CN110323787B - Iterative optimization method for junctor exchange power - Google Patents

Iterative optimization method for junctor exchange power Download PDF

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CN110323787B
CN110323787B CN201910584675.8A CN201910584675A CN110323787B CN 110323787 B CN110323787 B CN 110323787B CN 201910584675 A CN201910584675 A CN 201910584675A CN 110323787 B CN110323787 B CN 110323787B
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power generation
generation cost
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CN110323787A (en
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张新松
顾菊平
曹书秀
陆胜男
华亮
朱建红
郭晓丽
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Nantong University
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    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q10/00—Administration; Management
    • G06Q10/04—Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
    • G06Q50/06—Electricity, gas or water supply
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/008—Circuit arrangements for ac mains or ac distribution networks involving trading of energy or energy transmission rights
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
    • H02J3/46—Controlling of the sharing of output between the generators, converters, or transformers
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
    • H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E40/00—Technologies for an efficient electrical power generation, transmission or distribution
    • Y02E40/70—Smart grids as climate change mitigation technology in the energy generation sector
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S10/00—Systems supporting electrical power generation, transmission or distribution
    • Y04S10/50—Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications

Abstract

The invention relates to the technical field of power grid optimization, in particular to a tie line exchange power iterative optimization method. The invention provides a tie line exchange power iterative optimization method which mainly comprises the following steps: optimizing and obtaining the output arrangement of each regional power grid by taking the minimized power generation cost of each regional power grid as a target according to the unit power generation cost and safety constraint, the initial tie line exchange power and the short-term load prediction result; the method comprises the steps that with the aim of reducing the total power generation cost of two regional power grids, iterative updating is carried out on the exchange power of a tie line in each scheduling period based on the real-time marginal power generation cost of the regional power grids; and repeating the previous step until the total power generation cost can not be reduced by updating the junctor exchange power between the two regional power grids, and obtaining the iteratively optimized junctor exchange power and the unit output arrangement in each time period. According to the method, the total power generation cost of the two regional power grids is effectively reduced through a small amount of data communication, a large amount of data transmission is avoided, and data privacy is protected.

Description

Iterative optimization method for junctor exchange power
Technical Field
The invention relates to the technical field of power grid optimization, in particular to a tie line exchange power iterative optimization method.
Background
At present, the development of the construction of the ultrahigh voltage power grid in China is different day by day, the number of the ultrahigh voltage alternating current and direct current transmission lines is continuously increased, and the alternating current and direct current ultrahigh voltage regional power grid which controls the region span to be increasingly expanded and has tighter electrical connection is formed. Through multizone electric wire netting interconnection, carry out the cross-area transaction, be favorable to the resource in the optimal configuration of whole network within range, improve holistic economic nature and security. The unit combination is to make a reasonable unit output scheme according to various constraint conditions of the system and parameters of the generator unit, so that the minimum total power generation cost is realized. However, in the existing scheduling mode, most of the unit combinations can only optimize the power generation resources in the regional power grid, and the resource optimization in the whole grid range cannot be considered. Therefore, on the basis of the combination result of the regional power grid unit, the optimization of the exchange power of the tie line is one of the key links for realizing the cross-regional resource optimization configuration in the existing scheduling plan mode, and the method is an effective way for improving the energy utilization efficiency. Obviously, the tie line exchange power optimization has a great effect on the resource configuration of the power system, but the prior art has a certain limitation because of the lack of practical connection with the power grid or the insufficient consideration of the global optimization of the system.
Disclosure of Invention
The invention aims to provide a tie line exchange power iterative optimization method, which gives full play to the functions of tie lines in a regional power grid and reduces the total power generation cost of the whole grid.
In order to achieve the above object, the present invention provides a tie line exchange power iterative optimization method, which is applied to two interconnected regional power grids, and comprises:
s1, optimizing to obtain initial unit output arrangement of two regional power grids with the aim of minimizing the power generation cost of each regional power grid as a target according to the unit power generation cost and safety constraint, initial tie line exchange power and short-term load prediction results;
s2, calculating initial total power generation cost;
s3, aiming at reducing the total power generation cost, performing iterative optimization by updating the output arrangement and the junctor exchange power of the power grids in two areas in each scheduling period, and then calculating the total power generation cost;
and S4, comparing the total power generation cost calculated in the step S3 with the initial total power generation cost, if the total power generation cost is lower than the initial total power generation cost, replacing the initial total power generation cost with the total power generation cost calculated in the step S3, returning to the step S3, otherwise, stopping iteration, and outputting the junctor exchange power and the corresponding unit output arrangement of the two regional power grids in each scheduling time period in the current state.
Preferably, in step S3, aiming at reducing the total power generation cost, the performing the iterative optimization by updating the export arrangement and the tie line exchange power of the two regional power grids in each scheduling period is to update the export arrangement and the tie line exchange power of the two regional power grids in the tth scheduling period according to the following steps, where T is 1,2, …, T is a preset number of scheduling periods:
s31, respectively calculating marginal power generation costs of two regional power grids in the t-th scheduling period, and specifically comprising the following steps: calculating the marginal power generation cost of each generator set of the two regional power grids in the t-th scheduling time period, selecting the generator set with the highest marginal power generation cost in the current scheduling time period as the marginal generator set in the corresponding regional power grid, and setting the marginal power generation cost of the regional power grid in the t-th scheduling time period as the marginal power generation cost of the marginal generator set;
s32, judging whether an updating condition is met or not according to the marginal power generation cost of two regional power grids in the t-th scheduling period and a preset exchange power updating step length of the tie line, if the updating condition is met, reducing the marginal unit power generation power of the regional power grid with higher marginal power generation cost in the t-th scheduling period according to the exchange power updating step length of the tie line, increasing the marginal unit power generation power of the regional power grid with lower marginal power generation cost in the t-th scheduling period according to the exchange power updating step length of the tie line, and correspondingly updating the exchange power of the tie line in the t-th scheduling period according to the exchange power updating step length of the tie line; if the updating condition is not met, the exchange power of the tie lines of the two regional power grids and the corresponding output arrangement of the unit are unchanged in the t-th scheduling period;
wherein the update condition is represented by the following formula:
Figure BDA0002114139210000021
in the above formula, ρG,tThe marginal power generation cost of the regional power grid with higher marginal power generation cost in the tth scheduling period is set; rhoF,tMarginal power generation cost of the regional power grid with lower marginal power generation cost in the t-th scheduling period; rhoLThe price is transmitted to the electric energy of the tie line between the two regional power grids; pL,tExchanging power for the tie line for the t-th scheduling period; pSExchanging a power updating step length for a preset connecting line; pL,maxTransmitting a power limit for the regional grid tie;
Figure BDA0002114139210000022
marginal unit k of regional power grid with higher marginal power generation cost for t-th scheduling periodGThe generated power of (c);
Figure BDA0002114139210000023
marginal unit k of regional power grid with lower marginal power generation cost for t-th scheduling periodFThe generated power of (c);
Figure BDA0002114139210000024
marginal unit k of regional power grid with higher marginal power generation cost for tth scheduling periodGMinimum output of (d);
Figure BDA0002114139210000025
marginal unit k of regional power grid with lower marginal power generation cost for tth scheduling periodFThe maximum force applied.
Compared with the prior art, the invention provides a tie line exchange power iterative optimization method. Firstly, according to the generating cost and safety constraint of the unit, the exchange power of the initial tie line and the short-term load prediction result, the unit combination is respectively carried out on each regional power grid, and the initial unit output arrangement of each regional power grid is obtained through optimization with the aim of minimizing the generating cost of each regional power grid as a target. Then, on the basis of the unit combination result, the unit output arrangement of the two regional power grids in each scheduling time interval is changed time interval by time interval according to the real-time marginal cost of each regional power grid and the maximum/minimum output technical constraint of the marginal unit, the electric energy transmission price of the tie line between the regional power grids, the transmission power limit of the tie line and the preset tie line exchange power updating step length, the unit output arrangement of the two regional power grids in each scheduling time interval is optimized by updating the tie line exchange power of the two regional power grids in each scheduling time interval, the optimized tie line transmission power and the optimized unit output arrangement of the two regional power grids in each scheduling time interval are obtained, and the aim of reducing the whole-grid power generation cost is fulfilled. The above processes are repeated until the total power generation cost can not be reduced by updating the exchange power of the tie lines between the two regional power grids, and the total power generation cost of the two regional power grids reaches the optimum value. At this time, the tie line exchange power of the two regional power grids is the optimal tie line exchange power. According to the method, only a small amount of data communication is needed between the interconnected regional power grids, a large amount of data transmission is avoided, data privacy is protected, and the total power generation cost of the two regional power grids is effectively reduced by updating the exchange power of the tie lines.
Detailed Description
The technical solutions in the embodiments of the present invention are clearly and completely described below with reference to 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.
The embodiment of the invention provides a tie line exchange power iterative optimization method, which is applied to two interconnected regional power grids and specifically comprises the following steps:
s1: optimizing to obtain initial unit output arrangement of two regional power grids with the aim of minimizing the power generation cost of each regional power grid as a target according to the unit power generation cost and safety constraint, the initial tie line exchange power and a short-term load prediction result;
the two regional power grids are respectively marked as a regional power grid 1 and a regional power grid 2, and the forward direction of the exchange power of the tie lines of the two regional power grids in each scheduling period is defined as the active power flowing from the regional power grid 2 to the regional power grid 1. Optimizing to obtain initial unit output arrangement of the regional power grid 1 and the regional power grid 2 according to the unit power generation cost and safety constraint, the initial tie line exchange power and the short-term load prediction result by respectively taking the power generation cost minimization of the regional power grid 1 and the regional power grid 2 as a target;
s2, calculating initial total power generation cost;
and calculating to obtain initial total power generation cost according to the initial tie line exchange power and the power generation cost of the regional power grid 1 and the regional power grid 2.
S3, aiming at reducing the total power generation cost, performing iterative optimization by updating the junctor exchange power of each scheduling time interval between the two regional power grids and the output arrangement of each scheduling time interval of the two regional power grids, and then calculating the total power generation cost;
with the aim of reducing the total power generation cost, the iterative optimization is carried out by updating the junctor exchange power of each scheduling time interval between the two regional power grids and the output arrangement of each scheduling time interval of the two regional power grids, and the method specifically comprises the following steps:
firstly, according to the unit output arrangement of the two regional power grids in each scheduling time interval solved in step S1, the marginal power generation costs of the regional power grid 1 and the regional power grid 2 are calculated time interval by time interval, and the specific calculation formula is as follows:
ρi,t＝2ai,kPi,k,t+bi,k (1)
in the above formula, ρi,tThe marginal power generation cost of a regional power grid i in the t-th scheduling period is obtained, wherein i is a regional power grid index, and i is 1 or 2; t is a scheduling time interval index, and the whole scheduling interval consists of T scheduling time intervals, wherein T is 1,2, 3, ·, T; a isi,kAnd bi,kThe method comprises the steps that power generation cost data of marginal unit K of a regional power grid i are respectively generated, wherein K is a marginal unit index of each regional power grid in each scheduling time interval, each regional power grid is composed of K units, and K is 1,2, 3, ·, K; pi,k,tAnd generating power of the boundary unit k in the t scheduling period for the regional power grid i. Wherein, the regional power grid i is scheduled at the tAnd if the marginal power generation cost in the time interval is the maximum value of the marginal power generation cost of all the startup units of the regional power grid in the current scheduling time interval, the corresponding unit is the marginal unit of the regional power grid i in the t-th scheduling time interval. With the iterative update of the exchange power of the tie line, the marginal unit of each regional power grid in the current scheduling period may change, that is, the marginal unit index k of each regional power grid in each scheduling period may change.
Then, updating the tie line exchange power of the regional power grids 1 and 2 in each scheduling time interval by time interval through a preset tie line exchange power updating step length, a tie line electric energy transmission price, a tie line transmission power limit constraint and a marginal unit maximum/minimum output technology constraint, and specifically updating the exchange power of the tie line in the tth scheduling time interval according to the following steps, wherein T is 1,2, …, T is a preset scheduling time interval number:
(1) within the t-th scheduling period, if ρ1,t＞ρ2,tWhen the marginal power generation cost of the regional power grid 1 is high, G is 1, the marginal power generation cost of the regional power grid 2 is low, and F is 2, and the constraint conditions shown in the formula (2) are met, the interconnection line exchange power and the output arrangement of the marginal units of the regional power grids 1 and 2 in the current scheduling time period need to be updated.
Figure BDA0002114139210000031
In the above formula, ρL,tFor tie line electric energy delivery price, unit: $ MW; pL,tFor the exchange power of the tie line in the t-th scheduling period, the unit: MW; pSExchange power update step length for preset junctor, unit: MW; pL,maxFor the tie line transmit power limit, the unit: MW; p1,k1,t、P2,k2,tRespectively, marginal unit output values of the regional power grids 1 and 2 in the t-th scheduling period, unit: MW;
Figure BDA0002114139210000032
marginal for regional grid 1 in the tth scheduling periodMinimum output of the unit, unit: MW;
Figure BDA0002114139210000033
the maximum output of the marginal unit of the regional power grid 2 in the t-th scheduling period is as follows: MW. Wherein k is1、k2And respectively indexing marginal unit of the regional power grids 1 and 2 in the t-th scheduling period. If all the constraint conditions are met, the difference between the marginal power generation costs of the two regional power grids in the t-th scheduling period is larger than the transmission price of the tie line, and the limit constraint of the transmission power of the tie line and the maximum/minimum output technology constraint of the marginal unit are met. At this time, the tie line exchange power and the output value of the marginal unit between the two regional grids in the current scheduling period may be updated according to the following formula:
Figure BDA0002114139210000041
in the current scheduling period, after the marginal power generation cost of the regional power grid 1 is subtracted by the marginal power generation cost of the regional power grid 2, the difference value is larger than the power transmission price of the tie line. As the positive direction of the junctor exchange power of the two regional power grids at each scheduling period is defined as the active power flowing from the regional power grid 2 to the regional power grid 1, the junctor exchange power is increased by PSCorrespondingly, the marginal unit output value of the regional power grid 1 is adjusted downward PSAnd the output value of the marginal unit of the regional power grid 2 is adjusted up by PS。
(2) Within the t-th scheduling period, if ρ1,t＜ρ2,tWhen the marginal power generation cost of the regional power grid 1 is low, F is 1, the marginal power generation cost of the regional power grid 2 is high, G is 2, and the constraint condition shown in the formula (4) is met, the interconnection line exchange power and the output arrangement of the marginal unit of the regional power grids 1 and 2 in the current scheduling time period need to be updated, and the specific updating formula is shown in the formula (5).
Figure BDA0002114139210000042
In the above formula, ρL,tFor tie line electric energy delivery price, unit: $ MW; pL,tFor the exchange power of the tie line in the t-th scheduling period, the unit: MW; pSExchange power update step length for preset junctor, unit: MW; pL,maxFor the tie line transmit power limit, the unit: MW; p1,k1,t、P2,k2,tRespectively, marginal unit output values of the regional power grids 1 and 2 in the t-th scheduling period, unit: MW;
Figure BDA0002114139210000043
the maximum output of the marginal unit of the regional power grid 1 in the t-th scheduling period is as follows: MW;
Figure BDA0002114139210000044
the maximum output of the marginal unit of the regional power grid 2 in the t-th scheduling period is as follows: MW. Wherein k is1、k2And respectively indexing marginal unit of the regional power grids 1 and 2 in the t-th scheduling period. If all the constraint conditions are met, the difference between the marginal power generation costs of the two regional power grids in the t-th scheduling period is larger than the transmission price of the tie line, and the limit constraint of the transmission power of the tie line and the maximum/minimum output technology constraint of the marginal unit are met. At this time, the tie line exchange power and the output value of the marginal unit between the two regional grids in the current scheduling period may be updated according to the following formula:
Figure BDA0002114139210000045
in the current scheduling period, after the marginal power generation cost of the regional power grid 2 is subtracted by the marginal power generation cost of the regional power grid 1, the difference value is larger than the power transmission price of the tie line. Since the positive direction of the junctor exchange power of the two regional power grids in each scheduling period is defined as the active power flowing from the regional power grid 2 to the regional power grid 1, the junctor exchange power is reduced by PSCorrespondingly, the marginal unit output value of the regional power grid 1 is adjusted up by PSAnd the marginal unit output value of the regional power grid 2 is adjusted downwards by PS。
(3) And in the t-th scheduling period, if the condition of the formula (2) or the formula (4) is not met, keeping the exchange power of the tie lines of the two regional power grids and the output of the marginal unit unchanged in the current scheduling period.
And after the exchange power of the tie lines in all the scheduling time is updated, calculating the updated total power generation cost, comparing the updated total power generation cost with the initial total power generation cost, if the updated total power generation cost is lower than the initial total power generation cost, replacing the initial total power generation cost with the total power generation cost calculated in the step S3, returning to the step S3, otherwise, stopping iteration, and outputting the exchange power of the tie lines of the two regional power grids in each scheduling time period and the corresponding output arrangement of the unit in the current state.
And S4, comparing the total power generation cost calculated in the step S3 with the initial total power generation cost, if the total power generation cost is lower than the initial total power generation cost, replacing the initial total power generation cost with the total power generation cost calculated in the step S3, returning to the step S3, otherwise, stopping iteration, and outputting the junctor exchange power and the corresponding unit output arrangement of the two regional power grids in each scheduling time period in the current state.
The initial value of the tie exchange power of the regional power networks 1,2 is the tie exchange power given by the tie long-term power exchange plan, from which, in the manner described above, on the basis of the initial unit combination result, the unit output arrangement of two regional power grids in each scheduling period is changed time by time only according to the real-time marginal cost of each region, the upper and lower output limits of the real-time marginal unit of each region, the electric energy transmission price of the inter-region tie lines, the transmission power limit of the tie lines and the updating step length of the preset tie lines, by updating the tie line exchange power of the two regional power grids in each scheduling period, the unit output arrangement of the two regional power grids in each scheduling period is optimized, the optimized tie line transmission power and the optimized unit output arrangement of the two regional power grids in each scheduling period are obtained, and the aim of reducing the whole-grid power generation cost is fulfilled. And repeating the process until the exchange power of the tie line between the two areas cannot be updated, and the total power generation cost of the two area power grids reaches the optimum value. At this time, the tie line exchange power of the two regional power grids is the optimal tie line exchange power.
Firstly, inputting power generation cost data, technical parameters, short-term load prediction data and initial exchange power of a tie line of a unit in a scheduling period, and respectively combining the units in each regional power grid; then, a tie electricity transmission price, a tie exchange power update step size, and a tie transmission power limit value are inputted. In the embodiment, 2 regional power grids are provided, each regional power grid is provided with 10 generator sets, specific parameters of the generator sets are shown in tables 1 and 2, and load prediction data are shown in table 3.
It should be noted that in this embodiment, one scheduling cycle is one day, one scheduling period is 1 hour, and there are 24 scheduling periods in one scheduling cycle.
TABLE 1 regional grid 1 Generator set parameters
Figure BDA0002114139210000051
TABLE 2 regional grid 2 Generator set parameters
Figure BDA0002114139210000052
TABLE 3 load forecast data
Figure BDA0002114139210000053
The initial unit startup plan, the output arrangement and the load of the regional power grids 1 and 2 are shown in tables 4 and 5, respectively, and the parameters of the tie line between the two regional power grids are shown in table 6.
TABLE 4 regional grid 1 initial unit output arrangement
Figure BDA0002114139210000061
TABLE 5 regional grid 2 initial unit output scheduling
Figure BDA0002114139210000062
TABLE 6 Link parameters
Figure BDA0002114139210000071
The computer hardware environment for executing optimization is Intel (R) core (TM) i5-8265U, the dominant frequency is 1.60GHz, and the internal memory is 8 GB; the software environment is a Windows 10 operating system. The above data are adopted for simulation, table 7 and table 8 respectively show the optimal unit output arrangement of the regional power grids 1 and 2, and as can be seen from tables 7 to 8: the two regional power grids can completely meet the load requirement in the whole dispatching cycle without the condition of abandoning the electric energy.
TABLE 7 regional grid 1 optimal set output arrangement
Figure BDA0002114139210000072
TABLE 8 regional grid 2 optimal set output arrangement
Figure BDA0002114139210000073
Figure BDA0002114139210000081
As can be seen from Table 7, the total output of the regional power grid 1 in the scheduling periods 1 and 2 is increased by 60MW, and the total output of the regional power grid 1 in the scheduling periods 3, 8 and 15-19 is decreased by 10 MW. As shown in table 8, the total unit output of the regional power grid 2 in the scheduling periods 1 and 2 is reduced by 60MW, and the total unit output of the regional power grid 2 in the scheduling periods 3, 8, and 15-19 is increased by 10MW, which indicates that the tie line exchange power is iteratively updated based on the real-time marginal power generation cost of the regional power grid, and the function of the tie line transmission power between the regional power grids can be fully exerted.
TABLE 9 optimal tie line exchange power
Figure BDA0002114139210000082
Table 9 shows the optimal tie line exchange power and transmission cost, visually shows the flow direction of the exchange power of the tie lines between the regional power grids 1 and 2 in each scheduling period, and in the scheduling periods 1 and 2, the active power flows from the regional power grid 1 to the regional power grid 2 through the tie lines, and the values are all 60 MW. In the scheduling periods 3, 8 and 15-19, active power flows from the regional power grid 2 to the regional power grid 1 through the tie line, all at a value of 10 MW.
Table 10 gives the initial total power generation cost and the optimized total power generation cost for the regional grids 1, 2. Therefore, the initial total power generation cost of the whole grid is 1297017.8$, the optimized optimal total power generation cost of the whole grid is 1272200.8$, the cost is reduced by 24817$, and the economic benefit is obviously improved.
TABLE 10 comparison of operating economics
Figure BDA0002114139210000083
The analysis of the results shows that the method has important significance for reducing the total power generation cost of the whole network and improving the operation economy by optimizing the exchange power of the tie lines and simultaneously coordinating and optimizing the power generation plan in each regional power grid.
The method for optimizing the junctor exchange power provided by the application is described in detail above, and the above description is only used for helping to understand the method and the core idea of the application. It should be noted that, for those skilled in the art, it is possible to make various improvements and modifications to the present application without departing from the principle of the present application, and such improvements and modifications also fall within the scope of the claims of the present application.
The embodiments are described in a progressive manner in the specification, each embodiment focuses on differences from other embodiments, and the same and similar parts among the embodiments are referred to each other. The device disclosed by the embodiment corresponds to the method disclosed by the embodiment, so that the description is simple, and the relevant points can be referred to the method part for description.

Claims (1)

1. An iterative optimization method for exchange power of a tie line is applied to two interconnected regional power grids, and is characterized in that the iterative optimization method comprises the following steps:
s1, optimizing to obtain initial unit output arrangement of two regional power grids with the aim of minimizing the power generation cost of each regional power grid as a target according to the unit power generation cost and safety constraint, initial tie line exchange power and short-term load prediction results;
s2, calculating initial total power generation cost;
s3, aiming at reducing the total power generation cost, performing iterative optimization by updating the output arrangement and the junctor exchange power of the power grids in two areas in each scheduling period, and then calculating the total power generation cost;
s4, comparing the total power generation cost calculated in the step S3 with the initial total power generation cost, if the total power generation cost is lower than the initial total power generation cost, replacing the initial total power generation cost with the total power generation cost calculated in the step S3, returning to the step S3, otherwise, stopping iteration, and outputting the unit output arrangement and the corresponding tie line exchange power of the two regional power grids in each scheduling time period in the current state;
in step S3, aiming at reducing the total power generation cost, the iterative optimization by updating the output arrangement and the tie line exchange power of the two regional power grids in each scheduling period means that the output arrangement and the tie line exchange power of the two regional power grids in the tth scheduling period are updated according to the following steps, where T is 1,2, …, T, and T is a preset number of scheduling periods:
s31, respectively calculating marginal power generation costs of two regional power grids in the t-th scheduling period, and specifically comprising the following steps: calculating the marginal power generation cost of each generator set of the two regional power grids in the t-th scheduling time period, selecting the generator set with the highest marginal power generation cost in the current scheduling time period as the marginal generator set in the corresponding regional power grid, and setting the marginal power generation cost of the regional power grid in the t-th scheduling time period as the marginal power generation cost of the marginal generator set;
s32, judging whether an updating condition is met or not according to the marginal power generation cost of two regional power grids in the t-th scheduling period and a preset exchange power updating step length of the tie line, if the updating condition is met, reducing the marginal unit power generation power of the regional power grid with higher marginal power generation cost in the t-th scheduling period according to the exchange power updating step length of the tie line, increasing the marginal unit power generation power of the regional power grid with lower marginal power generation cost in the t-th scheduling period according to the exchange power updating step length of the tie line, and correspondingly updating the exchange power of the tie line in the t-th scheduling period according to the exchange power updating step length of the tie line; if the updating condition is not met, the exchange power of the tie lines of the two regional power grids and the corresponding output arrangement of the unit are unchanged in the t-th scheduling period;
wherein the update condition is represented by the following formula:
Figure FDA0003221506130000011
in the above formula, ρG,tThe marginal power generation cost of the regional power grid with higher marginal power generation cost in the tth scheduling period is set; rhoF,tMarginal power generation cost of the regional power grid with lower marginal power generation cost in the t-th scheduling period; rhoLThe price is transmitted to the electric energy of the tie line between the two regional power grids; pL,tExchanging power for the tie line for the t-th scheduling period; pSExchanging a power updating step length for a preset connecting line; pL,maxTransmitting a power limit for the regional grid tie;
Figure FDA0003221506130000012
marginal unit k of regional power grid with higher marginal power generation cost for t-th scheduling periodGThe generated power of (c);
Figure FDA0003221506130000013
marginal unit k of regional power grid with lower marginal power generation cost for t-th scheduling periodFThe generated power of (c);
Figure FDA0003221506130000014
marginal unit k of regional power grid with higher marginal power generation cost for tth scheduling periodGMinimum output of (d);
Figure FDA0003221506130000015
marginal unit k of regional power grid with lower marginal power generation cost for tth scheduling periodFThe maximum force applied.
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