CN111784021B - Unit partition identification and effective standby allocation method based on key section - Google Patents

Unit partition identification and effective standby allocation method based on key section Download PDF

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CN111784021B
CN111784021B CN202010381748.6A CN202010381748A CN111784021B CN 111784021 B CN111784021 B CN 111784021B CN 202010381748 A CN202010381748 A CN 202010381748A CN 111784021 B CN111784021 B CN 111784021B
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unit
power
constraint
power system
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CN111784021A (en
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徐立中
项中明
杨滢
陆春良
肖艳炜
郭超
陈鸿鑫
丁一
张彦涛
郑亚先
鹿满意
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Zhejiang University ZJU
State Grid Zhejiang Electric Power Co Ltd
China Electric Power Research Institute Co Ltd CEPRI
Nari Technology Co Ltd
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Zhejiang University ZJU
State Grid Zhejiang Electric Power Co Ltd
China Electric Power Research Institute Co Ltd CEPRI
Nari Technology Co Ltd
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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
    • G06Q10/00—Administration; Management
    • G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
    • G06Q10/063—Operations research, analysis or management
    • G06Q10/0631—Resource planning, allocation, distributing or scheduling for enterprises or organisations
    • 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
    • H02J3/38—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
    • H02J3/466—Scheduling the operation of the generators, e.g. connecting or disconnecting generators to meet a given demand
    • 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
    • H02J3/48—Controlling the sharing of the in-phase component
    • 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]

Abstract

The invention discloses a unit partition identification and effective standby allocation method based on a key section, and relates to the technical field of power system operation and control. The availability of power system backup has a significant impact on operational safety. The invention comprises the following steps: establishing a section-based power system standby partition model, determining power transmission distribution factors between each generator set and a key section of a power grid, and dividing power system standby partitions to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets; and (4) carrying out combined optimization scheduling model and solving on the spare capacity, incorporating and solving the key section quota constraint, and obtaining the output and spare arrangement condition of the generator. According to the technical scheme, the influence of the generator set on the trend of the key section is comprehensively considered, the situation that the actual unavailable condition is caused by factors such as overload of the operation section in the calling process of the bid amount in the standby auxiliary service provided by the generator set is avoided, and the operation safety of the power system is improved.

Description

Unit partition identification and effective standby allocation method based on key section
Technical Field
The invention relates to the technical field of power system operation and control, in particular to a unit partition identification and effective standby allocation method based on a key section.
Background
Currently, with the overall development of the reform of the power market, how to discover the effectiveness of the backup of the power system becomes an important challenge affecting the operation efficiency of the power market and the operation safety of the power system. Meanwhile, the bid amount in the standby auxiliary service provided by the generator set cannot be actually unavailable due to factors such as overload of the operation section and the like in the calling process, so that the challenge is brought to the safe operation of the power system.
Disclosure of Invention
The technical problem to be solved and the technical task to be solved by the invention are to perfect and improve the prior technical scheme and provide a method for identifying the unit partition and effectively allocating the standby on the basis of the key section, thereby achieving the purpose. Therefore, the invention adopts the following technical scheme.
1. A unit partition identification and effective standby allocation method based on a key section is characterized by comprising the following steps:
1) establishing a section-based power system standby partition model, determining power transmission distribution factors between each generator set and a key section of a power grid, and dividing power system standby partitions to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets;
2) establishing a reserve capacity joint optimization scheduling model based on power transmission distribution factors, incorporating constraints into the reserve capacity joint optimization scheduling model, and solving the key section quota caused by the reserve partitions of the power system; wherein the constraints include: critical section limits based on power system backup partitions;
3) and obtaining the output of the generator and the standby arrangement condition according to the solving result.
As a preferable technical means: the step 1) comprises the following steps:
101) acquiring key section parameters in the operation process of a power grid;
102) determining power transmission distribution factors between each generator set and a key section of a power grid;
103) and dividing the standby partitions of the power system to which the generator sets belong according to the positive and negative relations of different generator sets to the power transmission distribution factors.
As a preferable technical means: the step 2) comprises the following steps:
201) acquiring system operation parameters and market member declaration parameters;
202) determining an objective function, wherein the objective function maximizes social welfare;
203) determining a constraint of a reserve capacity joint optimization scheduling model based on the power transmission distribution factor;
the constraints also comprise system load balance constraint, positive standby constraint, negative standby constraint, total standby capacity constraint, partition standby capacity constraint, unit output upper and lower limit constraint, power regulation rate constraint and equipment stability limit constraint.
As a preferable technical means: in step 102), the step of determining the power transmission profile factor is:
A. establishing a node incidence matrix C:
Figure BDA0002482247530000021
the node correlation matrix C is a matrix with the dimensionality NL multiplied by Nb, NL represents the number of power system lines, and Nb represents the number of power system nodes; an element 1 in the node incidence matrix C is positioned in an ith column, a-1 is positioned in a jth column, and the positive direction of the current of the representative line i-j is set to flow from the node i to the node j;
B. establishing a matrix X:
Figure BDA0002482247530000031
the dimension of the matrix X is the same as that of the node correlation matrix C, and is a matrix of NL multiplied by Nb, NL represents the number of lines of the power system, and Nb represents the number of nodes of the power system; elements in matrix X
Figure BDA0002482247530000032
Is positioned in the ith column and is provided with a plurality of columns,
Figure BDA0002482247530000033
the positive and negative of the element in the position corresponding to the node incidence matrix are consistent with the positive and negative of the element in the jth column;
C. forming a node admittance matrix B:
Figure BDA0002482247530000034
the node admittance matrix B is a matrix with the dimensionality of Nb multiplied by Nb, and Nb represents the number of nodes of the power system; note that: in the process of establishing the node admittance matrix B, the admittance of the power system to the ground branch needs to be ignored;
D. forming a matrix B':
firstly, selecting a reference node of a power system, wherein a node Nb is set as the reference node;
then, the B' matrix is a vector or a matrix obtained by deleting the items related to the reference nodes from the elements in the matrix B;
the off-diagonal elements and diagonal elements of B' are calculated according to the following formulas:
Figure BDA0002482247530000035
Figure BDA0002482247530000041
wherein matrix B' is a matrix with dimensions Nb-1 × Nb-1, rijAnd xijRespectively representing the resistance and reactance of the lines i-j;
E. forming a power transmission distribution coefficient matrix T:
Figure BDA0002482247530000042
wherein, the elements in the matrix T are power transmission distribution coefficients.
As a preferable technical means: in step 103), comprising:
A. determining a key section matrix D of the power system:
the matrix D is a matrix with dimension Nd × 1, Nd represents the number of critical sections in the power system, and in a general power system, the number of critical sections is 4-5, and this patent assumes that D ═ a, b, c, D, where a, b, c, D are serial numbers of the critical sections;
B. forming a sensitivity matrix T' corresponding to the critical section:
Figure BDA0002482247530000043
the sensitivity matrix T' corresponding to the key sections is a matrix with the dimension Nd multiplied by Nb, Nd represents the number of the key sections in the power system, and Nb represents the number of nodes of the power system;
C. determining the number R of the reserve capacity partitions of the power systemN：
Determining a spare capacity partition of the power system according to the symbol of each element in the sensitivity matrix T' corresponding to the key section; nodes corresponding to columns with the same symbols in the matrix are divided into the same spare capacity partition.
As a preferable technical means: at step 202), the objective function is:
Figure BDA0002482247530000051
wherein:
u represents the sum of declared quantities of the power selling companies and the power consumers participating in the market at the day before;
n represents the total number of the units;
t represents the total number of considered time periods, and if the market considers 96 time periods in the day ahead, T is 96;
Pu,tthe bid-winning load of the electricity selling company and the electricity consumer u in the time period t is represented, and the demand price curves of 4 electricity selling company and the electricity consumer in 15 minutes in the same hour are the same and are equal to the demand price curve of the hour declared in the market in the day ahead;
Bu,t(Pu,t) The electricity purchasing cost of the electricity selling company and the electricity consumer u in the time period t;
Pi,trepresenting the output of the unit i in the time t;
SPRirepresenting the plant power rate of the unit i;
Ci,t(Pi,t，SPRi) Is composed ofThe online output running cost of the unit i in the time period t;
Figure BDA0002482247530000052
representing the standby cost of the unit i in the time period t;
the expression of the unit online output running cost function is as follows:
Figure BDA0002482247530000053
wherein NM is the total number of stages quoted by the unit, Pi,t,mFor winning the bid power in the mth output interval of the unit i at the time t, Ci,mEnergy price corresponding to m output interval declared for unit and SPRiRelated, LossPenaltyi,tA network loss penalty coefficient;
the expression of the unit backup cost function is as follows:
Figure BDA0002482247530000061
wherein the content of the first and second substances,
Figure BDA0002482247530000062
indicating the winning capacity of unit i, Br,iIndicating the reserve capacity quote for unit i.
As a preferable technical means: the critical section quota constraint expression is as follows:
Figure BDA0002482247530000063
wherein, Pa,tIs the active power at time t of the critical section a,
Figure BDA0002482247530000064
is the upper limit of the stable quota of the critical section a,
Figure BDA0002482247530000065
is the lower limit of the stability limit of the critical section a (usually-
Figure BDA0002482247530000066
)，
Figure BDA0002482247530000068
Represents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer, T'aiIs an element of the ith column of the a-th row in the sensitivity matrix T'.
The constraint expression is different from the traditional equipment stability quota constraint, and the influence of the bid-winning reserve capacity of the unit i on the tide of the critical section in all power systems is taken into consideration, so that the tide of the critical section a does not cross the line when the bid-winning reserve capacity of the unit i is called.
As a preferable technical means: in step 203) of the above-mentioned method,
A. system load balancing constraints
For each time period t, the system balance constraint is described as:
Figure BDA0002482247530000067
wherein, Pi,tIndicating the time period of unit itForce of (T)j,tRepresents the planned power (output negative, input positive) of the powered gateway j in time period t, NT is the total number of powered gateways, PLD，tFor non-marketized user load demand, P, of time period tu,tFor the market user load demand, indicating the bid winning load of the power selling company and the power user u in the time period t;
B. positive and backup constraints
For each time period t, the positive standby constraint is described as:
Figure BDA0002482247530000071
wherein the content of the first and second substances,
Figure BDA0002482247530000072
the maximum adjustable output of the unit i in the time period t is obtained; pi,tThe output of the unit i in the time period t is obtained;
Figure BDA0002482247530000073
for a system 30min reserve capacity requirement, RE, for time period ttThe system frequency modulation capacity requirement is the time period t;
C. negative standby constraint
For each time period t, the negative standby constraint is described as:
Figure BDA0002482247530000074
wherein the content of the first and second substances,
Figure BDA0002482247530000075
the minimum output of the unit i in the time period t is obtained;
Figure BDA0002482247530000076
for the system negative spare capacity requirement of time period t, REtThe capacity requirement of frequency modulation is t hours of the system;
D. total spare capacity constraint
Figure BDA0002482247530000077
In the formula:
Figure BDA0002482247530000078
the capacity of the set I for winning bid at t is shown, and I is the number of the sets for winning bid;
Figure BDA0002482247530000079
the standby requirement is 30min for the system t;
E. partition spare capacity constraint
Figure BDA00024822475300000710
In the formula:
Figure BDA00024822475300000711
the capacity of the unit i for winning the bid in the time t is obtained;
Figure BDA00024822475300000712
the standby requirement of the standby partition k for 30min is set as the system t; PTDFkRepresents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer;
F. upper and lower limit restraint of unit output
The output of the unit is between the upper output limit and the lower output limit, and the constraint conditions are described as follows:
Figure BDA0002482247530000081
Figure BDA0002482247530000082
the output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
G. power justification rate constraints
When the power of the unit is adjusted, the power adjustment rate requirement of the unit is met, and the constraint conditions are described as follows:
Pi,t-Pi,t-1≤ΔPi U
Pi,t-1-Pi,t≤ΔPi D
in the formula,. DELTA.Pi UUp-hill limit, Δ P, for unit ii DAnd the lower climbing limit value of the unit i. The output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
H. equipment stability quota constraint
Ps min≤Ps,t≤Ps max
Wherein, Ps,tIs time t of device sActive power of Ps maxIs the upper limit of the stability limit, P, of the device ss minIs the lower limit of the stability limit (usually-P) for the device ss max)。
Has the advantages that: in the traditional standby allocation method, the influence of the called standby on the power flow of the critical section when the power system fails is not considered, so that the reserved standby cannot be effectively called. The invention provides a method for identifying unit partitions and effectively allocating standby power, which is based on a key section, comprehensively considers the influence of the output condition and the standby condition of a generator set on the flow of the key section, and divides the standby partitions by the power transmission distribution factors between the generator sets and the key section of a power grid, so that the influence of the unit in each standby partition on the flow of each key section can be ensured to be the same; and then, considering the influence of the bid-reserve in the generator set on the critical section tide to form critical section quota constraint, thereby ensuring that the reserve capacity in the power system is the effective reserve capacity. The invention can effectively avoid the occurrence of the situation that the spare capacity provided by the generator set is actually unavailable due to factors such as overload of the operation section and the like in the calling process, and improve the operation safety of the power system.
Drawings
FIG. 1 is a flow chart of the present invention.
Detailed Description
The technical scheme of the invention is further explained in detail by combining the drawings in the specification.
As shown in fig. 1, the present invention comprises the steps of:
1) establishing a section-based power system standby partition model, determining power transmission distribution factors between each generator set and a key section of a power grid, and dividing power system standby partitions to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets;
2) establishing a reserve capacity joint optimization scheduling model based on power transmission distribution factors, incorporating constraints into the reserve capacity joint optimization scheduling model, and solving the key section quota caused by the reserve partitions of the power system; wherein the constraints include: critical section limits based on power system backup partitions;
3) and obtaining the output of the generator and the standby arrangement condition according to the solving result.
The present embodiment selects an IEEE 30 node system to further describe the method of the present invention.
The node parameters are as follows:
Figure BDA0002482247530000091
Figure BDA0002482247530000101
the generator set parameters were as follows:
Figure BDA0002482247530000102
s1, establishing a section-based power system standby partition model;
s101, acquiring key section parameters in the operation process of a power grid;
s102, determining power transmission distribution factors between each generator set and a key section of a power grid;
A. establishing a node incidence matrix C:
Figure BDA0002482247530000103
the node correlation matrix C is a matrix with the dimension NL multiplied by Nb, NL represents the number of power system lines, and Nb represents the number of power system nodes. The element 1 in the correlation matrix is located in the ith column, the element 1 is located in the jth column, and the positive direction of the current representing the line i-j is set to flow from the node i to the node j.
B. Establishing a matrix X:
Figure BDA0002482247530000104
the dimension of the matrix X is the same as that of the node association matrix C, and is a matrix of NL × Nb, where NL represents the number of power system lines, and Nb represents the number of power system nodes. Elements in matrix X
Figure BDA0002482247530000111
Is positioned in the ith column and is provided with a plurality of columns,
Figure BDA0002482247530000112
and the positive and negative of the element are consistent with the positive and negative of the element at the corresponding position of the node incidence matrix.
C. Forming a node admittance matrix B:
Figure BDA0002482247530000113
the node admittance matrix B is a matrix with the dimension Nb × Nb, and Nb represents the number of nodes in the power system. Note that: in the process of establishing the node admittance matrix B, the admittance of the power system to the ground branch needs to be ignored.
D. Forming a matrix B':
first, a reference node of the power system is selected, wherein the node Nb is set as the reference node.
The B' matrix is then a vector or matrix with the elements in matrix B removed from the entries associated with the reference nodes.
Specifically, the off-diagonal elements and diagonal elements of B' are calculated as follows:
Figure BDA0002482247530000114
Figure BDA0002482247530000115
wherein matrix B' is a matrix with dimensions Nb-1 × Nb-1, rijAnd xijRepresenting the resistance and reactance of the lines i-j, respectively.
E. Forming a power transmission distribution coefficient matrix T:
Figure BDA0002482247530000121
wherein, the elements in the matrix T are power transmission distribution coefficients.
S103, dividing the standby partitions of the power system to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets;
A. determining a key section matrix D of the power system:
the matrix D is a matrix with dimension Nd × 1, Nd represents the number of critical sections in the power system, and in a general power system, the number of critical sections is 4-5, and this patent assumes that D ═ a, b, c, D.
B. Forming a sensitivity matrix T' corresponding to the critical section:
Figure BDA0002482247530000122
the sensitivity matrix T' corresponding to the critical sections is a matrix with the dimension Nd multiplied by Nb, Nd represents the number of the critical sections in the power system, and Nb represents the number of nodes of the power system.
C. Determining the number R of the reserve capacity partitions of the power systemN：
And determining the spare capacity partition of the power system according to the symbol of each element in the sensitivity matrix T' corresponding to the critical section. Nodes corresponding to columns with the same symbols in the matrix are divided into the same spare capacity partition.
In this embodiment, after calculating the power transmission distribution factor parameters of each node of the system, the critical sections (line numbers: 21-22, 25-27, 15-23) are obtained.
Dividing the standby partitions of the power system to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets, wherein the standby partitions are shown in the following table;
TABLE 1 System Standby partition case
Figure BDA0002482247530000131
S2, establishing a reserve capacity joint optimization scheduling model based on the power transmission distribution factor and solving;
s201, acquiring system operation parameters and market member declaration parameters;
s202, determining an objective function, wherein the objective function maximizes social welfare;
the objective function is:
Figure BDA0002482247530000132
wherein:
u represents the sum of declared quantities of the power selling companies and the power consumers participating in the market at the day before;
n represents the total number of the units;
t represents the total number of considered time periods, and if the market considers 96 time periods in the day ahead, T is 96;
Pu,tthe bid-winning load of the electricity selling company and the electricity consumer u in the time period t is represented, and the demand price curves of 4 electricity selling company and the electricity consumer in 15 minutes in the same hour are the same and are equal to the demand price curve of the hour declared in the market in the day ahead;
Bu,t(Pu,t) The electricity purchasing cost of the electricity selling company and the electricity consumer u in the time period t;
Pi,trepresenting the output of the unit i in the time t;
SPRirepresenting the plant power rate of the unit i;
Ci,t(Pi,t，SPRi) The online output running cost of the unit i in the time period t is calculated;
Figure BDA0002482247530000141
representing the standby cost of the unit i in the time period t;
the expression of the unit online output running cost function is as follows:
Figure BDA0002482247530000142
wherein NM is the total number of stages quoted by the unit, Pi,t,mFor winning the bid power in the mth output interval of the unit i at the time t, Ci,mEnergy price corresponding to m output interval declared for unit and SPRiRelated, LossPenaltyi,tA network loss penalty coefficient;
the expression of the unit backup cost function is as follows:
Figure BDA0002482247530000143
wherein the content of the first and second substances,
Figure BDA0002482247530000144
indicating the winning capacity of unit i, Br,iIndicating the reserve capacity quote for unit i.
S203, determining the constraint of a reserve capacity joint optimization scheduling model based on the power transmission distribution factor;
the method specifically comprises the following steps:
A. system load balancing constraints
For each time period t, the system balance constraint is described as:
Figure BDA0002482247530000151
wherein, Pi,tIndicating the time period of unit itForce of (T)j,tRepresents the planned power (output negative, input positive) of the powered gateway j in time period t, NT is the total number of powered gateways, PLD，tFor non-marketized user load demand, P, of time period tu,tFor the market user load demand, indicating the bid winning load of the power selling company and the power user u in the time period t;
B. positive and backup constraints
For each time period t, the positive standby constraint is described as:
Figure BDA0002482247530000152
wherein the content of the first and second substances,
Figure BDA0002482247530000153
the maximum adjustable output of the unit i in the time period t is obtained; pi,tThe output of the unit i in the time period t is obtained;
Figure BDA0002482247530000154
for a system 30min reserve capacity requirement, RE, for time period ttThe system frequency modulation capacity requirement is the time period t;
C. negative standby constraint
For each time period t, the negative standby constraint is described as:
Figure BDA0002482247530000155
wherein the content of the first and second substances,
Figure BDA0002482247530000156
the minimum output of the unit i in the time period t is obtained;
Figure BDA0002482247530000157
for the system negative spare capacity requirement of time period t, REtThe capacity requirement of frequency modulation is t hours of the system;
D. total spare capacity constraint
Figure BDA0002482247530000158
In the formula:
Figure BDA0002482247530000159
the capacity of the set I for winning bid at t is shown, and I is the number of the sets for winning bid;
Figure BDA0002482247530000161
the standby requirement is 30min for the system t;
E. partition spare capacity constraint
Figure BDA0002482247530000162
In the formula:
Figure BDA0002482247530000163
the capacity of the unit i for winning the bid in the time t is obtained;
Figure BDA0002482247530000164
the standby requirement of the standby partition k for 30min is set as the system t; PTDFkRepresents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer;
F. upper and lower limit restraint of unit output
The output of the unit is between the upper output limit and the lower output limit, and the constraint conditions are described as follows:
Figure BDA0002482247530000165
Figure BDA0002482247530000166
the output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
G. power justification rate constraints
When the power of the unit is adjusted, the power adjustment rate requirement of the unit is met, and the constraint conditions are described as follows:
Pi,t-Pi,t-1≤ΔPi U
Pi,t-1-Pi,t≤ΔPi D
in the formula,. DELTA.Pi UOf a unit iUphill slope limit, Δ Pi DAnd the lower climbing limit value of the unit i. The output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
H. equipment stability quota constraint
Ps min≤Ps,t≤Ps max
Wherein, Ps,tIs the active power of the device s at time t, Ps maxIs the upper limit of the stability limit, P, of the device ss minIs the lower limit of the stability limit (usually-P) for the device ss max)。
I. Critical section quota constraint
Figure BDA0002482247530000171
Wherein, Pa,tIs the active power at time t of the critical section a,
Figure BDA0002482247530000172
is the upper limit of the stable quota of the critical section a,
Figure BDA0002482247530000173
is the lower limit of the stability limit of the critical section a (usually-
Figure BDA0002482247530000174
)，
Figure BDA0002482247530000176
Represents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer, T'aiIs an element of the ith column of the a-th row in the sensitivity matrix T'.
In specific implementation, the influence of the reserved reserve of the generator set on the line power flow is brought into a combined optimization scheduling model of the reserve capacity of the power system to form a standard nonlinear programming problem, and the output and the reserve arrangement condition of the generator are obtained by solving through an interior point Method (MIPS). The following table shows the spare allocation before and after the partition is divided for a single period.
Table 2 spare allocation before partitioning
Figure BDA0002482247530000175
TABLE 3 spare allocation after partitioning
Figure BDA0002482247530000181
For the system, the key operating sections are 21-22, 25-27 and 15-23. For the genset at the location of node 22, scheduling and reserve capacity allocation takes precedence as its generation cost and reserve cost are lowest for all gensets in the system. Comparing the scheduling results before and after partitioning, we can find that, under the condition of considering the transmission limit of the key operation section, the sum of the power generation capacity and the reserved spare capacity of the generator set where the node 22 is located does not exceed the installed capacity of the generator set. When the system fails, the standby is required to be called, and the reserved part of capacity of the generator set cannot be called completely due to the constraint of the key sections 21-22. The reserved spare capacity of the generator set is invalid, the total effective spare capacity in an actual system is reduced, and the reliability of a power system is influenced.
By dividing the power system into a plurality of partitions according to the key section, the problem that the spare capacity provided by the generator set is actually unavailable due to overload of the operation section in the calling process is solved. In the case of a spare partition, the total spare capacity of the system is allocated to the partition spare capacity according to the load ratio of each area. In the embodiment, the total spare capacity 60MW demand of the system is converted into the regional spare demands (regions I:29MW, II:15MW, III:16MW), the effectiveness of the spare capacity is guaranteed according to the limitation of the critical section, and the reliability and the safety of the power system are improved.
The patent of the invention focuses on the influence of the generator node on the tidal current of the critical section, and meanwhile, the PTDF matrix can effectively express the influence of the power change of the nodes of the power system on the branch tidal current. Therefore, the automatic partition of the spare capacity partitions of the power system is realized through the PTDF matrix. The calling of the reserve capacity generally occurs when the power system fails, and if the reserve capacity cannot be effectively called due to the limitation of the tidal current of the critical section, the safe and stable operation of the power system is seriously threatened. Therefore, the critical section quota constraint caused by the reserve needs to be incorporated into a reserve capacity joint optimization scheduling model based on the power transmission distribution factor and solved, so as to obtain the output of the generator and the reserve arrangement condition. By adding the limitation constraint of the critical section, the invention can solve the solution obtained by solving the joint optimization scheduling model provided by the invention, compared with the traditional method, the reserved transmission margin of the critical section is increased, and the bid amount in the unit in the blocked area is reduced.
The method for identifying a partition of a unit and allocating an effective spare area based on a critical section shown in fig. 1 is a specific embodiment of the present invention, and already embodies the substantial features and improvements of the present invention, and it is within the scope of the present invention to modify the same in shape, structure, etc. according to the practical needs.

Claims (6)

1. A unit partition identification and effective standby allocation method based on a key section is characterized by comprising the following steps:
1) establishing a section-based power system standby partition model, determining power transmission distribution factors between each generator set and a key section of a power grid, and dividing power system standby partitions to which the generator sets belong according to the positive and negative relations of the power transmission distribution factors of different generator sets;
2) establishing a reserve capacity joint optimization scheduling model based on power transmission distribution factors, incorporating constraints into the reserve capacity joint optimization scheduling model, and solving the key section quota caused by the reserve partitions of the power system; its constraints include: critical section limits based on power system backup partitions;
3) according to the solving result, the output of the generator and the standby arrangement condition of the generator are obtained;
the step 1) comprises the following steps:
101) acquiring key section parameters in the operation process of a power grid;
102) determining power transmission distribution factors between each generator set and a key section of a power grid;
103) dividing the standby partitions of the power system to which the generator sets belong according to the positive and negative relations of different generator sets to the power transmission distribution factors;
in step 102), the step of determining the power transmission profile factor is:
A. establishing a node incidence matrix C:
Figure FDA0002944835030000011
the node correlation matrix C is a matrix with the dimensionality NL multiplied by Nb, NL represents the number of power system lines, and Nb represents the number of power system nodes; an element 1 in the node incidence matrix C is positioned in an ith column, a-1 is positioned in a jth column, and the positive direction of the current of the representative line i-j is set to flow from the node i to the node j;
B. establishing a matrix X:
Figure FDA0002944835030000021
the dimension of the matrix X is the same as that of the node correlation matrix C, and is a matrix of NL multiplied by Nb, NL represents the number of lines of the power system, and Nb represents the number of nodes of the power system; elements in matrix X
Figure FDA0002944835030000022
Is positioned in the ith column and is provided with a plurality of columns,
Figure FDA0002944835030000023
the positive and negative of the element in the position corresponding to the node incidence matrix are consistent with the positive and negative of the element in the jth column;
C. forming a node admittance matrix B:
Figure FDA0002944835030000024
the node admittance matrix B is a matrix with the dimensionality of Nb multiplied by Nb, and Nb represents the number of nodes of the power system; in the process of establishing the node admittance matrix B, the admittance of the power system to the ground branch needs to be ignored;
D. forming a matrix B':
firstly, selecting a reference node of a power system, wherein a node Nb is set as the reference node;
then, the B' matrix is a vector or a matrix obtained by deleting the items related to the reference nodes from the elements in the matrix B;
the off-diagonal elements and diagonal elements of B' are calculated according to the following formulas:
Figure FDA0002944835030000025
Figure FDA0002944835030000026
wherein matrix B' is a matrix with dimensions Nb-1 × Nb-1, rijAnd xijRespectively representing the resistance and reactance of the lines i-j;
E. forming a power transmission distribution coefficient matrix T:
Figure FDA0002944835030000031
wherein, the elements in the matrix T are power transmission distribution coefficients.
2. The critical section-based unit partition identification and active spare allocation method according to claim 1, wherein: the step 2) comprises the following steps:
201) acquiring system operation parameters and market member declaration parameters;
202) determining an objective function, wherein the objective function maximizes social welfare;
203) determining a constraint of a reserve capacity joint optimization scheduling model based on the power transmission distribution factor;
the constraints also comprise system load balance constraint, positive standby constraint, negative standby constraint, total standby capacity constraint, partition standby capacity constraint, unit output upper and lower limit constraint, power regulation rate constraint and equipment stability limit constraint.
3. The critical section-based unit partition identification and active spare allocation method according to claim 2, wherein:
in step 103), comprising:
A. determining a key section matrix D of the power system:
the matrix D is a matrix with the dimension of Nd multiplied by 1, Nd represents the number of the key sections in the power system, and D is assumed to be [ a, b, c, D ], wherein a, b, c, D are serial numbers of the key sections;
B. forming a sensitivity matrix T' corresponding to the critical section:
Figure FDA0002944835030000041
the sensitivity matrix T' corresponding to the key sections is a matrix with the dimension Nd multiplied by Nb, Nd represents the number of the key sections in the power system, and Nb represents the number of nodes of the power system;
C. determining the number R of the reserve capacity partitions of the power systemN：
Determining a spare capacity partition of the power system according to the symbol of each element in the sensitivity matrix T' corresponding to the key section; nodes corresponding to columns with the same symbols in the matrix are divided into the same spare capacity partition.
4. The critical section-based crew partition identification and active spare allocation method of claim 3, wherein: at step 202), the objective function is:
Figure FDA0002944835030000042
wherein:
u represents the sum of declared quantities of the power selling companies and the power consumers participating in the market at the day before;
n represents the total number of the units;
t represents the total number of considered time periods, and if the market considers 96 time periods in the day ahead, T is 96;
Pu,tthe bid-winning load of the electricity selling company and the electricity consumer u in the time period t is represented, and the demand price curves of 4 electricity selling company and the electricity consumer in 15 minutes in the same hour are the same and are equal to the demand price curve of the hour declared in the market in the day ahead;
Bu,t(Pu,t) The electricity purchasing cost of the electricity selling company and the electricity consumer u in the time period t;
Pi,trepresenting the output of the unit i in the time t;
SPRirepresenting the plant power rate of the unit i;
Ci,t(Pi,t，SPRi) The online output running cost of the unit i in the time period t is calculated;
Figure FDA0002944835030000051
representing the standby cost of the unit i in the time period t;
the expression of the unit online output running cost function is as follows:
Figure FDA0002944835030000052
wherein NM is the total number of stages quoted by the unit, Pi,t,mFor winning the bid power in the mth output interval of the unit i at the time t, Ci,mEnergy price corresponding to m output interval declared for unit and SPRiRelated, LossPenaltyi,tA network loss penalty coefficient;
the expression of the unit backup cost function is as follows:
Figure FDA0002944835030000053
wherein the content of the first and second substances,
Figure FDA0002944835030000054
indicating the winning capacity of unit i, Br,iIndicating the reserve capacity quote for unit i.
5. The critical section-based crew partition identification and active spare allocation method of claim 4, wherein: the critical section quota constraint expression is as follows:
Figure FDA0002944835030000055
wherein, Pa,tIs the active power at time t of the critical section a,
Figure FDA0002944835030000056
is the upper limit of the stable quota of the critical section a,
Figure FDA0002944835030000057
is the lower limit of the stability limit of the critical section a, PTDFkRepresents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer, T'aiIs an element of the ith column of the a-th row in the sensitivity matrix T'.
6. The critical section-based crew partition identification and active spare allocation method of claim 5, wherein: in step 203) of the above-mentioned method,
A. system load balancing constraints
For each time period t, the system balance constraint is described as:
Figure FDA0002944835030000061
wherein, Pi,tRepresents the output of the unit i in the time period T, Tj,tRepresents the planned power of the power receiving gateway j in the time period t, NT is the total number of the power receiving gateways, PLD，tFor non-marketized user load demand, P, of time period tu,tFor the market user load demand, indicating the bid winning load of the power selling company and the power user u in the time period t;
B. positive and backup constraints
For each time period t, the positive standby constraint is described as:
Figure FDA0002944835030000062
wherein the content of the first and second substances,
Figure FDA0002944835030000063
the maximum adjustable output of the unit i in the time period t is obtained; pi,tThe output of the unit i in the time period t is obtained;
Figure FDA0002944835030000064
for a system 30min reserve capacity requirement, RE, for time period ttThe system frequency modulation capacity requirement is the time period t;
C. negative standby constraint
For each time period t, the negative standby constraint is described as:
Figure FDA0002944835030000065
wherein the content of the first and second substances,
Figure FDA0002944835030000066
the minimum output of the unit i in the time period t is obtained;
Figure FDA0002944835030000067
for the system negative spare capacity requirement of time period t, REtThe capacity requirement of frequency modulation is t hours of the system;
D. total spare capacity constraint
Figure FDA0002944835030000071
In the formula:
Figure FDA0002944835030000072
the capacity of the set I for winning bid at t is shown, and I is the number of the sets for winning bid;
Figure FDA0002944835030000073
the standby requirement is 30min for the system t;
E. partition spare capacity constraint
Figure FDA0002944835030000074
In the formula:
Figure FDA0002944835030000075
the capacity of the unit i for winning the bid in the time t is obtained;
Figure FDA0002944835030000076
the standby requirement of the standby partition k for 30min is set as the system t; PTDFkRepresents the kth subarea of the power system, and k is more than or equal to 1 and less than or equal to RNK is an integer;
F. upper and lower limit restraint of unit output
The output of the unit is between the upper output limit and the lower output limit, and the constraint conditions are described as follows:
Figure FDA0002944835030000077
Figure FDA0002944835030000078
the output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
G. power justification rate constraints
When the power of the unit is adjusted, the power adjustment rate requirement of the unit is met, and the constraint conditions are described as follows:
Pi,t-Pi,t-1≤ΔPi U
Pi,t-1-Pi,t≤ΔPi D
in the formula,. DELTA.Pi UUp-hill limit, Δ P, for unit ii DThe lower climbing limit value of the unit i is set; the output of the fixed output unit and the output of the unit which does not participate in the market do not take the constraint into account;
H. equipment stability quota constraint
Ps min≤Ps,t≤Ps max
Wherein, Ps,tIs the active power of the device s at time t, Ps maxIs the upper limit of the stability limit, P, of the device ss minIs the lower limit of the stability limit for the device s.
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