CN107579525B - Cold-start linear optimal power flow calculation method capable of calculating complete power flow information - Google Patents

Cold-start linear optimal power flow calculation method capable of calculating complete power flow information Download PDF

Info

Publication number
CN107579525B
CN107579525B CN201710712819.4A CN201710712819A CN107579525B CN 107579525 B CN107579525 B CN 107579525B CN 201710712819 A CN201710712819 A CN 201710712819A CN 107579525 B CN107579525 B CN 107579525B
Authority
CN
China
Prior art keywords
power
branch
active
power flow
node
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
CN201710712819.4A
Other languages
Chinese (zh)
Other versions
CN107579525A (en
Inventor
卫志农
张清松
孙国强
臧海祥
何天雨
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.)
Hohai University HHU
Original Assignee
Hohai University HHU
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 Hohai University HHU filed Critical Hohai University HHU
Priority to CN201710712819.4A priority Critical patent/CN107579525B/en
Publication of CN107579525A publication Critical patent/CN107579525A/en
Application granted granted Critical
Publication of CN107579525B publication Critical patent/CN107579525B/en
Active legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Landscapes

  • Supply And Distribution Of Alternating Current (AREA)

Abstract

The invention discloses a cold-start linearized optimal power flow calculation method capable of calculating complete power flow information. The example simulation result shows that the method maintains the high efficiency of the DC optimal power flow, and has higher precision and strong applicability.

Description

Cold-start linear optimal power flow calculation method capable of calculating complete power flow information
Technical Field
The invention relates to an optimal power flow calculation method, in particular to a cold-start linear optimal power flow calculation method capable of calculating complete power flow information.
Background
With the continuous increase of the load of the power grid and the increasingly complex operation characteristics of the power grid, the online calculation and analysis of the power system have more and more important significance in the operation and control of the power grid. An alternating current model is adopted for calculating the Optimal Power Flow (OPF) of the Power system. The alternating-current model is a typical nonlinear model, has high calculation precision and can completely reflect the real situation of the system. However, due to the nonlinear characteristics of the alternating current model, the calculation scale and difficulty of the alternating current model become larger with the increase of the power grid scale, so that the solution efficiency becomes lower, and even the situation of non-convergence may occur, which will hardly meet the requirements of online calculation and analysis of modern power systems.
The direct current model is a linear model which is most widely applied at present and is obtained by simplifying and approximating on the basis of an alternating current model, the direct current model is simple in calculation method, small in data volume, easy to obtain, high in calculation efficiency and free of convergence problems, but the direct current model ignores the influence of active loss and branch reactive power of a system, two important electrical quantities of a node voltage amplitude and reactive power cannot be obtained through calculation, and the two quantities have important significance for the stability and control of a power system.
Disclosure of Invention
The purpose of the invention is as follows: the invention provides a cold-start linear Optimal Power Flow calculation method capable of calculating complete Power Flow information, and solves the problems of poor precision and poor applicability of Direct Current Optimal Power Flow (DCOPF) in the field of electric Power system analysis and calculation degree.
The technical scheme is as follows:
the most central in the optimal power flow calculation is to establish a mathematical model of the optimal power flow calculation, and the mathematical model can substitute the obtained power parameters into the calculation for multiple iterations to finally obtain an optimal result; OPF mathematical models have long been applied to the planning and practical operation of power systems.
The mathematical model of OPF can be generally described as:
Figure GDA0002552184150000011
wherein: (x) is an objective function, h (x) is an equality constraint, g (x) is an inequality constraint, gmax、gminRespectively an upper limit and a lower limit of inequality constraint;
the objective function is mainly that the cost of the generator is minimum or the network loss of the system is minimum, namely:
Figure GDA0002552184150000021
or
Figure GDA0002552184150000022
In the formula: pGiActive power, P, for the i-th generatorDiIs the active load of node i, a2i、a1i、a0iIs the consumption characteristic curve parameter of the ith generator, ngNumber of generators, nbIs the number of system nodes.
The equality constraint is primarily a node power balance constraint, i.e.
Figure GDA0002552184150000023
In the formula: qGiReactive power, Q, for the i-th generatorDiFor reactive load of node i, Vi、VjVoltage amplitudes of nodes i, j, respectively，θi、θjThe voltage phase angles, G, of nodes i, j, respectivelyij、BijRespectively a real part and an imaginary part of the ith row and the jth column of the node admittance matrix; thetaijIs the voltage phase angle difference of the nodes i and j.
The inequality constraint is
Figure GDA0002552184150000024
In the formula: pijThe active power transmitted for the line ij,
Figure GDA0002552184150000025
·respectively, the upper and lower limits of the variable.
As can be seen from the OPF model, the method is a complex nonlinear programming problem, has more nonlinear equations, and as the scale of the power system is continuously enlarged, the OPF has higher and higher computational complexity, low computational efficiency and easy occurrence of the problem of non-convergence, which is difficult to meet the requirements of on-line computational analysis of the power system. Therefore, the invention linearizes the OPF model through 3 links of decoupling, replacing and cold starting.
1) Decoupling
Firstly, decoupling a nonlinear part in an equation constraint to obtain a new linear equation constraint, wherein the expression is as follows
Figure GDA0002552184150000031
Wherein: nl is the number of system branches, PGi、QGiActive and reactive power, P, respectively, from generators connected to node iil、QilActive and reactive power, P, respectively, at the head end of branch ll loss、
Figure GDA0002552184150000032
Active and reactive losses, P, in the branch lDi、QDiActive and reactive loads, A, respectively, of node iilIs constant when node i sends on branch lThe transmission power is 1, the reception power is-1, and the other cases are 0. A. theil' is a constant, A when node i receives power on branch lil' is 1, otherwise 0.
2) Substitution
Let i and j be the first and last nodes of branch l, then the flow equation of the branch is
Figure GDA0002552184150000033
In the formula: pjl、QjlActive and reactive powers, g, at the ends of the branches lij、bijThe algebraic relation with the corresponding element in the admittance matrix is gij＝-Gij、bij＝-Bij。
The active and reactive losses of a branch can be expressed as:
Figure GDA0002552184150000034
in this case, the formula (7) may be substituted for the formula (8)
Figure GDA0002552184150000035
By transforming the formula (9)
Figure GDA0002552184150000036
Since the node voltage amplitude is approximately 1.0, the square term V of the voltage amplitude in equations (7) and (9) can be obtained2Performing Taylor series expansion around 1.0, and omitting high-order terms
V2≈2V-1 (11)
Suppose that
ViVjsinθij≈θi-θj(12)
At this time, the linear branch power flow equation can be obtained by simultaneously carrying the equations (10), (11) and (12) into the equation (7):
Figure GDA0002552184150000041
thus, a linear calculation formula of the branch I power is obtained and is substituted into an equality constraint and an inequality constraint.
3) Cold start
A traditional alternating current power flow equivalent model diagram is shown in an attached drawing 2, and a network loss equivalent load r is introduced on the basis of the traditional alternating current power flowequ,ijInstead of the line active loss, virtual nodes i ', j' are introduced at the same time. As shown in fig. 3. Pi、PjAnd Pi′、Pj' are the active power of the corresponding nodes, respectively. Assuming that the voltage at each node is approximately equal to 1.0, when r is satisfiedequ,ij＝2/Ploss,ijIn time, the active power consumed by the resistor is Ploss,ij[ 2 ] satisfies Pi＝Pj+Ploss,ijSo that the active loss of the branch can be equivalent to the increased resistance. In the alternating current power flow calculation, the active loss of the branch is shown as the formula (14):
Figure GDA0002552184150000042
in the formula: i isr,ijIs flowed through rijCurrent of (S)ij' is the apparent power of branch i ' j ', αijTaking a proportionality factor between the branch apparent power and the active power as 1.05, Pij' is the active power of line i ' j '.
Based on the model shown in FIG. 3, the sum of the active power consumed by the equivalent load on the i side of all branches connected to the node i can be obtained according to equation (14)
Figure GDA0002552184150000043
In the formula: ploss,ijIs the active loss of branch ij.
P of all nodes except balance nodeequ.iForming a network loss equivalent load vector Pequ. At this time, the node injects an active power vector of
P＝PG-PD-Pequ(16)
In the formula: pGFor generating an active power vector, P, for the generatorDIs an active load vector.
P in formula (14)ijThe solution method is as follows:
the direct current power flow simplified branch model is shown in figure 3. The branch resistance is omitted from the model and V is assumedi,Vj≈1，θijAbout 0 is then sin thetaij≈θij，cosθ ij1, neglecting branch reactive power and only considering branch reactance xijThe active power of the branch is Pij＝(θi-θj)/xij. Solving a direct current model equation to obtain the voltage phase angle of each node, and calculating the active power of each branch according to the formula (17)
Figure GDA0002552184150000051
In the formula: pij' active power of branch ij, [ theta ]i′、θj' the magnitude of the phase angle of the voltage at nodes i, j, respectively.
According to the above concept, the active and reactive losses of each branch in equation (13) can be obtained by the following equation
Figure GDA0002552184150000052
In the formula: sijThe active power calculated according to the formula 17 is substituted into the formula (18) to obtain the active and reactive power losses for the apparent power at the head end of the branch l.
After the information such as the voltage phase angle and the like is obtained after each calculation, the active loss and the reactive loss are calculated through the formula (17) and then substituted into the next calculation.
Has the advantages that: the invention carries out linear processing on the optimal power flow calculation of the power system, can not only use the problem that the direct current model is inaccurate in result and limited in application occasions due to neglecting important parameters, but also solve the problem of low solving efficiency in the alternating current model, can be widely applied to power grids of various scales and meets the requirements of online calculation and analysis of modern power systems.
Drawings
FIG. 1: a method flow diagram of the invention;
FIG. 2 is a drawing: traditional alternating current power flow equivalent model diagram
FIG. 3: and simplifying a branch model by the direct current power flow.
DETAILED DESCRIPTION OF EMBODIMENT (S) OF INVENTION
The cold-start linearization optimal power flow calculation method capable of calculating complete power flow information is realized by the following steps:
(1) obtaining the bus number, name, active load, reactive load, parallel compensation capacitor of the power system, the branch number, the serial node number of the head end and the tail end node number, the series impedance, the parallel admittance, the transformer transformation ratio and the impedance of the power transmission line, the upper and lower limits of the active output and the reactive output of the generator, the coal-fired economic parameters of the generator and other network parameter information;
(2) initializing a program;
(3) calculating a complementary Gap, judging whether the complementary Gap meets the precision requirement, namely whether the complementary Gap is smaller than the convergence precision, if so, outputting an optimal solution, and ending circulation, otherwise, continuing;
(4) the optimal power flow mathematical model is established as follows:
Figure GDA0002552184150000061
wherein: (x) is an objective function, h (x) is an equality constraint, g (x) is an inequality constraint, gmax、gminRespectively an upper limit and a lower limit of inequality constraint;
wherein the objective function is the system network loss minimum, namely:
Figure GDA0002552184150000062
in the formula: pGiActive power, P, for the i-th generatorDiIs the active load of node i, ngNumber of generators, nbIs the number of system nodes.
Where the equation is constrained to:
Figure GDA0002552184150000063
wherein: nl is the number of system branches, PGi、QGiActive and reactive power, P, respectively, from generators connected to node iil、QilActive and reactive power, P, respectively, at the head end of branch ll loss、
Figure GDA0002552184150000064
Active and reactive losses, P, in branch lDi、QDiActive and reactive loads, A, respectively, of node iilIs a constant value, 1 when node i transmits power on branch l, -1 when receiving power, otherwise 0. A. theil' is a constant, A when node i receives power on branch lil' is 1, otherwise 0.
Wherein the inequality constraints are:
Figure GDA0002552184150000065
in the formula: pijThe active power transmitted for the line ij,
Figure GDA0002552184150000066
·respectively, the upper and lower limits of the variable.
The active power and the reactive power of the line can be calculated by utilizing the following branch flow equation and substituted into the constraint model for calculation:
Figure GDA0002552184150000071
(5) solving an optimized power flow mathematical model by using a primal-dual interior point method:
computing equality constraints, inequalitiesConstrained jacobian matrix
Figure GDA0002552184150000072
Hessian matrix for calculating objective function, equality constraint and inequality constraint
Figure GDA0002552184150000073
And each constant term L'x、Ly、Lw、
Figure GDA0002552184150000074
Solving the increment delta x, delta y, delta u and delta w of the total variable x, the Lagrange multiplier y and the relaxation variables u and w according to the following equations;
Figure GDA0002552184150000075
Figure GDA0002552184150000076
Figure GDA0002552184150000077
wherein:
Figure GDA0002552184150000078
Figure GDA0002552184150000079
Figure GDA00025521841500000710
(6) determining iteration step sizes of an original variable and a dual variable:
Figure GDA00025521841500000711
Figure GDA00025521841500000712
(7) update all variables and lagrange multipliers:
Figure GDA00025521841500000713
Figure GDA0002552184150000081
(8) obtaining node voltage phase angle information, and updating branch network loss substitution according to the following formula to perform next iterative calculation:
Figure GDA0002552184150000082
wherein: p'ij、S′ij、Ploss,ijThe equivalent active power, the equivalent apparent power and the active power loss of the line ij; i isr,ijTo flow through a resistor rijα is the proportional factor of the apparent power and the active power of the line, and takes 1.05Pequ,iAnd is the network loss equivalent load of the node i.
Wherein:
Figure GDA0002552184150000083
in the formula: p'ijIs the equivalent active power of line ij, thetai、θjThe phase angles of the voltages, x, of nodes i, j, respectivelyijIs the branch reactance.
(9) And (4) judging whether the iteration frequency reaches the maximum value, if so, calculating to be not converged, and if not, adding 1 to the iteration frequency, returning to the step (3) and continuing.
The program initialization in the step 2 comprises the following steps: setting an initial value for a state variable in an algorithm, setting an iteration counter K to be 0 and setting the maximum iteration number KmaxConvergence accuracy, forming a node admittance matrix B, etc.
Therefore, the invention processes the OPF model into the linearized OPF model by the linearization processing technology, the model has less simplification, theoretically has higher calculation precision, and can solve more complete trend information.
The invention carries out linear processing on the nonlinear concentrated node power balance equation and the line transmission power equation in the alternating current optimal power flow model, has higher calculation efficiency and stronger convergence compared with the alternating current optimal power flow theoretically, and has higher precision while solving and perfecting the power flow information.
The calculation method provided by the invention carries out example simulation in an IEEE-30, IEEE-300, Polish-2736 and Polish-3120 node system, and verifies that the calculation method provided by the invention has higher precision and can calculate more complete load flow information while ensuring the calculation efficiency by comparing the difference value between the DCOPF and the calculation result of the provided Optimal load flow model and (Alternating Current Optimal Power flow, ACOPF).
The following describes the results of the experiments of the present invention:
the invention takes IEEE-30, IEEE-300, Polish-2736 and Polish-3120 node systems as examples to verify the linearized optimal power flow model provided by the invention. For the convenience of observation and analysis, the optimum Cost of ACOPF is taken as the benchmark and is recorded as CostACAnd recording the optimal Cost of the optimal power flow of the linearized model as CostgThen the relative error of each model to ACOPF can be calculated according to equation (18):
ΔCostg＝|Costg-CostAC|/CostAC×100％
TABLE 1 optimal load flow calculation accuracy comparison based on different models
Figure GDA0002552184150000091
Table 1 gives the calculated results and relative errors for the different models. As can be seen from table 1, in each test system, the model provided by the present invention can be well converged to obtain the optimal solution and its neighborhood, which verifies the feasibility and effectiveness of the application of the linearization model introduced herein to the optimal power flow calculation. In addition, compared with ACOPF, the optimization result precision of DCOPF is poor, the relative error is more than 1.5%, and the error is larger and larger along with the increase of the system scale, so that a larger application bottleneck exists. The error of the linearized optimal power flow model provided by the invention is positively correlated with the system scale, but the errors are kept within 1%, compared with the DCOPF, the accuracy is greatly improved, and the accuracy is insensitive to the system scale change.
TABLE 2 number of calculation iterations and calculation times for different models
Figure GDA0002552184150000092
Table 2 gives the number of calculation iterations and the calculation time for the different models. As can be seen from the table, the number of iterations of the ACOPF increases with the increase of the system scale, a non-convergence situation is likely to occur in a large system due to the situations of an excessive load, an increase of the line impedance ratio, and the like, and the calculation time increases with the increase of the system scale, so that the online calculation and analysis requirements of the power system are difficult to meet. The DCOPF greatly simplifies the program by linearizing the complex nonlinear constraint, greatly reduces the iteration times, keeps the calculation time within 0.5s and has higher calculation efficiency. The linearization OPF provided by the invention linearizes the nonlinear constraint through less simplification, although the calculation time and the iteration times are slightly improved compared with the DCOPF, the efficiency is still kept, the calculation time is within 0.7s and is greatly improved compared with the ACOPF, and meanwhile, the iteration times are not greatly changed along with the system scale, the sensitivity to the system scale is low, and the online calculation analysis of a power system can be met.

Claims (4)

1. A cold start linearization optimal power flow calculation method capable of calculating complete power flow information is characterized by comprising the following steps:
(1) obtaining network parameter information of the power system;
(2) initializing a program;
(3) calculating the complementary Gap, judging whether the complementary Gap meets the precision requirement, if so, outputting an optimal solution, and ending circulation, otherwise, continuing;
(4) the optimal power flow mathematical model is established as follows:
Figure FDA0002552184140000011
wherein: (x) is an objective function, h (x) is an equality constraint, g (x) is an inequality constraint, gmax、gminRespectively an upper limit and a lower limit of inequality constraint;
(5) solving an optimized power flow mathematical model by using a primal-dual interior point method:
calculating Jacobian matrix of equality constraint and inequality constraint
Figure FDA0002552184140000012
Hessian matrix for calculating objective function, equality constraint and inequality constraint
Figure FDA0002552184140000013
And each constant term L'x、Ly、Lw、
Figure FDA0002552184140000014
Solving the increment delta x, delta y, delta u and delta w of the total variable x, the Lagrange multiplier y and the relaxation variables u and w according to the following equations;
Figure FDA0002552184140000015
Figure FDA0002552184140000016
Figure FDA0002552184140000017
wherein:
Figure FDA0002552184140000018
Figure FDA0002552184140000019
(6) determining iteration step sizes of an original variable and a dual variable:
Figure FDA00025521841400000110
Figure FDA00025521841400000111
(7) update all variables and lagrange multipliers:
Figure FDA0002552184140000021
Figure FDA0002552184140000022
(8) and updating the branch network loss according to the following calculation formula, and substituting the branch network loss into the next iterative calculation:
Figure FDA0002552184140000023
wherein, P'ij、S′ij、Ploss,ijThe equivalent active power, the equivalent apparent power and the branch network loss of the line ij are respectively; i isr,ijTo flow through a resistor rijα current magnitudeijIs a proportional factor between the apparent power and the active power of the branch circuit;
(9) judging whether the iteration frequency reaches the maximum value, if so, calculating to be not convergent, if not, adding 1 to the iteration frequency, returning to the step (3), and continuing;
the method is characterized in that: the equality constraint in the optimal power flow mathematical model specifically comprises the following steps:
Figure FDA0002552184140000024
wherein: nl is the number of system branches, PGi、QGiActive and reactive power, P, respectively, from generators connected to node iil、QilActive and reactive power, P, respectively, at the head end of branch ll loss、
Figure FDA0002552184140000025
Active and reactive losses, P, in branch lDi、QDiActive and reactive loads, A, respectively, of node iilIs a constant, 1 when node i transmits power on branch l, -1 when receiving power, 0 otherwise; a. theil' is a constant, A when node i receives power on branch lil' is 1, otherwise 0;
wherein: pil、QilCalculated as follows:
Figure FDA0002552184140000026
in the formula: pil、QilActive and reactive powers, g, at the ends of the branches lij、bijThe algebraic relation with the corresponding element in the admittance matrix is gij＝-Gij、bij＝-Bij，Gij、BijThe real part and the imaginary part, P, of the ith row and the jth column of the node admittance matrix respectivelyl loss、
Figure FDA0002552184140000027
Respectively, the active and reactive power losses, V, on branch li、VjVoltage amplitudes at nodes i, j respectivelyValue of thetai、θjVoltage phase angles of the nodes i and j are respectively;
Pl loss、
Figure FDA0002552184140000028
the calculation is as follows:
Figure FDA0002552184140000031
Pijactive power transmitted for line ij, αijFor the branch by a proportional factor between apparent power and active power, SijApparent power, x, of line ijijIs a branch reactance;
the inequality constraint
Figure FDA0002552184140000032
The method comprises the following inequalities:
PGi、QGirespectively active and reactive power, V, from generators connected to node iiIs the voltage amplitude of node i, θiIs the voltage phase angle of node i;P Gi、Q Gi、V i、θ i、P ijrespectively represent PGi、QGi、Vi、θi、PijA lower limit value of (d);
Figure FDA0002552184140000033
respectively represent PGi、QGi、Vi、θi、PijAn upper limit value of (d);
wherein: p in the inequality constraintijThe calculation method is as follows
Figure FDA0002552184140000034
gij、bijThe algebraic relation with the corresponding element in the admittance matrix is gij＝-Gij、bij＝-Bij，Gij、BijRespectively are the real part and the imaginary part, V, of the ith row and the jth column of the node admittance matrixi、VjThe voltage amplitudes, θ, of nodes i, j, respectivelyi、θjThe voltage phase angles of nodes i and j, respectively.
2. The cold-start linearized optimal power flow calculation method capable of calculating complete power flow information as claimed in claim 1, wherein: the equivalent active power P 'in the step (8)'ijThe calculation formula is as follows:
Figure FDA0002552184140000035
in the formula: p'ijEquivalent active power of branch ij, θiAnd thetajThe phase angles of the voltages, x, of nodes i, j, respectivelyijIs the branch reactance.
3. The method of claim 1, wherein the branch circuit apparent power to active power scaling factor α is a cold-start linearized optimal power flow calculation method capable of calculating complete power flow informationijThe value was 1.05.
4. The cold-start linearized optimal power flow calculation method capable of calculating complete power flow information as claimed in claim 1, wherein the network parameter information in step (1) includes: the system comprises a bus serial number, a name, an active load, a reactive load, a parallel compensation capacitor, a branch serial number, a head end node and a tail end node serial number, series impedance, a parallel admittance, transformer transformation ratio and impedance of a power transmission line, upper and lower limits of active power output and reactive power output of a generator and coal-fired economic parameters of the generator.
CN201710712819.4A 2017-08-18 2017-08-18 Cold-start linear optimal power flow calculation method capable of calculating complete power flow information Active CN107579525B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN201710712819.4A CN107579525B (en) 2017-08-18 2017-08-18 Cold-start linear optimal power flow calculation method capable of calculating complete power flow information

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN201710712819.4A CN107579525B (en) 2017-08-18 2017-08-18 Cold-start linear optimal power flow calculation method capable of calculating complete power flow information

Publications (2)

Publication Number Publication Date
CN107579525A CN107579525A (en) 2018-01-12
CN107579525B true CN107579525B (en) 2020-08-25

Family

ID=61033900

Family Applications (1)

Application Number Title Priority Date Filing Date
CN201710712819.4A Active CN107579525B (en) 2017-08-18 2017-08-18 Cold-start linear optimal power flow calculation method capable of calculating complete power flow information

Country Status (1)

Country Link
CN (1) CN107579525B (en)

Families Citing this family (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN109902854B (en) * 2019-01-11 2020-11-27 重庆大学 Method for constructing optimal power flow full-linear model of electric-gas interconnection system
CN110445146B (en) * 2019-07-24 2023-06-23 广东电网有限责任公司电力调度控制中心 Tidal current calculation method based on tidal current calculation model of multi-terminal-containing flexible direct-current series-parallel power grid
CN111884208B (en) * 2020-07-17 2023-11-14 国网重庆市电力公司 Linear power flow model library construction method based on state space transformation and quick response method thereof
CN111753255B (en) * 2020-07-30 2024-03-15 中国南方电网有限责任公司 Linearization technology for optimizing power grid operation constraint calculation
CN113381402B (en) * 2021-05-31 2022-05-06 深圳大学 Node level dispersion method for obtaining minimum state power flow of alternating current power system

Family Cites Families (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
KR20080047755A (en) * 2006-11-27 2008-05-30 군산대학교산학협력단 The optimal power flow algorithm by nonlinear interior point method
CN104616081A (en) * 2015-02-10 2015-05-13 河海大学 Disperse relaxation factor tidal current model based minimum electricity generating cost incremental quantity obtaining method
CN104794531A (en) * 2015-04-01 2015-07-22 河海大学 MDCOPF (modified direct current optimal power flow) method based on grid loss equivalent load model
CN105046588B (en) * 2015-08-13 2019-04-30 河海大学 A kind of calculation method of the improvement direct current Dynamic Optimal Power Flow Problem based on network loss iteration
CN106253288A (en) * 2016-07-19 2016-12-21 河海大学 A kind of optimal load flow algorithm containing THE UPFC based on automatic differential
CN106684857B (en) * 2016-09-05 2018-02-09 国网江苏省电力公司电力科学研究院 A kind of linearisation optimal load flow model containing THE UPFC
CN107039981A (en) * 2017-04-20 2017-08-11 河海大学 One kind intends direct current linearisation probability optimal load flow computational methods

Also Published As

Publication number Publication date
CN107579525A (en) 2018-01-12

Similar Documents

Publication Publication Date Title
CN107579525B (en) Cold-start linear optimal power flow calculation method capable of calculating complete power flow information
CN106532711B (en) Change the Newton load flow calculation method of Jacobian matrix with iteration and node type
US8326594B2 (en) Power flow analysis for balanced power distribution systems
CN108448585B (en) A kind of electric network swim equation solution method of linearization based on data-driven
CN109617080B (en) Rectangular coordinate Newton method load flow calculation method based on improved Jacobian matrix
CN104600697B (en) Quasi-direct current optimal power flow method considering temperature influence
CN106709243B (en) The penalty method polar coordinates Newton load flow calculation method of the power grid containing small impedance branches
CN108075480B (en) State estimation method and system of AC/DC system
CN106856327B (en) A kind of compensation of line series containing small impedance branches algorithm quicksort tidal current computing method
CN106532712B (en) The penalty method rectangular coordinate Newton load flow calculation method of the power grid containing small impedance branches
CN104765962B (en) A kind of power system state estimation method of meter and temperature change
CN109494748B (en) Newton method load flow calculation method based on node type and modified Jacobian matrix
Jiang et al. Boundary-derivative direct method for computing saddle node bifurcation points in voltage stability analysis
CN113555891B (en) Method for estimating stability domain of AC/DC system containing uncertain parameters based on square sum
CN106410811B (en) Iteration small impedance branches endpoint changes the tidal current computing method of Jacobian matrix for the first time
CN108183484B (en) Decoupling semi-linear optimal power flow model based on hot start environment
Ali et al. Calculating voltage feasibility boundaries for power system security assessment
CN111725812B (en) Load flow calculation method, device, equipment and storage medium of large-scale power distribution system
Lin et al. SVSM calculation of power system with high wind‐power penetration
CN106953331A (en) A kind of Harmonic Power Flow of Power Systems algorithm for considering uncertain and three-phase imbalance
Qin et al. A modified data-driven regression model for power flow analysis
CN106712029B (en) The Newton load flow calculation method of small impedance branches PQ endpoint change Jacobian matrix
CN108123434B (en) Method for calculating slope of PV curve to obtain operating point of PV curve
CN103336876A (en) Open loop distribution network power flow simulation method based on multi-agents
CN106529089B (en) Penalty method algorithm quicksort tidal current computing method for the power grid containing small impedance branches

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