CN111030196B - Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid - Google Patents

Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid Download PDF

Info

Publication number
CN111030196B
CN111030196B CN201911297768.9A CN201911297768A CN111030196B CN 111030196 B CN111030196 B CN 111030196B CN 201911297768 A CN201911297768 A CN 201911297768A CN 111030196 B CN111030196 B CN 111030196B
Authority
CN
China
Prior art keywords
formula
fault
reactive power
variable
state
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Active
Application number
CN201911297768.9A
Other languages
Chinese (zh)
Other versions
CN111030196A (en
Inventor
王彬
陈天华
郭庆来
陈建华
葛怀畅
杜磊
齐子杰
徐陆飞
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Tsinghua University
NARI Group Corp
Original Assignee
Tsinghua University
NARI Group Corp
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Tsinghua University, NARI Group Corp filed Critical Tsinghua University
Priority to CN201911297768.9A priority Critical patent/CN111030196B/en
Publication of CN111030196A publication Critical patent/CN111030196A/en
Application granted granted Critical
Publication of CN111030196B publication Critical patent/CN111030196B/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • 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
    • H02J3/50—Controlling the sharing of the out-of-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
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/12—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load
    • H02J3/16—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load by adjustment of reactive power
    • 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
    • H02J3/18—Arrangements for adjusting, eliminating or compensating reactive power in networks
    • 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
    • H02J3/36—Arrangements for transfer of electric power between ac networks via a high-tension dc link
    • 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
    • Y02E40/30—Reactive power compensation
    • 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
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/60—Arrangements for transfer of electric power between AC networks or generators via a high voltage DC link [HVCD]

Landscapes

  • Engineering & Computer Science (AREA)
  • Power Engineering (AREA)
  • Supply And Distribution Of Alternating Current (AREA)

Abstract

The invention relates to a dynamic sensitivity-based dynamic reactive power reserve optimization method for a receiving-end power grid, and belongs to the technical field of safety and control of power systems. Firstly, establishing a differential algebraic equation of an alternating current-direct current hybrid system, and solving the first-order dynamic sensitivity of the system; and then, aiming at the current condition, establishing a dynamic reactive power reserve optimization model and solving. After the solution is completed, each dynamic reactive power control device adjusts the steady-state reactive power value according to the optimization result, and if the generator needs to calculate the dynamic reactive power reserve result, a corresponding reactive power reserve amount is reserved. The invention can ensure that the AC/DC hybrid power grid can still safely operate when the phase commutation fails, thereby improving the operation reliability of the power grid.

Description

Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid
Technical Field
The invention belongs to the technical field of power system safety and control, and particularly provides a dynamic sensitivity-based dynamic reactive power reserve optimization method for a receiving-end power grid.
Background
The east and middle parts of China have built large-scale receiving end power grids with multiple direct current drop points, and the pattern of strong and weak cross is very obvious. As a common fault of the receiving-end power grid, phase commutation failure may occur ten to tens of times within a year in a single receiving-end converter station. During the occurrence of commutation failure, a large amount of dynamic reactive power is consumed. In the traditional reactive power optimization, a capacitive reactor group and a generator are controlled only by taking steady-state voltage distribution as a target, the operation mode under the fault condition is possibly unreasonable, and once a commutation failure fault occurs, the grid safety has great hidden danger due to insufficient dynamic reactive power reserve. Therefore, how to perform dynamic reactive power reserve optimization during steady-state operation, determine a reasonable reactive power equipment operation mode, and ensure the voltage safety of the alternating-current and direct-current series-parallel power grid is very important.
Disclosure of Invention
The invention aims to overcome the defects of the prior art and provides a dynamic reactive power reserve optimization method of a receiving-end power grid based on dynamic sensitivity. The invention can ensure that the AC/DC hybrid power grid can still safely operate when the phase commutation fails, thereby improving the operation reliability of the power grid.
The invention provides a dynamic sensitivity-based dynamic reactive power reserve optimization method for a receiving-end power grid, which is characterized by comprising the following steps of:
1) establishing an alternating current-direct current series-parallel system equation, and solving the first-order dynamic sensitivity of the system; the method comprises the following specific steps:
1-1) establishing a receiving end power grid equation in steady-state operation, as shown in formula (1):
Figure GDA0002705411510000011
wherein, x represents the state variables of the system, including the internal potential, power angle, excitation voltage and direct current variables of the generator; y represents an algebraic variable including a bus voltage amplitude of the system and a phase angle of the bus voltage; u represents a control variable including the reactive power output of the generator in steady state operation
Figure GDA0002705411510000012
Reactive power of reactor
Figure GDA0002705411510000013
1-2) after the fault occurs, the first expression in the formula (1) is kept unchanged;
replacing the second expression in the formula (1) by the formula (2) for the period before clearing after the occurrence of the fault;
replacing the second expression in the formula (1) by the formula (3) for the time period after the fault occurs and after the fault is cleared; the expressions are respectively obtained as follows:
0＝gs(x,y,u) (2)
0＝gs,c(x,y,u) (3)
in the formula, s represents a fault number; c represents clearance;
1-3) order
Figure GDA0002705411510000021
And
Figure GDA0002705411510000022
respectively representing the partial derivatives of the state variable and the algebraic variable to the control variable in the initial state after the fault occurs, and respectively calculating by using an equation (4) and an equation (5):
Figure GDA0002705411510000023
Figure GDA0002705411510000024
wherein, t0Indicating the fault occurrence time;
Figure GDA0002705411510000025
indicating an initial time before the occurrence of the fault;
Figure GDA0002705411510000026
indicating an initial time after the occurrence of the fault;
Figure GDA0002705411510000027
representing the partial derivative of the state variable to the control variable in the initial state before the fault occurs;
Figure GDA0002705411510000028
respectively representing the partial derivatives of the second expression in the formula (1) to the algebraic variable and the control variable in the initial state after the s-th fault occurs;
1-4) order
Figure GDA0002705411510000029
And
Figure GDA00027054115100000210
respectively representing the partial derivatives of the state variable and the algebraic variable to the control variable in the initial state after fault clearance, and respectively calculating by using the expressions (6) and (7):
Figure GDA00027054115100000211
Figure GDA00027054115100000212
wherein, tcIndicating the moment at which the fault is cleared,
Figure GDA00027054115100000213
indicating the initial moment before the fault is cleared,
Figure GDA00027054115100000214
indicating the initial time after the fault is cleared,
Figure GDA00027054115100000215
representing the partial derivative of the state variable to the control variable in the initial state before the fault occurs;
Figure GDA00027054115100000216
respectively representing the partial derivatives of the second expression in the formula (1) to the algebraic variable and the control variable in the initial state after the s-th fault is cleared;
1-5) at any time during the fault occurrence period
Figure GDA00027054115100000217
Let T be T, calculate the sensitivity at time T
Figure GDA00027054115100000218
Calculation of sensitivity at time T +1 Using equation (8)
Figure GDA00027054115100000219
Figure GDA0002705411510000031
In the formula, h represents the simulation step length, I represents an identity matrix, and J represents a Jacobian matrix of the system;
Figure GDA0002705411510000032
respectively representing the partial derivatives of the system state variable and the algebraic variable to the control variable at the time T;
Figure GDA0002705411510000033
respectively representing partial derivatives of the system state variable and the algebraic variable to the control variable at the time of T + 1;
Figure GDA0002705411510000034
respectively representing T moments, and partial derivatives of a first expression in the formula (1) to state variables and algebraic variables;
Figure GDA0002705411510000035
respectively representing T moments, and partial derivatives of a second expression in the formula (1) to state variables and algebraic variables;
Figure GDA0002705411510000036
respectively representing partial derivatives of the first expression in the formula (1) at the time T and the time T +1 to the control variable;
Figure GDA0002705411510000037
respectively representing the partial derivatives of the second formula in the formulas at the time (1) of T and T +1 to the control variable;
2) establishing a dynamic reactive power reserve optimization model, wherein the model consists of an objective function and constraint conditions; the method comprises the following specific steps: 2-1) establishing an objective function of a dynamic reactive power reserve optimization model, as shown in (9):
Figure GDA0002705411510000038
wherein N isstationThe total number of the capacitive reactance devices is shown,
Figure GDA0002705411510000039
Nc,irespectively representing the current input group number and the optimized input group number of the ith capacitive reactance device;
2-2) determining constraint conditions of the dynamic reactive power reserve optimization model, specifically as follows:
2-2-1) group number constraint of capacitive reactance of each station, as shown in formula (10):
Figure GDA00027054115100000310
wherein, cN,
Figure GDA00027054115100000311
respectively representing the lower limit value and the upper limit value of the input group number of each capacitive reactance device;
2-2-2) reactive power output constraint in the steady state of the generator, as shown in formula (11):
Figure GDA00027054115100000312
wherein,
Figure GDA00027054115100000313
represents an optimized value of the reactive output of the generator in a steady state,
Figure GDA00027054115100000314
respectively representing the lower limit value and the upper limit value of the reactive power output of the generator in a steady state;
2-2-3) the N-1 safety constraint condition after the commutation failure fault is shown as a formula (12):
Figure GDA00027054115100000315
wherein,
Figure GDA00027054115100000316
representing a critical voltage recovery value after the voltage fault of the alternating current bus of the converter station;
Figure GDA00027054115100000317
respectively represents T after the s-th fault occursendThe optimized value and the current value of the alternating current bus voltage of the current converter station at the moment; t isendIndicating the time of commutation recovery;
Figure GDA00027054115100000318
respectively representing an optimized value and a current value of the reactive power output of the generator in steady-state operation;
Figure GDA0002705411510000041
respectively representing an optimized value and a current value of reactive power output of the capacitive reactance during steady-state operation;
Figure GDA0002705411510000042
respectively represents the s-th fault, TendTime of day
Figure GDA0002705411510000043
To pair
Figure GDA0002705411510000044
And
Figure GDA0002705411510000045
the dynamic sensitivity of (1), the sensitivity value being determined in step 1);
3) solving the model established in the step 2) to obtain an optimal solution
Figure GDA0002705411510000046
Calculating the minimum dynamic reactive power reserve reserved by the reactive power compensation equipment by using the formula (13), and finishing the optimization;
Figure GDA0002705411510000047
in the formula,
Figure GDA0002705411510000048
for the minimum dynamic reactive reserve of the reactive compensation equipment, the subscript g denotes the generator.
The invention has the characteristics and beneficial effects that:
aiming at the defect that the traditional reactive power optimization only considers the steady state and does not consider the fault condition, the invention provides a dynamic reactive power reserve optimization model considering the voltage safety constraint under the fault condition and provides the operation modes of a capacitive reactor group and a generator under the steady state. The invention can guide the dispatching personnel to reasonably set the operation mode of the reactive power equipment, ensure that enough dynamic reactive power reserves are reserved under the fault condition, avoid the voltage safety problem caused by faults such as commutation failure and the like, and improve the safety of the power system.
Detailed Description
The invention provides a dynamic sensitivity-based dynamic reactive power reserve optimization method for a receiving-end power grid, which is further described in detail below by combining specific embodiments.
The invention provides a dynamic reactive power reserve optimization method of a receiving-end power grid based on dynamic sensitivity, which comprises the following steps:
1) establishing an alternating current-direct current series-parallel system equation, and solving the first-order dynamic sensitivity of the system; the method comprises the following specific steps:
1-1) establishing a receiving end power grid equation in steady operation, and expressing the receiving end power grid equation by using an equation (1). The two equations in equation (1) describe the algebraic relations between the dynamic process of the system and the system variables, respectively. Wherein, x represents the state variables of the system, including the internal potential, power angle, excitation voltage and direct current variables of the generator; y represents an algebraic variable including a bus voltage amplitude of the system and a phase angle of the bus voltage; u represents a control variable including the reactive power output of the generator in steady state operation
Figure GDA0002705411510000049
Reactive power of reactor
Figure GDA00027054115100000410
Figure GDA00027054115100000411
1-2) after the fault occurs, the first formula is unchanged and the second formula is changed in formula (1); the pre-clearing and post-clearing periods after the occurrence of the fault are represented by equations (2) and (3), respectively. In the formula, s represents a fault number, and c represents clearing.
0＝gs(x,y,u) (2)
0＝gs,c(x,y,u) (3)
Hereinafter, t0Indicates the time of occurrence of the fault, tcIndicating a fault clearing time;
Figure GDA0002705411510000051
and
Figure GDA0002705411510000052
respectively representing initial time before fault occurs and before fault clearance;
Figure GDA0002705411510000053
and
Figure GDA0002705411510000054
respectively, the initial times after the occurrence of the fault and after the fault is cleared.
Figure GDA0002705411510000055
And
Figure GDA0002705411510000056
when the initial states after the fault occurs are respectively represented, the partial derivatives of the state variable and the algebraic variable to the control variable are respectively obtained by the expressions (4) and (5). Wherein,
Figure GDA0002705411510000057
representing the partial derivative of the state variable with respect to the control variable in the initial state before the fault occurs.
Figure GDA0002705411510000058
Respectively, the partial derivatives of the second formula in the formula (1) on the algebraic variable and the controlled variable in the initial state after the occurrence of the s-th fault.
Figure GDA0002705411510000059
Figure GDA00027054115100000510
Figure GDA00027054115100000511
And
Figure GDA00027054115100000512
when the initial states after fault clearing are respectively represented, the partial derivatives of the state variables and the algebraic variables to the control variables are respectively obtained by the expressions (6) and (7). Wherein,
Figure GDA00027054115100000513
representing the partial derivative of the state variable with respect to the control variable in the initial state before the fault occurs.
Figure GDA00027054115100000514
Respectively, the partial derivatives of the second formula in the formula (1) on the algebraic variable and the control variable in the initial state after the clearing of the s-th fault occurs.
Figure GDA00027054115100000515
Figure GDA00027054115100000516
At any time during the fault occurrence period
Figure GDA00027054115100000517
Let T be T, the value at time T can be calculated
Figure GDA00027054115100000518
Which is the sensitivity at time T. Calculating the value at time T +1 using equation (8)
Figure GDA00027054115100000519
Which is the sensitivity at time T + 1.
Figure GDA00027054115100000520
In the formula, h represents the simulation step length, I represents an identity matrix, and J represents a Jacobian matrix of the system.
Figure GDA00027054115100000521
Respectively representing the partial derivatives of the system state variable and the algebraic variable to the control variable at the time T;
Figure GDA00027054115100000522
respectively representing partial derivatives of the system state variable and the algebraic variable to the control variable at the time of T + 1;
Figure GDA00027054115100000523
respectively representing T time, and partial derivatives of a first formula in the formula (1) to a state variable and an algebraic variable;
Figure GDA00027054115100000524
respectively representing T time, and partial derivatives of a second formula in the formula (1) to a state variable and an algebraic variable;
Figure GDA00027054115100000525
respectively representing the partial derivatives of the first formula in the formulas at the time (1) of T and T +1 to the control variable;
Figure GDA00027054115100000526
represents the partial derivative of the second of the equations for the control variable at time (1) T and T +1, respectively.
2) Aiming at the current condition of the system, establishing a dynamic reactive power reserve optimization model, wherein the model consists of an objective function and constraint conditions; the method comprises the following specific steps:
2-1) establishing an objective function of a dynamic reactive power reserve optimization model, as shown in (9):
Figure GDA0002705411510000061
and the formula (9) represents the sum of the minimum number of the capacitive reactors required to be put into all the generators after optimization. Wherein N isstationThe total number of the capacitive reactance devices is shown,
Figure GDA0002705411510000062
Nc,irespectively representing the current input group number and the optimized input group number of the ith capacitive reactance device.
2-2) determining constraint conditions of the dynamic reactive power reserve optimization model, specifically as follows:
2-2-1) group number constraint of capacitive reactance of each station, as shown in formula (10):
Figure GDA0002705411510000063
wherein, c,iN,
Figure GDA0002705411510000064
the lower limit value and the upper limit value represent the input group number of each capacitive reactance device respectively.
2-2-2) reactive power output constraint in the steady state of the generator, as shown in formula (11):
Figure GDA0002705411510000065
wherein,
Figure GDA0002705411510000066
and representing the column vector formed by the reactive power output of the generator in steady-state operation, namely the optimized value.
Figure GDA0002705411510000067
Respectively representing the lower limit value and the upper limit value of the reactive power output of the generator in a steady state;
2-2-3) the N-1 safety constraint condition after the commutation failure fault is shown as a formula (12):
Figure GDA0002705411510000068
wherein,
Figure GDA0002705411510000069
representing the recovery value of the critical voltage after the voltage fault of the alternating current bus of the converter station.
Figure GDA00027054115100000610
Respectively represents T after the s-th fault occursendAnd optimizing and current values of the AC bus voltage of the converter station at the moment. Usually TendGiven by the grid, represents the required time for commutation recovery.
Figure GDA00027054115100000611
Respectively generation by generationAnd (4) the optimal value and the current value of the reactive output of the generator in steady state operation are shown.
Figure GDA00027054115100000612
Respectively representing the optimized value and the current value of the reactive power output of the capacitive reactance device in steady-state operation.
Figure GDA00027054115100000613
Respectively represents the s-th fault, TendTime of day
Figure GDA00027054115100000614
To pair
Figure GDA00027054115100000615
And
Figure GDA00027054115100000616
the sensitivity value can be determined from step 1). The control variable u in step 1) is determined by
Figure GDA00027054115100000617
And
Figure GDA00027054115100000618
constructed vectors, i.e.
Figure GDA00027054115100000619
3) Solving the model established in the step 2) by using CPLEX to obtain a corresponding optimal solution obtained by the reactive compensation equipment
Figure GDA00027054115100000620
Then, the minimum dynamic reactive reserve to be reserved is calculated using equation (13):
Figure GDA00027054115100000621
in the formula
Figure GDA00027054115100000622
For the minimum dynamic reactive reserve of the reactive compensation equipment, g denotes the generator. The generator needs to be as required
Figure GDA00027054115100000623
And reserving reactive reserve.

Claims (1)

1. A receiving-end power grid dynamic reactive power reserve optimization method based on dynamic sensitivity is characterized by comprising the following steps:
1) establishing an alternating current-direct current series-parallel system equation, and solving the first-order dynamic sensitivity of the system; the method comprises the following specific steps:
1-1) establishing a receiving end power grid equation in steady-state operation, as shown in formula (1):
Figure FDA0002321024880000011
wherein, x represents the state variables of the system, including the internal potential, power angle, excitation voltage and direct current variables of the generator; y represents an algebraic variable including a bus voltage amplitude of the system and a phase angle of the bus voltage; u represents a control variable including the reactive power output of the generator in steady state operation
Figure FDA0002321024880000014
Reactive power of reactor
Figure FDA0002321024880000015
1-2) after the fault occurs, the first expression in the formula (1) is kept unchanged;
replacing the second expression in the formula (1) by the formula (2) for the period before clearing after the occurrence of the fault;
replacing the second expression in the formula (1) by the formula (3) for the time period after the fault occurs and after the fault is cleared; the expressions are respectively obtained as follows:
0＝gs(x,y,u) (2)
0＝gs,c(x,y,u) (3)
in the formula, s represents a fault number; c represents clearance;
1-3) order
Figure FDA0002321024880000016
And
Figure FDA0002321024880000017
respectively representing the partial derivatives of the state variable and the algebraic variable to the control variable in the initial state after the fault occurs, and respectively calculating by using an equation (4) and an equation (5):
Figure FDA0002321024880000012
Figure FDA0002321024880000013
wherein, t0Indicating the fault occurrence time;
Figure FDA0002321024880000018
indicating an initial time before the occurrence of the fault;
Figure FDA0002321024880000019
indicating an initial time after the occurrence of the fault;
Figure FDA00023210248800000110
representing the partial derivative of the state variable to the control variable in the initial state before the fault occurs;
Figure FDA00023210248800000111
respectively representing the partial derivatives of the second expression in the formula (1) to the algebraic variable and the control variable in the initial state after the s-th fault occurs;
1-4) order
Figure FDA0002321024880000025
And
Figure FDA0002321024880000026
respectively representing the partial derivatives of the state variable and the algebraic variable to the control variable in the initial state after fault clearance, and respectively calculating by using the expressions (6) and (7):
Figure FDA0002321024880000021
Figure FDA0002321024880000022
wherein, tcIndicating the moment at which the fault is cleared,
Figure FDA0002321024880000027
indicating the initial moment before the fault is cleared,
Figure FDA0002321024880000028
indicating the initial time after the fault is cleared,
Figure FDA0002321024880000029
representing the partial derivative of the state variable to the control variable in the initial state before the fault occurs;
Figure FDA00023210248800000210
respectively representing the partial derivatives of the second expression in the formula (1) to the algebraic variable and the control variable in the initial state after the s-th fault is cleared;
1-5) at any time during the fault occurrence period
Figure FDA00023210248800000211
Let T equal T, calculateSensitivity at time T
Figure FDA00023210248800000212
Calculation of sensitivity at time T +1 Using equation (8)
Figure FDA00023210248800000213
Figure FDA0002321024880000023
In the formula, h represents the simulation step length, I represents an identity matrix, and J represents a Jacobian matrix of the system;
Figure FDA00023210248800000214
respectively representing the partial derivatives of the system state variable and the algebraic variable to the control variable at the time T;
Figure FDA00023210248800000215
respectively representing partial derivatives of the system state variable and the algebraic variable to the control variable at the time of T + 1;
Figure FDA00023210248800000216
respectively representing T moments, and partial derivatives of a first expression in the formula (1) to state variables and algebraic variables;
Figure FDA00023210248800000217
respectively representing T moments, and partial derivatives of a second expression in the formula (1) to state variables and algebraic variables;
Figure FDA00023210248800000218
respectively representing partial derivatives of the first expression in the formula (1) at the time T and the time T +1 to the control variable;
Figure FDA00023210248800000219
represents the second formula pair control variables in the formulas at the time (1) of T and T +1 respectivelyA partial derivative of the quantity;
2) establishing a dynamic reactive power reserve optimization model, wherein the model consists of an objective function and constraint conditions; the method comprises the following specific steps:
2-1) establishing an objective function of a dynamic reactive power reserve optimization model, as shown in (9):
Figure FDA0002321024880000024
wherein N isstationThe total number of the capacitive reactance devices is shown,
Figure FDA00023210248800000220
Nc,irespectively representing the current input group number and the optimized input group number of the ith capacitive reactance device;
2-2) determining constraint conditions of the dynamic reactive power reserve optimization model, specifically as follows:
2-2-1) group number constraint of capacitive reactance of each station, as shown in formula (10):
Figure FDA0002321024880000031
wherein, cN,
Figure FDA0002321024880000035
respectively representing the lower limit value and the upper limit value of the input group number of each capacitive reactance device;
2-2-2) reactive power output constraint in the steady state of the generator, as shown in formula (11):
Figure FDA0002321024880000032
wherein,
Figure FDA0002321024880000036
represents an optimized value of the reactive output of the generator in a steady state,
Figure FDA0002321024880000037
respectively representing the lower limit value and the upper limit value of the reactive power output of the generator in a steady state;
2-2-3) the N-1 safety constraint condition after the commutation failure fault is shown as a formula (12):
Figure FDA0002321024880000033
wherein,
Figure FDA0002321024880000038
representing a critical voltage recovery value after the voltage fault of the alternating current bus of the converter station;
Figure FDA0002321024880000039
respectively represents T after the s-th fault occursendThe optimized value and the current value of the alternating current bus voltage of the current converter station at the moment; t isendIndicating the time of commutation recovery;
Figure FDA00023210248800000310
respectively representing an optimized value and a current value of the reactive power output of the generator in steady-state operation;
Figure FDA00023210248800000311
respectively representing an optimized value and a current value of reactive power output of the capacitive reactance during steady-state operation;
Figure FDA00023210248800000312
respectively represents the s-th fault, TendTime of day
Figure FDA00023210248800000313
To pair
Figure FDA00023210248800000314
And
Figure FDA00023210248800000315
the dynamic sensitivity of (1), the sensitivity value being determined in step 1);
3) solving the model established in the step 2) to obtain an optimal solution
Figure FDA00023210248800000316
Calculating the minimum dynamic reactive power reserve reserved by the reactive power compensation equipment by using the formula (13), and finishing the optimization;
Figure FDA0002321024880000034
in the formula,
Figure FDA00023210248800000317
for the minimum dynamic reactive reserve of the reactive compensation equipment, the subscript g denotes the generator.
CN201911297768.9A 2019-12-17 2019-12-17 Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid Active CN111030196B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN201911297768.9A CN111030196B (en) 2019-12-17 2019-12-17 Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN201911297768.9A CN111030196B (en) 2019-12-17 2019-12-17 Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid

Publications (2)

Publication Number Publication Date
CN111030196A CN111030196A (en) 2020-04-17
CN111030196B true CN111030196B (en) 2020-12-11

Family

ID=70209242

Family Applications (1)

Application Number Title Priority Date Filing Date
CN201911297768.9A Active CN111030196B (en) 2019-12-17 2019-12-17 Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid

Country Status (1)

Country Link
CN (1) CN111030196B (en)

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103580022A (en) * 2013-11-05 2014-02-12 国家电网公司 Electrical power system dynamic reactive storage computing method
CN103701140A (en) * 2014-01-06 2014-04-02 国家电网公司 Dynamic reactive power reserve optimization method for improving transient voltage stability of alternating-current and direct-current power grid
CN104362642A (en) * 2014-10-27 2015-02-18 国家电网公司 Dynamic reactive reserved optimizing method for improving long-term voltage stabilization in AC/DC (Alternating Current/Direct Current) power grid
CN104466984A (en) * 2014-12-12 2015-03-25 国家电网公司 Dynamic reactive standby optimization method for increasing safety level of direct current commutation
CN110224410A (en) * 2019-03-27 2019-09-10 广东电网有限责任公司 Power grid Dynamic reactive power optimization configuration method based on transient voltage security constraint
CN110401184A (en) * 2019-06-28 2019-11-01 河海大学 Multi-infeed DC receiving end power grid emergency control optimization method and system

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN103580022A (en) * 2013-11-05 2014-02-12 国家电网公司 Electrical power system dynamic reactive storage computing method
CN103701140A (en) * 2014-01-06 2014-04-02 国家电网公司 Dynamic reactive power reserve optimization method for improving transient voltage stability of alternating-current and direct-current power grid
CN104362642A (en) * 2014-10-27 2015-02-18 国家电网公司 Dynamic reactive reserved optimizing method for improving long-term voltage stabilization in AC/DC (Alternating Current/Direct Current) power grid
CN104466984A (en) * 2014-12-12 2015-03-25 国家电网公司 Dynamic reactive standby optimization method for increasing safety level of direct current commutation
CN110224410A (en) * 2019-03-27 2019-09-10 广东电网有限责任公司 Power grid Dynamic reactive power optimization configuration method based on transient voltage security constraint
CN110401184A (en) * 2019-06-28 2019-11-01 河海大学 Multi-infeed DC receiving end power grid emergency control optimization method and system

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
Dynamic reactive power reserve optimisation in wind power integration areas;Tao Niu et al.;《IEEE》;20171231;第507-517页 *
提高暂态电压安全水平的动态无功备用优化方法;孙全才 等;《F中国电机工程学报》;20150605;第35卷(第11期);第2718-2725页 *

Also Published As

Publication number Publication date
CN111030196A (en) 2020-04-17

Similar Documents

Publication Publication Date Title
CN105703393B (en) A kind of micro-capacitance sensor voltage restoration methods based on Distributed Predictive Control strategy
CN103870703B (en) A kind of dynamic short-circuit ratio computational methods based on Thevenin's equivalence parameter tracking
CN103124072A (en) Load characteristic considered power grid dynamic reactive power optimization system and method
CN113328430A (en) Load model structure containing distributed photovoltaic power generation and parameter calculation method and system
CN106655201A (en) Security domain-based safe optimization and control method for electric power thermal stability
CN111581856B (en) Black-start process modeling and simulation method based on isolated power grid
CN106684855A (en) Transient stability emergency control method based on key branch identification
CN105186586B (en) A kind of method for improving AC-DC hybrid power grid static electric voltage stability
CN109038572A (en) Consider the voltage security range determining method of AC-DC hybrid power grid failure
CN101363885B (en) Method for discriminating voltage instability and load angle instability based on thevenin equivalent
CN110687385A (en) Grid-connected unit remote frequency disturbance testing method based on load interval dynamic adjustment
CN104767207A (en) Voltage stabilization prevention and control method based on reactive storage sensitivity of generators
CN111030196B (en) Dynamic sensitivity-based dynamic reactive power reserve optimization method for receiving-end power grid
CN106960262B (en) Active reserve capacity evaluation method and device for expected faults of extra-high voltage direct current line
CN115291520B (en) Model order reduction method, system and storage medium in micro-grid group analysis control
CN102646983B (en) Long-term reactive voltage analyzing and optimizing method in power system
Oktaviani et al. Continuous power flow and time domain analysis for assessing voltage stability
CN109449956B (en) Dynamic security domain-based extra-large urban power grid stability measure making auxiliary method
Seo et al. Determination of reactive power compensation considering large disturbances for power flow solvability in the korean power system
CN107658894B (en) Load substation voltage instability judgment method and device
CN111641204B (en) Calculation method and device for distributed energy admission capacity
Wang et al. Improved singular perturbation based model reduction of PMSG integrated power systems for large disturbance stability analysis
CN103560529A (en) Control method for restraining irregular power fluctuation of power system alternating current tie lines
Yi et al. Fast Amplitude Determination of Switching Overvoltage in Black-Start Plans Based on Gas Turbine Distributed Energy Supply System
Zhao et al. On-line voltage stability monitoring and control (vsmc) system in fujian power grid

Legal Events

Date Code Title Description
PB01 Publication
PB01 Publication
SE01 Entry into force of request for substantive examination
SE01 Entry into force of request for substantive examination
GR01 Patent grant
GR01 Patent grant