A deep peak regulation control method participated by an AGC unit

Abstract

This invention relates to the field of automatic generation control technology in power systems, and discloses a deep peak-shaving control method involving AGC (Automatic Generation Control) units. This invention acquires real-time operating status data of the units, calculates the unit's power level factor and main steam pressure deviation factor, and calculates a comprehensive operating condition coefficient by weighted summation of the two factors. This coefficient is used to assess the health of the unit's operating status and quantifies its operating condition. Based on the comprehensive operating condition coefficient, the invention dynamically allocates weights to deep peak-shaving demand commands issued by the grid dispatch system and real-time adjustment commands issued by the automatic generation control system, calculates the single-power deviation between the two commands, and then generates a final execution command containing the final power generation setpoint allocated to the unit. This command is then sent to the unit's distributed control system to execute deep peak-shaving, realizing dynamic allocation of power generation to the unit under different operating conditions, thus improving the economic efficiency and safety of unit operation.

Description

Technical Field

[0001] This invention relates to the field of automatic generation control technology for power systems, specifically a deep peak shaving control method involving AGC (Automatic Generation Control) units. Background Technology

[0002] With the continuous grid connection of large-scale, fluctuating renewable energy sources such as wind and solar power, the peak-to-valley difference in the net load curve of the power system is widening, posing unprecedented challenges to the system's peak-shaving capacity. Deep peak shaving, which requires conventional thermal power units to reduce their active power to levels far below their minimum design technical output, has become a key means of absorbing excess renewable energy power during off-peak periods.

[0003] Currently, existing technologies generally lack quantitative assessment of the overall operating status of generating units. The deep peak-shaving plan commands issued by the dispatching system (typically slow-changing) and the real-time adjustment commands generated by the AGC system (requiring rapid response) are essentially two different sources of commands with different time scales and control objectives. Existing technologies typically simply superimpose them or select one for execution, failing to dynamically adjust based on the real-time operating status of the unit. This limits the unit's regulation performance when operating conditions are relatively good, and may not provide sufficient protection when operating conditions deteriorate. The failure to achieve intelligent fusion and dynamic balancing of the two commands based on the unit's real-time operating health status makes it difficult to simultaneously achieve the economic efficiency, safety, and grid support capabilities of unit operation under the extreme condition of deep peak shaving. Summary of the Invention

[0004] To address the shortcomings of existing technologies, this invention provides a deep peak-shaving control method involving AGC (Automatic Generation Control) units. This method has the advantages of improving the economy and safety of unit operation by acquiring real-time operating status data of the units, evaluating the comprehensive operating condition coefficient, assessing the overall operating status of the units, dynamically allocating weights to the upper-level scheduling instructions based on the comprehensive operating condition coefficient, and obtaining the final execution instructions of the units. This solves the aforementioned technical problems.

[0005] To achieve the above objectives, the present invention provides the following technical solution: a deep peak-shaving control method involving AGC units, comprising the following steps:

[0006] S1: Receives deep peak shaving demand instructions from the power grid dispatching system and real-time adjustment instructions from the automatic generation control system.

[0007] S2: Real-time acquisition of unit operating status data and determination of the unit's current operating mode;

[0008] S3: Based on the operating mode, dynamically assign weights to the deep peak shaving demand command and the real-time adjustment command, and determine the final execution command;

[0009] S4: Issues the final execution command to the distributed control system of the unit for execution, and feeds back the actual power generation and operating status of the unit to the grid dispatch system.

[0010] As a preferred embodiment of the present invention, the deep peak-shaving demand instruction from the power grid dispatching system in S1 includes the planned power generation allocated to the generating unit, and the real-time adjustment instruction from the automatic generation control system in S1 includes the real-time adjusted power generation allocated to the generating unit.

[0011] The operating status data of the S2 unit includes the unit's real-time power generation and the boiler's real-time main steam pressure.

[0012] As a preferred technical solution of the present invention, the step of S2 determining the current operating mode of the unit includes the following steps:

[0013] Step A1: Evaluate the power level factor based on the collected unit operating status data. and main steam pressure deviation factor ;

[0014] Step A2: Calculate the power level factor obtained in step A1. and main steam pressure deviation factor The weighted summation yields the comprehensive working condition coefficient. ;

[0015] Step A3: Based on the comprehensive operating condition coefficient obtained in step A2 The operating mode of the generating unit is determined as follows:

[0016] When the comprehensive working condition coefficient When the second safety threshold is greater than or equal to the first safety threshold, it indicates that the unit is in excellent condition, and the operating condition is determined to be in free adjustment mode; when the second safety threshold is less than or equal to the comprehensive operating condition coefficient... When the value is less than the first safety threshold, it indicates that the unit is operating close to its limit, and the operating condition is determined to be a restricted control mode; when the comprehensive operating condition coefficient is... When the value is less than the second safety threshold, it indicates that the unit is operating close to its limit and the safety margin is extremely small. Stable operation is the primary goal, and this is determined to be the stability maintenance mode.

[0017] As a preferred embodiment of the present invention, step A1 power level factor The expression is as follows: , in, This indicates the real-time power generation capacity of the generating unit; This indicates the optimal power setting under the current operating conditions; To ensure a wide range of safe power generation capacity, , To achieve maximum safe power generation, Minimum safe power generation capacity; It represents the absolute value.

[0018] As a preferred embodiment of the present invention, step A1, main steam pressure deviation factor, is described. The expression is as follows: , in, This indicates the real-time main steam pressure of the boiler; Indicates standard main steam pressure; Indicates the standard deviation of pressure operation; It is an exponential function.

[0019] As a preferred technical solution of the present invention, step A2, which involves the comprehensive operating condition coefficient, is described. The expression is as follows: , in, Indicates the power level factor; This represents the main steam pressure deviation factor; This represents the weighting coefficient.

[0020] As a preferred embodiment of the present invention, S3 determining the final execution instruction includes the following steps:

[0021] Step B1: Dynamically assign weights to deep peak shaving demand commands and real-time adjustment commands;

[0022] Step B2: Generate the final execution instruction, the expression of which is as follows: , in, This indicates the final power generation setpoint; and These represent the weights of deep peak shaving demand instructions and real-time adjustment instructions, respectively. This indicates the real-time power generation capacity of the generating unit; This indicates the deviation from the planned power generation capacity; This indicates the deviation in real-time adjustment of power generation.

[0023] As a preferred embodiment of the present invention, the deviation of the planned power generation is... The expression is as follows: , in, Indicates planned power generation capacity; This indicates the real-time power generation capacity of the generator unit.

[0024] As a preferred technical solution of the present invention, the real-time adjustment of the deviation of the power generation is... The expression is as follows: , in, This indicates real-time adjustment of power generation; This indicates the real-time power generation capacity of the generator unit.

[0025] As a preferred embodiment of the present invention, the relevant expression for the dynamic weight allocation of the deep peak shaving demand instruction and the real-time adjustment instruction in step B1 is as follows: , in, Indicates the weight of deep peak shaving demand instructions; This indicates that the command weights are adjusted in real time. Indicates the slope coefficient; Indicates the comprehensive operating condition coefficient; Indicates the offset coefficient; This represents an exponential function.

[0026] Compared with the prior art, the present invention provides a deep peak shaving control method involving AGC units, which has the following beneficial effects:

[0027] This invention acquires real-time operating status data of the generating unit, calculates the unit's power level factor and main steam pressure deviation factor, and calculates a comprehensive operating condition coefficient by weighted summation of the two factors. This coefficient is used to assess the health of the unit's operating status and quantifies the unit's operating status. Based on the comprehensive operating condition coefficient, the invention dynamically allocates weights to the deep peak-shaving demand command issued by the power grid dispatching system and the real-time adjustment command issued by the automatic generation control system. It also calculates the single power deviation between the two commands and generates a final execution command containing the final power generation setpoint allocated to the unit. This command is then sent to the unit's distributed control system to execute deep peak-shaving. This achieves dynamic allocation of power generation to the unit under different operating conditions, improving the unit's economic efficiency and safety. Attached Figure Description

[0028] Figure 1 This is a schematic diagram of the process of the present invention. Detailed Implementation

[0029] The technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0030] Please see Figure 1 A deep peak-shaving control method involving AGC units includes the following steps:

[0031] S1: Receives deep peak shaving demand instructions from the power grid dispatching system and real-time adjustment instructions from the automatic generation control system (AGC). The deep peak shaving demand instructions from the power grid dispatching system include the planned power generation allocated to the generating units, and the real-time adjustment instructions from the automatic generation control system include the real-time adjusted power generation allocated to the generating units.

[0032] Deep peak shaving demand instructions from the power grid dispatching system explicitly require specific generating units to reduce their power to a certain low level during a specific period. The purpose is to make room for the absorption of renewable energy sources such as wind power and photovoltaics, which have zero marginal cost, and to maximize the economic benefits for the whole society. This instruction itself is also smooth and changes slowly, usually in 15-minute or 1-hour periods, with a planned power generation set for each period. It does not make second-level adjustments based on the instantaneous state of the power grid at that time. The core objective of the Automatic Generation Control (AGC) system is to maintain the power grid frequency and tie-line exchange power near the rated value. Its real-time adjustment instructions are issued in response to the real-time power imbalance of the power grid. This instruction will change rapidly and continuously according to fluctuations that may occur at any time, such as user electricity demand, renewable energy power generation, and large generator failures. Therefore, the real-time adjustment instructions of the AGC system are often adjusted at the second level.

[0033] S2: Real-time acquisition of unit operating status data and determination of the current operating mode of the unit. The unit operating status data includes the unit's real-time power generation and the boiler's real-time main steam pressure.

[0034] Determining the current operating mode of the unit includes the following steps:

[0035] Step A1: Evaluate the power level factor based on the collected unit operating status data. and main steam pressure deviation factor ;

[0036] Power level factor The expression is as follows: , in, This indicates the real-time power generation capacity of the generating unit; This indicates the optimal power setting under the current operating conditions; To ensure a wide range of safe power generation capacity, , To achieve maximum safe power generation, Minimum safe power generation capacity; Represents absolute value; numerator term Quantified real-time power generation Deviation from optimal operating power The degree of, denominator term This represents the maximum adjustment range currently available. The range of values ​​is When the real-time power generation The closer to optimal power And the wider the adjustable range, the better. hour, The closer it is to 1, the better the generating capacity of the unit. Deviation or When it narrows, The decrease directly reflects the shrinking adjustment margin available to the unit;

[0037] Main steam pressure deviation factor The expression is as follows: , in, This indicates the real-time main steam pressure of the boiler; Indicates standard main steam pressure; Indicates the standard deviation of pressure operation; It is an exponential function; the closer the main steam pressure is to the standard value... , The closer the value is to 1, the more stable the boiler's heat storage and the stronger the unit's ability to respond to AGC commands. The range of values ​​is , The closer the value is to 1, the more stable the main steam pressure in the boiler is, and the stronger the dynamic ability of the unit to respond to external power commands; the closer the value is to 0, the greater the deviation of the main steam pressure in the boiler is, the more fragile the boiler energy balance is, and the more strictly the unit's adjustment actions need to be limited to ensure safety.

[0038] Step A2: Calculate the power level factor obtained in step A1. and main steam pressure deviation factor The weighted summation yields the comprehensive working condition coefficient. Its expression is as follows: , in, Indicates the power level factor; This represents the main steam pressure deviation factor; Indicates the weighting coefficient; comprehensive working condition coefficient. Used to reflect the overall operating status of the unit The higher the value, the healthier the overall operating status of the unit and the stronger its ability to respond to external power commands; conversely, the lower the value, the more fragile the unit is and the more conservative control strategies need to be adopted.

[0039] Step A3: Based on the comprehensive operating condition coefficient obtained in step A2 The operating mode of the generating unit is determined as follows:

[0040] When the comprehensive working condition coefficient When the second safety threshold is greater than or equal to the first safety threshold, it indicates that the unit is in excellent condition, and the operating condition is determined to be in free adjustment mode; when the second safety threshold is less than or equal to the comprehensive operating condition coefficient... When the value is less than the first safety threshold, it indicates that the unit is operating close to its limit, and the operating condition is determined to be a restricted control mode; when the comprehensive operating condition coefficient is... When the value is less than the second safety threshold, it indicates that the unit is operating close to its limit and the safety margin is extremely small. Stable operation should be the primary goal, and this is the stability maintenance mode.

[0041] S3: Based on the operating mode, dynamically assign weights to deep peak shaving demand commands and real-time adjustment commands, and determine the final execution command, including the following steps:

[0042] Step B1: Dynamically assign weights to deep peak shaving demand commands and real-time adjustment commands. The relevant expressions are as follows: , in, Indicates the weight of deep peak shaving demand instructions; This indicates that the command weights are adjusted in real time. This represents the slope coefficient, used to control the severity of weight shifting; Indicates the comprehensive operating condition coefficient; This represents the offset coefficient, used to determine the threshold for weight transfer; Represents an exponential function; The corresponding formula is an S-shaped function with a range of . When the comprehensive working condition coefficient When the temperature is low, meaning the overall operating condition of the unit is poor, When the comprehensive operating condition factor is close to 1, priority is given to tracking slowly changing deep peak-shaving demand commands to maintain stability; A higher level indicates that the overall operating condition of the unit is better. Reduced to make room for rapid real-time adjustment commands issued by AGC;

[0043] Step B2: Generate the final execution instruction, the expression of which is as follows: , in, This indicates the final power generation setpoint; and These represent the weights of deep peak shaving demand instructions and real-time adjustment instructions, respectively. This indicates the real-time power generation capacity of the generating unit; This indicates the deviation from the planned power generation capacity; This indicates the deviation in real-time adjustment of power generation;

[0044] Deviation of planned power generation The expression is as follows: , in, Indicates planned power generation capacity; This indicates the real-time power generation capacity of the generating unit;

[0045] Real-time adjustment of power generation deviation The expression is as follows: , in, This indicates real-time adjustment of power generation; This indicates the real-time power generation capacity of the generating unit;

[0046] S4: Will include the final power generation setpoint The final execution command is sent to the unit's distributed control system (DCS) for execution, and the actual power generation of the unit is recorded. and the comprehensive operating condition coefficient that reflects the operating status of the unit The operating conditions of the generating units are fed back to the power grid dispatching system, forming a closed loop. This provides dispatchers with real-time information on the adjustable capabilities of the generating units, thereby improving the transparency and intelligence of the entire power grid dispatching system.

[0047] Although embodiments of the invention have been shown and described, it will be understood by those skilled in the art that various changes, modifications, substitutions and alterations can be made to these embodiments without departing from the principles and spirit of the invention, the scope of which is defined by the appended claims and their equivalents.

Claims

1. A deep peak-shaving control method involving AGC units, characterized in that: Includes the following steps: S1: Receives deep peak shaving demand instructions from the power grid dispatching system and real-time adjustment instructions from the automatic generation control system. S2: Real-time acquisition of unit operating status data and determination of the unit's current operating mode; S3: Based on the operating mode, dynamically assign weights to the deep peak shaving demand command and the real-time adjustment command, and determine the final execution command; S4: Issues the final execution command to the distributed control system of the unit for execution, and feeds back the actual power generation and operating status of the unit to the grid dispatch system.

2. The deep peak-shaving control method involving AGC units according to claim 1, characterized in that: The deep peak-shaving demand instruction from the grid dispatching system S1 includes the planned power generation allocated to the generating units, and the real-time adjustment instruction from the automatic generation control system S1 includes the real-time adjusted power generation allocated to the generating units. The operating status data of the S2 unit includes the unit's real-time power generation and the boiler's real-time main steam pressure.

3. The deep peak-shaving control method involving AGC units according to claim 1, characterized in that: The steps for S2 to determine the current operating mode of the unit include: Step A1: Evaluate the power level factor based on the collected unit operating status data. and main steam pressure deviation factor ; Step A2: Calculate the power level factor obtained in step A1. and main steam pressure deviation factor The weighted summation yields the comprehensive working condition coefficient. ; Step A3: Based on the comprehensive operating condition coefficient obtained in step A2 The operating mode of the generating unit is determined as follows: When the comprehensive working condition coefficient When the second safety threshold is greater than or equal to the first safety threshold, it indicates that the unit is in excellent condition, and the operating condition is determined to be in free adjustment mode; when the second safety threshold is less than or equal to the comprehensive operating condition coefficient... When the value is less than the first safety threshold, it indicates that the unit is operating close to its limit, and the operating condition is determined to be a restricted control mode; when the comprehensive operating condition coefficient is... When the value is less than the second safety threshold, it indicates that the unit is operating close to its limit and the safety margin is extremely small. Stable operation is the primary goal, and this is determined to be the stability maintenance mode.

4. The deep peak-shaving control method involving AGC units according to claim 3, characterized in that: The power level factor in step A1 The expression is as follows: ， in, This indicates the real-time power generation capacity of the generating unit; This indicates the optimal power setting under the current operating conditions; To ensure a wide range of safe power generation capacity, , To achieve maximum safe power generation, Minimum safe power generation capacity; It represents the absolute value.

5. The deep peak-shaving control method involving AGC units according to claim 3, characterized in that: Step A1 Main steam pressure deviation factor The expression is as follows: ， in, This indicates the real-time main steam pressure of the boiler; Indicates standard main steam pressure; Indicates the standard deviation of pressure operation; It is an exponential function.

6. The deep peak-shaving control method involving an AGC unit according to claim 3, characterized in that: Step A2 Comprehensive Working Condition Coefficient The expression is as follows: ， in, Indicates the power level factor; This represents the main steam pressure deviation factor; This represents the weighting coefficient.

7. The deep peak-shaving control method involving an AGC unit according to claim 1, characterized in that: The S3 step of determining the final execution instruction includes the following steps: Step B1: Dynamically assign weights to deep peak shaving demand commands and real-time adjustment commands; Step B2: Generate the final execution instruction, the expression of which is as follows: ， in, This indicates the final power generation setpoint; and These represent the weights of deep peak shaving demand instructions and real-time adjustment instructions, respectively. This indicates the real-time power generation capacity of the generating unit; This indicates the deviation from the planned power generation capacity; This indicates the deviation in real-time adjustment of power generation.

8. The deep peak-shaving control method involving an AGC unit according to claim 7, characterized in that: The deviation of the planned power generation The expression is as follows: ， in, Indicates planned power generation capacity; This indicates the real-time power generation capacity of the generator unit.

9. A deep peak-shaving control method involving an AGC unit according to claim 7, characterized in that: The deviation of the real-time adjustment of power generation The expression is as follows: ， in, This indicates real-time adjustment of power generation; This indicates the real-time power generation capacity of the generator unit.

10. A deep peak-shaving control method involving an AGC unit according to claim 7, characterized in that: The relevant expression for dynamically allocating weights between the deep peak shaving demand instruction and the real-time adjustment instruction in step B1 is as follows: ， in, Indicates the weight of deep peak shaving demand instructions; This indicates that the command weights are adjusted in real time. Indicates the slope coefficient; Indicates the comprehensive operating condition coefficient; Indicates the offset coefficient; This represents an exponential function.

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