CN107563779B - Node marginal electricity price solving method - Google Patents
Node marginal electricity price solving method Download PDFInfo
- Publication number
- CN107563779B CN107563779B CN201610507583.6A CN201610507583A CN107563779B CN 107563779 B CN107563779 B CN 107563779B CN 201610507583 A CN201610507583 A CN 201610507583A CN 107563779 B CN107563779 B CN 107563779B
- Authority
- CN
- China
- Prior art keywords
- node
- load
- power
- marginal
- price
- 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
Links
- 230000005611 electricity Effects 0.000 title claims abstract description 116
- 238000000034 method Methods 0.000 title claims abstract description 54
- 108010074506 Transfer Factor Proteins 0.000 claims abstract description 29
- 238000005457 optimization Methods 0.000 claims abstract description 12
- 238000012937 correction Methods 0.000 claims abstract description 6
- 239000011159 matrix material Substances 0.000 claims description 47
- 239000013598 vector Substances 0.000 claims description 32
- 238000002347 injection Methods 0.000 claims description 12
- 239000007924 injection Substances 0.000 claims description 12
- 230000008859 change Effects 0.000 claims description 4
- 238000012546 transfer Methods 0.000 claims description 4
- 230000005540 biological transmission Effects 0.000 claims description 3
- 230000017105 transposition Effects 0.000 claims description 3
- 238000010276 construction Methods 0.000 abstract description 4
- 238000011161 development Methods 0.000 abstract description 3
- 238000010586 diagram Methods 0.000 description 6
- 238000009795 derivation Methods 0.000 description 3
- 238000011160 research Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 238000003672 processing method Methods 0.000 description 2
- 230000007704 transition Effects 0.000 description 2
- 230000000903 blocking effect Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 230000007547 defect Effects 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000008569 process Effects 0.000 description 1
Images
Landscapes
- Supply And Distribution Of Alternating Current (AREA)
- Pharmaceuticals Containing Other Organic And Inorganic Compounds (AREA)
Abstract
The invention relates to a node marginal electricity price solving method, which is based on direct current method B coefficient network loss correction and consideration of load side quotation and comprises the following steps: determining a direct current method B coefficient and a power transfer factor SF; establishing an economic dispatching model containing an optimization target, unit constraint and power flow constraint; deducing a node marginal electricity price model and determining the node marginal electricity price; determining the network loss micro-increment rates of the generator node and the load node; determining a marginal node and a full-load line; determining the unknown shadow price mu of the fully-loaded line and the system power price lambda; and determining the node marginal electricity price of the non-marginal node. The technical scheme provided by the invention has wide applicability, can be used for solving the node marginal electricity price of the generator node, the quoted sensitive pure load node and the non-quoted rigid pure load node, is suitable for market pricing in each stage of electric power market construction, and the detailed solving method provides reference for the development of node marginal electricity price solving software.
Description
Technical Field
The invention relates to a marginal electricity price solving method in the technical field of electric power market pricing/clearing, in particular to a node marginal electricity price solving method.
Background
The node marginal electricity price is the minimum electricity purchasing cost required by adding a unit active power to a certain node in the current system operation state and ensuring the safe operation of the power system. The price of electricity buying and selling is measured, the blocking cost and the network loss cost are measured, the by-products of economic dispatching are obtained, the minimum electricity purchasing cost of the whole system is guaranteed, and the scarce condition of system resources is measured. The network loss is difficult to simulate, and at present, the rough proportion of the network loss is commonly used. The solution of node electricity prices has two difficulties: firstly, the selection of the reference point influences the electricity price of the node; the second network loss model is difficult to simulate, the network loss factor of the network loss proportion sharing method is a fixed value, and the actual network loss factor is required to change along with the different power flow of the power grid.
At present, researches on node marginal electricity prices are concentrated on calculating the node marginal electricity prices by a direct current flow method without considering network loss, or calculating the node electricity prices by a proportion sharing method, and most researches only consider solving of the node marginal electricity prices of generator nodes but do not consider solving problems of the node marginal electricity prices of pure load nodes, and load side quotations are not considered when node marginal electricity price models are deduced, so that the method has certain limitation in application.
With the deep innovation of electric power marketization, the electric power supply is shifted from a traditional planning mode to a market mode, the electric power price in the market environment is determined by the market, and the node marginal electric price is an important market pricing method. In the transition period of the electric power market in China, only part of loads may participate in quotation, other loads still participate in the market as rigid loads, only demand is reported, price is not reported, considering that most nodes are pure rigid load nodes, the traditional processing method of substituting rigid loads into the model as fixed values can not solve the marginal electricity price of the nodes of the pure rigid load nodes, and the traditional processing method is not suitable for deducing the marginal electricity price model of the nodes under the market environment. Meanwhile, because the network loss is difficult to simulate, the current research commonly uses rough network loss proportion allocation, and a simplified node marginal electricity price model is obtained.
Disclosure of Invention
In order to solve the defects in the prior art, the invention aims to provide a node marginal electricity price solving method based on direct-current method B coefficient network loss correction and consideration of load side quotation.
The purpose of the invention is realized by adopting the following technical scheme:
the invention provides a node marginal electricity price solving method, which is improved in that the method is based on direct current method B coefficient network loss correction and consideration of load side quotation, and comprises the following steps:
the first step is as follows: determining a direct current method B coefficient and a power transfer factor SF;
the second step is that: establishing an economic dispatching model containing an optimization target, unit constraint and power flow constraint;
the third step: deducing a node marginal electricity price model, and determining node marginal electricity prices including node marginal electricity prices of a generator node and a load node;
the fourth step: determining the network loss micro-increment rates of the generator node and the load node;
the fifth step: determining a marginal node and a full-load line;
and a sixth step: determining unknown shadow price mu of a full-load line and an unknown electric energy price lambda of a system according to the node marginal electricity price, the network loss micro-increment rate and the power transfer factor of the marginal node;
the seventh step: and determining the node marginal electricity price of the non-marginal node according to the shadow price mu of the full-load line and the system electric energy price lambda.
Further, in the first step, a per unit value of the line parameter is obtained according to the reference parameter and the network topology, a reference point is selected, and a dc method coefficient B and a power transfer factor SF are respectively obtained according to the per unit value of the line parameter, the first step includes the following steps:
step 1: and (3) solving the per unit value of the line parameter:
wherein x is*Is a wirePer unit value of the line impedance, X is the line impedance, XBA reference parameter of the line impedance;
step 2: determining a direct current method B coefficient, comprising:
(1) the method comprises the following steps of (1) decomposing the grid loss of a power system into two parts related to voltage phase angles and voltage amplitude:
(2) assuming that the amplitude of each bus voltage is unchanged when the active power output of the power system is changed, only considering the network loss change related to the voltage angle; since the voltage amplitude is 1, and the set voltage amplitudes are all 1, then:
GNNij＝-gij
(3) linear relationship of the bus voltage angle of the DC power flow to the injected power is used:
Pin＝BNNθ
the grid loss of the power system is expressed as a function of the respective injected power:
PL＝θTGNNθ
＝(BNN -1Pin)TGNN(BNN -1Pin)
＝Pin T(BNN -1)TGNNBNN -1Pin
BNNij＝-bij
wherein, PLFor power system grid loss, PLθFor the part of the power system where the grid loss is related to the voltage phase angle, PLVN is the total number of nodes, i and j are two nodes of the branch respectively, Vi、VjTerminal voltage amplitudes, theta, at both ends of the branchi、θjTerminal voltage phase angles, g, at both ends of the branchijConducting for branch; theta is the voltage phase angle column vector, thetaTIs a transposed vector of the voltage phase angle column vector, GNNAs a node conductance matrix, GNNiiIs node self-conductance, GNNijIs the mutual conductance of the two nodes i and j; pinNet injection of power column vectors, B, for the nodesNNAs a node susceptance matrix, BNNiiRepresentation matrix BNNThe diagonal element of (A) is the sum of all branch node susceptances associated with the i node, BNNijRepresenting the off-diagonal element, is the negative of the mutual susceptance of the two nodes of the ij branch, bijRepresenting branch susceptance;
and step 3: determining a power transfer factor SF:
Fl＝BlABNN -1Pin
wherein, FlAs line flow column vectors, BlIs a branch susceptance matrix, and A is a network incidence matrix.
Further, in the second step, the generator and the load quotation data are obtained according to data declaration, the rigid load quotation which only reports the demand and does not report the price is set to be 0, the rigid load quotation is used as a variable in an economic dispatching model, the rigid load values are taken from the upper limit and the lower limit of the rigid load in the constraint condition, the economic dispatching model containing an optimization target, unit constraint and load flow constraint is established according to the generator and the quotation data comprising the rigid load quotation 0 load, and the economic dispatching model is solved; the economic dispatch model is represented by the following equation:
min pTPG-pD TPD
S.T.eT(PG-PD)-PL＝0
wherein p is the generator set quoted price, pTTransposing of a generator set quote p, pDFor load quotes, pD TFor transposition of the load quote, PGThe power is output by the generator set, GPis the lower limit of the output of the generator set,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor the grid loss of the power system, SF is the power transfer factor,
line tide quota, e ═ 1,1, …,1)T。
Further, the third step of deducing a node marginal electricity price model according to the economic dispatching model of the second step comprises the following steps:
step (1): constructing a Lagrangian function:
wherein, L is a Lagrange function, lambda is the system electric energy price, namely the Lagrange multiplier of the power balance constraint, e is the column vector with all elements of 1, mu is the shadow price of the full-load line, namely the Lagrange multiplier matrix corresponding to the power flow constraint of the full-load line, and p is the generator reportValence, pDFor load quotes, PGThe output of the generator is used as the output of the generator, GPis the lower limit of the output of the generator,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor system loss, SF is the power transfer matrix,
line tide limit of τ'G、τGLagrange multiplier matrix tau 'constrained by upper and lower generator output limits respectively'D、τDLagrange multiplier matrixes which are respectively constrained by the upper limit and the lower limit of the load power; pLIn order to reduce the grid loss of the power system,
step 2: the partial Cockchart EnKKT condition is unfolded as follows:
wherein, PGiIs the output of the generator set i, PDiIs the power of the load i, piFor unit i, pDiFor a quote of load i, μlLagrange multiplier, SF, constrained for the power flow limit of the l branchliPower transfer factor, τ ', for Branch l to node i net injected power'Gi、τGiLagrange multiplier matrix tau 'respectively constrained by upper limit and lower limit of unit i output'Di、τDiA Lagrange multiplier matrix for the constraint of the upper limit and the lower limit of the load i power,
to achieve a net loss increase rate for generator i,
the net loss micro-increment rate of the load i is obtained;
for the reference node, because
SFli0, so for the reference node:
and step 3: node marginal price of electricity:
where ρ isGiMarginal price of electricity, rho, for the node of the unit iDiThe node marginal electricity price of the node where the load i is located is as follows:
ρGi＝pi+τ′Gi-τGi＝λ
ρDi＝pDi-τ′Di+τDi＝λ
for a node with only a generator, the marginal price of the node is rhoGiFor the node with only load, the marginal price of electricity of the node is rhoDi；
For nodes with both generator and load, there is
I.e. node edgesThe inter-price of electricity is ρGi＝ρDi。
Further, the fourth step is that the network loss micro-increment rates of the generator nodes and the load nodes are calculated according to the economic dispatching optimization result of the third step;
assuming the node n as a reference point, calculating according to the following formula:
PL＝θTGNNθ
＝(BNN -1Pin)TGNN(BNN -1Pin)
＝Pin T(BNN -1)TGNNBNN -1Pin
＝Pin T·B·Pin
the net loss differential gain of the generator nodes and the load nodes is represented by the following formula:
wherein: pLFor the grid loss of the power system, theta is the voltage phase angle column vector, GNNAs a node conductance matrix, BNNAs a node susceptance matrix, PinFor node net injected power column vector, B is DC method B coefficient matrix, PGiFor the output of node i of the generator, PDiIs the power of the load node i, Pin,iNet injection of power column vector P for nodesinRepresents the net injected power of node i, i-1, 2,. n-1, n; b isi1Bi2…Bi,n-1Are elements of a coefficient matrix B.
Further, the fifth step determines the marginal node and the fully loaded line according to the economic dispatching result of the second step;
the marginal node refers to a power generator which is a marginal unit or a node with a limit value not taken by a winning load;
the marginal electricity price of the marginal node is the price quoted by the marginal unit of the node or the price quoted by the marginal load, and the marginal electricity price of the other nodes is the quantity to be requested; the shadow price corresponding to the full-load line constraint is not 0 and is a quantity to be solved, and the shadow prices corresponding to the other line constraints are all 0;
judging whether the output of the unit is between the upper limit and the lower limit of the output of the unit according to the output of the unit and the upper limit and the lower limit of the output of the unit obtained by optimizing
The node marginal electricity price of the node is quoted by the marginal unit:
and for the load nodes participating in quotation, determining tau 'when the load is positioned between the upper limit and the lower limit according to the optimized medium bid load and the upper limit and the lower limit of the load'D T＝τD T0, so the node marginal electricity price of the node takes the price of the load:
wherein: rhoGiMarginal price of electricity for node of unit iiFor unit i, PLFor the grid loss of the power system, λ is the system power price, i.e. lagrange multiplier of the power balance constraint, μlLagrange multiplier, P, constrained for the power flow limit of the l branchGiFor the output of the generator set i, SFliA power transfer factor for the net injected power to node i for branch l; tau'G T、τG TTranspose of lagrange multiplier matrices, τ ', constrained by upper and lower unit output limits, respectively'D T、τD TTransposing a Lagrange multiplier matrix constrained by the upper limit and the lower limit of the load power;
and when the power flow of the line reaches the transmission limit, the line is a full-load line, the shadow price corresponding to the full-load line constraint is not 0 and is a waiting quantity, and the shadow prices corresponding to the other line constraints are all 0.
Further, in the sixth step, determining an unknown shadow price μ and a system electric energy price λ according to the node marginal electricity price, the network loss micro-increment rate and the power transfer factor of the node where the marginal unit is located, including:
when m lines are fully loaded, m +1 marginal nodes exist, the unit output of the marginal nodes is positioned between an upper limit and a lower limit or the quoted load is positioned between the upper limit and the lower limit; assuming the numbers of the marginal nodes are 1,2, …, m, m +1, selecting the node n as a reference point, and if the number of the full-load line is 1,2, …, m, then:
wherein: λ is the system power price, i.e. lagrange multiplier of power balance constraint, μlA lagrange multiplier for the power flow limit constraint of the ith branch, wherein l is 1,2,. m; SFliA power transfer factor for the net injected power to node i for branch l; 1,2,. n-1, n; pinFor net injection of power column vectors, P, into the nodein,iNet injection of power column vector P for nodesinRepresents the net injected power of node i;
and (3) taking the price of the electricity of the node of the marginal node to obtain the price of the corresponding node to form m +1 equations, solving an equation set to obtain all unknowns, wherein the unknowns are m +1, and the unknowns are m shadow prices mu and 1 system electric energy price lambda respectively.
Further, in the seventh step, the node electricity price of the non-marginal node is solved according to the shadow price mu and the system electric energy price lambda;
solving the node electricity price of the non-marginal node according to the following formula:
wherein: p is a radical ofiFor unit i, PLFor the grid loss of the power system, lambda is the systemPrice of electric energy, i.e. lagrange multiplier, mu, of power balance constraintslLagrange multiplier, P, constrained for the power flow limit of the l branchGiFor the output of the generator set i, SFliA power transfer factor for the net injected power to node i for branch i, ═ 1,2,. m; rhoGiMarginal price of electricity, rho, for the node of the unit iDiMarginal price of electricity for node of load iDiIs the power of load i; tau'Gi、τGiLagrange multiplier tau 'respectively constrained by upper limit and lower limit of unit i output'Di、τDiAnd the lagrange multiplier is constrained by the upper limit and the lower limit of the load i power.
Compared with the closest prior art, the technical scheme provided by the invention has the following excellent effects:
according to the method, the price quoted at the load side is considered, the rigid load which is not quoted is reasonably processed during modeling, the network loss is considered based on the direct current method B coefficient, and the node marginal electricity price model with wider applicability is deduced, so that the node marginal electricity price model can be suitable for each stage of electric power market construction, and the node marginal electricity prices of the generator node and the pure load node are effectively solved.
According to the invention, relatively fine modeling of the price quoted at the load side and the network loss is considered, node marginal electricity price model derivation is carried out, a detailed solving method of the node marginal electricity price is provided, a basis and a reference are provided for solving the market node marginal electricity price, and a theoretical basis is provided for design and development of market electricity price clearing software.
Drawings
FIG. 1 is a flow chart of a node marginal electricity price solving method provided by the invention;
FIG. 2 is a schematic diagram of the derivation of B coefficients by DC method according to the present invention;
FIG. 3 is a diagram of a network topology according to embodiment 1 of the present invention;
fig. 4 is a network topology structure diagram of embodiment 2 provided by the present invention.
Detailed Description
The following describes embodiments of the present invention in further detail with reference to the accompanying drawings.
The following description and the drawings sufficiently illustrate specific embodiments of the invention to enable those skilled in the art to practice them. Other embodiments may incorporate structural, logical, electrical, process, and other changes. The examples merely typify possible variations. Individual components and functions are optional unless explicitly required, and the sequence of operations may vary. Portions and features of some embodiments may be included in or substituted for those of others. The scope of embodiments of the invention encompasses the full ambit of the claims, as well as all available equivalents of the claims. Embodiments of the invention may be referred to herein, individually or collectively, by the term "invention" merely for convenience and without intending to voluntarily limit the scope of this application to any single invention or inventive concept if more than one is in fact disclosed.
The invention provides a node marginal electricity price solving method based on direct current method B coefficient network loss correction and considering load side quotation, a flow chart of which is shown in figure 1 and comprises the following steps;
the first step is as follows: and according to the standard parameters and the network topological structure, per-unit values of the line parameters are obtained, a reference point is selected, and the direct current method B coefficients and the power transfer factor SF are respectively obtained according to the per-unit values of the line parameters. The dc method B coefficient is a B coefficient for correcting the network loss, and is an algorithm proposed in the 70 s. The power system loss modeling belongs to a known term.
Step 1: and calculating the coefficient B by a direct current method. Fig. 2 shows a schematic diagram of dc method B coefficient derivation, which includes:
(1) the network loss is decomposed into two parts related to voltage angle and voltage amplitude:
wherein, PLFor system loss, PLθFor the part of the grid loss related to the voltage phase angle, PLVIs the loss of the network and the voltageThe amplitude is related, n is the total number of nodes, i and j are two end points of the branch respectively, Vi、VjTerminal voltage amplitudes, theta, at both ends of the branchi、θjTerminal voltage phase angles, g, at both ends of the branchijThe branch conductance is taken.
(2) Assuming that the amplitude of each bus voltage is unchanged when the active power output of the power plant changes, only the change of the grid loss related to the phase angle is considered, and the latter is dominant. Since the voltage amplitude is about 1, assuming that the voltage amplitudes are all 1, the voltage amplitude is
GNNij＝-gij
Wherein, PLFor system loss, PLθN is the total number of nodes, i and j are two end points of the branch respectively, and thetai、θjTerminal voltage phase angles, g, at both ends of the branchijFor branch conductance, θ is the voltage phase angle column vector, GNNAs a node conductance matrix, GNNiiIs node self-conductance, GNNijIs the mutual conductance of two nodes.
(3) Linear relationship of the bus voltage angle of the DC power flow to the injected power is used:
Pin＝BNNθ
the net loss is expressed as a function of the respective injected power:
PL＝θTGNNθ
＝(BNN -1Pin)TGNN(BNN -1Pin)
＝Pin T(BNN -1)TGNNBNN -1Pin
BNNij＝-bij
wherein, PLFor power system grid loss, PLθFor the part of the power system where the grid loss is related to the voltage phase angle, PLVN is the total number of nodes, i and j are two nodes of the branch respectively, Vi、VjTerminal voltage amplitudes, theta, at both ends of the branchi、θjTerminal voltage phase angles, g, at both ends of the branchijConducting for branch; theta is the voltage phase angle column vector, thetaTIs a transposed vector of the voltage phase angle column vector, GNNAs a node conductance matrix, GNNiiIs node self-conductance, GNNijIs the mutual conductance of the two nodes i and j; pinNet injection of power column vectors, B, for the nodesNNAs a node susceptance matrix, BNNiiRepresentation matrix BNNThe diagonal element of (A) is the sum of all branch node susceptances associated with the i node, BNNijRepresenting the off-diagonal element, is the negative of the mutual susceptance of the two nodes of the ij branch, bijRepresenting branch susceptance;
step 2: and solving the power transfer factor SF.
Fl＝BlABNN -1Pin
Wherein, FlAs line flow column vectors, PinNet injection of power column vectors, B, for the nodesNNAs a node susceptance matrix, BlIs a branch susceptance matrix, and A is a network incidence matrix.
The second step is that: acquiring generator and load quotation data, performing special treatment on rigid loads which only report demands but do not report prices, setting quotation of the rigid loads to be 0, taking the rigid loads as variables in a model, taking rigid load values as upper and lower limits of the rigid loads in constraint conditions, establishing an optimization model containing an optimization target, unit constraint and flow constraint according to the quotation data (including the rigid load quotation 0) of all the generators and the loads, and solving the model.
min pTPG-pD TPD
S.T.eT(PG-PD)-PL＝0
Wherein p is the generator quoted price, pDFor load quotes, PGThe output of the generator is used as the output of the generator, GPis the lower limit of the output of the generator,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor system loss, SF is the power transfer matrix,
and limiting the line tide.
The third step: and deducing a node marginal electricity price model according to the economic dispatching model in the second step.
Considering the transition period of the electric power market in China, only part of loads may participate in quotation, and the other loads still participate in the market as rigid loads, only demand is reported, and price is not reported. In the existing economic dispatching model, loads are modeled as rigid loads, the loads are fixed values, if the node marginal electricity price model is deduced and the loads are processed according to the fixed values and no price is quoted, the objective function does not contain the load components, and for the node only containing the rigid loads, the node marginal electricity price of the node can not be calculated. Therefore, when the node marginal electricity price model is deduced, the rigid load needs to be set to be 0 in the objective function, the rigid load in the model is taken as a variable, the rigid load values are limited at the upper limit and the lower limit of the load in the constraint condition, so that the node marginal electricity price model can be suitable for each stage of electric power market construction in China, and the node marginal electricity prices of the generator node, the quoted load node and the pure rigid load node can be effectively solved.
Step 1: constructing a Lagrangian function:
wherein, L is Lagrange function, lambda is Lagrange multiplier (also called system electric energy price) of power balance constraint, e is column vector with elements all being 1, mu is Lagrange multiplier matrix (also called shadow price matrix) corresponding to line power flow constraint, p is generator quotationDFor load quotes, PGThe output of the generator is used as the output of the generator, GPis the lower limit of the output of the generator,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor system loss, SF is the power transfer matrix,
line tide limit of τ'G、τGLagrange multiplier matrix, τ ', constrained by generator output upper and lower limits, respectively'D、τDLagrange multiplier matrices constrained by the upper and lower limits of the load power are respectively used.
Step 2: the partial Cockcron (KKT) condition is unfolded as follows:
wherein, PGiIs the output of unit i, PDiIs the power of the load i, piFor unit i, pDiFor the quote of load i, λ is the lagrange multiplier of the power balance constraint (also called the system power price), μlLagrange multiplier, SF, constrained for the power flow limit of the l branchliPower transfer factor, τ ', for Branch l to node i net injected power'Gi、τGiAre lagrange multipliers of the constraint of the upper limit and the lower limit of output force of the unit i respectively'Di、τDiLagrange multipliers constrained by the upper and lower power limits of the load i,
to achieve a net loss increase rate for generator i,
the net loss increase rate for load i.
For the reference node, because
SFli0, so for the reference node
And step 3: node marginal price of electricity:
where ρ isGiMarginal price of electricity, rho, for the node of the unit iDiMarginal price of power for node of load iiFor unit i, pDiFor the quote of load i, λ is the lagrange multiplier of the power balance constraint (also called the system power price), μlLagrange multiplier, SF, constrained for the power flow limit of the l branchliPower transfer factor, τ ', for Branch l to node i net injected power'Gi、τGiAre lagrange multipliers of the constraint of the upper limit and the lower limit of output force of the unit i respectively'Di、τDiLagrange multipliers constrained by the upper and lower power limits of the load i,
to achieve a net loss increase rate for generator i,
the net loss increase rate for load i.
The node of the reference point has the electricity price of
ρGi＝pi+τ′Gi-τGi＝λ
ρDi＝pDi-τ′Di+τDi＝λ
For a node with only a generator, the node price is rhoGiFor nodes with only load, the node price is rhoDi。
For nodes with both generator and load, there is
So there is p at these nodesGi＝ρDi。
The fourth step: and calculating the network loss micro-increment rates of all the generator nodes and the load nodes according to the economic dispatching optimization result in the third step.
And (3) taking the node n as a reference point, and solving the network loss micro-increment rate according to the following formula:
PL＝θTGNNθ
＝(BNN -1Pin)TGNN(BNN -1Pin)
＝Pin T(BNN -1)TGNNBNN -1Pin
＝Pin T·B·Pin
the fifth step: and determining a marginal node (a generator is a marginal unit or a node (hereinafter referred to as marginal load) with a winning load not taking a limit value) and a full-load line according to the economic dispatching result of the second step. The marginal electricity price of the marginal node is the price quoted by the marginal unit of the node or the price quoted by the marginal load, and the marginal electricity price of the other nodes is the quantity to be requested; the shadow price corresponding to the full-load line constraint is not 0 and is the quantity to be solved, and the shadow prices corresponding to the other line constraints are all 0.
And according to the set output and the set upper and lower limits obtained by optimization, tau 'exists when the set output is judged to be positioned between the set output upper and lower limits'G T＝τG TAnd 0, the node marginal electricity price of the node takes the price quoted by the marginal unit:
and for the load nodes participating in quotation, determining tau 'when the load is positioned between the upper limit and the lower limit according to the optimized medium bid load and the upper limit and the lower limit of the load'D T＝τD T0, so the node marginal electricity price of the node takes the price of the load:
and when the power flow of the line reaches the transmission limit, the line is a full-load line. The shadow price corresponding to the full-load line constraint is not 0 and is the quantity to be solved, and the shadow prices corresponding to the other line constraints are all 0.
And a sixth step: and solving unknown shadow price mu and system electric energy price lambda according to the node marginal electricity price, the network loss micro-increment rate and the power transfer factor of the node where the marginal unit is located.
If m lines are fully loaded, m +1 marginal nodes exist (the unit output of the marginal nodes is positioned between an upper limit and a lower limit or the quoted load is positioned between the upper limit and the lower limit). Assuming the numbers of the marginal nodes are 1,2, …, m, m +1, the selected node n is the reference point, and if the number of the full-load line is 1,2, …, m, then
Wherein: λ is the system power price, i.e. lagrange multiplier of power balance constraint, μlA lagrange multiplier for the power flow limit constraint of the ith branch, wherein l is 1,2,. m; SFliA power transfer factor for the net injected power to node i for branch l; 1,2,. n-1, n; pinFor net injection of power column vectors, P, into the nodein,iNet injection of power column vector P for nodesinRepresents the net injected power of node i;
and (3) taking the price of the electricity of the node of the marginal node to obtain the price of the corresponding node to form m +1 equations, solving an equation set to obtain all unknowns, wherein the unknowns are m +1, and the unknowns are m shadow prices mu and 1 system electric energy price lambda respectively.
The seventh step: and solving the node electricity price of the non-marginal node according to the shadow price mu and the system electric energy price lambda.
Solving the node electricity price of the non-marginal node according to the following formula:
wherein: p is a radical ofiFor unit i, PLFor the grid loss of the power system, λ is the system power price, i.e. lagrange multiplier of the power balance constraint, μlLagrange multiplier, P, constrained for the power flow limit of the l branchGiFor the output of the generator set i, SFliA power transfer factor for the net injected power to node i for branch i, ═ 1,2,. m; rhoGiMarginal price of electricity, rho, for the node of the unit iDiMarginal price of electricity for node of load iDiIs the power of load i; tau'Gi、τGiLagrange multiplier tau 'respectively constrained by upper limit and lower limit of unit i output'Di、τDiAnd the lagrange multiplier is constrained by the upper limit and the lower limit of the load i power.
Example 1
The network topology structure diagram of embodiment 1 provided by the invention is shown in fig. 3, and comprises: 4 generators, 3 loads, and no pure load node. Generator quotation parameters are as in table 1, and load quotation parameters are as in table 2:
TABLE 1 Generator quotation parameters
| Generator | Capacity (MW) | Marginal cost ($/MWh) |
| A | 140 | 7.5 |
| B | 285 | 6 |
| C | 90 | 14 |
| D | 85 | 10 |
TABLE 2 load quotation parameters
Selecting a reference parameter SB＝100MVA，VB115 KV. The line parameters are as in table 3:
TABLE 3 line guidepost parameter
| Branch circuit | Admittance parameter (p.u.) | Capacity (MW) |
| 1-2 | 3.12-j2.94 | 80 |
| 1-3 | 2.68-j5.32 | 220 |
| 2-3 | 2.81-j4.49 | 130 |
(1) Select node 3 as the reference point, then
A node conductance matrix:
negative node susceptance matrix:
direct current method network loss B coefficient:
so the system loss is:
negative branch susceptance matrix:
network association matrix:
power transfer factor SF:
(2) economic dispatching model
min 7.5*PA+6*PB+14*PC+10*PD-14*L1-15*L2-0*L3
S.T.PA+PB+PC+PD-L1-L2-L3-PL＝0
0.2504(PA+PB-L1)-0.2966(PC-L2)≤0.8
0.7496(PA+PB-L1)+0.2966(PC-L2)≤2.2
0.2504(PA+PB-L1)+0.7034(PC-L2)≤1.3
0≤PA≤1.4
0≤PB≤2.85
0≤PC≤0.9
0≤PD≤0.85
0≤L1≤0.5
0≤L2≤1
3≤L3≤3
TABLE 4 economic dispatch results
| Generator | Power (p.u.) | Load(s) | Power (p.u.) |
| PA | 0.617 | L1 | 0.5 |
| PB | 2.85 | —— | —— |
| PC | 0.9 | L2 | 0.98 |
| PD | 0.85 | |
3 |
(3) Calculating the loss and gain of the network:
(4) and determining the marginal node and the fully loaded line according to the economic dispatching result.
If the line 1-3 is judged to be a full-load line according to the economic dispatching result, mu2≠0
The unit A outputs 61.7MW, then tau'G1 T＝τG1 TIs equal to 0, so
The load L2 is 98MW, then τ'D2 T＝τD2 T＝0
(5) Calculating the marginal electricity price of the node:
because the node electricity price of the marginal node is
Therefore, it is not only easy to use
Get it solved
Since the node 3 is the reference point, so
ρ3＝λ＝17$/MWH
Example 2
The network topology structure diagram of embodiment 2 provided by the invention is shown in fig. 4, and comprises: 3 generators, 3 loads, and node 2 is a pure load node. Generator quotation parameters are as in table 5, and load quotation parameters are as in table 6:
TABLE 5 Generator quotation parameters
| Generator | Capacity (MW) | Marginal cost ($/MWh) |
| A | 140 | 7.5 |
| B | 200 | 6 |
| C | 85 | 10 |
TABLE 6 load quotation parameters
| Load(s) | Minimum power (MW) | Maximum power (MW) | Marginal cost ($/MWh) |
| L1 | 0 | 0.5 | 14 |
| |
1 | 1 | —— |
| L3 | 0 | 2 | 15 |
The line parameters are as in table 3 of example 1.
(1) Economic dispatching model
min 7.5*PA+6*PB+10*PC-14*L1-0*L2-15*L3
S.T.PA+PB+PC-L1-L2-L3-PL＝0
0.2504(PA+PB-L1)-0.2966(0-L2)≤0.8
0.7496(PA+PB-L1)+0.2966(0-L2)≤2.2
0.2504(PA+PB-L1)+0.7034(0-L2)≤1.3
0≤PA≤1.4
0≤PB≤2
0≤PC≤0.85
0≤L1≤0.5
1≤L2≤1
0≤L3≤2
TABLE 7 economic dispatch results
| Generator | Power (p.u.) | Load(s) | Power (p.u.) |
| PA | 0.51 | L1 | 0.5 |
| |
2 | L2 | 1 |
| PC | 0.85 | L3 | 1.485 |
(2) Calculating the net loss micro-increment rate
(3) And determining the marginal node and the fully loaded line according to the economic dispatching result.
If the line 1-2 is judged to be a full-load line according to the economic dispatching result, mu is1≠0
The unit A outputs 51MW, tau'G1 T＝τG1 TIs equal to 0, so
Load L3 is 148.5MW, then τ'D2 T＝τD2 T＝0
(4) Calculating node marginal electricity price
Because the node electricity price of the marginal node is
Therefore, it is not only easy to use
Get it solved
Since the node 3 is the reference point, so
ρ2＝λ-λ*(-0.142)-μ1*(-0.2966)＝20.65$/MWH
The direct-current method B coefficient is adopted for network loss correction, node marginal electricity price fine modeling is carried out by considering the price quoted at the load side, the solution of the node electricity price of a pure rigid load node which only reports the demand and does not quote is considered, and the solution method of the node marginal electricity price is described in detail. The model has wide applicability, can be used for solving the node marginal electricity price of a generator node, a quoted pure load node and a non-quoted pure load node, is suitable for market pricing in each stage of electric power market construction, and the detailed solving method can provide reference for development of node marginal electricity price solving software in China.
Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art can make modifications and equivalents to the embodiments of the present invention without departing from the spirit and scope of the present invention, which is set forth in the claims of the present application.
Claims (8)
1. A node marginal electricity price solving method is characterized in that the method is based on direct current method B coefficient network loss correction and considering load side quotation, and comprises the following steps:
the first step is as follows: determining a direct current method B coefficient and a power transfer factor SF;
the second step is that: establishing an economic dispatching model containing an optimization target, unit constraint and power flow constraint;
the third step: deducing a node marginal electricity price model, and determining node marginal electricity prices including node marginal electricity prices of a generator node and a load node;
the fourth step: determining the network loss micro-increment rates of the generator node and the load node;
the fifth step: determining a marginal node and a full-load line;
and a sixth step: determining unknown shadow price mu of a full-load line and an unknown electric energy price lambda of a system according to the node marginal electricity price, the network loss micro-increment rate and the power transfer factor of the marginal node;
the seventh step: and determining the node marginal electricity price of the non-marginal node according to the shadow price mu of the full-load line and the system electric energy price lambda.
2. The method for solving the marginal electricity price of the node according to claim 1, wherein in the first step, a per unit value of the line parameter is obtained according to the reference parameter and the network topology, a reference point is selected, and a dc method B coefficient and a power transfer factor SF are respectively obtained according to the per unit value of the line parameter, the first step includes the following steps:
step 1: and (3) solving the per unit value of the line parameter:
wherein x is*Is the per unit value of the line impedance, X is the line impedance, XBA reference parameter of the line impedance;
step 2: determining a direct current method B coefficient, comprising:
(1) the method comprises the following steps of (1) decomposing the grid loss of a power system into two parts related to voltage phase angles and voltage amplitude:
(2) assuming that the amplitude of each bus voltage is unchanged when the active power output of the power system is changed, only considering the network loss change related to the voltage angle; since the voltage amplitude is 1, and the set voltage amplitudes are all 1, then:
GNNij＝-gij
(3) linear relationship of the bus voltage angle of the DC power flow to the injected power is used:
Pin＝BNNθ
the grid loss of the power system is expressed as a function of the respective injected power:
BNNij＝-bij
wherein, PLFor power system grid loss, PLθFor the part of the power system where the grid loss is related to the voltage phase angle, PLVN is the total number of nodes, i and j are two nodes of the branch respectively, Vi、VjTerminal voltage amplitudes, theta, at both ends of the branchi、θjTerminal voltage phase angles, g, at both ends of the branchijConducting for branch; theta is the voltage phase angle column vector, thetaTIs a transposed vector of the voltage phase angle column vector, GNNAs a node conductance matrix, GNNiiIs node self-conductance, GNNijIs the mutual conductance of the two nodes i and j; pinNet injection of power column vectors, B, for the nodesNNAs a node susceptance matrix, BNNiiRepresentation matrix BNNThe diagonal element of (A) is the sum of all branch node susceptances associated with the i node, BNNijRepresenting the off-diagonal element, is the negative of the mutual susceptance of the two nodes of the ij branch, bijRepresenting branch susceptance;
and step 3: determining a power transfer factor SF:
Fl＝BlABNN -1Pin
wherein, FlAs line flow column vectors, BlIs a branch susceptance matrix, and A is a network incidence matrix.
3. The method for solving the marginal electricity price of the node as claimed in claim 1, wherein in the second step, generator and load quotation data are obtained according to data declaration, rigid load quotation which only reports demand and does not report price is set to be 0, the rigid load quotation is used as a variable in the economic dispatch model, the upper and lower limits of the rigid load in the constraint condition take rigid load values, the economic dispatch model containing an optimization target, unit constraint and power flow constraint is established according to the generator and the quotation data comprising the rigid load quotation 0 load, and the economic dispatch model is solved; the economic dispatch model is represented by the following equation:
min pTPG-pD TPD
S.T.eT(PG-PD)-PL＝0
wherein p is the generator set quoted price, pTTransposing of a generator set quote p, pDFor load quotes, pD TFor transposition of the load quote, PGThe power is output by the generator set, GPis the lower limit of the output of the generator set,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor the grid loss of the power system, SF is the power transfer factor,
line tide quota, e ═ 1,1, …,1)T。
4. The method for solving the node marginal electricity price according to claim 1, wherein the third step derives a node marginal electricity price model according to the economic scheduling model of the second step, and the third step comprises the following steps:
step (1): constructing a Lagrangian function:
wherein, L is Lagrange function, lambda is system electric energy price, namely Lagrange multiplier of power balance constraint, e is column vector with elements of 1, mu is shadow price of full-load line, namely Lagrange multiplier matrix corresponding to full-load line power flow constraint, p is generator quotation, and p is power supplyDFor load quotes, PGThe output of the generator is used as the output of the generator, GPis the lower limit of the output of the generator,
upper limit of generator output, PDIn order to be the power of the load, DPin order to minimize the power of the load,
for maximum power of the load, PLFor system loss, SF is the power transfer matrix,
line tide limit of τ'G、τGLagrange multiplier matrix tau 'constrained by upper and lower generator output limits respectively'D、τDLagrange multiplier matrixes which are respectively constrained by the upper limit and the lower limit of the load power; pLIn order to reduce the grid loss of the power system,
step 2: the partial Cockchart EnKKT condition is unfolded as follows:
wherein, PGiIs the output of the generator set i, PDiIs the power of the load i, piFor unit i, pDiFor a quote of load i, μlLagrange multiplier, SF, constrained for the power flow limit of the l branchliThe power transfer factor for the net injected power for branch i to node i,τ′Gi、τGilagrange multiplier matrix tau 'respectively constrained by upper limit and lower limit of unit i output'Di、τDiA Lagrange multiplier matrix for the constraint of the upper limit and the lower limit of the load i power,
to achieve a net loss increase rate for generator i,
the net loss micro-increment rate of the load i is obtained;
for the reference node, because
So for the reference node:
and step 3: node marginal price of electricity:
where ρ isGiMarginal price of electricity, rho, for the node of the unit iDiThe node marginal electricity price of the node where the load i is located is as follows:
ρGi＝pi+τ′Gi-τGi＝λ
ρDi＝pDi-τ′Di+τDi＝λ
for only hairNode of motor with marginal price of rhoGiFor the node with only load, the marginal price of electricity of the node is rhoDi；
For nodes with both generator and load, there is
I.e. the node marginal electricity price is ρGi＝ρDi。
5. The node marginal electricity price solving method according to claim 1, wherein the fourth step calculates the grid loss micro-increment rates of the generator node and the load node according to the economic dispatching optimization result of the third step;
assuming the node n as a reference point, calculating according to the following formula:
PL＝θTGNNθ
＝(BNN -1Pin)TGNN(BNN -1Pin)
＝Pin T(BNN -1)TGNNBNN -1Pin
＝Pin T·B·Pin
the net loss differential gain of the generator nodes and the load nodes is represented by the following formula:
wherein: pLFor the grid loss of the power system, theta is the voltage phase angle column vector, GNNAs a node conductance matrix, BNNAs a node susceptance matrix, PinFor node net injected power column vector, B is DC method B coefficient matrix, PGiFor the output of node i of the generator, PDiIs the power of the load node i, Pin,iNet injection of power column vector P for nodesinRepresents the net injected power of node i, i-1, 2,. n-1, n; b isi1Bi2…Bi,n-1Are elements of a coefficient matrix B.
6. The node marginal electricity price solving method according to claim 1, wherein the fifth step determines a marginal node and a fully loaded line according to the economic dispatching result of the second step;
the marginal node refers to a power generator which is a marginal unit or a node with a limit value not taken by a winning load;
the marginal electricity price of the marginal node is the price quoted by the marginal unit of the node or the price quoted by the marginal load, and the marginal electricity price of the other nodes is the quantity to be requested; the shadow price corresponding to the full-load line constraint is not 0 and is a quantity to be solved, and the shadow prices corresponding to the other line constraints are all 0;
judging whether the output of the unit is between the upper limit and the lower limit of the output of the unit according to the output of the unit and the upper limit and the lower limit of the output of the unit obtained by optimizing
The node marginal electricity price of the node is quoted by the marginal unit:
for the load nodes participating in quotation, the existence exists when the load is judged to be positioned between the upper limit and the lower limit according to the winning bid load and the upper limit and the lower limit of the load obtained by optimization
Therefore, the node marginal electricity price of the node takes the price of the load:
wherein: rhoGiMarginal price of electricity for node of unit iiFor unit i, PLFor the grid loss of the power system, λ is the system power price, i.e. lagrange multiplier of the power balance constraint, μlFor the first branch tideLagrange multiplier, P, of stream quota constraintGiFor the output of the generator set i, SFliA power transfer factor for the net injected power to node i for branch l;
τG Tare respectively the transpositions of the Lagrange multiplier matrix of the unit output upper limit and lower limit constraints,
τD Ttransposing a Lagrange multiplier matrix constrained by the upper limit and the lower limit of the load power;
and when the power flow of the line reaches the transmission limit, the line is a full-load line, the shadow price corresponding to the full-load line constraint is not 0 and is a waiting quantity, and the shadow prices corresponding to the other line constraints are all 0.
7. The method for solving the node marginal electricity price of claim 1, wherein in the sixth step, according to the node marginal electricity price of the node where the marginal unit is located, the grid loss micro-increment rate and the power transfer factor, determining an unknown shadow price μ and a system electric energy price λ comprises:
when m lines are fully loaded, m +1 marginal nodes exist, the unit output of the marginal nodes is positioned between an upper limit and a lower limit or the quoted load is positioned between the upper limit and the lower limit; assuming the numbers of the marginal nodes are 1,2, …, m, m +1, selecting the node n as a reference point, and if the number of the full-load line is 1,2, …, m, then:
wherein: λ is the system power price, i.e. lagrange multiplier of power balance constraint, μlA lagrange multiplier for the power flow limit constraint of the ith branch, wherein l is 1,2,. m; SFliA power transfer factor for the net injected power to node i for branch l; 1,2,. n-1, n; pinFor net injection of power column vectors, P, into the nodein,iNet injection of power column vector P for nodesinRepresents the net injected power of node i;
and (3) taking the price of the electricity of the node of the marginal node to obtain the price of the corresponding node to form m +1 equations, solving an equation set to obtain all unknowns, wherein the unknowns are m +1, and the unknowns are m shadow prices mu and 1 system electric energy price lambda respectively.
8. The method for solving the marginal electricity price of the node according to claim 1, wherein in the seventh step, the node electricity price of the non-marginal node is solved according to the shadow price μ and the system power price λ;
solving the node electricity price of the non-marginal node according to the following formula:
wherein: p is a radical ofiFor unit i, PLFor the grid loss of the power system, λ is the system power price, i.e. lagrange multiplier of the power balance constraint, μlLagrange multiplier, P, constrained for the power flow limit of the l branchGiFor the output of the generator set i, SFliA power transfer factor for the net injected power to node i for branch i, ═ 1,2,. m; rhoGiMarginal price of electricity, rho, for the node of the unit iDiMarginal price of electricity for node of load iDiIs the power of load i; tau'Gi、τGiLagrange multiplier tau 'respectively constrained by upper limit and lower limit of unit i output'Di、τDiAnd the lagrange multiplier is constrained by the upper limit and the lower limit of the load i power.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610507583.6A CN107563779B (en) | 2016-06-30 | 2016-06-30 | Node marginal electricity price solving method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610507583.6A CN107563779B (en) | 2016-06-30 | 2016-06-30 | Node marginal electricity price solving method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN107563779A CN107563779A (en) | 2018-01-09 |
| CN107563779B true CN107563779B (en) | 2020-08-28 |
Family
ID=60968730
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610507583.6A Active CN107563779B (en) | 2016-06-30 | 2016-06-30 | Node marginal electricity price solving method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107563779B (en) |
Families Citing this family (17)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108667018A (en) * | 2018-06-08 | 2018-10-16 | 河海大学 | It is a kind of meter and electric vehicle and heat pump power distribution network node electricity price computational methods |
| CN109102155B (en) * | 2018-07-09 | 2022-03-15 | 中国南方电网有限责任公司 | Ultra-short-term node marginal electricity price probability prediction method and system |
| CN109064236A (en) * | 2018-09-04 | 2018-12-21 | 东南大学 | Transmission rights pricing method under cross-border electricity trading environment based on power sensitivity |
| CN109523309B (en) * | 2018-10-26 | 2021-04-30 | 武汉华中思能科技有限公司 | Power quotation simulation method and system based on load flow analysis and calculation |
| CN109447715B (en) * | 2018-11-09 | 2021-08-31 | 福州大学 | Node electricity price calculation method considering wind power grid-connected transmission margin value |
| CN109492809B (en) * | 2018-11-09 | 2021-08-31 | 福州大学 | Wind power plant value evaluation method based on node electricity price |
| CN110674969A (en) * | 2019-08-15 | 2020-01-10 | 广东电网有限责任公司电力调度控制中心 | Node marginal electricity price prediction method and device |
| CN110956493A (en) * | 2019-11-18 | 2020-04-03 | 远光软件股份有限公司 | Method and device for predicting node electricity price through virtual area node |
| CN110889778A (en) * | 2019-11-29 | 2020-03-17 | 国网河南省电力公司经济技术研究院 | Electric energy value evaluation method based on network security constraint |
| CN112991086B (en) * | 2019-12-18 | 2022-07-22 | 南京南瑞继保电气有限公司 | Power price visualization analysis method and system for power spot market node |
| CN111598725B (en) * | 2020-05-19 | 2024-04-19 | 广东电力交易中心有限责任公司 | Node marginal electricity price calculation method and device based on network loss |
| CN112084634B (en) * | 2020-08-20 | 2022-09-23 | 清华大学 | Load parameter change domain calculation method for guaranteeing unchanged electricity price of power market node |
| CN112200596B (en) * | 2020-09-01 | 2023-04-28 | 中国南方电网有限责任公司 | Method, system, device and medium for determining regional marginal electricity price of power system |
| CN112150202B (en) * | 2020-09-23 | 2022-02-15 | 广东电网有限责任公司电力调度控制中心 | Marginal unit analysis method and device |
| CN114493639B (en) * | 2020-10-23 | 2024-09-06 | 陕西电力交易中心有限公司 | Node electricity price pricing method considering elastic load contract |
| CN113300477B (en) * | 2021-05-31 | 2024-04-09 | 深圳供电局有限公司 | Optimization method for energy storage configuration of central urban power grid |
| CN114202359A (en) * | 2021-12-06 | 2022-03-18 | 国网江苏省电力有限公司扬州供电分公司 | N-1 accident-considered power system node pricing mechanism and method |
Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101719668A (en) * | 2009-12-03 | 2010-06-02 | 重庆大学 | Energy-saving power generation dispatching method considering security constraint and network loss modification |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US10037501B2 (en) * | 2013-12-18 | 2018-07-31 | International Business Machines Corporation | Energy management costs for a data center |
-
2016
- 2016-06-30 CN CN201610507583.6A patent/CN107563779B/en active Active
Patent Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101719668A (en) * | 2009-12-03 | 2010-06-02 | 重庆大学 | Energy-saving power generation dispatching method considering security constraint and network loss modification |
Also Published As
| Publication number | Publication date |
|---|---|
| CN107563779A (en) | 2018-01-09 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107563779B (en) | Node marginal electricity price solving method | |
| Jabr | Optimization of AC transmission system planning | |
| JP6025575B2 (en) | System and method for three-phase power flow analysis | |
| US10198018B2 (en) | Systems and methods for convex relaxations and linear approximations for optimal power flow in multiphase radial networks | |
| WO2015196743A1 (en) | Active distribution network reconfiguration method and apparatus | |
| CN111222917A (en) | Virtual power plant bidding strategy interacting with power distribution side multi-element retail market | |
| CN110880758B (en) | Decomposition coordination optimal power flow control method for power transmission network and power distribution network in electric power system | |
| CN109787240B (en) | Main and distribution network coordinated distributed power flow optimization method and related equipment | |
| CN109802392A (en) | Large-scale distribution network tidal current computing method and device | |
| CN115146872A (en) | Flexible aggregation method, device, equipment and medium for adjustable resources in power distribution network | |
| Li et al. | A loop-analysis theory based power flow method and its linear formulation for low-voltage DC grid | |
| CN101702521B (en) | State estimation method for electric power system considering influences of multi-balancing machine | |
| CN109560552B (en) | Pricing method and device for power distribution of power grid, computer equipment and storage medium | |
| Okajima et al. | Strategic behavior and market power of aggregators in energy demand networks | |
| CN111047346A (en) | Local area collaborative reactive compensation service value making method | |
| CN104917197B (en) | A kind of method of parallel computation active distribution network three-phase unbalanced load flow | |
| CN111654025B (en) | Transmission and distribution integrated coordination scheduling method considering interconnection between distribution networks | |
| CN108648024A (en) | A kind of power distribution network distributed generation resource deploying node computational methods | |
| CN117748449A (en) | Regional electric energy substitution distributed optimization method and system based on electric carbon transaction | |
| CN111834996B (en) | Power grid line loss calculation method and device | |
| CN111106631A (en) | Distributed reactive power scheduling method, system, equipment and storage medium for power distribution network | |
| CN107947153B (en) | Method for minimizing active loss in alternating current-direct current hybrid power transmission system | |
| CN109038588A (en) | A kind of distribution power system load flow calculation method | |
| CN104600700A (en) | Method for calculating incremental transmission loss based on Norton equivalence and generalized inverse of generator | |
| CN109921406A (en) | True bipolar flexible DC grid is layered tidal current computing method |
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 |