CN110782281A - Day-ahead market clearing method for multi-owner cascade power station basin electric quantity transfer - Google Patents
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Abstract
The invention has disclosed the market clearing method before the day of a kind of multi-owner step power station basin electric quantity transfer, said method comprises (S1) after the market begins before the day of the electric power spot shipment, according to the relevant information of market that the electric power scheduling organization releases; (S2) calculating out the safety constraint unit combination SCUC optimization of the cascade hydroelectric power upstream and downstream power stations by only considering power constraint; (S3) checking the information obtained by SCUC optimization calculation by adopting a hydraulic checking model, and continuously calculating the result according to the SCED optimization calculation considering only the electric power constraint when the step hydropower output time interval meets the water constraint, and (S4) calculating the result by adopting the SCED optimization calculation considering both the hydraulic limitation condition and the electric power constraint when the step hydropower output time interval does not meet the water constraint.
Description
Technical Field
The invention belongs to the technical field of electric quantity clearing, and particularly relates to a day-ahead market clearing method for transferring electric quantity of a multi-owner cascade power station drainage basin.
Background
At present, China's electric power trade is beginning to move to electric power spot trade with a shorter time period, and the steady promotion of the electric power spot market will certainly enable the step hydropower station to compete with other types of power stations on the same platform. The upstream power station can flexibly participate in the spot market due to the good storage and regulation capacity, and the downstream power station with poor regulation capacity cannot independently participate in the market due to the fact that the power generation amount depends on the origin flow of the upstream power station. The upstream and downstream power stations of the cascade hydropower station in most areas of China are in different owners, and the benefits of all the power stations are difficult to coordinate, so that the cascade hydropower stations cannot be optimized and participate in the market.
Meanwhile, for the current spot market, the market operating organization mainly adopts two core models of Security-constraint unit combination (SCUC) and Security-constraint economic dispatch (SCED) to complete the current clearing. At this time, if the SCUC and SCED models in the market clearing model are considered to be optimized for clearing by taking the cascade hydropower upstream and downstream water connection and power constraint into consideration in the same way according to the traditional short-term scheduling method, the SCUC model contains integer variables, and the addition of the water connection constraint can generate a large amount of technical constraint and 0 and 1 integer decision variables for the power station, so that the possible association relationship of the upstream and downstream output is increased in geometric stages according to the runoff, a 'dimensional disaster' is generated, and the clearing result can not be obtained.
In conclusion, in the case that the cascade hydropower station cannot accurately acquire the market strategy information of the upstream power station, a clear scheme which is reasonable and can be applied to actual engineering is worth exploring. Currently, there are mainly 4 solutions to this problem.
The first method adopts a step hydropower agency mechanism to promote the step hydropower combined operation, namely, the upstream and downstream sides of the step hydropower station voluntarily negotiate to generate agency contracts, the upstream power station acts on the downstream power station to participate in the market, and the profit is distributed according to the contracts. (reference: meaning, Korean, Zhang particle. agency mechanism for efficient allocation of stepped hydroelectric resources in market Environment [ J ] electric Power System Automation, 2010,34(7):26-30)
And in the second method, a step hydropower benefit compensation mechanism is adopted, namely an effective and accurate compensation benefit verification method and a compensation benefit allocation method which is accepted and accepted by all parties are researched, and the multi-benefit subject step hydropower station group can be promoted to carry out joint economic operation. (reference: Li Jinpeng, Wang Yongxiang, Guo morning glory, etc.. Cascade Power station Compensation benefit apportioned group consensus coordinated planning method [ J ]. hydroelectric Power science 2010,28(7): 138-)
Although the two clearing methods can stimulate the upstream and downstream power stations of the cascade hydropower station to realize the optimal allocation of the cascade hydropower resources to maximize the benefit, the two clearing methods are both economic distribution problems in essence, different capital owners have the core of self-profit for participating in the market, and if the profits obtained by the joint participation of the two parties in the market cannot reach the expected profit, the collaborative mode faces the situation of collapse.
And thirdly, embedding the hydraulic power and electric power coupling relation between the upstream power station and the downstream power station of the cascade hydropower station into a clearing model, wherein the downstream power station is used as a price acceptor without quotation, and the generated energy of the downstream power station is related to the reported amount of the upstream power station, so that the downstream power station obtains a clearing result matched with the generated energy of the upstream power station when the market is cleared. (refer to Zhang particle, Liu Fang, xu Tong, etc.. the day-ahead market clearing model of multi-operation main body cascade hydropower station participation [ J ]. power system automation, 2018(1):104-
And on the basis of the third method, the downstream power station is provided to use self limited output margin to formulate a self-scheduling bidding strategy, namely the output adjustment of 'tenuous storage before peak and water storage after peak' is used for expanding the income space. (reference: Zhang particles, Liu Fang, permissive, etc.. Multi-subject step hydropower participation in the day-ahead market downstream stations self-scheduling bidding strategy [ J ] Power System Automation, 2018,42(19):33-39.)
In the two modes of realizing the joint participation of the cascade hydropower stations in the market through model optimization, most of the benefits of the downstream power stations are determined by the upstream power stations, the initiative of the downstream power stations in the market is ignored, and the competitiveness of the drainage basin cannot be improved.
Disclosure of Invention
In order to overcome the defects in the prior art, the invention provides a method for clearing the day-ahead market for transferring the electric quantity of the basin of the multi-owner cascade power station, which can avoid the situation that the trading result cannot be executed due to independent bidding of the upstream power station and the downstream power station, is beneficial to dividing the benefits of water and electricity, reduces the electricity and water abandonment and realizes the maximum utilization of water resources.
In order to achieve the purpose, the technical scheme adopted by the invention is as follows:
a method for clearing the day-ahead market for transferring the electric quantity of a multi-owner cascade power station basin comprises the following steps:
(S1) after the market starts before the current power market, based on the market-related information issued by the power dispatching organization;
(S2) calculating out the safety constraint unit combination SCUC optimization of the cascade hydroelectric power upstream and downstream power stations by only considering power constraint;
(S3) verifying the information obtained by SCUC optimization calculation by adopting a hydraulic verification model, and continuously calculating the obtained information according to the SCED optimization calculation considering only the electric power constraint to obtain a power generation unit output plan in the corresponding time period for the step hydroelectric output time period meeting the water constraint; continuing to execute the next step for the step hydropower output time interval which does not meet the water constraint;
(S4) for the step hydropower output time interval which does not meet the water constraint, SCED optimization calculation clearing is carried out by simultaneously considering the hydraulic limitation condition and the power constraint, and if a clearing result is obtained, all power generation unit output plans and LMPs of a running day are output after the obtained optimization result is inherited (S3) at the same time; and if the clearing result still cannot be obtained after the SCED optimization calculation, continuously returning the optimization calculation by using the relaxation constraint priority, taking the obtained optimization result as a signal for finishing the relaxation of the constraint condition, failing the optimization when the relaxation times exceed the maximum value and still not obtaining the clearing result, and readjusting the price information declared by the generator.
Further, the market related information in the step (S1) includes a load prediction curve and a market limit.
Further, the power constraint in the step (S2) includes:
(S21) system load balancing constraints;
(S22) generating power limit constraints;
(S23) unit climbing restraint;
(S24) a unit limit/vibration zone constraint;
(S25) minimum continuous start-stop time constraint of the unit;
(S26) restraining the maximum start-stop times of the unit;
(S27) water level control interval constraints;
(S28) transmission branch power constraints.
Further, the SCED in the step (S3) is the minimum total electricity purchase cost, the constraint condition is the power constraint that needs to be considered for the operation of the unit or the power station, and the model input is the power generation unit sectional quotation curve and the time slot unit startup combination that the operation day obtained by the SCUC meets the water constraint; and outputting the model as an output plan of each unit in a corresponding time period of the operating day meeting the water constraint.
Specifically, the relaxation constraint priority in the step (S4) includes three levels, which are: the first-level priority constraint is a control water level interval constraint, the second-level priority constraint is a power transmission branch power constraint, the third-level priority constraint is a system load balance constraint, the maximum relaxation times are set to be (priority) III in parameter initialization, and the initial value is (priority) I.
Compared with the prior art, the invention has the following beneficial effects:
(1) compared with the agent agency mechanism and the hydropower interest compensation mechanism in the background technology, the method provided by the invention solves the embarrassing situation that upstream and downstream information is asymmetric, can ensure that a downstream power station fully participates in the market, improves the competitiveness of a drainage basin in the power spot market, can process the interest distribution problem of different owners of upstream and downstream cascade hydropower stations, ensures the market trade balance, and provides a thought for the weak regulation power station to participate in the spot market construction.
(2) The invention separately considers the electric power constraint and the hydraulic power constraint and adjusts the practical situation, firstly, the SCUC with the electric power constraint is optimized to obtain the clearance, and then the clearance mechanism of the electric power transfer is optimized by the hydraulic power constraint condition and the SCED, so that the situation that the clearance speed is influenced by too many 01 variables generated in the SCUC optimization process and even the clearance result can not be obtained can be avoided, the solving difficulty can be obviously reduced because the model in the electric power transfer process does not contain integer variables, the optimal solution can be always found after certain iteration, the dimension disaster is avoided, the clearance model and the algorithm are simplified to a certain extent, and the invention can be better suitable for practical engineering.
(3) Compared with the two hydropower combined clearing mechanisms in the background technology, the method can enhance the participation degree of the cascade hydropower downstream power station, enhance the competitiveness in the flow field and provide a new idea for the weakly-regulated hydropower station to participate in the spot market. And the electric quantity in the drainage basin is transferred, thereby being beneficial to the comprehensive configuration of water resources and effectively realizing the maximum utilization of the water resources.
(4) The constraint condition relaxation of the invention establishes priority, and increases solving feasible domain by short-time relaxation in a certain proportion range and the priority of the well-ordered constraint condition, thereby obtaining effective clearing optimization result.
Drawings
FIG. 1 is a flow chart of the present invention.
FIG. 2 is a schematic diagram of the price report of the power generation commercial of the power station.
FIG. 3 shows the optimized output of each power station after SCUC optimization according to the present invention.
Fig. 4 shows the output flow of each power station after the SCUC optimization according to the present invention.
Fig. 5 shows scalar quantities of each power generation quotient after the power transfer according to the present invention.
Fig. 6 shows the output flow of each power station after the electric quantity is transferred.
FIG. 7 is a current price of the market node of the present invention.
Detailed Description
The present invention is further illustrated by the following figures and examples, which include, but are not limited to, the following examples.
Examples
As shown in figures 1 to 7, the day-ahead market clearing method for the power transfer of the drainage basin of the multi-owner cascade power station adopts SCUC optimization calculation only considering power constraint to obtain a power generation business output plan at each time interval of an operating day, then uses a hydraulic power verification model and a SCED model jointly considering water and power constraint to carry out inter-drainage-basin power transfer adjustment on the output plan at a certain time interval which does not satisfy the upstream and downstream hydraulic power relation of cascade hydropower to obtain a new clearing result, output plans of all units and node marginal electricity prices (LMP) at the operating day, and simultaneously establishes constraint relaxation priority to expand the feasible area of the power optimization calculation. The specific implementation steps of the method are shown in fig. 2.
The method specifically comprises the following steps:
(S1) after the market starts before the spot-shipment of electric power, according to the market related information released by the electric power dispatching mechanism, such as a load prediction curve, a market limit price and the like, the cascade hydropower upstream power stations participating in the market provide basic unit constraint information to the market operating mechanism, declare a time-period cascade quotation curve, and need to report the current reservoir level, and the market operating mechanism determines the piecewise linear parameters of the function expression of the output and the generating flow of the hydropower station according to the reservoir level reported by the power generator. The unit constraint information and quotation information provided by the downstream power station to the market operating organization are consistent with those of the upstream power station. In addition, a predicted interval water inflow curve and piecewise linear parameters of a function expression of output and power generation flow obtained by calculation according to the current reservoir water level need to be reported.
(S2) calculating out a clear product by adopting SCUC optimization considering only power constraint aiming at the step hydropower station upstream and downstream power stations. The SCUC model objective function is the minimum total electricity purchasing cost; the constraint condition is the power constraint which needs to be considered in the operation of the unit or the power station; inputting a model into a power generation unit sectional quotation curve; and outputting the model as a group combination and an output plan of each unit at 96 starting points on the operating day.
SCUC model:
from the perspective of a market operating organization, an objective function of the SCUC optimization model is the maximization of social welfare and is expressed as the minimum of total electricity purchasing cost. The mathematical model is as follows:
wherein J is the total electricity purchase cost; t is the total time period number considered, and 24 is taken in the application; t is a time interval number; n is a radical of
GNumber of units, n
GNumbering the units, quoting the thermal power generator according to the unit, quoting the hydroelectric power generator according to the station, and numbering the hydroelectric power generator when the hydroelectric power generatorWhen quoted according to a factory station, only the output limit of a unit, the climbing rate, the vibration area and the like need to be linearly superposed; k
GReporting the number of capacity segments, k, for the generator
GReporting a capacity segment number for the generator;
for the generator n
GIn the capacity section k
GThe winning bid amount in time period t;
for the generator n
GIn the capacity section k
GQuotes over a period of time t.
The power constraints are as follows:
(S21) system load balancing constraints.
Wherein j is a tie line number; t is
j,tThe planned power for tie-line j at time t (positive input and negative output); NT is the total number of tie lines; d
tThe system load for time period t.
(S22) generating power limit constraint.
Wherein,
and
for a time period of t
GMaximum and minimum output forces;
for a time period of t
GIs measured.
(S23) the unit climbing restraint.
Wherein, Δ P
i U、ΔP
i DAre respectively a unit n
GMaximum upward climbing rate and maximum downward climbing rate.
(S24) restraining a unit limiting area (vibration area).
Wherein,
are respectively a unit n
G(typically a hydroelectric generating set) up/down limit of the kth vibration zone.
(S25) minimum continuous on-off time constraint of the unit.
Wherein, T
U、T
DRespectively the minimum continuous starting time and the minimum continuous stopping time of the unit;
are respectively a unit n
GTime that has been continuously powered on and time that has been continuously powered off at time period t;
for a time period of t
GIs measured.
And (S26) restraining the maximum starting and stopping times of the unit.
First, the startup and shutdown switching variables are defined. Definition of
Representing a unit n
GWhether to switch to the activated state at time period t; definition of
Representing a unit n
GWhether or not to switch to the shutdown state at time t,
the following conditions are satisfied:
unit n
GThe start-stop number limit of (c) can be expressed as follows:
wherein, define
Representing a unit n
GWhether to switch to the activated state at time period t; definition of
Representing a unit n
GWhether or not to switch to the shutdown state at time t.
(S27) water level control interval constraint.
Wherein,
respectively representing the upper and lower water level limits of the hydropower station u at the moment t; z
u,tRepresenting the level of the hydropower station u at time t.
(S28) transmission branch power constraints.
-P
l max≤P
l,t≤P
l max(14)
Wherein, P
l maxThe power transmission limit of branch l for time period t; p
l,tThe transmission power of branch l for a period t.
(S3) verifying the information obtained by SCUC optimization calculation by adopting a hydraulic verification model, and continuously calculating the obtained information according to the SCED optimization calculation considering only the electric power constraint to obtain a power generation unit output plan in the corresponding time period for the step hydroelectric output time period meeting the water constraint; continuing to execute the next step for the step hydropower output time interval which does not meet the water constraint; wherein, the SCED model objective function is the minimum of the total electricity purchasing cost; the constraint condition is the power constraint (no longer related to the unit 01 integer variable) which needs to be considered in the operation of the unit or the power station; the model inputs a section quotation curve of a power generation unit and a time interval unit startup combination which is obtained by SCUC and has running days meeting water constraints; the model output is the output plan of each unit in the time period of the operation day meeting the water constraint.
Hydraulic verification model:
the relation between the optimized output and the generated flow of the cascade hydropower station can be generally expressed by adopting a piecewise linear function:
wherein u and d are respectively upstream and downstream power station codesNumber; p
u,tAnd P
d,tRespectively the output of an upstream power station and a downstream power station;
and
respectively the output flow of an upstream power station and a downstream power station;
and
piecewise linear fitting parameters in a period t; k is a radical of
uAnd k
dThe segment intervals are numbered.
The inflow water flow of the cascade hydroelectric downstream power station comprises the generated water flow of the upstream power station and the interval natural inflow water flow of
Wherein u is an upstream power station unit; d is a downstream power station unit;
the water inflow of a downstream power station in a time period t; i is
d,tThe natural inflow water flow rate of the middle section in the time period t; tau is
u,dIs the water flow time lag constant between the upstream and downstream power stations; e.g. of the type
γThe coefficient of river channel leveling.
After the SCUC optimization calculation obtains a clear result, the linear functions (15) and (16) of the optimized output and the power generation flow are converted into the output water quantities of the upstream and downstream of the step hydropower station, and then the hydraulic limitation is verified, namely the output water quantities of the upstream and downstream power stations of the step hydropower station are compared, and the water inflow reaching the downstream power station is ensured to be larger than or equal to the difference between the output water quantity of the downstream power station and the natural water inflow in the interval, and the result is expressed as:
for special requirements in actual scheduling, if a part of cascade hydropower stations cannot generate water abandon phenomenon in a leveling period, the related hydraulic limitation check of the part of cascade hydropower is as follows:
(S4) for the cascade hydropower output time interval which does not meet the water constraint, SCED optimization calculation considering the hydraulic limitation condition and the power constraint at the same time is adopted to obtain a clear (wherein SCED is the minimum total electricity purchasing cost, the constraint condition is the hydraulic constraint and the power constraint which need to be considered in the operation of the unit or the power station, the model input is a power generation unit subsection price curve, SCUC is obtained, the operation day does not meet the water constraint time interval unit startup combination), and if a clear result is obtained, the obtained optimization result is inherited (S3) at the same time, and all power generation unit output plans and LMP on the operation day are output. And if the clearing result still cannot be obtained after the SCED optimization calculation, continuously returning the optimization calculation by using the relaxation constraint priority, taking the obtained optimization result as a signal for finishing the relaxation of the constraint condition, failing the optimization when the relaxation times exceed the maximum value and still not obtaining the clearing result, and readjusting the price information declared by the generator. And (5) constraint relaxation priority processing. In model solution, a few constraint conditions in the output model are usually allowed to relax within a certain proportion range in a short time to increase the solution feasible region, so that an effective output optimization result is obtained. Based on different degrees of influence of various constraints on the operation of the safety constraints of the power grid, the relaxation constraints are prioritized, and the secondary constraints are relaxed firstly. In the patent of the invention, the I-level priority constraint is a control water level interval constraint, the II-level priority constraint is a power transmission branch power constraint, and the III-level priority constraint is a system load balance constraint. Meanwhile, the maximum relaxation times are set to be III in parameter initialization, and the initial value is set to be I.
At the moment, the SCED model objective function is the minimum total electricity purchasing cost; the constraint conditions are power constraint and hydraulic limitation conditions (the integral variable of the unit 01 is not related) which need to be considered in the operation of the unit or the power station; the model inputs are a section quotation curve of a power generation unit, a starting combination of the unit in a running day which is obtained by SCUC and does not accord with a water constraint time interval, and an SCED optimization result in (S3); and outputting the model to be the re-optimized output plan of each unit in the running day which does not conform to the water constraint time period.
Constraint relaxation priority model:
the I-level priority constraint is a control water level interval constraint. When the clear result can not be obtained, the restriction of the control water level interval is returned to be adjusted, and the upper limit and the lower limit of the output of the power generation unit can be indirectly adjusted by properly loosening the control water level interval. That is, equation (13) adjusts to when a relaxation signal is received:
wherein Z is
u,tRepresenting the water level of the hydropower station u at the time t;
the backward relaxation variable and the forward relaxation variable of the water level constraint interval are respectively.
The class ii priority constraint is (S28) a transmission branch power constraint, and the relaxation order of the plurality of lines is determined according to the scheduling experience, and a weight coefficient is added therein. Upon receipt of a signal that there is no clear result after the I-level priority constraint is relaxed, equation (14) is adjusted to:
-P
l max-ΔP
l -≤P
l,t≤P
l max+ΔP
l +(21)
wherein, P
l,tThe transmission power of branch l for a period t; delta P
l-、ΔP
l +The backward and forward relaxation variables of the branch power constraint are respectively.
The level iii priority constraint is (S21) a system load balancing constraint, that is, the solution domain is expanded by limiting the amount of outgoing power at the load end or reducing the local load. When a signal that no clear result is obtained after the I-level and II-level priority constraints are relaxed is received, equation (2) is adjusted as follows:
wherein,
part of the output electricity is reduced; delta D
tTo illustrate the portion of the total system load shedding; t is
j,tThe planned power for tie-line j at time t (positive input and negative output); NT is the total number of tie lines; d
tThe system load for time period t.
Meanwhile, when the K-level priority constraint is relaxed, the I-level priority constraint of K-I, K-II, K-III and the like still keeps a relaxed state.
SCED model:
in the present application, the optimized target of the SCED is consistent with the SCUC, which is the minimum total electricity purchase cost, the mathematical model is also expressed by formula (1), and the constraints of the SCED optimized model include electric power constraint and hydraulic power limitation check. Hydraulic limitation checking is represented by formulas (18) and (19); the power constraint no longer contains a 01 variable, and is given by equations (2), (14) and:
wherein m is
0Numbering the vibration region regions which are determined by SCUC optimization; delta P
i U、ΔP
i DAre respectively a unit n
GThe maximum upward climbing speed and the maximum downward climbing speed;
are respectively a unit n
G(typically a hydroelectric generating set) up/down limit of the kth vibration zone.
According to the specific embodiment, the market trading area in the day ahead, which comprises 3 thermoelectric power generators and 2 thermoelectric power generators in the same drainage basin, is constructed. Wherein, the generators 1, 2 and 3 are planned to be conventional thermal power plants; the power generators 4 and 5 are stepped hydroelectric upstream and downstream power stations of the basin 1, respectively. The method is used for constructing a day-ahead market trading area containing 4 hydropower generators and 2 hydropower generators in the same drainage basin based on an IEEE 13 node standard test system, and the line parameters are shown in table 1. Wherein, the generators 1, 2, 3 and 4 are planned to be conventional thermal power plants; the power generators 5 and 6 are respectively the cascade hydroelectric upstream and downstream power stations of the basin 1, and part of the operation parameters are shown in table 2. The water flow time lag is assumed to be 1h, no interval water inflow exists, the river channel is smooth, and the power generation amount of a downstream power station is the power generation flow of an upstream power station.
TABLE 1 line parameters
TABLE 2 partial Generator operating parameters
Fig. 3 shows that various power station generators deal with load changes through strategic quotation, the results of two times of optimized output are basically consistent with the change trend of a load curve, and the optimized output is obviously higher than that in other periods during peak load periods. At the moment, the optimization model does not contain hydraulic restriction, meanwhile, the cascade hydropower downstream power station power generator adopts an independent flexible bidding strategy under the condition that strategy information of the upstream power station power generator is not obtained, and the downstream power station bears marginal units even at some load peak time.
According to the mathematical model, the output flow of the hydropower station and the optimized output are in a linear relation as shown in fig. 4, so that the flow trend after optimization is consistent with the optimized output trend of each power station in fig. 3, and the output flow at the peak load stage is obviously higher than that at other periods. However, on the premise that the water flow time lag is 1h and no interval water comes, the output flow of the downstream power station in the time periods of 7-13 and 16-20 is higher than that of the upstream power station in the previous 1h, and does not meet the hydraulic coupling relation of the upstream power station and the downstream power station of the cascade hydropower station, if the watershed electric quantity transfer is not carried out, the real power generation amount of the downstream power station is unbalanced with the optimized electric quantity, and therefore the transaction cannot be executed.
As can be seen by comparing fig. 5 with fig. 3, the trading power of the cascaded hydroelectric power generator changes significantly in some periods under the same price, for example: the actual transaction electric quantity of the downstream power station power generator is reduced by 43.5MW at the 7 th hour, reduced by 54MW at the 8 th hour, the subsequent time period is adjusted to be lower than that of the upstream power station, and the exchange electric quantity of the power generators of the power stations in the rest time periods is slightly adjusted.
As can be seen from fig. 6, the output flow of the downstream plant at each time interval at this time is significantly delayed or equal to the output flow of the upstream plant of the first 1 h: when the downstream plant output decreased by 43.5MW as in 7h, its output flow decreased by 74m3, which is on the same level as the upstream plant output flow for the first 1 h. The electric quantity transferring and clearing mechanism can effectively promote the competitive strength of the downstream power station in the drainage basin and realize the exertion of the overall benefit of the drainage basin while not violating the hydraulic coupling relation of the upstream power station and the downstream power station of the cascade hydropower.
In fig. 7, the day-ahead LMP of each node of the system is obtained by simulating day-ahead market trading, the overall trend of the LMP is basically consistent with the system load trend, and the change of the supply-demand relationship of the spot market is presented in the form of price. Comparing different LMPs in the graph, the LMPs of each node are equal at the time of 0:00-8:00 before the peak load, and in the subsequent two peak load periods, the LMPs of a few nodes are different, for example, the LMP of the node 2 at the time of 18:00 is 420 yuan/(MW & h), and the LMPs of the rest nodes are only 400 yuan/(MW & h), which is caused by the fact that the lines are blocked to different degrees, and at the time of 18:00-20:00, each power station is in the peak output stage, the transmission channel is blocked seriously, and the LMPs of the few nodes are increased.
The above embodiments are only preferred embodiments of the present invention, and are not intended to limit the scope of the present invention, but all changes that can be made by applying the principles of the present invention and performing non-inventive work on the basis of the principles shall fall within the scope of the present invention.
Claims (5)
1. A method for clearing the day-ahead market for transferring the electric quantity of a multi-owner cascade power station basin is characterized by comprising the following steps:
(S1) after the market starts before the current power market, based on the market-related information issued by the power dispatching organization;
(S2) calculating out the safety constraint unit combination SCUC optimization of the cascade hydroelectric power upstream and downstream power stations by only considering power constraint;
(S3) verifying the information obtained by SCUC optimization calculation by adopting a hydraulic verification model, and continuously calculating the obtained information according to the SCED optimization calculation considering only the electric power constraint to obtain a power generation unit output plan in the corresponding time period for the step hydroelectric output time period meeting the water constraint; continuing to execute the next step for the step hydropower output time interval which does not meet the water constraint;
(S4) for the step hydropower output time interval which does not meet the water constraint, SCED optimization calculation clearing is carried out by simultaneously considering the hydraulic limitation condition and the power constraint, and if a clearing result is obtained, all power generation unit output plans and LMPs of a running day are output after the obtained optimization result is inherited (S3) at the same time; and if the clearing result still cannot be obtained after the SCED optimization calculation, continuously returning the optimization calculation by using the relaxation constraint priority, taking the obtained optimization result as a signal for finishing the relaxation of the constraint condition, failing the optimization when the relaxation times exceed the maximum value and still not obtaining the clearing result, and readjusting the price information declared by the generator.
2. The method of claim 1, wherein the market-related information in step (S1) includes load forecast curves and market limits.
3. The method of claim 1, wherein the step (S2) of power constraint includes:
(S21) system load balancing constraints;
(S22) generating power limit constraints;
(S23) unit climbing restraint;
(S24) a unit limit/vibration zone constraint;
(S25) minimum continuous start-stop time constraint of the unit;
(S26) restraining the maximum start-stop times of the unit;
(S27) water level control interval constraints;
(S28) transmission branch power constraints.
4. The method of claim 1, wherein the SCED in step (S3) is the minimum total electricity purchase cost, the constraint condition is the power constraint to be considered for the operation of the unit or station, and the model inputs are the power generation unit sectional quotation curve and the time slot unit startup combination of the operating day obtained by the SCUC and the water constraint; and outputting the model as an output plan of each unit in a corresponding time period of the operating day meeting the water constraint.
5. The method of claim 1, wherein the relaxation constraint priority of step (S4) comprises three levels, respectively: the first-level priority constraint is a control water level interval constraint, the second-level priority constraint is a power transmission branch power constraint, the third-level priority constraint is a system load balance constraint, the maximum relaxation times are set to be III in parameter initialization, and the initial value is I.
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