Power grid unified frequency modulation control test method, device, equipment and storage medium

Abstract

The invention discloses a power grid unified frequency modulation control test method, device and equipment and a storage medium. The method comprises the steps of simulating a power system through a real-time digital simulator (RTDS) to determine a power system operation simulation result; according to the system frequency deviation and the system frequency deviation, determining an area control deviation; determining the total adjustment power of the region according to the region control deviation and the integral value of the region control deviation, and determining the adjustable power quantity of the new energy according to the new energy power generation prediction and the actual operation state of the new energy unit; according to the total adjusting power of the area and the adjustable power amount of the new energy, the adjusting power amount needed by the conventional unit is determined; according to the method, the regulation power borne by the AGC of each conventional unit is determined according to the regulation power amount required by the conventional unit, the operation cost of the unit is optimized while the stability of the power grid is ensured, and meanwhile, power grid faults caused by frequency fluctuation can be generally reduced and the reliability of the power grid can be improved through accurate frequency modulation control.

Description

Technical Field

[0001] The present application relates to the technical field of power system stability control, and in particular to a test method, device, equipment and storage medium for unified frequency modulation control of a power grid. Background Art

[0002] Before unified frequency control, each dispatching agency AGC independently calculated the ACE value based on the offline adjusted parameters and sent it to the power plants under its jurisdiction for execution. When the unified frequency control area of ​​the power grid is built, the general dispatching should uniformly calculate the regulation demand of the control area, and fairly distribute the control ACE of each central dispatching AGC according to the market clearing results. The AGCs of various dispatching agencies have close interactive communication. It can be seen that in the unified frequency control environment, it is urgent to establish a joint real-time test system for network and provincial AGCs to study and verify the coordination between the AGCs of network and provincial dispatching agencies, provide technical support for the testing and optimization of AGC strategy parameters, and ensure the safe and economic operation of the power spot market and the power grid.

[0003] However, the previous unified frequency control of the power grid did not take into account the regulating role of new energy sources such as wind power and photovoltaics. With the continuous increase in the penetration rate of wind and solar new energy in the power grid, the traditional unified frequency control of the power grid can hardly meet the frequency regulation requirements of the new power system. Summary of the invention

[0004] Based on this, it is necessary to propose a power grid unified frequency regulation control test method, device, equipment and storage medium to address the above problems.

[0005] The present application provides a method for testing unified frequency regulation control of a power grid, the method comprising:

[0006] The power system is simulated by a real-time digital simulator (RTDS) to determine the power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set;

[0007] determining a system frequency deviation based on the system frequency;

[0008] determining a regional control deviation based on the system frequency deviation and the system frequency deviation;

[0009] determining an integral value of a regional control deviation according to the regional control deviation;

[0010] Determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, wherein the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the renewable energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply;

[0011] Determine the adjustable power of new energy based on the new energy power generation forecast and the actual operating status of the new energy units;

[0012] Determine the amount of regulated power required by the conventional units according to the total regulated power of the area and the amount of regulated power of the new energy;

[0013] Determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0014] Forwarding the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0015] Each AGC sends the corresponding unit control information to each corresponding generator set simulated in RTDS.

[0016] In some embodiments, after each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS, the method also includes: each generator set in the RTDS adjusts the power generation output in response to the unit control information to obtain a new power system operation simulation result; re-obtaining the corresponding unit control information of each AGC based on the new power system operation simulation result, and each generator set in the RTDS adjusts the power generation output in response to the unit control information to obtain a new power system operation simulation result, until the obtained system frequency is less than the frequency regulation dead zone.

[0017] In some implementations, determining the system frequency deviation according to the system frequency f specifically includes determining the system frequency deviation Δf according to Δf=f-f0, wherein f0 is the system rated frequency, and f is the system frequency.

[0018] In some implementations, determining the regional control deviation according to the system frequency deviation and the system frequency deviation specifically includes: determining the regional control deviation ACE according to ACE=B*Δf, where B is a frequency deviation coefficient.

[0019] In some implementations, determining the integral value of the regional control deviation according to the regional control deviation specifically includes:

[0020] according to Determine the integral value ACEINT of the area control deviation.

[0021] In some implementations, determining the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation specifically includes: R =[(-G Pn )*ACE+(-G In )*ACEINT]+[(-G Pr )*ACE+(-GIr )*ACEINT]=P P +P I Determine the total regulation power P of the area R , where G Pn and G In are the proportional gain coefficient and integral gain coefficient of renewable energy generation, G Pr and G Ir are the proportional gain coefficient and integral gain coefficient of the conventional power supply, P P and P I They are the proportional component and the integral component of the adjusted power respectively.

[0022] In some embodiments, determining the regulating power borne by the AGC of each conventional unit according to the regulating power required by the conventional unit specifically includes: Determine the regulation power P borne by the i-th AGC ri , where α i is the economic allocation coefficient of the i-th PLC, which is inversely proportional to the unit's consumption increment rate and is provided by the online economic dispatch program; β i is the proportional distribution coefficient; P ri is the regulation power allocated to the i-th PLC; n is the total number of PLCs that bear the regulation power under the current situation; P r The amount of regulated power required for conventional units.

[0023] The present application also provides a power grid unified frequency regulation control test device, the device comprising:

[0024] A simulation module, used to simulate the power system through a real-time digital simulator (RTDS) to determine the power system operation simulation results; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation results include system frequency and output of each generator set;

[0025] A deviation calculation module, used to determine the system frequency deviation according to the system frequency; also used to determine the regional control deviation according to the system frequency deviation and the system frequency deviation; also used to determine the integral value of the regional control deviation according to the regional control deviation; also used to determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, the total regulated power of the region including the proportional gain coefficient and integral gain coefficient of the new energy power generation and the proportional gain coefficient and integral component of the regulated power determined by the integral gain coefficient of the conventional power supply; also used to determine the amount of power that can be regulated by the new energy according to the prediction of new energy power generation and the actual operating state of the new energy unit; also used to determine the amount of regulated power required by the conventional unit according to the total regulated power of the region and the amount of power that can be regulated by the new energy; and also used to determine the regulated power undertaken by the AGC of each conventional unit according to the amount of regulated power required by the conventional unit;

[0026] The control module is used to forward the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity; and is also used for each AGC to send the corresponding unit control information to the corresponding generator sets simulated in RTDS.

[0027] The embodiment of the present application further provides a computer device, including a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the following steps:

[0028] The power system is simulated by a real-time digital simulator (RTDS) to determine the power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set;

[0029] determining a system frequency deviation based on the system frequency;

[0030] determining a regional control deviation based on the system frequency deviation and the system frequency deviation;

[0031] determining an integral value of a regional control deviation according to the regional control deviation;

[0032] Determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, wherein the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the renewable energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply;

[0033] Determine the adjustable power of new energy based on the new energy power generation forecast and the actual operating status of the new energy units;

[0034] Determine the amount of regulated power required by the conventional units according to the total regulated power of the area and the amount of regulated power of the new energy;

[0035] Determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0036] Forwarding the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0037] Each AGC sends the corresponding unit control information to each corresponding generator set simulated in RTDS.

[0038] The embodiment of the present application further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the processor executes the following steps:

[0039] The power system is simulated by a real-time digital simulator (RTDS) to determine the power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set;

[0040] determining a system frequency deviation based on the system frequency;

[0041] determining a regional control deviation based on the system frequency deviation and the system frequency deviation;

[0042] determining an integral value of a regional control deviation according to the regional control deviation;

[0043] Determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, wherein the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the renewable energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply;

[0044] Determine the adjustable power of new energy based on the new energy power generation forecast and the actual operating status of the new energy units;

[0045] Determine the amount of regulated power required by the conventional units according to the total regulated power of the area and the amount of regulated power of the new energy;

[0046] Determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0047] Forwarding the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0048] Each AGC sends the corresponding unit control information to each corresponding generator set simulated in RTDS.

[0049] The embodiments of the present application have the following beneficial effects:

[0050] The present invention simulates the power system through a real-time digital simulator (RTDS), and can accurately obtain the operation simulation results of the power system, including the system frequency and the output of each generator set, providing an accurate data basis for subsequent frequency regulation. The prediction of new energy power generation and the actual operation status of the new energy unit are taken into account, so that the adjustable power amount of the new energy can be determined, which helps to make full use of the regulation capacity of the new energy unit. By determining the regional control deviation according to the system frequency deviation, and determining the total regulation power of the region according to the regional control deviation and its integral value, it is possible to achieve dynamic regulation of the grid frequency, which helps to quickly restore the system frequency to the vicinity of the rated value when the grid load changes, and ensure the stable operation of the grid; the regulation power borne by each conventional unit AGC (automatic generation control) is determined according to the economic allocation coefficient of the conventional unit, which helps to optimize the operating cost of the unit while ensuring the stability of the grid. At the same time, through precise frequency modulation control, it is possible to reduce the grid failure caused by frequency fluctuations and improve the reliability of the grid. BRIEF DESCRIPTION OF THE DRAWINGS

[0051] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative work.

[0052] in:

[0053] Figure 1 A schematic diagram of a flow chart of a unified frequency regulation control test method for a power grid in one embodiment;

[0054] Figure 2 A diagram of a hierarchical control mode of network optimization in an embodiment;

[0055] Figure 3 A functional architecture diagram of unified frequency modulation in one embodiment;

[0056] Figure 4 Another schematic diagram of a flow chart of a unified frequency regulation control test method for a power grid in one embodiment;

[0057] Figure 5 A structural diagram of a unified frequency modulation control test device for a power grid in one embodiment;

[0058] Figure 6is a schematic diagram of the structure of a computer device in one embodiment;

[0059] Figure 7 FIG. 4 is a schematic diagram of the structure of a computer-readable storage medium in one embodiment. DETAILED DESCRIPTION

[0060] The following will be combined with the drawings in the embodiments of the present application to clearly and completely describe the technical solutions in the embodiments of the present application. Obviously, the described embodiments are only part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0061] At present, several major power grids in my country adopt the "unified dispatching, hierarchical management" mode. The grid dispatching is the commander and responsible person for the peak and frequency regulation of the system. Generally speaking, the direct dispatching power plants of the grid dispatching are major large power plants distributed in various provinces, with good frequency regulation capabilities, and there is generally no load area in the grid dispatching control area. Based on this feature, combined with the performance of various control strategies discussed above, we propose a hierarchical control strategy for the grid dispatching FFC and provincial dispatching TBC mode, and establish the AGC control model of each provincial dispatching in the grid dispatching AGC, so that the grid dispatching AGC can understand the control capabilities of each provincial dispatching AGC, coordinate the coordination of the AGC control strategies between the grid and provincial dispatching, and maximize the advantages of the grid and provincial dispatching in controlling the power grid frequency.

[0062] Since the direct dispatch power plants of the grid dispatch are distributed in various provinces, the outgoing lines of these power plants should be used as the generalized connection lines between the grid dispatch and the provincial dispatch. Figure 2 As shown, Figure 2 The following is a hierarchical control mode diagram of the grid and provincial dispatch in an embodiment. The entire system is divided into four operating areas. The grid dispatch adopts the FFC (constant frequency control) mode, and each provincial dispatch adopts the TBC mode. In essence, the TBC mode reflects that each area is only responsible for adjusting the load changes within the area, taking into account the interests of each control area, and embodies the principle of fair and just frequency regulation. In terms of theoretical effect, it optimizes the power-frequency dynamic characteristics of the entire network and is more suitable for the existing management system. In addition, the grid dispatch operation area generally has main hydropower plants with strong frequency regulation capabilities. This solution can give full play to the frequency regulation capabilities of these power plants.

[0063] However, in the independent frequency control mode, when the power load increases in the control area of ​​Province A, the system frequency decreases, and the AGC power plants in the network control area and the AGC power plants in the A province control area increase their output at the same time, so that the system frequency returns to the specified range; thereafter, the ACE of the A province control area is still not zero, and its AGC power plants continue to increase their output, causing the frequency to rise, thereby reducing the output of the AGC power plants in the network control area until the original output level is restored. This process causes the fluctuation of the system frequency and the cascade of the external exchange power of Province A, and its advantages and disadvantages should be discussed in the following two situations.

[0064] (1) When the regulation area in Province A has sufficient regulation capacity and the system frequency does not change much, the regulation of the AGC units in the network regulation area is unnecessary and harmful.

[0065] (2) When the regulation capacity of the regulation area in Province A is insufficient, or the regulation speed is not fast enough, and the system frequency changes greatly, regulation of the AGC units in the network regulation area is necessary.

[0066] Similarly, when the power load changes outside the control area of ​​Province A, since the frequency component and the exchange power component in ACE cancel each other out, ACE is zero, and the AGC in the control area of ​​Province A does not participate in the regulation, which is reasonable. However, in an emergency, the influence of the exchange power should be temporarily reduced or even ignored to help the system restore the frequency.

[0067] In actual operation, each control area cannot strictly guarantee the simultaneity of frequency and inter-provincial exchange power data sampling. This will inevitably cause AGC to overshoot or undershoot to a certain extent, prolong the system frequency recovery process, increase the wear of AGC units, and also bring difficulties to the network adjustment assessment of the ACE pass rate of each province. At the same time, under the independent frequency control mode, the units in the FFC control area have priority in frequency regulation, and other control areas participate in frequency regulation through interconnection line power regulation. This sequential adjustment mode is not suitable for the frequency regulation market environment.

[0068] The Southern Regional Frequency Regulation System is a market jointly participated by multiple dispatching agencies such as the Southern Grid General Dispatching, Guangdong Central Dispatching, and Guangzhou Central Dispatching. The generators in the market are controlled by the AGCs of the grid dispatching and multiple provincial dispatching agencies. These AGCs currently have their own control strategies and control parameters, and each calculates the ACE and the regulation requirements of their respective regions, and controls the units under their respective jurisdiction. However, the Southern Regional Frequency Regulation Ancillary Service Market requires these AGCs to be able to jointly complete the frequency regulation tasks of the power grid according to the clearing results of the frequency regulation market, and the generators regulated by different AGCs can fairly participate in the market for frequency regulation.

[0069] In order to coordinate the AGCs of multiple dispatching agencies and meet the operation needs of the frequency regulation auxiliary service market in the southern region, the following coordinated control scheme is adopted:

[0070] The general dispatching department unifies the relevant parameters such as the threshold of the AGC regulation area, the frequency response coefficient (B), the gain coefficient (Kp, Ki) of each dispatching agency. Each dispatching AGC has two specific modes: coordinated control and independent control. Under normal circumstances, each AGC is put into coordinated control mode. In the event of AGC abnormality or power grid accident, it can return to independent control mode. AGC has two sets of fixed values ​​to adapt to the control mode switching. The fixed values ​​that need to be distinguished include the proportional gain coefficient (Kp) and frequency response coefficient (B) of different regulation areas.

[0071] Each central regulator can determine the regulation area of ​​the AGC according to the grid frequency and no longer send the original ACE. Each central regulator AGC sends the unregulated quantity P in real time according to the real-time execution of the frequency regulation power plant. 未调节,i The total dispatch calculates the control ACE of a certain dispatch i =β i *(ACE 原始 -∑P 未调节,i ).

[0072] Each intermediate AGC tracks the control ACE issued by the master according to the allocation coefficient i , considering the part of the controlled power plant being regulated, calculate the total regional regulation (ARR) i =K p ×(Control ACE i +P 未调节,i )+K i ×∫(Control ACE i +P 未调节,i )dt-P 未调节,i ).

[0073] AGC should allocate the regulation power demand to the winning power generation units according to certain principles. Different allocation principles can be considered for different regulation areas, such as allocation according to frequency regulation capacity, regulation rate, etc.

[0074] The AGC should have the function of automatic module switching, switching the winning power generation unit to the bandwidth frequency modulation mode, where the bandwidth is the winning capacity. The unsuccessful power generation unit is switched to the non-frequency modulation mode. When the PLC exits abnormally and is re-entered, it can switch to the corresponding default mode according to the winning situation.

[0075] AGC should have the function of preventing frequency fluctuations caused by the overall switching of the power generation unit control mode. For the power generation unit switched to the non-frequency regulation mode, it should return to the planned value in small steps (while satisfying ACE in the normal area or dead zone). This function can be set to be enabled or not.

[0076] AGC should be able to calculate the frequency regulation performance and frequency regulation mileage of power generation units by hour. The calculation of frequency regulation mileage, frequency regulation duration and frequency regulation performance should only consider power generation units in frequency regulation mode.

[0077] AGC should have the function of preventing the deterioration of stable sections from exceeding the limit, and it is prohibited to send commands for deterioration sections to lower-level AGCs or power plants.

[0078] During the FFC phase in the southern region, the central dispatching system should have the function of sending the AGC operating status in real time and the AGC refresh time. The AGC of the Southern Power Grid's main dispatching system should be connected to the operating status of the central dispatching system AGC and automatically adjust the allocation factor according to the operating status of the central dispatching system AGC. The main dispatching system sends the operating status of the main dispatching system AGC to each central dispatching system in real time. If the central dispatching system AGC receives an abnormal signal from the main dispatching system AGC, it should be able to suspend control and issue an alarm, and the dispatcher should manually switch to local independent control. The abnormal status signal can be generated by the AGC or manually set by the dispatcher.

[0079] The functional architecture of unified frequency modulation control is as follows Figure 3 As shown, Figure 3 This is a functional architecture diagram of unified frequency modulation in an embodiment; in the unified frequency modulation control mode, the network modulation collects the exchange power between provinces and uniformly calculates the ACE of each control area, so that the frequency modulation resources of each province and region can participate in frequency modulation equally and respond to instructions at the same time, reducing the power exchange process and achieving the purpose of fair control.

[0080] As can be seen from the above, before unified frequency control, each dispatching agency AGC independently calculated the ACE value based on the offline adjusted parameters and sent it to the power plants under its jurisdiction for execution. When the unified frequency control area of ​​the power grid is built, the general dispatching should uniformly calculate the regulation demand of the control area, and fairly allocate the control ACE of each central dispatching AGC according to the market clearing results. The AGCs of various dispatching agencies have close interactive communication. It can be seen that in the unified frequency control environment, it is urgent to establish a joint real-time test system for network and provincial AGCs to study and verify the coordination between the AGCs of network and provincial dispatching agencies, provide technical support for the testing and optimization of AGC strategy parameters, and ensure the safe and economic operation of the power spot market and the power grid.

[0081] However, the previous unified frequency regulation control of power grids did not take into account the regulation effect of wind power, photovoltaic and other renewable energy sources. With the continuous increase in the penetration rate of wind and solar renewable energy in the power grid, the traditional unified frequency regulation control of power grids is difficult to meet the frequency regulation requirements of new power systems. Therefore, this patent proposes a test method for unified frequency regulation control of power grids.

[0082] like Figure 1 As shown, in one embodiment, a method for testing unified frequency regulation control of a power grid is provided, the method comprising:

[0083] Step 101: simulating a power system through a real-time digital simulator (RTDS) to determine a power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes a system frequency and an output of each generator set;

[0084] Step 102: determining a system frequency deviation according to the system frequency;

[0085] Specifically, the system frequency deviation Δf is determined according to Δf=f-f0, wherein f0 is the system rated frequency, and f is the system frequency.

[0086] Exemplarily, the system rated frequency f0 is 50 Hz.

[0087] Step 103: determining a regional control deviation according to the system frequency deviation and the system frequency deviation;

[0088] Specifically, the system frequency deviation Δf and the output of each generator set are sent to the unified frequency control application module UFC (Unified Frequency Control) in the power grid operation control system OCS (Operation and Control System) to obtain ACE (Area Control Error).

[0089] The regional control deviation ACE is determined according to ACE=B*Δf, where B is the frequency deviation coefficient.

[0090] Exemplarily, B is the frequency deviation coefficient (MW / HZ), which is generally 1% to 1.5% of the annual expected maximum load of the power grid system.

[0091] Step 104: determining an integral value of the regional control deviation according to the regional control deviation;

[0092] Specifically, the control performed by ACE is proportional control, and its disadvantage is that it cannot take into account the time factor. In order to consider the influence of time on control, it is also necessary to implement integral control, that is, to use the integral value ACEINT of ACE to time to implement the integral control of AGC. Determine the integral value ACEINT of the area control deviation.

[0093] Written in discrete form:

[0094] ACEINT K+1 =ACEINT K +ACE K+1 *T AGC Where, T AGC is the execution cycle of AGC.

[0095] Step 105: determining the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation;

[0096] Specifically, the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the new energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply;

[0097] UFC sends ACE and ACEINT to the network-level SCADA (Supervisory Control And Data Acquisition) application.

[0098] According to P R =[(-G Pn )*ACE+(-G In )*ACEINT]+[(-G Pr )*ACE+(-G Ir )*ACEINT]=P P +P I Determine the total regulation power P of the area R , where G Pn and G In are the proportional gain coefficient and integral gain coefficient of renewable energy generation, G Pr and G Ir are the proportional gain coefficient and integral gain coefficient of the conventional power supply, P P and P I They are the proportional component and the integral component of the adjusted power respectively.

[0099] Step 106: Determine the adjustable power of the new energy according to the new energy power generation forecast and the actual operation status of the new energy unit;

[0100] Specifically, the power amount P that can be adjusted by the new energy N =P W +P P +P S (where P W , P P , P S are the adjustable power of wind power, photovoltaic power and energy storage respectively).

[0101] Step 107: determining the regulated power required by the conventional units according to the total regulated power of the area and the regulated power of the new energy;

[0102] Specifically, according to P r =P R -P N Determine the regulating power P required by conventional units r .

[0104] Step 108: determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0105] Specifically, according to Determine the regulation power P borne by the i-th AGC ri , where α i is the economic allocation coefficient of the i-th PLC, which is inversely proportional to the unit's consumption increment rate and is provided by the online economic dispatch program; β i is the proportional distribution coefficient; P ri is the regulation power allocated to the i-th PLC; n is the total number of PLCs that bear the regulation power under the current situation; P r The amount of regulated power required for conventional units.

[0106] Step 109: forwarding the regulated power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0107] Step 110: Each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS.

[0108] like Figure 4 As shown, in one embodiment, a method for testing unified frequency regulation control of a power grid is provided, the method comprising:

[0109] Step 201: simulating a power system through a real-time digital simulator (RTDS) to determine a power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set;

[0110] Step 202: determining a system frequency deviation according to the system frequency;

[0111] Specifically, the system frequency deviation Δf is determined according to Δf=f-f0, wherein f0 is the system rated frequency, and f is the system frequency.

[0112] For example, the system rated frequency f0 is 50 Hz

[0113] Step 203: determining a regional control deviation according to the system frequency deviation and the system frequency deviation;

[0114] Specifically, the system frequency deviation Δf and the output of each generator set are sent to the unified frequency control application module UFC (Unified Frequency Control) in the power grid operation control system OCS (Operation and Control System). The unified frequency control module UFC obtains ACE (Area Control Error)

[0115] The regional control deviation ACE is determined according to ACE=B*Δf, where B is the frequency deviation coefficient.

[0116] Exemplarily, B is the frequency deviation coefficient (MW / HZ), which is generally 1% to 1.5% of the annual expected maximum load of the power grid system.

[0117] Step 204: determining an integral value of the regional control deviation according to the regional control deviation;

[0118] Specifically, the control performed by ACE is proportional control, and its disadvantage is that it cannot take into account the time factor. In order to consider the influence of time on control, it is also necessary to implement integral control, that is, to use the integral value ACEINT of ACE to time to implement the integral control of AGC.

[0119] according to Determine the integral value ACEINT of the area control deviation.

[0120] Written in discrete form: ACEINT K+1 =ACEINT K +ACE K+1 *T AGC Where, T AGC is the execution cycle of AGC.

[0121] Step 205: determining the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation;

[0122] Specifically, the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the new energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply;

[0123] UFC sends ACE and ACEINT to the network-level SCADA (Supervisory Control And Data Acquisition) application.

[0124] According to P R =[(-G Pn )*ACE+(-GIn )*ACEINT]+[(-G Pr )*ACE+(-G Ir )*ACEINT]=P P +P I Determine the total regulation power P of the area R , where G Pn and G In are the proportional gain coefficient and integral gain coefficient of renewable energy generation, G Pr and G Ir are the proportional gain coefficient and integral gain coefficient of the conventional power supply, P P and P I They are the proportional component and the integral component of the adjusted power respectively.

[0125] Step 206: Determine the adjustable power of the new energy according to the new energy power generation forecast and the actual operation status of the new energy unit;

[0126] Specifically, the power amount P that can be adjusted by the new energy N =P W +P P +P S (where P W , P P , P S are the adjustable power of wind power, photovoltaic power and energy storage respectively).

[0127] Step 207: Determine the regulated power required by the conventional units according to the total regulated power of the area and the regulated power of the new energy;

[0128] Specifically, according to P r =P R -P N Determine the regulating power P required by conventional units r .

[0129] Step 208: determining the regulating power borne by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0130] Specifically, according to Determine the regulation power P borne by the i-th AGC ri , where α i is the economic allocation coefficient of the i-th PLC, which is inversely proportional to the unit's consumption increment rate and is provided by the online economic dispatch program; β i is the proportional distribution coefficient; P ri is the regulation power allocated to the i-th PLC; n is the total number of PLCs that bear the regulation power under the current situation; P r The amount of regulated power required for conventional units.

[0131] Step 209: forwarding the regulated power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0132] Step 210: Each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS.

[0133] Step 211: Each generator set in the RTDS adjusts the power generation output according to the generator set control information response to obtain a new power system operation simulation result;

[0134] Step 212: Repeat steps 201-212 until the obtained system frequency is less than the frequency modulation dead zone.

[0135] Specifically, the frequency modulation dead zone fd is set according to needs, and the AGC frequency modulation dead zone fd is generally set to 0.03 Hz.

[0136] The present invention simulates the power system through a real-time digital simulator (RTDS), and can accurately obtain the operation simulation results of the power system, including the system frequency and the output of each generator set, providing an accurate data basis for subsequent frequency regulation. The prediction of new energy power generation and the actual operation status of the new energy unit are taken into account, so that the adjustable power amount of the new energy can be determined, which helps to make full use of the regulation capacity of the new energy unit. By determining the regional control deviation according to the system frequency deviation, and determining the total regulation power of the region according to the regional control deviation and its integral value, it is possible to achieve dynamic regulation of the grid frequency, which helps to quickly restore the system frequency to the vicinity of the rated value when the grid load changes, and ensure the stable operation of the grid; the regulation power borne by each conventional unit AGC (automatic generation control) is determined according to the economic allocation coefficient of the conventional unit, which helps to optimize the operating cost of the unit while ensuring the stability of the grid. At the same time, through precise frequency modulation control, it is possible to reduce the grid failure caused by frequency fluctuations and improve the reliability of the grid.

[0137] like Figure 5 As shown, in one embodiment, a power grid unified frequency regulation control test device is provided, and the device includes: a simulation module 501, a deviation calculation module 502, and a control module 503.

[0138] The simulation module 501 is configured to simulate the power system through a real-time digital simulator (RTDS) to determine the power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set;

[0139] The deviation calculation module 502 is configured to determine the system frequency deviation according to the system frequency; determine the regional control deviation according to the system frequency deviation and the system frequency deviation; determine the integral value of the regional control deviation according to the regional control deviation; determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, wherein the total regulated power of the region includes the proportional gain coefficient and the integral gain coefficient of the renewable energy power generation and the proportional gain coefficient and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the conventional power source; determine the amount of power that can be regulated by renewable energy according to the renewable energy power generation forecast and the actual operation state of the renewable energy unit; determine the amount of regulated power required by the conventional unit according to the total regulated power of the region and the amount of power that can be regulated by the renewable energy unit; and determine the regulated power undertaken by the AGC of each conventional unit according to the regulated power required by the conventional unit;

[0140] The control module 503 is configured to forward the regulated power undertaken by the conventional unit AGC to the corresponding AGCs in the form of SCADA analog quantity; and to allow the AGCs to send the corresponding unit control information to the corresponding generator sets simulated in the RTDS.

[0141] For other details of implementing the above technical solution in each module in the power grid unified frequency regulation control test device, please refer to the description in the power grid unified frequency regulation control test method provided above, which will not be repeated here.

[0142] In one embodiment, a computer device is provided. Figure 6 , Figure 6 3 is a schematic diagram of the structure of a computer device in an embodiment. The device includes a memory 301 and a processor 302. The memory 301 stores a computer program. When the computer program is executed by the processor 302, the processor 302 performs the following steps:

[0143] Step 101: simulating a power system through a real-time digital simulator (RTDS) to determine a power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes a system frequency and an output of each generator set;

[0144] Step 102: determining a system frequency deviation according to the system frequency;

[0145] Step 103: determining a regional control deviation according to the system frequency deviation and the system frequency deviation;

[0146] Step 104: determining an integral value of the regional control deviation according to the regional control deviation;

[0147] Step 105: determining the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation;

[0148] Step 106: Determine the adjustable power of the new energy according to the new energy power generation forecast and the actual operation status of the new energy unit;

[0149] Step 107: determining the regulated power required by the conventional units according to the total regulated power of the area and the regulated power of the new energy;

[0150] Step 108: determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0151] Step 109: forwarding the regulated power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0152] Step 110: Each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS.

[0153] Among them, the processor 302 can also be called a CPU (Central Processing Unit), and the processor 302 may be an integrated circuit chip with signal processing capabilities; the processor 302 can also be a general-purpose processor, DSP (Digital Signal Process), ASIC (Application Specific Integrated Circuit), FPGA (Field Programmable Gate Array) or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, among which the general-purpose processor can be a microprocessor or the processor 302 can also be any conventional processor, etc.

[0154] In one embodiment, a computer readable storage medium is provided. Figure 7 , Figure 7 The structure diagram of a computer-readable storage medium in an embodiment is a schematic diagram, on which a readable computer program 401 is stored; wherein the computer program 401 may be stored in the above storage medium in the form of a software product, and includes a number of instructions for causing a computer device (which may be a personal computer, a server machine, or a network device, etc.) or a processor to perform the following steps:

[0155] Step 101: simulating a power system through a real-time digital simulator (RTDS) to determine a power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes a system frequency and an output of each generator set;

[0156] Step 102: determining a system frequency deviation according to the system frequency;

[0157] Step 103: determining a regional control deviation according to the system frequency deviation and the system frequency deviation;

[0158] Step 104: determining an integral value of the regional control deviation according to the regional control deviation;

[0159] Step 105: determining the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation;

[0160] Step 106: Determine the adjustable power of the new energy according to the new energy power generation forecast and the actual operation status of the new energy unit;

[0161] Step 107: determining the regulated power required by the conventional units according to the total regulated power of the area and the regulated power of the new energy;

[0162] Step 108: determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit;

[0163] Step 109: forwarding the regulated power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity;

[0164] Step 110: Each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS.

[0165] The aforementioned storage media include: U disk, mobile hard disk, magnetic disk or CD, ROM (Read-Only Memory), RAM (Random Access Memory) and other media that can store program code, or terminal devices such as computers, service machines, mobile phones, and tablets.

[0166] Those skilled in the art can understand that all or part of the processes in the above-mentioned embodiment methods can be completed by instructing the relevant hardware through a computer program, and the program can be stored in a non-volatile computer-readable storage medium. When the program is executed, it can include the processes of the embodiments of the above-mentioned methods. Among them, any reference to memory, storage, database or other media used in the embodiments provided in this application can include non-volatile and / or volatile memory. Non-volatile memory may include read-only memory (ROM), programmable ROM (PROM), electrically programmable ROM (EPROM), electrically erasable programmable ROM (EEPROM) or flash memory. Volatile memory may include random access memory (RAM) or external cache memory. As an illustration and not limitation, RAM is available in many forms, such as static RAM (SRAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), double data rate SDRAM (DDRSDRAM), enhanced SDRAM (ESDRAM), synchronous link (Synchlink) DRAM (SLDRAM), memory bus (Rambus) direct RAM (RDRAM), direct memory bus dynamic RAM (DRDRAM), and memory bus dynamic RAM (RDRAM).

[0167] The technical features of the above embodiments may be combined arbitrarily. To make the description concise, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.

[0168] The above-described embodiments only express several implementation methods of the present application, and the descriptions thereof are relatively specific and detailed, but they cannot be understood as limiting the scope of the present application. It should be pointed out that, for a person of ordinary skill in the art, several variations and improvements can be made without departing from the concept of the present application, and these all belong to the protection scope of the present application. Therefore, the protection scope of the present application shall be subject to the attached claims.

Claims

1. A test method for unified frequency modulation control of a power grid, characterized in that: The method includes: The power system is simulated by a real-time digital simulator (RTDS) to determine the power system operation simulation result; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation result includes system frequency and output of each generator set; determining a system frequency deviation based on the system frequency; determining a regional control deviation based on the system frequency deviation and the system frequency deviation; determining an integral value of a regional control deviation according to the regional control deviation; Determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, wherein the total regulated power of the region includes the proportional component and the integral component of the regulated power determined by the proportional gain coefficient and the integral gain coefficient of the renewable energy power generation and the proportional gain coefficient and the integral gain coefficient of the conventional power supply; Determine the adjustable power of new energy based on the new energy power generation forecast and the actual operating status of the new energy units; Determine the amount of regulated power required by the conventional units according to the total regulated power of the area and the amount of regulated power of the new energy; Determining the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit; Forwarding the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity; Each AGC sends the corresponding unit control information to each corresponding generator set simulated in RTDS.

2. The power grid unified frequency modulation control test method according to claim 1, characterized in that: After each AGC sends the corresponding unit control information to each corresponding generator set simulated in the RTDS, the method also includes: each generator set in the RTDS adjusts the power output according to the unit control information response to obtain a new power system operation simulation result; re-obtaining the corresponding unit control information of each AGC based on the new power system operation simulation result, and each generator set in the RTDS adjusts the power output according to the unit control information response to obtain a new power system operation simulation result, until the obtained system frequency is less than the frequency regulation dead zone.

3. The power grid unified frequency modulation control test method according to claim 1 or 2, characterized in that: Determining the system frequency deviation according to the system frequency f specifically includes determining the system frequency deviation Δf according to Δf=f-f0, wherein f0 is the system rated frequency, and f is the system frequency.

4. The power grid unified frequency modulation control test method according to claim 3 is characterized in that: The determining of the regional control deviation according to the system frequency deviation and the system frequency deviation specifically includes: determining the regional control deviation ACE according to ACE=B*Δf, wherein B is a frequency deviation coefficient.

5. The power grid unified frequency modulation control test method according to claim 4 is characterized in that: Determining the integral value of the regional control deviation according to the regional control deviation specifically includes: according to Determine the integral value ACEINT of the area control deviation.

6. The power grid unified frequency modulation control test method according to claim 5, characterized in that: The determining of the total adjustment power of the region according to the regional control deviation and the integral value of the regional control deviation specifically includes: R =[(-G Pn )*ACE+(-G In )*ACEINT]+[(-G Pr )*ACE+(-G Ir )*ACEINT]=P P +P I Determine the total regulation power P of the area R , where G Pn and G In are the proportional gain coefficient and integral gain coefficient of renewable energy generation, G Pr and G Ir are the proportional gain coefficient and integral gain coefficient of the conventional power supply, P P and P I They are the proportional component and the integral component of the adjusted power respectively.

7. The power grid unified frequency modulation control test method according to claim 6, characterized in that: The determining of the regulating power undertaken by the AGC of each conventional unit according to the regulating power required by the conventional unit specifically includes: The regulation power assumed by the i-th AGC is determined P ri , where α i is the economic allocation coefficient of the i-th PLC, which is inversely proportional to the unit's consumption increment rate and is provided by the online economic dispatch program; β i is the proportional distribution coefficient; P ri is the regulation power allocated to the i-th PLC; n is the total number of PLCs that bear the regulation power under the current situation; P r The amount of regulated power required for conventional units.

8. A power grid unified frequency modulation control test device, characterized in that: The device comprises: A simulation module, used to simulate the power system through a real-time digital simulator (RTDS) to determine the power system operation simulation results; the power system includes conventional generator sets and new energy generator sets, and the power system operation simulation results include system frequency and output of each generator set; A deviation calculation module, used to determine the system frequency deviation according to the system frequency; also used to determine the regional control deviation according to the system frequency deviation and the system frequency deviation; also used to determine the integral value of the regional control deviation according to the regional control deviation; also used to determine the total regulated power of the region according to the regional control deviation and the integral value of the regional control deviation, the total regulated power of the region including the proportional gain coefficient and integral gain coefficient of the new energy power generation and the proportional gain coefficient and integral component of the regulated power determined by the integral gain coefficient of the conventional power supply; also used to determine the amount of power that can be regulated by the new energy according to the prediction of new energy power generation and the actual operating state of the new energy unit; also used to determine the amount of regulated power required by the conventional unit according to the total regulated power of the region and the amount of power that can be regulated by the new energy; and also used to determine the regulated power undertaken by the AGC of each conventional unit according to the amount of regulated power required by the conventional unit; The control module is used to forward the regulating power undertaken by the AGC of each conventional unit to the corresponding AGC in the form of SCADA analog quantity; and is also used for each AGC to send the corresponding unit control information to the corresponding generator sets simulated in RTDS.

9. A computer-readable storage medium storing a computer program, wherein when the computer program is executed by a processor, the processor is caused to perform the steps of the method according to any one of claims 1 to 7.

10. A computer device comprising a memory and a processor, wherein the memory stores a computer program, and when the computer program is executed by the processor, the processor executes the steps of the method according to any one of claims 1 to 7.

Images