CN114912785A - Electric power spot market operation method, system, equipment and storage medium - Google Patents
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Abstract
The invention discloses a method, a system, equipment and a storage medium for operating a power spot market, and relates to the field of operation and control of a power system. The current electric power spot market operation can not ensure the stable transition and stable operation of the system; the invention comprises the following steps: the method comprises the steps of establishing an electric power spot market declaration model with participation of a gas combined cycle unit, establishing day-ahead and real-time market clearing models with the gas combined cycle unit, and determining a day-ahead market unit combination with a gas turbine power generation unit and a day-ahead and real-time market output plan based on the clearing models. The invention models the combined unit according to a single-unit mode, and solves the dependency relationship in the unit modeling mode; the quotation of the gas turbine is brought into a target function, the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, and the problem of variable operation modes of the combined cycle unit of the gas turbine is solved; when the complete machine is guaranteed to participate in the market, the stable transition and stable operation of the system are achieved, and the operation safety of the power system is improved.
Description
Technical Field
The invention relates to the field of operation and control of power systems, in particular to a method, a system, equipment and a storage medium for operating a power spot market based on participation of a gas combined cycle unit.
Background
At present, the complete development of the electric power market reform is realized, the set established in the current spot market system corresponds to the SCADA in the D5000 system and the physical model set in the state estimation one by one, and the market declaration, the market clearing and the market release all use a single machine as the minimum unit. However, in the conventional mode, the combined cycle unit is controlled in a complete unit mode, the starting, stopping and output of a combustion engine and a steam engine in the combined cycle unit have dependency relationships, and the existing market rules cannot process the dependency relationships in a single unit modeling mode. Meanwhile, the operation modes of the combined cycle unit are variable, multiple operation modes of two-driving-one, two-driving-two and the like exist, and if the combined cycle unit operation mode is transferred to be modeled, the rules, the models and the optimization algorithm are very complex; however, in the existing simplified algorithm, each operation mode of the set machine is regarded as an independent event, so that state conversion among different modes cannot be realized, and an optimal clearing result cannot be obtained. Under the background, how to design an electric power spot market operation model considering participation of the gas combined cycle unit minimizes output model change, ensures stable transition and stable operation of the system, and becomes an important challenge influencing operation safety of an electric power system and economic benefit of an electric power user.
In a traditional mode, an AGC control unit of the combined cycle unit is a control unit of the whole plant, namely, the AGC control unit is controlled in a set machine mode. However, in the electric power spot market environment, both market clearing and market distribution are the smallest units with a single machine. The deviation of the traditional mode and the control mode of the combined cycle unit in the spot-cargo environment limits the feasibility of participating in the spot-cargo market. The method is embodied in the following aspects: firstly, the data of the spot market system which takes a single machine as the minimum unit cannot be directly butted with the data of the AGC system which is controlled in a set machine mode, and the data conversion is needed in the middle. Secondly, the starting, stopping and output of a gas turbine and a steam turbine in the combined cycle unit are all dependent, and the traditional market rules cannot process the dependent relation in a single unit modeling mode; thirdly, the operation mode of the set machine is changeable, seven operation modes can be generated at most, if the combined cycle set operation mode is adopted for modeling, declaration and clearing are respectively carried out aiming at different operation modes, and the rules, the models and the optimization algorithm are very complex; however, in the existing simplified algorithm, each operation mode of the set of machines is regarded as an independent event, that is, only one mode can be selected during each optimization calculation, and the algorithm has exclusivity, cannot perform state conversion among different modes, and cannot obtain an optimal clearing result.
Disclosure of Invention
The technical problem to be solved and the technical task to be solved by the invention are to perfect and improve the prior technical scheme, and provide a power spot market operation method, a system, equipment and a storage medium so as to ensure the purposes of stable transition and stable operation of the system. Therefore, the invention adopts the following technical scheme.
A power spot market operation method based on participation of a gas combined cycle unit comprises the following steps:
1) based on the problem of switching different costs of the gas combined cycle split-shaft unit under different operation modes in a reporting link, establishing a power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
2) acquiring system operation parameter information and market subject declaration parameter information in the electric power spot market declaration model;
3) establishing a day-ahead and real-time market clearing model containing a gas combined cycle unit according to the electric power spot market declaration model in the step 1) and the parameter information obtained in the step 2), and determining a day-ahead market unit combination containing a gas turbine power generation unit and a day-ahead and real-time market clearing plan based on the clearing model; the method comprises the following steps that 1), an objective function of a power market clearing model is determined based on a declaration mode in step 1), and constraint conditions comprise system constraint taking a combined cycle gas turbine and a steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, so that the problem of variable operation modes of the combined cycle unit of the gas turbine is solved;
4) solving an electric power market clearing model containing a gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing a gas turbine power generation unit, an output plan and a real-time market output plan, wherein the real-time market output plan is issued to a gas turbine for execution through AGC after being superposed with a frequency modulation instruction, and the gas turbine follows the output of the gas turbine according to a fixed proportion;
5) and calculating according to the day-ahead market output plan, the real-time market metering data and a preset electric power market settlement model, obtaining the income of the day-ahead market, the income of the real-time market and the income of the frequency modulation market, and outputting and displaying the output plan and the income data so as to be used for market subject evaluation decision.
As a preferable technical means: in step 1) comprises:
101) in the electric energy market, the gas combined cycle split-shaft unit determines starting, stopping and output through quotation of a gas turbine power generation unit, a gas turbine power generation unit does not participate in quotation, a gas turbine follows the output of the gas turbine according to a fixed proportion, and the marginal cost of the gas turbine is converted into the quotation of the gas turbine; setting the gas turbine market declaration price of the split-axis gas turbine, wherein the upper price limit of the split-axis gas turbine is determined based on the coaxial gas turbine set so as to ensure that the combined cycle split-axis gas turbine and the coaxial gas turbine can bid on the same station;
102) in the frequency modulation market, only the gas turbine power generation unit reports the frequency modulation mileage price, the frequency modulation capacity price and the frequency modulation capacity, and the steam turbine power generation unit does not participate in reporting.
As a preferable technical means: in step 3), the objective function is minimization of electricity purchase cost; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
As a preferable technical means: the SCUC objective function is:
the SCED objective function is:
wherein:
n represents the total number of the units;
t represents the total number of considered time periods, and assuming 96 time periods are considered in one day, T is 96;
P i,t representing the output of the unit i in the time period t;
C i,t (P i,t )、
respectively the running cost, the starting cost and the no-load cost of the unit i in the time period t, wherein the unit running cost C i,t (P i,t ) The method is a multi-segment linear function related to each segment of output interval declared by a set and the corresponding energy price, and the set only brings the combustion engine quoted price into an objective function.
M is a network flow constraint relaxation penalty factor for market clearing optimization, and the value in SCUC is 1 multiplied by 10 8 。
As a preferable technical means: in the step 3) of the process,
A) system constraints
The system constraints comprise a load balancing constraint, a system positive spare capacity constraint, a system negative spare capacity constraint and a system rotating spare capacity constraint, and the system balancing constraint comprises the following steps:
for each time period t, the load balancing constraint expression is:
wherein S is gas Representing a set of combustion engines; s steam Representing a steam turbine set; s others Representing other unit sets;
representing the total output of the combustion engine set in the time period t;
representing the total output of the steam turbine set in the time period t, namely the steam turbine output is taken as a decision variable and is included in the system electricity utilization balance constraint;
represents the total output of all other units in the time period T, T j,t Represents the planned power of the tie j during the time period t, N is the total number of ties, D t And the system load is the t period, wherein the output force of the steam turbine is taken as a decision variable and is included in the system utilization electric balance constraint.
B) Unit restraint
The unit constraint comprises traditional unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit electric quantity constraint and set constraint, wherein the set constraint is as follows:
the output proportional relation of the internal combustion engine and the steam turbine of the complete machine is as follows:
wherein: s Kit Representing a set of machines; s k Representing a set of units in the set machine k; s gas Representing a collection of combustion engines; s steam Representing a steam turbine set; p i,t Representing the output of the combustion engine in the time t and deciding variables; p i,j,t Representing the output of a steam turbine j connected with a combustion engine i in a time period t, and deciding a variable; r i,t A proportionality coefficient representing a period t of the combustion engine i; r i,j,t And the proportionality coefficient of a period t of a steam turbine j connected with the combustion engine i is shown.
The steam turbine set output is further expressed as:
when the complete machine is modeled, the output of the combustion engine is provided with the output proportion of the corresponding steam turbine, and the output of the steam turbine carried by the combustion engine is determined by the output of the combustion engine; then the output of the steam turbine is obtained through the definition of the output of the steam turbine;
because the output of the steam turbine is also a decision variable and is reflected in the distribution electric balance, the steam turbine and the combustion engine participate in the distribution electric balance constraint together; the steam engine has no price, so the output of the steam engine has no cost, and the output is determined by the proportional relation of the output and the combustion engine, so the output of the steam engine is equivalent to the output of the combustion engine converted into the output of the combustion engine. If the set of machines are used as marginal machine sets, the power demand of 1MW is increased by the system, the gas turbine and the steam turbine are adopted according to the proportion, and the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the quotation of the gas turbine and is converted according to the output ratio;
C) network constraints
C1) Line flow constraint
The line power flow constraint expression is as follows:
wherein, P l max Is the tidal current transmission limit of line l; g l-i Outputting a power transfer distribution factor for a generator of a line l by a node where a unit i is located; k is the number of nodes of the system; g l-k A generator output power transfer distribution factor for node k to line l; d k,t Is the bus load value of node k in the period t.
Respectively, the positive and reverse power flow relaxation variables of the line l.
C2) Cross section tidal current restraint
Considering the tidal current constraint of the key section, the section tidal current constraint expression is as follows:
wherein, P s min 、P s max Respectively the tidal current transmission limit of the section s; g s-i The generator output power of the section s is transferred to a distribution factor for the node where the unit i is located; g s-k And the distribution factor of the output power transfer of the generator is the node k to the section s.
Respectively the positive and reverse tide relaxation variables of the section s.
D) Modeling of unit operating cost
D1) Unit output expression
Wherein M is the total number of the sections quoted by the unit, P i,t,m The winning power of the unit i in the mth output interval in the t period is shown,
and (4) converting the output of the steam turbine into the output of the corresponding steam turbine in equal proportion according to the upper and lower boundaries of the m-th output interval declared by the unit i.
D2) Unit operation cost expression
Wherein M is the total number of the sections quoted by the unit, C i,t,m And (4) the energy price corresponding to the mth output subsection declared by the unit i in the t period is not quoted by the steam turbine, and the cost synthesis of the steam turbine is present in the quoted price of the combustion engine.
D3) Unit starting cost expression
Wherein,
is the single start-up cost of unit i.
As a preferable technical means: in step 5), the method comprises the following steps:
501) the method comprises the following steps that the unit combination and the output plan of the gas turbine are obtained by the market in the day ahead according to optimization calculation, the gas turbine follows the output of the gas turbine according to a fixed proportion, and the settlement electric quantity of the set of gas turbine is the sum of the electric quantities of the set of gas turbine and the gas turbine and is the sum of the profits of the gas turbine and the gas turbine;
502) in the real-time market, the settlement electric quantity of the complete machine is the actual metering electric quantity of the gas turbine and the steam turbine, and the real-time market income of the complete machine is the sum of the income of the gas turbine and the steam turbine;
503) in the frequency modulation market, the gain of the frequency modulation capacity and the gain of the frequency modulation mileage are respectively calculated based on the winning frequency modulation capacity, the actual frequency modulation mileage and the comprehensive frequency modulation performance index of the gas turbine in the frequency modulation market, and the total frequency modulation gain of the gas turbine is formed after superposition.
The second purpose of the invention is to provide an electric power spot market operation system based on participation of a gas combined cycle unit; the electric power spot market operation system comprises:
the electric power spot market declares the model configuration module: the method is used for solving the problem of different cost switching under different operation modes of the gas combined cycle split-shaft unit in a reporting link, establishing an electric power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
a parameter information acquisition module: the system is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the data acquisition module is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the electric power market clearing model configuration module is connected with the electric power spot market declaration model configuration module and the data acquisition module; the method is used for establishing an electric power market clearing model of the combined cycle unit containing the gas;
the electric power market clearing model solving module is used for solving an electric power market clearing model containing the gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing the gas turbine power generation unit, an output plan and a real-time market output plan, wherein the real-time market output plan is issued to the gas turbine for execution through AGC after being superposed with a frequency modulation instruction, and the gas turbine follows the output of the gas turbine according to a fixed proportion;
the electric power market settlement model solving module is connected with the electric power market settlement model solving module and used for calculating a future market contribution plan, real-time market metering data and a preset electric power market settlement model to obtain the income of the future market, the income of the real-time market and the income of the frequency modulation market of the complete machine;
and the display and output module is used for outputting and displaying the output plan and the income data.
As a preferable technical means: in the electric power market clearing model configuration module, configuring an objective function and constraint conditions, wherein the objective function is the minimization of the electricity purchasing cost; the constraint conditions comprise system constraint taking the combined cycle gas turbine and the steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, so that the problem of variable operation modes of the combined cycle unit of the gas turbine is solved; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
It is a third object of the present invention to provide an electric power spot market operating apparatus based on participation of a gas combined cycle plant, the apparatus comprising a processor and a memory:
the memory is used for storing program codes and transmitting the program codes to the processor;
the processor is used for executing the electric power spot market operation method based on participation of the gas combined cycle unit according to any one of claims 1-6 according to instructions in the program code.
A fourth object of the present invention is to provide a computer readable storage medium for storing a program code for executing a method for operating a power spot market based on participation of a gas combined cycle plant according to any one of claims 1 to 6.
Has the advantages that:
when the technical scheme is used for market declaration, market clearing and market release, a single machine is taken as a minimum unit to keep consistency with an SCADA (supervisory control and data acquisition) in a D5000 system and a physical model in state estimation, and the single machine directly interacts with D5000 real-time data in the processes of security check calculation and market clearing, so that complex data conversion and special processing are avoided.
And secondly, solving the problem of dependence in a single unit modeling mode through the constructed electric power spot market declaration model and the output of the gas turbine following the combustion engine. The power generation cost of the steam turbine is converted in the process of reporting the combustion engine, and meanwhile, the steam turbine is used as one of decision variables and participates in distribution and utilization balance constraint together with the combustion engine, so that the distribution and utilization balance of a power grid is guaranteed, and the combined cycle split-shaft combustion engine and the coaxial combustion engine can bid on the same station.
And thirdly, a model is obtained through the constructed power market containing the gas combined cycle unit, only the gas turbine quotation is brought into an objective function in the gas combined cycle unit, and the output of a steam turbine is taken as a decision variable to be reflected in a service electric balance constraint through a preset proportional relation between the gas turbine and the steam turbine, so that the problem of variable running modes of a complete machine of the gas combined cycle unit is solved. For a two-drive-two set machine with seven operation modes, the two combustion engines are regarded as two independent machine sets during optimization calculation, the steam turbine outputs power along with gas, a strong coupling relation among a plurality of combustion engine steam turbines in the set machine is separated, seven operation modes of the set machine are independently declared and a complex conversion model among the seven operation modes is simplified into an optimization algorithm of the two independent machine sets, an optimal set machine operation mode is automatically selected through target optimization on the basis of meeting balance constraint, the model algorithm is greatly simplified, and the exclusivity that only one operation mode can be selected by a traditional optimization algorithm in one day is avoided.
Drawings
FIG. 1 is a flow chart of the present invention.
Detailed Description
The technical scheme of the invention is further explained in detail by combining the drawings in the specification.
The first embodiment is as follows:
as shown in fig. 1, the present invention comprises the steps of:
s1: based on the problem of switching different costs of the gas combined cycle split-shaft unit under different operation modes in a reporting link, establishing a power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
s101: in the electric energy market, the gas combined cycle split-shaft unit determines starting, stopping and output through quotation of a gas turbine power generation unit, a gas turbine power generation unit does not participate in quotation, a gas turbine follows the output of the gas turbine according to a fixed proportion, and the marginal cost of the gas turbine is converted into the quotation of the gas turbine; setting the gas turbine market declaration price of the split-axis gas turbine, wherein the upper price limit of the split-axis gas turbine is determined based on the coaxial gas turbine set so as to ensure that the combined cycle split-axis gas turbine and the coaxial gas turbine can bid on the same station;
s102: in the frequency modulation market, only the gas turbine power generation unit reports the frequency modulation mileage price, the frequency modulation capacity price and the frequency modulation capacity, and the steam turbine power generation unit does not participate in reporting.
S2: acquiring system operation parameter information and market subject declaration parameter information in the electric power spot market declaration model;
s3: establishing a day-ahead and real-time market clearing model containing a gas combined cycle unit according to the electric power spot market declaration model in the step S1 and the parameter information obtained in the step S2, and determining a day-ahead market unit combination containing a gas turbine power generation unit and a day-ahead and real-time market clearing plan based on the clearing model; the target function of the market clearing model is determined based on a declaration mode in S1, and the constraint conditions comprise system constraint taking a combined cycle gas turbine and a steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, so that the problem of variable operation modes of the combined cycle unit of the gas turbine is solved;
the objective function is the minimization of the electricity purchasing cost; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
The objective function of the future market clearing SCUC is as follows:
the objective function for day-ahead and real-time market clearing SCED is:
wherein:
n represents the total number of the units;
t represents the total number of considered time periods, and assuming 96 time periods are considered in one day, T is 96;
P i,t representing the output of the unit i in the time period t;
C i,t (P i,t )、
respectively the running cost, the starting cost and the no-load cost of the unit i in the time period t, wherein the unit running cost C i,t (P i,t ) The method is a multi-segment linear function related to each segment of output interval declared by a set and the corresponding energy price, and the set only brings the combustion engine quoted price into an objective function.
M is a network flow constraint relaxation penalty factor for market clearing optimization, and the value in SCUC is 1 multiplied by 10 8 。
A: system constraints
The system constraints comprise a load balancing constraint, a system positive spare capacity constraint, a system negative spare capacity constraint and a system rotating spare capacity constraint, and the system balancing constraint comprises the following steps:
for each time period t, the load balancing constraint expression is:
wherein S is gas Representing a set of combustion engines; s steam Representing a steam turbine set; s others Representing other unit sets;
representing the total output of the combustion engine set in the time period t;
representing the total output of the steam turbine set in the time period t, namely the steam turbine output is taken as a decision variable and is included in the system electricity utilization balance constraint;
representing the total output, T, of all other units during time period T j,t Representing the planned power of the tie j during the time period t, N being the total number of ties, D t And the system load is the t period, wherein the output force of the steam turbine is taken as a decision variable and is included in the system utilization electric balance constraint.
B: unit restraint
The unit constraint comprises traditional unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit electric quantity constraint and set constraint, wherein the set constraint is as follows:
the output proportional relation of the internal combustion engine and the steam turbine of the complete machine is as follows:
wherein: s Kit Representing a set of machines; s. the k Representing a set of units in the set machine k; s gas Representing a set of combustion engines; s steam Representing a steam turbine set; p i,t Representing the output of the combustion engine in the time t and deciding variables; p i,j,t Representing the output of a steam turbine j connected with the combustion engine i in a time period t, and deciding a variable; r i,t A proportionality coefficient representing a period t of the combustion engine i; r i,j,t And the proportionality coefficient of a period t of a steam turbine j connected with the combustion engine i is shown.
The steam turbine set output is further expressed as:
when the complete machine is modeled, the output of the combustion engine is provided with the output proportion of the corresponding steam turbine, and the output of the steam turbine carried by the combustion engine is determined by the output of the combustion engine; then the output force of the steam turbine is obtained through the definition of the output force of the steam turbine;
because the output of the steam turbine is also a decision variable and is reflected in the distribution electric balance, the steam turbine and the combustion engine participate in the distribution electric balance constraint together; the steam engine has no price, so the output of the steam engine has no cost, and the output is determined by the proportional relation of the output and the combustion engine, so the output of the steam engine is equivalent to the output of the combustion engine converted into the output of the combustion engine. If the set of machine is used as a marginal machine set, the power demand of 1MW is increased by the system, the gas turbine and the steam turbine bear the power demand in proportion, and the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the conversion of the gas turbine quotation according to the output ratio;
c: network constraints
C1: line flow constraint
The line power flow constraint expression is as follows:
wherein, P l max Is the tidal current transmission limit of line l; g l-i Outputting a power transfer distribution factor for a generator of a line l by a node where a unit i is located; k is the number of nodes of the system; g l-k A generator output power transfer distribution factor for node k to line l; d k,t Is the bus load value of node k in the period t.
Respectively, the positive and reverse power flow relaxation variables of the line l.
C2: cross section tidal current restraint
Considering the tidal current constraint of the key section, the section tidal current constraint expression is as follows:
wherein, P s min 、P s max Respectively the tidal current transmission limit of the section s; g s-i The generator output power of the section s is transferred to a distribution factor for the node where the unit i is located; g s-k The generator output power transfer distribution factor is node k to section s.
Respectively the positive and reverse tide relaxation variables of the section s.
D: modeling of unit operating cost
D1: unit output expression
Wherein M is the total number of the sections quoted by the unit, P i,t,m The winning power of the unit i in the mth output interval in the t period is shown,
and (4) converting the output of the steam turbine into the output of the corresponding steam turbine in equal proportion according to the upper and lower boundaries of the m-th output interval declared by the unit i.
D2: unit operation cost expression
Wherein M is the total number of the sections quoted by the unit, C i,t,m And (4) the energy price corresponding to the mth output subsection declared by the unit i in the t period is not quoted by the steam turbine, and the cost synthesis of the steam turbine is present in the quoted price of the combustion engine.
D3: unit starting cost expression
Wherein,
for a single start-up of unit i.
S4: solving an electric power market clearing model containing a gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing a gas turbine power generation unit and an electric energy market output plan, and forming the gas turbine output plan after superimposing a frequency modulation instruction; the power is transmitted to a gas turbine to be executed through AGC, and the gas turbine outputs power along with the gas turbine according to a fixed proportion;
s5: and calculating according to the output plan and a preset electric power market settlement model to obtain the income of the market, the real-time market and the frequency modulation market of the complete machine participating in the day ahead, and displaying the output plan and the income data for the evaluation decision of the market subject.
S501: the method comprises the following steps that a unit combination and an output plan of the gas turbine are obtained by the market at present according to optimization calculation, the gas turbine follows the output of the gas turbine according to a fixed proportion, and the settlement electric quantity of the gas turbine is the sum of the electric quantities of the gas turbine and is the sum of profits of the gas turbine and the gas turbine;
s502: in the real-time market, the settlement electric quantity of the set machine is the sum of the actual metering electric quantities of the gas turbine and the steam turbine, and the real-time market income of the set machine is the sum of the income of the gas turbine and the steam turbine;
s503: in the frequency modulation market, the gain of the frequency modulation capacity and the gain of the frequency modulation mileage are respectively calculated based on the winning frequency modulation capacity, the actual frequency modulation mileage and the comprehensive frequency modulation performance index of the gas turbine in the frequency modulation market, and the total frequency modulation gain of the gas turbine is formed after superposition.
Through the application of the embodiment, the Zhejiang spot-market system (including the frequency modulation market) can continue to adopt a single machine modeling mode, the single machines correspond to the D5000 system unit models one to one, the spot-market (including the frequency modulation market) declaration, release, delivery and safety check calculation all use the single machine as a unit, and the delivery model is adjusted slightly. The electric power spot market operation method considering participation of the gas combined cycle unit, which is provided by the technical scheme, is combined with the Zhejiang electric power spot market settlement trial operation data, and the scheme is shown that the accuracy and the accuracy of the clearing result are not influenced while the clearing algorithm is simplified and the model solving efficiency is improved.
Example two:
an electric power spot market operation system based on participation of a gas combined cycle unit; the electric power spot market operation system comprises:
the electric power spot market declares the model configuration module: the method is used for solving the problem of switching different costs of the gas combined cycle split-shaft unit under different operation modes in a reporting link, establishing an electric power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
a parameter information acquisition module: the system is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the data acquisition module is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the electric power market clearing model configuration module is connected with the electric power spot market declaration model configuration module and the data acquisition module; the method is used for establishing an electric power market clearing model containing the gas combined cycle unit;
the electric power market clearing model solving module is used for solving an electric power market clearing model containing the gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing the gas turbine power generation unit, an output plan and a real-time market output plan, wherein the real-time market output plan is superposed with a frequency modulation instruction to form the gas turbine output plan; the power is sent to a combustion engine for execution through AGC, and the steam engine outputs power along with the combustion engine according to a fixed proportion;
the electric power market settlement model solving module is connected with the electric power market settlement model solving module and used for calculating according to the day-ahead market output plan, the real-time market metering data and the preset electric power market settlement model to obtain the income of the set of machines participating in the day-ahead market, the income of the real-time market and the income of the frequency modulation market;
and the display and output module is used for outputting and displaying the output plan and the income data.
The method comprises the steps that an electric power market clearing model configuration module is used for configuring an objective function and constraint conditions, wherein the objective function is the minimum of electricity purchasing cost; the constraint conditions comprise system constraint taking the combined cycle gas turbine and the steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the integrated machine is brought into a constraint condition, so that the problem that the integrated machine operation mode of the gas combined cycle unit is changeable is solved; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
Example three:
an electric spot market operating apparatus based on participation of a gas combined cycle unit, the apparatus comprising a processor and a memory:
the memory is used for storing program codes and transmitting the program codes to the processor;
the processor is used for executing the power spot market operation method based on participation of the gas combined cycle unit according to the instructions in the program codes.
Example four:
a computer readable storage medium for storing program code for performing a method of operating a power spot market based on participation of a gas combined cycle plant as previously described.
The above method and apparatus for modeling the operation of the electric power spot market based on the participation of the gas combined cycle unit shown in fig. 1 is a specific embodiment of the present invention, has embodied the substantial features and the progress of the present invention, and can be modified equivalently in shape, structure and the like according to the practical use requirements and under the teaching of the present invention, all of which are within the protection scope of the present solution.
Claims (10)
1. A power spot market operation method based on participation of a gas combined cycle unit is characterized by comprising the following steps:
1) based on the problem of switching different costs of the gas combined cycle split-shaft unit under different operation modes in a reporting link, establishing a power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
2) acquiring system operation parameter information and market subject declaration parameter information in the electric power spot market declaration model;
3) establishing a day-ahead and real-time market clearing model containing a gas combined cycle unit according to the electric power spot market declaration model in the step 1) and the parameter information obtained in the step 2), and determining a day-ahead market unit combination containing a gas turbine power generation unit and a day-ahead and real-time market clearing plan based on the clearing model; the method comprises the following steps that 1), a target function of a market clearing model is determined based on a declaration mode in the step 1), and constraint conditions comprise system constraint taking a combined cycle gas turbine and a steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, so that the problem of variable operation modes of the combined cycle unit of the gas turbine is solved;
4) solving a market clearing model containing a gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing a gas turbine power generation unit, a day-ahead output plan and a real-time market output plan, wherein the real-time market output plan is issued to a gas turbine for execution through AGC after a frequency modulation instruction is superposed on the real-time market output plan, and the gas turbine outputs power along with the gas turbine according to a fixed proportion;
5) and calculating according to the day-ahead market output plan, the real-time market metering data and a preset electric power market settlement model, obtaining the income of the day-ahead market, the income of the real-time market and the income of the frequency modulation market, and outputting and displaying the output plan and the income data so as to be used for market subject evaluation decision.
2. The electric power spot market operation method based on participation of the gas combined cycle unit according to claim 1, characterized in that: in step 1) comprises:
101) in the electric energy market, the gas combined cycle split-shaft unit determines starting, stopping and output through quotation of a gas turbine power generation unit, a gas turbine power generation unit does not participate in quotation, a gas turbine follows the output of the gas turbine according to a fixed proportion, and the marginal cost of the gas turbine is converted into the quotation of the gas turbine; setting a gas turbine market declaration price of the split-axis gas turbine, wherein the upper price limit of the gas turbine market declaration price is determined based on a coaxial gas turbine set so as to ensure that the split-axis gas turbine and the coaxial gas turbine can bid on the same station;
102) in the frequency modulation market, only the gas turbine power generation unit reports the frequency modulation mileage price, the frequency modulation capacity price and the frequency modulation capacity, and the steam turbine power generation unit does not participate in reporting.
3. The electric power spot market operation method based on participation of the gas combined cycle unit according to claim 2, characterized in that: in step 3), the objective function is minimization of the electricity purchasing cost; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
4. The electric power spot market operation method based on participation of the gas combined cycle unit according to claim 1, characterized in that:
the objective function of the market clearing SCUC at present is as follows:
the objective function for future and real-time market clearing SCED is:
wherein:
n represents the total number of the units;
t represents the total number of considered time periods, and assuming 96 time periods are considered in one day, T is 96;
P i,t representing the output of the unit i in the time period t;
C i,t (P i,t )、
respectively the running cost, the starting cost and the no-load cost of the unit i in the time period t, wherein the unit running cost C i,t (P i,t ) The method is a multi-segment linear function related to each segment of output interval declared by a set of machines and corresponding energy price, and only the quotation of a gas turbine is included into a target function;
m is a network flow constraint relaxation penalty factor for market clearing optimization, and the value in SCUC is 1 multiplied by 10 8 ；
5. The electric power spot market operation method based on participation of the gas combined cycle unit according to claim 4, wherein: in the step 3) of the process,
A) system constraints
The system constraints comprise a load balancing constraint, a system positive spare capacity constraint, a system negative spare capacity constraint and a system rotating spare capacity constraint, and the system balancing constraint comprises the following steps:
for each time period t, the load balancing constraint expression is:
wherein S is gas Representing a collection of combustion engines; s steam Representing a steam turbine set; s others Representing other unit sets;
representing the total output of the combustion engine set in the time period t;
the total output of the steam turbine set in the time period t is represented, namely the steam turbine output is taken as a decision variable and is included into the system electricity balance constraint;
representing the total output, T, of all other units during time period T j,t Representing the planned power of the tie j during the time period t, N being the total number of ties, D t System load for time period t;
B) unit restraint
The unit constraint comprises traditional unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit electric quantity constraint and set constraint, wherein the set constraint is as follows:
the output proportional relation of the internal combustion engine and the steam turbine of the complete machine is as follows:
wherein: s Kit Representing a set of machines; s k Representing a set of units in the set machine k; s gas Representing a set of combustion engines; s steam Representing a steam turbine set; p i,t Representing the output of the combustion engine in the time t and deciding variables; p is i,j,t Representing the output of a steam turbine j connected with a combustion engine i in a time period t, and deciding a variable; r i,t When representing combustion engine iThe proportionality coefficient of segment t; r i,j,t A proportionality coefficient representing a period t of a steam turbine j connected with a combustion engine i;
the steam turbine set output is further expressed as:
when modeling is carried out on the complete machine, the output ratio of the gas turbine and the output ratio of the corresponding steam turbine is provided, and the output of the steam turbine carried by the gas turbine is determined by the output of the gas turbine; then the output force of the steam turbine is obtained through the definition of the output force of the steam turbine;
because the output of the steam turbine is also a decision variable and is reflected in the distribution electric balance, the steam turbine and the combustion engine participate in the distribution electric balance constraint together; the steam engine has no price, so the output of the steam engine has no cost, and the output is determined by the proportional relation between the steam engine and the combustion engine, so the output of the steam engine is equivalent to the output of the combustion engine converted into the output of the combustion engine; if the set of machine is used as a marginal machine set, the power demand of 1MW is increased by the system, the gas turbine and the steam turbine bear the power demand in proportion, and the required power generation cost is only the cost of the gas turbine, so the marginal price is equivalent to the conversion of the gas turbine quotation according to the output ratio;
C) network constraints
C1) Line flow constraint
The line power flow constraint expression is as follows:
wherein, P l max Is the tidal current transmission limit of line l; g l-i Outputting a power transfer distribution factor for a generator of a line l by a node where a unit i is located; k is the number of nodes of the system; g l-k The generator output power transfer distribution factor of node k to line l; d k,t Is the bus load value of the node k in the time period t;
respectively, forward and backward of line lA power flow relaxation variable;
C2) cross section tidal current restraint
Considering the tidal current constraint of the key section, the section tidal current constraint expression is as follows:
wherein, P s min 、P s max Respectively the tidal current transmission limit of the section s; g s-i The generator output power of the section s is transferred to a distribution factor for the node where the unit i is located; g s-k The distribution factor of the output power transfer of the generator is the node k to the section s;
respectively positive and reverse tide relaxation variables of the section s;
D) modeling of unit operating cost
D1) Unit output expression
Wherein M is the total number of the sections quoted by the unit, P i,t,m The winning power of the unit i in the mth output interval in the t period is shown,
respectively converting the output of the steam turbine into the output of the corresponding steam turbine in equal proportion at the upper and lower boundaries of the mth output interval declared by the unit i;
D2) unit operation cost expression
Wherein M is the total number of the sections quoted by the unit, C i,t,m The energy price corresponding to the mth output subsection declared by the unit i in the t period is not quoted by the steam turbine, and the cost synthesis of the steam turbine is applied to the quotation of the gas turbine;
D3) unit starting cost expression
Wherein,
for a single start-up of unit i.
6. The electric power spot market operation method based on participation of the gas combined cycle unit according to claim 5, wherein: in step 5), the method comprises the following steps:
501) the method comprises the following steps that a unit combination and an output plan of the gas turbine are obtained by the market at present according to optimization calculation, the gas turbine follows the output of the gas turbine according to a fixed proportion, and the settlement electric quantity of the gas turbine is the sum of the electric quantities of the gas turbine and is the sum of profits of the gas turbine and the gas turbine;
502) in the real-time market, the settlement electric quantity of the set machine is the sum of the actual metering electric quantities of the gas turbine and the steam turbine, and the real-time market income of the set machine is the sum of the income of the gas turbine and the steam turbine;
503) in the frequency modulation market, the gain of the frequency modulation capacity and the gain of the frequency modulation mileage are respectively calculated based on the winning frequency modulation capacity, the actual frequency modulation mileage and the comprehensive frequency modulation performance index of the gas turbine in the frequency modulation market, and the total frequency modulation gain of the gas turbine is formed after superposition.
7. An electric power spot market operation system based on participation of a gas combined cycle unit is characterized by comprising:
the electric power spot market declares the model configuration module: the method is used for solving the problem of switching different costs of the gas combined cycle split-shaft unit under different operation modes in a reporting link, establishing an electric power spot market reporting model containing participation of the gas combined cycle unit to obtain a reporting mode of the gas combined cycle unit in an electric energy market and a frequency modulation market, and realizing the same-station bidding of the split-shaft gas turbine and the coaxial gas turbine;
a parameter information acquisition module: the system is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the data acquisition module is used for acquiring system operation parameter information and market member declaration parameter information in the electric power spot market declaration model;
the electric power market clearing model configuration module is connected with the electric power spot market declaration model configuration module and the data acquisition module; the method is used for establishing an electric power market clearing model containing the gas combined cycle unit;
the electric power market clearing model solving module is used for solving an electric power market clearing model containing the gas combined cycle unit according to preset constraint conditions to obtain a day-ahead market unit combination containing the gas turbine power generation unit, an output plan and a real-time market output plan, wherein the real-time market output plan is issued to the gas turbine for execution through AGC after being superposed with a frequency modulation instruction, and the gas turbine follows the output of the gas turbine according to a fixed proportion;
the electric power market settlement model solving module is connected with the electric power market settlement model solving module and used for calculating according to the day-ahead market output plan, the real-time market metering data and the preset electric power market settlement model to obtain the income of the set of machines participating in the day-ahead market, the income of the real-time market and the income of the frequency modulation market;
and the display and output module is used for outputting and displaying the output plan and the income data.
8. The electric power spot market operating system based on participation of a gas combined cycle unit according to claim 7, wherein: in the electric power market clearing model configuration module, configuring an objective function and constraint conditions, wherein the configured objective function is the minimization of the electricity purchasing cost; the constraint conditions comprise system constraint taking the combined cycle gas turbine and the steam turbine as decision variables, unit constraint and network constraint considering the output proportional relation of the combined cycle gas turbine and the steam turbine, and unit operation cost modeling; the electric power market clearing model models the combined cycle unit according to a single machine mode, unit constraints comprise set machine constraints, and the dependency relationship in the unit modeling mode is solved through the set machine constraints; the quotation of the gas turbine is brought into a target function, and the output proportion of the internal combustion engine and the steam turbine of the combined cycle unit is brought into a constraint condition, so that the problem of variable operation modes of the combined cycle unit of the gas turbine is solved; the unit constraints comprise unit output upper and lower limit constraints, unit climbing constraints, unit minimum continuous start-stop time constraints, unit maximum start-stop times constraints, unit electric quantity constraints and unit set constraints; the network constraint comprises line flow constraint and section flow constraint; the unit operation cost modeling comprises the steps of setting a unit output expression, a unit operation cost expression and a unit starting cost expression.
9. The utility model provides an electric power spot market operation equipment based on gas combined cycle unit participates in which characterized in that: the apparatus includes a processor and a memory:
the memory is used for storing program codes and transmitting the program codes to the processor;
the processor is used for executing the electric power spot market operation method based on participation of the gas combined cycle unit according to any one of claims 1-6 according to instructions in the program code.
10. A computer-readable storage medium for storing program code for performing the method for electric power spot market operation based on gas combined cycle plant participation of any one of claims 1-6.
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