CN113381424A - Power grid surplus resource consumption system considering gas storage cost - Google Patents
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Abstract
The invention provides a power grid surplus resource consumption system considering gas storage cost, which adopts an equivalent mode to perform electricity-gas conversion and realizes the consumption of the surplus resources of a power grid. The system has short required time and is suitable for daily real-time scheduling of the power system; the system divides an electric network into different areas by adopting a regional division mode, each area selects a gas turbine set as an 'electricity-gas' conversion point, and a constraint condition is adopted to constrain surplus electric power resources in the same area to be only provided for the 'electricity-gas' conversion point of the area; and then, the surplus power resources are used for replacing partial output of the gas turbine unit through a power grid demand response mechanism, which is equivalent to reducing the consumption of natural gas of the gas turbine unit, and the amount of partial natural gas is equivalent to equivalently saving on the gas grid side, and the partial natural gas can be stored through a gas storage tank.
Description
Technical Field
The invention relates to the technical field of surplus resource consumption of a power grid, in particular to a surplus resource consumption system of the power grid considering the gas storage cost.
Background
With the increasing proportion of new energy power generation, the consumption problem is increasingly prominent. Aiming at the problem of the consumption of surplus resources of the power grid, scholars at home and abroad put forward a plurality of methods. Among them, the electro-pneumatic (P2G) technology is a potential way to solve this problem. The method mainly converts electric energy into natural gas through chemical reaction and then carries out remote transportation and storage. However, since the time of day real-time scheduling of the power system is often short, and the conversion time required by P2G is long, this method is not suitable for day-of-day optimal scheduling of the power grid.
Disclosure of Invention
The invention provides a power grid surplus resource consumption system considering the gas storage cost, which is short in required time and suitable for daily real-time scheduling of a power system.
In order to achieve the technical effects, the technical scheme of the invention is as follows:
a power grid surplus resource consumption system considering gas storage cost comprises:
the system comprises a power grid network frame data module, a power grid day-ahead optimized scheduling module, a virtual power plant output and quotation module, a natural gas storage module, an electric-gas conversion point unit actual maximum output reducible amount estimation module considering gas storage cost, an electric-gas conversion point unit actual maximum output reducible amount data module, a virtual power plant output optimal distribution module required for storing equivalent natural gas amount, and a virtual power plant output optimal distribution scheme module;
the power grid network frame data module provides power grid network frame structure data and network load data for the system;
the power grid day-ahead optimization scheduling module is used for receiving the data provided by the power grid network frame data module and outputting a power grid day-ahead scheduling optimization result;
the virtual power plant output and quotation module is responsible for providing the maximum capacity of surplus resources of the power grid and expected quotation of the surplus resources;
the natural gas storage module is responsible for providing gas network gas price, the maximum gas storage capacity of the gas storage tank and the maximum injected natural gas amount of the gas storage tank at each moment;
the actual maximum output reducible amount estimation module of the electric-gas conversion point set considering the gas storage cost is used for receiving data of the power grid network frame data module, the power grid day-ahead optimization scheduling module and the virtual power plant output and quotation module and outputting an actual maximum output reducible amount and a stored equivalent natural gas amount optimization result of the electric-gas conversion ignition gas turbine considering the gas storage cost;
the actual maximum output reducible quantity data module of the electric-gas conversion point unit is responsible for receiving the actual maximum output reducible quantity result of the conversion point unit output by the actual maximum output reducible quantity estimation module of the electric-gas conversion point unit considering the gas storage cost;
the optimal virtual power plant output distribution module required by the equivalent natural gas storage amount is used for receiving the optimization result of the actual maximum output reducible amount estimation module of the electric-gas conversion point unit considering the gas storage cost and the grid data provided by the power grid data module and outputting the optimization result;
the virtual power plant output optimal distribution scheme module is responsible for receiving an optimal distribution result of the virtual power plant output required by the equivalent natural gas storage amount and output by the virtual power plant output optimal distribution module required by the equivalent natural gas storage amount.
Further, the actual maximum output reducible quantity estimation module of the electric-gas conversion point unit considering the gas storage cost is responsible for constructing an actual maximum output reducible quantity estimation model of the electric-gas conversion point unit considering the gas storage cost, and according to the data of the power grid rack data module, the power grid day-ahead optimization scheduling module and the virtual power plant output and quotation module, a relevant optimization result is obtained through calculation, and the constructed estimation model is as follows:
an objective function: max:. DELTA.Pgr
Constraint conditions are as follows:
wherein, Δ PgrIndicating the actual maximum reducible power, P, of the gas turbine at the transition pointgrFor converting the output of the ignition gas turbine unit, PvRepresenting the output of a virtual power plant, Pdr,TThe day-ahead output of other units except the gas unit at the moment T, D is the load of the power grid, Pv,maxFor a virtual power plant maximum output, Pgr,afFor converting the output of a day-ahead unit of a fired gas turbine, Δ Pgr,maxFor converting the maximum value of the amount of decrease in the output of the ignition gas turbine, PL is a line flow matrix, x is a matrix multiplication, SF is a transfer factor matrix, KP is a node-unit correlation matrix, P is an overall unit output matrix, KD is a node-load correlation matrix, PL is a load-load correlation matrixre,maxThe maximum value of the remaining capacity of the line in the day, n is the connection line between different areas, PLn,afFor the line trend of n days ahead, delta Gr is the natural gas quantity saved by the output reduction of the unit at the conversion point, alpha, beta and chi are characteristic parameters of the gas turbine, GrafGas usage, ζ, predetermined for gas turbine engines in the market at a day-ahead timevCorresponding to the output cost of the virtual power plant, k is the gas storage price coefficient, the gas supply price of the omega gas well, γ is the power grid dispatching service charge rate, Cin,TFor time T the remaining capacity of the tank, Cin,maxIs the maximum gas storage capacity of the gas tank, Qin,maxFor each moment of injection of a maximum amount of natural gas, Qin,minInjecting the minimum value of the natural gas quantity for each moment;
the target function represents that the output reducible quantity of the gas unit at the conversion point is maximum, the constraints of the optimized mathematical model comprise virtual power plant output constraints, transmission network constraints and gas network related constraints, wherein the constraints (1) are system power balance constraints, the constraints (2) are virtual power plant output constraints, the constraints (3) - (4) are output reducible quantity constraints of the gas unit at the conversion point, the constraints (5) are power flow equation constraints, the constraints (6) are system power flow constraints, the constraints (7) are region division constraints, the constraints (8) are equivalent natural gas quantity constraints of the output reducible quantity conversion of the gas unit at the conversion point, the constraints (9) are gas storage cost constraints, the constraints (10) - (11) are gas storage capacity constraints, and the constraints (12) are natural gas injection constraints at a moment.
Furthermore, the estimation module for the actual maximum output reducible quantity of the electric-gas conversion point unit considering the gas storage cost performs region division when converting the surplus resources of the power grid into equivalent natural gas for storage, so as to ensure that the surplus resources of the power grid in the region are only provided for the electric-gas conversion point gas unit in the region, and the region division constraint is specifically expressed as formula (7); the actual maximum output reducible quantity estimation module of the electric-gas conversion point unit considering the gas storage cost considers the gas storage cost when converting surplus resources of a power grid into equivalent natural gas for storage, ensures that the system operation cost is the lowest, and is specifically represented as formula (9) gas storage cost constraint.
Further, the actual maximum output reducible amount data module of the electric-gas conversion point unit is an optimization result of the constructed estimation model, and outputs the actual maximum output reducible amount result of the conversion point unit.
Further, the optimal virtual power plant output distribution module required for storing the equivalent natural gas amount is responsible for constructing an optimal virtual power plant output distribution model required for storing the equivalent natural gas amount, and outputting an optimal virtual power plant output distribution result required for the corresponding conversion point unit output reduction amount according to data submitted by the data module considering the actual maximum output reducible amount of the electric-gas conversion point unit, wherein the constructed optimal distribution model is as follows:
an objective function:
constraint conditions are as follows:
wherein, Pv,TRepresents the output of the virtual power plant at time T, Pgr,TRepresenting the actual output, Δ P, of the unit at the transition point at time Tgr,TFor switching point machineActual maximum reducible power of a group at time T, Pgr,af,TThe output of the day-ahead unit of the gas turbine at the time of T, Pdr,TThe day-ahead output of other units except the gas unit at the time of T, PLTFor time T grid line flow matrix, PTAll the unit output matrixes are set at the moment T; the objective function representation represents that the virtual plant output cost is the lowest. The constraints of the optimized mathematical model comprise virtual power plant output constraints and transmission network constraints, wherein a formula (13) is used for calculating the actual output of the unit at the time of the conversion point, a constraint (14) is a system power balance constraint, a constraint (15) is a virtual power plant output constraint, a constraint (16) is a power flow equation constraint, a constraint (17) is a system power flow constraint, and a constraint (18) is a region division constraint; the virtual power plant output optimal distribution scheme module is used for outputting a virtual power plant output optimal distribution scheme for an optimization result of the constructed optimal distribution model;
the day-ahead scheduling optimization result of the power grid comprises a day-ahead preset output plan of each unit and day-ahead line residual capacity of the power grid.
Compared with the prior art, the technical scheme of the invention has the beneficial effects that:
the invention provides a power grid surplus resource consumption system considering the gas storage cost, which adopts an equivalent mode to carry out electricity-gas conversion and realizes the consumption of the surplus resources of the power grid. The system has short required time and is suitable for daily real-time scheduling of the power system; the system divides an electric network into different areas by adopting a regional division mode, each area selects a gas turbine set as an 'electricity-gas' conversion point, and a constraint condition is adopted to constrain surplus electric power resources in the same area to be only provided for the 'electricity-gas' conversion point of the area; and then, the surplus power resources are used for replacing partial output of the gas turbine unit through a power grid demand response mechanism, which is equivalent to reducing the consumption of natural gas of the gas turbine unit, and the amount of partial natural gas is equivalent to equivalently saving on the gas grid side, and the partial natural gas can be stored through a gas storage tank.
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FIG. 1 is a block diagram of the system of the present invention.
Detailed Description
The drawings are for illustrative purposes only and are not to be construed as limiting the patent;
for the purpose of better illustrating the embodiments, certain features of the drawings may be omitted, enlarged or reduced, and do not represent the size of an actual product;
it will be understood by those skilled in the art that certain well-known structures in the drawings and descriptions thereof may be omitted.
The technical solution of the present invention is further described below with reference to the accompanying drawings and examples.
As shown in fig. 1, the present invention provides a power grid surplus resource consumption system considering gas storage cost, which includes a power grid network frame data module, a power grid day-ahead optimization scheduling module, a virtual power plant output and quotation module, a natural gas storage module, an actual maximum output reducible amount estimation module of an electric-gas conversion point unit considering gas storage cost, an actual maximum output reducible amount data module of the electric-gas conversion point unit, an optimal virtual power plant output allocation module required for storing equivalent natural gas amount, and an optimal virtual power plant output allocation scheme module.
Firstly, the power grid network frame data module is used for collecting basic data such as power grid network frame data, power grid load data, generator set characteristic parameters and the like, and inputting the data into the power grid day-ahead optimization scheduling module.
The power grid day-ahead optimization scheduling module is responsible for receiving related power grid network frame data and performing modeling analysis by adopting a typical unit combination model. A typical unit combination model is as follows:
an objective function:
constraint conditions are as follows:
wherein the objective function is to minimize the operating cost on the basis of the generator set quote. The constraints of the unit optimization mathematical model comprise unit constraints and transmission network complete constraints, wherein the constraints (19) are system power balance constraints, the constraints (20) are actual generator generating capacity constraints, the constraints (21) are generator set power climbing constraints, the constraints (22) are generator set power descending constraints, the constraints (23) are power flow equation constraints, and the constraints (24) are power flow constraints.
Wherein: NG is the number of generator sets, NT is the number of hours, Fi(Pit) Generating cost at time t, P, which is a cost function of the ith generator setitIs the output of the ith generator set at time t, IitFor start-stop state at time t of the ith power plant, SUitAnd SDitFor the start-stop cost of the unit of the ith power plant for t hours, DtFor the grid load at time t, URiFor the power rise slope, UP, of the ith power plant between any two timesiFor the power rise slope, DR, at the initial moment of the ith power plantiFor the power down slope, DP, of the ith power plant between any two timesiIs the power reduction slope of the ith power plant at the initial moment, SF is the transfer factor matrix, KP is the node-unit association matrix, PtFor all unit output matrices, KD is a node-load incidence matrix, PLmin,PLmaxRespectively the minimum and maximum values of the network power flow.
After the day-ahead optimized scheduling is completed, the power grid day-ahead optimized scheduling module submits an optimized result to the actual maximum output reducible quantity estimation module of the electric-gas conversion point unit considering the gas storage cost, wherein the optimized result comprises the day-ahead output result of each generator unit and the day-ahead residual capacity of the power grid line.
After the actual maximum output reducible amount estimation module of the electric-gas conversion point unit receives data submitted by the virtual power plant output, quotation module, natural gas storage module and power grid day-ahead optimization scheduling module, modeling analysis is carried out on related data by constructing an actual maximum output reducible amount estimation model of the electric-gas conversion point unit considering gas storage cost, and an optimization result is output. The mathematical model was constructed as follows:
an objective function: max:. DELTA.Pgr
Constraint conditions
Wherein the objective function represents that the output reducing amount of the gas turbine set at the conversion point is maximum. The constraints of the optimized mathematical model comprise virtual power plant output constraints, transmission network constraints, gas network related constraints and the like. The method comprises the following steps that constraint (1) is system power balance constraint, constraint (2) is virtual power plant output constraint, constraints (3) - (4) are conversion point unit output reduction quantity constraint, constraint (5) is flow equation constraint, constraint (6) is system flow constraint, constraint (7) is region division constraint, constraint (8) is equivalent natural gas quantity constraint of conversion point unit output reduction quantity conversion, constraint (9) is gas storage cost constraint, constraints (10) - (11) are gas storage capacity constraint, and constraint (12) is natural gas quantity constraint injected at any time.
Wherein, Δ PgrIndicating the actual maximum reducible power, P, of the gas turbine at the transition pointgrFor converting the output of the ignition gas turbine unit, PvRepresenting the output of a virtual power plant, Pdr,TThe day-ahead output of other units except the gas unit at the moment T, D is the load of the power grid, Pv,maxFor a virtual power plant maximum output, Pgr,afFor converting the output of a day-ahead unit of a fired gas turbine, Δ Pgr,maxFor converting the maximum value of the amount of decrease in the output of the ignition gas turbine, PL is a line flow matrix, x is a matrix multiplication, SF is a transfer factor matrix, KP is a node-unit correlation matrix, P is an overall unit output matrix, KD is a node-load correlation matrix, PL is a load-load correlation matrixre,maxThe maximum value of the remaining capacity of the line in the day, n is the connection line between different areas, PLn,afFor the line trend of n days ahead, delta Gr is the natural gas quantity saved by the output reduction of the unit at the conversion point, alpha, beta and chi are characteristic parameters of the gas turbine, GrafGas usage, ζ, predetermined for gas turbine engines in the market at a day-ahead timevCorresponding to the output cost of the virtual power plant, k is the gas storage price coefficient, the gas supply price of the omega gas well, γ is the power grid dispatching service charge rate, Cin,TFor time T the remaining capacity of the tank, Cin,maxMaximizing the gas storage capacity of the gas tankValue, Qin,maxFor each moment of injection of a maximum amount of natural gas, Qin,minAnd injecting the minimum value of the natural gas quantity for each moment.
And the actual maximum output reducible amount estimation module of the electric-gas conversion point unit outputs the actual maximum output reducible amount result of the conversion point unit to the actual maximum output reducible amount data module of the electric-gas conversion point unit, and submits the data to the virtual power plant output optimal distribution module required by storing equivalent natural gas amount through the module.
And after the optimal virtual power plant output distribution module required by the equivalent natural gas storage capacity receives the relevant data, modeling and analyzing the relevant data by constructing the optimal virtual power plant output distribution module required by the equivalent natural gas storage capacity, and submitting an optimization result to the optimal virtual power plant output distribution scheme module. The mathematical model was constructed as follows:
an objective function:
constraint conditions are as follows:
wherein the objective function representation represents that the output cost of the virtual power plant is the lowest. The constraints of the optimized mathematical model include virtual power plant output constraints, transmission network constraints, and the like. The formula (13) is used for calculating the actual output of the unit at the conversion point at the moment, the constraint (14) is a system power balance constraint, the constraint (15) is a virtual power plant output constraint, the constraint (16) is a power flow equation constraint, the constraint (17) is a system power flow constraint, and the constraint (18) is a region division constraint.
Wherein, Pv,TRepresents the output of the virtual power plant at time T, Pgr,TRepresenting the actual output, Δ P, of the unit at the transition point at time Tgr,TFor the actual maximum reducible contribution of the unit at the transfer point at time T, Pgr,af,TThe output of the day-ahead unit of the gas turbine at the time of T, Pdr,TThe day-ahead output of other units except the gas unit at the time T,PLTfor time T grid line flow matrix, PTAnd (4) obtaining a matrix of all unit output at the time T.
And finally, outputting the optimal distribution scheme of the output of the virtual power plant by the optimal distribution scheme module of the output of the virtual power plant.
The invention provides a power grid surplus resource consumption system considering gas storage cost, which adopts an equivalent substitution mode to carry out electricity-gas conversion, and replaces partial output of a gas turbine by a virtual power plant, so that the output of a gas turbine unit is reduced, the natural gas required originally is saved, and the consumption of the surplus resource of a power grid is realized. In addition, because the real electricity is not converted into gas, the required time of the system is short, and the method is suitable for day-to-day real-time scheduling of the power system.
The same or similar reference numerals correspond to the same or similar parts;
the positional relationships depicted in the drawings are for illustrative purposes only and are not to be construed as limiting the present patent;
it should be understood that the above-described embodiments of the present invention are merely examples for clearly illustrating the present invention, and are not intended to limit the embodiments of the present invention. Other variations and modifications will be apparent to persons skilled in the art in light of the above description. And are neither required nor exhaustive of all embodiments. Any modification, equivalent replacement, and improvement made within the spirit and principle of the present invention should be included in the protection scope of the claims of the present invention.
Claims (10)
1. A power grid surplus resource consumption system considering gas storage cost is characterized by comprising:
the system comprises a power grid network frame data module, a power grid day-ahead optimized scheduling module, a virtual power plant output and quotation module, a natural gas storage module, an electric-gas conversion point unit actual maximum output reducible amount estimation module considering gas storage cost, an electric-gas conversion point unit actual maximum output reducible amount data module, a virtual power plant output optimal distribution module required for storing equivalent natural gas amount, and a virtual power plant output optimal distribution scheme module;
the power grid network frame data module provides power grid network frame structure data and network load data for the system;
the power grid day-ahead optimization scheduling module is used for receiving the data provided by the power grid network frame data module and outputting a power grid day-ahead scheduling optimization result;
the virtual power plant output and quotation module is responsible for providing the maximum capacity of surplus resources of the power grid and expected quotation of the surplus resources;
the natural gas storage module is responsible for providing gas network gas price, the maximum gas storage capacity of the gas storage tank and the maximum injected natural gas amount of the gas storage tank at each moment;
the actual maximum output reducible amount estimation module of the electric-gas conversion point set considering the gas storage cost is used for receiving data of the power grid network frame data module, the power grid day-ahead optimization scheduling module and the virtual power plant output and quotation module and outputting an actual maximum output reducible amount and a stored equivalent natural gas amount optimization result of the electric-gas conversion ignition gas turbine considering the gas storage cost;
the actual maximum output reducible quantity data module of the electric-gas conversion point unit is responsible for receiving the actual maximum output reducible quantity result of the conversion point unit output by the actual maximum output reducible quantity estimation module of the electric-gas conversion point unit considering the gas storage cost;
the optimal virtual power plant output distribution module required by the equivalent natural gas storage amount is used for receiving the optimization result of the actual maximum output reducible amount estimation module of the electric-gas conversion point unit considering the gas storage cost and the grid data provided by the power grid data module and outputting the optimization result;
the virtual power plant output optimal distribution scheme module is responsible for receiving an optimal distribution result of the virtual power plant output required by the equivalent natural gas storage amount and output by the virtual power plant output optimal distribution module required by the equivalent natural gas storage amount.
2. The system for eliminating surplus resources in power grids considering gas storage costs according to claim 1, wherein the estimation module for estimating the actual maximum output reducible amount of the electric-to-gas conversion point unit considering gas storage costs is responsible for constructing an estimation model for estimating the actual maximum output reducible amount of the electric-to-gas conversion point unit considering gas storage costs, and obtaining relevant optimization results through calculation according to data of the grid rack data module, the grid day-ahead optimization scheduling module, the virtual power plant output and quotation module, wherein the estimation model is constructed as follows:
an objective function: max:. DELTA.Pgr
Constraint conditions are as follows:
wherein, Δ PgrIndicating the actual maximum reducible power, P, of the gas turbine at the transition pointgrFor converting the output of the ignition gas turbine unit, PvRepresenting the output of a virtual power plant, Pdr,TThe day-ahead output of other units except the gas unit at the moment T, D is the load of the power grid, Pv,maxFor a virtual power plant maximum output, Pgr,afFor converting the output of a day-ahead unit of a fired gas turbine, Δ Pgr,maxFor converting the maximum value of the amount of decrease in the output of the ignition gas turbine, PL is a line flow matrix, x is a matrix multiplication, SF is a transfer factor matrix, KP is a node-unit correlation matrix, P is an overall unit output matrix, KD is a node-load correlation matrix, PL is a load-load correlation matrixre,maxThe maximum value of the remaining capacity of the line in the day, n is the connection line between different areas, PLn,afFor the line trend of n days ahead, delta Gr is the natural gas quantity saved by the output reduction of the unit at the conversion point, alpha, beta and chi are characteristic parameters of the gas turbine, GrafGas usage, ζ, predetermined for gas turbine engines in the market at a day-ahead timevCorresponding to the output cost of the virtual power plant, k is the gas storage price coefficient, the gas supply price of the omega gas well, γ is the power grid dispatching service charge rate, Cin,TFor time T the remaining capacity of the tank, Cin,maxIs the maximum gas storage capacity of the gas tank, Qin,maxFor each moment of injection of a maximum amount of natural gas, Qin,minAnd injecting the minimum value of the natural gas quantity for each moment.
3. The system of claim 2, wherein the objective function represents a maximum reduction in output of the gas turbine at the transition point, the constraints of the optimized mathematical model include virtual power plant output constraints, transmission network constraints, and gas grid related constraints, the method comprises the following steps that constraint (1) is system power balance constraint, constraint (2) is virtual power plant output constraint, constraints (3) - (4) are conversion point unit output reduction quantity constraint, constraint (5) is flow equation constraint, constraint (6) is system flow constraint, constraint (7) is region division constraint, constraint (8) is equivalent natural gas quantity constraint of conversion point unit output reduction quantity conversion, constraint (9) is gas storage cost constraint, constraints (10) - (11) are gas storage capacity constraint, and constraint (12) is natural gas quantity constraint injected at any time.
4. The system for consuming surplus resources of power grid considering gas storage cost according to claim 3, wherein the module for estimating the actual maximum output reducible amount of the set of electric-to-gas conversion points considering gas storage cost performs region division when converting the surplus resources of power grid into equivalent natural gas for storage, so as to ensure that the surplus resources of power grid in the region are only provided for the set of electric-to-gas conversion points in the region, which is specifically expressed as the region division constraint of formula (7).
5. The system for consuming surplus resources of power grid considering gas storage cost according to claim 4, wherein the module for estimating the actual maximum output reducible amount of the set of electric-to-gas conversion points considering gas storage cost considers gas storage cost when converting the surplus resources of power grid into equivalent natural gas for storage, thereby ensuring that the system operation cost is the lowest, which is specifically expressed as the constraint of gas storage cost of equation (9).
6. The system for absorbing surplus resources of a power grid in consideration of gas storage costs according to claim 5, wherein the data module for reducing the actual maximum output of the electric-gas conversion point unit is an optimization result of the constructed estimation model, and outputs a reduction result of the actual maximum output of the conversion point unit.
7. The power grid surplus resource consumption system considering gas storage cost according to claim 6, wherein the virtual power plant output optimal allocation module for storing the equivalent natural gas amount is responsible for constructing a virtual power plant output optimal allocation model for storing the equivalent natural gas amount, and outputting a virtual power plant output optimal allocation result required by the unit output reduction amount of the corresponding conversion point according to data submitted by the data module considering the actual maximum output reducible amount of the unit at the electric-gas conversion point, wherein the constructed optimal allocation model is as follows:
an objective function:
constraint conditions are as follows:
wherein, Pv,TRepresents the output of the virtual power plant at time T, Pgr,TRepresenting the actual output, Δ P, of the unit at the transition point at time Tgr,TFor the actual maximum reducible contribution of the unit at the transfer point at time T, Pgr,af,TThe output of the day-ahead unit of the gas turbine at the time of T, Pdr,TThe day-ahead output of other units except the gas unit at the time of T, PLTFor time T grid line flow matrix, PTAnd (4) obtaining a matrix of all unit output at the time T.
8. The system of claim 7, wherein the objective function represents that the output cost of the virtual power plant is the lowest. The constraints of the optimized mathematical model comprise virtual power plant output constraints and transmission network constraints, wherein a formula (13) is used for calculating the actual output of the unit at the time of the conversion point, a constraint (14) is a system power balance constraint, a constraint (15) is a virtual power plant output constraint, a constraint (16) is a power flow equation constraint, a constraint (17) is a system power flow constraint, and a constraint (18) is a region division constraint.
9. The power grid surplus resource consumption system considering gas storage costs according to claim 8, wherein the virtual power plant output optimal allocation scheme module outputs a virtual power plant output optimal allocation scheme for an optimization result of the constructed optimal allocation model.
10. The system of claim 9, wherein the power grid day-ahead scheduling optimization result includes a predetermined output plan of each unit day-ahead and a remaining capacity of a power grid line day-ahead.
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