KR20160042554A - The Development Of Optimal Operation Planning And Price Evaluating Algorithm For Heat Trading Between Combined Heat and Power Plants - Google Patents

Abstract

According to the present invention, provided is an algorithm for establishing an optimum operation plan and calculating a heat transaction unit price for heat transaction between heat combination business operators who operates a first combined heat power generation system (10) and a second combined heat power generation system (20). The algorithm includes: an input data input step (S110); an input data output and data calculation step (S120); a first economic heat load dispatch (EHLD) program performing step (S130) of performing an EHLD program; a compulsive operation setting step (S140) of determining an operation mode which can satisfy a compulsive operation energy amount; a second EHLD program performing step (S160) of performing the EHLD program; an optimum path and heat storage tank operating condition determining step (S170) of determining an optimum path and an operating condition of a heat storage tank (ACC); a decoupled independent system analyzing step (S180) of analyzing independent decoupled system results by individual systems (10, 20); and a related system analyzing step (S190) of calculating an optimum connection amount between the systems (10, 20).

Description

[0001] The present invention relates to an optimal operation plan and a heat transaction price calculation algorithm for heat transaction between cogeneration entities,

The present invention relates to an optimal operation plan and a heat transaction price calculation algorithm for heat transaction between cogeneration operators, and more particularly, to a cogeneration system having a first cogeneration system and a second cogeneration system interconnected through a heat pipe network, It is possible to quantitatively evaluate the economic gain in the heat transaction between the operators, so that the optimal operation plan for the heat transaction can be established, and the optimal operation plan for the heat transaction to calculate the heat transaction unit price and the calculation algorithm of the heat transaction price .

Generally, a system that simultaneously produces and supplies heat and electricity from the same fuel source for efficient use of energy is called Combined Heat and Power. Recently, a heat pipe network has been constructed between each cogeneration system, and the heat is transferred to and from the cogeneration plant through cooperation, which makes it possible to operate a complementary power generation system that is both economically and technically feasible.

However, in the past, cogeneration plants were operated independently, and therefore, for each cogeneration system operating independently, an optimization operation plan was established to efficiently operate each production facility of the power generation system in accordance with the required heat load, Although it is used to individually or integrally control the production facilities, no software has been developed for establishing an optimization operation plan for the entire two cogeneration systems thermally connected through a heat pipe network. As a result, there is a problem in that it is difficult to calculate the heat transaction price for the heat transaction between each cogeneration system through the optimum operation of the associated two-heat separation power plants.

Patent Document 10-2014-0004309 (Apr. 13, 2013), a control system for production and distribution of electricity and thermal energy

SUMMARY OF THE INVENTION The present invention has been made in order to solve the above problems, and it is an object of the present invention to provide a cogeneration system and a cogeneration system, which are thermally connected to each other through heat piping, It is possible to quantitatively evaluate the economic gain by taking both systems into consideration at the time of transaction, so that it is possible to establish an optimal operation plan for the heat transaction and establish the optimum operation plan for the heat transaction that can calculate the heat transaction cost, And to provide a transaction price calculation algorithm.

According to an aspect of the present invention, there is provided an optimal operation planning and heat transaction unit price calculation algorithm for heat transaction between a cogeneration service provider operating the first cogeneration system 10 and the second cogeneration system 20, An input data input step (S110) of inputting input data through the input part (41) of the computing device (40); An input data output and data operation step 120 for calculating a required thermal load for each of the systems 10 and 20, calculating an energy upper and lower limit value and a thermal threshold value for each operation mode, and setting a forced operation amount for each time period; A first EHLD program execution step (S130) of executing an EHLD (Economic Heat Load Dispatch) program according to inputted data in a state where a thermal storage tank (ACC) provided in each system (10, 20) is not considered; A forced operation setting step (S140) of determining an operation mode capable of satisfying a forced operation energy amount at a minimum cost by measuring a forced operation energy generated in a forced operation by operation mode; A second EHLD program execution step (S160) for executing the EHLD program in consideration of the combination of the shaft heat dissipation of each of the thermal storage tanks ACC, the combination of the production facility input, and the operation mode; An optimal path for determining an optimal path and a ACC (Acclimated Storage Tank) operating state by a DP (Dynamic Programming) path search based on result data according to the execution of the EHLD program in the second EHLD program execution step (S160) (S170); Using the optimum result of the DP path search in the optimal path and the heat storage tank operating state determination step (S170), the fuel cost according to the forced, unforced and fuel cost is calculated, and the system heat, energy production amount, (S180) for analyzing the result of the non-link system alone; The optimal operating condition of each system (10,20) is calculated by calculating the change in fuel cost due to the linkage, calculating the hourly and weekly trading volume at the time of linkage, calculating the linkage limit backward cost and the heat transaction unit price, And a linkage system analysis step (S190) of calculating an optimal linkage amount between each of the systems (10, 20) based on the conditions.

According to another aspect of the present invention, after the forcible operation setting step (S140), the axial heat releasable capacity is calculated according to the number of the ACC operation states of each system (10, 20) ACC), and a heat storage tank state setting step (S150) for generating a load considering a heat dissipation operation of the heat exchanger. The optimization operation planning and thermal transaction unit price calculation algorithm for inter-crossover heat transaction is provided.

As described above, according to the present invention, it is possible to quantitatively evaluate the economic gain in the heat transaction between the first and second cogeneration systems connected to each other through the heat pipe network and the respective cogeneration systems of the second cogeneration system, It is possible to establish a plan and calculate the heat transaction price accordingly.

In addition, since the optimum operation plan can be established for each operation mode in consideration of the installation quantity and operation state of each heat storage tank provided in each cogeneration system, it is possible to calculate a more accurate and reliable optimum operation plan and a heat transaction cost .

BRIEF DESCRIPTION OF THE DRAWINGS FIG. 1 is a schematic view showing a configuration of a main production facility provided in each cogeneration system according to a preferred embodiment of the present invention and a state connected to a heat pipe network;
FIG. 2 is a schematic view showing a configuration of an operation apparatus in which an optimal operation plan for heat transaction between cogeneration operators according to a preferred embodiment of the present invention and an algorithm for calculating a heat transaction unit price are installed in an application form,
FIG. 3 is a flowchart illustrating an algorithm for establishing an optimal operation plan for heat transaction between cogeneration operators according to a preferred embodiment of the present invention and an algorithm for calculating a heat transaction unit price.

The objects, features and advantages of the present invention will become more apparent from the following detailed description. Hereinafter, preferred embodiments of the present invention will be described with reference to the accompanying drawings.

The optimal operation plan establishment and thermal transaction unit price calculation algorithm for heat transaction between cogeneration providers according to the preferred embodiment of the present invention includes a first cogeneration system (10) and the second cogeneration system (20), it is possible to quantitatively evaluate the economic gain in the heat transaction between the respective cogeneration companies, thereby establishing the optimum operation plan for the heat transaction, As an algorithm, it is stored and installed in the form of an application in an arithmetic unit 40 as shown in FIG. 2, and various data are read out and processed to output result data for establishing an optimal operation plan and calculated thermal transaction unit price data can do.

In the figure, the CHP (Combined Heat and Power), the PLB (Peak Load Boiller), the ACC, the ACC, and the incinerator are disposed in each of the systems 10 and 20, And additional facilities provided in a conventional cogeneration system such as a heat recovery steam generator (HRSG) may be further included.

The computing device 40 is a data processing device such as a general PC or a notebook computer. The computing device 40 reads various data stored in the memory 43 according to an input signal input through an input part 41 such as a keyboard or a mouse And the data calculated in accordance with the arithmetic operation of the arithmetic and control unit 42 is outputted to the output unit 44 such as a display and a printer.

As shown in FIG. 3, the algorithm for establishing the optimal operation plan and calculating the thermal transaction price for the heat transaction between cogeneration providers according to the preferred embodiment of the present invention includes an input data input step (S110), an input data output and data operation (Step S120), the first EHLD program execution step S130, the forced operation setting step S140, the heat storage tank state setting step S150, the second EHLD program performing step S160, the optimal path and heat storage tank operation state determination step S170, , A non-linked single system analysis step (S180), and a linked system analysis step (S190).

First, the input data input step (S110) is a step of inputting the input data for simulation through the input unit 41 of the arithmetic unit 40. Details of the detailed input data will be described later.

Here, the operation mode control of the operation equipment included in each of the systems 10 and 20 is configured as follows.

ISYS_CFG = 1: Operation of the system by incineration series, CHP, PLB

ISYS_CFG = 2: Operation of the system by incineration series, CHP, PLB, ACC

ISYS_CFG = 3: System operation by incineration series, CHP, PLB, ACC, linked operation

Next, the input data output and data operation step 120 calculates the required thermal load for each of the systems 10 and 20, calculates the upper and lower limits of the energy for each operation mode, and calculates the forced operation amount per time period .

Here, operation mode 1 is thermal load following operation, operation mode 2 is gas turbine single operation, operation mode 3 is electric load following operation, operation mode 4 is maximum thermal load operation, and operation mode 5 is electric thermal load following operation.

Then, the load is 8760 hours (1 year), and the operation of the heat storage tank is performed in weekly basis, so that the load of the main unit corresponding to the input value (168 hours) is generated. In some cases, you may create a monthly load.

Also, calculate the original thermal load characteristics of the system. The thermal load calculates the maximum load, the minimum load, and the thermal load factor, and the thermal load factor can be calculated by the following equation (1).

[Equation 1]

Thermal load factor = average load / maximum load * 100

In addition, in order to satisfy the customer's GCAL, the heat load required to be produced by the cogeneration plant (CHP) and the peak load generator (PLB), which are the heat production facilities, is calculated to reflect the annual amount except the incinerator heat.

The adjustment of the load as a whole is carried out by the following steps.

[1] Adjustment of the load according to the amount of heat: The amount of heat is excluded from the heat load of the customer and the heat production equipment produces heat.

[2] If the adjustment of the load is made according to the connection capacity constraint, the system that is transmitted will increase the heat demand by the calculated optimum amount and the heat demand system reduces the heat demand by the calculated optimal amount . In this case, the increase and decrease of heat load are based on the optimal annual amount calculated by time zone, and when considering the limitation of annual amount, the optimal heat transaction amount considering the annual amount restriction is used.

[3] For forced operation, adjust the thermal load as follows. If the optimal heat output is larger than the thermal load by comparing the sum of the optimal heat output due to the forced operation and the load, all of the heat generated by the forced operation is supplied to the heat load, so that the heat load becomes zero. Output - heat load).

In addition, when the optimal heat output is smaller than the heat load, there is no excess heat. Since all of the heat generated by the forced operation is supplied to the heat load (non-forced CHP and other heat production facilities) .

[4] Load adjustment taking into account the axial heat dissipation operation of the accumulator (ACC) shall be adjusted in accordance with the state configuration of the accumulator (ACC). The state of the thermal storage tank (ACC) is determined according to the number of charged thermal storage tanks (ACC) and the amount of thermal storage capacity per hour. Since the heat accumulator (ACC) requires heat to be stored, the thermal load is increased by the amount of heat accumulated. Therefore, the heat is generated instead of the production facility, so that the heat load is reduced by the amount of heat.

[5] The load adjustment by the annual weighing is basically modeled by the increase of the thermal load in the heat transfer and the thermal load in the heat transfer.

Meanwhile. The production equipment provided in each system 10, 20 is set as follows.

[1] System change according to input control

Adjust system configuration according to input control such as system operation with incineration plant, CHP, peak load generator (PLB).

[2] Calculate energy upper and lower limit values and thermal ladder limit values for each operation mode by using thermoelectric function of CHP.

[3] Calculation of energy upper and lower limit values and thermal ladder limit values for each operation mode by using the thermoelectric function of the forced operation cogeneration generator (CHP)

[4] Forced operation based on input Generates the forced operation amount for each time zone of the generator. That is, the forced operation amount is constant for each cogeneration unit (CHP) and it is assumed that the forced operation amount is operated for a given time.

[5] Recalculate the fuel cost function according to the fuel rate change rate. At this time, the fuel cost of the CHP and the fuel cost of the peak load generator (PLB) are different from each other because the unit price is different. This is to confirm the change of the profit due to the change of the unit cost of the fuel cost in anticipation of the fuel cost change in the future.

Next, the first EHLD program execution step (S130) is a step of executing the EHLD program according to the input data inputted without considering the thermal storage tank (ACC) provided in each system 10, 20, It is first judged whether or not it is constituted to be able to satisfy the thermal load, and it is checked in advance whether or not the Feasible Solution exists in all calculation processes to be performed. That is, it is to judge the appropriateness of system design.

Specific implementation methods are as follows.

[1] Before the EHLD program is executed, a simple comparison is performed as the maximum value for the thermal load size and production facility size to determine whether the thermal load can be satisfied with a given system. This is to check whether the input for the EHLD program execution can be checked in the state that the ACC is not considered.

[2] Determine whether the given system can perform EHLD, the economic heat load distribution.

[3] The thermal storage tank (ACC) executes the EHLD program for all the loads in all operating modes in the unconsidered state. At this time, the EHLD program is executed for each operation mode of the cogeneration unit (CHP), and if there are several cogeneration unit (CHP), the operation mode is assumed to be the same. That is, if any cogeneration unit (CHP) of a plurality of cogeneration units (CHP) is operated in the operation mode 1, all the remaining cogeneration units (CHP) are operated in the operation mode 1 and if one of the given operation modes satisfies the heat load It is assumed that the EHLD program is executed. On the other hand, since operation mode 2 is a mode without heat production, operation mode 2 is not considered in execution of EHLD program.

[4] In this course, the purpose of system operation is to minimize fuel cost. This is because the objective function only changes during the optimization process and there is no substantial effect on the optimization process.

Next, the forced operation setting step S140 is a step of determining an operation mode capable of satisfying the forced operation energy amount at the minimum cost in consideration of the forced operation energy generated in the forced operation by operation mode.

Here, forced operation means operation unconditionally operated for production of electric power regardless of thermal load for energy production. That is, regardless of the optimal process of the system, the remaining production facilities must optimally produce heat considering the result of heat production due to the forced operation. Therefore, in this simulator, forced operation should be considered in advance, and then optimum operation of the remaining heat production facilities should be considered.

In case of forced operation, it is assumed that operation mode 2 is the optimum result, and no heat is produced. In the remaining operation mode, heat is generated, and heat produced by forced operation is supplied to the system heat load first.

Actually, forced operation of a cogeneration plant is operated in operation mode 2 when heat is not needed, operation mode 1 when heat and energy ratio are similar, and operation mode 5 when heat is required more than energy.

[1] It is determined whether the inputted forced operation energy violates the upper and lower limits of the cogeneration unit (CHP).

[2] Forced operation In order to generate the energy of the CHP, the optimum operation mode is selected as the operation mode that can satisfy the forced operation energy amount at the minimum cost among all the operation modes.

[3] Calculate the heat production, energy production, production cost, and backhaul cost in the determined optimum operation mode.

[4] When the forced operation is determined, the surplus heat calculation and the load adjustment reflecting the heat generation amount are performed as described above.

Next, the heat storage tank state setting step S150 calculates the axial heat storage capacity according to the number of operation states of the ACCs provided in the respective systems 10 and 20, And generating the considered load.

In this case, a combination of the number of ACCs in each system 10 and 20 and the ACC in a storage tank ACC is calculated according to the RR (Ramp Rate) ACC) to determine the STATE of the DP to take into account the optimum operation of the storage tank (ACC). On the other hand, in order to determine which accumulating tank (ACC) is in operation, a unique INDEX is assigned to each accumulating tank (ACC).

The concrete implementation method is as follows.

[1] A combination of the operation and operation of the accumulator (ACC) to take into consideration the operation of the condenser (ACC) is generated.

[2] Thermal storage tank (ACC) Calculate the capacity of thermal storage capacity according to the number of operation states (number of STATE of DP). This is to derive the optimum considering the ACC operation.

Here, the number of possible heat dissipation is the same as the number of the generated combinations, and all the STATEs in all the STAGEs of the DP should be composed of 2 * In this case, the above two times are for considering the heat accumulation and heat dissipation of the ACC, and +1 is taken into consideration when there is no axial heat dissipation.

In addition, the number of STATEs generated according to the number of inputs of the accumulator (ACC) is 2 ^^ (the number of the storage tank injected) * 2 + 1, for example, when considering 4 storage tanks (ACC) ) -1) * 2-1, total 31 heat storage operation states are considered.

[3] Calculate the heat storage capacity of the storage tank (ACC) in each state, and calculate the heat storage tank number capable of storing the heat storage capacity and the heat storage capacity.

At this time, according to the allowable axial heat dissipation amount (RR) per hour of the accumulating tank (ACC), the accumulation tank (ACC) number responsible for the allowable heat dissipation amount is sorts together based on the amount of heat dissipation in each stage. This is because in order to reduce the axial heat radiation amount due to the combination of the ACC ramp rate, it is necessary to arrange the heat radiation amount in descending order. That is, the STATE of the DP can be configured in descending order.

[4] Generate a load considering the shaft heat dissipation operation of the thermal storage tank (ACC). The number of loads considering the heat of the shaft (ACC) in the original load N. * The state of the heat storage tank Creates several new loads and executes the EHLD program with the new load created.

[5] In this process, it may happen that the load size is negative in the result of the load generation considering the shaft heat dissipation operation of the ACC. In this case, for the load, the transition cost to the corresponding STATE is set to BIG, and the path is excluded in the step of finding the minimum path in the process of performing the DP in the future.

Next, the second EHLD program execution step (S160) is a step of executing the EHLD program in consideration of the shaft heat dissipation of each thermal storage tank (ACC), the combination of the input of production facilities, and the operation mode.

To do this, first, [1] form a production facility combination for EHLD program execution. Here, the combination of the production facilities means that all combinations in which the production facilities can be input are generated, and a combination of 2 ^^ (number of production facility inputs) -1 number is generated according to the number of production facilities.

Actually, optimization of the economic load distribution has a restriction that the input heat production facility must be operated. However, in order to optimally operate the cogeneration, it is necessary to input a certain heat production facility. To determine whether the objective can be achieved. That is, the optimization process should actually include a shutdown plan for the heat production facility. Therefore, to solve this problem, it is necessary to create all possible combinations of input facilities and perform EHLD for each combination.

The following shows the possible combinations of input facilities created by input of production facilities.

[2] Execute EHLD program for all operation modes of each STAGE (load) and each STATE (heat storage operation). In this case, operation mode 2 is an operation mode without heat production, so do not consider operation mode 2 when EHLD program is executed.

As an example, the number of EHLD program execution times for a system in which four heat production equipments, four operation modes, and three accumulation tanks (ACC) are charged is shown in Equation (2) below.

&Quot; (2) "

Total number of loads = Number of original load loads * Number of storage tank STATE = 168 * 15 = 2520

Number of EHLD calculations for one load = number of production facility combinations * Number of operation modes = 31 * 4 = 124

Total Number of EHLD Performances = Total Number of Loads * Number of EHLD Calculations for One Load = 2520 * 124 = 312480

In other words, one of the total 312,480 objects is derived.

[3] Calculate energy production according to EHLD program execution result. At this time, since the peak load generator (PLB) does not generate heat, it is necessary to distinguish between the cogeneration generator (CHP) and the peak load generator (PLB).

[4] In order to exclude paths that do not satisfy supply and demand among the EHLD program results in the DP path SEARCH process, the cost of the corresponding load (STATE) should be set to BIG, which is close to infinity.

[5] The objective function can be set in the optimization process. The ultimate goal in the algorithm according to the preferred embodiment of the present invention is profit maximization. However, it may be necessary to optimize the operation in the absence of reverse transmission, so that the purpose of minimizing the fuel cost can also be considered.

Substantially, the revenue items of a cogeneration plant consist of:

[1] Production cost

    <1> Fuel cost

    <2> Waste Heat Heat Cost

[2] Sales cost

    <3> Heat selling cost

    <4> Cost of energy sales

However, waste heat has already been determined, and the heat sale of the consumer is a fixed income, except when the selling price is changed. Therefore, factors influencing the optimization are fuel cost and energy sales cost. Therefore, in the algorithm according to the preferred embodiment of the present invention, the problem of profit maximization is constituted by the duality problem of maximizing fuel cost + energy area ratio.

Next, the non-linked single system analysis step S180 calculates the fuel cost according to the forcible, non-enforced, and fuel cost using the optimum result of the DP path search according to the optimal path and the heat storage tank operation state determination step S170 , The system heat, the energy production amount, and the characteristics of the system, and analyzes the result of the independent non-connected system for each system 10, 20.

First, [1] Estimate the fuel cost according to cases (forced, non-forced, fuel cost) using DP optimal results.

[2] The calculation of system heat, energy production and system characteristics is as follows.

Heat load to be supplied

Surplus waste heat

Non-forced operation CHP, PLB Heat output (non-forced operation CHP, PLB amount)

Non-forced operation CHP heat output

PLB heat output

Non-forced operation CHP + PLB Heat output

Heat storage tank heat capacity

Non-forced operation Total heat output

Heat (= total heat output - heat sales) (non-forced operation amount)

CHP energy output

Non-enforced operation CHP Back-to-back back-up and back-haul costs Total energy production  

Total CHP energy output

[3] Calculation of various costs is calculated as follows.    

Waste Heat Heat Cost

Heat selling cost

Energy sales cost

Current energy sales costs

Expected energy sales cost

[4] Record the value for USING.DAT for calculation of forced operation limit unit price.

[5] Forced operation limit unit price calculation

The forced operation limit unit price means the marginal cost at which profit is generated even when forced operation is performed.

&Quot; (3) &quot;

Total revenue for non-forced operation (FREE_INCOME) - Total revenue for forced operation (TINCOME)

= Energy output (SUMTOT_PWR)

 * (SMP forced operation limit unit price (COM_EXPINCOME) -SMP current unit cost average (COST_ELEC))

Here, the System Marginal Price (SMP) refers to the marginal cost of KEPCO.

[6] The following items should be calculated to understand the situation and efficiency of system operation.

Production ratio

Heat production composition ratio

Energy production ratio

Cost composition ratio

Fuel cost, heat and energy sales ratio

Next, the linkage system analysis step (S190) calculates the change in the fuel cost due to the linkage, calculates the weekly transaction amount at the time of linkage, calculates the linkage limit backtransport cost and the heat transaction unit price, 20 and derives the optimum amount of annual load between each system 10, 20 from the derived optimum operation.

This linked system analysis step (S190) can be performed in the following order.

[1] HEATING CHECK

[2] Calculation of fuel cost change by linkage

The change in the unit price does not affect the result of the linkage. This is because, when the unit price increases, the energy sales cost increases in both linked systems, and the transaction at the time of linkage is determined by the difference in profit between linkage and non-linkage.

[3] Energy generation check of linked system

[4] Distribution of gain due to linked operation

[5] Estimation of hourly and weekly trading volume

[6] Link Limit Backward Cost

The combined marginal cost refers to the marginal cost at which reverse marginal returns can be increased through linkage and is calculated by the following equation (4).

&Quot; (4) &quot;

Revenue increase in connection = current reverse remittance - limit SMP * energy output

[7] Estimate of transaction price

The final linked trading unit price and the final linked compensation trading unit price are calculated and added together to calculate the total final trading unit price.

[8] The derivation of the optimum annual amount for the annual limit is as follows.

In this algorithm, the optimal linkage amount is calculated between the two systems 10 and 20 from the optimized operation derived from the optimal operation of the A and B systems with the A system and the B system linked.

The optimal amount of annual yield thus obtained is the optimal annual amount when there is no annual limit.

However, the capacity of the heat pipe network 30, which can already be connected to the system in operation, has been determined. In order to take this into consideration, we consider the limitation of the connection capacity as follows.

[1] In the case where there is no annual limitation, if the derived optimal linkage violates the linkage capacity upper limit, it shall be operated at the upper limit of the linkage capacity. In practice, the optimum amount of the optimal system between two systems is based on the incremental fuel cost of the two systems. Therefore, if the upper limit is exceeded, the incremental fuel cost of the system does not change from the optimum direction. Therefore, the optimal system is maintained.

[2] In the actual system, if the annual amount is adjusted by taking into account the annual weight limit, the following phenomenon may occur when the thermal load is small.

Before considering the linkage, the cogeneration unit (CHP) can be operated, that is, it is larger than the lower limit of the cogeneration unit (CHP). If the size of the load becomes smaller by considering the coupling, and becomes smaller than the lower limit of the cogeneration unit The cogeneration unit (CHP) can not be started, but the peak load generator (PLB) is started and the cost is increased.

Therefore, it is disadvantageous if the thermal load considering the connection is smaller than the MIN value of the CHP. That is, the size of the load considering the annual load must be larger than the largest value among the minimum values of the CHPs injected into the SYSTEM. This is because some cogeneration generators (CHPs) may not be operational.

Therefore, in the algorithm according to the preferred embodiment of the present invention, when the linkage is considered, the linkage is made to be greater than the largest value among the minimum values of the CHPs input to the SYSTEM.

[9] Create input file

Independent Operation OR Quantity Constraint Constant Operation: For a single system considering <1> optimal constraint constraint constraint: <2> Generate an input file to perform <2>. The input file should be created as OPTWHE.DAT in 01. ISO_IN FILE.

Next, a description will be given of a method for using the calculation device 40 according to the preferred embodiment of the present invention to establish an optimal operation plan for heat transaction between cogeneration service providers and to calculate a heat transaction price calculation algorithm.

First, a simulation of a single system without linkage between the systems 10 and 20 is performed. SIMULATION method of single system without connection is as follows.

(1) FOLDER CHP_DATA / 01. After inputting system data to SIMULATION to A_C_GEN, A_GEN, A_LOAD, COST, WEEK_INDEX of INPUT

(2) Single operation OR Weighing mode Constraint Single operation selection <1>

(3) In case of single system without connection <1>

(4) Select between Non-Forced Operation <0> and Forced Operation <1>

(5) maximize profit <1>, minimize fuel cost <2>

(6) When calculating the energy limit price for forced operation when forcible operation is selected <1> Estimation <2>

<1> CHP_DATA / 02 when selected. 49. Enter the revenue value of USING.OUT on screen in ISO_OUT

However, it should be done after performing all the above steps so that the profit value is calculated in advance.

(Review of performance results)

The result is CHP_DATA / 02. Review A11_SYSTEM.OUT, A12_EHLD_FUEL.OUT, A13_COMBI_GEN.OUT, A14_DP.OUT, and A15_ECONO.OUT in ISO_OUT.

Single operation SIMULATION Example

Then, each system 10, 20 simulates the interconnected systems that are interconnected. The SIMULATION method of the linkage system is divided into the linkage capacity non-linkage linkage system and linkage capacity linkage linkage system.

(1) FOLDER CHP_DATA / 01. Of INPUT

A SYSTEM: A_C_GEN, A_GEN, A_LOAD

B SYSTEM: B_C_GEN, B_GEN, B_LOAD

A-B linked SYSTEM: AB_C_GEN, AB_GEN, AB_LOAD

All system common use: SIMULATION to COST, WEEK_INDEX Perform after system data input.

[1] Linkage Capacity Unconstrained Linkage System

(2) Linkage capacity Unconstrained linkage operation <2> Selection

(3) Select between Non-Forced Operation <0> and Forced Operation <1>

(4) maximize profit <1>, minimize fuel cost <2>

5) When selecting the forced operation, calculate the energy limit price for forced operation <1> Estimate <2>

<1> CHP_DATA / 02 when selected. 49. Enter the revenue value of USING.OUT on screen in ISO_OUT

However, it should be done after performing all the above steps so that the profit value is calculated in advance.

(Review of performance results)

The result is CHP_DATA / 03. WHE_OUT

(1) Optimal operation of the A system is A11_SYSTEM.OUT, A12_EHLD_FUEL.OUT, A13_COMBI_GEN.OUT, A14_DP.OUT, A15_ECONO.OUT

(2) B The optimal operation of the single system is B11_SYSTEM.OUT, B12_EHLD_FUEL.OUT, B13_COMBI_GEN.OUT, B14_DP.OUT, B15_ECONO.OUT

(3) Optimal operation of the A-B linkage system is AB11_SYSTEM.OUT, AB12_EHLD_FUEL.OUT, AB13_COMBI_GEN.OUT, AB14_DP.OUT, AB15_ECONO.OUT

(4) Information on system characteristics and back-haul information, revenue, transaction volume and transaction cost after linking 777. INTER_AB.OUT

[2] Linkage capacity constraint linkage system

(2) [2-1] Connected Capacity Unconstrained linkage system is performed first

<After>

(3) Independent operation OR Weighing mode Constraint independent operation selection <1>

(4) Selection for the case of a single system considering optimal weighing constraint <2>

(5) Linkage capacity Have you performed linkage-free operation? ENTER

(6) Linkage capacity Unconstrained linkage operation Proceed to the next step in the same condition as SIMULATION

(6-1) Select between Non-Forced Operation <0> and Forced Operation <1>

(6-2) Choose between maximizing profit <1> and minimizing fuel cost <2>

(6-3) When selecting the forced operation, the energy limit price for the forced operation is calculated. <1> Estimation <2>

<1> CHP_DATA / 02 when selected. 49. Enter the revenue value of USING.OUT on screen in ISO_OUT

However, it should be done after performing all the above steps so that the profit value is calculated in advance.

(Review of performance results)

(1) Optimal operation of A system in linkage system when link capacity constraint is CHP_DATA / 02. A11_SYSTEM.OUT, A12_EHLD_FUEL.OUT, A13_COMBI_GEN.OUT, A14_DP.OUT, A15_ECONO.OUT of ISO_OUT

(2) Optimal operation of B system in linkage system when link capacity constraint is CHP_DATA / 02. B11_SYSTEM.OUT, B12_EHLD_FUEL.OUT, B13_COMBI_GEN.OUT, B14_DP.OUT, B15_ECONO.OUT of ISO_OUT

(3) Optimal operation of A-B linkage system is CHP_DATA / 03. CAB11_SYSTEM.OUT, CAB12_EHLD_FUEL.OUT, CAB13_COMBI_GEN.OUT, CAB14_DP.OUT, CAB15_ECONO.OUT of WHE_OUT

(4) CHP_DATA / 03 for system characteristics and back-haul information, revenue, transaction volume and transaction cost after linkage. 777 in WHE_OUT. INTER_AB.OUT

The above is summarized in [Table 1] and [Table 2] below.

Case 1

Case 2
Case 3
Case 4
Case 5
Case 6 Connection capacity
Unconstrained linkage Connection capacity
Unconstrained linkage Connection capacity
Unconstrained linkage Connection capacity
Pharmaceutical linkage Connection capacity
Pharmaceutical linkage Connection capacity
Pharmaceutical linkage Non-coercion Weekly compulsory Hourly force Non-coercion Weekly compulsory Hourly force revenue revenue revenue revenue revenue revenue 2 2 2 2 2 2 0 One One 0 One One One 0 One One 0 One WEEK input One One WEEK input One One WEEK input WEEK input Run again WEEK input WEEK input One One One One Enter Revenue
(using, out) 2 Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out) enter Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out) 0 Enter Revenue
(using, out) Enter Revenue
(using, out) One Run again Run again WEEK One One 2 2 enter enter One One 0 One One One WEEK WEEK One One Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out)

Case 7

Case 8
Case 9
Case 10
Case 11
Case 12 Connection capacity
Unconstrained linkage Connection capacity
Unconstrained linkage Connection capacity
Unconstrained linkage Connection capacity
Pharmaceutical linkage Connection capacity
Pharmaceutical linkage Connection capacity
Pharmaceutical linkage Non-coercion Weekly compulsory Hourly force Non-coercion Weekly compulsory Hourly force Fuel cost Fuel cost Fuel cost Fuel cost Fuel cost Fuel cost 2 2 2 2 2 2 0 One One 0 One One 2 0 One 2 0 One WEEK input 2 2 WEEK input 2 2 WEEK input WEEK input Run again WEEK input WEEK input One One One One Enter Revenue
(using, out) 2 Enter Revenue
(using, out) Enter Revenue
(using, out)
Enter Revenue
(using, out) enter Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out) 0 Enter Revenue
(using, out) Enter Revenue
(using, out) 2 Run again Run again WEEK One One 2 2 enter enter One One 0 One 2 2 WEEK WEEK One One Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out) Enter Revenue
(using, out)

The main contents of the simulation result are as follows.

(1) A11_SYSTEM.OUT: Thermal load characteristics, load adjustment characteristics, linkage simulation conditions, CHP characteristics, PLB characteristics, ACC characteristics, forced operation CHP characteristics and operation time,

(2) A12_EHLD_FUEL.OUT: After considering the heat storage tank, each combination of each load, each operation mode, objective function and facility operation output for each storage tank STATE

(3) A13_COMBI_GEN.OUT: CHT + PLB input enable combination, ACC input enable combination STATE configuration state

(4) A14_DP.OUT: Optimal facility operation result and optimum cost in 168 hours

(5) A15_ECONO.OUT: operation result of forced operation CHP, heat demand characteristic, heat hydrothermal characteristic, CHP, PLB heat production characteristic, heat storage tank heat production characteristic, heat supply characteristic, energy production characteristic, , Revenue analysis for rising prices of energy sales, unit price of forced driving backward limit, components of fuel cost), production composition ratio (heat, energy)

(6) 777. INTER_AB.OUT: The heat production characteristics of the system, the fuel cost in the single operation, the fuel cost in the linked operation, the energy production characteristics of the system, the energy sales cost in the single operation, Trading volume, revenue distribution, backrelease information, optimal trading volume, trading unit price

Simultaneous operation SIMULATION Example

The input configuration of the simulator is classified into the following five categories.

* COST

The input of the cost-related variables is shown in the table below.

(1) Cost unit cost Item Expected energy return price Waste heat heat unit price Heat selling unit price Energy back-up unit by hour

(2) Unit Price Change Rate Item CHP fuel price change rate PLB fuel price change rate Current SMP rate of change

(3) Variables related to thermal load adjustment Item 168 hours Load size Overall adjustment ratio Whether load smoothing is performed (0: not performed, 1: performed) Number of load smoothing loads Amount of load smoothing load

(4) Annual amount data Item A system upper limit value between SYSTEM and B SYSTEM Optimum annual amount of time
This file is created when ICHOICE = 2 and it is not an input file.
Used only when ICHOICE = 1 and ILIMIT = 2
In the above case, it is the case to calculate the operation of each A SYSTEM and B SYSTEM when the optimal linkage is obtained after deriving the optimal annual amount in the linkage system.

* LOAD Item Consumer thermal load [Gcal] Incineration Heat Calories [GCAL] Consumer electrical load [MW]

* A_GEN

(1) Cogeneration generator (CHP) Item How to use CHP algebra PLB Algebra ACC algebra Number of operating modes of CHP Mode 1 (1): Thermal load following operation (GT => HP ST => Heat Exchanger)
Mode 3 (2): Electric load following operation (GT => HP ST => LP ST)
Mode 4 (3): Maximum thermal load following operation (GT => Heat Exchanger)
Mode 5 (4): electricity + thermal load following operation (GT => HP ST => LP ST => heat exchanger)
Mode 2: Gas turbine single operation (GT)
The gas turbine alone operation is not actually operated, so it is not considered when configuring the program. JP MODE of CHP I
Expression index of thermoelectric function 0, the thermoelectric rate for calculating the amount of energy production according to the amount of heat production
1, the thermoelectric rate for calculating the amount of heat production according to the amount of energy production Operation mode number of CHP J-th MODE of CHP I
Coefficient of fuel cost function J-th MODE of CHP I
Heat or energy production
Upper and lower limit [Gcal] When IDX_MODE (I, J) = 0, column production [Gcal]
The energy output [MW] must be calculated according to the heat output [Gcal]. f (heat [Gcal]) = energy [MW]
If IDX_MODE (I, J) = 1, energy production [MW] should be entered as upper and lower limits. Enter the heat output [Gcal] to be calculated according to the energy production [MW]. f (energy [MW]) = heat [Gcal] J-th MODE of CHP I
Coefficient of thermoelectric function

(2) Peak load generator (PLB) Item Coefficient of fuel ratio function of PLB I The upper and lower limits of the heat output of PLB No. I

(3) Heat storage tank (ACC) Item Maximum Capacity of Heat Storage Tank [GCAL] Shaft per hour, maximum heat dissipation [GCAL / H] Initial heat level [GCAL] = Final heat level

* A_C_GEN

Item CHP number forcibly operated CHP electric output for forced operation Start time of forcible operation for each day of CHP for the weekly time unit forcible operation target Time unit of the weekly forced driving End of the forced driving operation of CHP by date
The forced operation amount per 168 hours by CHP is automatically generated based on this input

* WEEK_INDEX

Item The corresponding WEEK number to simulate during the year

On the other hand, the precautions for the forced operation input configuration are as follows.

[1] Linking <A-B SYSTEM> When inputting <A SYSTEM SYSTEM>, it is necessary to input <B SYSTEM> data sequentially after <A SYSTEM data input.

CHP B SYSTEM (second cogeneration system (20)) after CHP A SYSTEM (first cogeneration system (10)), PLB B SYSTEM after PLB A SYSTEM, ACC B SYSTEM

[2] In case of forced operation of CHP, the input data should be the same as the input data of non-forced system, and only the forced CHP data should be moved to the bottom.

Depending on whether there is forced operation or not, the input files are different, but the two files are not used at the same time

In the case of forced operation, the input of the CHP that inputs the production facility not forcibly operated and forcibly operates is input at the end. In this case, the logic is configured to take into account the CHP that performs the program with the logic as well as the forced operation, for the production facilities that do not perform forced operation.

Forced operation is the operation to fix the electric output. There is no restriction of the operation mode in the forced operation. When the forced operation is operated in the operation mode other than the operation mode 2, surplus heat is generated.

Meanwhile, in the algorithm according to the preferred embodiment of the present invention, the characteristics of the system in which the current driving simulation is performed are recorded, and the recording items are as follows.

Number of hours to be considered from the driver's shareholder: 168 hours (input SYSTEM)

[1-11] Characteristics of the thermal load of the customer

<1> maximum heat load, <2> minimum heat load, <3> thermal load ratio [%]

[2-11] Status of load adjustment

[3-11] Linkage simulation condition and simulation method

[4-11] Thermal Load Characteristics by Coupling and Sequence

[5-11] Non-forced operation CHP logarithm, number of operation modes, upper and lower limits of heat and capacity, forced operation time and capacity information

[6-11] Number and characteristics of peak load generator (PLB)

[7-11] Algebra and Characteristics of Thermal Storage Tank (ACC)

[8-11] Heat Storage Tank (ACC) Maximum heat dissipation per hour

Heat transfer rate, incinerator heat quantity,

[9-11] Cost-related variables

<1> Current SMP average unit price

<2> Expected energy sales unit price

<3> Surplus waste heat unit price

<4> Heat selling unit price

<A> CHP fuel price change rate

<B> PLB fuel price change rate

<C> SMP change rate

[10-11] System configuration status

[11-11] Variable substitution results for each mode of operation according to the number of production facilities to perform EHLD

* COMBI_GEN.OUT

The combination of the heat production facility and the heat storage tank and the unique number are recorded.

[1-13] Combination Creation Results According to Input of Heat Storage Tank

[2-13] ACC input number for combination

[3-13] Combination of generating number of heat storage tank

Total number of combinations of generated heat storage tank

Number of storage tank STATE by combination

[4-13] Result of combination production according to input of production facility

[5-13] Production Equipment Input Number, Combination Number

Total number of combinations of production facilities created: 3

[6-13] The unique number according to the generated combination

* ELDH_FUEL.OUT

[1-12] Production facility characteristics by operation mode

Thermal under, Thermal over, Under low energy, High energy limit

Upper limit of heat considering thermal storage tank operation

[2-12] EHLD results of a given system before construction of a production facility combination

[3-12] Load generation result obtained by processing the heat storage tank operation and (-) load

[4-12] EHLD optimum results for each combination after the combination of production facility and heat storage tank combination

[5-12] EHLD results in each load, combination, and mode

[6-12] Step-by-step optimal results

[7-12] EHLD optimal STATE for each combination after the combination of production facility and heat storage tank combination

* DP.OUT

[1-14] Expenses for each STATE in the beginning

[2-14] The heat storage tank number that is responsible for the possible heat dissipation of the shaft and the heat dissipation of the shaft according to the operation of the storage tank (production combination) in each STAT, and the axial heat dissipation amount

[3-14] A standard value for determining the level of the storage tank in each stage

[4-14] STAGE ==> ELDH optimal target cost (before the thermal storage tank top and bottom condition violation determination) in the load considering the target cost heat storage operation condition at each STATE

[5-14] Water level calculation result of individual storage tank in STATE according to the number of operation of the storage tank to exclude the upper and lower limit violation value of the storage tank

[6-14] Violation of Upper and Lower Limit of Heat Capacity in Heat Storage Tanks ==> Exclusion from Optimal Path Search

[7-14] STAGE ==> Cost at each STATE

BIG ***** is processed for the condition that one of the individual heat storage tank violates the upper and lower limit value of the storage tank capacity

[8-14] Recall the minimum value and the previous STATE number of the target cost from the previous stage STAGE to the present stage STAGE

[9-14] Information about beginning and end pinning

[10-14] DP Optimal Path Tracking Process

[11-14] STATE number of DP optimum path

[12-14] Output of optimum result by DP

<1> Production facility operation result

<2> Results of Operation of Two Storage Tanks

* ECONO.OUT

[0-20] Operation result of forced operation CHP

[1-20] Heat Demand Characteristics

[2-20] Heat and heat characteristics

[3-20] Heat production characteristics

[4-20] Heat production characteristics of heat storage tank

[5-20] Heat Supply Characteristics

[6-20] Energy production characteristics

[7-20] Cost characteristics

[8-20] Configuration ratio characteristics

* INTER.OUT

[1-777] Load adjustment reflecting heat generation due to forced operation

 [2-777] Heat production characteristics of the system

[3-777] Fuel cost in stand-alone operation, linked operation

[4-777] Energy production characteristics of the system

[5-777] Energy sales cost in single operation, linked operation

[6-777] Total Revenue Increase by Linked Operation

[7-777] Initial weekly trading volume (<A SYSTEM> ==> <B SYSTEM>)

[8-777] Distribution of profit increase by linked operation

[9-777] Determination of linkage cost for backward linkage (linkage backward cost)

[10-777] Backhaul information by time zone due to linked driving

[11-777] Adjusting the annual amount when the load is negative

[12-777] A SYSTEM and B SYSTEM load adjustment process output

[13-777] Final Linked weekly trading volume (<A SYSTEM> ==> <B SYSTEM>)

[14-777] Final linked profit transaction unit price

According to the preferred embodiment of the present invention as described above, by the steps of establishing the optimal operation plan for the heat transaction between the cogeneration units and calculating the heat transaction unit price, the first cogeneration unit It is possible to quantitatively evaluate the economic gain in the heat transaction between each of the cogeneration systems of the system 10 and the second cogeneration system 20 so that an optimal operation plan for the heat transaction can be established and the heat transaction unit price can be calculated have.

In addition, since the optimum operation plan can be established for each operation mode in consideration of the installation quantity and operational state of each of the accumulating tanks (ACC) provided in each of the systems 10 and 20, it is possible to establish a more accurate and reliable optimal operation schedule, The unit price can be calculated.

It will be apparent to those skilled in the art that various modifications and variations can be made in the present invention without departing from the spirit or scope of the inventions. It will be clear to those who have knowledge.

10 ... 1st cogeneration system 20 ... 2nd cogeneration system
30 ... thermal pipe network 40 ... computing device
41 ... input unit 42 ... operation control unit
43 ... memory 44 ... output section
S110 ... input data input step
S120 ... input data output and data operation step
S130 ... First EHLD program execution step
S140 ... Forced operation setting step
S150 ... Thermal storage tank condition setting step
Step S160 ... Second EHLD program execution step
S170 ... Optimum path and heat storage tank operation state determination step
S180 ... Non-linked single system analysis step
S190 ... Linkage system analysis step

Claims (2)

In an optimal operation planning and heat transaction price calculation algorithm for heat transaction between the cogeneration service provider operating the first cogeneration system 10 and the second cogeneration system 20,
An input data input step (S110) of inputting input data for simulation through an input part (41) of the computing device (40);
An input data output and data operation step 120 for calculating a required thermal load for each of the systems 10 and 20, calculating an energy upper and lower limit value and a thermal threshold value for each operation mode, and setting a forced operation amount for each time period;
A first EHLD program execution step (S130) of executing an EHLD (Economic Heat Load Dispatch) program according to inputted data in a state where a thermal storage tank (ACC) provided in each system (10, 20) is not considered;
A forced operation setting step (S140) of determining an operation mode capable of satisfying a forced operation energy amount at a minimum cost by measuring a forced operation energy generated in a forced operation by operation mode;
A second EHLD program execution step (S160) for executing the EHLD program in consideration of the combination of the shaft heat dissipation of each of the thermal storage tanks (ACC), the introduction of the production facilities, and the operation mode;
An optimal path for determining an optimal path and a ACC (Acclimated Storage Tank) operating state by a DP (Dynamic Programming) path search based on result data according to the execution of the EHLD program in the second EHLD program execution step (S160) (S170);
Using the optimum result of the DP path search in the optimal path and the heat storage tank operating state determination step (S170), the fuel cost according to the forced, unforced and fuel cost is calculated, and the system heat, energy production amount, (S180) for analyzing the result of the non-link system alone;
The optimal operating condition of each system (10,20) is calculated by calculating the change in fuel cost due to the linkage, calculating the hourly and weekly trading volume at the time of linkage, calculating the linkage limit backward cost and the heat transaction unit price, (S190) of calculating an optimal amount of radiation between each system (10, 20)
An Optimal Operation Plan for Heat Transactions between Heat and Combined Heat Exchangers and Algorithm for Calculating Thermal Transaction Price.
The method according to claim 1,
After the forced operation setting step (S140), the axial heat releasable capacity is calculated according to the number of the ACC operation states of each system (10, 20) (S150) of generating a heat storage tank condition for generating a heat storage tank condition (S150).

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