Inertia-demand-considered calculation method and system for optimized clearing result of inertia auxiliary service market, and medium

Abstract

The invention discloses a calculation method and system for an inertia auxiliary service market optimization clearing result considering an inertia demand, and a medium, and the calculation method comprises the steps: solving a system minimum inertia demand based on RoCoF and FN constraints, determining a system minimum inertia purchasing demand, and taking the system minimum inertia purchasing demand as one of the constraints of a market joint optimization clearing model, therefore, a reasonable power supply structure is guided to be formed, the adequacy of inertia resources in the transaction process is guaranteed, and the frequency safety problem caused by insufficient inertia supply capacity of a power system is solved. According to the invention, the electric energy purchase cost, the unit start-stop cost and the inertia purchase cost are taken as the total scheduling cost, and the respective supply cost of the inertia and the electric energy is considered as a whole, so that the overall economic operation of the system is realized.

Description

Technical Field

[0001] The present invention relates to the field of power systems, and in particular to a method, system and medium for calculating optimized clearing results of an inertia auxiliary service market taking inertia demand into consideration. Background Art

[0002] Inertia market clearing can be categorized as independent clearing or joint clearing with electric energy. While independent clearing has a simpler algorithm and avoids the challenges of multi-objective optimization, it increases the system's total dispatch costs and is generally more suitable for medium- and long-term market transactions. Joint clearing with electric energy, while complex in structure, involves numerous constraints and more complex market rules, ultimately achieving overall economic operation of the system. However, conventional power market clearing algorithms only cover basic physical constraints such as active power balance, unit operation, and ramping, and cannot address frequency security issues caused by insufficient inertia supply capacity in the power system. Summary of the Invention

[0003] Purpose of the invention: The purpose of the present invention is to provide a method for calculating the optimized clearing results of the inertia ancillary service market, which can comprehensively consider the supply costs of inertia and electric energy and solve the frequency security problem caused by insufficient inertia supply capacity of the power system. Another purpose of the present invention is to provide a system and medium for calculating the optimized clearing results of the inertia ancillary service market, which takes into account inertia demand.

[0004] Technical solution: The method for calculating the optimized clearing result of the inertia auxiliary service market considering inertia demand of the present invention comprises the following steps:

[0005] Calculate the system minimum inertia requirements under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint respectively, and select the larger value from the obtained system minimum inertia requirements as the system minimum inertia procurement requirement;

[0006] Taking the minimum total dispatch cost as the clearing target, a market joint optimization clearing model is constructed under the constraints of the system's minimum inertia procurement demand, active power balance, unit output, ramp-up / slope constraints, and system reserve capacity.

[0007] The market joint optimization clearing model is solved to obtain the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each time period of the next day, that is, the clearing result of the inertia auxiliary service market considering inertia demand.

[0008] Furthermore, the minimum inertia requirement of the system under the frequency change rate RoCoF constraint is calculated as follows:

[0009] The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation:

[0010]

[0011] Among them, E sys is the total inertia of the system, f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t; P in (t) is the total additional power of the system frequency modulation resources at time t, P m is the mechanical power, P e is the electromagnetic power; D sys is the load frequency adjustment coefficient; f i (t) is the frequency of the generator node i at time t; H i represents the inertia constant of unit i;

[0012] The frequency change rate RoCoF constraint is as follows:

[0013]

[0014] ΔP(t 0+ )=P m (t 0+ )-P e (t 0+ )

[0015] Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set;

[0016] The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for

[0017]

[0018] Furthermore, the minimum inertia requirement of the system under the constraint of the lowest frequency point FN is calculated as follows:

[0019] Based on the primary frequency modulation response stage, a primary frequency modulation power model is constructed:

[0020]

[0021] Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response;

[0022] The frequency minimum point FN constraint is as follows:

[0023]

[0024] Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set;

[0025] Since the lowest frequency point FN appears in the PFR response stage, the PFR additional power is equal to the unbalanced power. The time t corresponding to FN nadir for

[0026]

[0027] The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for

[0028]

[0029] Furthermore, the minimum total scheduling cost is the clearing target minF is

[0030]

[0031] Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,t is the winning bid output of unit i in period t; C i (P i,t ) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,t is the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state;

[0032] The system minimum inertia procurement demand constraint is

[0033]

[0034] Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the minimum inertia requirement of the system during time period t;

[0035] The active power balance constraint is

[0036]

[0037] Among them, P L,t is the system load demand during time period t;

[0038] The unit output constraint is

[0039] I i,t ·P i min ≤P i,t ≤I i,t ·P i max

[0040] Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively;

[0041] The climbing / sliding rate constraint is

[0042]

[0043] in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively;

[0044] The system spare capacity constraint is

[0045]

[0046] in, and Respectively represent the upper and lower spare constraints reserved by the system.

[0047] The calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand of the present invention includes:

[0048] The system minimum inertia purchase demand calculation module is used to calculate the system minimum inertia demand under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint respectively, and select the larger value from the obtained system minimum inertia demand as the system minimum inertia purchase demand;

[0049] The market joint optimization clearing model construction module is used to build a market joint optimization clearing model with the minimum total dispatch cost as the clearing target, under the constraints of the system's minimum inertia procurement demand, active power balance constraints, unit output constraints, ramping / slope constraints, and system spare capacity constraints;

[0050] The decision-making solution module is used to solve the market joint optimization clearing model to obtain the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each time period of the next day, that is, the clearing result of the inertia auxiliary service market considering inertia demand.

[0051] Furthermore, in the system minimum inertia procurement requirement calculation module, the system minimum inertia requirement under the frequency change rate RoCoF constraint is calculated as follows:

[0052] The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation:

[0053]

[0054] Among them, E sys is the total inertia of the system, f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t; P in (t) is the total additional power of the system frequency modulation resources at time t, P m is the mechanical power, P e is the electromagnetic power; D sys is the load frequency adjustment coefficient; f i (t) is the frequency of the generator node i at time t; H i represents the inertia constant of unit i;

[0055] The frequency change rate RoCoF constraint is as follows:

[0056]

[0057] ΔP(t 0+ )=P m (t 0+ )-P e (t 0+ )

[0058] Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set;

[0059] The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for

[0060]

[0061] Furthermore, in the system minimum inertia procurement demand calculation module, the system minimum inertia demand under the frequency minimum point FN constraint is calculated as follows:

[0062] Based on the primary frequency modulation response stage, a primary frequency modulation power model is constructed:

[0063]

[0064] Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response;

[0065] The frequency minimum point FN constraint is as follows:

[0066]

[0067] Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set;

[0068] Since the lowest frequency point FN appears in the PFR response stage, the PFR additional power is equal to the unbalanced power. The time t corresponding to FN nadir for

[0069]

[0070] The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for

[0071]

[0072] Furthermore, in the market joint optimization clearing model construction module, the minimum total scheduling cost is the clearing target minF

[0073]

[0074] Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,t is the winning bid output of unit i in period t; C i (P i,t ) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,tis the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state;

[0075] The system minimum inertia procurement demand constraint is

[0076]

[0077] Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the minimum inertia requirement of the system during time period t;

[0078] The active power balance constraint is

[0079]

[0080] Among them, P L,t is the system load demand during time period t;

[0081] The unit output constraint is

[0082] I i,t ·P i min ≤P i,t ≤I i,t ·P i max

[0083] Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively;

[0084] The climbing / sliding rate constraint is

[0085]

[0086] in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively;

[0087] The system spare capacity constraint is

[0088]

[0089] in, and Respectively represent the upper and lower spare constraints reserved by the system.

[0090] The computer device of the present invention includes a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of the above method are implemented.

[0091] The computer-readable storage medium of the present invention stores a computer program thereon, and the computer program implements the steps of the above method when executed by a processor.

[0092] Beneficial effects: Compared with the existing technology, the present invention has the following significant advantages: 1. The present invention solves the system minimum inertia demand based on RoCoF and FN constraints respectively, determines the system minimum inertia procurement demand, and uses it as one of the constraints of the market joint optimization clearing model, thereby guiding the formation of a reasonable power supply structure, ensuring the abundance of inertia resources during the transaction process, and solving the frequency safety problem caused by insufficient inertia supply capacity of the power system; 2. The present invention takes the electricity procurement cost, unit start-up and shutdown cost, and inertia procurement cost as the total dispatching cost, comprehensively considers the respective supply costs of inertia and electricity, thereby achieving the overall economic operation of the system. BRIEF DESCRIPTION OF THE DRAWINGS

[0093] Figure 1 A schematic diagram of a flow chart of an embodiment of the present invention;

[0094] Figure 2 This is a schematic diagram of the response process of the primary frequency modulation power increase model of the present invention. DETAILED DESCRIPTION

[0095] The present invention will be further described below with reference to the accompanying drawings.

[0096] The calculation method of the optimized clearing result of the inertia auxiliary service market considering inertia demand of the present invention is as follows:

[0097] On the day before the operation, the next day's operating parameters are obtained from the information publicly available on the trading platform. These parameters include the renewable energy output forecast curve, load (demand) forecast curve, system inertia demand curve, and key information such as basic generator parameters, quotation range, and trading period submitted by power generators and inertia service providers. The system's minimum inertia requirement is assessed and calculated using the frequency safety operation index limit (frequency index constraint limit), and its value must meet both frequency stability requirements and market trading regulations.

[0098] Given a system's power structure and actual operating conditions, we screen out extreme power disturbances (maximum anticipated faults) and calculate their unbalanced power. The maximum power disturbance event that could occur in a system is typically the tripping of the largest generator unit, a disconnection of the AC tie line, or a DC blockage, depending on the system's operating conditions.

[0099] (1) Under this disturbance accident, the system minimum inertia requirements under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint are calculated respectively, and the larger value is selected from the obtained system minimum inertia requirements as the system minimum inertia procurement requirement.

[0100] (11) Calculate the minimum inertia requirement of the system under the frequency change rate RoCoF constraint as follows:

[0101] The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation:

[0102]

[0103] Among them, E sys is the total inertia of the system, in MWs; f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t, in Hz; P in (t) is the total additional power of the system frequency modulation resources at time t, in MW; P m is the mechanical power, P e is the electromagnetic power; D sys is the load frequency regulation coefficient, in MW / Hz.

[0104] The present invention only considers the time-varying characteristics of the system inertia, and does not consider the differences in the spatial distribution of inertia. The inertia of all generator sets is equivalently concentrated at the inertia center, with the inertia center frequency f coi To characterize the frequency response characteristics of the system as a whole. The inertia center frequency f at time t coi (t) is

[0105]

[0106] Among them, f i (t) is the frequency of the generator node i at time t; H i Represents the inertia constant of unit i.

[0107] At the moment of disturbance, since the power system frequency regulation resources have not yet been activated and the frequency has not changed, there is P in (0 + )=0,Δf coi (0 + )=0, only inertia can respond instantaneously, and the RoCoF is the largest at this time. In order to ensure that the RoCoF at every moment after the disturbance does not exceed the set safety threshold RoCoF max , the maximum RoCoF0+ at the moment of disturbance should be used as the benchmark.

[0108] The frequency change rate RoCoF constraint is as follows:

[0109]

[0110] ΔP(t 0+ )=P m (t 0+ )-P e (t 0+ )

[0111] Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set;

[0112] The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for

[0113]

[0114] (12) Calculate the minimum inertia requirement of the system under the constraint of the lowest frequency point FN, as follows:

[0115] The FN after the power shortage disturbance usually appears in the primary frequency regulation (PFR) stage, but at this time the inertia does not stop responding. Instead, as the speed regulator increases the mechanical power, the inertia support power gradually decreases. Therefore, FN depends on the synergistic effect of the inertia response and the primary frequency regulation response. To simplify the analysis, the present invention does not consider the effect of the fast frequency response (FFR) for the time being, and constructs a mathematical model that simulates the change of the PFR power increase response process over time. In order to reduce the complexity of the solution while ensuring a certain calculation accuracy, the PFR power increase curve is approximately linearized, and based on the primary frequency regulation response stage, a primary frequency regulation power increase model is constructed:

[0116]

[0117] Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response;

[0118] Since the lowest frequency point FN occurs in the PFR response phase (t1-t2), the PFR additional power is exactly equal to the unbalanced power at this time.

[0119]

[0120] The time t corresponding to FN nadir for

[0121]

[0122] Integrate the equivalent generator rotor motion equation in the interval [t1, t2] to obtain the frequency deviation Δf(t) at the lowest frequency point:

[0123]

[0124] In order to ensure that the frequency deviation |Δf(t)| at each moment after the disturbance does not exceed the set frequency deviation threshold value |Δf max |, the frequency deviation when the frequency reaches the lowest point |Δf nadir | is the benchmark, and it is not allowed to cross the set threshold value |Δf max The frequency minimum point FN is constrained as follows:

[0125]

[0126] Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set;

[0127] The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for

[0128]

[0129] (2) Taking the minimum total dispatch cost as the clearing target, a market joint optimization clearing model is constructed under the constraints of the system's minimum inertia procurement demand, active power balance, unit output, ramping / slope rate, and system spare capacity.

[0130] Considering the strong coupling between inertia and electric energy at the physical and economic levels, inertia auxiliary services and electric energy are jointly cleared in the day-ahead market. k The optimization variable is the minimum total dispatch cost, which includes the electricity procurement cost, unit start-up and shutdown cost, and inertia procurement cost. The minimum total dispatch cost is the clearing target minF.

[0131]

[0132] Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,tis the winning bid output of unit i in period t; C i (P i,t ) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,t is the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state.

[0133] For each period t, the total inertia provided by the units in the power system should be greater than or equal to the system minimum inertia purchase demand for that period. The system minimum inertia purchase demand constraint is:

[0134]

[0135] Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the minimum inertia requirement of the system during period t.

[0136] The active power balance constraint is

[0137]

[0138] Among them, P L,t is the system load demand during time period t;

[0139] The unit output constraint is

[0140] I i,t ·P i min ≤P i,t ≤I i,t ·P i max

[0141] Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively;

[0142] The climbing / sliding rate constraint is

[0143]

[0144] in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively;

[0145] For each operating period, the online generator sets need to reserve a certain amount of spare capacity to meet the positive and negative spare capacity constraints of the system. The system spare capacity constraint is

[0146]

[0147] in, and Respectively represent the upper and lower spare constraints reserved by the system.

[0148] (3) The market joint optimization clearing model is used to solve the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each period of the next day, and the inertia auxiliary service market clearing results considering inertia demand are obtained.

[0149] The day before the operation day, the trading center must publish the next day's operating parameters in advance and publicly display them on the trading platform. Since inertia service transactions take place in the day-ahead spot market, inertia service declarations are made simultaneously with electricity energy declarations. Therefore, the start and end times for inertia declarations coincide with those for the day-ahead electricity energy market. Based on the market's published load and inertia demands, each market participant must declare the electricity energy quantity-price curve and the inertia quantity-price curve for each time period of the next day within the specified time period. The electricity energy quantity-price curve can be single-segment or multi-segment, and each segment can be either linear or quadratic. However, unlike electricity energy, inertia supply is a discrete 0-1 variable whose size cannot be changed. Therefore, inertia suppliers declare the amount of inertia that the unit can provide and the unit inertia cost. Inertia is declared in terms of rotational kinetic energy (MWs), and the price is declared in the form of x yuan / MWs.

[0150] After the supply parties submit the data, they jointly optimize and clear the market in the day-ahead market. The clearing goal is to minimize the total cost of system procurement inertia and electricity energy. The clearing constraints include multiple constraints such as minimum inertia demand constraints, conventional safety constraints, and unit operation constraints. Finally, the unit combination results, electricity energy clearing results, and inertia clearing results are calculated.

[0151] The calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand of the present invention includes:

[0152] The system minimum inertia purchase demand calculation module is used to calculate the system minimum inertia demand under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint respectively, and select the larger value from the obtained system minimum inertia demand as the system minimum inertia purchase demand;

[0153] The market joint optimization clearing model construction module is used to build a market joint optimization clearing model with the minimum total dispatch cost as the clearing target, under the constraints of the system's minimum inertia procurement demand, active power balance constraints, unit output constraints, ramping / slope constraints, and system spare capacity constraints;

[0154] The decision-making solution module is used to solve the market joint optimization clearing model to obtain the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each time period of the next day, that is, the clearing result of the inertia auxiliary service market considering inertia demand.

[0155] Furthermore, in the system minimum inertia procurement requirement calculation module, the system minimum inertia requirement under the frequency change rate RoCoF constraint is calculated as follows:

[0156] The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation:

[0157]

[0158] Among them, E sys is the total inertia of the system, f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t; P in (t) is the total additional power of the system frequency modulation resources at time t, P m is the mechanical power, P e is the electromagnetic power; D sys is the load frequency adjustment coefficient; f i (t) is the frequency of the generator node i at time t; H i represents the inertia constant of unit i;

[0159] The frequency change rate RoCoF constraint is as follows:

[0160]

[0161] ΔP(t 0+ )=P m (t 0+ )-P e (t 0+ )

[0162] Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set;

[0163] The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for

[0164]

[0165] Furthermore, in the system minimum inertia procurement demand calculation module, the system minimum inertia demand under the frequency minimum point FN constraint is calculated as follows:

[0166] Based on the primary frequency modulation response stage, a primary frequency modulation power model is constructed:

[0167]

[0168] Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response;

[0169] The frequency minimum point FN constraint is as follows:

[0170]

[0171] Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set;

[0172] Since the lowest frequency point FN appears in the PFR response stage, the PFR additional power is equal to the unbalanced power. The time t corresponding to FN nadir for

[0173]

[0174] The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for

[0175]

[0176] Furthermore, in the market joint optimization clearing model construction module, the minimum total scheduling cost is the clearing target minF

[0177]

[0178] Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,t is the winning bid output of unit i in period t; C i (P i,t) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,t is the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state;

[0179] The system minimum inertia procurement demand constraint is

[0180]

[0181] Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the minimum inertia requirement of the system during time period t;

[0182] The active power balance constraint is

[0183]

[0184] Among them, P L,t is the system load demand during time period t;

[0185] The unit output constraint is

[0186] I i,t ·P i min ≤P i,t ≤I i,t ·P i max

[0187] Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively;

[0188] The climbing / sliding rate constraint is

[0189]

[0190] in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively;

[0191] The system spare capacity constraint is

[0192]

[0193] in, and Respectively represent the upper and lower spare constraints reserved by the system.

[0194] The computer device of the present invention includes a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of the above method are implemented.

[0195] Those skilled in the art will appreciate that the embodiments of the present application can be provided as methods, systems, or computer program products. Therefore, the application can adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the application can adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that contain computer-usable program code. The scheme in the embodiment of the present application can be implemented in various computer languages, for example, object-oriented programming language Java and literal translation scripting language JavaScript, etc.

[0196] The present application is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to the embodiments of the present application. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the steps in the process. Figure 1 a process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0197] These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 a process or multiple processes and / or boxes Figure 1 The function specified in one or more boxes.

[0198] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing the instructions executed on the computer or other programmable device for implementing the process. Figure 1a process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

Claims

1. A method for calculating the optimal clearing results of the inertia auxiliary service market considering inertia demand, characterized in that: The following steps are involved: Calculate the system minimum inertia requirements under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint respectively, and select the larger value from the obtained system minimum inertia requirements as the system minimum inertia procurement requirement; Taking the minimum total dispatch cost as the clearing target, a market joint optimization clearing model is constructed under the constraints of the system's minimum inertia procurement demand, active power balance, unit output, ramp-up / slope constraints, and system reserve capacity. The market joint optimization clearing model is solved to obtain the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each time period of the next day, that is, the optimized clearing result of the inertia auxiliary service market considering inertia demand.

2. The calculation method for optimizing the clearing results of the inertia auxiliary service market considering inertia demand according to claim 1 is characterized in that: Calculate the minimum system inertia requirement under the frequency change rate RoCoF constraint as follows: The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation: Among them, E sys is the total inertia of the system, f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t; P in (t) is the total additional power of the system frequency modulation resources at time t, P m (t) is the mechanical power at time t, P e (t) is the electromagnetic power at time t; D sys is the load frequency adjustment coefficient; f i (t) is the frequency of the generator node i at time t; H i represents the inertia constant of unit i; The frequency change rate RoCoF constraint is as follows: Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set; The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for 3. The calculation method for optimizing the clearing results of the inertia auxiliary service market considering inertia demand according to claim 2 is characterized in that: Calculate the minimum inertia requirement of the system under the frequency minimum point FN constraint as follows: Based on the primary frequency modulation response stage, a primary frequency modulation power model is constructed: Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response; The frequency minimum point FN constraint is as follows: Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set; Since the lowest frequency point FN appears in the PFR response stage, the PFR additional power is equal to the unbalanced power. The time t corresponding to FN nadir for The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for 4. The method for calculating the optimal clearing result of the inertia auxiliary service market considering inertia demand according to claim 3 is characterized in that: The minimum total scheduling cost is the clearing target minF Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,t is the winning bid output of unit i in period t; C i (P i,t ) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,t is the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state; The system minimum inertia procurement demand constraint is Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the system minimum inertia procurement demand during period t; The active power balance constraint is Among them, P L,t is the system load demand during time period t; The unit output constraint is Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively; The climbing / sliding rate constraint is in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively; The system spare capacity constraint is in, and Respectively represent the upper and lower spare constraints reserved by the system.

5. A calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand, characterized in that: include The system minimum inertia purchase demand calculation module is used to calculate the system minimum inertia demand under the frequency change rate RoCoF constraint and the frequency minimum point FN constraint, and select the larger value from the obtained system minimum inertia demand as the system minimum inertia purchase demand; The market joint optimization clearing model construction module is used to build a market joint optimization clearing model with the minimum total dispatch cost as the clearing target, under the constraints of the system's minimum inertia procurement demand, active power balance constraints, unit output constraints, ramping / slope constraints, and system spare capacity constraints; The decision-making solution module is used to solve the market joint optimization clearing model to obtain the start-up and shutdown status, winning bid quantity and corresponding clearing price of different types of units in each time period of the next day, that is, the clearing result of the inertia auxiliary service market considering inertia demand.

6. The calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand according to claim 5 is characterized in that: In the system minimum inertia procurement requirement calculation module, the system minimum inertia requirement under the frequency change rate RoCoF constraint is calculated as follows: The dynamic frequency response of the power system after power disturbance is described by the equivalent generator rotor motion equation: Among them, E sys is the total inertia of the system, f0 is the rated frequency of the system; Δf coi (t) is the change in the system inertia center frequency at time t; P in (t) is the total additional power of the system frequency modulation resources at time t, P m (t) is the mechanical power at time t, P e (t) is the electromagnetic power at time t; D sys is the load frequency adjustment coefficient; f i (t) is the frequency of the generator node i at time t; H i represents the inertia constant of unit i; The frequency change rate RoCoF constraint is as follows: Among them, the frequency change rate reaches its maximum at the moment of disturbance. is the frequency change rate at the moment of disturbance; For the disturbance moment Unbalanced power at all times; RoCoF max The frequency change rate safety threshold is set; The minimum system inertia requirement E under the frequency change rate RoCoF constraint sys.RoCoF.min for 7. The calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand according to claim 6 is characterized in that: In the system minimum inertia procurement demand calculation module, the system minimum inertia demand under the frequency minimum point FN constraint is calculated as follows: Based on the primary frequency modulation response stage, a primary frequency modulation power model is constructed: Among them, P PFR is the maximum additional power of PFR; t1 is the start time of PFR response; t2 is the end time of PFR response; The frequency minimum point FN constraint is as follows: Among them, the frequency deviation is at the lowest frequency point t nadir Reaching the maximum, Δf nadir The time t when the frequency drops to the lowest point after the disturbance nadir Frequency deviation, Δf max The frequency deviation safety threshold is set; Since the lowest frequency point FN appears in the PFR response stage, the PFR additional power is equal to the unbalanced power. The time t corresponding to FN nadir for The system minimum inertia requirement E under the frequency minimum point FN constraint sys.FN.min for 8. The calculation system for optimizing the clearing results of the inertia auxiliary service market considering inertia demand according to claim 7 is characterized in that: In the market joint optimization clearing model construction module, the minimum total scheduling cost is the clearing target minF Where N is the number of generator sets; T is the total number of dispatch periods; M is the total number of units that can provide inertia; P i,t is the winning bid output of unit i in period t; C i (P i,t ) is the power generation operation cost function reported by unit i in period t; is the startup cost of thermal power unit i in period t; E k,i,t is the inertia size of unit i in the period t; p i The unit inertia cost reported by unit i; I i,t is the start-stop state variable of unit i in period t, when I i,t When it is 1, it means the unit is in the power-on state. i,t When it is 0, it means the unit is in shutdown state; The system minimum inertia procurement demand constraint is Among them, E k,i is the inertia that unit i can provide; E sys.min,t is the minimum inertia requirement of the system during time period t; The active power balance constraint is Among them, P L,t is the system load demand during time period t; The unit output constraint is I i,t ·P i min ≤P i,t ≤I i,t ·P i max Among them, P i min and P i max They represent the minimum and maximum technical output of unit i respectively; The climbing / sliding rate constraint is in, and They represent the maximum climbing and sliding capabilities of the active output of unit i per hour respectively; The system spare capacity constraint is in, and Respectively represent the upper and lower spare constraints reserved by the system.

9. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the method according to any one of claims 1 to 4 are implemented.

10. A computer-readable storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the steps of the method according to any one of claims 1 to 4 are implemented.

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