CN113131531B - Adjustment standby sharing method and system suitable for different operation conditions of power grid - Google Patents
Adjustment standby sharing method and system suitable for different operation conditions of power grid Download PDFInfo
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- CN113131531B CN113131531B CN201911413488.XA CN201911413488A CN113131531B CN 113131531 B CN113131531 B CN 113131531B CN 201911413488 A CN201911413488 A CN 201911413488A CN 113131531 B CN113131531 B CN 113131531B
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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
- H02J3/38—Arrangements for parallely feeding a single network by two or more generators, converters or transformers
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- 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
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Abstract
The invention discloses a method and a system for adjusting standby sharing under different operation conditions of a power grid, wherein the method comprises the following steps: determining the expected active power deviation of each power grid control area based on the predetermined area control deviation of the power grid control area; determining the adjustment reserve sharing quantity under different operation conditions according to the expected active power deviation of each power grid control area; checking the determined adjustment standby sharing amount; and distributing the regulated standby sharing amount after the verification is passed to each power grid control area so as to enable each power grid control area to realize standby sharing amount regulation. The method combines the adjustment standby conditions of different power grid control areas, determines the adjustment standby sharing quantity based on different operation conditions, solves the problems that the prior adjustment standby sharing method is heavier on the allocation after the fault and considers the adjustment characteristics under different power grid operation conditions in daily operation, further improves the control stability in the normal operation state and improves the safe and stable operation capability of the power grid.
Description
Technical Field
The invention relates to a regulation standby sharing method suitable for different operation working conditions of a power grid, and belongs to the technical field of automatic power generation control of power systems.
Background
At present, a provincial power grid control area of a Chinese power grid is a control main body of Automatic Generation Control (AGC), a tie-line power and frequency deviation control (TBC) mode is usually adopted to be responsible for active power balance of the control area, and with continuous development of an extra-high voltage alternating current-direct current hybrid power grid, the partition balance mode is difficult to support dispatching operation requirements, and multi-level dispatching coordinated operation, multi-control area adjustment resource and standby sharing are urgently required to be realized.
The sharing of resource adjustment and standby among control areas mainly relates to AGC cooperative control and daily plan correction, and promotes the standby enthusiasm of each area sharing unit by matching with a marketing means. In the aspect of application practice of domestic power grids, attention is paid to how each control area inside an ultra-high voltage alternating-current tie line power fluctuation amount is shared and controlled, large-scale power loss lower sending ends such as direct-current receiving end area peak shaving, large-capacity unit tripping and direct-current blocking and power shortage is shared in the receiving end area power grid. The main idea of these researches is how to properly transfer the regulation responsibility to other control areas to improve the frequency and active power control efficiency of the tie line when the regulation resource of a single control area is insufficient. In fact, fault recovery is only one of the targets of backup sharing, and is also an important means for improving the economical efficiency and the stability of the operation of the power grid. In the southwest power grid, the operation characteristics of the power grid are changed profoundly in an asynchronous interconnection mode, the proportion of the installed electricity in the whole power grid is more than 70%, and the characteristics of large machine and small network provide higher requirements for the dynamic quality of AGC adjustment under a cross-level multi-control-area structure. More particularly, the water and electricity are mainly used in Sichuan and Tibet areas, the thermal power is mainly used in Chongqing areas, the overall adjustment performance difference of different control areas is large, and the frequency and the power oscillation of a connecting line can be aggravated if effective coordination is not available, so that the safe and stable operation of a power grid is not facilitated.
To sum up, the existing backup sharing method adapted to different power grid operation conditions lacks a systematic design structure, is heavily stressed on allocation after a fault, and does not consider economic factors in daily operation. Therefore, a multi-provincial power grid control area regulation standby sharing method which can automatically adapt to the change of the power grid operation condition and has a certain prediction function needs to be provided.
Disclosure of Invention
The invention provides a method and a system for adjusting standby sharing under different operating conditions of a power grid, aiming at solving the problems that the existing method for adjusting standby sharing is heavier than the apportionment after the fault and does not consider the adjusting characteristics under different power grid operating conditions during daily operation. The invention adopts the following technical scheme:
on one hand, the invention provides a method for adjusting standby sharing under different operation conditions of a power grid, which comprises the following steps:
determining the expected active power deviation of each power grid control area based on the predetermined area control deviation of the power grid control area;
determining the adjustment standby sharing quantity of each power grid control area under different operation conditions according to the expected active power deviation of each power grid control area; and distributing the adjusted standby sharing amount to each power grid control area so as to enable each power grid control area to realize standby sharing amount adjustment.
Further, the calculation method formula of the expected active power deviation of each power grid control area is as follows:
0≤R n T≤(G d,n -G a,n )
in the formula (I), the compound is shown in the specification,
the expected active power deviation amount of each power grid control area; e ACE,i Controlling deviation for the area of the power grid control area; n is the total number of AGC controlled units in the power grid control area; r n Adjusting the speed of the nth AGC controlled unit in the power grid control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the power grid control area; Δ V d,i To predict the active deviation rate of change; g d,n Outputting the target output of the nth AGC controlled unit in the power grid control area; g a,n And the actual output of the nth AGC controlled unit in the power grid control area.
Further, according to the adjustment standby condition of each power grid control area, the calculation method formula of the expected active power deviation of each power grid control area is as follows:
0≤R n T≤(G d,n -G a,n )
wherein
The expected active power deviation amount of each power grid control area;
the regional control deviation of the standby shared power grid control area is considered and adjusted; n is the total number of AGC controlled units in the power grid control area; r is n Adjusting the speed of the nth AGC controlled unit in the power grid control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the power grid control area; Δ V d,i To predict the active deviation rate of change; g d,n Outputting the target output of the nth AGC controlled unit in the power grid control area; g a,n And the actual output of the nth AGC controlled unit in the power grid control area.
Still further, the calculation formula of the area control deviation of the power grid control area after the adjustment of the backup sharing is considered as follows:
in the formula, B i Setting a frequency deviation coefficient of a power grid control area; f. of A The actual frequency of the power grid; f. of S Planning frequency, P, for the grid A The actual load flow of the external connecting line is added for the power grid control area; p S The total planned value of the external tie line for the power grid control area; p co,i Planning correction quantity of the virtual tie line superposed in the power grid control area; and i is the number of the power grid control area.
Further, the working condition comprises a first operating condition, the first operating condition is a normal operating condition, the adjustment backup sharing amount in the first operating condition comprises an adjustment backup sharing amount of a group with frequency deviation and an adjustment backup sharing amount of a group with frequency deviation,
the formula for determining the control area adjustment standby sharing quantity in the frequency deviation difference unit according to the expected active power deviation of each power grid control area is as follows:
wherein, P co,w Adjusting the spare share amount for the control area in the frequency offset difference number group;
the expected active power deviation amount of the control area in the frequency deviation difference signal group;
calculating the control area adjustment standby sharing quantity in the same group with the frequency deviation, and adopting an unbalance quantity equal proportion distribution mode, wherein the formula is as follows:
in the formula: p co,v Adjusting the amount of spare sharing for control areas in the same group as the frequency deviation;
an expected amount of active power deviation for control zones within the same number of frequency deviation; v and W are the number of control areas in the same or different sign groups with the frequency deviation respectively.
Further, the working condition includes a second operation condition, the second operation condition is an operation condition that the power grid frequency deviation is within a preset range after the fault occurs, the second operation condition is switched to a standby climbing rate proportion to share the standby sharing amount again, and a formula of the standby sharing correction amount of the control area in the same group with the frequency deviation after the fault is as follows:
of formula (II) to (III)' co,v Spare sharing correction quantity of the control area in the same group with the frequency deviation after the fault; r v For controlling the zone equivalent climbing rate, P co,v And adjusting the spare sharing amount for the control areas in the same group with the frequency deviation, wherein V is the number of the control areas in the same group with the frequency deviation.
Further, different working conditions include a third operating condition, the third operating condition is an operating condition that the power grid Frequency deviation is outside a preset range after a fault occurs, the power grid Control area switches an ACE (ACE-line Bias Control) mode from a TBC (TBC) mode to a fixed Frequency Control mode (FFC, flat Frequency Control), and each power grid Control area directly recovers the power grid Frequency and does not participate in adjusting standby sharing optimization allocation;
further, the determined adjustment standby sharing amount is verified, and the verification is that the determined adjustment standby sharing amount is distributed to each power grid control area, and the verification method is to judge whether the adjustment standby sharing amount meets the following constraints:
1) The physical branch transmission constraint which forms the sub-section is expressed as follows:
wherein L is the number of physical branches contained in the trans-provincial conveying sub-section,
reverse quota for the l physical branch; f. of l The actual power flow of the first physical branch is obtained; f. of max,l The forward quota is the l physical branch; p co,h Adjusting standby sharing quantity on any external sub-section h for any power grid control area;
2) And restricting the adjustable range of the AGC unit, wherein the expression is as follows:
in the formula, N is the total number of AGC controlled units in the power grid control area, alpha nl Quasi-steady-state sensitivity, G, of unit n to link l a,n Actual output of the unit;
3) The main hydropower is sent out to be restricted by a channel, and the expression formula is shown as follows:
f m +(G max,n -G a,n )α nm ≤L max,m
in the formula, N r The number of main output sections selected for the interior of the power grid control area; alpha is alpha nm The quasi-steady-state sensitivity of the unit n to the section m is obtained; k ml A power transmission distribution factor of the section m on the connecting line l; f. of m The actual tide of the section m is obtained; l is max,m Is a forward limit of section m, G max,n The upper limit of the adjustment of the unit n; g min,n The lower limit of the set n is adjusted; l is the total number of the connecting lines; and M is the total number of the sections contained in the power grid control area.
4) The sub-sections of different connecting lines are constrained, and the expression is as formula (14)
In the formula:
is a sub-section reverse quota; k he Controlling power transmission distribution factors of the sub-section h on other sub-sections e; s h The actual tidal current value of the section is obtained; s max,e Is a forward limit of the section.
5) Self reserves the standby constraint.
In a second aspect, the adjusting standby sharing system applicable to different operation conditions of a power grid is characterized by comprising a power grid control area expected active power deviation determining module, an adjusting standby sharing amount calculating module, a standby sharing safety checking module and an instruction issuing module;
the power grid control area expected active power deviation determining module is used for determining the expected active power deviation of each power grid control area based on the predetermined area control deviation of the power grid control area;
the adjustment standby sharing quantity calculation module is used for determining adjustment standby sharing quantities of each power grid control area under different operation conditions according to the expected active power deviation of each power grid control area;
and the instruction issuing module is used for distributing the adjusted standby sharing amount to each power grid control area so as to enable each power grid control area to realize standby sharing amount adjustment.
In a third aspect, the present invention provides a method for adjusting backup sharing under different operating conditions of a power grid, which is characterized by comprising the following steps:
the method comprises the following steps that a branch scheduling control center determines expected active power deviation of each power grid control area based on a predetermined area control deviation of the power grid control area; determining the adjustment standby sharing quantity of each power grid control area under different operation conditions according to the expected active power deviation of each power grid control area; verifying the determined adjustment standby sharing quantity, and distributing the verified adjustment standby sharing quantity to each power grid control area;
and each power grid control area receives and adjusts the spare sharing quantity, superposes the received adjusted spare sharing quantity on each power grid control area ACE, and issues an adjusting instruction to a regulating and managing power plant according to the new ACE to realize the adjustment of the spare sharing quantity of each power grid control area.
Further, each power grid control area judges the unit regulation state according to the expected control time or the tracking precision to determine whether to issue a new regulation instruction, the expected control time is calculated according to the regulation rate set manually or sent by a power plant through remote measurement, and the calculation method comprises the following steps:
in the formula, S u Controlling time for anticipation; delta P r Is a new adjustment command increment; r u The unit speed is set;
the tracking accuracy determination method comprises the following steps:
1) If the unit is required to be adjusted upwards:
G a,n ＞G d,n -G D
2) If the unit is required to be adjusted downwards:
G a,n ＜G d,n +G D
in the formula, G a,n For actual output of the unit, G d,n Target output of the unit, G D Dead zones are adjusted for the unit.
In the formula, P h,max Supporting a forward quota for regulating backup sharing;
supporting reverse quota for regulating backup sharing, P co,h For arbitrary power grid control region to external controlAdjustment backup share on ideogram h.
Because the astronomical clock frequency in a supervisory control and data acquisition (SCADA) system is faster than the refresh rate of tie line data, issuing a normal adjustment command after a fault may aggravate the cross-section out-of-limit degree. Therefore, when the frequency exceeds the limit, the AGC system stops sending a new command for 2 control cycles, and the section control function takes effect.
The calculated adjustment standby sharing quantity is superposed to ACE (adaptive communication control) raw data of each power grid control area, and the adjustment performance of the internal unit of each control area is adapted after low-pass filtering, control algorithm, static and dynamic dead zones and the like so as to ensure the stability of closed-loop feedback control.
The invention achieves the following beneficial effects:
the method determines the expected active power deviation of each provincial power grid control area through the area control deviation based on the predetermined power grid control area; the method has the advantages that the adjustment standby sharing amount of each power grid control area under different operation conditions is determined according to the expected active power deviation of each provincial power grid control area, the method can adapt to the design structure that the standby sharing method under different power grid operation conditions lacks systematicness, the phenomenon that the standby sharing method is distributed after being stressed on faults is avoided, and the economical factor in daily operation is considered, so that the method can automatically adapt to the change of the power grid operation condition, and the economical efficiency and the stability of the power grid operation are improved;
the invention provides an adjusting standby sharing method suitable for different operation conditions of a power grid, which combines the adjusting standby conditions of different provincial power grid control areas and provides two standby sharing modes of positive and negative standby replacement and same-direction standby mutual assistance aiming at different operation conditions, thereby further improving the control stability in a normal operation state, improving the control efficiency and the adjusting speed after the fault, and lightening the daily operation pressure of a dispatcher, thereby improving the operation efficiency of the power grid and improving the safe and stable operation capability of the power grid.
Drawings
The foregoing is only an overview of the technical content of the present invention, and in order to make the technical means of the present invention more clearly understood, the present invention will be further described in detail with reference to the accompanying drawings and the detailed description.
Fig. 1 is a schematic diagram of an implementation process of a method for adjusting backup sharing according to an embodiment of the present invention;
fig. 2 is a flowchart illustrating a method for adjusting backup sharing according to an embodiment of the present invention.
Detailed Description
The present invention will be better understood and implemented by those skilled in the art by the following detailed description of the technical solution of the present invention with reference to the accompanying drawings and specific examples, which are not intended to limit the present invention.
The first embodiment provides a method for adjusting standby sharing under different operation conditions of a power grid, which comprises the following steps:
step 1: the method comprises the steps that a branch dispatching Control center obtains frequency of Sichuan and Chongqing power grids and power operation data of external tie lines, and calculates the amount of active power unbalance of a provincial power grid Control Area, namely Area Control Error (ACE);
regional control deviation E ACE,i The calculation formula of (a) is as follows:
E ACE,i ＝-10B i (f A -f S )+(P A -P S )
wherein B is i Setting a frequency deviation coefficient of a provincial power grid control area; f. of A The actual frequency of the power grid; f. of S Planning frequency, P, for the grid A Adding the actual power flow of the external connecting line for the control area; p S A total planned value of the control area to the external connecting line; p is co,i Planning correction quantity for the virtual connecting line superposed in the control area; and i is the provincial power grid control area number.
And 2, step: and calculating the expected active power deviation according to the active power unbalance of the provincial power grid Control area by considering the response condition of Automatic Generation Control (AGC) units in the Sichuan and Chongqing power grids. Because the AGC unit has a variable control period, and the calculation formula for calculating the expected active power deviation of each provincial power grid control area is as follows by combining the unit regulation state:
0≤R n T≤(G d,n -G a,n )
in the formula (I), the compound is shown in the specification,
anticipating an active power deviation amount for each control area (namely a power grid control area); e ACE,i Controlling deviation for the region of the provincial power grid control region; n is the total number of AGC controlled units in the control area; r is n Adjusting the speed of the nth AGC controlled unit in the control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the control area; Δ V d,i To predict the active deviation rate of change; g d,n The target output of the nth AGC controlled unit in the control area is obtained; g a,n And the actual output of the nth AGC controlled unit in the control area.
And step 3: according to the expected active power deviation of each provincial power grid control area, determining the adjustment reserve sharing amount of each provincial power grid control area under different operation conditions of the southwest power grid formed by Sichuan and Chongqing; checking the determined adjustment standby sharing amount; and distributing the regulated standby sharing quantity after passing the verification to each provincial power grid control area so as to realize standby sharing quantity regulation in each provincial power grid control area.
1) Under the condition of normal operation, the frequent adjustment of the unit is reduced through the replacement of positive and negative adjustment standby among different provincial control areas;
2) Under the condition of a small fault, the dynamic response performance of the in-system unit after the fault is improved by regulating the standby mutual aid in the same direction;
3) In case of a major fault, the control mode of the provincial power grid control area is changed from the TBC mode to the fixed control mode FFC.
In the embodiment, the fault type that the grid frequency deviation is within 50 +/-0.1 Hz after the fault of the minor operation fault finger occurs; the larger operation fault refers to a fault type that the grid frequency deviation is beyond 50 +/-0.1 Hz after the fault occurs.
Under the condition that the power grid normally operates, the control area adjustment standby sharing quantity of the frequency deviation number group is calculated as follows:
in the formula, P co,w Adjusting the spare share amount for the control area in the frequency offset difference number group;
the amount of expected active power deviation from the control zone within the set of frequency deviation signals.
The control area of the same group of the normal operation state and the frequency deviation adjusts the standby sharing amount by adopting an unbalance equal proportion distribution mode, and the distribution mode is as follows.
In the formula: p co,v Adjusting the amount of spare sharing for control areas in the same number group as the frequency deviation;
an expected amount of active power deviation for control zones within the same number of frequency deviation; v and W are the number of control areas in the same or different sign groups with the frequency deviation respectively.
And under the condition of a small fault of the power grid, the fault is in a state. In data-triggered mode with ACE or frequency setting thresholds, important faults (such as dc latch) are switched to the backup ramp rate ratio in an event-triggered mode to again share the frequency as soon as possible.
Of formula (II) to (III)' co,v Spare sharing correction quantity of the control area in the same group with the frequency deviation after the fault; r is v In order to control the equivalent ramp rate of the zone,formed by superposing the climbing rates of main AGC units in a control area, P co,v The amount of spare sharing is adjusted for control zones within the same group as the frequency offset.
When the frequency deviation of a southwest power grid reaches 0.1Hz, frequency recovery is the most urgent task, and only the safety constraint of a connecting line is required to be complied with, namely after each control area is converted into a full-grid frequency modulation mode, global line overloading and even out-of-limit are possibly caused, so that the increasing and decreasing output directions of AGC controlled power plants are limited by each control area, and the method mainly aims at the unit regulation behavior with the sensitivity coefficient larger than 0.2.
And 4, step 4: and the southwest power dispatching control sub-center forwards the standby sharing superposition amount to each provincial power grid control area in a telemetering forwarding mode, so that the standby sharing superposition amount can be superposed on each provincial power grid control area ACE to realize the standby sharing of the whole network. The calculated adjustment standby sharing amount is superposed to ACE (adaptive communication control) raw data of each provincial power grid control area, and the adjustment standby sharing amount is adapted to the adjustment performance of the internal unit of each control area after being processed by low-pass filtering, a control algorithm, static and dynamic dead zones and the like so as to ensure the stability of closed-loop feedback control.
In a second embodiment, on the basis of the above embodiment, the checking the determined adjusted backup share amount includes checking whether the adjusted backup share amount satisfies the following constraint:
1) Physical branch transmission constraints forming a sub-section
Wherein L is the number of physical branches contained in the trans-provincial conveying sub-section,
reverse quota for physical tributary; f. of l Is the actual trend of the physical branch; f. of max,l Is the physical leg forward quota.
2) AGC set adjustable range constraint
In the formula, alpha nl Is the quasi-steady state sensitivity of the unit n to the tie line l.
3) Primary water and electricity delivery channel restraint
In the formula, N r The number of main delivery sections selected for the interior of the control area; alpha is alpha nm The quasi-steady-state sensitivity of the unit n to the section m is obtained; k ml A power transmission distribution factor of the section M on a connecting line l; f. of m The actual tide of the section m is obtained; l is max,m Is a forward limit of the section m.
4) Inter-fracture constraint of different tie lines
In the formula:
is a sub-section reverse quota; k he Controlling power transmission distribution factors of the sub-section h on other sub-sections e; s h The actual tidal current value of the section is obtained; s max,e Is a forward limit of the section.
5) Self-reserving backup constraints
For a specific large hydroelectric generating set in a Sichuan power grid, the upper limit and the lower limit of the generating set which can participate in standby sharing are properly adjusted, and certain adjustable standby is reserved for external support to cope with load climbing, new energy power fluctuation and the like which may occur in the future.
The southwest power dispatching control sub-center is used as a decision mechanism for adjusting standby sharing, safety verification is carried out by combining main constraint conditions, and the key point is that P is used co,v Or P' co,v Identifying sub-sections P according to flow support direction co,h And setting the limit value when the out-of-limit condition exists.
After safety verification, the southwest power dispatching control sub-center forwards the standby sharing result to the Sichuan and Chongqing power grid control areas as telemetering data.
The embodiment determines the adjustment standby sharing amount based on different operation conditions of each provincial power grid control area, and solves the problems that the existing adjustment standby sharing method is focused on the allocation after the fault and the adjustment characteristics under different power grid operation conditions in daily operation are considered.
Third embodiment, a flowchart of the present embodiment is shown in fig. 2, and on the basis of the above embodiments, in order to truly reflect the amount of active power imbalance in the provincial power grid control area, the present embodiment considers the adjustment requirement for adjusting the backup sharing, adjusts the backup sharing result, and determines the expected active power deviation of each provincial power grid control area according to the adjustment backup condition of each provincial power grid control area, where the calculation method formula is as follows:
0≤R n T≤(G d,n -G a,n )
wherein
The expected active power deviation amount for each control area;
the regional control deviation of the provincial power grid control region after standby sharing is considered and adjusted; n is the total number of AGC controlled units in the control area; r is n Adjusting the speed of the nth AGC controlled unit in the control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the control area; Δ V d,i To predict the active deviation rate of change; g d,n The target output of the nth AGC controlled unit in the control area is obtained; g a,n For the nth AGC of the control region to be controlledThe actual output of the unit.
The regional control deviation of the provincial power grid control region after the standby sharing is adjusted in consideration of the above
ACE is calculated as follows:
in the formula (I), the compound is shown in the specification,
consider an ACE after standby sharing; b is i Setting a frequency deviation coefficient of a provincial power grid control area; f. of a The actual frequency of the power grid; f. of s Planning the frequency for the power grid, generally taking 50Hz; p a Adding the actual power flow of the external connecting line for the control area; p s A total planned value of the control area to the external connecting line; p is co,i And planning correction quantity for the virtual connecting line superposed in the control area.
In this embodiment, a simulation system based on actual operation data may be used to simulate frequency response coefficients under different grid frequency deviations, set a multi-stage frequency deviation coefficient, and select a frequency deviation coefficient of the provincial grid control area from the multi-stage frequency deviation coefficient. The simulation system is provided with basic control models and parameters of a water-fire-electricity speed regulator, a load, a direct-current frequency controller and the like, the load is increased in an equal proportion under the condition of AGC open loop, and a frequency response coefficient is calculated according to the corresponding power grid frequency deviation change condition.
In the specific embodiment, the simulation system is provided with basic control models and parameters thereof such as a water-fire-electricity speed regulator, a load, a direct-current frequency controller and the like, the load is increased in an equal proportion according to the rate of 1% under the condition of AGC open loop, and the frequency response coefficient is calculated according to the corresponding power grid frequency deviation change condition. According to the corresponding frequency response coefficients in the normal operation state, the smaller fault state and the larger fault state, the allowable fluctuation bandwidths are set to be segmented into 0-0.05 Hz, 0.05-0.07 Hz and 0.07-0.1Hz respectively, the frequency deviation coefficients of the segments are selected respectively and set in the ACE calculation of the AGC system of the Sichuan and Chongqing power grids.
The simulation system based on the power grid operation data simulates frequency response coefficients under different power grid frequency deviations, and sets a multi-section frequency deviation coefficient; calculating an expected active power deviation value by considering the response condition of a unit in the power grid; under normal conditions, frequent adjustment of the unit is reduced through positive and negative adjustment standby replacement among different provincial control areas; under the condition of a small fault, the dynamic response performance of the in-system unit after the fault is improved by regulating the standby mutual aid in the same direction; under the condition of larger fault, the control mode of the provincial power grid control area is converted into a full-grid frequency modulation mode, so that the active power control efficiency of the power grid is improved.
The fourth embodiment provides an adjusting standby sharing system suitable for different operation conditions of a power grid, and the adjusting standby sharing system comprises a provincial power grid control area expected active power deviation determining module, an adjusting standby sharing amount calculating module, a standby sharing safety checking module and an instruction issuing module;
the provincial power grid control area expected active power deviation determining module is used for determining the provincial power grid control area expected active power deviation based on the predetermined regional control deviation of the provincial power grid control area;
the adjusting standby sharing quantity calculating module is used for determining adjusting standby sharing quantities under different operation conditions according to the expected active power deviation of each provincial power grid control area;
the standby sharing safety checking module is used for checking the determined adjusted standby sharing quantity;
and the instruction issuing module is used for distributing the regulated standby sharing amount after the verification is passed to each provincial power grid control area so as to realize the regulation of the standby sharing amount in each provincial power grid control area.
It should be noted that, the specific method for implementing each function by each module in this embodiment is as described in the foregoing embodiments, and is not described herein again.
Fifth embodiment, on the basis of the above embodiments, this embodiment provides an adjustment backup sharing method suitable for different operating conditions of a power grid, and an implementation process of this embodiment is schematically illustrated in fig. 1, where an upper-level department (a branch scheduling control center) illustrated in fig. 1 calculates an adjustment sharing amount according to a condition of a provincial power grid control area, checks whether the adjustment sharing amount is reasonable or not, distributes (forwards by telemetry) the adjustment sharing amount to each provincial power grid, and the provincial power grid receives the adjustment sharing amount and then superimposes the adjustment sharing amount on its own ACE, and then issues an adjustment instruction to control power plant output, so as to implement backup sharing control of the upper-level department. The upper department is not responsible for issuing the adjustment instruction until the standby sharing amount is allocated. The method of the embodiment comprises the following steps:
the branch scheduling control center determines the expected active power deviation of each provincial power grid control area based on the predetermined regional control deviation of the provincial power grid control area; determining the adjustment standby sharing amount under different operation conditions according to the expected active power deviation of each provincial power grid control area; verifying the determined adjustment standby sharing quantity, and distributing the verified adjustment standby sharing quantity to each provincial power grid control area;
the specific steps performed by the branch dispatching control center in this embodiment are the same as those provided in the above embodiments, and will not be described again.
And each provincial power grid control area receives and adjusts the standby sharing quantity, superposes the received adjusted standby sharing quantity on each provincial power grid control area ACE, and sends an adjusting instruction to the dispatching power plant according to the new ACE to realize the adjustment of the standby sharing quantity of each provincial power grid control area.
On the basis of the fifth embodiment, the adjustment state of the unit needs to be judged according to the expected control time or the tracking precision to determine whether to issue a new adjustment instruction. Each provincial power grid control area judges the unit regulation state according to the expected control time or the tracking precision to determine whether to issue a new regulation instruction, the expected control time is calculated according to the regulation rate set manually or sent by a power plant through remote measurement, and the calculation method comprises the following steps:
in the formula, S u Controlling time for anticipation; delta P r Is a new adjustment command increment; r u Is the unit rate.
The tracking accuracy determination method comprises the following steps:
1) If the unit is required to be adjusted upwards:
G a,n ＞G d,n -G D (5)
in the formula, G D Dead zones are adjusted for the unit.
2) If the unit is required to be adjusted downwards:
G a,n ＜G d,n +G D (6)。
the regulation state of the unit is judged according to the expected control time or tracking precision of each AGC controlled unit to determine whether to issue a new regulation instruction, the response period and the action characteristic of the unit are considered, and the problem that the safe and stable operation of the unit is influenced because the unit frequently increases and decreases the generating power caused by frequently issuing the instruction in a short time is avoided.
Because the astronomical clock frequency in a supervisory control and data acquisition (SCADA) system is faster than the refresh rate of tie line data, issuing a normal adjustment command after a fault may aggravate the cross-section out-of-limit degree. Therefore, when the frequency is out of limit, the AGC system stops 2 control cycles to issue a new command, and the section control function is enabled.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
While the present invention has been described with reference to the particular illustrative embodiments, it is to be understood that the invention is not limited to the disclosed embodiments, but is intended to cover various modifications, equivalent arrangements, and equivalents thereof, which may be made by those skilled in the art without departing from the spirit and scope of the invention as defined by the appended claims.
Claims (4)
1. A regulation standby sharing method suitable for different operation conditions of a power grid is characterized by comprising the following steps:
determining the expected active power deviation of each power grid control area based on the predetermined area control deviation of the power grid control area;
determining the adjustment standby sharing quantity of each power grid control area under different operation conditions according to the expected active power deviation of each power grid control area;
distributing the determined adjustment standby sharing quantity to each power grid control area so as to enable each power grid control area to realize standby sharing quantity adjustment;
the calculation method formula of the expected active power deviation of each power grid control area is as follows:
0≤R n T≤(G d,n -G a,n )
in the formula (I), the compound is shown in the specification,
the expected active power deviation amount of each power grid control area; e ACE,i Adopting regional control deviation under a frequency tie line power deviation mode for a power grid control region; n is the total number of AGC controlled units in the power grid control area; r is n Adjusting the speed of the nth AGC controlled unit in the power grid control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the power grid control area; Δ V d,i To predict the active deviation rate of change; g d,n Outputting the unit target of the nth AGC controlled unit in the power grid control area; g a,n The actual output of the nth AGC controlled unit in the power grid control area is obtained;
the calculation formula for considering the regional control deviation of the power grid control area after the adjustment of the standby sharing is as follows:
in the formula, B i Setting a frequency deviation coefficient of a power grid control area; f. of A The actual frequency of the power grid; f. of S Planning frequency, P, for the grid A For controlling the gridThe actual power flow of the district external tie line is summed; p is S A total plan value of an external tie line for a power grid control area; p co,i Planning correction quantity of the virtual tie line superposed in the power grid control area; i is the number of the power grid control area;
and verifying the determined adjustment standby sharing quantity, wherein the verification is realized by distributing the determined adjustment standby sharing quantity to each power grid control area, and the verification method is to judge whether the adjustment standby sharing quantity meets the following constraints:
1) And forming physical branch transmission constraint of the sub-section, wherein the expression is as follows:
wherein L is the number of physical branches contained in the trans-provincial conveying sub-section,
reverse quota for the l physical branch; f. of l The actual power flow of the first physical branch is obtained; f. of max,l Forward quota for the l-th physical branch; p co,h Adjusting standby sharing quantity on any external sub-section h for any power grid control area;
2) And restricting the adjustable range of the AGC unit, wherein the expression is as follows:
in the formula, N is the total number of AGC controlled units in the power grid control area, alpha nl For quasi-steady-state sensitivity of the unit n to the link l, G a,n Actual output of the unit;
3) The main hydropower delivery channel constraints are expressed as follows:
f m +(G max,n -G a,n )α nm ≤L max,m
in the formula, N r The number of main output sections selected for the interior of the power grid control area; alpha (alpha) ("alpha") nm The quasi-steady-state sensitivity of the unit n to the section m is obtained; k ml A power transmission distribution factor of the section m on the connecting line l; f. of m The actual tide of the section m is obtained; l is max,m Is a forward limit of section m, G max,n The upper limit of the adjustment of the unit n; g min,n The lower limit of the set n is adjusted; l is the total number of the connecting lines; m is the total number of sections contained in the power grid control area;
4) The sub-sections of different connecting lines are constrained, and the expression is as follows
In the formula:
is the reverse quota of the sub-section; k he Controlling power transmission distribution factors of the sub-sections h on other sub-sections e; s h The actual tidal current value of the section is obtained; s. the max,e The forward quota of the section is set;
5) Self-reserving standby constraint;
the working condition comprises a first operating condition, the first operating condition is a normal operating condition, the adjustment backup sharing quantity under the first operating condition comprises an adjustment backup sharing quantity of a group with frequency deviation and an adjustment backup sharing quantity of a group with the same frequency deviation,
the formula for determining the control area adjustment standby sharing quantity in the frequency deviation difference unit according to the expected active power deviation of each power grid control area is as follows:
wherein, P co,w Is different from the frequency deviationThe control area in the number group adjusts the spare sharing amount;
the expected active power deviation value of the control area in the frequency deviation signal group is obtained;
calculating the control area adjustment standby sharing quantity in the same group with the frequency deviation, and adopting an unbalance quantity equal proportion distribution mode, wherein the formula is as follows:
in the formula: p co,v Adjusting the amount of spare sharing for control areas in the same number group as the frequency deviation;
an expected amount of active power deviation for control zones within the same number of frequency deviation; v and W are respectively the number of control areas in the same or different sign groups with the frequency deviation;
the working condition comprises a second operation condition, the second operation condition is that the power grid frequency deviation is within a preset range after a fault occurs, the standby sharing amount is apportioned again by switching to the standby climbing rate proportion under the second operation condition, and the formula of the standby sharing correction amount of the control area in the same group with the frequency deviation after the fault is as follows:
of formula (II) to (III)' co,v Spare sharing correction quantity of the control area in the same group with the frequency deviation after the fault; r v For controlling the zone equivalent climbing rate, P co,v Adjusting the spare sharing quantity for the control areas in the same group with the frequency deviation, wherein V is the number of the control areas in the same group with the frequency deviation;
the working condition comprises a third operating condition, the third operating condition is the operating condition that the power grid frequency deviation is out of the preset range after the fault occurs, the power grid control area switches the regional control deviation of the power grid control area into a constant frequency control mode for calculation, and each power grid control area directly recovers the power grid frequency and does not participate in adjusting the standby sharing optimization distribution.
2. The method for sharing the adjustment reserve of the power grid under the different operating conditions according to claim 1, wherein the expected active power deviation of each power grid control area is determined according to the adjustment reserve condition of each power grid control area, and the calculation method formula is as follows:
0≤R n T≤(G d,n -G a,n )
in the formula (I), the compound is shown in the specification,
anticipating active power deviation amount for each power grid control area;
the regional control deviation of the standby shared power grid control area is considered and adjusted; n is the total number of AGC controlled units in the power grid control area; r n Adjusting the speed of the nth AGC controlled unit in the power grid control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the power grid control area; Δ V d,i To predict the active deviation rate of change; g d,n Outputting the target output of the nth AGC controlled unit in the power grid control area; g a,n And the actual output of the nth AGC controlled unit in the power grid control area.
3. An adjustment backup sharing system suitable for different operation conditions of a power grid is characterized in that the adjustment backup sharing method according to any one of claims 1-2 is applied, and comprises the following steps: the system comprises a power grid control area expected active power deviation determining module, a standby sharing amount adjusting calculation module, a standby sharing safety checking module and an instruction issuing module;
the power grid control area expected active power deviation determining module is used for determining the expected active power deviation of each power grid control area based on the predetermined area control deviation of the power grid control area;
the adjustment standby sharing quantity calculation module is used for determining adjustment standby sharing quantities of each power grid control area under different operation conditions according to the expected active power deviation of each power grid control area;
the standby sharing safety checking module is used for checking the determined adjusted standby sharing quantity;
the instruction issuing module is used for distributing the regulated standby sharing quantity after the verification is passed to each power grid control area so as to realize the regulation of the standby sharing quantity in each power grid control area;
the calculation method formula of the expected active power deviation of each power grid control area is as follows:
0≤R n T≤(G d,n -G a,n )
in the formula (I), the compound is shown in the specification,
the expected active power deviation amount of each power grid control area; e ACE,i Adopting regional control deviation under a frequency tie line power deviation mode for a power grid control region; n is the total number of AGC controlled units in the power grid control area; r n Adjusting the speed of the nth AGC controlled unit in the power grid control area; t is execution time delay; omega r,n Identifying the adjustment state of the nth AGC controlled unit in the power grid control area; Δ V d,i To predict the active deviation rate of change; g d,n Outputting the unit target of the nth AGC controlled unit in the power grid control area; g a,n The actual output of the nth AGC controlled unit in the power grid control area is obtained;
the calculation formula of the area control deviation of the power grid control area after the adjustment of the standby sharing is considered as follows:
in the formula, B i Setting a frequency deviation coefficient of a power grid control area; f. of A The actual frequency of the power grid; f. of S Planning frequency, P, for the grid A The actual load flow of the external connecting line is added for the power grid control area; p S A total plan value of an external tie line for a power grid control area; p co,i Planning correction quantity of the virtual tie line superposed in the power grid control area; i is the number of the power grid control area;
verifying the determined adjustment standby sharing quantity, wherein the verification is realized by distributing the determined adjustment standby sharing quantity to each power grid control area, and the verification method is to judge whether the adjustment standby sharing quantity meets the following constraints:
1) And forming physical branch transmission constraint of the sub-section, wherein the expression is as follows:
wherein L is the number of physical branches contained in the trans-provincial conveying sub-section,
the reverse quota is set for the first physical branch; f. of l The actual power flow of the first physical branch is obtained; f. of max,l The forward quota is the l physical branch; p is co,h Adjusting standby sharing quantity on any external sub-section h for any power grid control area;
2) And the adjustable range of the AGC unit is restricted, and the expression formula is as follows:
in the formula, N is a AGC controlled machine in a power grid control areaTotal number of groups, α nl For quasi-steady-state sensitivity of the unit n to the link l, G a,n Actual output of the unit is obtained;
3) The main water electricity delivery channel constraint is expressed as follows:
f m +(G max,n -G a,n )α nm ≤L max,m
in the formula, N r The number of main output sections selected for the interior of the power grid control area; alpha is alpha nm The quasi-steady-state sensitivity of the unit n to the section m is obtained; k ml A power transmission distribution factor of the section m on the connecting line l; f. of m The actual tide of the section m is obtained; l is max,m Is a forward limit of section m, G max,n The upper limit of the adjustment of the unit n; g min,n The lower limit of the set n is adjusted; l is the total number of the connecting lines; m is the total number of sections contained in the power grid control area;
4) The sub-sections of different connecting lines are constrained according to the expression formula
In the formula:
is the reverse quota of the sub-section; k he Controlling power transmission distribution factors of the sub-section h on other sub-sections e; s h The actual tidal current value of the section is obtained; s max,e The forward quota of the section is set;
5) Self reserves the standby constraint.
4. A regulation standby sharing method suitable for different operation conditions of a power grid is characterized by comprising the following steps:
the branch dispatching control center executes the regulation standby sharing method as claimed in any one of claims 1-2; each power grid control area receives and adjusts the standby sharing quantity, superposes the received adjusted standby sharing quantity on each power grid control area ACE, and sends an adjusting instruction to a regulating and managing power plant according to the new ACE to realize the adjustment of the standby sharing quantity of each power grid control area;
each power grid control area judges the unit regulation state according to the expected control time or the tracking precision to determine whether to issue a new regulation instruction, the expected control time is calculated according to the regulation rate set manually or sent by a power plant through remote measurement, and the calculation method comprises the following steps:
in the formula, S u Controlling time for anticipation; delta P r Is a new adjustment command increment; r is u The unit rate;
the tracking accuracy determination method comprises the following steps:
1) If the unit is required to be adjusted upwards:
G a,n >G d,n -G D
2) If the unit is required to be adjusted downwards:
G a,n <G d,n +G D
in the formula, G a,n For the actual output of the unit, G d,n Target output of the unit, G D Adjusting dead zones for the unit;
in the formula, P h,max Supporting a forward quota for regulating backup sharing;
supporting the reverse quota for regulating the backup share, P co,h And adjusting the standby sharing quantity on any external sub-section h for any power grid control area.
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