CN101141064B - Method for distributed tidal current analyzing by exchange boundary node state and net damage information - Google Patents

Abstract

The invention discloses a method of completing the distributed tide analysis by exchanging the border node state and the network damage information, which comprises: establishing a distributed tide analyzing system according to the actual scheduling management manner of the electric power system; based on the topology connection relations of the electric power system and the operation situations of the practical system, dividing the interconnected electric network by the dividing method with border area, and clarifying the counting objects and the data sources of the counting server and the coordinating counting server; a domain tide counting server and the superior coordinating counting server are initialized by counting data and parameters, while the coordinating counting server calls the domain tide counting server to together complete the network integrative tide decomposition coordinating solve; besides, the servers call the processes, the domain tide counting server feeds back the result to the coordinating counting server so as to make the coordinating counting server obtain the convergent network integrative tide result.

Description

Finish the method for distributed tidal current analysis by exchange boundary node state and net damage information

Technical field

The present invention relates to a kind of method of finishing distributed tidal current analysis, particularly a kind ofly finish the method for distributed tidal current analysis, belong to electric power system distributed simulation technology field by exchange boundary node state and net damage information.

Background technology

Along with the interconnected continuous reinforcement of electric power system, electrical network constitutes complicated more, and the operation difficulty increases greatly.When local fault takes place,, will develop into the major accident that jeopardizes whole system if deal with improperly.In order to improve the security and stability of interconnected electric power system, integrated simulation analysis that whole electrical network is not had a simplification seems and more and more is necessary.

China's electrical network adopts the management system of " differentiated control, hierarchical control, distribution process " by coordinated management of multi-stage scheduling center and control.As shown in Figure 1, the regional power grid control centre that rank is lower, as economize to transfer, transfer etc., only be responsible for keeping the power-balance in the region within the jurisdiction, administer and maintain system running state and parameter; And the higher control centre of rank as net accent, state's accent etc., then will be responsible for interregional Power Exchange control, coordinates regional dispatching of power netwoks activity.Because China's electric power system has wide area distribution, parameter magnanimity, model complexity, high-level control centre can't directly obtain the electric network state of having jurisdiction over and parameter, need transmit or report desired data layer by layer by low-level control centre.This make the collection of nationwide integrated power grid parameter and real-time status, synchronously, to integrate required time longer, and maintenance difficulties is bigger.Simultaneously, along with deepening continuously of electricity market process, in market competition, each is dispatched mechanism and payes attention to protection to its data and information more, thickeied the information barrier of each scheduling mechanism, has further hindered the shared of data and information system the in.Therefore, traditional integrated simulation calculation of centralized the whole network is difficult to canbe used on line.

Adopt the electrical network analysis computational methods of distributed computing technology in the independence of each side's its data that keeps participating in calculating and computational resource, to obtain the integrated simulation analysis result of the whole network, have rapidly and efficiently, information security, applying flexible and the characteristics that are easy to expand.The critical function that distributed tidal current is calculated is to obtain the unified simulation result of the whole network when keeping each control centre's calculating independence, thereby this technology is expected to become the effective means that solves the integrated emulation of extensive interconnected systems.At present, to the research of distributed trend of interconnected network and association area thereof, mainly concentrate on the following aspects both at home and abroad:

1. rational electric power networks cutting method;

2. transplanting and the test of parallel flow derivation algorithm in distributed environment;

3. the equivalent network of trend composition decomposition solution procedure calculates and system's imbalance power distribution;

As can be seen, how the integrated trend composition decomposition of existing interconnected network calculating Methods Research mainly concentrates on according to practical power systems zone situation and carries out decomposition that trend calculates and to existing parallel flow algorithm improvement aspect.These researchs lack the consideration of the characteristics such as high communication delay, data and computational resource isomery that the distributed computing environment (DCE) in the Wide Area Network environment is had mostly, do not have to set up yet and can unify to handle the composition decomposition computation model that the whole network trend balance and imbalance power distribute, thus in practical power systems the application power deficiency.

Summary of the invention

The objective of the invention is to, a kind of method of finishing distributed tidal current analysis by exchange boundary node state and net damage information is provided, with the interconnection electric current is coordination variable, only needs to transmit a small amount of boundary information in the computational process, the problem of can flexible processing the whole network imbalance power distributing.Consulting of its distributed integrated tidal current analysis basic procedure is shown in Figure 2.

The present invention adopts following technological means to realize:

A kind ofly finish the method for distributed tidal current analysis, comprising by exchange boundary node state and net damage information:

Step 1; Make up distributed tidal current analysis system according to electrical network actual schedule way to manage; Interconnected network is interconnected by the harmonious management in regional power grid control centre and higher level control centre, information; Described distributed tidal current analysis system is connected and composed by network by regional trend calculation server in the regional power grid control centre and the coordination calculation server in the higher level control centre; Wherein: regional trend calculation server, be responsible for the trend of its electrical network of having jurisdiction over and calculate; And the coordination calculation server is responsible for coordinating each regional power grid trend computational process, and it concerns as shown in Figure 3;

Step 2; From the power network topology annexation,, adopt the cutting method that has borderline region that actual electric network is carried out cutting, as shown in Figure 4 according to the operation conditions of actual electric network.The calculating object and the Data Source of clear and definite regional trend calculation server and coordination calculation server;

Define two regional interconnected S ₀Comprise two regional power grid S ₁And S ₂, l interconnects by interconnection, as shown in Figure 7; B wherein ₁, B ₂Represent regional power grid S respectively ₁, S ₂Boundary node,

Be respectively S ₁, S ₂In other nodes are formed except boundary node network; With boundary node B ₁And B ₂Division respectively forms the virtual boundary node

With And with the virtual boundary node at interconnection l and its two ends

With

Regard a zone separately as, other All Ranges effects of connection are played in this zone, are defined as borderline region S _BPartitioned mode as shown in Figure 8;

Described regional power grid S ₁And S ₂Belong to regional power grid control centre compass of competency, borderline region S _BBelong to higher level control centre compass of competency; Under this slit mode, the condition of convergence of the whole network trend is: regional power grid S ₁And S ₂Middle trend is calculated and is reached convergence, regional power grid S ₁And S ₂Internal node power all reaches balance, and boundary node state satisfies

$\left\{\begin{array}{c}{u}_B=u_{\tilde{B}},{\mathrm{\θ}}_B={\mathrm{\θ}}_{\tilde{B}}\\ {\stackrel{\→}{i}}_B+{\stackrel{\→}{i}}_{\tilde{B}}=0\end{array}\right.---\left(1\right)$

U wherein _BAnd θ _BBe regional power grid S ₁And S ₂Interior trend is calculated boundary node B among the convergence result ₁And B ₂Voltage magnitude and phase angle vector;

With

Be borderline region S _BBoundary node B when interior trend is calculated convergence ₁And B ₂Voltage magnitude and phase angle vector;

Be regional power grid S ₁And S ₂Trend is calculated boundary node B among the convergence result ₁And B ₂Going up the vector of forming from the injection current phasor of interconnection, is positive direction with the inflow;

Be borderline region S _BMiddle trend is calculated when restraining from boundary node B ₁And B ₂The vector that the electric current phasor that injects on interconnection is formed is a positive direction with the outflow;

Step 3; Zone trend calculation server and coordination calculation server calculate with data and parameter initialization, may further comprise the steps:

Step 3.1: the basic network parameter of the regional trend calculation server electrical network that initialization is had jurisdiction in the regional power grid control centre comprises that all participate in type, load and generator output set point, generator machine end node voltage magnitude and the slack bus phase angle etc. of the network node of trend calculating;

Step 3.2: the regional trend calculation server initialization boundary condition information in the regional power grid control centre, comprise the numbering, title etc. of boundary node, the composition of boundary condition, i.e. the vector sum regional power grid slack bus phase angle formed of the injection current phasor of boundary node;

Step 3.3: the trend calculation server initialization trend parameters calculated in the regional power grid control centre comprises employed iterative method, maximum iteration time, node voltage bound, the minimum power deviation in order to judge that trend restrains;

Step 3.4: the coordination calculation server initialization borderline region network parameter in the higher level control centre comprises title, the interconnection impedance of boundary node;

Step 3.5: the coordination calculation server in the higher level control centre is set the integrated trend of the whole network and is coordinated to find the solution Control Parameter, the proportionality coefficient that comprises maximum iteration time, each zone burden the whole network active power loss, and the required precision of boundary node power-balance, i.e. unbalanced current vector maximum amplitude on the required boundary node of Decision boundaries node power balance;

Step 4: the coordination calculation server calls regional trend calculation server and finishes the integrated trend composition decomposition of the whole network solution procedure jointly; Call flow comprises following basic step as shown in Figure 5 between server:

Step 4.1: the coordination calculation server in the higher level control centre is according to step 3.4,3.5 initialization borderline region network data and Control Parameter, and regional power grid control centre inner region trend calculation server is according to the basic network parameter and the trend parameters calculated of step 3.1～3.3 electrical networks that initialization is had jurisdiction over;

Step 4.2: coordinate calculation server and set the initial boundary condition, and divide relation, corresponding injection current and phase angle set point are sent to regional trend calculation server according to electrical network in the step 2 according to method in the claim 3;

Step 4.3: regional trend calculation server starts one's respective area trend computational process, according to resulting boundary condition and internal node parametric solution zone power flow equation, obtains the voltage of deviation boundary node from the trend result of convergence

With the regional network damage information

I=1,2, and information sent to the coordination calculation server;

Step 4.4: coordinate calculation server according to the parameter of setting in regional calculation of tidal current information that obtains and the initialization procedure, the amount of unbalance Δ P of the current imbalance amount Δ I of computation bound node and regional power grid burden the whole network active power loss;

Step 4.5: if ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ then judges the convergence of the whole network trend, and computational process finishes, wherein ‖ ‖ ₂Two norms of expression vector, ξ is little positive constant; Otherwise according to [Δ I, Δ P] ^TCalculation of boundary conditions correction [Δ I _B, Δ Θ] ^TThe boundary condition set point is upgraded in the back, returns step 4.2;

Step 5: regional trend calculation server feeds back to the coordination calculation server with result of calculation, so that coordinate the integrated calculation of tidal current of the whole network that calculation server obtains convergence.

Aforesaid according to the current imbalance amount of computation bound node and the amount of unbalance of regional power grid active power loss, judge whether uniform convergence of the integrated trend of the whole network; Need satisfy following primary condition simultaneously:

A: boundary node power reaches balance, promptly satisfies (1) formula in the step 2;

B: the whole network active power loss is reasonable distribution between each regional power grid, satisfies following equation,

$\mathrm{\Δ}{P}_{\mathrm{loss}}^i=P_{\mathrm{loss}}^i-P_{\mathrm{loss}}^{\mathrm{all}}{\mathrm{\η}}_i=0,i=\mathrm{1,2}---\left(2\right)$

П={ η wherein _iBe regional power grid S ₁And S ₂The vector that the proportionality coefficient of burden the whole network active power loss is formed;

It is the active power loss that from the regional power grid calculation of tidal current, counts;

It is the whole network active power loss that obtains by each regional power grid active power loss addition;

It is regional power grid active power loss amount of unbalance.

Aforesaid boundary condition comprises: the vectorial IB and the regional power grid slack bus phase angle set point Θ that form from the injection current phasor of interconnection on the border bus of regional power grid.

Aforesaid regional trend calculation server is according to given boundary condition zoning trend; Wherein said regional power grid electrical network S ₁Be made up of n node and some branch roads, the trend computation model can be expressed as the Nonlinear System of Equations form, promptly

$g({\stackrel{\→}{v}}_1,{\stackrel{\→}{v}}_2,...{\stackrel{\→}{v}}_n)=\left\{\begin{array}{c}{P}_i^{\mathrm{SP}}-u_i\underset{j\∈i}{\mathrm{\Σ}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\θ}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\θ}}_{\mathrm{ij}})=0\\ Q_i^{\mathrm{SP}}-u_i\underset{j\∈i}{\mathrm{\Σ}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\θ}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\θ}}_{\mathrm{ij}})=0\end{array}\right.---\left(3\right)$

Wherein

I=1,2 ..., n is a node voltage phasor, g is the node power equilibrium equation, With Be the given meritorious and reactive power of node i, G _Ij+ jB _IjBe the admittance between node i and the node j, j ∈ i represents all nodes of linking with the i node to comprise i node self.

Aforesaid S ₁All nodes of zone are by internal node

With boundary node B ₁Two parts are formed, corresponding with

Represent the vector of the voltage phasor composition of internal node, with

The vector of representing the border node voltage phasor to form; Accordingly, the node power equilibrium equation group that (3) formula is described can be divided into two classes, internal node The power balance equation group Power balance equation group with boundary node

Do not select boundary node as slack bus when calculating trend as regional power grid, in finishing given internal node generator node meritorious exert oneself, the node voltage amplitude, meritorious and the load or burden without work of load bus, and under the voltage magnitude of slack bus and the phase angle situation, internal node power balance equation group

Relevant with internal node with boundary node voltage, boundary node power balance equation group With internal node voltages, boundary node voltage and boundary node B ₁Injection current phasor from interconnection l is relevant, and it is expressed as following form,

${\mathrm{<figure-callout\; id="1"\; label="g"\; filenames="HSB00000218026900031.png,HSB00000218026900062.png"\; state="\{\{state\}\}">g</figure-callout>}}_1=\left\{\begin{array}{c}{g}_{\mathrm{In}}^1(V_{\mathrm{<figure-callout\; id="1"\; label="B"\; filenames="HSB00000218026900031.png,HSB00000218026900062.png"\; state="\{\{state\}\}">B</figure-callout>}}^1,V_{\mathrm{In}}^1)=\left\{\begin{array}{c}{P}_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}})=0,i\&Element;S_{\mathrm{In}}^1\\ Q_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}})=0,i\&Element;S_{\mathrm{In}}^1\end{array}\right.\\ g_B^1({\mathrm{<figure-callout\; id="1"\; label="V\; B"\; filenames="HSB00000218026900031.png,HSB00000218026900062.png"\; state="\{\{state\}\}">V</figure-callout>}}_B^{},V_{\mathrm{In}}^1,I_B^1)=u_k\&angle;{\mathrm{\&theta;}}_k*\widehat{\stackrel{\&RightArrow;}{i_k}}-u_k\underset{j\&Element;k}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}})\\ -{\mathrm{ju}}_k\underset{j\&Element;k}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}})=0,k\&Element;S_B^1\end{array}\right.---\left(4\right)$

Wherein

Be by boundary node B ₁Go up the vector of forming from the injection current phasor of interconnection l,

Expression node k goes up the conjugation from the injection current phasor of interconnection l, and its dependent variable meaning is with (3) formula.

Behind the basic data initialization procedure of the electrical network of having jurisdiction in the aforesaid completing steps 3.1, given again

With regional power grid S ₁Interior slack bus voltage phase angle set point

Can adopt common Newton-Raphson method to find the solution (4) formula, obtain regional power grid S ₁Interior trend.

Coordinate the current imbalance amount Δ I that calculation server need come the computation bound node according to boundary condition, interconnection parameter and regional power grid calculation of tidal current in the aforesaid step 4.3, vectorial Δ P with regional power grid active power loss amount of unbalance composition, i.e. [Δ I, Δ P] ^TConcrete calculation process may further comprise the steps as shown in Figure 6:

A: coordinate calculation server conditions setting I _BAnd Θ, be sent to regional trend calculation server;

B: regional trend calculation server calculates the one's respective area electric network swim according to (4) formula, extracts V from the trend result _BAnd P _LossInformation, wherein V _BBe the vector that the boundary node voltage phasor is formed, P _LossBe by

The vector of forming, and these information are sent to the coordination calculation server;

C: coordinate the voltage V of calculation server according to boundary node _B, according to the injection current theoretical value of (5) formula computation bound node from interconnection

With the exit boundary node is positive direction,

${\stackrel{\&RightArrow;}{i}}_{{\tilde{B}}_i}=(u_{{\tilde{B}}_i}\&angle;{\mathrm{\&theta;}}_{{\tilde{B}}_i}-u_{{\tilde{B}}_j}\&angle;{\mathrm{\&theta;}}_{{\tilde{B}}_j})(g_l+j{b}_l)---\left(5\right)$

The boundary condition electric current I of setting among a _BWith the injection current theoretical value

Sum is boundary node current imbalance amount Δ I, promptly

$\mathrm{\&Delta;I}=I_B+{\tilde{I}}_B---\left(6\right)$

D: coordinate calculation server according to the active power loss information P that counts among the ratio vector П of regional power grid burden the whole network active power loss of setting and each regional power grid trend result _Loss, according to the vector of (2) formula zoning electric network active network loss amount of unbalance composition

Aforesaid coordination calculation server adopts the correction of improved Jacobian-free Newton-GMRES (m) method calculation of boundary conditions, and iteration is until ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ, concrete steps are as follows:

(a): make k=-1, make x _B=[Re (I _B), Im (I _B), Θ] ^TBe the vector of boundary condition composition, wherein Re (I _B) and Im (I _B) represent that respectively boundary node is from the injection current phasor real part of interconnection l and the vector of imaginary part composition; Given initial boundary condition

Select any nonsingular matrix M ₀Be preconditioning matrix;

(b): k=k+1, repeating step (b)～(i) is until ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ satisfies or k＞max NIter, and max NIter finishes for the restriction of Newton iterations;

(c): order

For boundary condition is The time boundary node current imbalance amount Δ I that calculates by the step a in the claim 6～d and the regional active power loss amount of unbalance vectorial Δ P that forms, need be separately in order to calculate with the real part of Δ I and imaginary part;

(d)：?

l＝1，ρ＝β＝‖r ₀‖ ₂，v ₁＝r ₀，errtol _G＝ε‖r ₀‖ ₂＞0，1＞ε＞0；

(e): if ρ＞errtol _GAnd l＜max GIter, max GIter are GMRES iterations restrictions, l=l+1 then, z _l=M _kv _l,

v _L+1=Δ G ^l/ w, w are a little positive constant, generally get 10 ^-5＞w＞0;

(f): revise preconditioning matrix $M_k=M_k+\frac{{(\mathrm{\&Delta;}{x}_B^l-M_k\mathrm{\&Delta;}{G}^l)\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k}{{\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k\mathrm{\&Delta;}{G}^l};$

(g): orthogonalization V _L+1=[v ₁, v ₂..., v _L+1] obtain the Hessenberg battle array

Find the solution

Wherein β is the constant that defines in the steps d, obtains ρ and y _l, if ρ＜errtol _G, then obtain Otherwise return step e;

(h)： $x_B^{k+1}=x_B^{k+1}+\mathrm{\&Delta;}{x}_B^k,$ $\mathrm{\&Delta;}{G}^k=G\left(x_B^{k+1}\right)-G\left(x_B^k\right);$

(i): revise preconditioning matrix

Return step b.

Aforesaid step (f) and (i) be internal layer and outer preconditioning matrix correction.

The present invention compared with prior art has following remarkable advantages and beneficial effect:

The present invention finishes the method for distributed tidal current analysis by exchange boundary node state and net damage information, distributed monitoring technology and the interconnected present situation of electrical network at China's electric power system, proposed to finish the method for distributed tidal current analysis by exchange boundary node state and net damage information, this method is a coordination variable with the interconnection electric current, only need to transmit a small amount of boundary information in the computational process, the problem of can flexible processing the whole network imbalance power distributing, each regional power grid can use independently phase angle reference node in the computational process, it is general to have model, data-interface is simplified, the constringency performance height, advantages such as the required number of communications of coordination solution procedure is less are adapted at using in the heterogeneous computing environment in the Wide Area Network.

Description of drawings

Fig. 1 is a prior art multi-stage scheduling center connection diagram;

Fig. 2 is distributed integrated tidal current analysis basic procedure schematic diagram;

Fig. 3 is the distributed tidal current analysis system schematic of electric power system;

Fig. 4 is system's slit mode schematic diagram of band edge boundary region;

Fig. 5 is the integrated trend composition decomposition of a whole network solution procedure schematic diagram;

Fig. 6 calculates [Δ I, Δ P] for coordinating calculation server ^TThe process schematic diagram;

Fig. 7 is two interconnected coordination schematic diagrames in zone;

Fig. 8 is system's slit mode schematic diagram of band edge boundary region;

Fig. 9 is the cutting schematic diagram of IEEE39 system.

Embodiment

In specific embodiment, the present invention implements according to following three phases:

Stage 1:,, adopt the cutting method that has borderline region that actual electric network is carried out cutting according to the operation conditions of actual electric network from the electric power system topological connection relation.

With the IEEE39 node system is example (see also shown in Figure 9, be the cutting schematic diagram of IEEE39 system), and it is divided into three regional power grids zone and a borderline region, and concrete slit mode is seen Fig. 4.Branch road 9～8,3～4,14～15,16～17 is an interconnection, and node 3,4,8,9,14,15,16,17 is a boundary node, their common boundary zones; Three regional power grid zones comprise node, and to count situation as shown in table 1, and node that each is regional and branch road parameter are shown in table 2～7

Table 1 IEEE39 node system zone situation

The zone	1?	2?	3?
				The node number	15?	12?	12?

Table 2 regional power grid zone 1 node parameter

Node number

Voltage magnitude

Voltage phase angle

Meritorious exerting oneself

Idle exerting oneself

Burden with power

Load or burden without work

Shunt conductance

Admittance in parallel

Node type

1?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

2?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

3?

1?

0?

0?

0?

3.22?

0.024?

0?

0.1107?

PQ?

9?

1?

0?

0?

0?

0?

0?

0?

0.1902?

PQ?

17?

1?

0?

0?

0?

0?

0?

0?

0.0671?

PQ?

18?

1?

0?

0?

0?

1.58?

0.3?

0?

0?

PQ?

25?

1?

0?

0?

0?

2.24?

0.472?

0?

0?

PQ?

26?

1?

0?

0?

0?

1.39?

0.17?

0?

0?

PQ?

27?

1?

0?

0?

0?

2.81?

0.755?

0?

0?

PQ?

28?

1?

0?

0?

0?

2.06?

0.276?

0?

0?

PQ?

29?

1?

0?

0?

0?

2.835?

0.269?

0?

0?

PQ?

30?

1.047?

0?

2.5?

0?

0?

0?

0?

0?

PV?

37?

1.027?

0?

5.4?

0?

0?

0?

0?

0?

PV?

38?

1.026?

0?

8.3?

0?

0?

0?

0?

0?

PV?

39?

1.03?

0?

10?

0?

11.04?

2.5?

0?

0?

Vθ?

Table 3 regional power grid zone 1 branch road parameter

First node	Tail node	Resistance	Reactance	Charging capacitor	No-load voltage ratio
						2?	1?	0.0035?	0.0411?	0.6987?	1?
39?	1?	0.001?	0.025?	0.75?	1?
						3?	2?	0.0013?	0.0151?	0.2572?	1?
25?	2?	0.007?	0.0086?	0.146?	1?
						18?	3?	0.0011?	0.0133?	0.2138?	1?
39?	9?	0.001?	0.025?	1.2?	1?
						18?	17?	0.0007?	0.0082?	0.1319?	1?
27?	17?	0.0013?	0.0173?	0.3216?	1?
						26?	25?	0.0032?	0.0323?	0.513?	1?
27?	26?	0.0014?	0.0147?	0.2396?	1?
						28?	26?	0.0043?	0.0474?	0.7802?	1?
29?	26?	0.0057?	0.0625?	1.029?	1?
						29?	28?	0.0014?	0.0151?	0.249?	1?
2?	30?	0?	0.0181?	0?	1.025?

25?	37?	0.0006?	0.0232?	0?	1.025?
						29?	38?	0.0008?	0.0156?	0?	1.025?

Table 4 regional power grid zone 2 node parameters

Node number

Voltage magnitude

Voltage phase angle

Meritorious exerting oneself

Idle exerting oneself

Burden with power

Load or burden without work

Shunt conductance

Admittance in parallel

Node type

4?

1?

0?

0?

0?

5?

1.84?

0?

0.1107?

PQ?

5?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

6?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

7?

1?

0?

0?

0?

2.338?

0.84?

0?

0?

PQ?

8?

1?

0?

0?

0?

5.22?

1.76?

0?

0.1902?

PQ?

10?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

11?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

12?

1?

0?

0?

0?

0.085?

0.88?

0?

0?

PQ?

13?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

14?

1?

0?

0?

0?

0?

0?

0?

0.183?

PQ?

31?

0.982?

0?

5.72?

0?

0.092?

0.046?

0?

0?

Vθ?

32?

0.983?

0?

6.5?

0?

0?

0?

0?

0?

PV?

Table 5 regional power grid zone 2 branch road parameters

First node	Tail node	Resistance	Reactance	Charging capacitor	No-load voltage ratio
						5?	4?	0.0008?	0.0128?	0.1342?	1?
14?	4?	0.0008?	0.0129?	0.1382?	1?
						6?	5?	0.0002?	0.0026?	0.0434?	1?
8?	5?	0.0008?	0.0112?	0.1476?	1?
						7?	6?	0.0006?	0.0092?	0.113?	1?
11?	6?	0.0007?	0.0082?	0.1389?	1?
						8?	7?	0.0004?	0.0046?	0.078?	1?
11?	10?	0.0004?	0.0043?	0.0729?	1?
						13?	10?	0.0004?	0.0043?	0.0729?	1?
14?	13?	0.0009?	0.0101?	0.1723?	1?
						6?	31?	0?	0.025?	0?	1.07?
12?	11?	0.0016?	0.0435?	0?	1.006?
						12?	13?	0.0016?	0.0435?	0?	1.006?
10?	32?	0?	0.02?	0?	1.07?

Table 6 regional power grid zone 3 node parameters

Node number

Voltage magnitude

Voltage phase angle

Meritorious exerting oneself

Idle exerting oneself

Burden with power

Load or burden without work

Shunt conductance

Admittance in parallel

Node type

15?

1?

0?

0?

0?

3.2?

1.53?

0?

0.183?

PQ?

16?

1?

0?

0?

0?

3.29?

0.323?

0?

0.0671?

PQ?

19?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

20?

1?

0?

0?

0?

6.8?

1.03?

0?

0?

PQ?

21?

1?

0?

0?

0?

2.74?

1.15?

0?

0?

PQ?

22?

1?

0?

0?

0?

0?

0?

0?

0?

PQ?

23?

1?

0?

0?

0?

2.475?

0.846?

0?

0?

PQ?

24?

1?

0?

0?

0?

3.086?

-0.922?

0?

0?

PQ?

33?

0.997?

0?

6.32?

0?

0?

0?

0?

0?

PV?

34?

1.012?

0?

5.08?

0?

0?

0?

0?

0?

PV?

35?

1.049?

0?

6.5?

0?

0?

0?

0?

0?

V?θ

36?

1.063?

0?

5.6?

0?

0?

0?

0?

0?

PV?

Table 7 regional power grid zone 3 branch road parameters

First node	Tail node	Resistance	Reactance	Charging capacitor	No-load voltage ratio
						16?	15?	0.0009?	0.0094?	0.171?	1?
19?	16?	0.0016?	0.0195?	0.304?	1?
						21?	16?	0.0008?	0.0135?	0.2548?	1?
24?	16?	0.0003?	0.0059?	0.068?	1?
						19?	20?	0.0007?	0.0138?	0?	1.06?
22?	21?	0.0008?	0.014?	0.2565?	1?
						23?	22?	0.0006?	0.0096?	0.1846?	1?
24?	23?	0.0022?	0.035?	0.361?	1?
						19?	33?	0.0007?	0.0142?	0?	1.07?
20?	34?	0.0009?	0.018?	0?	1.009?
						22?	35?	0?	0.0143?	0?	1.025?
23?	36?	0.0005?	0.0272?	0?	1?

Based on above-mentioned interconnected electric power network slit mode, be responsible for the zoning electric network swim by regional trend calculation server, be responsible for upgrading and sending boundary condition by coordinating calculation server in the higher level control centre, and judge whether the integrated trend of the whole network restrains to each regional power grid.

Stage 2: the integrated trend composition decomposition of the whole network calculates initialization procedure.This process comprises in initialization of regional trend calculation server and the higher level control centre coordinates calculation server initialization two parts, below introduces respectively.

(2.1) regional power grid trend calculation server is finished initialization according to following steps;

(2.1.1) read in node and the branch road parameter that the one's respective area trend is calculated, for example parameter shown in the table 2 and 3;

(2.1.2) initialization boundary condition information comprises boundary node numbering and title, and the corresponding relation between boundary condition and the boundary node;

(2.1.3) initialization trend calculation control parameter comprises iterative method, maximum iteration time, node voltage bound, the convergence criterion of use;

(2.2) coordinate calculation server in the higher level control centre and finish initialization according to following steps;

(2.2.1) read in the borderline region network parameter, comprise boundary node title, interconnection impedance etc.;

(2.2.2) the initialization area electrical network is born the whole network active power loss scale parameter vector П;

(2.2.3) set employing Jacobian-free Newton-GMRES (m) and find the solution the Control Parameter of border coordination equation, comprise maximum Newton iterations max NIter, maximum GMRES iterations max GIter, Newton iteration convergence precision ξ (required precision of boundary node current balance type and zone burden the whole network active power loss balance), GMRES iteration convergence precision ε, finite difference step-length w etc.

Stage 3: adopt improvement Jacobian-free Newton-GMRES (m) method to find the solution the border coordination equation, realize integrated the finding the solution of the whole network trend.

Concrete solution procedure is as follows:

(3.1) make k=-1, make x _B=[Re (I _B), Im (I _B), Θ] ^TBe the vector of boundary condition composition, wherein Re (I _B) and Im (I _B) represent that respectively boundary node is from the injection current phasor real part of interconnection and the vector of imaginary part composition; Given initial boundary condition

Select any nonsingular matrix M ₀Be preconditioning matrix, for example unit matrix;

(3.2) k=k+1, repeating step (3.2)～(3.9),

Or k＞max NIter, finish;

(3.3) enter GMRES (m) iterative update equation:

Wherein

Expression border coordination equation exists

The single order inverse, i.e. the Jacobian matrix of border coordination equation,

For boundary condition is The time border coordination function value, need be separately in order to calculate with the real part of Δ I and imaginary part, order

(3.4)? l＝1，ρ＝β＝‖r ₀‖ ₂，v ₁＝r ₀，errtol _G＝ε‖r ₀‖ ₂＞0，1＞ε＞0；

(3.5) if ρ＞errtol _GAnd l＜max GIter, then l=l+1 calculates z _l=M _kv _l,

v _L+1=Δ G ^l/ w, w are a little positive constant, generally get 10 ^-5＞w＞0:

(3.6) revise preconditioning matrix $M_k=M_k+\frac{{(\mathrm{\&Delta;}{x}_B^l-M_k\mathrm{\&Delta;}{G}^l)\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k}{{\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k\mathrm{\&Delta;}{G}^l};$

(3.7) orthogonalization V _L+1=[v ₁, v ₂..., v _L+1] obtain the Hessenberg battle array Find the solution

Wherein β is the constant of definition in the step (d), obtains ρ and y _l, if ρ＜errtol _G, then obtain

Otherwise return step (3.5);

(3.8) $x_B^{k+1}=x_B^{k+1}+\mathrm{\&Delta;}{x}_B^k,$ $\mathrm{\&Delta;}{G}^k=G\left(x_B^{k+1}\right)-G\left(x_B^k\right);$

(3.9) revise preconditioning matrix

Return step (3.2);

Border coordination function G (x wherein _B) the evaluation process finish according to following steps:

(3.10) the coordination calculation server conditions setting in the higher level control centre, the i.e. vectorial I that forms from the injection current phasor of interconnection l on the regional power grid boundary node _BAnd the vector theta of each regional power grid slack bus phase angle set point composition, and, corresponding injection current and phase angle set point are sent to regional trend calculation server according to the region subordinate relation;

(3.11) regional trend calculation server starts one's respective area trend computational process, according to resulting boundary condition and internal node parametric solution regional power grid S ₁And S ₂Power flow equation (4) obtains the voltage V of deviation boundary node from the trend result of convergence _BWith regional network damage information P _Loss, and these information are sent to the coordination calculation server;

(3.12) coordinate calculation server according to the parameter of setting in regional calculation of tidal current information that obtains and the initialization procedure, according to the current imbalance amount Δ I of formula (5) and (6) computation bound node, and according to the amount of unbalance Δ P of formula (2) zoning electrical network burden the whole network active power loss;

According to step 3.1～3.12, be example with the IEEE39 system, it is as shown in table 8 to obtain distributed tidal current calculation test result:

Table 8 distributed tidal current is calculated test result

Can find out from table 8: adopt JFNG (m) algorithm to find the solution the border coordination equation, its external iteration number of times and traditional serial NR method are suitable, have higher convergence.The use of self adaptation preconditioning technique can significantly improve the convergence of internal layer iteration, thereby reduce the number of times that the equation of comptability is found the solution, this will improve the number of communications of algorithm in distributed computing environment (DCE) greatly, thereby make algorithm be applicable to the wide area network traffic environment of high time-delay.The integrated trend composition decomposition of the whole network that the present invention provides derivation algorithm computational accuracy is higher, can satisfy the practical needs that calculate.

It should be noted that at last: above embodiment only in order to the explanation the present invention and and unrestricted technical scheme described in the invention; Therefore, although this specification has been described in detail the present invention with reference to each above-mentioned embodiment,, those of ordinary skill in the art should be appreciated that still and can make amendment or be equal to replacement the present invention; And all do not break away from the technical scheme and the improvement thereof of the spirit and scope of invention, and it all should be encompassed in the middle of the claim scope of the present invention.

Claims (8)

1. finish the method for distributed tidal current analysis by exchange boundary node state and net damage information for one kind, it is characterized in that comprising:

Step 1; Make up distributed tidal current analysis system according to electric power system actual schedule way to manage;

Interconnected network is interconnected by the harmonious management in regional power grid control centre and higher level control centre, information;

Described distributed tidal current analysis system is connected and composed by network by regional trend calculation server in the regional power grid control centre and the coordination calculation server in the higher level control centre; Wherein: regional trend calculation server, be responsible for the trend of its electrical network of having jurisdiction over and calculate; And the coordination calculation server is responsible for coordinating each regional power grid trend computational process;

Step 2; From the power network topology annexation, according to the operation conditions of actual electric network, adopt the cutting method that has borderline region that actual electric network is carried out cutting, the calculating object and the Data Source of clear and definite regional trend calculation server and coordination calculation server;

Define two regional interconnected network S ₀Comprise two regional power grid S ₁And S ₂, l interconnects by interconnection; B wherein ₁, B ₂Represent regional power grid S respectively ₁, S ₂Boundary node,

Be respectively S ₁, S ₂In other nodes are formed except boundary node network;

With boundary node B ₁And B ₂Division respectively forms the virtual boundary node

With

And with the virtual boundary node at interconnection l and its two ends With

Regard a zone separately as, other All Ranges effects of connection are played in this zone, are defined as borderline region S _B

Described regional power grid S ₁And S ₂Belong to regional power grid control centre compass of competency, borderline region S _BBelong to higher level control centre compass of competency; Under this slit mode, the condition of convergence of the whole network trend is: regional power grid S ₁And S ₂Middle trend is calculated and is reached convergence, regional power grid S ₁And S ₂Internal node power all reach balance, and boundary node state satisfies

$\left\{\begin{array}{c}{u}_B=u_{\tilde{B}},{\mathrm{\&theta;}}_B={\mathrm{\&theta;}}_{\tilde{B}}\\ {\stackrel{\&RightArrow;}{i}}_B+{\stackrel{\&RightArrow;}{i}}_{\tilde{B}}=0\end{array}\right.---\left(1\right)$

U wherein _BAnd θ _BBe regional power grid S ₁And S ₂Interior trend is calculated boundary node B among the convergence result ₁And B ₂Voltage magnitude and phase angle vector;

With

Be borderline region S _BBoundary node B when interior trend is calculated convergence ₁And B ₂Voltage magnitude and phase angle vector;

Be regional power grid S ₁And S ₂Interior trend is calculated boundary node B among the convergence result ₁And B ₂Going up the vector of forming from the injection current phasor of interconnection l, is positive direction with the inflow; Be borderline region S _BMiddle trend is calculated when restraining from boundary node B ₁And B ₂To the vector that the last electric current phasor that injects of interconnection l is formed, be positive direction with the outflow;

Step 3; Zone trend calculation server and coordination calculation server calculate with data and parameter initialization, may further comprise the steps:

Step 3.1: the basic network parameter of the regional trend calculation server electrical network that initialization is had jurisdiction in the regional power grid control centre comprises that all participate in type, load and generator output set point, generator machine end node voltage magnitude and the slack bus phase angle of the network node of trend calculating;

Step 3.2: the regional trend calculation server initialization boundary condition information in the regional power grid control centre, comprise numbering, the title of boundary node, the composition of boundary condition, i.e. the vector sum regional power grid slack bus phase angle formed of the injection current phasor of boundary node;

Step 3.3: the regional trend calculation server initialization trend parameters calculated in the regional power grid control centre comprises employed iterative method, maximum iteration time, node voltage bound, the minimum power deviation in order to judge that trend restrains;

Step 3.4: the coordination calculation server initialization borderline region network parameter in the higher level control centre comprises title, the interconnection impedance of boundary node;

Step 3.5: the coordination calculation server in the higher level control centre is set the integrated trend of the whole network and is coordinated to find the solution Control Parameter, the proportionality coefficient that comprises maximum iteration time, each zone burden the whole network active power loss, and the required precision of boundary node power-balance, i.e. unbalanced current vector maximum amplitude on the required boundary node of Decision boundaries node power balance;

Step 4: the coordination calculation server calls regional trend calculation server and finishes the integrated trend composition decomposition of the whole network solution procedure jointly; Call flow between server comprises following basic step:

Step 4.1: the coordination calculation server in the higher level control centre is according to step 3.4,3.5 initialization borderline region network data and Control Parameter, and regional power grid control centre inner region trend calculation server is according to the basic network parameter and the trend parameters calculated of step 3.1～3.3 electrical networks that initialization is had jurisdiction over;

Step 4.2: coordinate calculation server and set the initial boundary condition, be i.e. the vectorial I that forms from the injection current phasor of interconnection l on the regional power grid boundary node _BAnd the vector theta of each regional power grid slack bus phase angle set point composition, and, corresponding injection current and phase angle set point are sent to regional trend calculation server according to network division relation in the step 2;

Step 4.3: regional trend calculation server starts one's respective area trend computational process, according to resulting boundary condition and internal node parametric solution zone power flow equation, obtains the voltage of boundary node from the trend result of convergence

With the regional network damage information

I=1,2, and these object informations are sent to the coordination calculation server;

Step 4.4: coordinate calculation server according to the parameter of setting in regional calculation of tidal current information that obtains and the initialization procedure, the vectorial Δ P that the current imbalance amount Δ I of computation bound node and the amount of unbalance of regional power grid active power loss are formed;

Step 4.5: if ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ then judges the convergence of the whole network trend, and computational process finishes, wherein ‖ ‖ ₂Two norms of expression vector, ξ is little positive constant; Otherwise according to [Δ I, Δ P] ^TCalculation of boundary conditions correction [Δ I _B, Δ Θ] ^TThe boundary condition set point is upgraded in the back, returns step 4.2;

Step 5: regional trend calculation server feeds back to the coordination calculation server with result of calculation, so that coordinate the integrated calculation of tidal current of the whole network that calculation server obtains convergence.

2. the method for finishing distributed tidal current analysis by exchange boundary node state and net damage information according to claim 1, it is characterized in that:, judge whether uniform convergence of the integrated trend of the whole network according to the vectorial Δ P that the amount of unbalance of the current imbalance amount Δ I of computation bound node and regional power grid active power loss is formed; Need satisfy following primary condition simultaneously:

A: boundary node power reaches balance, promptly satisfies (1) formula requirement in the claim 1;

B: the whole network active power loss is reasonable distribution between each regional power grid, satisfies following equation,

$\mathrm{\&Delta;}{P}_{\mathrm{loss}}^i=P_{\mathrm{loss}}^i-P_{\mathrm{loss}}^{\mathrm{all}}{\mathrm{\&eta;}}_i=0,i=\mathrm{1,2}---\left(2\right)$

П={ η wherein _iBe the ratio vector of regional power grid burden the whole network active power loss;

It is the active power loss that from the regional power grid calculation of tidal current, counts;

It is the whole network active power loss that obtains by each regional power grid active power loss addition;

It is regional power grid active power loss amount of unbalance.

3. according to claim 2ly finish the method for distributed tidal current analysis by exchange boundary node state and net damage information, it is characterized in that: the regional trend calculation server described in the step 4.3 is according to given boundary condition zoning trend; Wherein said regional power grid S ₁Be made up of n node and some branch roads, the trend computation model can be expressed as node power equilibrium equation group, promptly

$g({\stackrel{\&RightArrow;}{v}}_1,{\stackrel{\&RightArrow;}{v}}_2,...{\stackrel{\&RightArrow;}{v}}_n)=\left\{\begin{array}{c}{P}_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}})=0\\ Q_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}})=0\end{array}\right.---\left(3\right)$

Wherein

I=1,2 ..., n is a node voltage phasor, g is the node power equilibrium equation, With

Be the given meritorious and reactive power of node i, G _Ij+ jB _IjBe the admittance between node i and the node j, j ∈ i represents all nodes of linking with the i node to comprise i node self.

4. according to claim 3ly finish the method for distributed tidal current analysis, it is characterized in that: regional power grid S by exchange boundary node state and net damage information ₁All nodes are by internal node

With boundary node B ₁Two parts are formed, corresponding with Represent the vector of the voltage phasor composition of internal node, with

The vector of representing the border node voltage phasor to form; Accordingly, the node power equilibrium equation group that (3) formula is described can be divided into two classes, internal node The power balance equation group Power balance equation group with boundary node

Do not select boundary node as slack bus when calculating trend as regional power grid, in finishing given internal node generator node meritorious exert oneself, the node voltage amplitude, meritorious and the load or burden without work of load bus, and under the voltage magnitude of slack bus and the phase angle situation, internal node power balance equation group

Relevant with internal node with boundary node voltage, boundary node power balance equation group

With internal node voltages, boundary node voltage and boundary node B ₁Injection current phasor from interconnection l is relevant, and it is expressed as following form,

$g_1=\left\{\begin{array}{c}{g}_{\mathrm{In}}^1(V_B^1,V_{\mathrm{In}}^1)=\left\{\begin{array}{c}{P}_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}})=0,i\&Element;S_{\mathrm{In}}^1\\ Q_i^{\mathrm{SP}}-u_i\underset{j\&Element;i}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}})=0,i\&Element;S_{\mathrm{In}}^1\end{array}\right.\\ g_B^1(V_B^1,V_{\mathrm{In}}^1,I_B^1)=u_k\&angle;{\mathrm{\&theta;}}_k*\widehat{\stackrel{\&RightArrow;}{i_k}}-u_k\underset{j\&Element;k}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}}+B_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}})\\ -{\mathrm{ju}}_k\underset{j\&Element;k}{\mathrm{\&Sigma;}}{u}_j(G_{\mathrm{ij}}\sin {\mathrm{\&theta;}}_{\mathrm{ij}}-B_{\mathrm{ij}}\cos {\mathrm{\&theta;}}_{\mathrm{ij}})=0,k\&Element;S_B^1\end{array}\right.---\left(4\right)$

Wherein

Be by boundary node B ₁Go up the vector of forming from the injection current phasor of interconnection l,

Expression node k goes up the conjugation from the injection current phasor of interconnection l, and its dependent variable meaning is with (3) formula.

5. according to claim 4ly finish the method for distributed tidal current analysis, it is characterized in that: after the basic network parameter initialization process of the electrical network of having jurisdiction in the completing steps 3.1, given again by exchange boundary node state and net damage information

With regional power grid S ₁Interior slack bus voltage phase angle set point

Can adopt common Newton-Raphson method to find the solution (4) formula, obtain regional power grid S ₁Interior trend.

6. the method for finishing distributed tidal current analysis by exchange boundary node state and net damage information according to claim 4, it is characterized in that: coordinating calculation server in the step 4.3 need come the current imbalance amount Δ I of computation bound node and the vectorial Δ P that regional power grid active power loss amount of unbalance is formed according to boundary condition, interconnection parameter and regional power grid calculation of tidal current; May further comprise the steps:

A: coordinate calculation server conditions setting I _BAnd Θ, be sent to regional trend calculation server;

B: regional trend calculation server calculates the one's respective area electric network swim according to (4) formula, extracts V from the trend result _BAnd P _LossInformation, wherein V _BBe the vector that the boundary node voltage phasor is formed, P _LossBe by The vector of forming, and these information are sent to the coordination calculation server;

C: coordinate the voltage V of calculation server according to boundary node _B, according to the injection current theoretical value of (5) formula computation bound node from interconnection

With the exit boundary node is positive direction,

${\stackrel{\&RightArrow;}{i}}_{{\tilde{B}}_i}=(u_{{\tilde{B}}_i}\&angle;{\mathrm{\&theta;}}_{{\tilde{B}}_i}-u_{{\tilde{B}}_j}\&angle;{\mathrm{\&theta;}}_{{\tilde{B}}_j})(g_l+j{b}_l)---\left(5\right)$

The boundary condition electric current I of setting among a _BWith the injection current theoretical value

Sum is boundary node current imbalance amount Δ I, promptly

$\mathrm{\&Delta;I}=I_B+{\tilde{I}}_B---\left(6\right)$

D: coordinate calculation server according to the active power loss information that counts among the ratio vector П of regional power grid burden the whole network active power loss of setting and each regional power grid trend result

Vector according to (2) formula zoning electric network active network loss amount of unbalance composition

7. the method for finishing distributed tidal current analysis by exchange boundary node state and net damage information according to claim 6, it is characterized in that: described coordination calculation server adopts the correction of improved Jacobian-free Newton-GMRES (m) method calculation of boundary conditions, and iteration is until ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ, concrete steps are as follows:

(a): make k=-1, make x _B=[Re (I _B), Im (I _B), Θ] ^TBe the vector of boundary condition composition, wherein Re (I _B) and Im (I _B) represent that respectively boundary node is from the injection current phasor real part of interconnection l and the vector of imaginary part composition; Given initial boundary condition

Select any nonsingular matrix M ₀Be preconditioning matrix;

(b): k=k+1, repeating step (b)～(i) is until ‖ [Δ I, Δ P] ^T‖ ₂≤ ξ satisfies or k＞max NIter, and max NIter finishes for the restriction of Newton iterations;

(c): order

For boundary condition is

The time boundary node current imbalance amount Δ I that calculates by described step a～d and the regional active power loss amount of unbalance vectorial Δ P that forms, need be separately in order to calculate with the real part of Δ I and imaginary part;

(d)： l＝1，ρ＝β＝‖r ₀‖ ₂，v ₁＝r ₀，errtol _G＝ε‖r ₀‖ ₂＞0，1＞ε＞0；

(e): if ρ＞errtol _GAnd l＜max GIter, max GIter are GMRES iterations restrictions, l=l+1 then, z _l=M _kv _l,

V _L+1=Δ G ^l/ w, w are a little positive constant, generally get 10 ^-5＞w＞0;

(f): revise preconditioning matrix $M_k=M_k+\frac{(\mathrm{\&Delta;}{x}_B^l-M_k\mathrm{\&Delta;}{G}^l){\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k}{{\left(\mathrm{\&Delta;}{x}_B^l\right)}^T{M}_k\mathrm{\&Delta;}{G}^l};$

(g): orthogonalization V _L+1=[v ₁, v ₂..., v _L+1] obtain the Hessenberg battle array

Find the solution Wherein β is the constant of definition in the step (d), obtains ρ and y _l, if ρ＜errtol _G, then obtain

Otherwise return step (e);

(h)： $x_B^{k+1}=x_B^{k+1}+\mathrm{\&Delta;}{x}_B^k,$ $\mathrm{\&Delta;}{G}^k=G\left(x_B^{k+1}\right)-G\left(x_B^k\right);$

(i): revise preconditioning matrix

Return step (b).

8. according to claim 7ly finish the method for distributed tidal current analysis, it is characterized in that: step (f) and (i) be internal layer and outer preconditioning matrix correction wherein by exchange boundary node state and net damage information.

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