CN112184337B - Double-layer clearing pricing method for spot market considering water-fire coordination - Google Patents

Double-layer clearing pricing method for spot market considering water-fire coordination Download PDF

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CN112184337B
CN112184337B CN202011177649.2A CN202011177649A CN112184337B CN 112184337 B CN112184337 B CN 112184337B CN 202011177649 A CN202011177649 A CN 202011177649A CN 112184337 B CN112184337 B CN 112184337B
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刘映尚
周华锋
彭超逸
顾慧杰
高红亮
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China Southern Power Grid Co Ltd
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Abstract

The invention discloses a spot market double-layer clearing pricing method considering water-fire coordination, which comprises the steps of inputting basic data into a preset SCUC model not considering water and electricity water abandon constraint to obtain a unit combination result; establishing a safety constraint economic dispatching model without considering water and electricity water abandoning constraint to obtain a first round of clear results; inputting the basic data into a preset SCUC model considering the constraint of the water and electricity waste water to obtain a unit combination result; establishing a safety constraint economic dispatching model considering the hydropower water abandoning constraint to obtain a second round of clear results; judging whether the winning power in the two rounds of clearing results is consistent; if yes, outputting a clearing result; if not, taking the unit output value in the second round of output results as the fixed output of the hydroelectric generating set; calculating a node electricity price result according to a preset node electricity price calculation model without considering the water and electricity water abandoning constraint; therefore, on the premise of ensuring high-efficiency market clearing, the resource optimization configuration and the reasonable distribution of the market main body benefits are realized.

Description

Double-layer clearing pricing method for spot market considering water-fire coordination
Technical Field
The invention relates to the technical field of power dispatching automation, in particular to a spot market double-layer clearing pricing method considering water and fire coordination, a computer terminal device and a computer readable storage medium.
Background
The essence of the electric power spot market clearing is that the optimal economic benefit is realized on the premise of meeting the system safe operation constraint, and in the market clearing process, a market operating mechanism needs to consider the multi-power supply operation characteristics in a management area and the coordination relationship among different power supplies. In the construction process of the spot market of a part of provincial/regional power grid with hydropower serving as a main part and thermal power serving as an auxiliary part in China, the water and fire coordination scheduling problems such as water and electricity storage capacity limitation, water and electricity vibration area limitation, preferential water and electricity consumption when bidding on the same water and fire station and the like need to be considered by a scheduling mechanism. If the mathematical model of the relevant factors is strictly considered, a large number of 0-1 integer variables and constraint conditions are inevitably introduced, so that the calculation efficiency of the clearing of the electric power spot market is greatly reduced; meanwhile, a common treatment method considering water and electricity preferential consumption is to add a penalty function related to water curtailment electric quantity/flow in an optimization target, wherein the value of the penalty factor influences the market clearing price (the penalty factor is low, water and electricity preferential consumption cannot be guaranteed, the penalty factor is high, and the marginal electricity price of partial nodes is a negative value), and the benefit distribution among market main bodies is determined.
Disclosure of Invention
The invention aims to provide a spot market double-layer clearing pricing method considering water-fire coordination, which is based on a spot market standard optimization model and a mature mathematical optimization algorithm, comprehensively considers various complex constraint conditions, and can quickly and accurately identify a functional integer variable set needing branch calculation so as to solve the problem that the calculation efficiency of the problem is greatly influenced by numerous discrete variables and different complex constraint conditions.
In order to achieve the above object, an embodiment of the present invention provides a spot market double-layer clearing pricing method considering water-fire coordination, including:
acquiring basic data required by calculation;
inputting the basic data into a preset safety constraint unit combination model without considering the hydropower water abandoning constraint to obtain the starting and stopping states of various units as a first result;
establishing a safety constraint economic dispatching model without considering water and electricity water abandon constraints, and calculating by combining a first result to obtain a first round of clear results;
inputting the basic data into a preset safety constraint unit combination model considering the hydropower water abandoning constraint to obtain the start-stop states of various units as a second result;
establishing a safety constraint economic dispatching model considering the hydropower water abandoning constraint, and calculating by combining a second result to obtain a second round of clear results;
Judging whether the winning bid amount in the first round of clearing results is consistent with the winning bid amount in the second round of clearing results or not;
if yes, outputting a clearing result;
if not, taking the unit output value in the second round of output results as the fixed output of the hydroelectric generating set;
obtaining a node electricity price result according to a preset node electricity price calculation model without considering the constraint of the water and electricity water abandonment;
and outputting a clear result.
In some embodiments, the base data comprises: system data, unit data, power plant data, tie line plan data, load data, section data and sensitivity data.
In some embodiments, the method comprises: and constructing a preset safety constraint unit combination model without considering the water and electricity water abandoning constraint.
In some embodiments, the constructing a preset safety constraint unit combination model without considering the hydroelectric water abandonment constraint comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000021
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure BDA0002748176920000022
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor used for market clearing optimization,
Figure BDA0002748176920000023
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000024
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections;
establishing a constraint, the constraint comprising: the system comprises a system load balance constraint, a system positive spare capacity constraint, a system negative spare capacity constraint, a system rotation spare constraint, a unit output upper and lower limit constraint, a unit climbing constraint, a unit minimum continuous start-stop time constraint, a unit maximum start-stop times constraint, a unit specified state constraint, a station water level control constraint, a hydropower vibration region constraint, a line power flow constraint and a section power flow constraint.
In some embodiments, the establishing a safety-constrained economic dispatch model that does not take into account hydropower water curtailment constraints comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000025
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000031
Respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000032
positive and negative power flow relaxation variables of section sNS is the total number of the sections;
establishing a constraint, the constraint comprising: the system comprises a system load balance constraint, a system rotation standby constraint, a unit output upper and lower limit constraint, a unit climbing constraint, a station water level control constraint, a hydropower vibration region constraint, a line flow constraint and a section flow constraint.
In some embodiments, the method comprises: and constructing a preset safety constraint unit combination model considering the hydropower water abandoning constraint.
In some embodiments, the constructing a preset safety constraint unit combination model considering the hydroelectric water abandonment constraint comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000033
Figure BDA0002748176920000034
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure BDA0002748176920000035
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor used for market clearing optimization,
Figure BDA0002748176920000036
Respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000037
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H For collections of hydroelectric power plantsIn the synthesis process, the raw materials are mixed,
Figure BDA0002748176920000038
the electric quantity of the water abandoned by the hydropower plant h in the time period t, M H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system positive spare capacity constraint, system negative spare capacity constraint, system rotation spare constraint, unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit maximum start-stop times constraint, unit specified state constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and water abandoning power determination constraint.
In some embodiments, the establishing a safety-constrained economic dispatch model that takes into account a hydro-electric water curtailment constraint includes:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000041
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000042
Respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000043
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Is a collection of hydraulic power plants and is,
Figure BDA0002748176920000044
the electric quantity of the water abandoned by the hydropower plant h in the time period t, M H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system rotation standby constraint, unit output upper and lower limit constraint, unit climbing constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and abandoned water electric quantity judgment constraint.
The embodiment of the invention also provides computer terminal equipment which comprises one or more processors and a memory. A memory coupled to the processor for storing one or more programs; when executed by the one or more processors, cause the one or more processors to implement a spot-market double-tiered closeout pricing method that considers water and fire coordination as described in any of the embodiments above.
Embodiments of the present invention further provide a computer-readable storage medium, on which a computer program is stored, where the computer program, when executed by a processor, implements the spot market double-tiered shipment pricing method considering water and fire coordination according to any of the above embodiments.
In the spot market double-layer clearing pricing method considering water-fire coordination, the spot clearing model considering water-electricity water-abandon constraint/not considering water-electricity water-abandon constraint and the hydropower output calculation node electricity price with increment fixed based on the difference of the calculation results of the two models are calculated in parallel, so that the resource optimization configuration and the reasonable distribution of the market main body benefits are realized on the premise of ensuring the high-efficiency clearing of the market.
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In order to more clearly illustrate the technical solution of the present invention, the drawings needed to be used in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a schematic flow chart of a spot market double-tiered shipment pricing method considering water-fire coordination according to an embodiment of the present invention;
FIG. 2 is a schematic diagram of the curves of the hydroelectric vibration region and the operating region provided by another embodiment of the present invention;
fig. 3 is a schematic structural diagram of a computer terminal device according to an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
It should be understood that the step numbers used herein are for convenience of description only and are not intended as limitations on the order in which the steps are performed.
It is to be understood that the terminology used in the description of the invention herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. As used in the specification of the present invention and the appended claims, the singular forms "a," "an," and "the" are intended to include the plural forms as well, unless the context clearly indicates otherwise.
The terms "comprises" and "comprising" indicate the presence of the described features, integers, steps, operations, elements, and/or components, but do not preclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and/or groups thereof.
The term "and/or" refers to and includes any and all possible combinations of one or more of the associated listed items.
Referring to fig. 1, an embodiment of the present invention provides a spot market double-layer clearing pricing method considering water-fire coordination, including:
s10, acquiring basic data required by calculation;
s21, inputting the basic data into a preset safety constraint unit combination model without considering the hydropower water curtailment constraint, and obtaining various unit start-stop states as a first result;
s22, establishing a safety constraint economic dispatching model without considering hydropower waste water constraint, and calculating by combining the first result to obtain a first round of clear results;
s31, inputting the basic data into a preset safety constraint unit combination model considering the hydropower water curtailment constraint, and obtaining various unit start-stop states as a second result;
s32, establishing a safety constraint economic dispatching model considering the hydropower water abandoning constraint, and calculating by combining a second result to obtain a second round of clear results;
s40, judging whether the winning power in the first round of cleaning results is consistent with the winning power in the second round of cleaning results;
s70, if yes, outputting a clearing result;
S50, if not, taking the output value of the unit in the second round of output results as the fixed output of the hydroelectric generating set;
s60, obtaining a node electricity price result according to a preset node electricity price calculation model without considering the water and electricity water abandoning constraint;
and S70, outputting a clearing result.
Specifically, basic data required by the combined calculation of the safety constraint unit is obtained firstly, then a first round of clearing is carried out, the basic data is input into a preset Safety Constraint Unit Combination (SCUC) model which does not consider the water and electricity water abandonment constraint, a mature optimization algorithm software package (such as CPLEX) is called for solving, and various unit start-stop states and output standard results are obtained and stored; and then, on the basis of a unit starting and stopping state result obtained after a safety constraint unit combination model which does not consider hydropower water curtailment is solved, a mature optimization algorithm software package (such as CPLEX) is called to optimize and calculate a safety constraint economic dispatching model which does not consider hydropower water curtailment, and a marking power result in the unit, namely a first round of clear result, is obtained. The round of clearing result is not used as a settlement basis, and is only used for comparing with the second round of clearing electric quantity to judge which hydroelectric generating sets need to be set as fixed output when the node electricity price is calculated. The second round of output cleaning is to input the basic data into a preset safety constraint unit combination model considering the hydropower water-abandoning constraint, and call a mature optimization algorithm software package (such as CPLEX) to solve to obtain and store various unit start-stop states and output results of the central mark; and then on the basis of a unit starting and stopping state result obtained after a safety constraint unit combination model considering hydropower water and abandoned water constraint is solved, a safety constraint economic dispatching model considering hydropower water and abandoned water constraint is solved by calling a mature optimization algorithm software package (such as CPLEX), and a unit bid amount and dispatching plan clear result of a second round of clear model are obtained. And sending the clearing result to each unit for execution and serving as a settlement basis of the electric power spot market. And comparing the output results of the first round of output and the second round of output, and setting the output of the hydroelectric generating set/unit of which the output is increased by comparing the output of the second round of output with the output of the first round of output as fixed output. And the fixed output value is the output value of the unit/power generation unit obtained by the second round of optimized output. The fixed capacity unit/generator unit is not priced in the spot market at this time. And constructing an optimization model of the electricity price of the computing node without penalty factors, wherein the model is consistent with a safety constraint economic dispatching model which is established in the first round of clearing and does not take the water and electricity abandon water constraint into consideration. Shadow prices of system load balance constraint and section flow constraint are obtained by solving the model, node marginal electricity prices of all nodes of the whole network are obtained by combining section flow sensitivity calculation, and node electricity price solving results of the model are used as settlement prices of a power generation side and a user side. And finally, outputting clearing results, wherein the outputted clearing results comprise unit combination, unit winning power, power plant winning power, node marginal price and the like.
In some embodiments, the base data comprises: system data, unit data, power plant data, tie line plan data, load data, section data and sensitivity data.
In this embodiment, the basic data includes system data: time interval information, system load; the unit data: the method comprises the following steps of generating set basic information, generating set calculation parameters, generating set starting quotation, generating set energy quotation, generating set initial state, generating set appointed state, generating set electric power constraint, generating set climbing speed, generating set minimum continuous start-stop time, hydroelectric generating set vibration area and the like; power plant data: the method comprises the following steps of generating basic information of a power plant, calculating parameters of the power plant, power constraint of the power plant, electric quantity constraint of the power plant, water level parameters of storage capacity of a hydraulic power plant, cascade relation of the hydraulic power plant, water level constraint of the hydraulic power plant, historical state of the hydraulic power plant and the like; tie-line planning data: tie line basic information, tie line planned power; load data: basic information of bus load and bus load prediction; section data: the method comprises the following steps of (1) basic information of a section, section calculation parameters, section containing equipment, section cutting load power and section transmission limit; sensitivity data: basic information of the topological nodes, mapping of equipment and the topological nodes, and sensitivity of section flow relative to each topological node.
In some embodiments, the method comprises: and constructing a preset safety constraint unit combination model without considering the water and electricity water abandoning constraint.
In this embodiment, a safety constraint unit combination model without consideration of the hydroelectric water abandon constraint needs to be established in advance, and the objective function and the constraint condition of the model do not consider the water abandon absorption factor.
In some embodiments, the constructing a preset safety constraint unit combination model without considering the hydroelectric water abandonment constraint comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000071
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure BDA0002748176920000072
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Relating to the output interval of each section declared by the unit and the corresponding energy priceA multi-segment linear function, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000073
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000074
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections;
establishing a constraint, the constraint comprising: the system comprises a system load balance constraint, a system positive spare capacity constraint, a system negative spare capacity constraint, a system rotation spare constraint, a unit output upper and lower limit constraint, a unit climbing constraint, a unit minimum continuous start-stop time constraint, a unit maximum start-stop times constraint, a unit specified state constraint, a station water level control constraint, a hydropower vibration region constraint, a line power flow constraint and a section power flow constraint.
In the embodiment, the objective function of the safety constraint unit combination model without considering the hydropower and water curtailment constraints is
Figure BDA0002748176920000075
Wherein: n represents the total number of units, T represents the total number of considered time intervals, if 96 time intervals 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 )、
Figure BDA0002748176920000076
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor used for market clearing optimization,
Figure BDA0002748176920000081
each of the lines lThe forward and reverse power flow relaxation variables, NL is the total number of lines,
Figure BDA0002748176920000082
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections; the unit output expression is as follows:
Figure BDA0002748176920000083
Figure BDA0002748176920000084
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,
Figure BDA0002748176920000085
and the upper and lower boundaries of the mth output interval declared by the unit i are respectively set.
The unit operation expense expression is as follows:
Figure BDA0002748176920000086
wherein M is the total number of the sections quoted by the unit, C i,t,m And (4) carrying out segmentation on the corresponding energy price of the mth output reported by the unit i in the t period.
Unit starting cost expression
Figure BDA0002748176920000087
Wherein the content of the first and second substances,
Figure BDA0002748176920000088
for a single start-up of unit i.
And finally establishing a constraint condition, wherein the constraint condition is as follows:
(1) system load balancing constraints
For each time period t, the load balancing constraint may be described as:
Figure BDA0002748176920000089
wherein, P i,t Represents the output of the unit i in the time period T, T j,t Represents the optimal power (positive input and negative output) of the tie line j in the time period t, NT is the total number of tie lines, D t The system load for the time period t.
(2) System positive spare capacity constraint
Figure BDA00027481769200000810
Wherein alpha is i,t Representing the starting and stopping states of the unit i in the time period t, alpha i,t 0 denotes a unit shutdown, α i,t 1 represents the starting of the unit; n is the total number of the units;
Figure BDA00027481769200000811
the maximum output (generally rated capacity) of the unit i in the time period t is obtained; NT is the total number of crossties, T j,t Represents the optimized power (feed-in positive and output negative) D of the tie-line j during the time period t t For the system load of the time period t,
Figure BDA0002748176920000091
the positive spare capacity requirement of the system for time period t.
(3) System negative spare capacity constraint
The system negative spare capacity constraint may be described as:
Figure BDA0002748176920000092
wherein the content of the first and second substances,
Figure BDA0002748176920000093
the minimum output of the unit i in the time period t is obtained;
Figure BDA0002748176920000094
the system negative spare capacity requirement for the t period.
(4) System rotational back-up constraint
The up-regulation capacity sum and the down-regulation capacity sum of the unit output at each time interval need to meet the up-regulation and down-regulation rotation standby requirements of actual operation.
Figure BDA0002748176920000095
Figure BDA0002748176920000096
Wherein, Δ P i U For the unit i maximum climbing rate, Δ P i D The maximum downward climbing speed of the unit i;
Figure BDA0002748176920000097
Figure BDA0002748176920000098
respectively the maximum output and the minimum output of the unit i in the time period t;
Figure BDA0002748176920000099
the standby requirements are respectively adjusted up and down for the time period t.
(5) Upper and lower limit restraint of unit output
The capacity of the unit should be within its maximum/minimum technical capacity, and its constraint can be described as:
Figure BDA00027481769200000910
if the unit is shut down, α i,t If the output power of the unit is 0, the output power of the unit can be limited to 0 by the constraint condition; when the unit is started, alpha i,t 1, the constraint being conventionalAnd (5) restraining an upper limit and a lower limit of the output.
(6) Unit climbing restraint
When the unit climbs up or down, the requirement of climbing speed is met. The hill climbing constraint can be described as:
Figure BDA00027481769200000911
Figure BDA00027481769200000912
wherein, Δ P i U For the unit i maximum climbing rate, Δ P i D The maximum downward climbing rate of the unit i. The unit lifting output constraint is determined by several factors:
when the unit is in a normal operation state, the lifting output range of the unit is controlled by delta P i U 、ΔP i D Determining;
when the unit is at the starting moment, the lifting output range of the unit is determined by the allowable starting speed (here, the allowable starting speed) of the unit
Figure BDA0002748176920000101
) Determining;
when the unit is at the shutdown time, the range of the lifting output of the unit is determined by the allowable shutdown rate of the unit (here, the allowable shutdown rate of the unit)
Figure BDA0002748176920000102
) And (6) determining.
(7) Minimum continuous on-off time constraint of unit
Due to the physical properties and actual operation requirements of the thermal power generating unit, the thermal power generating unit is required to meet minimum continuous startup/shutdown time. The minimum continuous on-off time constraint can be described as:
Figure BDA0002748176920000103
Figure BDA0002748176920000104
wherein alpha is i,t The starting and stopping states of the unit i in the time period t are set; t is U 、T D The minimum continuous starting time and the minimum continuous stopping time of the unit are obtained;
Figure BDA0002748176920000105
for the time when the unit i has been continuously started and continuously stopped during the time period t, the state variable α can be used i,t (i is 1 to N, and T is 1 to T):
Figure BDA0002748176920000106
Figure BDA0002748176920000107
(8) maximum number of start and stop times constraint of unit
First, the startup and shutdown switching variables are defined. Definition eta i,t Whether the unit i is switched to a starting state in a time period t or not is judged; definition of gamma i,t Indicating whether the unit i is switched to a shutdown state in the period t, eta i,t 、γ i,t The following conditions are satisfied:
Figure BDA0002748176920000108
Figure BDA0002748176920000109
the limitation of the number of start-stop times of the corresponding unit i can be expressed as follows:
Figure BDA00027481769200001010
Figure BDA0002748176920000111
wherein the content of the first and second substances,
Figure BDA0002748176920000112
the maximum starting and stopping times of the unit i are respectively.
η i,t 、γ i,t The analytical expression of (a) is as follows:
Figure BDA0002748176920000113
(9) unit assigned state constraint
Maintenance, specified start-stop, specified output and the like.
(10) Hydropower plant/station water level control constraint
In modeling, the following assumptions were made:
in the period of time before the day of clearing, the water consumption rate of the hydropower station is unchanged;
In the period of time of day-ahead clearing, the water level-water storage capacity of the hydropower station is in a linear relation, namely the water surface area of the reservoir is unchanged;
the lag time between the hydropower stations before the day is irrelevant to the downward leakage flow of the upper hydropower station.
Figure BDA0002748176920000114
Wherein the parameters are as follows:
Figure BDA0002748176920000115
the water level control requirement upper and lower limits of the hydropower station i determined by the water regulation position at the end of the time period t are obtained through a water regulation system. Z i,0 The parameter represents the initial water level of the hydropower station i at the zero point of the next day, which can be generally estimated from the previous market clearing result or the real-time clearing result of the previous day and is obtained by a market operation mechanism system;
h i is the water consumption rate of the hydropower station i; s i Representing the water surface area of a reservoir of the hydropower station i; i is i,τ Representing the natural incoming water flow of the hydropower station i in the time period tau;
decision variables
Figure BDA0002748176920000116
The reject flow for hydropower station i during time period τ. up (i) represents the upstream hydropower station of the hydropower station i, s (i) represents the upstream lag time, P, encountered by the hydropower station i up(i),t-s(i) The power generation output of upstream hydropower station up (i) of hydropower station i at time period t-s (i);
Figure BDA0002748176920000117
the reject flow of water at a hydropower station up (i) upstream of the hydropower station i during a time period t-s (i).
(11) Restriction of hydroelectric vibration region
Referring to fig. 2, the restriction of the hydroelectric vibration region means that the output of the hydroelectric generating set/unit needs to avoid the output range corresponding to the vibration region, so as to ensure the safe operation of the hydroelectric generating set.
Figure BDA0002748176920000121
Figure BDA0002748176920000122
Respectively representing the lower limit and the upper limit of the 1 st vibration area of the ith unit.
δ i,1,t 1 represents the ith unit at time period t
Figure BDA0002748176920000123
In between.
P i,1,t And the output of the operation interval is represented when the ith unit is in the 1 st operable interval at the t time period.
Figure BDA0002748176920000124
The inequality constraint can limit the output force of the unit to be within a certain operable interval, and the output force of the unit cannot exceed the interval.
Figure BDA0002748176920000125
The unit output can be limited to only fall in one operable interval through the inequality constraint.
(12) Line flow constraint
The line flow constraint may be described as:
Figure BDA0002748176920000126
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; g l-j Outputting a power transfer distribution factor for the generator of the link line l by the node where the link line j 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 at time period t.
Figure BDA0002748176920000127
Respectively, the positive and reverse power flow relaxation variables of the line l.
(13) Cross section tidal current restraint
Considering the critical profile power flow constraint, the constraint can be described as:
Figure BDA0002748176920000128
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-j Is a tie line jThe generator output power at the node pair section s is transferred to a distribution factor; g s-k The generator output power transfer distribution factor is node k to section s.
Figure BDA0002748176920000131
Respectively the positive and reverse tide relaxation variables of the section s.
In some embodiments, the establishing a safety-constrained economic dispatch model that does not take into account hydropower water curtailment constraints comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000132
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000133
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000134
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections;
establishing a constraint, the constraint comprising: the system comprises a system load balance constraint, a system rotation standby constraint, a unit output upper and lower limit constraint, a unit climbing constraint, a station water level control constraint, a hydropower vibration region constraint, a line flow constraint and a section flow constraint.
In this embodiment, an optimization objective is set, and an objective function is established according to the optimization objective, where the objective function includes:
Figure BDA0002748176920000135
n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000136
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000137
Figure BDA0002748176920000138
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections; unit output expression
Figure BDA0002748176920000139
Figure BDA00027481769200001310
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,
Figure BDA00027481769200001311
and the upper and lower boundaries of the mth output interval declared by the unit i are respectively set.
Unit operation cost expression
Figure BDA0002748176920000141
Wherein M is the total number of the sections quoted by the unit, C i,t,m And (4) carrying out segmentation on the corresponding energy price of the mth output reported by the unit i in the t period.
Then, establishing a constraint condition, wherein the constraint condition is as follows:
(1) system load balancing constraints
For each time period t, the load balancing constraint may be described as:
Figure BDA0002748176920000142
wherein, P i,t Represents the output of the unit i in the time period T, T j,t Represents the optimal power (positive input and negative output) of the tie line j in the time period t, NT is the total number of tie lines, D t The system load for the time period t.
(2) System rotational back-up constraint
The up-regulation capacity sum and the down-regulation capacity sum of the unit output at each time interval need to meet the up-regulation and down-regulation rotation standby requirements of actual operation.
Figure BDA0002748176920000143
Figure BDA0002748176920000144
Wherein, Δ P i U For the unit i maximum climbing rate, Δ P i D The maximum downward climbing speed of the unit i;
Figure BDA0002748176920000145
Figure BDA0002748176920000146
respectively the maximum output and the minimum output of the unit i in the time period t;
Figure BDA0002748176920000147
the standby requirements are respectively adjusted up and down for the time period t.
(3) Upper and lower limit constraint of unit output
The capacity of the unit should be within its maximum/minimum technical capacity, and its constraint can be described as:
Figure BDA0002748176920000148
if the unit is shut down, α i,t If the output power of the unit is 0, the output power of the unit can be limited to 0 by the constraint condition; when the unit is started, alpha i,t The constraint is a conventional upper and lower force limit constraint.
(4) Unit climbing restraint
When the unit climbs up or down, the requirement of climbing speed is met. The hill climbing constraint can be described as:
P i,t -P i,t-1 ≤ΔP i U
P i,t-1 -P i,t ≤ΔP i D
wherein, Δ P i U For the unit i maximum climbing rate, Δ P i D The maximum downward climbing rate of the unit i.
(5) Hydropower plant/station water level control constraint
In modeling, the following assumptions were made:
in the period of time before the day of clearing, the water consumption rate of the hydropower station is unchanged;
in the period of time of day-ahead clearing, the water level-water storage capacity of the hydropower station is in a linear relation, namely the water surface area of the reservoir is unchanged;
the lag time between the hydropower stations before the day is irrelevant to the downward leakage flow of the upper hydropower station.
Figure BDA0002748176920000151
Wherein the parameters are as follows:
Figure BDA0002748176920000152
the water level control requirement upper and lower limits of the hydropower station i determined by the water regulation position at the end of the time period t are obtained through a water regulation system. Z i,0 The parameter represents the initial water level of the hydropower station i at the zero point of the next day, which can be generally estimated from the previous market clearing result or the real-time clearing result of the previous day and is obtained by a market operation mechanism system;
h i is the water consumption rate of the hydropower station i; s. the i Representing the water surface area of a reservoir of the hydropower station i; i is i,τ Representing the natural incoming water flow of the hydropower station i in the time period tau;
decision variables
Figure BDA0002748176920000153
The reject flow for hydropower station i during time period τ. up (i) represents the upstream hydropower station of the hydropower station i, s (i) represents the upstream lag time, P, encountered by the hydropower station i up(i),t-s(i) The power generation output of upstream hydropower station up (i) of hydropower station i at time period t-s (i);
Figure BDA0002748176920000154
the reject flow of water at a hydropower station up (i) upstream of the hydropower station i during a time period t-s (i).
(6) Restriction of hydroelectric vibration region
The restriction of the hydroelectric vibration area means that the output of the hydroelectric generating set/unit needs to avoid the output range corresponding to the vibration area so as to ensure the safe operation of the hydroelectric generating set.
The hydroelectric generating set i has k vibration areas in total, and the upper limit and the lower limit of the k vibration area are
Figure BDA0002748176920000155
The upper and lower limits of the output force at a certain time are P i GTmin (t)、P i GTmax (t) then its corresponding operational zone is
Figure BDA0002748176920000156
Figure BDA0002748176920000157
If the output of the hydroelectric generating set optimized in the step 3 falls within the operable area, the upper and lower limits of the output of the hydroelectric generating set are the upper and lower limits of the operable area and are recorded as
Figure BDA0002748176920000161
Figure BDA0002748176920000162
And if the output force of the hydroelectric generating set optimized in the step 3 falls within the vibration region, the output force of the hydroelectric generating set is matched nearby, the minimum output force of the hydroelectric generating set is fixed as the upper limit of the vibration region, or the maximum output force of the hydroelectric generating set is fixed as the lower limit of the vibration region, and the output range is the corresponding operation region.
(7) Line flow constraint
The line flow constraint may be described as:
Figure BDA0002748176920000163
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; g l-j Outputting a power transfer distribution factor for the generator of the link line l by the node where the link line j 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.
Figure BDA0002748176920000164
Respectively, the positive and reverse power flow relaxation variables of the line l.
(8) Cross section tidal current restraint
Considering the critical profile power flow constraint, the constraint can be described as:
Figure BDA0002748176920000165
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-j The generator output power of the section s is transferred with a distribution factor for the node where the tie line j is located; g s-k The generator output power transfer distribution factor is node k to section s.
Figure BDA0002748176920000166
Respectively the positive and reverse tide relaxation variables of the section s.
In some embodiments, the method comprises: and constructing a preset safety constraint unit combination model considering the hydropower water abandoning constraint.
In this embodiment, a safety constraint unit combination model considering the hydropower water curtailment constraint needs to be established in advance, and in order to ensure maximum consumption of clean energy, a clear model with fixed penalty factors is adopted, that is, both objective functions and constraint conditions consider the water curtailment consumption factors.
In some embodiments, the constructing a preset safety constraint unit combination model considering the hydroelectric water abandonment constraint comprises:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000171
Figure BDA0002748176920000172
Wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure BDA0002748176920000173
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is related to the output interval of each section and the corresponding energy price declared by the unitA linear function is segmented, M is a network flow constraint relaxation penalty factor for the market clearing optimization,
Figure BDA0002748176920000174
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000175
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Being a collection of hydroelectric power plants/stations,
Figure BDA0002748176920000176
the water-abandoning electric quantity M of the hydropower plant/station h in the time period t H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system positive spare capacity constraint, system negative spare capacity constraint, system rotation spare constraint, unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit maximum start-stop times constraint, unit specified state constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and water abandoning power determination constraint.
In this embodiment, compared with the constraint conditions of the safety constraint unit combination model without considering the hydroelectric water abandoning constraint, the constraint conditions of the safety constraint unit combination model without considering the hydroelectric water abandoning constraint are added with the abandoned water amount judgment constraint
Figure BDA0002748176920000177
Figure BDA0002748176920000178
P h,max The capacity/maximum output of the unit of the hydropower station h is shown; p is h,t The output of the hydropower station h in the time period t is obtained;
Figure BDA0002748176920000179
the water discharge of the hydropower station h in the time period t is determined; h is a total of h Is the water consumption rate of the hydropower station h. M is a very large positive number.
a h,t Is a variable from 0 to 1 when
Figure BDA00027481769200001710
When a is h,t 1 is ═ 1; when in use
Figure BDA00027481769200001711
When a is h,t ＝0。
In some embodiments, the establishing a safety-constrained economic dispatch model that takes into account a hydro-electric water curtailment constraint includes:
setting an optimization target, and establishing an objective function according to the optimization target, wherein the objective function comprises:
Figure BDA0002748176920000181
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000182
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000183
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Being a collection of hydroelectric power plants/stations,
Figure BDA0002748176920000184
the water-abandoning electric quantity M of the hydropower plant/station h in the time period t H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system rotation standby constraint, unit output upper and lower limit constraint, unit climbing constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and abandoned water electric quantity judgment constraint.
In this embodiment, the safety constraint economic dispatching model considering the hydropower water-abandoning constraint is established according to the second round of output allocation result, and the established objective function is as follows:
Figure BDA0002748176920000185
wherein: n represents the total number of units, T represents the total number of considered time intervals, if 96 time intervals 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 ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure BDA0002748176920000186
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure BDA0002748176920000187
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Is a collection of hydraulic power plants/stations,
Figure BDA0002748176920000188
the water-abandoning electric quantity M of the hydropower plant/station h in the time period t H A penalty factor for water abandonment;
then, establishing constraint conditions, wherein the constraint conditions of the safety constraint economic dispatching model considering the hydropower water curtailment constraint are that the water curtailment electricity quantity judgment constraint is newly added on the basis of the constraint conditions of the safety constraint economic dispatching model not considering the hydropower water curtailment constraint
Figure BDA0002748176920000189
Figure BDA0002748176920000191
P h,max The capacity/maximum output of the unit of the hydropower station h is shown; p is h,t The output of the hydropower station h in the time period t is obtained;
Figure BDA0002748176920000192
the water discharge of the hydropower station h in the time period t is determined; h is h The water consumption rate of the hydropower station h. M is a very large positive number.
a h,t Is a variable from 0 to 1 when
Figure BDA0002748176920000193
When a is h,t 1 is ═ 1; when in use
Figure BDA0002748176920000194
When a is h,t ＝0。
Referring to fig. 3, an embodiment of the present invention provides a computer terminal device, which includes one or more processors and a memory. A memory is coupled to the processor for storing one or more programs, which when executed by the one or more processors, cause the one or more processors to implement a spot market double-tiered shipment pricing method that takes into account water and fire coordination as in any of the embodiments described above.
The processor is used for controlling the overall operation of the computer terminal equipment so as to complete all or part of the steps of the spot market double-layer clearing pricing method considering water-fire coordination. The memory is used to store various types of data to support the operation at the computer terminal device, which data may include, for example, instructions for any application or method operating on the computer terminal device, as well as application-related data. The Memory may be implemented by any type of volatile or non-volatile Memory device or combination thereof, such as Static Random Access Memory (SRAM), Electrically Erasable Programmable Read-Only Memory (EEPROM), Erasable Programmable Read-Only Memory (EPROM), Programmable Read-Only Memory (PROM), Read-Only Memory (ROM), magnetic Memory, flash Memory, magnetic disk, or optical disk.
In an exemplary embodiment, the computer terminal Device may be implemented by one or more Application Specific 1 integrated circuits (AS 1C), a Digital Signal Processor (DSP), a Digital Signal Processing Device (DSPD), a Programmable Logic Device (PLD), a Field Programmable Gate Array (FPGA), a controller, a microcontroller, a microprocessor, or other electronic components, for performing the above-mentioned spot market double-layer clearing pricing method considering fire and water coordination, and achieving technical effects consistent with the above-mentioned method.
In another exemplary embodiment, a computer readable storage medium is also provided that includes program instructions which, when executed by a processor, implement the steps of the spot market double-tiered shipment pricing method in any of the above embodiments that take into account water and fire coordination. For example, the computer readable storage medium may be the memory described above including program instructions executable by the processor of the computer terminal device to perform the spot market double-tiered shipment pricing method described above in view of water and fire coordination, and to achieve a technical effect consistent with the method described above.
In summary, in the spot market double-layer export pricing method considering water-fire coordination in the embodiment of the invention, the electricity price is calculated by parallel calculation of the spot export model considering/not considering water-electricity and water-abandon constraints and the hydropower output with increment fixed based on the difference of the calculation results of the two models, so that the resource optimization configuration and the reasonable allocation of the market main body benefits are realized on the premise of ensuring the high-efficiency export of the market.
While the foregoing is directed to the preferred embodiment of the present invention, it will be understood by those skilled in the art that various changes and modifications may be made without departing from the spirit and scope of the invention.

Claims (8)

1. A spot market double-tiered shipment pricing method considering water-fire coordination, comprising:
acquiring basic data required by calculation;
inputting the basic data into a preset safety constraint unit combination model without considering the hydropower water abandoning constraint to obtain the starting and stopping states of various units as a first result; the method specifically comprises the following steps:
constructing a preset safety constraint unit combination model without considering the hydropower water abandoning constraint, wherein the constructing of the preset safety constraint unit combination model without considering the hydropower water abandoning constraint comprises the following steps:
Establishing an objective function, the objective function comprising:
Figure FDA0003697526960000011
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure FDA0003697526960000012
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor used for market clearing optimization,
Figure FDA0003697526960000013
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure FDA0003697526960000014
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections;
establishing a constraint, the constraint comprising: system load balance constraint, system positive spare capacity constraint, system negative spare capacity constraint, system rotation spare constraint, unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit maximum start-stop times constraint, unit specified state constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint and section power flow constraint;
establishing a safety constraint economic dispatching model without considering water and electricity water abandon constraints, and calculating by combining a first result to obtain a first round of clear results;
Inputting the basic data into a preset safety constraint unit combination model considering the hydropower water abandoning constraint to obtain the start-stop states of various units as a second result;
establishing a safety constraint economic dispatching model considering the hydropower water abandoning constraint, and calculating by combining a second result to obtain a second round of clear results;
judging whether the winning power in the first round of clearing results is consistent with the winning power in the second round of clearing results;
if yes, outputting a clearing result;
if not, taking the unit output value in the second round of output results as the fixed output of the hydroelectric generating set;
obtaining a node electricity price result according to a preset node electricity price calculation model without considering the constraint of the water and electricity water abandonment;
and outputting a clear result.
2. The spot market double-tiered shipment pricing method in view of water-fire coordination according to claim 1, wherein the base data comprises: system data, unit data, power plant data, tie line plan data, load data, section data and sensitivity data.
3. The spot market double-tiered shipment pricing method considering water-fire coordination according to claim 1, wherein the establishing a safety-constrained economic dispatch model that does not consider water-electricity-water curtailment constraints comprises:
Establishing an objective function, wherein the objective function comprises:
Figure FDA0003697526960000021
wherein: n denotes the total number of units, T denotes the total number of time phases considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure FDA0003697526960000022
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure FDA0003697526960000023
respectively a positive tide relaxation variable and a reverse tide relaxation variable of the section s, wherein NS is the total number of the sections;
establishing a constraint, the constraint comprising: the system comprises a system load balance constraint, a system rotation standby constraint, a unit output upper and lower limit constraint, a unit climbing constraint, a station water level control constraint, a hydropower vibration region constraint, a line flow constraint and a section flow constraint.
4. The spot market double-tiered shipment pricing method considering water-fire coordination according to claim 1, characterized by comprising:
and constructing a preset safety constraint unit combination model considering the hydropower water abandoning constraint.
5. The spot market double-tiered shipment pricing method considering water-fire coordination according to claim 4, wherein constructing a preset safety constraint unit combination model considering water-electricity-abandonment constraints comprises:
Establishing an objective function, wherein the objective function comprises:
Figure FDA0003697526960000024
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t )、
Figure FDA0003697526960000025
Respectively the running cost and the starting cost of the unit i in the time period t, wherein the running cost C of the unit i,t (P i,t ) Is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor used for market clearing optimization,
Figure FDA0003697526960000031
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure FDA0003697526960000032
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Is a collection of hydraulic power plants and is,
Figure FDA0003697526960000033
the electric quantity of the water abandoned by the hydropower plant h in the time period t, M H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system positive spare capacity constraint, system negative spare capacity constraint, system rotation spare constraint, unit output upper and lower limit constraint, unit climbing constraint, unit minimum continuous start-stop time constraint, unit maximum start-stop times constraint, unit specified state constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and water abandoning power determination constraint.
6. The spot market double-tiered shipment pricing method considering water-fire coordination according to claim 1, wherein the establishing a safety-constrained economic dispatch model considering water abandonment constraints comprises:
establishing an objective function, wherein the objective function comprises:
Figure FDA0003697526960000034
wherein: n denotes the total number of units, T denotes the total number of time periods considered, P i,t Representing the output of the unit i in the time period t, C i,t (P i,t ) The running cost of the unit i in the time t is a multi-segment linear function related to each segment of output interval declared by the unit and the corresponding energy price, M is a network power flow constraint relaxation penalty factor for market clearing optimization,
Figure FDA0003697526960000035
respectively, positive and reverse power flow relaxation variables of the line l, NL is the total number of the line,
Figure FDA0003697526960000036
respectively the forward and reverse power flow relaxation variables of the section s, NS is the total number of the sections, omega H Is a collection of hydraulic power plants and is,
Figure FDA0003697526960000037
the electric quantity of the water abandoned by the hydropower plant h in the time period t, M H A penalty factor for water abandonment;
establishing a constraint, the constraint comprising: the method comprises the following steps of system load balance constraint, system rotation standby constraint, unit output upper and lower limit constraint, unit climbing constraint, station water level control constraint, hydropower vibration region constraint, line power flow constraint, section power flow constraint and abandoned water electric quantity judgment constraint.
7. The spot market double-tiered closeout pricing method considering water-fire coordination according to claim 1, characterized in that the preset nodal electricity price calculation model not considering water-electricity-abandonment constraints is the same as the safety-constrained economic dispatch model not considering water-electricity-abandonment constraints.
8. A computer-readable storage medium, on which a computer program is stored which, when being executed by a processor, carries out a spot market double-tiered shipment pricing method taking into account water-fire coordination according to any of claims 1 to 7.
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