CN110854852A - Method for configuring key parameters of AGC (automatic gain control) master station in high-proportion hydropower region - Google Patents
Method for configuring key parameters of AGC (automatic gain control) master station in high-proportion hydropower region Download PDFInfo
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Abstract
A method for configuring key parameters of an AGC (automatic gain control) main station in a high-proportion hydropower area comprises the following steps: a. establishing a simulation model of the whole process of the regional power grid; b. acquiring a natural frequency characteristic coefficient of a regional power grid by a simulation means; c. establishing a common disturbance set of a power grid; d. setting a configuration scheme applicability evaluation index; e. forming a set of frequency deviation coefficients; f. setting proportional gain sizes of different control areas; g. setting a system normal area threshold, a secondary emergency area threshold and an emergency area threshold; h. and e, carrying out rationality evaluation on the frequency deviation coefficient and the proportional gain, returning to the step e if the frequency deviation coefficient and the proportional gain do not meet the requirements, and taking the frequency deviation coefficient and the proportional gain as a final configuration scheme if the frequency deviation coefficient and the proportional gain meet the requirements. On the basis of establishing a simulation model of the whole process of the regional power grid, the invention realizes the configuration of key parameters of the AGC master station in the high-proportion hydropower region by means of simulation.
Description
Technical Field
The invention relates to a method for configuring key parameters of an AGC (automatic gain control) master station in a high-proportion hydropower region, belonging to the technical field of power transmission and distribution.
Background
In recent years, with the successive production of extra-high voltage direct current system engineering, the scale of a power grid is continuously enlarged, and the operation difficulty of the power grid is gradually increased. In order to ensure the safety of a power grid and improve the operation reliability, an alternating current connecting line is cancelled between a sending end system and a main grid, interconnection is realized only by direct current, alternating current decoupling is realized, and the sending end power grid and the main grid are asynchronously interconnected. After asynchronous interconnection, the scale of a power grid is greatly reduced, the load level is sharply reduced, the operation difficulty of the power grid is greatly improved, and the frequency stability becomes a key factor influencing the safe and stable operation of the system.
The AGC plays a key role in improving the frequency quality of a power grid and ensuring the safe and economic operation of the power grid as an important means for controlling the active power of a modern power grid. The high water occupancy asynchronous operation sending end power grid puts higher requirements on the operation of AGC. And the main station parameters play a crucial role in the secondary frequency modulation effect.
At present, the setting of the domestic and foreign main station parameters mostly depends on the operation experience of a dispatcher, the frequency deviation coefficient, the proportional gain of different control areas and the division of control area thresholds are manually adjusted mainly by depending on the feedback of the operation effect of an actual power grid, and the trial and error cost is high. In the master station control setting, partial domestic high-proportion hydroelectric power grids try to adopt a segmented frequency deviation coefficient or set a proportional gain for a control area to improve the system regulation level. Using too many frequency offset factors may cause the local power offset to oscillate during frequent switching of the frequency offset factors. And the use of a single large frequency deviation coefficient in cooperation with multiple sets of proportional gains will result in the failure of the tie line component in the area control deviation under small frequency deviation.
Disclosure of Invention
The invention aims to provide a method for configuring key parameters of an AGC master station in a high-proportion hydropower region aiming at the defects of the prior art so as to improve the frequency quality of a power grid and ensure the safe and economic operation of the power grid.
The problems of the invention are solved by the following technical scheme:
a method for configuring key parameters of an AGC (automatic gain control) main station in a high-proportion hydropower area comprises the following steps:
a. establishing a simulation model of the whole process of the regional power grid;
b. acquiring a natural frequency characteristic coefficient of a regional power grid by a simulation means;
c. establishing a common disturbance set of the power grid according to the disturbance quantity;
d. setting a configuration scheme applicability evaluation index;
e. forming a group of frequency deviation coefficients according to the natural frequency characteristic coefficients and the dynamic characteristics of the power grid frequency-related elements;
f. setting proportional gain sizes of different control areas according to the frequency deviation coefficient;
g. setting a system normal region threshold, a secondary emergency region threshold and an emergency region threshold according to the frequency deviation coefficient and the proportional gain;
h. and e, carrying out rationality evaluation on the frequency deviation coefficient and the proportional gain, returning to the step e if the frequency deviation coefficient and the proportional gain do not meet the requirements, and taking the frequency deviation coefficient and the proportional gain as a final configuration scheme if the frequency deviation coefficient and the proportional gain meet the requirements.
According to the configuration method of the key parameters of the AGC master station in the high-proportion hydropower region, the simulation model of the whole process of the regional power grid comprises all frequency-related elements of primary frequency modulation and secondary frequency modulation, and the load regulation effect is considered.
The method for configuring the key parameters of the AGC master station in the high-proportion hydropower region comprises the following specific steps of:
modifying the simulation model of the whole process of the regional power grid, and keeping the load regulation effect, the primary frequency modulation of the generator set and the frequency modulation capability of the direct-current frequency limiter; the operation of the whole network secondary frequency modulation quits, and the operation of the hydroelectric generating set primary frequency modulation quits below the designated capacity of the whole network;
and setting the load of the whole network to fluctuate unidirectionally in the same proportion, and ensuring that the power network is in a quasi-steady state all the time, wherein the load variation and the system frequency deviation are the natural frequency characteristic coefficient of the system.
According to the configuration method of the key parameters of the AGC master station in the high-proportion hydropower region, the disturbance set comprises steady-state random fluctuation, disturbance of a main power unit and direct-current disturbance; the steady random fluctuation is the sum of the fluctuation around the base point and the consistency fluctuation within a certain time length; the consistency fluctuation comprises five types of splicing of power slow-rise, power fast-fall, power maintenance and power slow-fall; the disturbance of the main power unit comprises tripping of the main power unit in the region and tripping of the main power unit outside the region; the direct current disturbance comprises direct current power speed reduction and direct current blocking.
According to the method for configuring the key parameters of the AGC master station in the high-proportion hydropower region, the applicability evaluation indexes comprise steady-state operation frequency deviation, frequency recovery speed after fault disturbance and the condition of reverse modulation of disturbance outside the region, and the steady-state operation frequency deviation indexes comprise frequency excess allowance times, maximum frequency deviation size and frequency deviation mean square deviation within specified time; counting the time required for the deviation from the lowest frequency point to the system frequency after the occurrence of the self-disturbance to recover to the thermal power regulation dead zone for the first time by using the frequency recovery speed index after the fault disturbance; the out-of-area disturbance inverse tone index comprises the maximum inverse tone quantity and the inverse tone existing time length in the disturbance process.
According to the configuration method of the key parameters of the AGC master station in the high-proportion hydropower region, the frequency deviation coefficient is set according to the natural frequency characteristic coefficient under the hydropower dead zone frequency deviation and the natural frequency characteristic coefficient of the dead zone frequency deviation of the direct-current frequency limiter.
According to the method for configuring the key parameters of the AGC master station in the high-proportion hydropower region, the proportional gain reference frequency deviation coefficients of different control regions are set and are sequentially increased according to the proportional coefficients of a normal region, a secondary emergency region and an emergency region.
On the basis of establishing a simulation model of the whole process of the regional power grid, the invention realizes the configuration of key parameters of the AGC master station of the high-proportion hydropower region by means of simulation, can accurately set a control region division threshold and proportional gains of different control regions, can form a parameter configuration scheme with high adaptability without trial and error of the actual power grid, can cope with various possible operation conditions of the power grid with high quality, and improves the stability and the economy of the operation of the power grid. Compared with the traditional method, the method can effectively improve the frequency quality of the power grid and ensure the safe and economic operation of the power grid.
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The present invention will be described in further detail with reference to the accompanying drawings.
FIG. 1 is a flow chart of the present invention;
FIG. 2 is a schematic diagram of a typical configuration of a power grid;
FIG. 3 is a graph comparing the effects of frequency control under several typical conditions;
fig. 4 is a power-frequency curve of an embodiment of the present invention.
Detailed Description
The invention comprises the following steps:
step 1, establishing a regional power grid overall process simulation model:
the regional power grid simulation model is required to contain all frequency related elements of primary and secondary frequency modulation, such as a speed regulator, a steam turbine, a water turbine, an AGC system, a power plant monitoring system, a direct current frequency limiter (FC or FLC) and the like, and the load regulation effect is considered;
step 2, researching the natural frequency characteristic coefficient of the regional power grid by a simulation means:
the research method comprises the following steps: modifying the whole network model, and keeping the load regulation effect, the primary frequency modulation of the generator set and the frequency modulation capability of the direct-current frequency limiter; and the operation of the whole network secondary frequency modulation is stopped, and the operation of the hydroelectric generating set primary frequency modulation below the specified capacity (such as 50MW) of the whole network is stopped.
Setting the load of the whole network to slowly and unidirectionally fluctuate in the same proportion, ensuring that the power network is in a quasi-steady state all the time, and considering the load variation and the system frequency deviation as the natural frequency characteristic coefficient of the system;
step 3, establishing a common disturbance set of the power grid according to the disturbance quantity:
the disturbance set at least comprises three types of disturbance, namely steady state random fluctuation, disturbance of a main power unit and direct current disturbance; the steady-state random fluctuation is the sum of the fluctuation around the base point and the consistency fluctuation within a certain time period. The fluctuation around the base point can reversely deduce the load fluctuation amount through the frequency fluctuation when the power grid exits AGC operation, and the consistency fluctuation can be obtained through a scheduling curve. The consistency fluctuation at least comprises five types of splicing of power slow-rising, power fast-falling, power maintaining and power slow-falling. The disturbance of the main power unit comprises tripping of the main power unit in the region and tripping of the main power unit outside the region. The direct current disturbance needs to include common direct current disturbances such as direct current power rapid reduction, direct current blocking and the like;
step 4, setting the configuration scheme applicability evaluation index:
the evaluation indexes of the applicability of the scheme comprise three indexes of steady-state operation frequency deviation, frequency recovery speed after fault disturbance and the condition of disturbance back modulation outside the area. The steady state operating frequency deviation index at least comprises: the frequency exceeds the quota times (2) and the maximum frequency deviation size (3) and the mean square deviation size of the frequency deviation in the appointed time (1). And counting the time required for the deviation from the lowest frequency point to the system frequency after the occurrence of the self-disturbance to recover to the thermal power regulation dead zone for the first time by the fault disturbance frequency recovery speed index. The out-of-range disturbance inverse tone index at least comprises: in the disturbance process, (1) the maximum backstepping quantity and (2) the existence duration of the backstepping;
step 5, forming a group of frequency deviation coefficients according to the natural frequency characteristic coefficients and the dynamic characteristics of the power grid frequency-related elements:
the frequency deviation coefficient determining method comprises the following steps: the system natural frequency characteristic coefficient presents strong nonlinearity, and the difference between small frequency deviation and large frequency deviation is great. Different frequency deviation requirements are difficult to meet by setting a single frequency deviation coefficient; setting too many frequency offset coefficients may cause local power offset oscillations. Frequency deviation coefficients are set according to the types of frequency modulation elements in the power grid, the fact that a typical high-proportion hydroelectric region is an asynchronous running power grid which is connected with direct current in an interconnected mode mostly is considered, the load level is low, and any disturbance can cause the frequency to exceed a thermal power dead zone. Therefore, a frequency deviation coefficient is not set independently aiming at the frequency deviation corresponding to the thermal power dead zone, but the frequency deviation coefficient under the condition that the thermal power participates in frequency modulation is taken into consideration, namely a coefficient is set by referring to a natural frequency characteristic coefficient under the thermal power dead zone frequency deviation. The hydropower primary frequency modulation capability of a high-proportion hydropower region is strong, the frequency deviation coefficient of a threshold system of the direct-current frequency limiter is considered to be changed violently, and a coefficient can be set by referring to the dead-zone frequency deviation natural frequency characteristic coefficient of the direct-current frequency limiter. The main station is usually converted into FFC operation under the condition of extra disturbance, reverse regulation of a non-fault area is not required to be considered, and a frequency deviation coefficient is not set independently. If necessary, a frequency deviation coefficient can be additionally set by referring to the frequency of the FFC;
and 6, setting the proportional gain of different control areas according to the frequency deviation coefficient:
the setting method of the proportional gain of different control areas comprises the following steps: and setting different proportional gains for different control regions according to the magnitude of the frequency deviation coefficient. The normal region has a larger frequency deviation factor and a smaller scaling factor (e.g., 0.4) is set to prevent overshoot. The secondary emergency area and the emergency area gradually amplify the proportional gain, so that the control efficiency under the conditions of load climbing and failure is improved;
step 7, setting a system normal region threshold, a sub-emergency region threshold and an emergency region threshold according to the frequency deviation coefficient and the proportional gain:
the control area sets thresholds as follows: (1) a smaller normal region threshold is set to reduce the delay effect of PI regulation. The value can not be too small, so that the frequency deviation coefficient set in the step 5 under the threshold value is matched with the proportional gain set in the step 6 to avoid oscillation (2), a larger secondary emergency area threshold is set, the system ACE is ensured not to enter the secondary emergency area generally under the steady-state load fluctuation working condition, and only the ACE under the severe changing working conditions such as rapid system load climbing enters the secondary emergency area from the normal area. The value cannot be too large, and a general unit trip disturbance system ACE can enter a secondary emergency area to accelerate the frequency recovery of the system. (3) The emergency area threshold is reasonably set, when the system is greatly disturbed, the system ACE can enter the emergency area, and a certain difference exists between the system ACE and the secondary emergency area threshold;
and 8, performing rationality evaluation on the frequency deviation coefficient and the proportional gain. If not, readjusting is needed until a final configuration scheme is obtained:
firstly, simulating each working condition by using full-process simulation software according to the disturbance set extracted in the step 4, and evaluating a simulation result according to the evaluation index extracted in the step 5. And after the evaluation is passed, the actual power grid system is carried.
Meanwhile, the proportional gain of an ACE normal area is reduced, so that the overshoot effect of the normal area is reduced.
One specific example is given below.
And one power grid is asynchronously interconnected with one main grid, the Yubei flexible direct delivery is realized, and the other power grid is asynchronously interconnected with the other power grid. The transmission end power grid has the following typical characteristics: the water and electricity occupation ratio is high, the direct current outgoing power is large, the power grid scale is greatly reduced, and the frequency modulation problem is prominent. Summarizing the characteristics and forming a typical characteristic power grid a, wherein the power grid a comprises a main tone and a provincial tone, the main tone adopts FFC, and the provincial tone adopts TBC control; the main grid frequency modulated power plants are located in a control area 1, as shown in fig. 2.
The method comprises the following steps:
1. a power grid simulation data model is established in a generous manner, and a frequency simulation model including a speed regulator, a steam turbine, a water turbine, an AGC system, a power plant monitoring system, a direct current frequency limiter (FC or FLC) and the like is established, and the load regulation effect is considered.
2. Establishing a common disturbance set, wherein the disturbance set comprises three types of disturbance, namely steady-state random fluctuation, disturbance of a main power unit and direct current disturbance; the steady-state random fluctuation is the sum of the fluctuation around the base point and the consistency fluctuation within a certain time period. The consistency fluctuation at least comprises five types of splicing of power slow-rising, power fast-falling, power maintaining and power slow-falling. The disturbance of the main power unit comprises tripping of the main power unit in the region and tripping of the main power unit outside the region. The dc disturbances include dc power ramp down, dc latch-up, and other common dc disturbances.
3. And establishing an applicability evaluation index, wherein the scheme applicability evaluation index comprises three indexes of steady-state operation frequency deviation, frequency recovery speed after fault disturbance and disturbance back-modulation condition outside the area. The steady state operating frequency deviation index at least comprises: the frequency exceeds the quota times (2) and the maximum frequency deviation size (3) and the mean square deviation size of the frequency deviation in the appointed time (1). And counting the time required for the deviation from the lowest frequency point to the system frequency after the occurrence of the self-disturbance to recover to the thermal power regulation dead zone for the first time by the fault disturbance frequency recovery speed index. The out-of-range disturbance inverse tone index at least comprises: and (1) the maximum backspace quantity (2) the existence duration of the backspace in the disturbance process.
4. Researching the frequency characteristic coefficient of a certain power grid by a simulation means, quitting the AGC of the power grid a in the simulation, continuously increasing the load according to the rate of 1%/min until the system frequency drops to 49.90Hz, and drawing a frequency-power curve, wherein the frequency-power curve is shown in the following table:
simulation calculation B coefficient (frequency deviation coefficient)
The power-frequency curve is shown in fig. 4.
5. And selecting 2 groups of coefficients B according to the β factors under different frequency deviations, and respectively corresponding to the frequency deviations under the hydropower control dead zone and the direct current FCL dead zone.
6. And respectively setting different proportional gains for different control regions according to the size of the coefficient B. The normal region has a larger frequency deviation coefficient and a smaller scale factor (0.4) is set to prevent overshoot. The sub-emergency area and the emergency area gradually amplify the proportional gain (0.7 and 1.1), and the control efficiency under the conditions of load climbing and faults is improved.
7. And setting a control area threshold and a smaller normal area threshold to reduce the delay effect of PI regulation. The value can not be too small, and the frequency deviation coefficient under the threshold value is matched with the proportional gain to avoid oscillation; a larger secondary emergency area threshold is set, so that the system ACE does not generally enter the secondary emergency area under the steady state load fluctuation working condition, and only enters the secondary emergency area from the normal area under the severe changing working conditions such as rapid climbing of the system load and the like. The value cannot be too large, and a general unit trip disturbance system ACE can enter a secondary emergency area to accelerate the frequency recovery of the system; the emergency area threshold is reasonably set, when the system is greatly disturbed, the system ACE can enter the emergency area, and a certain difference exists between the system ACE and the secondary emergency area threshold.
8. The effect of comparing the frequency adjustment effect of the master station control area parameters set by the method with the conventional master station control area parameters is shown in fig. 3.
Claims (7)
1. A method for configuring key parameters of an AGC master station in a high-proportion hydropower area is characterized by comprising the following steps:
a. establishing a simulation model of the whole process of the regional power grid;
b. acquiring a natural frequency characteristic coefficient of a regional power grid by a simulation means;
c. establishing a common disturbance set of the power grid according to the disturbance quantity;
d. setting a configuration scheme applicability evaluation index;
e. forming a group of frequency deviation coefficients according to the natural frequency characteristic coefficients and the dynamic characteristics of the power grid frequency-related elements;
f. setting proportional gain sizes of different control areas according to the frequency deviation coefficient;
g. setting a system normal region threshold, a secondary emergency region threshold and an emergency region threshold according to the frequency deviation coefficient and the proportional gain;
h. and e, carrying out rationality evaluation on the frequency deviation coefficient and the proportional gain, returning to the step e if the frequency deviation coefficient and the proportional gain do not meet the requirements, and taking the frequency deviation coefficient and the proportional gain as a final configuration scheme if the frequency deviation coefficient and the proportional gain meet the requirements.
2. The method for configuring key parameters of the AGC master station in the high-proportion hydropower region according to claim 1, wherein the simulation model of the whole process of the regional power grid comprises all frequency-related elements of primary frequency modulation and secondary frequency modulation, and the load regulation effect is considered.
3. The method for configuring key parameters of the AGC master station in the high-proportion hydropower region according to claim 1 or 2, wherein the specific method for acquiring the natural frequency characteristic coefficient of the regional power grid is as follows:
modifying the simulation model of the whole process of the regional power grid, and keeping the load regulation effect, the primary frequency modulation of the generator set and the frequency modulation capability of the direct-current frequency limiter; the operation of the whole network secondary frequency modulation quits, and the operation of the hydroelectric generating set primary frequency modulation quits below the designated capacity of the whole network;
and setting the load of the whole network to fluctuate unidirectionally in the same proportion, and ensuring that the power network is in a quasi-steady state all the time, wherein the load variation and the system frequency deviation are the natural frequency characteristic coefficient of the system.
4. The method for configuring key parameters of the AGC master station in the high-proportion hydropower area according to claim 3, wherein the disturbance set comprises steady-state random fluctuation, disturbance of a main power unit and direct-current disturbance; the steady random fluctuation is the sum of the fluctuation around the base point and the consistency fluctuation within a certain time length; the consistency fluctuation comprises five types of splicing of power slow-rise, power fast-fall, power maintenance and power slow-fall; the disturbance of the main power unit comprises tripping of the main power unit in the region and tripping of the main power unit outside the region; the direct current disturbance comprises direct current power speed reduction and direct current blocking.
5. The method for configuring the key parameters of the AGC master station in the high-proportion hydropower region according to claim 4, wherein the method applicability evaluation indexes comprise steady-state operation frequency deviation, frequency recovery speed after fault disturbance and the condition of disturbance reverse modulation outside a region, and the steady-state operation frequency deviation indexes comprise frequency excess quota times, maximum frequency deviation and frequency deviation mean square deviation within specified time; counting the time required for the deviation from the lowest frequency point to the system frequency after the occurrence of the self-disturbance to recover to the thermal power regulation dead zone for the first time by using the frequency recovery speed index after the fault disturbance; the out-of-area disturbance inverse tone index comprises the maximum inverse tone quantity and the inverse tone existing time length in the disturbance process.
6. The method for configuring key parameters of the high-proportion hydropower region AGC master station according to claim 5, wherein the frequency deviation coefficient is set according to a natural frequency characteristic coefficient under hydropower dead-zone frequency deviation and a natural frequency characteristic coefficient of dead-zone frequency deviation of a direct-current frequency limiter.
7. The method for configuring key parameters of the AGC master station in the high-proportion hydropower region as claimed in claim 6, wherein the setting of the proportional gain reference frequency deviation coefficients of different control regions is sequentially increased according to the proportional coefficients of a normal region, a secondary emergency region and an emergency region.
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