plants that takes into account the autonomous response of grid-type equipment. Background Technology

[0002] Traditional grid-connected converter equipment is controlled by current source control logic and has weak active frequency support capability. By introducing grid-connected equipment with voltage source output characteristics to build grid-connected-grid hybrid new energy power plants, the underlying control loop of the grid-connected equipment can quickly output active power when grid frequency disturbances occur, forming an instantaneous autonomous frequency response, effectively improving the problem of frequency drop in the early stage of system disturbance.

[0003] Current power station-level primary frequency regulation control strategies generally treat on-site generating equipment as ideal power execution units, failing to quantify or comprehensively account for the autonomous response power spontaneously generated by grid-connected equipment during the entire frequency disturbance process. When frequency disturbances occur in the power grid, grid-connected equipment relies on the underlying control to instantaneously output autonomous response active power, consuming a large amount of the equipment's adjustable capacity margin. If the power station controller still adopts the conventional equal-sharing / fixed-proportion allocation strategy to issue the full amount of primary frequency regulation command, the autonomous response power will be superimposed on the power issued by the power station, directly causing the output power of the grid-connected equipment to quickly reach the upper and lower power limits.

[0004] However, the existing technology has the following shortcomings: First, grid-connected equipment enters the limiting range in advance and cannot fully execute the frequency regulation commands allocated by the power station; second, the remaining adjustable capacity margin of the grid-connected equipment in the power station is not fully utilized, and the frequency regulation potential is idle; third, the overall hybrid power station has insufficient response to the power shortage of the primary frequency regulation of the power grid, and the comprehensive frequency support capability of the power station is severely restricted, making it difficult to meet the frequency stability control requirements of high-proportion new energy power systems.

[0005] Therefore, in order to solve the technical problems of traditional control strategies not taking into account the instantaneous autonomous output of grid-connected equipment, the easy over-limit of equipment power, and the inability to fully release the frequency regulation potential of power stations, a new method is urgently needed to achieve efficient frequency support for disturbance transients in grid-connected hybrid new energy power stations. Summary of the Invention

[0006] The purpose of this invention is to provide a primary frequency regulation control method for power plants that takes into account the autonomous response of grid-connected equipment. This method solves the problem of easy amplitude limiting of grid-connected equipment in traditional schemes, fully releases the frequency regulation potential of both types of equipment, and provides theoretical support for response power calculation and frequency regulation strategy optimization. It effectively improves the integrity of the primary frequency regulation response and transient frequency support capability of grid-connected hybrid new energy power plants.

[0007] To achieve the above objectives, the present invention provides a primary frequency regulation control method for power stations that considers the autonomous response of network-type equipment, comprising the following steps: S1. Construct an analytical model of the frequency response of a two-region SFR system for a hybrid renewable energy power station, including VSG-connected units and PQ-connected units. Divide the region into two areas: Region 1 is the renewable energy power station and Region 2 is the external synchronous grid. Establish mathematical models for power station frequency dynamics, synchronous machine speed regulation dynamics, and tie-line interactive power. Verify the model accuracy through time-domain simulation. Input the system capacity, unit rated parameters, line impedance, and VSG underlying control parameters into the model. Output a standard model parameter set that can characterize the frequency dynamics under all operating conditions, and provide system reference parameters to the downstream frequency acquisition and calculation stage. S2. The grid operating frequency is collected in real time by the measuring device at the grid connection point of the substation. The measured frequency signal is transmitted to the frequency deviation calculation unit to calculate the real-time frequency deviation signal of the substation. The frequency deviation signal is then uploaded to the substation primary frequency regulation centralized controller in real time as input data for the downstream autonomous response power calculation link. S3. The station's primary frequency regulation centralized controller retrieves the pre-stored VSG virtual inertia, virtual damping, and low-pass filter time constant parameters. Combined with the real-time frequency deviation signal output in step S2, it uses frequency domain calculation logic with low-pass filter to quantify and solve the instantaneous autonomous active power response of the VSG network unit under the current frequency disturbance. The solved autonomous active power response is then output to the unit capacity margin correction stage. S4. Using the instantaneous autonomous active power response, rated power limit of the unit, and initial steady-state output before disturbance output from step S3 as input data, dynamically correct the effective remaining frequency regulation capacity margin of the two types of units; then, based on the corrected effective remaining frequency regulation capacity margin of the units, calculate the total primary frequency regulation power demand of the station in combination with the real-time frequency deviation obtained in step S2, generate dynamic frequency regulation allocation coefficients according to the margin ratio, split the total frequency regulation power using the allocation coefficients, generate independent primary frequency regulation power commands for the VSG network-connected units and the PQ network-connected units respectively, and send them to the corresponding units to perform active power regulation.

[0008] Preferably, in the two-region SFR model constructed in step S1, the equivalent virtual inertia and equivalent damping coefficient of the new energy power station are calculated using the following formula: ; ; In the formula, The virtual inertia constant of a single network-connected device; The virtual damping coefficient for a single network-connecting device; Rated capacity for network-type equipment; This is the system's baseline capacity; The equivalent virtual inertia of the station; This is the equivalent damping coefficient of the station; The active power response of VSG network-connected units and PQ network-connected units is dynamically equivalent to a first-order inertial element, expressed as: ; ; In the formula, This is the reference command for the controlled power of network-type equipment after dynamic limiting; In order to follow the controlled power reference command of the network-type equipment, the GFL equipment has no underlying autonomous frequency response power and no dynamic limiting constraint; The equivalent time constant of the active power response of network-type equipment; The equivalent time constant of the active power response of network-type equipment.

[0009] Preferably, step S3 includes two instantaneous autonomous active power response calculation models; Unfiltered ideal calculation model: ; In the formula, The autonomous frequency response power of network-type equipment; Frequency deviation in the station area; Engineering low-pass filter correction model: ; In the formula, The time constant of the first-order low-pass filter in the differentiation element; the low-pass filter is used to suppress the field noise interference generated by the differentiation operation of frequency measurement.

[0010] Preferably, the specific sub-processes of step S4, which dynamically corrects the effective remaining frequency regulation capacity margin of the unit and allocates frequency regulation commands, include: S401, The formula for calculating the effective remaining frequency regulation capacity margin of the two types of generating units is as follows: ; ; In the formula, This refers to the effective remaining adjustable capacity margin of network-type equipment; This is the maximum active power output limit for network-type equipment; The initial steady-state output of the network equipment before the frequency disturbance occurs; S402, Calculation formula for total primary frequency regulation power demand of the entire station: ; In the formula, This is the primary frequency regulation total power command for the power station; This refers to the primary frequency modulation droop gain coefficient at the field station level. S403, Formula for calculating the dynamic allocation coefficient of frequency regulation power of grid-connected units: ; In the formula, To assign weighting coefficients; S404, splitting to obtain two types of independent frequency regulation commands for the generating units: ; ; In the formula, To issue a primary frequency modulation power command to the network-type equipment; This is a primary frequency modulation power command issued to network-connected equipment.

[0011] Preferably, in step S1, the active power exchanged between the two area tie lines satisfies the following relationship: ; ; In the formula, Synchronization power factor for tie lines; , These are the voltage amplitudes at nodes in region 1 and region 2, respectively. It is the phase angle difference between the nodes in region 1 and region 2; The impedance of the connecting line; The active power exchanged by the tie line is determined by the real-time frequency deviation difference between area 1 and area 2, as well as the tie line synchronization power coefficient.

[0012] Therefore, the present invention employs the above-mentioned primary frequency regulation control method for power stations that considers the autonomous response of network-type equipment. Compared with the prior art, the technical solution of the present invention has the following beneficial effects: (1) This invention quantifies the instantaneous autonomous active power response of VSG network equipment under frequency disturbance in real time, dynamically corrects the actual available frequency regulation capacity margin of the equipment, solves the core defects of traditional control strategies that ignore the underlying spontaneous power generation and network equipment is prone to premature amplitude limit, and fully releases the inertia and damping instantaneous frequency support capability of network equipment. (2) The present invention adopts an adaptive frequency regulation command allocation mechanism based on real-time corrected capacity margin, automatically balances the frequency regulation output allocation ratio of grid-connected and grid-connected equipment, fully taps the idle frequency regulation potential of grid-connected converters in the field, and improves the overall primary frequency regulation response integrity of hybrid power stations. (3) The present invention constructs a two-region SFR frequency response analytical model adapted to the hybrid renewable energy power station, which can accurately characterize the virtual inertia, damping, tie line interaction power and equipment power dynamics of the power station, and provide reliable theoretical support for autonomous response power quantification calculation and frequency modulation strategy optimization. (4) Simulation verification shows that, compared with the traditional fixed allocation control strategy that does not consider autonomous response, the present invention can raise the lowest frequency point after system disturbance, improve the frequency drop depth of the system, improve the frequency support performance of the power station by about 5.45%, and significantly improve the transient frequency stability of the high proportion of new energy power system.

[0013] The technical solution of the present invention will be further described in detail below with reference to the accompanying drawings and embodiments. Attached Figure Description

[0014] Figure 1 This is a flowchart illustrating an embodiment of a primary frequency regulation control method for power stations that considers the autonomous response of network-type equipment according to the present invention; Figure 2 This is a grid connection architecture diagram of a new energy grid-connected hybrid power station, which is an embodiment of a power station primary frequency regulation control method for power stations that takes into account the autonomous response of grid-connected equipment according to the present invention. Figure 3 This is a schematic diagram of the frequency response model of a two-region interconnected new energy hybrid power station SFR system, which is an embodiment of the power station primary frequency regulation control method for considering the autonomous response of grid-type equipment according to the present invention. Figure 4 This is a comparison and verification curve of the accuracy between the SFR model and the detailed time-domain simulation model of an embodiment of the station primary frequency regulation control method considering the autonomous response of network-type equipment according to the present invention. Figure 4 In the figure, (a) represents the frequency dynamic curve of the external power grid area; Figure 4 (b) in the figure represents the regional frequency dynamic curve of the new energy power station; Figure 5 This is a dynamic frequency comparison curve of a new energy power station in an embodiment of a power station primary frequency regulation control method for considering the autonomous response of grid-type equipment according to the present invention; Figure 6 This is a comparison curve of the active power output of the grid-type equipment in an embodiment of the primary frequency regulation control method for power stations that takes into account the autonomous response of grid-type equipment according to the present invention. Figure 7 This is a comparison curve of the active power output of a network-type (VSG) device in an embodiment of the primary frequency regulation control method for a power station that takes into account the autonomous response of network-type devices according to the present invention. Detailed Implementation

[0015] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. All other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention. Unless otherwise defined, the technical or scientific terms used in the present invention should have the ordinary meaning understood by those skilled in the art.

[0016] Example 1 like Figures 1-3 As shown, this embodiment provides a primary frequency regulation control method for a power station that takes into account the autonomous response of network-type equipment. It should be understood that the specific parameters, models and protocols mentioned in this embodiment are only examples to help those skilled in the art understand the present invention, and are not intended to limit the present invention.

[0017] The present invention provides a primary frequency regulation control method for power stations that considers the autonomous response of network-type equipment, comprising the following steps: S1. Construct a grid-connected system topology for a hybrid renewable energy power plant, aggregating all power generation equipment in the plant into two equivalent units: a grid-connected equivalent unit using a fixed PQ control strategy and a grid-connected equivalent unit using a virtual synchronous machine (VSG) control strategy. The plant's centralized controller uses basic allocation logic based on the remaining available capacity margin of the equipment to allocate primary frequency regulation commands.

[0018] Based on the above grid topology, a frequency response (SFR) model of the two-region interconnected system is constructed. Region 1 is a hybrid renewable energy power station region connected to the grid, and Region 2 is an external synchronous power grid region. The two regions achieve active power exchange through a tie line. Relying on the detailed time-domain simulation model of the system, the accuracy of the SFR model is verified under the same frequency disturbance condition, and the accuracy of the model in representing the dynamic process of the system disturbance frequency is verified.

[0019] The frequency dynamic mathematical model for the region (Region 1) of the hybrid renewable energy power station network is as follows: The frequency deviation at the power station is jointly determined by the internal disturbance of the power station, the cross-connection power, the actual active power output of the equivalent units in the grid, and the actual active power output of the equivalent units in the grid. The frequency domain expression is as follows: ; In the formula, This refers to the system frequency deviation at the station side; The equivalent virtual inertia constant for new energy power stations; This is the equivalent damping coefficient of the station; For the Laplace operator; The actual active power output of the network-type equipment; To match the actual active power output of the grid-connected equipment; This refers to the active power disturbance within the power station. It exchanges active power for regional tie lines.

[0020] For hybrid renewable energy power plants with grid-connected systems, the inertia and damping of the non-synchronous generating units are entirely provided by the grid-connected VSG equipment. The formulas for calculating the equivalent virtual inertia and equivalent damping coefficient of the power plant are expressed as follows: ; ; In the formula, The virtual inertia constant of a single network-connected device; The virtual damping coefficient for a single network-connecting device; Rated capacity for network-type equipment; This is the system's baseline capacity.

[0021] The station controller collects the station frequency deviation in real time, calculates the total frequency modulation power command for the station by converting it to the primary frequency modulation droop gain, and then distributes it to each equivalent unit according to the allocation coefficient. After receiving the reference power command, the network-type and grid-following equipment are constrained by a dynamic limiting element. The dynamic characteristics of the power response are equivalent to a first-order inertial element, and the frequency domain expression is as follows: ; ; In the formula, This is the reference command for the controlled power of network-type equipment after dynamic limiting; The equivalent time constant of the active power response of network-type equipment; The equivalent time constant of the active power response of network-type equipment. The reference command for controlled power of network-connected equipment is used; the GFM equipment autonomously consumes adjustable capacity in real time, and the adjustable upper limit changes dynamically with disturbances, which is equivalent to producing a dynamic limiting effect.

[0022] Construct a frequency dynamic mathematical model for the external power grid region (Region 2), specifically as follows: The external power grid's regional frequency regulation resources are synchronous generator sets. The synchronous generator rotor motion equation and the governor system jointly determine the regional frequency dynamics. The power grid frequency deviation generates the prime mover's mechanical power regulation through the generator droop coefficient and power limiting circuit. The governor's mechanical power dynamics and the regional 2 frequency deviation model are expressed as follows: ; ; In the formula, The actual additional mechanical power generated by the speed controller; For droop control gain and the reference power after limiting; The work-to-weight ratio coefficient for the prime mover; The prime mover time constant; This refers to the system frequency deviation of the external power grid; It is the equivalent inertia constant of the external power grid; This represents the disturbance to the external power grid.

[0023] Construct a regional link interaction power model, specifically as follows: The active power exchange between the tie line in Region 1 and Region 2 is equivalent to a pure integral element. The magnitude of the exchange power is determined by the frequency deviation difference between the two regions. The model expression is: ; ; In the formula, Synchronization power factor for tie lines; , These are the voltage amplitudes at nodes in region 1 and region 2, respectively. It is the phase angle difference between the nodes in region 1 and region 2; Let be the impedance of the tie line; assume that the node voltage remains constant under small disturbance conditions.

[0024] S2. Configure a synchronous phasor measurement device at the grid connection point of the power station to collect the measured values ​​of the three-phase voltage and frequency at the grid connection point in real time; calculate the difference between the measured frequency and the rated frequency of the power grid to obtain the real-time frequency deviation of the power station area. The frequency deviation signal is uploaded to the site coordination controller in real time as an input for subsequent calculations. S3. The grid-connected equipment adopts the VSG active-frequency control architecture. The active loop includes a virtual inertia differential element and a virtual damping proportional element. When the grid frequency is disturbed, the grid-connected equipment relies on the local grid connection point frequency detection signal to spontaneously output the active power increment. This active power increment is defined as the autonomous frequency response power.

[0025] Unfiltered ideal calculation model: ; In the formula, The autonomous frequency response power of network-type equipment; This refers to the frequency deviation in the field station area.

[0026] The engineering low-pass filter correction model is constructed as follows: Pure differential terms are prone to amplifying noise in field measurements. The engineering controller is equipped with a first-order low-pass filter to smooth the differential terms. The corrected autonomous response power calculation model is expressed as: ; In the formula, is the time constant of the first-order low-pass filter in the differentiating element.

[0027] S4. Dynamically correct the remaining adjustable capacity margin of grid-type equipment, and based on the corrected single-unit capacity margin ratio, redistribute the total primary frequency regulation command at the station level and issue it to each power generation equipment in the station. This step includes two sub-steps: dynamic adjustment of capacity margin and dynamic allocation of frequency modulation commands. Specifically: S401. Real-time correction of the effective remaining adjustable capacity margin of each unit. The station coordination controller collects the rated capacity of the grid-connecting and grid-following equipment and the initial steady-state output before the disturbance. Combined with the autonomous response power of the grid-connecting equipment obtained in step 3, it calculates the effective power margin that can be used to respond to the station's frequency modulation command at the current moment for the two types of equipment. The two types of equipment are the VSG grid-connecting units (GFM equipment) and the PQ grid-following units (GFL equipment) inside the station.

[0028] The formula for calculating the effective remaining capacity margin of network-type equipment is expressed as follows: ; In the formula, This refers to the effective remaining adjustable capacity margin of network-type equipment; This is the maximum active power output limit for network-type equipment; The initial steady-state output of the network equipment before the frequency disturbance occurs; The formula for calculating the effective remaining capacity margin of network-type equipment is as follows: Network-connected devices lack underlying instantaneous autonomous frequency response characteristics, and their capacity margin is not affected by self-generated power consumption. The expression is: ; In the formula, The initial steady-state output of the unit before the disturbance; S402. Based on the corrected capacity margin, update the frequency regulation command allocation ratio and generate independent frequency regulation reference commands for each unit.

[0029] The solution to the total primary frequency regulation power requirement of the power station is as follows: Based on the real-time frequency deviation, the station controller calculates the total frequency modulation power required for the entire station to increase or decrease transmission capacity using the station's frequency modulation droop coefficient. ; In the formula, This is the primary frequency regulation total power command for the power station; This refers to the primary frequency modulation droop gain coefficient at the field station level. The calculation of the frequency modulation power allocation coefficient for network-type equipment is as follows: The allocation weight coefficients are updated in real time using the sum of the real-time effective remaining capacity margins of the two types of equipment as the denominator and the margin of the network equipment as the numerator. ; In the formula, To assign weighting coefficients.

[0030] The sub-equipment issues a frequency modulation reference power command, specifically as follows: Based on the allocation coefficient, the total frequency regulation command for the entire station is split into separate primary frequency regulation control commands for network-type and follow-network-type equipment: ; ; In the formula, To issue a primary frequency modulation power command to the network-type equipment; This is a primary frequency modulation power command issued to network-connected equipment.

[0031] This allocation logic has adaptive adjustment characteristics: when the autonomous response power of network equipment under frequency disturbances significantly occupies its own capacity margin, the allocation coefficient... Automatic reduction shifts the frequency regulation power demand towards grid-connected equipment with sufficient remaining margin; this ensures that the overall frequency regulation output of the station fully compensates for the system power deficit, while also reserving capacity space for autonomous response of grid-connected equipment, thus fundamentally avoiding power limiting issues caused by the superposition of autonomous output and station commands.

[0032] A simulation system for interconnection between two regions was built. Region 1 is a hybrid renewable energy power station with a grid connection, and Region 2 is an external power grid with synchronous generator units. The rated installed capacity of both regions is 1000MW. The power station in Region 1 is equipped with one VSG grid-connected device with a rated capacity of 400MW and one fixed PQ grid-connected device with a rated capacity of 600MW. The simulation condition is set to cause a 500MW active power deficit disturbance in the tie line, which triggers the primary frequency regulation action of the power station. The steady-state parameters and disturbance conditions of the system are shown in Table 1.

[0033] Table 1 Initial operating parameters and frequency disturbance conditions of the two-region hybrid system

[0034] like Figures 4-7 As shown, when using the traditional control strategy that does not take into account the autonomous response of the network equipment, the system frequency drops to a minimum of 49.6973Hz after disturbance; after adopting the dynamic margin correction and adaptive allocation control method of the present invention, the minimum system frequency is raised to 49.7138Hz, the frequency drop depth is reduced, the station frequency support effect is improved by 5.45%, and the transient frequency stability performance is significantly optimized.

[0035] This invention adaptively increases the weight of frequency modulation commands allocated to network-connected devices, fully utilizes the idle capacity margin of network-connected devices, and after disturbances, the active power generated by network-connected devices is significantly higher than that of traditional control schemes, thus sharing the frequency modulation pressure of network-connected devices.

[0036] Under traditional control strategies, the power of the autonomous response of the network equipment at the bottom layer is superimposed with the power of the frequency modulation command issued by the power station. The output power quickly reaches the 400MW power limit, and the equipment enters the limiting range and cannot continuously provide frequency modulation power. This invention dynamically deducts the capacity margin occupied by the autonomous response and reduces the frequency modulation allocation ratio of the network equipment. The output of the equipment never reaches the power limit and continuously participates in frequency support throughout the process.

[0037] Under the two control strategies, the total steady-state frequency regulation output of the power station is basically the same; however, in the initial transient stage of the disturbance, the present invention can avoid the short-term power gap caused by the limiting of the grid equipment, and the overall active power output of the power station is more continuous, effectively suppressing the rapid frequency drop.

[0038] Therefore, the present invention adopts the above-mentioned primary frequency regulation control method for power plants that takes into account the autonomous response of grid-connected equipment. This method solves the problem of easy amplitude limiting of grid-connected equipment in traditional schemes, fully releases the frequency regulation potential of both types of equipment, and provides theoretical support for response power calculation and frequency regulation strategy optimization. It effectively improves the integrity of primary frequency regulation response and transient frequency support capability of grid-connected hybrid new energy power plants.

[0039] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0040] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention and not to limit them. Although the present invention has been described in detail with reference to preferred embodiments, those skilled in the art should understand that modifications or equivalent substitutions can still be made to the technical solutions of the present invention, and these modifications or equivalent substitutions cannot cause the modified technical solutions to deviate from the spirit and scope of the technical solutions of the present invention.

Claims

1. A primary frequency regulation control method for power stations considering the autonomous response of network-type equipment, characterized in that, Includes the following steps: S1. Construct an analytical model of the frequency response of a two-region SFR system for a hybrid renewable energy power station, including VSG-connected units and PQ-connected units. Divide the region into two areas: Region 1 is the renewable energy power station and Region 2 is the external synchronous grid. Establish mathematical models for power station frequency dynamics, synchronous machine speed regulation dynamics, and tie-line interactive power. Verify the model accuracy through time-domain simulation. Input the system capacity, unit rated parameters, line impedance, and VSG underlying control parameters into the model. Output a standard model parameter set that can characterize the frequency dynamics under all operating conditions, and provide system reference parameters to the downstream frequency acquisition and calculation stage. S2. The grid operating frequency is collected in real time by the measuring device at the grid connection point of the substation. The measured frequency signal is transmitted to the frequency deviation calculation unit to calculate the real-time frequency deviation signal of the substation. The frequency deviation signal is then uploaded to the substation primary frequency regulation centralized controller in real time as input data for the downstream autonomous response power calculation link. S3. The station's primary frequency regulation centralized controller retrieves the pre-stored VSG virtual inertia, virtual damping, and low-pass filter time constant parameters. Combined with the real-time frequency deviation signal output in step S2, it uses frequency domain calculation logic with low-pass filter to quantify and solve the instantaneous autonomous active power response of the VSG network unit under the current frequency disturbance. The solved autonomous active power response is then output to the unit capacity margin correction stage. S4. Using the instantaneous autonomous active power response, rated power limit of the unit, and initial steady-state output before disturbance output from step S3 as input data, dynamically correct the effective remaining frequency regulation capacity margin of the two types of units; then, based on the corrected effective remaining frequency regulation capacity margin of the units, calculate the total primary frequency regulation power demand of the station in combination with the real-time frequency deviation obtained in step S2, generate dynamic frequency regulation allocation coefficients according to the margin ratio, split the total frequency regulation power using the allocation coefficients, generate independent primary frequency regulation power commands for the VSG network-connected units and the PQ network-connected units respectively, and send them to the corresponding units to perform active power regulation.

2. The primary frequency regulation control method for a power station considering the autonomous response of network-type equipment according to claim 1, characterized in that, In the two-region SFR model constructed in step S1, the equivalent virtual inertia and equivalent damping coefficient of the new energy power station are calculated using the following formula: ； ； In the formula, The virtual inertia constant of a single network-connecting device; The virtual damping coefficient for a single network-connecting device; Rated capacity for network-type equipment; This is the system's baseline capacity; The equivalent virtual inertia of the station; This is the equivalent damping coefficient of the station; The active power response dynamic equivalent of the first-order inertial element for VSG network-connected units and PQ network-connected units is expressed as follows: ； ； In the formula, This is the reference command for the controlled power of network-type equipment after dynamic limiting; For reference commands on controlled power of network-connected devices; The equivalent time constant of the active power response of network-type equipment; The equivalent time constant of the active power response of network-type equipment.

3. The primary frequency regulation control method for a power station considering the autonomous response of network-type equipment according to claim 2, characterized in that, Step S3 includes two instantaneous autonomous active power response calculation models; Unfiltered ideal calculation model: ； In the formula, The autonomous frequency response power of network-type equipment; Frequency deviation in the field area; Engineering low-pass filter correction model: ； In the formula, The time constant of the first-order low-pass filter in the differentiation element; the low-pass filter is used to suppress the field noise interference generated by the differentiation operation of frequency measurement.

4. The primary frequency regulation control method for a power station considering the autonomous response of network-type equipment according to claim 3, characterized in that, Step S4, dynamically correcting the unit's effective remaining frequency regulation capacity margin and allocating frequency regulation commands, includes the following sub-processes: S401. The formula for calculating the effective remaining frequency regulation capacity margin of grid-connected and grid-linked generating units is as follows: ； ； In the formula, This refers to the effective remaining adjustable capacity margin of network-type equipment; This is the maximum active power output limit for network-type equipment; The initial steady-state output of the network equipment before the frequency disturbance occurs; S402, Calculation formula for total primary frequency regulation power demand of the entire station: ； In the formula, This is the primary frequency regulation total power command for the power station; This refers to the primary frequency modulation droop gain coefficient at the field station level. S403, Formula for calculating the dynamic allocation coefficient of frequency regulation power of grid-connected units: ； In the formula, To assign weighting coefficients; S404, splitting to obtain independent frequency regulation commands for grid-connected and grid-linked generating units: ； ； In the formula, To issue a primary frequency modulation power command to the network-type equipment; This is a primary frequency modulation power command issued to network-connected equipment.

5. The primary frequency regulation control method for a substation considering the autonomous response of network-type equipment according to claim 1, characterized in that, In step S1, the active power exchanged between the two area tie lines satisfies the following relationship: ； ； In the formula, Synchronization power factor for tie lines; , These are the voltage amplitudes at nodes in region 1 and region 2, respectively. It is the phase angle difference between the nodes in region 1 and region 2; The impedance of the connecting line; The active power exchanged by the tie line is determined by the real-time frequency deviation difference between Region 1 and Region 2 and the tie line synchronization power coefficient.

6. A computer device, characterized in that, include: A processor configured to be coupled to memory, read and execute instructions and / or program code in the memory to perform the method as described in any one of claims 1-5.

7. A computer-readable medium, characterized in that, The computer-readable medium stores computer program code that, when executed on a computer, causes the computer to perform the method as described in any one of claims 1-5.

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