CN114024331B - Planning operation measure optimization method for improving direct current bearing capacity - Google Patents

Planning operation measure optimization method for improving direct current bearing capacity Download PDF

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CN114024331B
CN114024331B CN202110988496.8A CN202110988496A CN114024331B CN 114024331 B CN114024331 B CN 114024331B CN 202110988496 A CN202110988496 A CN 202110988496A CN 114024331 B CN114024331 B CN 114024331B
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direct current
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CN114024331A (en
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魏明奎
蔡绍荣
周泓
江栗
路亮
陶宇轩
沈力
王庆
梁文举
文一宇
张鹏
杨宇霄
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Southwest Branch of State Grid Corp
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    • 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
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/12—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load
    • H02J3/14—Circuit arrangements for ac mains or ac distribution networks for adjusting voltage in ac networks by changing a characteristic of the network load by switching loads on to, or off from, network, e.g. progressively balanced loading
    • H02J3/144—Demand-response operation of the power transmission or distribution network
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/18—Arrangements for adjusting, eliminating or compensating reactive power in networks
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J3/00—Circuit arrangements for ac mains or ac distribution networks
    • H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
    • H02J3/46—Controlling of the sharing of output between the generators, converters, or transformers
    • H02J3/466—Scheduling the operation of the generators, e.g. connecting or disconnecting generators to meet a given demand
    • 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
    • Y02B—CLIMATE CHANGE MITIGATION TECHNOLOGIES RELATED TO BUILDINGS, e.g. HOUSING, HOUSE APPLIANCES OR RELATED END-USER APPLICATIONS
    • Y02B70/00—Technologies for an efficient end-user side electric power management and consumption
    • Y02B70/30—Systems integrating technologies related to power network operation and communication or information technologies for improving the carbon footprint of the management of residential or tertiary loads, i.e. smart grids as climate change mitigation technology in the buildings sector, including also the last stages of power distribution and the control, monitoring or operating management systems at local level
    • Y02B70/3225—Demand response systems, e.g. load shedding, peak shaving
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E40/00—Technologies for an efficient electrical power generation, transmission or distribution
    • Y02E40/30—Reactive power compensation
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y02E60/60—Arrangements for transfer of electric power between AC networks or generators via a high voltage DC link [HVCD]
    • 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
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S20/00—Management or operation of end-user stationary applications or the last stages of power distribution; Controlling, monitoring or operating thereof
    • Y04S20/20—End-user application control systems
    • Y04S20/222—Demand response systems, e.g. load shedding, peak shaving

Abstract

The invention discloses a planning operation measure optimization method for improving direct current bearing capacity, and belongs to the technical field of power grid planning. The invention comprises the following steps of 1: acquiring a power supply and a load plan of a power grid of a sending end, and evaluating the maximum direct current transmission capacity of a given grid frame according to the power supply and the load plan of the power grid of the sending end; step 2: if the maximum direct current transmission capacity is smaller than the rated transmission power, making corresponding operation optimization measures; and step 3: if the direct current carrying capacity is still smaller than the rated transmission power after various operation optimization measures are taken, various costs caused by the fact that direct current cannot be sent out at full power are unified and monetized, and risk costs of an operation layer are formed; and 4, step 4: planning measures are made, and investment priority ranking is carried out on different planning measures until the maximum direct current transmission capacity reaches the rated transmission power. The invention preferentially adopts operation measures and planning measures, screens out the optimal measure combination with the best effect and the lowest cost, avoids resource waste and reduces the cost.

Description

Planning operation measure optimization method for improving direct current bearing capacity
Technical Field
The invention belongs to the technical field of power grid planning, and particularly relates to a planning operation measure optimization method for improving direct current bearing capacity.
Background
At present, research on the dc bearing capacity is still in an exploration phase, and without a clear definition, the dc bearing capacity shall include two aspects of "dc" and "bearing capacity", where dc is an important power transmission method for power transmission, and the bearing capacity includes its own attribute, that is, the capacity of dc transmission cannot exceed a "threshold" that can be carried by a power system. For a transmitting-end power grid, from the perspective of planning, the direct-current carrying capacity is derived from energy planning and power planning, the direct-current planning serves a renewable energy development plan of a regional power grid, and when a large amount of surplus power exists in the regional power grid, direct current becomes a surplus power delivery means. In essence, the direct current bearing capacity depends on the degree of energy development and the upgrading and transformation plan of the matched alternating current net rack following power supply and direct current load planning, and the main power for driving the direct current bearing capacity to be gradually improved is the development and construction of renewable energy. Theoretically, if the new power supply and the main framework structure and other supporting projects are built in advance or synchronously, the direct current output is not limited, conversely, the power supply and the power grid can not be disconnected, the direct current planning can not be carried out, or the direct current transmission capacity can not be improved, and the source, the power grid and the direct current load are planned in a coordinated mode.
From the operation perspective, because the safety problem is checked according to N-1 mainly by considering the abundance and economy such as power and electric quantity balance, peak regulation standby and the like when planning the direct current construction, and the construction of the direct current engineering is far ahead of the construction of a main alternating current network, the direct current bearing capacity in the actual operation is generally smaller than the rated power of the direct current planning, and the method is particularly obvious in the transition period of direct current operation. Therefore, optimization can be carried out from the aspects of operation measures and planning measures so as to improve the direct current carrying capacity.
However, in the prior art, if the optimization is performed only from the aspect of operation measures, the optimization effect is limited, and if the optimization is performed only from the aspect of planning measures, the cost is high, and resource waste is easily caused.
Disclosure of Invention
Aiming at the problems in the prior art, the invention provides a planning operation measure optimization method for improving the direct current bearing capacity, which aims to: and on the premise of improving the direct current bearing capacity, screening out operation optimization measures and planning measures with the best optimization effect and the lowest cost.
The technical scheme adopted by the invention is as follows:
a planning operation measure optimization method for improving direct current bearing capacity comprises the following steps:
step 1: acquiring a power supply and a load plan of a power grid at a sending end, and evaluating the maximum direct current transmission capacity of a given grid frame according to the power supply and the load plan of the power grid at the sending end;
step 2: if the maximum direct current transmission capacity is smaller than the rated transmission power, making corresponding operation optimization measures;
and 3, step 3: if the direct current carrying capacity is still smaller than the rated transmission power after various operation optimization measures are taken, unified monetization is carried out on electricity abandonment loss caused by that direct current cannot be sent out at full power, emergency control cost and 599 punishment cost caused by load shedding, and risk cost of an operation layer is formed;
and 4, step 4: planning measures are made, and investment priority ranking is carried out on different planning measures until the maximum direct current transmission capacity reaches the rated transmission power.
Preferably, the planning measures in step 4 include: a dynamic reactive power compensation device STATCOM is arranged in the vicinity of the direct current converter station; strengthening the near-region alternating current net rack to improve the short circuit capacity of the near-region alternating current system; for new energy existing in the direct-current matching power supply, the electrical distance between the new energy and the converter station is increased, and the new energy offline risk is reduced; in order to avoid the high frequency of a transmitting end caused by the failure of the simultaneous transmission and receiving of the direct current commutation, the direct current inversion station adopts a VSC commutation station during planning construction.
Preferably, the operation optimization measures in step 2 include a first operation optimization measure, a second operation optimization measure and a third operation optimization measure.
Preferably, the one-pass operation optimization measure specifically includes: when the dynamic stability problem exists after the N-1 fault or the N-2 fault of the direct current near-zone alternating current section exists, the damping ratio after the large disturbance fault is increased by optimizing the excitation and PSS parameters of the hydroelectric generating set, and the power flow organization capacity of the direct current near-zone alternating current section is improved; the starting mode of the direct-current near-zone unit is optimized, the unit with strong dynamic reactive voltage supporting capability is increased, the transient state or steady state voltage rise after the direct-current fault is reduced, and the direct-current transmission capability is improved; and for the simultaneous-transmitting and simultaneous-receiving direct currents, performing cooperative optimization on the starting values of all direct current commutation failure prediction links according to multi-direct current interaction, coordinating a multi-direct current recovery sequence, and reducing the risk of simultaneous commutation failure.
Preferably, the two-run optimization measures include: for the condition that the direct current transmission capacity is limited by the steady-state overvoltage after direct current locking, the sequence of the generator tripping objects and the measure quantity are finely arranged; the output of the hydroelectric generating set is quickly adjusted by directly supplying a hydroelectric generating set output quick adjustment instruction to a hydroelectric generating set speed adjusting system through a stability control system, partial discrete machine cutting amount is replaced, and the system frequency characteristic after direct-current large-disturbance impact is optimized.
Preferably, the three operation optimization measures include: and for the condition that the frequency of the direct current transmission capacity is stable under the impact of direct current high power, the strategy of the high-frequency generator tripping of the power grid is optimized, the fixed value of the high-frequency generator tripping is finely arranged, and the low-frequency load shedding is matched.
Preferably, in step 4, the investment priority ranking of the different planning measures is determined by the maximum value of the difference between the operation risk variation and the investment cost before and after the investment of the planning measures, and the calculation formula is as follows:
Figure GDA0003407655940000021
in the formula: c discard 、C ec 、C pe Respectively the electricity abandon cost, the emergency control cost and the like caused by the failure of full power transmission of direct current,599 penalty cost; c risk 0 、C risk ' operation risks before and after planning measures are input respectively; c invest Cost for planning measures; i. lambda [ alpha ] i 、ω t The typical working condition number, the working condition probability and the fault probability are respectively; j is the working condition that the power of the direct current arrangement is larger than the maximum transmissible power; p j 、P DC max The direct current power arranged under the working condition j and the direct current maximum bearing capacity subjected to multiple constraints are respectively arranged, k is the unit cost of electricity abandonment, and P is DC max ＝min(P DC ESCR ,P DC AC ,P DC voltage ,P DC frequency )。P DC ESCR For maximum DC transmission power, P, subject to short-circuit ratio DC AC For maximum transmission power of DC, P, constrained by the electrical organization of the AC channels DC voltage For a maximum transmission power of DC, P, subject to voltage stability constraints DC frequency Is the dc maximum transmission power subject to frequency constraints.
In summary, due to the adoption of the technical scheme, the invention has the beneficial effects that:
1. the invention preferentially performs operation optimization under the condition that the direct current bearing capacity is smaller than the rated transmission power, and adopts planning measures for the working condition that the direct current bearing capacity is still smaller than the rated transmission power after the operation optimization so as to reduce the planning investment as much as possible, avoid the resource waste and reduce the cost.
2. Before planning measures are taken, unified monetization is carried out on electricity abandon loss caused by that direct current cannot be sent out with full power, emergency control cost, 599 punishment cost caused by load shedding and the like, risk cost of an operation layer is formed, economic evaluation is carried out on investment effects of various planning measures, and investment priority ranking is carried out on different planning measures until the maximum transmission capacity of the direct current reaches the rated transmission power of the direct current. Therefore, the optimal combination of planning measures and operation measures is obtained, and the planning personnel of the power system is guided to perfect all the planning measures.
Drawings
The invention will now be described, by way of example, with reference to the accompanying drawings, in which:
FIG. 1 is a DC transmission structure diagram of a southwest power grid in an embodiment;
FIG. 2 is a converter station AC bus voltage after DC blocking according to an embodiment;
fig. 3 shows the frequency deviation after dc commutation failure in the same transmission and reception of the embodiment.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present application clearer, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all the embodiments. The components of the embodiments of the present application, generally described and illustrated in the figures herein, can be arranged and designed in a wide variety of different configurations. Thus, the following detailed description of the embodiments of the present application, as presented in the figures, is not intended to limit the scope of the claimed application, but is merely representative of selected embodiments of the application. All other embodiments, which can be derived by a person skilled in the art from the embodiments of the present application without making any creative effort, shall fall within the protection scope of the present application.
The present invention will be described in detail with reference to fig. 1.
Taking the southwest of China as an example, extra-high voltage direct current of three loops of Yahu-Nanchang, white Crane beach-Jiangsu and white Crane beach-Zhejiang in 2023 years ago is sequentially connected to a power grid in the climbing of Sichuan, a regional power grid forms a trans-regional power transmission pattern of 'two longitudinal directions and eight transverse directions', the water-electricity ratio is over 70%, the trans-regional rated outgoing capacity is increased to 5420 ten thousand kilowatts, and the conventional direct current capacity of simultaneous transmission and reception in the southwest and the east of China is 3360 ten thousand kilowatts.
TABLE 1 D.C. Scale of southwest electric network in 2023
Figure GDA0003407655940000041
(1) Single DC carrying capacity and planning measure optimization
Taking Yahu direct current as an example, only 4 sets of Yang Fang ditch power plants are put into production before 2023 years, the capacity is 150 ten thousand kilowatts, a new energy set is accessed in a near area, the capacity is 80 thousand kilowatts, and the rest of electric power is collected from a main network. Different from the modes of Binjin, repavone and Jinsu extra-high voltage direct current 'big water and electricity + big direct current', the small water and electricity in the Yahu direct current near area are numerous, the power organization and the voltage supporting capability are not enough, and the single direct current is limited by the direct current bearing capability with multiple constraints of safety, and mainly comprises the following steps:
(a) Overload restraint is carried out after the cross section alternating current N-2 fault is collected;
(b) Restraining transient overvoltage and steady overvoltage of the converter station after the direct current blocking fault;
(c) After direct current commutation fails, the new energy in the near area passes through at low voltage, the direct current near area voltage characteristic is deteriorated, and the new energy is disconnected.
After the multiple constraint conditions are considered, the DC carrying capacity of the Yahu lake is only 400 ten thousand kilowatts and is far lower than the rated power of 800 ten thousand kilowatts. Optimization is therefore preferably carried out by means of operational measures, including: 1. starting the direct current near area; 2. and optimizing the generator tripping control strategy after the direct current locking, wherein the direct current carrying capacity is improved to 510 ten thousand kilowatts from 400 ten thousand kilowatts after the two steps of operation optimization measures are taken.
From the main limited factor of the DC bearing capacity of the Yahu lake, the DC bearing capacity is essentially caused by delayed production of a matched power supply, uncoordinated development of source-DC load and insufficient power collection capacity of an AC network frame, so that when planning measures are optimized, a dynamic reactive power compensation device is added and a DC near-region power transmission network is strengthened. As the direct current near-district moon city station faces the risk of exceeding the standard of short-circuit current, the direct current near-district moon city station is not suitable for installing a phase modulator, and a static synchronous compensator (STATCOM) with a good dynamic reactive power supporting effect is preferentially selected. And determining the priority sequencing and the installation place of the dynamic reactive power compensation device and the power transmission line by comparing the risk benefits of different planning measures. Wherein the compensation capacity of the STATCOM is 600Mvar, the time constant of the filter is 0.02s, the response delay is 0.02s, and the comprehensive manufacturing cost is about 200 yuan/kVar. The kilometer cost of each unit capacity of a 500kV line is about 3012 yuan, and the capacity of the newly added line is about 3803MW. The unit of the power supply can be referred to for the price of the power on the internet, for example, the unit cost of the power abandonment of the hydropower is 227.7 yuan/MWh. 500kV line fault probability 114 times/100 km.year, the main transformer fault probability is 1.29 times/100.year, the direct current single pole fault probability is 1.6 times/year, and the double pole fault probability is 0.1 times/year. The load amount of the post-fault dump does not reach the penalty condition of 599 regulations, C pe Is 0. The calculated risk gains after respectively investing different planning measures are shown in table 2.
TABLE 2 Risk and cost under different planning measures
Figure GDA0003407655940000051
As can be seen from fig. 2 and table 2, the measures of installing the STATCOM in the converter station are adopted to maximize the risk benefit, improve the dc carrying capacity with the best effect, and reduce the overvoltage risk after the dc blocking fault. And because the investment cost of the newly-built line is too high, the risk and income of the year cannot offset the line investment cost. Therefore, a recommended measure for improving the dc capability is to add a STATCOM device to the converter station.
(2) Load-bearing capacity and operation optimization of simultaneous-transmission and simultaneous-reception direct-current group
In 2023, the conventional direct current capacity of the southwest and the east China who are simultaneously transmitted and received is 3360 ten thousand kilowatts, the total inertia of the southwest power grid in the Fengchi mode is 372027MW.s, and according to theoretical estimation, the newly added direct current outgoing power is considered to be provided by a matched power supply with the same parameters as the white crane beach unit, namely the maximum output of a single unit is 1000MW, and the kinetic energy is 4675.6MW.s. As can be known from the Huadong alternating current fault simulation, the risk that 5 times of extra-high voltage direct current simultaneously causes 2 times of continuous phase commutation failure exists, namely delta t is 0.4s. The maximum DC carrying capacity of 2720 ten thousand kilowatts, which is not more than 50.8Hz after the DC commutation failure of the same transmission and reception, can be estimated by the formula, and is smaller than the total 3360 ten thousand kilowatts of the five extra-high voltage conventional DC. And (3) adopting operation optimization measures, carrying out cooperative optimization on starting values of all direct current commutation failure prediction links, coordinating a multi-direct current recovery sequence, reducing the risk of simultaneous continuous commutation failure of five loops of direct current to one time, namely, the delta t is 0.2s, the maximum direct current bearing capacity with the maximum frequency not exceeding 50.8Hz is 13740 ten thousand kilowatts, and increasing the power of simultaneously-transmitted and-received direct current, wherein a generator frequency deviation curve after commutation failure is shown in figure 3 and is lower than 50.8Hz.
In summary, the direct current carrying capacity of simultaneous transmission and reception of the southwest power grid and the east China power grid is greatly improved after the optimization of operation measures is considered.
The above-mentioned embodiments only express the specific embodiments of the present application, and the description thereof is more specific and detailed, but not construed as limiting the scope of the present application. It should be noted that, for those skilled in the art, without departing from the technical idea of the present application, several changes and modifications can be made, which are all within the protection scope of the present application.

Claims (1)

1. A planning operation measure optimization method for improving direct current bearing capacity is characterized by comprising the following steps:
step 1: acquiring a power supply and a load plan of a power grid of a sending end, and evaluating the maximum direct current transmission capacity of a given grid frame according to the power supply and the load plan of the power grid of the sending end;
step 2: if the maximum direct current transmission capacity is smaller than the rated transmission power, making corresponding operation optimization measures;
and 3, step 3: if the direct current carrying capacity is still smaller than the rated transmission power after various operation optimization measures are taken, unified monetization is carried out on electricity abandonment loss caused by that direct current cannot be sent out at full power, emergency control cost and 599 punishment cost caused by load shedding, and risk cost of an operation layer is formed;
and 4, step 4: planning measures are made, and investment priority ranking is carried out on different planning measures until the maximum direct current transmission capacity reaches the rated transmission power;
the planning measures in the step 4 comprise: a dynamic reactive power compensation device STATCOM is arranged in the vicinity of the direct current converter station; strengthening the near-region alternating current net rack to improve the short circuit capacity of the near-region alternating current system; for new energy existing in the direct-current matching power supply, the electrical distance between the new energy and the converter station is increased, and the new energy offline risk is reduced; in order to avoid high frequency of a transmitting end caused by failure of simultaneous transmission and receiving direct current commutation, a VSC (voltage source converter) station is adopted in a direct current inversion station during planning construction;
the operation optimization measures in the step 2 comprise a first operation optimization measure, a second operation optimization measure and a third operation optimization measure;
the one-pass operation optimization measure specifically comprises the following steps: when the dynamic stability problem exists after the N-1 fault or the N-2 fault of the direct current near-zone alternating current section, the damping ratio after the large disturbance fault is increased by optimizing the excitation and PSS parameters of the hydroelectric generating set, and the power flow organization capacity of the direct current near-zone alternating current section is improved; the starting mode of the direct-current near-zone unit is optimized, the unit with strong dynamic reactive voltage supporting capability is increased, the transient state or steady state voltage rise after the direct-current fault is reduced, and the direct-current transmission capability is improved; for the simultaneous-transmitting and receiving direct currents, performing cooperative optimization on starting values of all direct-current commutation failure prediction links according to multi-direct-current interaction, coordinating a multi-direct-current recovery sequence, and reducing the risk of simultaneous commutation failure;
the two-run optimization measures comprise: for the condition that the direct current transmission capacity is limited by the steady-state overvoltage after direct current locking, the sequence of the generator tripping objects and the measure quantity are finely arranged; the output of the hydroelectric generating set is quickly adjusted through a stability control system by directly supplying a hydroelectric generating set output quick adjustment instruction to a hydroelectric generating set speed regulation system, partial discrete machine cutting amount is replaced, and the system frequency characteristic after direct current large disturbance impact is optimized;
the three operation optimization measures comprise: for the condition that the frequency of the direct current transmission capacity is stable under the impact of direct current high power, the strategy of a high-cycle generator tripping of the power grid is optimized, the fixed value of the high-cycle generator tripping is finely arranged, and the fixed value is matched with the low-cycle load shedding;
in step 4, the investment priority ranking of different planning measures is determined by the maximum value of the difference between the operation risk variation and the investment cost before and after the investment of the planning measures, and the calculation formula is as follows:
max(ΔC risk -C invest )
Figure FDA0003751144480000021
in the formula: c discard 、C ec 、C pe Respectively due to the failure of full power transmission of DCElectricity cost, emergency control cost, 599 penalty cost; c risk 0 、C risk ' operating risks before and after planning measures are input respectively; c invest Cost for planning measures; i. lambda i 、ω t The typical working condition number, the working condition probability and the fault probability are respectively; j is the operating condition that the power of the DC arrangement is greater than the maximum transmissible power, lambda j Is the probability of condition j; p j 、P DC max The direct current power and the direct current maximum bearing capacity subjected to multiple constraints are respectively arranged for the working condition j; k is the unit cost of power curtailment.
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