CN112054515A - Receiving-end power grid DC receiving capacity detection method based on multi-objective optimization - Google Patents

Receiving-end power grid DC receiving capacity detection method based on multi-objective optimization Download PDF

Info

Publication number
CN112054515A
CN112054515A CN202010882430.6A CN202010882430A CN112054515A CN 112054515 A CN112054515 A CN 112054515A CN 202010882430 A CN202010882430 A CN 202010882430A CN 112054515 A CN112054515 A CN 112054515A
Authority
CN
China
Prior art keywords
direct current
index
receiving
total
node
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
CN202010882430.6A
Other languages
Chinese (zh)
Other versions
CN112054515B (en
Inventor
彭晓涛
李华取
覃琴
张健
韩家辉
张立波
郭强
张弛
李楠
姚良忠
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
State Grid Corp of China SGCC
Wuhan University WHU
China Electric Power Research Institute Co Ltd CEPRI
State Grid Tianjin Electric Power Co Ltd
Original Assignee
State Grid Corp of China SGCC
Wuhan University WHU
China Electric Power Research Institute Co Ltd CEPRI
State Grid Tianjin Electric Power Co Ltd
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by State Grid Corp of China SGCC, Wuhan University WHU, China Electric Power Research Institute Co Ltd CEPRI, State Grid Tianjin Electric Power Co Ltd filed Critical State Grid Corp of China SGCC
Priority to CN202010882430.6A priority Critical patent/CN112054515B/en
Publication of CN112054515A publication Critical patent/CN112054515A/en
Application granted granted Critical
Publication of CN112054515B publication Critical patent/CN112054515B/en
Expired - Fee Related legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Images

Classifications

    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q10/00—Administration; Management
    • G06Q10/04—Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q10/00—Administration; Management
    • G06Q10/06—Resources, workflows, human or project management; Enterprise or organisation planning; Enterprise or organisation modelling
    • G06Q10/063—Operations research, analysis or management
    • G06Q10/0639—Performance analysis of employees; Performance analysis of enterprise or organisation operations
    • G06Q10/06393—Score-carding, benchmarking or key performance indicator [KPI] analysis
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Information and communication technology [ICT] specially adapted for implementation of business processes of specific business sectors, e.g. utilities or tourism
    • G06Q50/06—Energy or water supply
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/36—Arrangements for transfer of electric power between ac networks via a high-tension dc link
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J5/00—Circuit arrangements for transfer of electric power between ac networks and dc networks
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J2203/00—Indexing scheme relating to details of circuit arrangements for AC mains or AC distribution networks
    • H02J2203/20—Simulating, e g planning, reliability check, modelling or computer assisted design [CAD]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/60—Arrangements for transfer of electric power between AC networks or generators via a high voltage DC link [HVCD]

Landscapes

  • Business, Economics & Management (AREA)
  • Engineering & Computer Science (AREA)
  • Human Resources & Organizations (AREA)
  • Economics (AREA)
  • Strategic Management (AREA)
  • Tourism & Hospitality (AREA)
  • General Business, Economics & Management (AREA)
  • Power Engineering (AREA)
  • Theoretical Computer Science (AREA)
  • Marketing (AREA)
  • Entrepreneurship & Innovation (AREA)
  • General Physics & Mathematics (AREA)
  • Development Economics (AREA)
  • Physics & Mathematics (AREA)
  • Operations Research (AREA)
  • Quality & Reliability (AREA)
  • Educational Administration (AREA)
  • Game Theory and Decision Science (AREA)
  • Health & Medical Sciences (AREA)
  • Public Health (AREA)
  • Water Supply & Treatment (AREA)
  • General Health & Medical Sciences (AREA)
  • Primary Health Care (AREA)
  • Supply And Distribution Of Alternating Current (AREA)

Abstract

The invention relates to a receiving end power grid DC accepting capability detection method based on multi-objective optimization, which comprises the steps of firstly, primarily screening DC falling points and reducing the number of scenes; then adopting a Generalized Equivalent Short Circuit Ratio (GESCR) index, a Transient Voltage Support Intensity (TVSI) index and a grid loss index as optimization targets of a direct current drop point and unit output, and considering multi-constraint conditions to establish a multi-target optimization model of the direct current feed-in receiving end power grid; then, performing constant step length increment of direct current feed-in scale and repeating direct current point drop and unit optimization until the safe operation constraint condition is not met; and finally, performing N-1 safety and stability verification on the reverse sequence of the calculation and analysis result, and taking the verification result as the maximum direct current bearing scale of the receiving-end power grid. The calculation and analysis method provided by the invention has clear logic, comprehensive consideration factors and easy engineering realization, and can effectively obtain the maximum direct current receiving capacity of the receiving-end power grid.

Description

Receiving-end power grid DC receiving capacity detection method based on multi-objective optimization
Technical Field
The invention relates to a receiving-end power grid DC receiving capacity calculation method, in particular to a receiving-end power grid maximum DC receiving capacity analysis and detection method which considers the influence of DC drop points and unit output distribution on the DC carrying capacity of a receiving-end power grid and establishes a multi-objective optimization method and multi-constraint conditions.
Background
The high-voltage direct-current transmission has unique advantages in large-capacity and long-distance transmission and plays a key role in energy optimization configuration in China. For a receiving-end power grid, simultaneous feeding of multiple direct currents easily causes a series of safety and stability problems such as voltage collapse, frequency instability, commutation failure and the like, and particularly, with the continuous increase of the scale of the fed direct currents, the safety and stability problems of the receiving-end power grid are increasingly prominent, so that a scientific and effective analysis method for the maximum direct current carrying capacity of the receiving-end power grid is researched and established, the maximum direct current carrying scale of the receiving-end power grid is obtained, and the method has important reference significance for planning and scheduling of an alternating-current and direct-current hybrid power grid.
At present, an evaluation method for researching the direct current receiving capacity of a receiving-end power grid is mainly based on a multi-feed short circuit ratio (MSCR) index, by continuously increasing the direct current feed scale until the MSCR index is equal to a critical value, and performing some safety and stability checks, the carrying scale which can pass various safety constraints is the maximum direct current receiving capacity of the receiving-end power grid. Therefore, in the existing research, MSCR indexes are mainly used for quantitatively evaluating the receiving-end power grid direct current receiving capacity, and some safety and stability auxiliary verifications are performed, but because the critical value of the multi-feed short-circuit ratio depends on engineering experience, the voltage stability margin of the receiving-end power grid cannot be accurately quantized in practical application, the obtained receiving-end power grid direct current receiving capacity may have deviation, and meanwhile, a complete receiving-end power grid direct current receiving capacity detection method system based on multi-objective optimization is not formed in the existing research. Furthermore, existing studies do not consider and relate to the impact of optimal allocation of genset output on dc-carrying size when assessing dc-acceptance of the receiving grid.
The invention establishes an index system and a calculation method for evaluating the maximum direct current bearing scale of a receiving-end power grid from two levels of direct current drop point and unit output optimization through a loop iteration mode and by considering multi-constraint conditions. Firstly, the primary screening of direct current falling points is carried out, and the number of scenes is reduced. And then establishing a direct current drop point and a unit output as optimization targets by adopting a Generalized Equivalent Short Circuit Ratio (GESCR) index, a Transient Voltage Support Intensity (TVSI) index and a network loss index, and establishing a multi-target optimization model of the direct current feed-in receiving-end power grid by considering multi-constraint conditions. And repeatedly performing drop point and unit output optimization through the cyclic increasing of the direct current feed-in scale until the set safe operation constraint condition is not met, performing N-1 safe and stable verification on the reverse sequence of the calculation analysis result, and taking the verification result as the maximum direct current receiving capacity of the receiving-end power grid. And finally, the IEEE 39 node system is used as a receiving-end power grid fed with multiple direct currents, the maximum direct current receiving capacity of the receiving end is obtained through calculation and analysis, and the feasibility and the effectiveness of the established receiving-end power grid maximum direct current receiving capacity analysis method are verified.
Disclosure of Invention
The technical problem of the invention is mainly solved by the following technical scheme:
a receiving-end power grid DC receiving capacity detection method based on multi-objective optimization is characterized by comprising the following steps:
step 1, primarily screening all possible direct current drop points of a receiving-end power grid based on a determined receiving-end power grid structure and a direct current feed-in typical operation mode to obtain an alternative drop point set D;
step 2, defining the direct current feed-in number N of the initial receiving end power griddc＝N0And setting the maximum transmission power P of each direct current transmission linedmaxRunning;
step 3, determining an optimal drop point and an active and reactive power output scheme of the unit through the direct current drop point and the unit output optimization by using the established direct current drop point and unit output combination optimization model;
step 4, under the optimized optimal operation mode, judging whether various safe operation constraint conditions are met, if so, entering step 5, and if not, entering step 7;
step 5, NdcThe strip DC increasing the power delivered by a step size Δ P, i.e. Pd(Ndc)＝Pd(Ndc) + Δ P, with judgment of Pd(Ndc) And PdmaxSize, if Pd(Ndc)≤PdmaxGo to step 3, otherwise, go toEntering a step 6;
step 6, executing Ndc＝Ndc+1, and set the NthdcThe strip DC transmission power being at a minimum limit value, i.e. Pd(Ndc)＝PdminRunning, and entering step 3;
step 7, performing N-1 safety and stability verification on the obtained iterative optimization result in a reverse mode according to the size of the total direct current feed power until a direct current feed scheme without safety and stability problems such as voltage overrun, branch power flow overrun, power flow non-convergence and the like in the N-1 verification is obtained, taking the direct current feed scheme as the maximum direct current receiving scale of a receiving end, and entering step 8;
step 8, determining the final fed direct current number N according to the result in step 7dcAnd counting the maximum receiving DC scale P of the receiving-end power gridD_totalI.e. by
Figure BDA0002654484050000021
In the method, in order to reduce the number of direct current drop point scenes and improve the optimization accuracy, in step 1, a load concentration index and a node degree index are defined to perform preliminary screening on the drop points, as shown in formula one:
Figure BDA0002654484050000031
in the formula I, F (i) and M (i) are respectively the load concentration ratio of the node i and the node degree index value; j is an adjacent node set of the node i; l is a system load node set; pLj、PLkThe active loads of the node j and the node k are respectively; lbijIs a branch between the nodes i and j; count is a counting function.
In the method, when the direct current drop point and unit output combined optimization model is established in the step 3, a Generalized Equivalent Short Circuit Ratio (GESCR) index and a transient voltage support intensity index (I) are utilizedTVSI) And constructing an optimization target by the network loss index, wherein the optimization target comprises the following steps:
when the GESCR index quantitatively evaluates the voltage supporting capability of the receiving-end power grid, the GESCR index has a theoretical critical value of 1, and has better accuracy and practicability compared with a multi-feed short circuit ratio (MSCR) index, the GESCR index is selected as the index for evaluating the voltage supporting capability of the receiving-end power grid, and the GESCR index is divided into an equilibrium index and a safety margin index which are respectively as follows:
Figure BDA0002654484050000032
in the formula II, Ibal(i)、Imar(i) Respectively obtaining the balance and safety margin index values under the ith multiple direct current feed-in schemes; n is a radical ofdcThe total number of DC feeds; GESCR (j) represents the GESCR corresponding to the j direct current feed-in node; GESCRaveFeeding corresponding GESCR average values for each direct current under the ith scheme; GESCRminThe size of the GESCR corresponding to the critical stability of the node voltage is equal to 1, wherein the GESCR index is defined as: for LCC type direct current, when the fixed power of a sending end and the fixed extinction angle of a receiving end are adopted for control, the GESCR indexes corresponding to the jth feed-in direct current are as follows:
Figure BDA0002654484050000033
in the formula III, ULjA node voltage of load node j; zeqjAfter the influence of other direct current feed-in on the direct current is converted to a current conversion bus j through an impedance form, the equivalent impedance of a feed-in point is obtained; sdjApparent power for the dc feed node j; QVCF is a reactive voltage compensation coefficient, which represents the influence of the dc control characteristic on the GESCR, and the expression is:
Figure BDA0002654484050000034
in the formula IV, QdjAbsorbing reactive power for the jth direct current conversion bus; thetaeqjIs an equivalent impedance ZeqjThe impedance angle of (d);
secondly, in order to reflect the mutual influence degree among all the current conversion buses, a transient voltage support strength index is adopted(ITVSI) As one of the optimization objectives, the average transient voltage support strength index under the ith dc-feeding scheme is defined as:
Figure BDA0002654484050000041
in the formula V, NdcThe total number of DC feeds; wherein, ITVSIThe index is defined as:
Figure BDA0002654484050000042
in the formula VI, XekjOnly the transfer impedance between the nodes k and j in the equivalent power grid of the converter buses k and j is reserved; xekThe branch impedance between the node k in the equivalent network and the equivalent power supply is obtained;
thirdly, the operation economy of the power grid is ensured in the optimization process, and the grid loss index under the ith operation scheme is defined as follows:
Iloss(i)＝PG_total(i)+PD_total(i)-PL_total(i) formula seven
In the formula VII, PG_totalThe total active output of the conventional generator set of the system; pD_totalFeeding total power into receiving end direct current; pL_totalIs the total load of the system.
In the method, in the first step and the third step, in order to process the inconsistency of the index magnitude and direction, the index under the ith scheme is processed by a range transform method, the method is shown as the formula eight, and the indexes are subjected to subjective and objective combination weighting by adopting an analytic hierarchy process and an entropy weight resisting process;
Figure BDA0002654484050000043
in the formula VIII, I1、I2Respectively representing a negative index and a positive index;
Figure BDA0002654484050000044
respectively are indexes after standardized treatment; i ismax、IminThe value range after index normalization is expressed to avoid normalization to a closed interval [0, 1%]When the index value is 0, the index value can be taken as Imax＝0.996,Imin＝0.002。
In the method, in step 4, multiple constraint conditions such as system power flow constraint, generator active and reactive power constraint, node voltage constraint, short-circuit current constraint, branch maximum transmission power constraint, GESCR index not less than a critical value, effective direct-current inertia time constant constraint, maximum single feed-in constraint and the like are constructed, as shown in formula nine:
s.t.
Figure BDA0002654484050000051
in the formula Jiu, PiAnd QiActive and reactive power are injected into a node i;ijis the voltage phase difference between nodes i and j; gijAnd BijRespectively, the mutual conductance and the mutual admittance between the nodes i and j;
Figure BDA0002654484050000052
and
Figure BDA0002654484050000053
respectively representing the upper limit and the lower limit of active power output and reactive power output of the generator; n is the total number of system nodes; n is a radical ofGThe total number of the nodes of the generator of the system is; n is a radical oflThe total number of the system branches;
Figure BDA0002654484050000054
and
Figure BDA0002654484050000055
respectively representing the upper limit and the lower limit of the node voltage;
Figure BDA0002654484050000056
representing the upper limit of node short-circuit current control;
Figure BDA0002654484050000057
representing the upper limit of the transmission power of the branch; hdcTaking the effective direct current inertia time constant to be more than 2-3; gamma raydcmax,iThe ith direct current is locked due to the fault of a receiving end system, after the system recovers the steady state, in order to ensure that the steady state frequency of the system can be maintained within an allowable deviation range, the lower ith direct current transmission power accounts for the maximum ratio of the output power of all the generator sets of the system, wherein HdcAnd gammadcmax,iThe calculation expression of (a) is:
Figure BDA0002654484050000058
formula ten, JA_totalIs the total moment of inertia of the receiving end system; pD_totalFeeding DC total power to a receiving end; reqThe equivalent difference adjustment coefficient of the system generator set is obtained; dLAdjusting the coefficient for the system load active frequency; gamma is the ratio of the total power of the fed-in direct current to the sum of the active power output of all the generators in the system; Δ fmaxMaximum allowable steady state frequency deviation for the system; f. ofNThe system nominal frequency.
In the method, in the step 3, the direct current drop point and unit output combined optimization model is solved by using an MOEA/D optimization algorithm, so that the local search capability of the MEOA/D optimization algorithm is enhanced, the optimization effect is improved, and the population diversity is increased by adopting Gaussian variation after the evolution operation; for the ith element v in the evolved individualiThe mutation operation is as follows:
Figure BDA0002654484050000061
in the eleventh formula, rand is a function for generating random numbers; c is a random number matrix; n is a radical ofvRepresenting the number of independent variables; gussiant (t) denotes a Gaussian function with an argument t;i 2given variance of gaussian variation; piThe mutation rate is.
Therefore, compared with the prior art, the receiving-end power grid DC receiving capacity analysis method based on multi-objective optimization has the following advantages: based on GESCR indexes, a calculation and analysis method for the maximum direct current receiving capacity of a receiving-end power grid is established systematically, and the ambiguity and inaccuracy of the receiving-end voltage supporting capacity evaluated by MSCR indexes in the traditional method are overcome; the influence of different unit output optimization distribution on the direct current scale borne by the receiving end is considered, the optimal drop point and the unit output distribution change are considered along with the iterative increase of the direct current feed-in scale, the direct current drop point and the unit output are repeatedly optimized, the reasonability is achieved, and compared with the method that the optimal drop point is fixed firstly, the power receiving scale obtained by the iterative direct current scale increasing method is not biased to be conservative; in addition, multi-constraint conditions such as effective direct current inertia time constant constraint and maximum single feed-in constraint after direct current feed-in are considered, safety and stability check is carried out on the result according to a reverse order, and the receiving end maximum direct current receiving capacity obtained through calculation by the method is higher in reliability and accuracy.
Drawings
Fig. 1 is a flow chart of a receiving-end power grid maximum direct current receiving capacity calculation method based on multi-objective optimization.
Fig. 2 is a topology diagram of an IEEE 39 node system.
Detailed Description
The technical scheme of the invention is further specifically described by the following embodiments and the accompanying drawings.
1. A receiving-end power grid maximum direct current receiving capacity calculation method based on multi-objective optimization is disclosed.
The invention provides a method for analyzing the maximum direct current receiving capacity of a receiving-end power grid based on a multi-objective optimization method, the flow of the method is shown as figure 1, and the specific method comprises the following steps:
step 1, primarily screening all possible direct current drop points of a receiving-end power grid based on a determined receiving-end power grid structure and a direct current feed-in typical operation mode to obtain an alternative drop point set D;
step 2, setting the direct current feed-in number N of the initial receiving end power griddc＝N0And setting the maximum transmission power P of each DC linedmaxRunning;
step 3, determining an optimal drop point and an active and reactive power output scheme of the unit through the drop point and the unit output optimization by using the established direct current drop point and unit output combined optimization model;
step 4, under the obtained optimal operation mode, judging whether various safe operation constraint conditions are met, if so, entering step 5, and if not, entering step 7;
step 5, NdcThe strip DC increasing the power delivered by a step size Δ P, i.e. Pd(Ndc)＝Pd(Ndc) + Δ P, with judgment of Pd(Ndc) And PdmaxSize, if Pd(Ndc)≤PdmaxEntering step 3, otherwise, entering step 6;
step 6, executing Ndc＝Ndc+1, and set the NthdcThe strip DC transmission power being at a minimum limit value, i.e. Pd(Ndc)＝PdminRunning, and entering step 3;
step 7, performing N-1 safety and stability verification on the obtained iterative optimization result in a reverse mode according to the size of the total direct current feed power until a direct current feed scheme without safety and stability problems such as voltage overrun, branch power flow overrun, power flow non-convergence and the like in the N-1 verification is obtained, taking the direct current feed scheme as the maximum direct current receiving scale of a receiving end, and entering step 8;
step 8, determining the final fed direct current number N according to the result in step 7dcAnd counting the maximum receiving DC scale P of the receiving-end power gridD_totalI.e. by
Figure BDA0002654484050000071
2. And (5) primarily screening direct current falling points.
According to the method in 1, in order to reduce the number of scenes and improve the optimization accuracy, in step 1, a load concentration index and a node degree index are defined to perform preliminary screening on the drop points, as shown in formula 1:
Figure BDA0002654484050000072
wherein, F (i), M (i) are load concentration ratio of node i and node degree index value respectively; j is an adjacent node set of the node i; l is a system load node set; pLj、PLkThe active loads of the node j and the node k are respectively; lbijIs a branch between the nodes i and j; count is a counting function.
3. And constructing a direct current drop point and unit output optimization target.
According to the method in the step 1, in the direct current drop point and unit output combined optimization model in the step 3, a Generalized Equivalent Short Circuit Ratio (GESCR) index and a transient voltage support intensity index (I) are utilizedTVSI) And constructing an optimization target by the network loss index, wherein the optimization target comprises the following steps:
when the GESCR index quantitatively evaluates the voltage supporting capability of the receiving-end power grid, the GESCR index has a theoretical critical value of 1, and has better accuracy and practicability compared with a multi-feed short circuit ratio (MSCR) index, the GESCR index is selected as the index for evaluating the voltage supporting capability of the receiving-end power grid, and the GESCR index is divided into an equilibrium index and a safety margin index which are respectively as follows:
Figure BDA0002654484050000081
in the formula Ibal(i)、Imar(i) Respectively obtaining the balance and safety margin index values under the ith multiple direct current feed-in schemes; n is a radical ofdcThe total number of DC feeds; GESCR (j) represents the GESCR corresponding to the j direct current feed-in node; GESCRaveFeeding corresponding GESCR average values for each direct current under the ith scheme; GESCRminThe size of the GESCR corresponding to the critical stability of the node voltage is equal to 1, wherein the GESCR index is defined as: for LCC type direct current, when the fixed power of a sending end and the fixed extinction angle of a receiving end are adopted for control, the GESCR indexes corresponding to the jth feed-in direct current are as follows:
Figure BDA0002654484050000082
in the formula of ULjA node voltage of load node j; zeqjAfter the influence of other direct current feed-in on the direct current is converted to a current conversion bus j through an impedance form, the equivalent impedance of a feed-in point is obtained; sdjApparent power for the dc feed node j; QVCF is a reactive voltage compensation coefficient, which represents the influence of the dc control characteristic on the GESCR, and the expression is:
Figure BDA0002654484050000083
in the formula, QdiAbsorbing reactive power for the ith direct current conversion bus; thetaeqiIs an equivalent impedance ZeqjThe impedance angle of (c).
Secondly, in order to reflect the mutual influence degree among all the commutation buses, a transient voltage support intensity index (I) is adoptedTVSI) As one of the optimization objectives, the average transient voltage support strength index under the ith dc-feeding scheme is defined as:
Figure BDA0002654484050000084
in the formula, NdcThe total number of DC feeds; wherein, ITVSIThe index is defined as:
Figure BDA0002654484050000085
in the formula, XekjOnly the transfer impedance between the nodes k and j in the equivalent power grid of the converter buses k and j is reserved; xekIs the branch impedance between node k and the equivalent power source in the equivalent network.
And thirdly, ensuring the operation economy of the power grid after the combination of the direct current drop point and the unit output, and defining the grid loss index under the ith operation scheme as follows:
Iloss(i)＝PG_total(i)+PD_total(i)-PL_total(i) (7)
in the formula, PG_totalThe total active output of the conventional generator set of the system; pD_totalFeeding total power into receiving end direct current; pL_totalIs the total load of the system.
4. Index processing and index weight determination methods.
According to the method described in the step 1, in the step one and the step three, in order to process the inconsistency of the magnitude and the direction of the index, the index under the ith scheme is processed by a range transform method, the method is shown as the formula (8), and the index is subjectively and objectively weighted by an analytic hierarchy process and an entropy weight resisting method.
Figure BDA0002654484050000091
In the formula I1、I2Respectively representing a negative index and a positive index;
Figure BDA0002654484050000092
respectively are indexes after standardized treatment; i ismax、IminThe value range after index normalization is expressed to avoid normalization to a closed interval [0, 1%]When the index value is 0, the index value can be taken as Imax＝0.996,Imin＝0.002。
In summary, the total objective function of the primary screening of the direct current drop point, the total objective function of the direct current drop point and the unit output optimization are respectively as follows:
Figure BDA0002654484050000093
in the formula (f)D,i、fiPrimarily screening a total target value for the direct current drop point under the ith scheme and optimizing the total target value by combining the drop point and the unit output; lambda [ alpha ]1、λ2、α1、α2、α3And alpha4Are all weight factors, where1+λ2＝1，α1+α2+α3+α4＝1。
5. And constructing multiple constraints.
According to the method in 1, in step 4, multiple constraint conditions such as system power flow constraint, generator active and reactive power constraint, node voltage constraint, short-circuit current constraint, branch maximum transmission power constraint, GESCR index not less than a critical value, effective direct current inertia time constant constraint, maximum single feed-in constraint and the like are constructed, as shown in formula (10):
s.t.
Figure BDA0002654484050000101
in the formula, PiAnd QiActive and reactive power are injected into a node i;ijis the voltage phase difference between nodes i and j; gijAnd BijRespectively, the mutual conductance and the mutual admittance between the nodes i and j;
Figure BDA0002654484050000102
and
Figure BDA0002654484050000103
respectively representing the upper limit and the lower limit of active power output and reactive power output of the generator; n is the total number of system nodes; n is a radical ofGThe total number of the nodes of the generator of the system is; n is a radical oflThe total number of the system branches;
Figure BDA0002654484050000104
and
Figure BDA0002654484050000105
respectively representing the upper limit and the lower limit of the node voltage;
Figure BDA0002654484050000106
representing the upper limit of node short-circuit current control;
Figure BDA0002654484050000107
representing the upper limit of the transmission power of the branch; hdcThe effective direct current inertia time constant is generally more than 2-3; gamma raydcmax,iWhen the ith direct current is locked due to system fault, the steady-state frequency of the system in recovering the steady state can be maintained at the allowable valueWithin the allowable deviation range, the maximum ratio of the ith direct current transmission power to the output power of all the generator sets of the system, wherein HdcAnd gammadcmax,iThe calculation expression of (a) is:
Figure BDA0002654484050000108
in the formula, JA_totalIs the total moment of inertia of the receiving end system; reqThe equivalent difference adjustment coefficient of the system generator set is obtained; dLAdjusting the coefficient for the system load active frequency; gamma is the ratio of the total power of the fed-in direct current to the sum of the active power output of all the generators in the system; Δ fmaxMaximum allowable steady state frequency deviation for the system; f. ofNThe system nominal frequency.
6. And (6) solving an optimization model.
According to the method in the step 1, in the step 3, the direct current drop point and unit output combined optimization model is solved by using an MOEA/D optimization algorithm, so that the local search capability of the MEOA/D optimization algorithm is enhanced, the optimization effect is improved, and the population diversity is increased by adopting Gaussian variation after the evolution operation. For element v in evolved individualsiThe mutation operation is as follows:
Figure BDA0002654484050000111
wherein rand is a function for generating random numbers; c is a random number matrix; n is a radical ofvRepresenting the number of independent variables; gussiant (t) denotes a Gaussian function with an argument t;
Figure BDA0002654484050000112
given variance of gaussian variation; piThe mutation rate is.
7. Based on the IEEE 39 receiver net rack embodiment.
7.1, setting parameters.
And (3) adopting an IEEE 39 node system as a receiving-end power grid fed with multiple direct currents to carry out maximum direct current bearing scale analysis. The system topology structure is shown in fig. 2, the system comprises 29 load nodes and 10 generator nodes, wherein the node 31 is a generator balance node, the total load of the system is 6254.23MW, and the reference value is 100 MW.
The fed-in direct currents are all LCC type direct currents, and a sending end fixed power control mode and a receiving end fixed extinction angle control mode are adopted. Without loss of generality, the fed direct currents have the same parameters, and the inversion sides are all formed by 12-pulse inverters, wherein the main direct current parameters are shown in table 1.
TABLE 1 feeding in DC control parameters
Figure BDA0002654484050000113
In addition, in the process of evaluating and calculating the maximum direct current bearing scale of the receiving-end power grid, the system node voltage U is setiThe allowable range of (1) is 0.94 pu-1.06 pu, and the rated value is 1.0 pu; upper limit of node short circuit current control
Figure BDA0002654484050000114
Is 63 kA; maximum transmission power of branch
Figure BDA0002654484050000115
Is 1000 MW; the total rotational inertia of the system is 15000MW & S; setting the equivalent difference adjustment coefficient R of the systemeqIs 0.036, and has a load active frequency regulation coefficient DLIs 1.5, the rated frequency f of the systemNAt 50Hz, the maximum steady state frequency deviation Δ f allowed for the systemmaxIs 0.5 Hz; the generator output allowable range is shown in table 3 below.
7.2, maximum admission capacity calculation.
In order to avoid the mutual influence between the converter station and the power plant, when direct current is fed in, direct current falling into the generator nodes is not considered temporarily, so that 29 load nodes are possible direct current falling points, screening and sorting are carried out on all the falling points after the load concentration index and the degree standardization processing of the nodes, the first 15 nodes in the ranking are selected as alternative falling point sets, and sorting results and corresponding index values are shown in a table 2.
TABLE 2 alternative set of DC drop points
Figure BDA0002654484050000121
Setting the DC increasing step length as 0.5pu, and setting the initial DC feed-in number as N0＝1，Pdmax、Pdmin1000MW and 500MW respectively. The maximum iteration number of the MOEA/D algorithm is set to be 100, and the Gaussian variation rate is 0.1. For the loop iteration result, starting from the maximum feed-in direct current scale, performing N-1 safety and stability verification in reverse order and performing proper adjustment until a scheme which can pass the safety and stability verification is selected, wherein the final result is as follows: DC transmission power Pd1、Pd2And Pd31000MW, 1000MW and 650MW, respectively, and the optimal dc drop points are nodes 16, 2 and 9, and the generator active and reactive power output allowable ranges and the terminal voltage are shown in table 3.
TABLE 3 Unit output Range and optimization results
Figure BDA0002654484050000131
At the DC feed scale, the allowable frequency deviation Δ f of the systemmaxWhen the frequency is 0.5Hz, the maximum allowable transmission power of single direct current is 1095MW, which is larger than PdmaxAt 1000MW, the maximum dc carrying capacity of the receiving grid is therefore 3 loops, for a total of 2650 MW.
The specific embodiments described in this application are merely illustrative of the spirit of the invention. Various modifications or additions may be made to the described embodiments or alternatives may be employed by those skilled in the art without departing from the spirit or ambit of the invention as defined in the appended claims.

Claims (6)

1. A receiving-end power grid DC receiving capacity detection method based on multi-objective optimization is characterized by comprising the following steps:
step 1, primarily screening all possible direct current drop points of a receiving-end power grid based on a determined receiving-end power grid structure and a direct current feed-in typical operation mode to obtain an alternative drop point set D;
step 2, defining the direct current feed-in number N of the initial receiving end power griddc＝N0And setting the maximum transmission power P of each direct current transmission linedmaxRunning;
step 3, determining an optimal drop point and an active and reactive power output scheme of the unit through the direct current drop point and the unit output optimization by using the established direct current drop point and unit output combination optimization model;
step 4, under the optimized optimal operation mode, judging whether various safe operation constraint conditions are met, if so, entering step 5, and if not, entering step 7;
step 5, NdcThe strip DC increasing the power delivered by a step size Δ P, i.e. Pd(Ndc)＝Pd(Ndc) + Δ P, with judgment of Pd(Ndc) And PdmaxSize, if Pd(Ndc)≤PdmaxEntering step 3, otherwise, entering step 6;
step 6, executing Ndc＝Ndc+1, and set the NthdcThe strip DC transmission power being at a minimum limit value, i.e. Pd(Ndc)＝PdminRunning, and entering step 3;
step 7, performing N-1 safety and stability verification on the obtained iterative optimization result in a reverse mode according to the size of the total direct current feed power until a direct current feed scheme without safety and stability problems such as voltage overrun, branch power flow overrun, power flow non-convergence and the like in the N-1 verification is obtained, taking the direct current feed scheme as the maximum direct current receiving scale of a receiving end, and entering step 8;
step 8, determining the final fed direct current number N according to the result in step 7dcAnd counting the maximum receiving DC scale P of the receiving-end power gridD_totalI.e. by
Figure FDA0002654484040000011
2. The method of claim 1, wherein in step 1, a load concentration index and a node degree index are defined to perform a preliminary screening on the drop points for reducing the number of direct current drop point scenes and improving the optimization accuracy, as shown in formula one:
Figure FDA0002654484040000012
in the formula I, F (i) and M (i) are respectively the load concentration ratio of the node i and the node degree index value; j is an adjacent node set of the node i; l is a system load node set; pLj、PLkThe active loads of the node j and the node k are respectively; lbijIs a branch between the nodes i and j; count is a counting function.
3. The method of claim 1, wherein the direct current drop point and unit output combined optimization model is established in step 3 by using a Generalized Equivalent Short Circuit Ratio (GESCR) indicator and a transient voltage support intensity indicator (I)TVSI) And constructing an optimization target by the network loss index, wherein the optimization target comprises the following steps:
when the GESCR index quantitatively evaluates the voltage supporting capability of the receiving-end power grid, the GESCR index has a theoretical critical value of 1, and has better accuracy and practicability compared with a multi-feed short circuit ratio (MSCR) index, the GESCR index is selected as the index for evaluating the voltage supporting capability of the receiving-end power grid, and the GESCR index is divided into an equilibrium index and a safety margin index which are respectively as follows:
Figure FDA0002654484040000021
in the formula II, Ibal(i)、Imar(i) Respectively obtaining the balance and safety margin index values under the ith multiple direct current feed-in schemes; n is a radical ofdcThe total number of DC feeds; GESCR (j) represents the GESCR corresponding to the j direct current feed-in node; GESCRaveFeeding corresponding GESCR average values for each direct current under the ith scheme; GESCRminIs a nodeThe size of the GESCR corresponding to the voltage critical stability is equal to 1, wherein the GESCR index is defined as: for LCC type direct current, when the fixed power of a sending end and the fixed extinction angle of a receiving end are adopted for control, the GESCR indexes corresponding to the jth feed-in direct current are as follows:
Figure FDA0002654484040000022
in the formula III, ULjA node voltage of load node j; zeqjAfter the influence of other direct current feed-in on the direct current is converted to a current conversion bus j through an impedance form, the equivalent impedance of a feed-in point is obtained; sdjApparent power for the dc feed node j; QVCF is a reactive voltage compensation coefficient, which represents the influence of the dc control characteristic on the GESCR, and the expression is:
Figure FDA0002654484040000023
in the formula IV, QdjAbsorbing reactive power for the jth direct current conversion bus; thetaeqjIs an equivalent impedance ZeqjThe impedance angle of (d);
secondly, in order to reflect the mutual influence degree among all the current conversion buses, a transient voltage support strength index I is adoptedTVSIAs one of the optimization objectives, the average transient voltage support strength index under the ith dc-feeding scheme is defined as:
Figure FDA0002654484040000024
in the formula V, NdcThe total number of DC feeds; wherein, ITVSIThe index is defined as:
Figure FDA0002654484040000031
in the formula VI, XekjTo reserve only commutationTransfer impedance between nodes k and j in the equivalent power grid of the buses k and j; xekThe branch impedance between the node k in the equivalent network and the equivalent power supply is obtained;
thirdly, the operation economy of the power grid is ensured in the optimization process, and the grid loss index under the ith operation scheme is defined as follows:
Iloss(i)＝PG_total(i)+PD_total(i)-PL_total(i) formula seven
In the formula VII, PG_totalThe total active output of the conventional generator set of the system; pD_totalFeeding total power into receiving end direct current; pL_totalIs the total load of the system.
4. The method as claimed in claim 1, wherein in the first step and the third step, in order to process the inconsistency of the magnitude and direction of the index, the index under the ith scheme is processed by a range transform method, which is shown in the formula eight, and the index is subjected to subjective and objective combination weighting by an analytic hierarchy process and an entropy weight resisting method;
Figure FDA0002654484040000032
in the formula VIII, I1、I2Respectively representing a negative index and a positive index;
Figure FDA0002654484040000033
respectively are indexes after standardized treatment; i ismax、IminAnd expressing the value range after index normalization.
5. The method of claim 1, wherein multiple constraints such as system power flow constraint, generator active and reactive constraint, node voltage constraint, short circuit current constraint, branch maximum transmission power constraint, GESCR index not less than a critical value, effective DC inertia time constant constraint, maximum single feed constraint, etc. are constructed in step 4, as shown in formula nine:
Figure FDA0002654484040000041
in the formula Jiu, PiAnd QiActive and reactive power are injected into a node i;ijis the voltage phase difference between nodes i and j; gijAnd BijRespectively, the mutual conductance and the mutual admittance between the nodes i and j;
Figure FDA0002654484040000042
and
Figure FDA0002654484040000043
respectively representing the upper limit and the lower limit of active power output and reactive power output of the generator; n is the total number of system nodes; n is a radical ofGThe total number of the nodes of the generator of the system is; n is a radical oflThe total number of the system branches;
Figure FDA0002654484040000044
and
Figure FDA0002654484040000045
respectively representing the upper limit and the lower limit of the node voltage;
Figure FDA0002654484040000046
representing the upper limit of node short-circuit current control;
Figure FDA0002654484040000047
representing the upper limit of the transmission power of the branch; hdcTaking the effective direct current inertia time constant to be more than 2-3; gamma raydcmax,iThe ith direct current is locked due to the fault of a receiving end system, after the system recovers the steady state, in order to ensure that the steady state frequency of the system can be maintained within an allowable deviation range, the lower ith direct current transmission power accounts for the maximum ratio of the output power of all the generator sets of the system, wherein HdcAnd gammadcmax,iThe calculation expression of (a) is:
Figure FDA0002654484040000048
formula ten, JA_totalIs the total moment of inertia of the receiving end system; pD_totalFeeding DC total power to a receiving end; reqThe equivalent difference adjustment coefficient of the system generator set is obtained; dLAdjusting the coefficient for the system load active frequency; gamma is the ratio of the total power of the fed-in direct current to the sum of the active power output of all the generators in the system; Δ fmaxMaximum allowable steady state frequency deviation for the system; f. ofNThe system nominal frequency.
6. The method of claim 1, wherein in step 3, the direct current drop point and unit output combined optimization model is solved by using an MOEA/D optimization algorithm, in order to enhance the local search capability of the MEOA/D optimization algorithm and improve the optimization effect, and the population diversity is increased by using Gaussian variation after the evolution operation; for the ith element v in the evolved individualiThe mutation operation is as follows:
Figure FDA0002654484040000051
in the eleventh formula, rand is a function for generating random numbers; c is a random number matrix; n is a radical ofvRepresenting the number of independent variables; gussiant (t) denotes a Gaussian function with an argument t;
Figure FDA0002654484040000052
given variance of gaussian variation; piThe mutation rate is.
CN202010882430.6A 2020-08-28 2020-08-28 Receiving-end power grid DC receiving capacity evaluation method based on multi-objective optimization Expired - Fee Related CN112054515B (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
CN202010882430.6A CN112054515B (en) 2020-08-28 2020-08-28 Receiving-end power grid DC receiving capacity evaluation method based on multi-objective optimization

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
CN202010882430.6A CN112054515B (en) 2020-08-28 2020-08-28 Receiving-end power grid DC receiving capacity evaluation method based on multi-objective optimization

Publications (2)

Publication Number Publication Date
CN112054515A true CN112054515A (en) 2020-12-08
CN112054515B CN112054515B (en) 2022-12-06

Family

ID=73606473

Family Applications (1)

Application Number Title Priority Date Filing Date
CN202010882430.6A Expired - Fee Related CN112054515B (en) 2020-08-28 2020-08-28 Receiving-end power grid DC receiving capacity evaluation method based on multi-objective optimization

Country Status (1)

Country Link
CN (1) CN112054515B (en)

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN118468195A (en) * 2024-07-10 2024-08-09 太原泰森智能科技有限公司 Power grid engineering operation and maintenance method and system based on artificial intelligence

Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102723726A (en) * 2012-06-01 2012-10-10 中国电力科学研究院 Method for determining maximal direct current receiving quantity in alternating current receiving system
CN105048521A (en) * 2015-04-08 2015-11-11 国电南瑞科技股份有限公司 Method for calculating direct current access capability of receiving end power grid with consideration of multiple constraints
CN105281325A (en) * 2015-10-10 2016-01-27 国网天津市电力公司 Network structure optimization method improving external power receiving capacity of receiving-end power network
CN105356481A (en) * 2015-11-18 2016-02-24 中国电力科学研究院 Multi-infeed-short-circuit-ratio-based dynamic reactive compensation point selection method
CN106845752A (en) * 2016-11-08 2017-06-13 国家电网公司 A kind of extensive extra-high voltage interconnected network receives electric Scale Evaluation system
CN107134799A (en) * 2017-04-19 2017-09-05 国家电网公司 A kind of extra-high voltage grid transverter reactive configuration method based on short-circuit ratio
JP2017158265A (en) * 2016-02-29 2017-09-07 パナソニックＩｐマネジメント株式会社 Electric power supply system and electric power conversion system
CN107681682A (en) * 2017-10-25 2018-02-09 国家电网公司 A kind of ac and dc systemses equivalence method equivalent based on WARD
CN109873442A (en) * 2019-04-03 2019-06-11 广东电网有限责任公司电力调度控制中心 A kind of newly-increased direct current synchronizing point comprehensive estimation method of multi-infeed HVDC system
CN110048446A (en) * 2019-03-21 2019-07-23 中国电力科学研究院有限公司 A kind of method and system of the determining layering best drop point of direct current access system receiving end

Patent Citations (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102723726A (en) * 2012-06-01 2012-10-10 中国电力科学研究院 Method for determining maximal direct current receiving quantity in alternating current receiving system
CN105048521A (en) * 2015-04-08 2015-11-11 国电南瑞科技股份有限公司 Method for calculating direct current access capability of receiving end power grid with consideration of multiple constraints
CN105281325A (en) * 2015-10-10 2016-01-27 国网天津市电力公司 Network structure optimization method improving external power receiving capacity of receiving-end power network
CN105356481A (en) * 2015-11-18 2016-02-24 中国电力科学研究院 Multi-infeed-short-circuit-ratio-based dynamic reactive compensation point selection method
JP2017158265A (en) * 2016-02-29 2017-09-07 パナソニックＩｐマネジメント株式会社 Electric power supply system and electric power conversion system
CN106845752A (en) * 2016-11-08 2017-06-13 国家电网公司 A kind of extensive extra-high voltage interconnected network receives electric Scale Evaluation system
CN107134799A (en) * 2017-04-19 2017-09-05 国家电网公司 A kind of extra-high voltage grid transverter reactive configuration method based on short-circuit ratio
CN107681682A (en) * 2017-10-25 2018-02-09 国家电网公司 A kind of ac and dc systemses equivalence method equivalent based on WARD
CN110048446A (en) * 2019-03-21 2019-07-23 中国电力科学研究院有限公司 A kind of method and system of the determining layering best drop point of direct current access system receiving end
CN109873442A (en) * 2019-04-03 2019-06-11 广东电网有限责任公司电力调度控制中心 A kind of newly-increased direct current synchronizing point comprehensive estimation method of multi-infeed HVDC system

Non-Patent Citations (3)

* Cited by examiner, † Cited by third party
Title
BINJIE CHENG等: "Optimal DC-Segmentation for Multi-Infeed HVDC Systems Based on Stability Performance", 《IEEE TRANSACTIONS ON POWER SYSTEMS》 *
HAMMAM ABDELWAHAB等: "Maximizing Solar Energy Input for Cubesat Using Sun Tracking System and A Maximum Power Point Tracking", 《2017 INTERNATIONAL CONFERENCE ON COMMUNICATION, CONTROL, COMPUTING AND ELECTRONICS ENGINEERING》 *
汤奕等: "特高压直流分层接入方式下受端交流系统接纳能力分析", 《中国电机工程学报》 *

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN118468195A (en) * 2024-07-10 2024-08-09 太原泰森智能科技有限公司 Power grid engineering operation and maintenance method and system based on artificial intelligence

Also Published As

Publication number Publication date
CN112054515B (en) 2022-12-06

Similar Documents

Publication Publication Date Title
CN113595158B (en) Power supply capacity evaluation method for regional power distribution network under power distribution and sales competition situation
CN108418255B (en) Planning method and system suitable for extra-high voltage direct current outgoing power grid containing high-permeability new energy
CN107679658B (en) Power transmission network planning method under high-proportion clean energy access
CN110896231B (en) Distributed photovoltaic capacity receiving calculation method and system for power distribution network in poverty alleviation area
CN111446721B (en) Power distribution network voltage regulation control method based on transient voltage sensitivity
CN110970905B (en) Multi-power-supply reactive power coordination method and system for optimizing voltage control capability of wind power plant
CN111614110B (en) Receiving-end power grid energy storage optimization configuration method based on improved multi-target particle swarm optimization
CN113962159A (en) Method for evaluating maximum photovoltaic access capacity of power distribution network based on reasonable light abandonment
CN114996908B (en) Active power distribution network expansion planning method and system considering intelligent soft switch access
CN118174346A (en) Optimization method and system for adjusting direct current outward sending capacity based on supporting capacity of sending end system
CN112054515B (en) Receiving-end power grid DC receiving capacity evaluation method based on multi-objective optimization
CN107947183A (en) The power distribution network adaptive optimization method containing three end SNOP based on differential evolution
CN109390971B (en) Power distribution network multi-target active reconstruction method based on doorman pair genetic algorithm
CN115021308A (en) Distributed photovoltaic bearing capacity calculation method in power distribution network considering load off-line
CN104732302A (en) Multistage electromagnetic loop circuit optimized loop-opening method based on immunity algorithm
CN108512219B (en) Method for evaluating power receiving capacity of multi-channel receiving end system under voltage stability constraint
CN107732972A (en) A kind of area power grid wind-powered electricity generation receives capability assessment method
CN113363991B (en) Tidal current control method based on comprehensive sensitivity
Elende et al. Distribution network optimization by optimal sizing and placement of d-statcom using teaching and learning based optimization algorithm
CN112600260B (en) Unit difference adjustment coefficient optimization method and device based on transient voltage sensitivity sequencing
CN111697607A (en) Multi-terminal flexible direct-current transmission receiving-end power grid access method and system
CN115051392A (en) Reactive power coordination optimization control method containing new energy, stored energy and flexible load
CN107069703A (en) A kind of alternating current-direct current distribution planing method of meter and new energy access
CN113241793A (en) Prevention control method for power system with IPFC (intelligent power flow controller) considering wind power scene
Li et al. Wind farms reactive power optimization using genetic/tabu hybrid algorithm

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
CF01 Termination of patent right due to non-payment of annual fee
CF01 Termination of patent right due to non-payment of annual fee

Granted publication date: 20221206