This application claims priority to and benefits of Chinese Patent Application No. 201710097510.9, filed with the State Intellectual Property Office of P. R. China on Feb. 22, 2017, the entire contents of which are incorporated herein by reference.
The present disclosure relates to the power system operation technology field, and more particularly, to a dispatch method and a dispatch apparatus for a combined heat and power system.
A combined heat and power (CHP for short) system may include electric power systems (EPSs for short) and central heating systems (CHSs for short). For example, the CHP system may include CHP units, non-CHP thermal units, wind farms and heating boilers. The CHP units are configured to generate electricity for the EPSs and useful heat for the CHSs at the same time. However, utilization of wind power in the CHP system has encountered a critical problem in winter. For example, the wind resources are abundant but the electricity load is insufficient. More seriously, a significant conflict exists between the CHSs and wind power utilization. CHSs are supplied by the CHP units, and the generation output of a CHP unit is determined solely by the heat load demand A typical daily residential heat load curve peak occurs at nighttime, which is exactly when the daily curve of wind power peaks. Due to heating supply priority, CHP units must generate a large amount of electricity overnight, and thus wind power generation must be restricted. This conflict between the central heating supply and wind power utilization exists in urban areas with CHSs all over the world.
Embodiments of the present disclosure provide a dispatch method for controlling a combined heat and power (CHP for short) system. The CHP system includes CHP units, non-CHP thermal units, wind farms and heating boilers; the CHP units, the non-CHP thermal units and the wind farms form an electric power system (EPS for short) of the CHP system; the CHP units and the heating boilers form a central heating system (CHS for short) of the CHP system; and the EPS and the CHS are isolable. The method includes: establishing a combined heat and power dispatch (CHPD for short) model of the CHP system, in which an objective function of the CHPD model is a minimizing function of a total generation cost of the CHP units, the non-CHP thermal units, the wind farms and the heating boilers and constraints of the CHPD model are established based on generation cost of the CHP units, the non-CHP thermal units, the wind farms and the heating boilers; solving the CHPD model based on Benders decomposition to obtain dispatch parameters for the EPS and the CHS; and controlling the EPS and the CHS according to the corresponding dispatch parameters respectively.
Embodiments of the present disclosure provide a dispatch device for controlling a CHP system. The CHP system includes CHP units, non-CHP thermal units, wind farms and heating boilers; the CHP units, the non-CHP thermal units and the wind farms form an EPS of the CHP system; the CHP units and the heating boilers form a CHS of the CHP system; and the EPS and the CHS are isolable. The device includes a processor; and a memory for storing instructions executable by the processor, in which the processor is configured to perform the above dispatch method for controlling a CHP system.
Embodiments of the present disclosure provide a non-transitory computer-readable storage medium having stored therein instructions that, when executed by a processor of a computer, causes the computer to perform the above dispatch method for controlling a CHP system.
It is to be understood that both the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive of the invention, as claimed.
In order to explicitly illustrate embodiments of the present disclosure, a brief introduction for the accompanying drawings corresponding to the embodiments will be listed as follows. Apparently, the drawings described below are only corresponding to some embodiments of the present disclosure, and those skilled in the art may obtain other drawings according to these drawings without creative labor.
In order to make objectives, technical solutions and advantages of the present disclosure clearer, in the following the present disclosure will be described in detail with reference to drawings. Apparently, the described embodiments are only some embodiments of the present disclosure and do not represent all the embodiments. Based on the embodiment described herein, all the other embodiments obtained by those skilled in the art without creative labor belong to the protection scope of the present disclosure.
At block 10, a combined heat and power dispatch (CHPD for short) model of the CHP system is established. An objective function of the CHPD model is a minimizing function of a total generation cost of the CHP units, the non-CHP thermal units, the wind farms and the heating boilers and constraints of the CHPD model are established based on generation cost of the CHP units, the non-CHP thermal units, the wind farms and the heating boilers.
At block 20, the CHPD model is solved based on Benders decomposition to obtain dispatch parameters for the EPS and the CHS.
At block 30, the EPS and the CHS are controlled respectively according to the corresponding dispatch parameters.
In the following, the dispatch method will be described in detail.
(1) The CHPD model of the CHP system is established. The CHPD model includes the objective function and the constraints. The CHPD model is described in detail as follows.
(1-1) The objective function of the CHPD model
The objective function of the CHPD model aims to minimize a total generation cost of the CHP units, the non-CHP thermal units, the wind farms and the heating boilers. The total generation cost is established by a formula of
where, t represents a dispatch time period, T represents an index set of dispatch time periods, ICHP represents an index set of the CHP units, ITU represents an index set of the non-CHP thermal units, IWD represents an index set of the wind farms, IHB represents an index set of the heating boilers, Ci,tCHP represents a generation cost function of CHP unit i during period t, Ci,tTU represents a generation cost function of non-CHP thermal unit i during the period t, Ci,tWD represents a generation cost function of wind farm i during the period t, and Ci,tHB represents a generation cost function of heating boiler i during the period t.
The generation cost function of the CHP unit i during the period t is established by a formula of
C
i,t
CHP(pi,tCHP,qi,tCHP)=CiCHP,0+CiCHP,p1·pi,tCHP+CiCHP,q1·qi,tCHP+CiCHP,p2·(pi,tCHP)2+CiCHP,q2·(qi,tCHP)2+CiCHP,pq2·pi,tCHPqi,tCHP,∀iϵICHP,∀tϵT
where, CiCHP,0, CiCHP,p1, CiCHP,q1, CiCHP,p2, CiCHP,q2 and CiCHP,pq2 represent generation cost coefficients of the CHP unit i, pi,tCHP represents a power output of the CHP unit i during the period t, and qi,tCHP represents a heat output of the CHP unit i during the period t. The generation cost coefficients are characteristic parameters of the CHP unit.
The generation cost function of the non-CHP thermal unit i during the period t is established by a formula of
C
i,t
TU(pi,tTU)=CiTU,0+CiTU,p1pi,tTU+CiTU,p2·(pi,tTU)2,∀iϵITU,∀tϵT
and CiTU,0, CiTU,p1 and CiTU,p2 represent generation cost coefficients of the non-CHP thermal unit i, and pi,tTU represents a power output of the non-CHP thermal unit i during the period t. Similarly, the generation cost coefficients are characteristic parameters of the non-CHP thermal unit.
The generation cost function of the wind farm i during the period t is established by a formula of
C
i,t
WD(pi,tWD)=CiWD,ply(
where, CiWD,pty represents a penalty coefficient,
The generation cost function of the heating boiler i during the period t is established by a formula of
C
i,t
HB(qi,tHB)=CiHB·qi,tHB,∀iϵIHB,∀tϵT
where, CiHB represents a generation cost coefficient of the heating boiler i, which is a characteristic parameter of the heating boiler i, and qi,tHB represents a heat output of the wind farm i during the period t.
(1-2) The constraints of the CHPD model
The constraints of the CHPD model include constraints of the EPS and constraints of the CHS.
The constraints of the EPS include operation constraints of the CHP units, ramping up and down constraints of the CHP units, operation constraints of the non-CHP thermal units, ramping up and down constraints of the non-CHP thermal units, spinning reserve constraints of the non-CHP thermal units, operation constraints of the wind farms, a power balance constraint of the EPS, a line flow limit constraint of the EPS, and a spinning reserve constraint of the EPS.
The constraints of the CHS include: constraints between supply/return water temperature differences of nodes and heat outputs, heat output constraints of the heating boilers, supply water temperature constraints at nodes with heat sources connected, constraints between supply/return water temperature differences of nodes and heat exchanges of heat exchange stations, return water temperature constraints of heat exchange stations, and operation constraints of heating networks of the CHS.
(1-2-1) The constraints of the EPS.
The operation constraints of the CHP units are denoted by a formula of
where, NEi represents an index set of extreme points of the CHP unit i, Piγ, Qiγ represent respectively a power output at extreme point γ of the CHP unit i and a heat output at the extreme point γ of the CHP unit i, and αi,tγ represents a convex combination coefficient of the extreme point γ of the CHP unit i during the period t. The extreme points refer to points formed by heat output limits and power output limits of the CHP units.
The ramping up and down constraints of the CHP units are denoted by a formula of
−RDiCHP·ΔT≤pi,t+1CHP−pi,tCHP≤RUiCHP·ΔT,∀iϵICHP,∀tϵT
where, RUiCHP represents an upward ramp rate of the CHP unit i, RDiCHP represents a downward ramp rate of the CHP unit i, pi,t+1CHP represents a power output of the CHP unit i during period t+1, and ΔT represents a dispatch interval.
The operation constraints of the non-CHP thermal units are denoted by a formula of
P
i
TU
≤pi,tTU≤
where,
The ramping up and down constraints of the non-CHP thermal units are denoted by a formula of
−RDiTU·ΔT≤pi,t+1TU−pi,tTU≤RUiTUΔ·T,∀iϵITU,∀tϵT
where, RUiTU represents an upward ramp rate of the non-CHP thermal unit i, RDiTU represents a downward ramp rate of the non-CHP thermal unit i, and pi,t+1TU represents a power output of the non-CHP thermal unit i during period t+1.
The spinning reserve constraints of the non-CHP thermal units are denoted by a formula of
0≤rui,tTU≤RUiTU,rui,tTU≤
0≤rdi,tTU≤RDiTU,rdi,tTU≤pi,tTU−
where, rui,tTU represents an upward spinning reserve contribution of the non-CHP thermal unit i during the period t, and rdi,tTU represents a downward spinning reserve contribution of the non-CHP thermal unit i during the period t.
The operation constraints of the wind farms are denoted by a formula of
0≤pi,tWD≤PiWD,∀iϵIWD,∀tϵT
where, pi,tWD represents a power output of the wind farm i during the period t, and
The power balance constraint of the EPS is denoted by a formula of
where, ILD represents an index set of loads in the EPS and Dm,t represents a power demand of load m in the EPS during the period t.
The line flow limit constraint of the EPS is denoted by a formula of
where, IEPS represents an index set of buses in the EPS, SFj-l represents a shift factor for bus l on line j of the EPS, IEPS,lCHP represents an index set of CHP units connected to the bus l of the EPS, IEPS,lTU represents an index set of non-CHP thermal units connected to the bus l of the EPS, IEPS,lWD represents an index set of wind farms connected to the bus l of the EPS, IEPS,lLD represents an index set of loads connected to the bus l of the EPS, Li represents a flow limit of the line j of the EPS, and ILN represents an index set of lines in the EPS.
The spinning reserve constraint of the EPS is denoted by a formula of
where, SRUt represents an upward spinning reserve demand of the EPS during the period t and SRDt represents a downward spinning reserve demand of the EPS during the period t.
(1-2-2) The constraints of the CHS
(1-2-2-1) Heating constraints of heat sources of the CHP units and the heating boilers
The constraints between the supply/return water temperature differences of the nodes and the heat outputs are denoted by a formula of
where, ICHS,kCHP represents an index set of CHP units connected to node k of the CHS, ICHS,kHB represents an index set of heating boilers connected to the node k of the CHS, C represents a specific heat capacity of water, MkN represents a total mass flow rate of water at the node k of the CHS, τk,tS represents a water temperature of the node k in supply pipelines of the CHS during the period t, τk,tR represents a water temperature of the node k in return pipelines of the CHS during the period t, and IHSCHS represents an index set of nodes with heat sources connected in the CHS.
The heat output constraints of the heating boilers are denoted by a formula of
0≤qi,tHB≤
where,
The supply water temperature constraints at the nodes with heat sources connected are denoted by a formula of
T
k
S
≤τk,tS≤
where,
(1-2-2-2) Operation constraints of the heat exchange stations
The constraints between the supply/return water temperature differences of the nodes and the heat exchanges of the heat exchange stations in the CHS are denoted by a formula of
where, ICHS,kHES represents an index set of heat exchange stations connected to node k of the CHS, Qn,tHES represents a heat exchange of heat exchange station n during the period t, C represents a specific heat capacity of water, MkN represents a total mass flow rate of water at the node k of the CHS, and IHESCHS represents an index set of nodes with heat exchange stations connected in the CHS.
The return water temperature constraints of the heat exchange stations are denoted by a formula of
T
k
R
≤τk,tR≤
where,
(1-2-2-3) Operation constraints of heating networks
The operation constraints of the heating networks of the CHS are denoted by a formula of
where, Mk2→k1B,S represents a mass flow rate of water transferred from node k2 to node k1 in supply pipelines of the CHS, Mk2→k1B,R represents a mass flow rate of return water transferred from the node k2 to the node k1 in return pipelines of the CHS, ICHS,k1CN,S represents an index set of child nodes of the node k1 in supply pipelines of the CHS, ICHS,k1CN,R represents an index set of child nodes of the node k1 in return pipelines of the CHS, TtAMB represents an ambient temperature during the period t, HLk2→k1S represents a heat transfer factor of water transferred from the node k2 to the node k1 in supply pipelines of the CHS, HLk2→k1R represents a heat transfer factor of water transferred from the node k2 to the node k1 in return pipelines of the CHS.
HLk2→k1S and HLk2→k1R are calculated by a formula of
where, Yk2→k1S represents a heat transfer coefficient per unit length of pipeline from the node k2 to the node k1 in the supply pipelines of the CHS, Yk2→k1R represents a heat transfer coefficient per unit length of pipeline from the node k2 to the node k1 in the return pipelines of the CHS, Lk2→k1S represents a length of the supply pipeline from the node k2 to the node k1, Lk2→k1R represents a length of the return pipeline from the node k2 to the node k1.
τk2→k1,tS,temp and τk2→k1,tR,temp are intermediate variables representing temperature of the node k1 and only considering a transfer delay of water from its child node k2, wherein τk2→k1,tS,temp and τk2→k1,tR,temp are denoted by a formula of
τk2→k1,tS,temp=(└Φk2→k1S┘+1−Φk2→k1S)τk2,t−└Φ
τk2→k1,tR,temp=(└Φk2→k1R┘+1−Φk2→k1R)τk2,t−└Φ
where, Φk2→k1S represents transfer time periods of water from the node k2 to the node k1 in supply pipelines of the CHS, Φk2→k1R represents transfer time periods of water from the node k2 to the node k1 in return pipelines of the CHS, and └⋅┘ represents a rounding down operator.
(2) The CHPD model established in (1) is transformed into a model in a matrix form.
In detail, the CHPD model is summarized as a following quadratic programming (QP) problem in the matrix form by a formula of:
where, xE represents variables of the EPS, and the variables of the EPS comprises pi,tTU, rui,tTU, rdi,tTU, pi,tWD, pi,tCHP, qi,tCHP and αi,tγ; and xH represents variables of the CHS, and the variables of the CHS comprises qi,tHB, τk,tS and τk,tR.
CE represents the objective function of the EPS and CH represents the objective function of the CHS. CE refers to
and CH refers to
AExE≤bE refers to the constraints of the EPS, which includes all constraints described in (1-2-1). Each row in AE and bE has one-to-one correspondence with each constraint in the EPS. Each column in AE and bE has one-to-one correspondence with each variable in the EPS. Each element in AE is a coefficient of a variable corresponding to a column where the element is located in a constraint corresponding to a row where the element is located. Elements in each row in bE are inequality constant terms in the constraint corresponding to the elements.
AHxH≤bH refers to the constraints of the CHS except the constraints between the supply/return water temperature differences of the nodes and the heat outputs, which includes the constraints described in (1-2-2) except the constraints between the supply/return water temperature differences of the nodes and the heat outputs. Each row in AH and bH has one-to-one correspondence with each constraint in the CHS. Each column in AH and bH has one-to-one correspondence with each variable in the CHS. Each element in AH is a coefficient of a variable corresponding to a column where the element is located in a constraint corresponding to a row where the element is located. Elements in each row in bH are inequality constant terms in the constraint corresponding to the elements.
DxE+ExH≤f refers to the constraints between the supply/return water temperature differences of the nodes and the heat outputs described in (1-2-2), i.e. coupling constraints on the EPS and the CHS. Each row in D, E and f has one-to-one correspondence with each constraint in the coupling constraints on the EPS and the CHS. Each row in D has one-to-one correspondence with each variable in the EPS. Each row in E has one-to-one correspondence with each variable in the CHS. Each element in D and E is a coefficient of a variable corresponding to a column where the element is located in a constraint corresponding to a row where the element is located. Elements in each row in f are inequality constant terms in the constraint corresponding to the elements.
(3) The CHPD model in the matrix form described in (2) is solved by the Benders decomposition.
(3-1) Initializing: an iteration number m is initialized as 0, the number of optimal cuts p is initialized as 0 and the number of feasible cuts q is initialized as 0. Then an EPS problem is solved to obtain a solution as xE(m) by a formula of
(3-2) A CHS problem is solved according to the solution xE(m) by a formula of
(3-2-1) If the CHS problem in (3-2) is feasible, p is increased by 1 and an optimal cut is generated as follows,
A
p
OC
x
E
+b
p
OC,
where, AOC=λT, bOC=CH←E(xE(m))−λTxE(m), and λ represents a Lagrange multiplier of a constraint xE=xE(m) in (3-2), and CH←E(xE(m)) represents an objective value of the CHS problem in (3-2).
(3-2-2) If the CHS problem in (3-2) is infeasible, q is increased by 1 and an feasible cut is generated as follows,
A
q
FC
x
E
≤b
q
FC.
AqFC and bqFC are calculated according to following acts:
(3-2-2-1) denoting a feasibility problem of the CHS problem as a formula of:
(3-2-2-2) introducing a relaxation term ε to relax the feasibility problem of the CHS problem in (3-2-2-1) as a formula of:
(3-2-2-3) denoting a Lagrange multiplier of a constraint AHxH≤bH in the relaxed feasibility problem of the CHS problem (3-2-2-2) as û and a Lagrange multiplier of a constraint DxE(m)+ExH+1Tε≤f in the relaxed feasibility problem (3-2-2-2) as {circumflex over (v)}; and calculating AqFC and bqFC according to a formula of:
A
q
FC
={circumflex over (v)}
T
D,b
q
FC
=û
T
b
H
+{circumflex over (v)}
T
f.
(3-3) The EPS problem is solved by a formula of
the iteration number m is increased by 1 and a solution is denoted as xE(m).
(3-4) A convergence is checked. If ∥xE(m)−xE(m-1)∥∞<Δ, the iteration is terminated to obtain the dispatch parameters for the EPS and the CHS according to the solution, in which Δ is a convergence threshold, for example, a value of A is 0.001, and then (3-5) is executed; and if ∥xE(m)−xE(m-1)∥∞≥Δ, (3-2) is returned.
(3-5) The obtained solution is used as the dispatch parameters for the EPS and the CHS.
Embodiments of the present disclosure further provide a dispatch apparatus for controlling a CHP system. The device includes: a processor; and a memory for storing instructions executable by the processor. The processor is configured to perform the above method.
Embodiments of the present disclosure further provide a non-transitory computer readable storage medium. The non-transitory computer readable storage medium according to embodiments of the present disclosure may include instructions that, when executed by a processor of an apparatus, causes the apparatus to execute the above method.
The technical solutions provided by embodiments of the present disclosure have following advantageous effects.
In the technical solutions of the present disclosure, the CHPD model can be established by combining the dispatch model of the EPS and the dispatch model of the CHS. An algorithm for solving the proposed CHPD model is provided based on Benders decomposition. In the provided algorithm for solving the proposed CHPD model, the operator of the EPS and the operator of the CHS can optimize corresponding internal systems independently, and the global optimal solution of the CHPD model can be obtained based on the interactive iteration between the boundary conditions of the EPS and CHS. The provided algorithm for solving the proposed CHPD model may have a good convergence rate and significantly improve an operation flexibility of the CHS.
Any process or method described in the flowing diagram or other means may be understood as a module, segment or portion including one or more executable instruction codes of the procedures configured to achieve a certain logic function or process, and the preferred embodiments of the present disclosure include other performances, in which the performance may be achieved in other orders instead of the order shown or discussed, such as in an almost simultaneous way or in an opposite order, which should be appreciated by those having ordinary skills in the art to which embodiments of the present disclosure belong.
The logic and/or procedures indicated in the flowing diagram or described in other means herein, such as a constant sequence table of the executable code for performing a logical function, may be implemented in any computer readable storage medium so as to be adopted by the code execution system, the device or the equipment (such a system based on the computer, a system including a processor or other systems fetching codes from the code execution system, the device and the equipment, and executing the codes) or to be combined with the code execution system, the device or the equipment to be used. With respect to the description of the present invention, “the computer readable storage medium” may include any device including, storing, communicating, propagating or transmitting program so as to be used by the code execution system, the device and the equipment or to be combined with the code execution system, the device or the equipment to be used. The computer readable medium includes specific examples (a non-exhaustive list): the connecting portion (electronic device) having one or more arrangements of wire, the portable computer disc cartridge (a magnetic device), the random access memory (RAM), the read only memory (ROM), the electrically programmable read only memory (EPROMM or the flash memory), the optical fiber device and the compact disk read only memory (CDROM). In addition, the computer readable storage medium even may be papers or other proper medium printed with program, as the papers or the proper medium may be optically scanned, then edited, interpreted or treated in other ways if necessary to obtain the program electronically which may be stored in the computer memory.
It should be understood that, each part of the present disclosure may be implemented by the hardware, software, firmware or the combination thereof. In the above embodiments of the present invention, the plurality of procedures or methods may be implemented by the software or hardware stored in the computer memory and executed by the proper code execution system. For example, if the plurality of procedures or methods is to be implemented by the hardware, like in another embodiment of the present invention, any one of the following known technologies or the combination thereof may be used, such as discrete logic circuits having logic gates for implementing various logic functions upon an application of one or more data signals, application specific integrated circuits having appropriate logic gates, programmable gate arrays (PGA), field programmable gate arrays (FPGA).
It can be understood by those having the ordinary skills in the related art that all or part of the steps in the method of the above embodiments can be implemented by instructing related hardware via programs, the program may be stored in a computer readable storage medium, and the program includes one step or combinations of the steps of the method when the program is executed.
In addition, each functional unit in the present disclosure may be integrated in one progressing module, or each functional unit exists as an independent unit, or two or more functional units may be integrated in one module. The integrated module can be embodied in hardware, or software. If the integrated module is embodied in software and sold or used as an independent product, it can be stored in the computer readable storage medium.
The non-transitory computer-readable storage medium may be, but is not limited to, read-only memories, magnetic disks, or optical disks.
Reference throughout this specification to “an embodiment,” “some embodiments,” “one embodiment”, “another example,” “an example,” “a specific example,” or “some examples,” means that a particular feature, structure, material, or characteristic described in connection with the embodiment or example is included in at least one embodiment or example of the present disclosure. Thus, the appearances of the phrases such as “in some embodiments,” “in one embodiment”, “in an embodiment”, “in another example,” “in an example,” “in a specific example,” or “in some examples,” in various places throughout this specification are not necessarily referring to the same embodiment or example of the present disclosure. Furthermore, the particular features, structures, materials, or characteristics may be combined in any suitable manner in one or more embodiments or examples.
Although explanatory embodiments have been shown and described, it would be appreciated by those skilled in the art that the above embodiments cannot be construed to limit the present disclosure, and changes, alternatives, and modifications can be made in the embodiments without departing from spirit, principles and scope of the present disclosure.
Number | Date | Country | Kind |
---|---|---|---|
201710097510.9 | Feb 2017 | CN | national |
Filing Document | Filing Date | Country | Kind |
---|---|---|---|
PCT/CN2017/114317 | 12/1/2017 | WO | 00 |