CN112383069B - Dynamic prediction method for primary frequency modulation compensation capability of generator set - Google Patents
Dynamic prediction method for primary frequency modulation compensation capability of generator set Download PDFInfo
- Publication number
- CN112383069B CN112383069B CN202011222183.3A CN202011222183A CN112383069B CN 112383069 B CN112383069 B CN 112383069B CN 202011222183 A CN202011222183 A CN 202011222183A CN 112383069 B CN112383069 B CN 112383069B
- Authority
- CN
- China
- Prior art keywords
- frequency modulation
- compensation
- primary frequency
- generator set
- frequency difference
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 238000000034 method Methods 0.000 title claims abstract description 35
- 230000008569 process Effects 0.000 claims abstract description 14
- 239000011159 matrix material Substances 0.000 claims description 24
- 238000006243 chemical reaction Methods 0.000 claims description 11
- 238000004364 calculation method Methods 0.000 claims description 6
- 230000001105 regulatory effect Effects 0.000 description 6
- 230000008859 change Effects 0.000 description 4
- 230000009471 action Effects 0.000 description 3
- 230000004044 response Effects 0.000 description 3
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000011217 control strategy Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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
- H02J3/24—Arrangements for preventing or reducing oscillations of power in networks
- H02J3/241—The oscillation concerning frequency
-
- 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
- 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
- H02J3/48—Controlling the sharing of the in-phase component
-
- 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
- Y04S10/00—Systems supporting electrical power generation, transmission or distribution
- Y04S10/50—Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications
Landscapes
- Engineering & Computer Science (AREA)
- Power Engineering (AREA)
- Control Of Eletrric Generators (AREA)
Abstract
The invention discloses a dynamic prediction method for primary frequency modulation compensation capacity of a generator set, which classifies, arranges and preprocesses test data according to a primary frequency modulation remote test result, predicts dynamic variation processes of frequency modulation quantities of each generator set and the whole network under different frequency differences after primary frequency modulation occurs by adopting Euclidean distance according to a principle that working conditions are similar, is convenient for a dispatcher to master the frequency modulation capacity of the generator set and supports the safe operation of power grid dispatching.
Description
Technical Field
The invention relates to the field of prediction of frequency modulation compensation capacity of a generator set, in particular to a dynamic prediction method of primary frequency modulation compensation capacity of the generator set.
Background
When each unit is connected to the power grid, the frequency of the power grid changes under the influence of external load change. The regulating system of each unit participates in the regulation action, changes the load carried by each unit to balance the load with the external load, and simultaneously reduces the change of the power grid frequency as much as possible, and the process is primary frequency modulation. The primary frequency modulation response is quick, the power grid frequency can be quickly corrected, and the method is an important means for ensuring the safe operation of the power grid. At present, the proportion of thermal power of a Shandong power grid is smaller and smaller, direct current furnace units are more and more, and the frequency modulation capacity of the added parts such as nuclear power, extra-high voltage input electric quantity, wind power and the like is limited, so that the primary frequency modulation compensation capacity in a future period of time can be accurately predicted, and powerful support can be provided for safe and stable operation of the power grid.
At present, a grid-connected starting unit is periodically subjected to a primary frequency modulation remote test with fixed frequency difference by a power grid dispatching control center, a test result is compared with a theoretical compensation value, and whether the primary frequency modulation capability meets the requirement or not is verified. The existing primary frequency modulation remote test can verify whether a certain primary frequency modulation capability meets the requirement, but the frequency modulation compensation capability cannot be predicted according to the primary frequency modulation remote test.
Disclosure of Invention
The invention provides a dynamic prediction method for frequency modulation compensation capacity, which classifies, arranges and preprocesses test data according to a primary frequency modulation remote test result, predicts dynamic variation processes of frequency modulation quantities of each unit and the whole network under different frequency differences after primary frequency modulation occurs by adopting Euclidean distance according to a principle that working conditions are similar, is convenient for a dispatcher to master the frequency modulation capacity of the generator unit and supports the safe operation of power grid dispatching.
In order to solve the technical problem, the technical scheme adopted by the invention is as follows: a dynamic prediction method for primary frequency modulation compensation capability of a generator set comprises the following steps:
s01), collecting historical data, collecting all historical data of a primary frequency modulation test of a single generator set, wherein the historical data comprises active power before the action of the primary frequency modulation test, a master control instruction, main steam pressure, test frequency difference and a 60S primary frequency modulation compensation curve of the generator set after the primary frequency modulation test is started, converting the primary frequency modulation compensation curve according to the relation between the historical frequency difference and a target frequency difference, and forming a historical matrix by the converted primary frequency modulation compensation curve and other collected data;
all primary frequency modulation test data before the current moment are all historical data collected in the step, if the historical data are null, a theoretical compensation curve is used as a primary frequency modulation compensation curve under the target frequency difference of a single generator set, and if the historical data are not null, the step S02 is continued;
s02), data per-unit, per-unit is carried out on the active power, the main control instruction and the main steam pressure in the historical matrix, and the active power, the main control instruction and the main steam pressure after per-unit form a standard position matrix A;
s03), real-time data acquisition and per-unit, acquiring real-time active power, a main control instruction and main steam pressure of a single generator set, and per-unit the active power, the main control instruction and the main steam pressure to form a matrix B;
s04), calculating a primary frequency modulation compensation curve under the target frequency difference of a single generator set;
calculating the distance from the matrix A to the matrix B to obtain a distance set R, judging whether the number of elements in the distance set R is smaller than K, if so, taking all values in R, if so, taking the minimum K values in R, then taking the converted primary frequency modulation compensation curves corresponding to the values, and taking the average value of the converted primary frequency modulation compensation curves of the number of the K or all elements in R as the primary frequency modulation compensation curve under the target frequency difference of the generator set;
s05), calculating a primary frequency modulation compensation curve of the whole network generator set, and taking the sum of the primary frequency modulation compensation curves of the whole network generator set as a final primary frequency modulation compensation curve of the whole network.
Further, in step S01, the process of converting the primary frequency modulation compensation curve according to the relationship between the historical test frequency difference and the target frequency difference is as follows:
an nth second compensation reduced value = (nth second active power-0 th second active power) (| target frequency difference | -0.033)/(| test frequency difference | -0.033);
the compensation values from 0s to 60s form a converted primary frequency modulation compensation curve;
the nth second active power reduced value = 0 th second active power + nth second compensation amount reduced value.
Further, in step S01, the calculation process of the theoretical compensation curve is as follows:
first, a theoretical compensation value is calculated:
secondly, theoretical compensation values of different seconds are specified, wherein 0 second is 0 percent of the theoretical compensation value, 3 second is 10 percent of the theoretical compensation value, 15 second is 75 percent of the theoretical compensation value, 30 second is 90 percent of the theoretical compensation value, 45 second is 100 percent of the theoretical compensation value, and 60 second is 100 percent of the theoretical compensation value;
and finally, connecting the theoretical compensation values of the 0 th second, the 3 rd second, the 15 th second, the 30 th second, the 45 th second and the 60 th second to form a theoretical compensation curve.
Further, in step S04, when calculating the next frequency modulation compensation curve of the target frequency difference of the single generator set, it is determined whether the current target frequency difference needs to be converted into another frequency difference, and if yes, the conversion is performed, where the conversion process is:
the N second compensation quantity conversion value = N second compensation quantity | target frequency difference |/| test frequency difference | wherein the test frequency difference is the current target frequency difference, and the target frequency difference is other frequency differences to be converted;
and the compensation values from 0s to 60s form a primary frequency modulation compensation curve of the target frequency difference.
Further, the master control instruction determines the opening degree of the steam turbine.
Further, the target frequency difference is 0.1 Hz.
Further, the generator set is a thermal power generating unit or a nuclear power generating unit.
Further, K = 3.
Further, in step S04, the euclidean distance from the matrix a to the matrix B is calculated.
The invention has the beneficial effects that: according to the invention, the dynamic change process of the frequency modulation quantity of the generator set after the primary frequency modulation occurs is predicted according to the historical performance of each generator set, so that the current dynamic response primary frequency modulation capability of the generator set can be conveniently and intuitively known in scheduling, and the method has important guiding significance for the scheduling and operation of a power grid. The main control command, the main steam pressure and the active power are used as main influence factors for calculation, but the calculation method is not limited to the main steam pressure and the active power, and other factors can be added into the calculation method after conversion and per unit.
Drawings
Fig. 1 is a flow chart of primary frequency modulation compensation capability prediction.
Detailed Description
The invention is further described with reference to the following figures and specific embodiments.
Example 1
The embodiment discloses a dynamic prediction method for primary frequency modulation compensation capacity of a generator set.
The primary frequency modulation compensation capability of the generator set mainly takes the following factors into consideration:
(1) influence of the opening degree of a steam turbine regulating valve: according to the linear corresponding relation among the current opening position of the steam turbine regulating valve, the opening of the steam turbine regulating valve and active power, the primary frequency-modulated output of the generator set is limited by the maximum opening of the actual output of the regulating valve, and the opening of the steam turbine regulating valve is determined by a master control instruction.
(2) Main steam pressure, main steam temperature: after main parameters of the generator set, such as main steam pressure and main steam temperature, obviously exceed the allowable range of the generator set, the control strategy of the generator set can protect the generator set, and the continuous increase of primary frequency modulation output is limited.
The noun explanation calculation method used in this embodiment is as follows:
nth second offset: the 1 second before the primary frequency modulation remote test is started is recorded as the 0 th second, and the test signal issuing starting test is recorded as the 1 st second. And the Nth second compensation quantity is the primary frequency modulation compensation quantity of the generator set in the Nth second after the test starts.
Theoretical compensation value:
Theoretical compensation curve: according to the primary frequency modulation acceptance dynamic index, the theoretical compensation curve dynamic response process in the embodiment is specified as follows:
second 0 takes 0% of the theoretical compensation value.
The 3 rd second is 10% of the theoretical compensation value.
The 15 th second takes 75% of the theoretical compensation.
The 30 th second takes 90% of the theoretical compensation.
The 45 th second takes 100% of the theoretical compensation value.
The 60 th second takes 100% of the theoretical compensation value.
Theoretical compensation values at 0 th, 3 rd, 15 th, 30 th, 45 th and 60 th seconds are connected to form a theoretical compensation curve.
As shown in fig. 1, the dynamic prediction method for primary frequency modulation compensation capability of a generator set in this embodiment includes the following steps:
s01), collecting historical data, collecting all historical data of a primary frequency modulation test of a single generator set, wherein the historical data comprises active power before the action of the primary frequency modulation test, a master control instruction, main steam pressure, test frequency difference and a 60S primary frequency modulation compensation curve of the generator set after the primary frequency modulation test is started, converting the primary frequency modulation compensation curve according to the relation between the historical frequency difference and a target frequency difference, and forming a historical matrix by the converted primary frequency modulation compensation curve and other collected data;
all primary frequency modulation test data before the current moment are all historical data collected in the step, if the historical data are null, a theoretical compensation curve is used as a primary frequency modulation compensation curve under the target frequency difference of a single generator set, and if the historical data are not null, the step S02 is continued;
s02), data per unit, per unit is carried out on the active power, the main control instruction and the main steam pressure in the historical matrix, and the active power, the main control instruction and the main steam pressure after per unit form a standard position matrix A;
s03), real-time data acquisition and per-unit, acquiring real-time active power, a main control instruction and main steam pressure of a single generator set, and per-unit the active power, the main control instruction and the main steam pressure to form a matrix B;
s04), calculating a primary frequency modulation compensation curve under the target frequency difference of a single generator set;
calculating the distance from the matrix A to the matrix B to obtain a distance set R, judging whether the number of elements in the distance set R is less than 3, if so, taking all values in the R, if so, taking the minimum 3 values in the R, then taking the converted primary frequency modulation compensation curves corresponding to the values, and taking the average value of the converted primary frequency modulation compensation curves of 3 or all elements in the R as the primary frequency modulation compensation curve under the target frequency difference of the generator set;
s05), calculating a primary frequency modulation compensation curve of the whole network generator set, and taking the sum of the primary frequency modulation compensation curves of the whole network generator set as the whole network primary frequency modulation compensation curve.
Usually, the test frequency difference of the primary frequency modulation remote test is selected to be near 0.1Hz, the target frequency difference can be set to be 0.1Hz through the prediction of the primary frequency modulation compensation capability of a single generator set, and the primary frequency modulation compensation capability under the typical frequency difference of 0.1Hz is preferentially calculated and displayed.
In step S01, the process of converting the primary frequency modulation compensation curve according to the relationship between the historical test frequency difference and the target frequency difference is as follows:
an nth second compensation reduced value = (nth second active power-0 th second active power) (| target frequency difference | -0.033)/(| test frequency difference | -0.033);
the compensation values from 0s to 60s form a converted primary frequency modulation compensation curve;
the nth second active power reduced value = 0 th second active power + nth second compensation amount reduced value.
In step S04, when calculating the next frequency modulation compensation curve of the target frequency difference of a single generator set, it is determined whether or not conversion from the current target frequency difference to another frequency difference is required, and if yes, the conversion is performed, and the conversion process is:
the nth second offset is converted into = nth second offset | target frequency difference | experimental frequency difference |,
wherein the test frequency difference is the current target frequency difference (0.1 Hz), and the target frequency difference is other frequency differences to be converted;
and the compensation values from 0s to 60s form a primary frequency modulation compensation curve of the target frequency difference.
In this embodiment, the generator unit may be a thermal power unit or a nuclear power unit.
In step S04, the euclidean distance from matrix a to matrix B is calculated.
The method is based on the primary frequency modulation remote test result, the test data is classified, sorted and preprocessed, the dynamic change process of the frequency modulation quantity of each unit and the whole network under different frequency differences after primary frequency modulation is generated is predicted by adopting the Euclidean distance according to the principle that the working conditions are similar, the scheduling personnel can conveniently master the frequency modulation capacity of the generator units, and the power grid is supported to schedule and run safely.
The foregoing description is only for the basic principle and the preferred embodiments of the present invention, and modifications and substitutions by those skilled in the art are included in the scope of the present invention.
Claims (9)
1. A dynamic prediction method for primary frequency modulation compensation capability of a generator set is characterized by comprising the following steps: the method comprises the following steps:
s01), collecting historical data, collecting all historical data of a primary frequency modulation test of a single generator set, wherein the historical data comprises active power, a master control instruction, main steam pressure, test frequency difference and a 60S primary frequency modulation compensation curve of the generator set after the primary frequency modulation test starts, converting the primary frequency modulation compensation curve according to the relation between the historical frequency difference and a target frequency difference, and forming a historical matrix by the converted primary frequency modulation compensation curve and other collected data;
all primary frequency modulation test data before the current moment are all historical data collected in the step, if the historical data are null, a theoretical compensation curve is used as a primary frequency modulation compensation curve under the target frequency difference of a single generator set, and if the historical data are not null, the step S02 is continued;
s02), data per-unit, per-unit is carried out on the active power, the main control instruction and the main steam pressure in the historical matrix, and the active power, the main control instruction and the main steam pressure after per-unit form a standard position matrix A;
s03), real-time data acquisition and per-unit, acquiring real-time active power, a main control instruction and main steam pressure of a single generator set, and per-unit the active power, the main control instruction and the main steam pressure to form a matrix B;
s04), calculating a primary frequency modulation compensation curve under the target frequency difference of a single generator set;
calculating the distance from the matrix A to the matrix B to obtain a distance set R, judging whether the number of elements in the distance set R is smaller than K, if so, taking all values in R, if so, taking the minimum K values in R, then taking the converted primary frequency modulation compensation curves corresponding to the values, and taking the average value of the converted primary frequency modulation compensation curves of all the elements in K or R as the primary frequency modulation compensation curve under the target frequency difference of the generator set;
s05), calculating a primary frequency modulation compensation curve of the whole network generator set, and taking the sum of the primary frequency modulation compensation curves of the whole network generator set as a final primary frequency modulation compensation curve of the whole network.
2. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: in step S01, the process of converting the primary frequency modulation compensation curve according to the relationship between the historical test frequency difference and the target frequency difference is as follows:
an nth second compensation reduced value = (nth second active power-0 th second active power) (| target frequency difference | -0.033)/(| test frequency difference | -0.033);
the compensation values from 0s to 60s form a converted primary frequency modulation compensation curve;
the nth second active power reduced value = 0 th second active power + nth second compensation amount reduced value.
3. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: in step S01, the calculation process of the theoretical compensation curve is:
first, a theoretical compensation value is calculated:
secondly, theoretical compensation values of different seconds are specified, wherein 0 second is 0 percent of the theoretical compensation value, 3 second is 10 percent of the theoretical compensation value, 15 second is 75 percent of the theoretical compensation value, 30 second is 90 percent of the theoretical compensation value, 45 second is 100 percent of the theoretical compensation value, and 60 second is 100 percent of the theoretical compensation value;
and finally, connecting the theoretical compensation values of the 0 th second, the 3 rd second, the 15 th second, the 30 th second, the 45 th second and the 60 th second to form a theoretical compensation curve.
4. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: in step S04, when calculating the next frequency modulation compensation curve of the target frequency difference of a single generator set, it is determined whether or not conversion from the current target frequency difference to another frequency difference is required, and if yes, the conversion is performed, and the conversion process is:
the nth second compensation quantity conversion value = nth second compensation quantity x | target frequency difference |/| test frequency difference |, wherein the test frequency difference is the current target frequency difference, and the target frequency difference is other frequency differences to be converted;
and the compensation values from 0s to 60s form a primary frequency modulation compensation curve of the target frequency difference.
5. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: and the master control instruction determines the opening degree of the steam turbine.
6. The dynamic prediction method for primary frequency modulation compensation capability of the generator set according to claim 1 or 3, characterized in that: the target frequency difference was 0.1 Hz.
7. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: the generating set is a thermal power generating set or a nuclear power generating set.
8. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: k = 3.
9. The dynamic prediction method for the primary frequency modulation compensation capability of the generator set according to claim 1, characterized in that: in step S04, the euclidean distance from the matrix a to the matrix B is calculated.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011222183.3A CN112383069B (en) | 2020-11-05 | 2020-11-05 | Dynamic prediction method for primary frequency modulation compensation capability of generator set |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011222183.3A CN112383069B (en) | 2020-11-05 | 2020-11-05 | Dynamic prediction method for primary frequency modulation compensation capability of generator set |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN112383069A CN112383069A (en) | 2021-02-19 |
| CN112383069B true CN112383069B (en) | 2022-06-03 |
Family
ID=74579656
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011222183.3A Active CN112383069B (en) | 2020-11-05 | 2020-11-05 | Dynamic prediction method for primary frequency modulation compensation capability of generator set |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN112383069B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN113972669B (en) * | 2021-11-01 | 2023-11-24 | 国网重庆市电力公司电力科学研究院 | Online prediction method for primary frequency modulation dynamic adjustment capacity of generator set |
Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107341559A (en) * | 2016-11-25 | 2017-11-10 | 国网山东省电力公司电力科学研究院 | A kind of Primary frequency control ability Forecasting Methodology based on main vapour pressure tolerance |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107609697B (en) * | 2017-09-06 | 2018-11-09 | 南京邮电大学 | A kind of Wind power forecasting method |
| CN107749631B (en) * | 2017-10-25 | 2020-10-30 | 国电南瑞科技股份有限公司 | Unit primary frequency modulation capability pre-estimating method |
| CN111049161A (en) * | 2020-01-03 | 2020-04-21 | 浙江大学台州研究院 | Energy storage multi-scene application cooperative control method |
| CN111598388B (en) * | 2020-04-09 | 2023-01-06 | 国家电网有限公司 | Online evaluation method for frequency modulation resource demand of real-time market of power grid |
| CN111709554A (en) * | 2020-05-22 | 2020-09-25 | 广西电网有限责任公司 | Method and system for joint prediction of net loads of power distribution network |
-
2020
- 2020-11-05 CN CN202011222183.3A patent/CN112383069B/en active Active
Patent Citations (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107341559A (en) * | 2016-11-25 | 2017-11-10 | 国网山东省电力公司电力科学研究院 | A kind of Primary frequency control ability Forecasting Methodology based on main vapour pressure tolerance |
Also Published As
| Publication number | Publication date |
|---|---|
| CN112383069A (en) | 2021-02-19 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| EP2721291B1 (en) | Selective droop response control for a wind turbine power plant | |
| US3932735A (en) | Method of controlling supply of power | |
| EP2227856B1 (en) | Apparatus and method for controlling the reactive power from a cluster of wind turbines connected to a utility grid | |
| CN102597507B (en) | Control device for wind-powered electricity-generating device, wind farm, and control method for wind-powered electricity generating device | |
| JP5167106B2 (en) | Wind power plant and its power generation control method | |
| CN104641529A (en) | A method of determining individual set points in a power plant controller, and a power plant controller | |
| CN109921438B (en) | Primary frequency modulation dynamic adjusting device considering AGC reverse adjustment | |
| CN110230575B (en) | Method and system for maintaining a wind power plant of a group of wind power plants | |
| CN112383069B (en) | Dynamic prediction method for primary frequency modulation compensation capability of generator set | |
| EA021216B1 (en) | System and method for regulation of a regenerative energy generation installation | |
| CN111525616A (en) | Control system and method for wind power plant | |
| JP2019161845A (en) | Processor, control device for power storage system, power storage system, processing method and program | |
| JP2016093049A (en) | Supply-demand control device and supply-demand control method | |
| CN115409360A (en) | Power scheduling method, system, equipment and storage medium for multi-machine type wind power plant | |
| EP2280167A2 (en) | Control method of electric power generation system utilizing renewable energy | |
| WO2014057788A1 (en) | Storage cell system and power plant control system | |
| CN117436773A (en) | Independent micro-grid resource planning method and system containing interruptible load | |
| CN110994639A (en) | Simulation constant volume method, device and equipment for power plant energy storage auxiliary frequency modulation | |
| CN116613782A (en) | Light-fire cooperation flexible peak shaving power generation control system and control method | |
| JP6593000B2 (en) | Energy supply and demand planning device and program | |
| CN115149547A (en) | Energy storage auxiliary thermal power secondary frequency modulation system and control method | |
| CN114514688A (en) | Method for controlling boosted power output of power generation unit | |
| JP4031412B2 (en) | Power generation control device and program for power consignment | |
| JP2007159266A (en) | Frequency controller | |
| CN115296338B (en) | Wind power output extreme climbing risk assessment method based on multi-time scale analysis |
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 |