A method, system, device and storage medium for operating electric power spot market

Abstract

The present invention discloses a method, system, equipment and storage medium for the operation of a power spot market, and relates to the field of power system operation and control. At present, the operation of the power spot market cannot guarantee the smooth transition and stable operation of the system; the present invention includes the steps of: establishing a power spot market declaration model involving the participation of gas-fired combined cycle units, establishing a day-ahead and real-time market clearing model involving gas-fired combined cycle units, and determining the day-ahead market unit combination and the day-ahead and real-time market output plan of the gas-fired power generation unit based on the clearing model. The present invention models the combined unit in the form of a single machine to solve the dependency relationship in the unit modeling method; incorporates the gas turbine quotation into the objective function, and incorporates the output ratio of the internal combustion engine and the steam turbine of the set into the constraint condition, which solves the problem of variable operation modes of the gas-fired combined cycle set; while ensuring the set's participation in the market, the smooth transition and stable operation of the system are achieved, and the safety of power system operation is improved.

Description

Technical Field

[0001] The present invention relates to the field of power system operation and control, and in particular to a method, system, equipment and storage medium for operating a power spot market based on the participation of a gas combined cycle unit. Background Art

[0002] At present, the reform of the power market is in full swing. The units established in the spot market system correspond one-to-one with the physical model units in the SCADA and state estimation of the D5000 system. Market declaration, market clearing and market release are all based on a single unit as the minimum unit. However, in the traditional mode, the combined cycle unit is controlled in the form of a set of units. The start and stop and output of the gas turbine and steam turbine in the combined cycle unit are dependent. The existing market rules cannot handle the dependencies in the modeling of a single unit. At the same time, the combined cycle unit has a variety of operating modes, including two-to-one and two-to-two. If the combined cycle unit operating mode transfer is used to model, the rules, models and optimization algorithms are very complex; and the existing simplified algorithms regard each operating mode of the set as an independent event, which cannot achieve state conversion between different modes and cannot obtain the optimal clearing results. In this context, how to design an electricity spot market operation model that takes into account the participation of gas combined cycle units, minimize the changes in the clearing model, and ensure the smooth transition and stable operation of the system has become an important challenge affecting the safety of power system operation and the economic benefits of power users.

[0003] In the traditional mode, the AGC control unit of the combined cycle unit is a single control unit for the entire plant, that is, it is controlled in a package manner. However, in the power spot market environment, market clearing and market release are based on a single unit as the minimum unit. The deviation in the control method of the combined cycle unit in the traditional mode and the spot environment limits its feasibility of participating in the spot market. It is specifically reflected in the following aspects: First, the spot market system data with a single machine as the minimum unit cannot be directly connected with the AGC system data controlled in a package manner, and data conversion is required in the middle. Second, there are dependencies between the start-up and shutdown and output of the gas turbines and steam turbines in the combined cycle units, and traditional market rules cannot handle the dependencies in the modeling of single units. Third, the operating modes of the units are changeable, with up to seven operating modes. If the combined cycle unit operating mode transfer is used for modeling, that is, declarations and clearing are made for different operating modes separately, the rules, models and optimization algorithms are very complex. The existing simplified algorithm regards each operating mode of the unit as an independent event, that is, only one mode can be selected in each optimization calculation, which is exclusive and cannot achieve state conversion between different modes, nor can it obtain the optimal clearing result. Summary of the invention

[0004] The technical problem to be solved and the technical task proposed by the present invention are to improve and perfect the existing technical solutions, and provide a method, system, device and storage medium for operating the power spot market to ensure the smooth transition and stable operation of the system. To this end, the present invention adopts the following technical solutions.

[0005] A method for operating a power spot market based on participation of a gas combined cycle unit comprises the following steps:

[0006] 1) Based on the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the declaration process, a power spot market declaration model involving gas-fired combined cycle units is established, and the declaration method of gas-fired combined cycle units in the electricity market and frequency regulation market is obtained, so as to realize the same-station bidding of split-shaft gas turbines and coaxial gas turbines;

[0007] 2) Obtain system operation parameter information and market subject declaration parameter information in the power spot market declaration model;

[0008] 3) According to the electricity spot market declaration model of step 1) and the parameter information obtained in step 2), a day-ahead and real-time market clearing model containing gas-fired combined cycle units is established to determine the day-ahead market unit combination and the day-ahead and real-time market output plan containing gas turbine power generation units based on the clearing model; wherein the objective function of the electricity market clearing model is determined based on the declaration method in step 1), and the constraints include system constraints that take the combined cycle gas turbine and steam turbine as decision variables at the same time, unit constraints and network constraints that consider the output ratio relationship between the combined cycle gas turbine and steam turbine, and modeling of unit operation costs; the electricity market clearing model models the combined cycle unit in the form of a single unit, and the unit constraints include unit constraints, and the dependencies in the unit modeling method are resolved through the unit constraints; and the gas turbine quotation is included in the objective function, and the unit output ratio of the unit internal combustion engine and steam turbine is included in the constraint conditions, so as to solve the problem of variable unit operation modes of the gas-fired combined cycle unit;

[0009] 4) Solve the power market clearing model containing gas-fired combined cycle units according to the preset constraints, and obtain the day-ahead market unit combination, output plan and real-time market output plan containing gas turbine power generation units. The real-time market output plan is superimposed with the frequency regulation command and then sent to the gas turbine for execution through the AGC, and the steam turbine follows the gas turbine output at a fixed ratio;

[0010] 5) Calculate according to the day-ahead market output plan, real-time market metering data and preset electricity market settlement model to obtain the benefits of the unit participating in the day-ahead market, the benefits of the real-time market and the benefits of the frequency regulation market, output and display the output plan and benefit data for market players to use in evaluation and decision-making.

[0011] As a preferred technical means: in step 1) including:

[0012] 101) In the electricity market, the start-up, shutdown and output of gas-fired combined cycle split-shaft units are determined by the bids of the gas turbine generation units. The steam turbine generation units do not participate in the bids. The steam turbine follows the output of the gas turbine at a fixed ratio, and the marginal cost of the steam turbine is converted into the bid of the gas turbine. The market bid price of split-shaft gas turbines is set, and its price cap is determined based on the coaxial gas turbine units to ensure that the combined cycle split-shaft gas turbines and coaxial gas turbines can bid on the same platform;

[0013] 102) In the frequency regulation market, only gas turbine power generation units declare frequency regulation mileage price, frequency regulation capacity price and frequency regulation capacity, and steam turbine power generation units do not participate in the declaration.

[0014] As the preferred technical means: in step 3), the objective function is to minimize the cost of purchasing electricity; the unit constraints include upper and lower limit constraints on unit output, unit climbing constraints, minimum continuous start and stop time constraints on the unit, maximum start and stop times constraints on the unit, unit power constraints, and set constraints; the network constraints include line flow constraints and section flow constraints; the unit operating cost modeling includes setting the unit output expression, the unit operating cost expression, and the unit startup cost expression.

[0015] As an optimal technical means: SCUC objective function is:

[0016]

[0017] The SCED objective function is:

[0018]

[0019] in:

[0020] N represents the total number of units;

[0021] T represents the total number of time periods considered. Assuming that 96 time periods are considered in one day, T is 96;

[0022] P i,t represents the output of unit i in period t;

[0023] C i,t (P i,t ), are the operating cost, startup cost and no-load cost of unit i in period t, among which the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to the output ranges declared by the unit and the corresponding energy prices. Only the gas turbine quotation of the package is included in the objective function.

[0024] M is the network power flow constraint relaxation penalty factor used for market clearing optimization. In SCUC, this value is 1×10 8 .

[0025] are the forward and reverse power flow relaxation variables of line l respectively; NL is the total number of lines;

[0026] are the positive and negative flow relaxation variables of section s respectively; NS is the total number of sections.

[0027] As a preferred technical means: in step 3),

[0028] A) System Constraints

[0029] System constraints include load balance constraints, system positive reserve capacity constraints, system negative reserve capacity constraints, and system spinning reserve capacity constraints. The system balance constraints are as follows:

[0030] For each time period t, the load balance constraint expression is:

[0031]

[0032] Among them, S gas represents the set of combustion engines; S steam represents the turbine set; S others Indicates the set of other units; It represents the total output of the gas turbine set in time period t; represents the total output of the steam turbine set in time period t, that is, the steam turbine output is included in the system power generation and consumption balance constraint as a decision variable; represents the total output of all other units in time period t, T j,t represents the planned power of tie line j in time period t, N is the total number of tie lines, D t is the system load during period t, where the output of the steam turbine is included as a decision variable in the system power generation and consumption balance constraint.

[0033] B) Crew Constraints

[0034] The unit constraints include traditional unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start and stop time constraints, unit power constraints and set constraints. The set constraints are as follows:

[0035] The output ratio of the internal combustion engine and the steam turbine is:

[0036]

[0037] Where: S Kit Represents a set of kits; S k represents the set of units in set k; S gas represents the set of combustion engines; S steam represents the turbine set; P i,t represents the output of the gas turbine at time period t, a decision variable; Pi,j,t represents the output of steam turbine j connected to gas turbine i at time period t, a decision variable; R i,t Represents the proportionality coefficient of the engine in period t; R i,j,t It represents the proportional coefficient of steam turbine j connected to gas turbine i during period t.

[0038] The turbine unit output is further expressed as:

[0039]

[0040] When modeling the set of machines, the ratio of the output of the gas turbine to the output of the corresponding steam turbine is provided, and the output of the steam turbine driven by the gas turbine is determined by the output of the gas turbine; then the output of the steam turbine is obtained through the definition of the steam turbine output;

[0041] Since the steam turbine output is also a decision variable and is reflected in the power generation and consumption balance, the steam turbine and the gas turbine participate in the power generation and consumption balance constraint together; since there is no quotation for the steam turbine, its output has no cost, and the output is determined by its proportional relationship with the gas turbine, so it is equivalent to converting the steam turbine output into the gas turbine output. If the set is used as a marginal unit, the system increases the power demand by 1MW, which will be borne by the gas turbine and the steam turbine in proportion, because the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the gas turbine quotation converted according to the output ratio;

[0042] C) Network constraints

[0043] C1) Line flow constraints

[0044] The line power flow constraint expression is:

[0045]

[0046] Among them, P l max is the power transmission limit of line l; G l-i is the generator output power transfer distribution factor of the node where unit i is located to line l; K is the number of nodes in the system; G l-k is the generator output power transfer distribution factor of node k to line l; D k,t is the bus load value of node k in period t. are the forward and reverse power flow slack variables of line l respectively.

[0047] C2) Section flow constraints

[0048] Considering the flow constraints of key sections, the cross-section flow is approximately expressed as:

[0049]

[0050] Among them, P s min , Ps max are the power flow transmission limits of section s; G s-i G is the generator output power transfer distribution factor of the node where unit i is located to section s; s-k is the generator output power transfer distribution factor for node k to section s. are the positive and reverse flow relaxation variables of section s respectively.

[0051] D) Unit operating cost modeling

[0052] D1) Unit output expression

[0053]

[0054]

[0055] Among them, M is the total number of sections of the unit quotation, P i,t,m is the winning bid power of unit i in the mth output interval in period t, They are respectively the upper and lower limits of the mth output range declared by unit i. The turbine output is converted in proportion to the corresponding turbine output.

[0056] D2) Unit operating cost expression

[0057]

[0058] Among them, M is the total number of sections of the unit quotation, C i,t,m It is the energy price corresponding to the mth output segment declared by unit i in period t. The steam turbine does not quote, and its cost is comprehensively reflected in the gas turbine quotation.

[0059] D3) Unit startup cost expression

[0060]

[0061] in, is the single startup cost of unit i.

[0062] As a preferred technical means: in step 5), including:

[0063] 501) The market obtains the unit combination and output plan of the gas turbine according to the optimization calculation. The steam turbine follows the output of the gas turbine at a fixed ratio. The settlement power of the set is the sum of the power of the two, which is the sum of the income of the gas turbine and the steam turbine.

[0064] 502) In the real-time market, the settlement electricity of the package is the actual metered electricity of the gas turbine and steam turbine, and the real-time market revenue of the package is the sum of the revenue of the gas turbine and steam turbine;

[0065] 503) In the frequency regulation market, the frequency regulation capacity benefit and frequency regulation mileage benefit are calculated based on the frequency regulation capacity of the gas turbine in the frequency regulation market, the actual frequency regulation mileage and the comprehensive frequency regulation performance indicators of the gas turbine, and the total frequency regulation benefit of the set is formed after superposition.

[0066] The second object of the present invention is to provide an electricity spot market operation system based on the participation of gas combined cycle units; the electricity spot market operation system comprises:

[0067] Electricity spot market declaration model configuration module: used to solve the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the declaration process, establish an electricity spot market declaration model involving gas-fired combined cycle units, obtain the declaration method of gas-fired combined cycle units in the electricity market and frequency regulation market, and realize the same-station bidding of split-shaft gas turbines and coaxial gas turbines;

[0068] Parameter information acquisition module: used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model;

[0069] A data acquisition module, used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model;

[0070] The power market clearing model configuration module is connected to the power spot market declaration model configuration module and the data acquisition module; it is used to establish a power market clearing model containing gas combined cycle units;

[0071] The power market clearing model solving module is used to solve the power market clearing model containing gas-fired combined cycle units according to preset constraints, and obtain the day-ahead market unit combination, output plan and real-time market output plan containing gas turbine power generation units. The real-time market output plan is superimposed with the frequency regulation instruction and then sent to the gas turbine for execution through the AGC, and the steam turbine follows the gas turbine output at a fixed ratio;

[0072] The power market settlement model solving module is connected to the power market clearing model solving module and is used to calculate based on the day-ahead market output plan, real-time market metering data and the preset power market settlement model to obtain the benefits of the unit participating in the day-ahead market, the benefits of the real-time market and the benefits of the frequency regulation market;

[0073] The display and output module is used to output and display output plans and revenue data.

[0074] As the preferred technical means: in the configuration module of the electricity market clearing model, the objective function and constraints are configured, wherein the objective function is configured to minimize the cost of purchasing electricity; the constraints include system constraints that take the combined cycle gas turbine and steam turbine as decision variables at the same time, unit constraints and network constraints that consider the output ratio of the combined cycle gas turbine and steam turbine, and unit operating cost modeling; the electricity market clearing model models the combined cycle unit in the form of a single unit, and the unit constraints include set constraints, and the dependencies in the unit modeling method are solved through set constraints; and the gas turbine quotation is included in the objective function, and the output ratio of the set internal combustion engine and steam turbine is included in the constraints to solve the problem of variable operation mode of the gas combined cycle unit set; the unit constraints include upper and lower limit constraints on unit output, unit climbing constraints, minimum continuous start and stop time constraints on the unit, maximum start and stop times constraints on the unit, unit power constraints, and set constraints; the network constraints include line flow constraints and section flow constraints; the unit operating cost modeling includes setting unit output expressions, unit operating cost expressions, and unit startup cost expressions.

[0075] The third object of the present invention is to provide a power spot market operation device based on the participation of a gas combined cycle unit, the device comprising a processor and a memory:

[0076] The memory is used to store program code and transmit the program code to the processor;

[0077] The processor is used to execute the electricity spot market operation method based on the participation of gas combined cycle units as described in any one of claims 1-6 according to the instructions in the program code.

[0078] The fourth object of the present invention is to provide a computer-readable storage medium, which is used to store program codes, and the program codes are used to execute the method for operating the electricity spot market based on the participation of gas combined cycle units as described in any one of claims 1-6.

[0079] Beneficial effects:

[0080] 1. This technical solution uses a single machine as the smallest unit when conducting market declaration, market clearing and market release, so as to be consistent with the physical model in the SCADA and state estimation of the D5000 system, and directly interacts with the real-time data of D5000 during the safety verification calculation and market clearing process, avoiding complex data conversion and special processing.

[0081] Second, the dependency problem in the single-unit modeling method is solved by constructing a power spot market declaration model and steam turbines following gas turbine output. The power generation cost of the steam turbine is included in the gas turbine declaration process. At the same time, the steam turbine is one of the decision variables and participates in the power generation and consumption balance constraint together with the gas turbine, which not only ensures the power generation and consumption balance of the power grid, but also ensures that the combined cycle split-shaft gas turbine and the coaxial gas turbine can bid on the same platform.

[0082] 3. By constructing a power market clearing model containing gas-fired combined cycle units, and in the gas-fired combined cycle units, only the gas turbine quotation is included in the objective function. Through the preset proportional relationship between the gas turbine and the steam turbine, the steam turbine output is used as a decision variable to reflect the power generation and consumption balance constraint, which solves the problem of variable operation modes of the gas-fired combined cycle units. For the two-to-two units with seven operating modes, the proposed scheme regards the two gas turbines as two independent units during the optimization calculation, and the steam turbine follows the gas output. By separating the strong coupling relationship between multiple gas turbines and steam turbines in the unit, the seven operating modes of the unit are separately reported and the complex conversion model between them is simplified into an optimization algorithm for two independent units. On the basis of meeting the balance constraint, the optimal unit operation mode is automatically selected through target optimization, which greatly simplifies the model algorithm and avoids the exclusivity of the traditional optimization algorithm that can only select one operating mode a day. BRIEF DESCRIPTION OF THE DRAWINGS

[0083] Figure 1 It is a flow chart of the present invention. DETAILED DESCRIPTION

[0084] The technical solution of the present invention is further described in detail below in conjunction with the accompanying drawings.

[0085] Embodiment 1:

[0086] like Figure 1 As shown, the present invention includes the steps of:

[0087] S1: Based on the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the declaration process, a power spot market declaration model involving gas-fired combined cycle units is established, and the declaration method of gas-fired combined cycle units in the electricity market and frequency regulation market is obtained, so as to realize the same bidding of split-shaft gas turbines and coaxial gas turbines;

[0088] S101: In the electricity market, the start-up, shutdown and output of the gas-fired combined cycle split-shaft unit are determined by the bid of the gas turbine power generation unit. The steam turbine power generation unit does not participate in the bid. The steam turbine follows the output of the gas turbine at a fixed ratio, and the marginal cost of the steam turbine is converted into the bid of the gas turbine. The market bid price of the split-shaft gas turbine is set, and its price cap is determined based on the coaxial gas turbine unit to ensure that the combined cycle split-shaft gas turbine and the coaxial gas turbine can bid on the same platform;

[0089] S102: In the frequency regulation market, only gas turbine power generation units declare the frequency regulation mileage price, frequency regulation capacity price and frequency regulation capacity, and steam turbine power generation units do not participate in the declaration.

[0090] S2: Obtain system operation parameter information and market subject declaration parameter information in the power spot market declaration model;

[0091] S3: According to the electricity spot market declaration model of step S1 and the parameter information obtained in S2, a day-ahead and real-time market clearing model containing gas-fired combined cycle units is established to determine the day-ahead market unit combination and the day-ahead and real-time market output plan containing gas turbine power generation units based on the clearing model; wherein the objective function of the market clearing model is determined based on the declaration method in S1, and the constraints include system constraints that take the combined cycle gas turbine and steam turbine as decision variables at the same time, unit constraints and network constraints that consider the output ratio of the combined cycle gas turbine and steam turbine, and modeling of unit operation costs; the electricity market clearing model models the combined cycle unit in the form of a single unit, and the unit constraints include unit constraints, and the dependencies in the unit modeling method are resolved through unit constraints; and the gas turbine quotation is included in the objective function, and the unit output ratio of the unit internal combustion engine and steam turbine is included in the constraint conditions, so as to solve the problem of variable unit operation modes of the gas-fired combined cycle unit;

[0092] The objective function is to minimize the cost of purchasing electricity; unit constraints include upper and lower limit constraints on unit output, unit climbing constraints, minimum continuous start and stop time constraints, maximum start and stop times constraints, unit power constraints, and set constraints; network constraints include line flow constraints and section flow constraints; unit operating cost modeling includes setting unit output expressions, unit operating cost expressions, and unit startup cost expressions.

[0093] The objective function of the day-ahead market clearing SCUC is:

[0094]

[0095] The objective function of the day-ahead and real-time market clearing SCED is:

[0096]

[0097] in:

[0098] N represents the total number of units;

[0099] T represents the total number of time periods considered. Assuming that 96 time periods are considered in one day, T is 96;

[0100] P i,t represents the output of unit i in period t;

[0101] C i,t (P i,t ), are the operating cost, startup cost and no-load cost of unit i in period t, among which the unit operating cost C i,t (P i,t ) is a multi-segment linear function related to the output ranges declared by the unit and the corresponding energy prices. Only the gas turbine quotation of the package is included in the objective function.

[0102] M is the network power flow constraint relaxation penalty factor used for market clearing optimization. In SCUC, this value is 1×10 8 .

[0103] are the forward and reverse power flow relaxation variables of line l respectively; NL is the total number of lines;

[0104] are the positive and negative flow relaxation variables of section s respectively; NS is the total number of sections.

[0105] A: System constraints

[0106] System constraints include load balance constraints, system positive reserve capacity constraints, system negative reserve capacity constraints, and system spinning reserve capacity constraints. The system balance constraints are as follows:

[0107] For each time period t, the load balance constraint expression is:

[0108]

[0109] Among them, S gas represents the set of combustion engines; S steam represents the turbine set; S others Indicates the set of other units; It represents the total output of the gas turbine set in time period t; represents the total output of the steam turbine set in time period t, that is, the steam turbine output is included in the system power generation and consumption balance constraint as a decision variable; represents the total output of all other units in time period t, T j,t represents the planned power of tie line j in time period t, N is the total number of tie lines, D t is the system load during period t, where the output of the steam turbine is included as a decision variable in the system power generation and consumption balance constraint.

[0110] B: Crew constraints

[0111] The unit constraints include traditional unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start and stop time constraints, unit power constraints and set constraints. The set constraints are as follows:

[0112] The output ratio of the internal combustion engine and the steam turbine is:

[0113]

[0114] Where: S Kit Represents a set of kits; S k represents the set of units in set k; S gas represents the set of combustion engines; S steam represents the turbine set; P i,t represents the output of the gas turbine at time period t, a decision variable; P i,j,t represents the output of steam turbine j connected to gas turbine i at time period t, a decision variable; R i,t Represents the proportionality coefficient of the engine in period t; R i,j,t It represents the proportional coefficient of steam turbine j connected to gas turbine i during period t.

[0115] The turbine unit output is further expressed as:

[0116]

[0117] When modeling the set of machines, the ratio of the output of the gas turbine to the output of the corresponding steam turbine is provided, and the output of the steam turbine driven by the gas turbine is determined by the output of the gas turbine; then the output of the steam turbine is obtained through the definition of the steam turbine output;

[0118] Since the steam turbine output is also a decision variable and is reflected in the power generation and consumption balance, the steam turbine and the gas turbine participate in the power generation and consumption balance constraint together; since there is no quotation for the steam turbine, its output has no cost, and the output is determined by its proportional relationship with the gas turbine, so it is equivalent to converting the steam turbine output into the gas turbine output. If the set is used as a marginal unit, the system increases the power demand by 1MW, which will be borne by the gas turbine and the steam turbine in proportion, because the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the gas turbine quotation converted according to the output ratio;

[0119] C: Network constraints

[0120] C1: Line flow constraints

[0121] The line power flow constraint expression is:

[0122]

[0123] Among them, P l max is the power transmission limit of line l; G l-i is the generator output power transfer distribution factor of the node where unit i is located to line l; K is the number of nodes in the system; G l-k is the generator output power transfer distribution factor of node k to line l; D k,t is the bus load value of node k in period t. are the forward and reverse power flow slack variables of line l respectively.

[0124] C2: Section flow constraints

[0125] Considering the flow constraints of key sections, the cross-section flow is approximately expressed as:

[0126]

[0127] Among them, P s min , P s max are the power flow transmission limits of section s; G s-i G is the generator output power transfer distribution factor of the node where unit i is located to section s; s-k is the generator output power transfer distribution factor for node k to section s. are the positive and reverse flow relaxation variables of section s respectively.

[0128] D: Unit operating cost modeling

[0129] D1: Unit output expression

[0130]

[0131]

[0132] Among them, M is the total number of sections of the unit quotation, P i,t,m is the winning bid power of unit i in the mth output interval in period t, They are respectively the upper and lower limits of the mth output range declared by unit i. The turbine output is converted in proportion to the corresponding turbine output.

[0133] D2: Unit operating cost expression

[0134]

[0135] Among them, M is the total number of sections of the unit quotation, C i,t,m It is the energy price corresponding to the mth output segment declared by unit i in period t. The steam turbine does not quote, and its cost is comprehensively reflected in the gas turbine quotation.

[0136] D3: Unit startup cost expression

[0137]

[0138] in, is the single startup cost of unit i.

[0139] S4: Solve the power market clearing model containing gas-fired combined cycle units according to the preset constraints, obtain the day-ahead market unit combination and power market output plan containing gas turbine power generation units, and form a gas turbine output plan after superimposing the frequency regulation command; send it to the gas turbine for execution through the AGC, and the steam turbine follows the gas turbine output at a fixed ratio;

[0140] S5: Calculate according to the output plan and the preset electricity market settlement model to obtain the benefits of the unit participating in the day-ahead market, the benefits of the real-time market, and the benefits of the frequency regulation market, and display the output plan and benefit data for market players to evaluate and make decisions.

[0141] S501: The market obtains the unit combination and output plan of the gas turbine according to the optimization calculation. The steam turbine follows the output of the gas turbine at a fixed ratio. The settlement power of the set is the sum of the power of the two, which is the sum of the benefits of the gas turbine and the steam turbine.

[0142] S502: In the real-time market, the settlement electricity of the package is the sum of the actual metered electricity of the gas turbine and the steam turbine, and the real-time market revenue of the package is the sum of the revenue of the gas turbine and the steam turbine;

[0143] S503: In the frequency regulation market, the frequency regulation capacity benefit and the frequency regulation mileage benefit are calculated based on the frequency regulation capacity of the gas turbine in the frequency regulation market, the actual frequency regulation mileage and the comprehensive frequency regulation performance index of the gas turbine, and the total frequency regulation benefit of the set is formed after superposition.

[0144] Through the above-mentioned application of this embodiment, the Zhejiang spot market system (including the frequency regulation market) can continue to adopt the single-machine modeling method, and the single machine corresponds to the D5000 system unit model one by one. The declaration, release, clearing, and safety verification calculations of the spot market (including the frequency regulation market) are all based on single machines, and the adjustment of the clearing model is relatively small. The proposed method of operating the power spot market considering the participation of gas combined cycle units proposed by this technical solution, combined with the settlement trial operation data of the Zhejiang power spot market, shows that the proposed solution simplifies the clearing algorithm and improves the efficiency of model solving without affecting the precision and accuracy of the clearing results.

[0145] Embodiment 2:

[0146] A power spot market operation system based on the participation of gas combined cycle units; the power spot market operation system comprises:

[0147] Electricity spot market declaration model configuration module: used to solve the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the declaration process, establish an electricity spot market declaration model involving gas-fired combined cycle units, obtain the declaration method of gas-fired combined cycle units in the electricity market and frequency regulation market, and realize the same-station bidding of split-shaft gas turbines and coaxial gas turbines;

[0148] Parameter information acquisition module: used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model;

[0149] A data acquisition module, used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model;

[0150] The power market clearing model configuration module is connected to the power spot market declaration model configuration module and the data acquisition module; it is used to establish a power market clearing model containing gas combined cycle units;

[0151] The power market clearing model solving module is used to solve the power market clearing model containing gas combined cycle units according to preset constraints, and obtain the day-ahead market unit combination, output plan and real-time market output plan containing gas turbine power generation units. The real-time market output plan is superimposed with the frequency regulation instruction to form the gas turbine output plan; it is sent to the gas turbine for execution through the AGC, and the steam turbine follows the gas turbine output at a fixed ratio;

[0152] The power market settlement model solving module is connected to the power market clearing model solving module and is used to calculate according to the day-ahead market output plan, real-time market metering data and the preset power market settlement model to obtain the benefits of the unit participating in the day-ahead market, the benefits of the real-time market and the benefits of the frequency regulation market;

[0153] The display and output module is used to output and display output plans and revenue data.

[0154] Among them, in the configuration module of the electricity market clearing model, the objective function and constraints are configured, wherein the objective function is to minimize the cost of purchasing electricity; the constraints include system constraints that take combined cycle gas turbines and steam turbines as decision variables at the same time, unit constraints and network constraints that consider the output ratio of combined cycle gas turbines and steam turbines, and unit operating cost modeling; the electricity market clearing model models the combined cycle unit in the form of a single unit, and the unit constraints include set constraints, and the dependencies in the unit modeling method are solved through set constraints; and the gas turbine quotation is included in the objective function, and the output ratio of the set internal combustion engine and steam turbine is included in the constraints to solve the problem of variable operation mode of the gas combined cycle unit set; the unit constraints include upper and lower limit constraints on unit output, unit climbing constraints, minimum continuous start and stop time constraints on the unit, maximum number of start and stop times constraints on the unit, unit power constraints, and set constraints; the network constraints include line flow constraints and section flow constraints; the unit operating cost modeling includes setting unit output expressions, unit operating cost expressions, and unit startup cost expressions.

[0155] Embodiment three:

[0156] A power spot market operation device based on the participation of a gas combined cycle unit, the device comprising a processor and a memory:

[0157] The memory is used to store program code and transmit the program code to the processor;

[0158] The processor is used to execute the aforementioned method for operating the electricity spot market based on the participation of gas combined cycle units according to the instructions in the program code.

[0159] Embodiment 4:

[0160] A computer-readable storage medium is used to store program codes, wherein the program codes are used to execute the aforementioned method for operating a power spot market based on the participation of a gas combined cycle unit.

[0161] above Figure 1 The method and device for modeling the operation of the electricity spot market based on the participation of a gas combined cycle unit shown is a specific embodiment of the present invention, which has embodied the substantial characteristics and progress of the present invention. According to actual use needs and under the guidance of the present invention, equivalent modifications in shape, structure, etc. can be made to it, which are all within the protection scope of this scheme.

Claims

1. A method for operating a power spot market based on the participation of gas combined cycle units, characterized in that The following steps are involved: 1) Based on the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the application process, a power spot market application model involving gas-fired combined cycle units is established, and the application method of gas-fired combined cycle units in the electricity market and frequency regulation market is obtained, so as to realize the same bidding of split-shaft gas turbines and co-shaft gas turbines; 2) Obtain system operation parameter information and market subject declaration parameter information in the power spot market declaration model; 3) According to the electricity spot market declaration model of step 1) and the parameter information obtained in step 2), a day-ahead and real-time market clearing model containing gas-fired combined cycle units is established to determine the day-ahead market unit combination and the day-ahead and real-time market output plan containing gas turbine power generation units based on the clearing model; wherein the objective function of the market clearing model is determined based on the declaration method in step 1), and the constraints include system constraints that take the combined cycle gas turbine and steam turbine as decision variables at the same time, unit constraints and network constraints that consider the output ratio of the combined cycle gas turbine and steam turbine, and modeling of unit operation costs; the electricity market clearing model models the combined cycle unit in the form of a single unit, and the unit constraints include unit constraints, and the dependencies in the unit modeling method are resolved through unit constraints; and the gas turbine quotation is included in the objective function, and the unit output ratio of the internal combustion engine and steam turbine is included in the constraint conditions to solve the problem of variable unit operation modes of the gas-fired combined cycle unit; 4) Solve the market clearing model containing gas-fired combined cycle units according to the preset constraints to obtain the day-ahead market unit combination, day-ahead output plan and real-time market output plan containing gas turbine power generation units. The real-time market output plan is superimposed with the frequency regulation command and then sent to the gas turbine for execution through the AGC. The steam turbine follows the gas turbine output at a fixed ratio. 5) Calculate the revenue of the unit participating in the day-ahead market, the revenue of the real-time market and the frequency regulation market based on the day-ahead market output plan, real-time market metering data and the preset power market settlement model, and output and display the output plan and revenue data for market players to evaluate and make decisions; In step 1) include: 101) In the electricity market, the start-up, shutdown and output of the gas combined cycle split-shaft unit are determined by the bid of the gas turbine power generation unit. The steam turbine power generation unit does not participate in the bid. The steam turbine follows the output of the gas turbine at a fixed ratio, and the marginal cost of the steam turbine is converted into the bid of the gas turbine. The market bid price of the split-shaft gas turbine is set, and its price cap is determined based on the coaxial gas turbine unit to ensure that the split-shaft gas turbine and the coaxial gas turbine can bid on the same platform; 102) In the frequency regulation market, only gas turbine power generation units shall declare the frequency regulation mileage price, frequency regulation capacity price and frequency regulation capacity, and steam turbine power generation units shall not participate in the declaration; In step 3), the objective function is to minimize the cost of electricity purchase; unit constraints include upper and lower limits of unit output, unit ramp constraints, minimum continuous start and stop time constraints, maximum start and stop times constraints, unit power constraints, and set constraints; network constraints include line flow constraints and section flow constraints; unit operation cost modeling includes setting unit output expressions, unit operation cost expressions, and unit startup cost expressions; In step 3), A) System Constraints System constraints include load balance constraints, system positive reserve capacity constraints, system negative reserve capacity constraints, and system spinning reserve capacity constraints. The system balance constraints are as follows: For each period , the load balance constraint expression is: in, represents a collection of combustion engines; represents a steam turbine set; Indicates the set of other units; Indicates that the gas turbines are assembled in the time period Total output of represents the total output of the steam turbine set in time period t, that is, the steam turbine output is included in the system power generation and consumption balance constraint as a decision variable; Indicates that all other units in the period The total output of Indicates contact line j In the period t The planned power, N is the total number of tie lines, for System load during the time period; B) Crew Constraints The unit constraints include traditional unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start and stop time constraints, unit power constraints and set constraints. The set constraints are as follows: The output ratio of the internal combustion engine and the steam turbine is: in: Represents a kit collection; Indicates the kit Internal unit collection; represents a collection of combustion engines; represents a steam turbine set; Indicates the engine Time The output of , the decision variable; Indicates the engine Mounted steam engine Time The output of , the decision variable; Indicates the engine Time The proportionality coefficient of Indicates the engine Mounted steam engine Time The proportionality coefficient of The turbine unit output is further expressed as: When modeling the set of machines, the ratio of the output of the gas turbine to the output of the corresponding steam turbine is provided, and the output of the steam turbine driven by the gas turbine is determined by the output of the gas turbine; then the output of the steam turbine is obtained through the definition of the steam turbine output; Since the steam turbine output is also a decision variable and is reflected in the power generation and consumption balance, the steam turbine and the gas turbine participate in the power generation and consumption balance constraint together; since there is no quotation for the steam turbine, its output has no cost, and the output is determined by its proportional relationship with the gas turbine, so it is equivalent to converting the steam turbine output into the gas turbine output; if the set is used as a marginal unit, the system increases the power demand by 1MW, which will be borne by the gas turbine and the steam turbine in proportion, because the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the gas turbine quotation converted according to the output ratio; C) Network constraints C1) Line flow constraints The line power flow constraint expression is: in, For Line The power flow transmission limit of For the crew Node to line The generator output power transfer distribution factor; is the number of nodes in the system; For Node To line The generator output power transfer distribution factor; For Node exist Bus load value of the time period; , Line Forward and reverse power flow relaxation variables; C2) Section flow constraints Considering the flow constraint of the key section, the flow constraint expression of the section is: in, , Section The power flow transmission limit of For the crew Node section The generator output power transfer distribution factor; For Node Cross-section The generator output power transfer distribution factor; , Section Forward and reverse power flow relaxation variables; D) Unit operating cost modeling D1) Unit output expression in, The total number of sections quoted for the unit, For the crew exist Time period The winning bid power in the output range, , The first The upper and lower limits of the output range, the turbine output is converted in proportion to the corresponding turbine output; D2) Unit operating cost expression in, The total number of sections quoted for the unit, For the crew exist The first time period reported The energy price corresponding to each output segment is not quoted for steam turbines, but its cost is comprehensively reflected in the quote for gas turbines. D3) Unit startup cost expression in, For the crew One-time startup fee; In step 5), include: 501) The market obtains the unit combination and output plan of the gas turbine based on the optimization calculation. The steam turbine follows the output of the gas turbine at a fixed ratio. The settlement power of the set is the sum of the power of the two, which is the sum of the income of the gas turbine and the steam turbine. 502) In the real-time market, the settlement electricity of the package is the sum of the actual metered electricity of the gas turbine and the steam turbine, and the real-time market revenue of the package is the sum of the revenue of the gas turbine and the steam turbine; 503) In the frequency regulation market, the frequency regulation capacity benefit and frequency regulation mileage benefit are calculated separately based on the frequency regulation capacity won by the gas turbine in the frequency regulation market, the actual frequency regulation mileage and the comprehensive frequency regulation performance indicators of the gas turbine, and the total frequency regulation benefit of the set is formed after superposition.

2. The method for operating a power spot market based on participation of a gas-fired combined cycle unit according to claim 1, characterized in that: The objective function of the day-ahead market clearing SCUC is: The objective function of the day-ahead and real-time market clearing SCED is: in: Indicates the total number of units; represents the total number of time periods considered; Indicates the unit exist Output during the time period; , , For each unit In the period The operating costs, startup costs and no-load costs of the unit It is a multi-segment linear function related to the output ranges reported by the unit and the corresponding energy prices. Only the gas turbine quotation of the package is included in the objective function. is the network power constraint relaxation penalty factor used for market clearing optimization. The value is 1 in SCUC. ; , Line l Forward and reverse power flow relaxation variables; is the total number of lines; , Section s Forward and reverse power flow relaxation variables; The total number of sections.

3. A power spot market operation system using a power spot market operation method based on gas combined cycle units as described in claim 1, characterized in that include: Electricity spot market declaration model configuration module: used to solve the problem of different cost switching under different operating modes of gas-fired combined cycle split-shaft units in the declaration process, establish an electricity spot market declaration model involving gas-fired combined cycle units, obtain the declaration method of gas-fired combined cycle units in the electricity market and frequency regulation market, and realize the same-station bidding of split-shaft gas turbines and coaxial gas turbines; Parameter information acquisition module: used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model; A data acquisition module, used to obtain system operation parameter information and market member declaration parameter information in the power spot market declaration model; The power market clearing model configuration module is connected to the power spot market declaration model configuration module and the data acquisition module; it is used to establish a power market clearing model containing gas combined cycle units; The power market clearing model solving module is used to solve the power market clearing model containing gas-fired combined cycle units according to preset constraints, and obtain the day-ahead market unit combination, output plan and real-time market output plan containing gas turbine power generation units. The real-time market output plan is superimposed with the frequency regulation instruction and then sent to the gas turbine for execution through the AGC, and the steam turbine follows the gas turbine output at a fixed ratio; The power market settlement model solving module is connected to the power market clearing model solving module and is used to calculate according to the day-ahead market output plan, real-time market metering data and the preset power market settlement model to obtain the benefits of the unit participating in the day-ahead market, the benefits of the real-time market and the benefits of the frequency regulation market; The display and output module is used to output and display output plans and revenue data.

4. The power spot market operation system according to claim 3, characterized in that: In the configuration module of the power market clearing model, the objective function and constraints are configured, where the objective function is to minimize the cost of purchasing electricity; the constraints include system constraints that take the combined cycle gas turbine and steam turbine as decision variables at the same time, unit constraints and network constraints that consider the output ratio of the combined cycle gas turbine and steam turbine, and unit operation cost modeling; the power market clearing model models the combined cycle unit as a single unit, and the unit constraints include set constraints, and the dependencies in the unit modeling method are resolved through the set constraints; The gas turbine quotation is included in the objective function, and the output ratio of the internal combustion engine and steam turbine of the unit is included in the constraint conditions to solve the problem of changeable operation modes of the gas combined cycle unit set; the unit constraints include the upper and lower limit constraints of the unit output, the unit climbing constraints, the minimum continuous start and stop time constraints of the unit, the maximum number of start and stop times of the unit, the unit power constraints, and the unit constraints; the network constraints include line flow constraints and section flow constraints; the unit operating cost modeling includes setting the unit output expression, the unit operating cost expression, and the unit startup cost expression.

5. An electric power spot market operation device based on the participation of gas combined cycle units, characterized in that: The device comprises a processor and a memory: The memory is used to store program code and transmit the program code to the processor; The processor is used to execute the electricity spot market operation method based on the participation of gas combined cycle units as described in claim 1 or 2 according to the instructions in the program code.

6. A computer-readable storage medium, characterized in that: The computer-readable storage medium is used to store program code, and the program code is used to execute the method for operating an electricity spot market based on the participation of a gas combined cycle unit as described in any one of claims 1 or 2.

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