A method of management for the electric power of cogeneration systems

Abstract

A cogeneration power management method is applicable to managing the electrical output status and steam output status of multiple cogeneration units installed in a cogeneration field, and is implemented by a computing device. For each cogeneration unit, based on electricity consumption information, steam consumption information, electricity price trading information, energy storage battery discharge power information, and cogeneration unit information, a nonlinear programming method is used to obtain the power generation and steam output corresponding to the cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window.

Description

Technical Field

[0001] This invention relates to an energy management method, and more particularly to an energy management method for cogeneration units. Prior Technology

[0002] Traditional thermal power generation, which uses fossil fuels such as coal, oil, or natural gas, cannot completely convert heat energy into electricity during fuel combustion, resulting in significant heat loss and cost waste. Therefore, many industrial processes are now adopting the concept of cogeneration, which captures the heat energy lost during traditional thermal power generation for industrial manufacturing or waste heat power generation, thereby reducing carbon emissions from power generation systems and improving the efficiency of energy conversion.

[0003] In a typical cogeneration plant, in addition to multiple cogeneration units, there may also be green energy power generation systems such as solar, biogas, and biomass. In industrial processes, there will be multiple production lines with electricity and steam load requirements. The cogeneration plant may also have an electricity purchase and sale contract with the commercial power grid to sell back excess electricity. In order to meet the different production needs of the production lines every day, it is extremely important to continuously adjust the allocation of various heterogeneous and distributed power resources in the cogeneration plant while meeting the basic electricity and heat needs of the production lines, so as to reduce the factory's electricity costs. Summary of the Invention

[0004] Therefore, the objective of this invention is to provide a method for managing the combined steam and electricity power consumption of multiple combined steam and electricity generating units.

[0005] Therefore, the cogeneration power management method of the present invention is applicable to managing the electrical output status and steam output status of multiple cogeneration units installed in a cogeneration field, and is implemented by a computing device. The cogeneration power management method includes a step (A).

[0006] In step (A), for each cogeneration unit, based on electricity consumption information related to power consumption, steam consumption information related to steam consumption, electricity purchase and sale information related to the power grid, energy storage battery discharge power information related to the discharge of an energy storage battery, and cogeneration unit information related to the steam production and power generation of the cogeneration unit, a nonlinear programming method is used to obtain the power generation and steam output corresponding to each time window of the cogeneration unit in a scheduling cycle, as well as the grid purchase power and grid sale power corresponding to the cogeneration field in each time window.

[0007] The advantages of this invention are: for each cogeneration unit, the nonlinear programming is used to obtain the power generation and steam output of each time window corresponding to the cogeneration unit and the scheduling period, so as to dynamically adjust the power output state and steam output state of the cogeneration unit, thereby reducing the total electricity cost of the cogeneration units in the cogeneration field. Simple Explanation of the Diagram

[0008] Other features and effects of the present invention will be clearly presented in the embodiments with reference to the drawings, wherein: Figure 1 is a block diagram illustrating a computing device for implementing the cogeneration power management method of the present invention; Figure 2 is a flowchart illustrating the first embodiment of the cogeneration power management method of the present invention; and Figure 3 is a schematic diagram illustrating multiple power dispatching constraints of the cogeneration power management method of the present invention; and Figure 4 is a flowchart illustrating the fourth embodiment of the cogeneration power management method of the present invention. Implementation

[0009] Before the invention is described in detail, it should be noted that similar elements are represented by the same numbers in the following description.

[0010] Referring to Figure 1, a first embodiment of the cogeneration power management method of the present invention is applicable to managing the electrical output status and steam output status of multiple cogeneration units (not shown) installed in a cogeneration field, and is implemented by a computing device 1. The computing device 1 includes a storage unit 11 storing electricity and price trading information related to the purchase and sale of electricity with a power grid (not shown), energy storage battery discharge power information related to the discharge of an energy storage battery (not shown), and cogeneration unit information related to the steam and electricity generation of the cogeneration units, and a processing unit 12 electrically connected to the storage unit 11.

[0011] It should be noted that, in this first embodiment, the cogeneration field has I cogeneration units, and one scheduling cycle of these I cogeneration units has T time panes. The power purchase and sale contracts with the power grid are composed of electricity and electricity price trading information for K electricity consumption time intervals. This electricity and electricity price trading information includes the grid purchase price. Electricity sales price Electricity purchase and sale selection coefficient , Contracted power purchase capacity during the k-th electricity consumption time interval The electricity purchase price during the k-th electricity consumption time interval Overdue determination coefficient in the k-th electricity consumption time interval Power purchased by the grid in the j-th time pane (of which 1) Maximum grid power output Maximum power purchased by the grid The energy storage battery discharge power information includes the discharge power of the energy storage battery in the t-th time pane. The information on the cogeneration units includes the minimum generating capacity of the cogeneration units in the t-th time pane. The maximum power generation of the combined heat and power generating units in the t-th time window. The maximum power generation change of the combined steam and electric power generation unit in the t-th time window. The minimum steam output of the i-th combined steam and electric generator unit in the t-th time window. The maximum steam output of the i-th combined steam and electric generator unit in the t-th time window. The change in steam production of the combined steam and electric power unit in the t-th time pane. Where t is a positive integer from 1 to T, i is a positive integer from 1 to I, and k is a positive integer from 1 to K. It should be noted that in this embodiment, each time pane is 30 minutes, so there are a total of 48 time panes in a day (i.e., T is 48). These K electricity consumption intervals can be distinguished according to the peak, half-peak, and off-peak electricity consumption periods in a day, but are not limited to this.

[0012] Referring to Figures 1 and 2, the first embodiment of the cogeneration power management method of the present invention can be described in detail using the following steps.

[0013] In step 21, the processing unit 12 obtains power consumption information related to the total power consumption of the cogeneration field. It is noteworthy that, in this first embodiment, the power consumption information includes the total power consumption of loads in the cogeneration field, such as lighting, air conditioning, computers, and the cogeneration units, in the t-th time pane. , where t is every positive integer from 1 to T. The total power consumption can be obtained using a power consumption prediction model for predicting the total power consumption of the cogeneration field. The power consumption prediction model can obtain the total power consumption based on multiple historical power consumption data, power price information, energy storage battery discharge power information, and cogeneration unit information, but is not limited to these.

[0014] In step 22, the processing unit 12 obtains steam consumption information related to the steam consumption of the cogeneration unit. It is noteworthy that, in this first embodiment, the steam consumption information includes the steam consumption of the cogeneration unit in the t-th time pane. , where t is every positive integer from 1 to T. The steam consumption can be obtained using a steam consumption prediction model for predicting the expected steam consumption of such cogeneration units. The steam consumption prediction model can obtain the steam consumption based on multiple historical steam consumption data, electricity price information, energy storage battery discharge power information, and cogeneration unit information, but is not limited to these.

[0015] In step 23, for each cogeneration unit, the processing unit 12, based on the electricity consumption information, steam consumption information, electricity price trading information, energy storage battery discharge power information, and cogeneration unit information, uses a nonlinear programming method to obtain the power generation and steam output corresponding to the cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window. In this embodiment, the objective function of the nonlinear programming can be expressed as the following formula (1), and the multiple constraints satisfied by the objective function can be expressed as the following constraints 1 to 9: ,…(1) in, , , ,in , ,in , , ,when Greater than hour, , Restriction 1: ,in, , Restriction 2: ,in, , Restriction 3: , Restriction 4: , Restriction 5: , Restriction 6: , Restriction 7: , Restriction 8: , Restriction 9: , in, Let i be the power generation cost of the i-th combined heat and power unit in the t-th time window. The total electricity purchase cost of the combined steam and electric power units in the t-th time pane is... The total electricity sales revenue of the combined heat and power generating units in the t-th time pane is... For the total cost of contracted capacity, Let i be the power generation of the i-th combined heat and power unit in the t-th time window. Let i be the steam output of the i-th combined steam generator unit in the t-th time window. , , Let be the coefficients of the steam and electricity of the i-th combined steam and electricity generator unit for this cost function, and , , It is obtained based on a linear fit. For the combined steam-electric generating units, the grid power purchased by the units in the t-th time pane. Let be the grid power sold by the combined steam and electric power generating units in the t-th time pane, and the power purchase / sale selection factor. , It can be 1 or 0, when When it is 1 It is 0, and when When it is 0 =1, To incur penalties for exceeding the limit by no more than 10% during the k-th electricity usage time interval, The penalty cost for exceeding the limit by more than 10% in the k-th electricity usage time interval. The maximum grid power purchase during the T time windows of the scheduling period. Let the power loss of the combined steam and electric power unit be the power consumption in the t-th time window. Let the power generation of the combined steam and electric power unit be the power output in the t-th time window. Let be the steam consumption loss of the combined steam and electricity generator unit in the t-th time window. Let the steam output of the combined steam and electric power unit be the steam output in the t-th time window. The conversion factor for steam to generate electricity. Let be the steam production rate of the i-th cogeneration unit in the t-th time pane, where 0.5 represents that each time pane in this embodiment is 30 minutes (0.5 hours), and 0.03 represents the proportion of total power loss. For I cogeneration units in T time panes... and This refers to the power generation capacity and the steam output. The combined steam and power generating unit operates within T time panes. and That is, the power purchased by such power grid and the power sold by such power grid.

[0016] Referring to Figure 3, in this first embodiment, for each cogeneration unit, the nonlinear programming must also satisfy a first power dispatch constraint, a second power dispatch constraint, and a third power dispatch constraint related to the power generation and steam output of the corresponding cogeneration unit. The first power dispatch constraint indicates that when the cogeneration unit is at maximum fuel consumption and the steam output is increased, the power generation decreases. The second power dispatch constraint indicates that when the cogeneration unit is at maximum steam output and the power generation decreases, fuel consumption decreases. The third power dispatch constraint indicates that when the cogeneration unit is at minimum fuel consumption and the steam output is increased, the power generation decreases. The first, second, and third power dispatch constraints can be expressed as follows: First power dispatching constraint: Second power dispatching constraint: Third power dispatching restrictions: In Figure 3, line segment AB illustrates that when the cogeneration unit is at its maximum fuel consumption and the steam output increases, the power generation decreases. Point A represents the power generation when the cogeneration unit is at its maximum fuel consumption and the steam output is 0, and point B represents the power generation when the cogeneration unit is at its maximum fuel consumption and the steam output is at its maximum. This represents the power generation capacity of the combined heat and power unit when it is at point A. This represents the power generation capacity of the combined heat and power unit when it is at point B. This represents the steam output when the combined steam and electric power unit is at point A. Let B be the steam output of the combined steam generator unit. Line segment BC indicates the decrease in fuel consumption when the combined steam generator unit is at its maximum steam output and the power generation is reduced. Point C represents the power generation when the combined steam generator unit is at its minimum fuel consumption and the steam output is maximum. This represents the power generation capacity of the combined heat and power unit when it is at point C. Let C represent the steam output of the combined steam generator unit. Line segment CD illustrates the decrease in power generation as the combined steam generator unit operates at minimum fuel consumption and the steam output increases. Point D represents the power generation when the combined steam generator unit operates at minimum fuel consumption and the steam output is zero. This represents the power generation capacity of the combined heat and power unit when it is at point D. This represents the steam output when the combined steam and electric power unit is at point D.

[0017] A second embodiment of the cogeneration power management method of the present invention is implemented by the computing device 1 shown in FIG1. ​​The storage unit 11 stores, in addition to the energy storage battery discharge power information, the cogeneration unit information, and the electricity price trading information, ancillary service information related to the ancillary services of the cogeneration units. For each cogeneration unit, the processing unit 12 executes steps 21-22 to obtain the electricity consumption information and steam consumption information corresponding to that cogeneration unit. Based on the electricity consumption information, steam consumption information, energy storage battery discharge power information, cogeneration unit information, electricity price trading information, and ancillary service information, it uses another nonlinear programming method to obtain the power generation, steam output, and ancillary service power generation corresponding to the cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window.

[0018] It is worth noting that, in this second embodiment, the ancillary service information includes the ancillary service quality rate of the cogeneration units in the t-th time pane. The power dispatch cost of the combined steam and electric power unit in the t-th time pane. The settlement price in the t-th time pane The day-ahead electricity price in the t-th time pane The actual electrical energy in the t-th time pane Ancillary service bid capacity in the t-th time pane The maximum power generation capacity of these combined steam and electric power units The maximum power generation of these combined steam and electric power units varies , where t is every positive integer from 1 to T.

[0019] It should be noted that, in this second embodiment, in addition to satisfying the constraints 1-9, the first power dispatch constraint, the second power dispatch constraint, and the third power dispatch constraint, the other objective function of the other nonlinear programming must also satisfy constraint 10 and constraint 11. The other objective function can be expressed as the following formula (2), and constraint 10 and constraint 11 can be expressed as follows: …(2) in, ,in , , , Restriction 10: , Restriction 11: , in, For the ancillary service revenue of the combined steam and electricity generator units in the t-th time pane, For the ancillary service capacity cost of the combined heat and power generating units in the t-th time pane, For the auxiliary service power generation of the i-th combined heat and power unit in the t-th time window, Let the power dispatch cost of the combined steam and electric power unit in the t-th time pane be... This refers to the total number of cogeneration units used to support ancillary services among these cogeneration units.

[0020] Referring to Figure 4, a third embodiment of the cogeneration power management method of the present invention is implemented by the computing device 1 shown in Figure 1. The storage unit 11 stores information on the discharge power of the energy storage battery, the cogeneration unit information, the electricity price trading information, and the ancillary service information, as well as a carbon emission coefficient converted from power generation cost. For each cogeneration unit, the processing unit 12 executes steps 21-22 to obtain the electricity consumption information and steam consumption information corresponding to that cogeneration unit. Based on the electricity consumption information, steam consumption information, energy storage battery discharge power information, cogeneration unit information, electricity price trading information, ancillary service information, and the carbon emission coefficient converted from power generation cost, it uses another nonlinear programming method to obtain the power generation, steam output, and ancillary service power generation corresponding to that cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window.

[0021] It should be noted that, in this third embodiment, the other objective function of the other nonlinear programming must satisfy the following constraints 1~11, the first power dispatch constraint, the second power dispatch constraint, and the third power dispatch constraint. The other objective function can be expressed as the following formula (3): …(3) in, ,in , , in, Let i be the carbon emission cost of the i-th combined heat and power unit in the t-th time window. Let i be the carbon emissions of the i-th combined heat and power unit in the t-th time window. Let the carbon emissions from electricity purchases be the amount of carbon emissions in the t-th time pane. The figure is a coefficient for converting power generation costs into carbon emission coefficients, where 300 is the purchase price per ton of carbon, and 0.509 is a coefficient for converting the power purchased from the grid by an energy bureau into carbon emission coefficients.

[0022] A fourth embodiment of the cogeneration power management method of the present invention is implemented by the computing device 1 shown in FIG. 1. The storage unit 11 stores the discharge power information of the energy storage battery, the information of the cogeneration unit, the electricity price trading information, the power generation cost conversion to carbon emission coefficient, and ancillary service information. For each cogeneration unit, after the processing unit 12 executes steps 31-32 as in steps 21-22 to obtain the electricity consumption information and the steam consumption information corresponding to the cogeneration unit, the processing unit 12 further executes steps 33-34 to obtain solar power generation information and biogas power generation information. In step 35, the processing unit 12, based on the electricity consumption information, steam consumption information, energy storage battery discharge power information, cogeneration unit information, electricity price trading information, ancillary service information, the conversion of power generation cost to carbon emission coefficient, solar power generation information, and biogas power generation information, uses another nonlinear programming to obtain the power generation, steam output, and ancillary service power generation corresponding to the cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window. The solar power generation information includes the solar power generation of the solar modules (not shown) installed in the cogeneration field in the t-th time window. The biogas power generation information includes the biogas power generation capacity of the biogas module (not shown) installed in the cogeneration field at the t-th time window. Where t is every positive integer from 1 to T. The solar power generation can be obtained using a solar power generation prediction model for predicting the expected power generation of the solar module, and the biogas power generation can be obtained using a biogas power generation prediction model for predicting the expected power generation of the biogas module. The solar power generation prediction model can obtain the solar power generation based on multiple historical solar power generation data and multiple weather forecast data, and the biogas power generation prediction model can obtain the biogas power generation based on multiple historical biogas power generation data, but is not limited to these.

[0023] It should be noted that, in this fourth embodiment, the other objective function of the other nonlinear programming is the objective function of formula (3), and it must satisfy all constraints except constraint 1, the first power dispatch constraint, the second power dispatch constraint, and the third power dispatch constraint, and satisfy constraint 12, as shown in the following formula: Restriction 12: ,in, .

[0024] In summary, the cogeneration power management method of the present invention, for each cogeneration unit, utilizes nonlinear programming to obtain the power generation, steam output, and ancillary service power generation of each time window corresponding to the cogeneration unit and the scheduling cycle, so as to dynamically adjust the power output state and steam output state of the cogeneration unit, thereby reducing the total electricity cost of such cogeneration units in the cogeneration field, thus effectively achieving the purpose of the present invention.

[0025] However, the above description is merely an embodiment of the present invention and should not be construed as limiting the scope of the present invention. Any simple equivalent changes and modifications made in accordance with the scope of the patent application and the contents of the patent specification of the present invention shall still fall within the scope of the patent of the present invention.

[0026] 1: Arithmetic unit 11: Storage Unit 12: Processing Unit Steps 21-23 Steps 31-35 A: Power generation capacity B: Power generation capacity C: Power generation D: Power generation

Claims

1. A cogeneration power management method, applicable to managing the power output status and steam output status of multiple cogeneration units installed in a cogeneration field, and implemented by a computing device, the cogeneration power management method comprising the following steps: (A) For each cogeneration unit, based on power consumption information related to power consumption, steam consumption information related to steam consumption, electricity purchase and sale information related to a power grid, energy storage battery discharge power information related to energy storage battery discharge, and cogeneration unit information related to steam generation and power generation of the cogeneration unit, a nonlinear programming method is used to obtain the power generation and steam output corresponding to each time window of the cogeneration unit in a scheduling cycle, as well as the power grid purchase and power grid sale power of the cogeneration field in each time window.

2. The cogeneration power management method as described in claim 1, wherein, In step (A), the objective function of the nonlinear programming and the multiple constraints satisfied by the objective function can be expressed as: , , , , where, , where, , , When greater than, , Constraint 1: , where, , Constraint 2: , where, , Constraint 3: , Constraint 4: , Constraint 5: , Constraint 6: , Constraint 7: , Constraint 8: , Constraint 9: , Where T is the total number of time slots in the scheduling cycle, I is the total number of such cogeneration units, is the power generation cost of the i-th cogeneration unit in the t-th time slot, is the total electricity purchase cost of the such cogeneration units in the t-th time slot, is the total electricity sales revenue of the such cogeneration units in the t-th time slot, is the total contracted capacity cost, is the power generation of the i-th cogeneration unit in the t-th time slot, is the steam output of the i-th cogeneration unit in the t-th time slot, , are the coefficients of steam and electricity of the i-th cogeneration unit on this cost function, is the grid purchase price, and is the total cost of the cogeneration units. The grid-purchased power of the group in the t-th time window, is the grid-sold power price, is the grid-sold power of the cogeneration unit in the t-th time window, and are the power purchase / sold selection coefficients, and can be 1 or 0, is 0 when is 1 and 1 when is 0, K is the total number of multiple power consumption time intervals, is the penalty cost for overdue amount not exceeding 10% in the k-th power consumption time interval, is the penalty cost for overdue amount exceeding 10% in the k-th power consumption time interval, is the maximum grid-purchased power in the T time windows during the scheduling period, is the contracted power purchase power in the k-th power consumption time interval, and is the purchase power in the k-th power consumption time interval. Electricity price, is the overdue judgment coefficient in the k-th electricity consumption time interval, is the grid power purchase in the j-th time window, 1, is the total power consumption of the cogeneration field in the t-th time window, is the power consumption loss of the cogeneration units in the t-th time window, is the power generation of the cogeneration units in the t-th time window, is the discharge power of the energy storage battery in the t-th time window, is the steam consumption of the cogeneration units in the t-th time window, is the steam consumption loss of the cogeneration units in the t-th time window, is the steam output of the cogeneration units in the t-th time window, is the maximum grid power consumption. Power sold, maximum power purchased from the grid, minimum power generation of the cogeneration unit in the t-th time window, maximum power generation of the cogeneration unit in the t-th time window, change in maximum power generation of the cogeneration unit in the t-th time window, conversion coefficient of steam to power generation, steam yield of the i-th cogeneration unit in the t-th time window, minimum steam output of the i-th cogeneration unit in the t-th time window, maximum steam output of the i-th cogeneration unit in the t-th time window, and change in steam production of the cogeneration unit in the t-th time window.

3. The cogeneration power management method as described in claim 2, wherein, In step (A), for each cogeneration unit, the nonlinear programming must also satisfy a first power dispatch constraint, a second power dispatch constraint, and a third power dispatch constraint related to the power generation and steam output of the corresponding cogeneration unit. The first power dispatch constraint indicates that when the cogeneration unit is at maximum fuel consumption and the steam output is increased, the power generation decreases. The second power dispatch constraint indicates that when the cogeneration unit is at maximum steam output and the power generation decreases, the fuel consumption decreases. The third power dispatch constraint indicates that when the cogeneration unit is at minimum fuel consumption and the steam output is increased, the power generation decreases.

4. The cogeneration power management method as described in claim 1, wherein, In step (A), for each cogeneration unit, the computing device further uses the nonlinear programming based on ancillary service information to obtain the ancillary service power generation corresponding to the cogeneration in each time window. For each cogeneration unit, the objective function of the nonlinear programming and the multiple constraints satisfied by the objective function can be expressed as: , , , , where, , where, , , When greater than, , , where, , , Constraint 1: , where, , Constraint 2: , where, , Constraint 3: , Constraint 4: , Constraint 5: , Constraint 6: , Constraint 7: , Constraint 8: , Constraint 9: , Constraint 10: , Constraint 11: , Where T is the total number of time windows in the scheduling cycle, I is the total number of such cogeneration units, is the power generation cost of the i-th cogeneration unit in the t-th time window, is the total electricity purchase cost of the cogeneration units in the t-th time window, is the total electricity sales revenue of the cogeneration units in the t-th time window, is the ancillary service revenue of the cogeneration units in the t-th time window, is the total contracted capacity cost, is the power generation of the i-th cogeneration unit in the t-th time window, and is the total power generation of the i-th cogeneration unit in the t-th time window. Let be the steam output, be the coefficients of steam and electricity of the i-th cogeneration unit on this cost function, be the grid purchase price, be the grid purchase power of the cogeneration unit in the t-th time window, be the grid sales price, be the grid sales power of the cogeneration unit in the t-th time window, be , and be , which can be 1 or 0, being 0 when 1 and 1 when 0, K is the total number of multiple electricity consumption time intervals, be the penalty cost for exceeding the limit by no more than 10% in the k-th electricity consumption time interval, and be the penalty cost for exceeding the limit by more than 10% in the k-th electricity consumption time interval. Let be the maximum grid-purchased power in the T time panes during the scheduling period, be the contracted power purchase in the k-th power consumption time interval, be the power purchase price in the k-th power consumption time interval, be the overdue judgment coefficient in the k-th power consumption time interval, be the grid-purchased power in the j-th time pane, 1, be the ancillary service capacity cost of the cogeneration units in the t-th time pane, be the ancillary service quality rate of the cogeneration units in the t-th time pane, be the power dispatch cost of the cogeneration units in the t-th time pane, and be the power dispatch cost of the cogeneration units in the t-th time pane. The settlement price for each time pane is: the auxiliary service power generation of the i-th cogeneration unit in time pane t; the daytime electricity price in time pane t; the actual electrical energy in time pane t; the total power consumption of the cogeneration site in time pane t; the power consumption loss of the cogeneration units in time pane t; the power generation of the cogeneration units in time pane t; the discharge power of the energy storage battery in time pane t; and the steam consumption of the cogeneration units in time pane t.Let be the steam consumption loss of the combined steam and power generating units in the t-th time pane, be the steam output of the combined steam and power generating units in the t-th time pane, be the maximum grid power sold, be the maximum grid power purchased, be the minimum power generation of the combined steam and power generating units in the t-th time pane, be the maximum power generation of the combined steam and power generating units in the t-th time pane, be the change in the maximum power generation of the combined steam and power generating units in the t-th time pane, be the conversion coefficient for steam to power generation, be the steam yield of the i-th combined steam and power generating unit in the t-th time pane, be the minimum steam output of the i-th combined steam and power generating unit in the t-th time pane, be the maximum steam output of the i-th combined steam and power generating unit in the t-th time pane, be the change in steam production of the combined steam and power generating units in the t-th time pane, be the ancillary service bidding capacity in the t-th time pane, be the maximum power generation of the combined steam and power generating units, and be the change in the maximum power generation of the combined steam and power generating units.

5. The cogeneration power management method as described in claim 4, wherein, In step (A), for each cogeneration unit, the computing device also uses the nonlinear programming to obtain the power generation, steam output and ancillary service power generation corresponding to the cogeneration unit in each time window, based on a power generation cost converted into a carbon emission coefficient, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window.

6. The cogeneration power management method as described in claim 5, wherein, In step (A), for each cogeneration unit, the objective function of the nonlinear programming and the multiple constraints satisfied by the objective function can be expressed as: , , , , where, , where, , , When greater than, , , where, , , where, , where, , Constraint 1: , where, , Constraint 2: , where, , Constraint 3: , Constraint 4: , Constraint 5: , Constraint 6: , Constraint 7: , Constraint 8: , Constraint 9: , Constraint 10: , Constraint 11: , Where T is the total number of time windows in the scheduling cycle, I is the total number of such cogeneration units, is the power generation cost of the i-th cogeneration unit in the t-th time window, is the total electricity purchase cost of the cogeneration units in the t-th time window, is the total electricity sales revenue of the cogeneration units in the t-th time window, is the ancillary service revenue of the cogeneration units in the t-th time window, is the carbon emission cost of the i-th cogeneration unit in the t-th time window, is the total contracted capacity cost, is the power generation of the i-th cogeneration unit in the t-th time window, and is the total power generation cost of the i-th cogeneration unit. The steam output of the unit in the t-th time window, , are the coefficients of steam and electricity of the i-th cogeneration unit on this cost function, is the grid purchase price, is the grid purchase power of the cogeneration unit in the t-th time window, is the grid sales price, is the grid sales power of the cogeneration unit in the t-th time window, can be 1 or 0, when is 1 it is 0, and when is 0 it is 1, K is the total number of multiple electricity consumption time intervals, is the penalty cost for exceeding the limit by no more than 10% in the k-th electricity consumption time interval, is the penalty cost for exceeding the limit by ... The maximum grid-purchased power in the T time panes during the process period is , where is the contracted power purchase in the k-th power consumption time interval, is the power purchase price in the k-th power consumption time interval, is the overdue judgment coefficient in the k-th power consumption time interval, is the grid-purchased power in the j-th time pane, 1 is the ancillary service capacity cost of the cogeneration units in the t-th time pane, is the ancillary service quality rate of the cogeneration units in the t-th time pane, is the power dispatch cost of the cogeneration units in the t-th time pane, is the settlement price in the t-th time pane, and is the i-th cogeneration unit. The auxiliary service power generation of the unit in the t-th time pane is , the day-ahead electricity price in the t-th time pane is , the actual electrical energy in the t-th time pane is , the carbon emissions of the i-th cogeneration unit in the t-th time pane is , the carbon emissions from electricity purchase in the t-th time pane is , the conversion factor from power generation cost to carbon emissions is , the total power consumption of the cogeneration site in the t-th time pane is , the power loss of the cogeneration units in the t-th time pane is , the power generation of the cogeneration units in the t-th time pane is , and the discharge power of the energy storage battery in the t-th time pane is .Let be the steam consumption of the cogeneration unit at time t, be the steam loss of the cogeneration unit at time t, be the steam output of the cogeneration unit at time t, be the maximum grid power sales, be the maximum grid power purchase, be the minimum power generation of the cogeneration unit at time t, be the maximum power generation of the cogeneration unit at time t, be the change in the maximum power generation of the cogeneration unit at time t, and be the steam output. The conversion factor for steam to power generation is denoted as , where is the steam yield of the i-th cogeneration unit at time t, is the minimum steam output of the i-th cogeneration unit at time t, is the maximum steam output of the i-th cogeneration unit at time t, is the change in steam production of the cogeneration units at time t, is the ancillary service bidding capacity at time t, is the maximum power generation of the cogeneration units, and is the change in the maximum power generation of the cogeneration units.

7. The cogeneration power management method as described in claim 5, wherein, In step (A), for each cogeneration unit, the computing device further uses nonlinear programming to obtain the power generation, steam output and ancillary service power generation corresponding to the cogeneration unit in each time window, as well as the grid purchase power and grid sales power corresponding to the cogeneration field in each time window, based on a solar power generation information containing multiple solar power generation power corresponding to the corresponding time window and a biogas power generation information containing multiple biogas power generation power corresponding to the corresponding time window.

8. The cogeneration power management method as described in claim 7, wherein, In step (A), for each cogeneration unit, the objective function of the nonlinear programming and the multiple constraints satisfied by the objective function can be expressed as: , , , , where, , where, , , When greater than, , , where, , , where, , where, , Constraint 1: , where, , Constraint 2: , where, , Constraint 3: , Constraint 4: , Constraint 5: , Constraint 6: , Constraint 7: , Constraint 8: , Constraint 9: , Constraint 10: , Constraint 11: , Constraint 12: , Where T is the total number of time windows in the scheduling cycle, I is the total number of such cogeneration units, is the power generation cost of the i-th cogeneration unit in the t-th time window, is the total electricity purchase cost of the cogeneration units in the t-th time window, is the total electricity sales revenue of the cogeneration units in the t-th time window, is the ancillary service revenue of the cogeneration units in the t-th time window, is the carbon emission cost of the i-th cogeneration unit in the t-th time window, is the total contracted capacity cost, is the power generation of the i-th cogeneration unit in the t-th time window, and is the total power generation cost of the i-th cogeneration unit. The steam output of the unit in the t-th time window, , are the coefficients of steam and electricity of the i-th cogeneration unit on this cost function, is the grid purchase price, is the grid purchase power of the cogeneration unit in the t-th time window, is the grid sales price, is the grid sales power of the cogeneration unit in the t-th time window, can be 1 or 0, when is 1 it is 0, and when is 0 it is 1, K is the total number of multiple electricity consumption time intervals, is the penalty cost for exceeding the limit by no more than 10% in the k-th electricity consumption time interval, is the penalty cost for exceeding the limit by ... The maximum grid-purchased power in the T time panes during the process period is , where is the contracted power purchase in the k-th power consumption time interval, is the power purchase price in the k-th power consumption time interval, is the overdue judgment coefficient in the k-th power consumption time interval, is the grid-purchased power in the j-th time pane, 1 is the ancillary service capacity cost of the cogeneration units in the t-th time pane, is the ancillary service quality rate of the cogeneration units in the t-th time pane, is the power dispatch cost of the cogeneration units in the t-th time pane, is the settlement price in the t-th time pane, and is the i-th cogeneration unit. The auxiliary service power generation of the unit in the t-th time pane is , the day-ahead electricity price in the t-th time pane is , the actual electrical energy in the t-th time pane is , the carbon emissions of the i-th cogeneration unit in the t-th time pane is , the carbon emissions from electricity purchase in the t-th time pane is , the conversion factor from power generation cost to carbon emissions is , the total power consumption of the cogeneration site in the t-th time pane is , the power loss of the cogeneration units in the t-th time pane is , the power generation of the cogeneration units in the t-th time pane is , and the discharge power of the energy storage battery in the t-th time pane is .Let be the solar power generation of the solar modules installed in the cogeneration field at time t, be the biogas power generation of the biogas modules installed in the cogeneration field at time t, be the steam consumption of the cogeneration units at time t, be the steam consumption loss of the cogeneration units at time t, be the steam output of the cogeneration units at time t, be the maximum grid-sold power, be the maximum grid-purchased power, be the minimum power generation of the cogeneration units at time t, be the maximum power generation of the cogeneration units at time t, and be the power generation of the cogeneration units. The maximum power generation change in the t-th time pane is denoted by , where is the conversion coefficient from steam to power generation, is the steam yield of the i-th cogeneration unit in the t-th time pane, is the minimum steam output of the i-th cogeneration unit in the t-th time pane, is the maximum steam output of the i-th cogeneration unit in the t-th time pane, is the change in steam production of the cogeneration units in the t-th time pane, is the ancillary service bidding capacity in the t-th time pane, is the maximum power generation of the cogeneration units, is the change in the maximum power generation of the cogeneration units, and is the total power sold by the cogeneration units in the t-th time pane.

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