A natural gas and electricity complementary energy management system

Abstract

The present invention relates to a natural gas and electricity complementary energy management system, comprising a day-ahead scheduling optimization module and a real-time scheduling optimization module; the day-ahead scheduling optimization module comprises a day-ahead prediction unit and a day-ahead energy allocation unit, the day-ahead prediction unit is used to predict the energy load curve of the next day, and the day-ahead energy allocation unit is used to optimize the gas-electricity complementary energy allocation plan of the next day according to the energy load curve of the next day; the real-time scheduling optimization unit comprises a real-time prediction unit and a real-time energy allocation unit, the real-time prediction unit is used to predict the short-term energy load curve of the day, and the real-time energy allocation unit is used to optimize the short-term gas-electricity complementary energy allocation plan of the day according to the short-term energy load curve of the day. The present invention can fully promote multi-energy complementarity in the natural gas and electricity complementary energy system.

Description

Technical Field

[0001] The invention relates to a natural gas and electricity complementary energy management system. Background Art

[0002] As a clean and efficient energy source, natural gas accounts for an increasing proportion of energy consumption. Countries around the world are also continuously building natural gas units. For this reason, the coupling between natural gas systems and power systems is becoming increasingly close. Existing research on the management of natural gas and electricity complementary integrated energy systems often assumes that the demand for natural gas in the electrical network can be met at all times. For example, if a gas turbine suddenly changes its output, the mutual absorption capacity between the natural gas network and the electrical network is limited, and the natural gas network cannot meet the needs of the electrical network indefinitely. However, if the supply of natural gas and electricity is not reasonably adjusted, the advantages of natural gas power generation cannot be fully utilized. Therefore, the present invention proposes a day-ahead prediction and real-time optimization solution to provide the benefits of multi-energy complementarity and promote the further development of the natural gas and electricity complementary energy system. Summary of the Invention

[0003] The purpose of the present invention is to propose a natural gas and electricity complementary energy management system to ensure the safe, reliable and economical operation of the gas-electricity complementary integrated energy system.

[0004] To achieve the above objectives, an embodiment of the present invention proposes a natural gas and electricity complementary energy management system, including a day-ahead scheduling optimization module and a real-time scheduling optimization module;

[0005] The day-ahead scheduling optimization module includes a day-ahead prediction unit and a day-ahead energy allocation unit. The day-ahead prediction unit is used to predict the energy load curve of the next day. The day-ahead energy allocation unit is used to optimize the gas-electric complementary energy allocation plan for the next day according to the energy load curve of the next day, including the output of the gas turbine generator set for the next day, the natural gas injection flow rate of the gas source node for the next day, and the gas pressure at the adjustable point of the natural gas network for the next day;

[0006] The real-time scheduling optimization unit includes a real-time prediction unit and a real-time energy allocation unit. The real-time prediction unit is used to predict the short-term energy load curve of the day. The real-time energy allocation unit is used to optimize the short-term gas-electricity complementary energy allocation plan of the day according to the short-term energy load curve of the day, including the short-term gas turbine generator output of the day, the short-term gas source node natural gas injection plan of the day, and the short-term gas pressure of the adjustable point of the natural gas network.

[0007] Preferably, the optimization objective function F1(x) of the day-ahead scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and maximizing the natural gas pipeline network gas storage reserve function maxf3;

[0008]

[0009] Where N is the total number of components of the natural gas pipeline network, i represents the i-th component of the natural gas pipeline network, and F in is the energy supply income, F om is the operation and maintenance cost, F el is the electricity cost, F ga is the gas cost, F de is the equipment depreciation cost; C represents the primary energy consumption of the gas-electricity complementary integrated energy system, W i , Q i and R i They represent the electric power, thermal power and cooling power of the i-th component of the natural gas pipeline network; G3 represents the pipeline set of the natural gas pipeline network, LR i (k) represents the kth natural gas pipeline for gas storage and standby in the i-th component of the natural gas pipeline network, and S(k) represents the operating status of the kth natural gas pipeline, which is one of the two status values of being able to operate or not being able to operate.

[0010] Preferably, the optimization objective function F2(x) of real-time scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and minimizing the energy exchange offset minf3:

[0011]

[0012] Where P1(t) is the energy consumption process W in the day-ahead scheduling optimization model. i , Q i 、R i The intermediate solution value of the sum, P2(t+Δt) is the actual value of energy exchange, t is time, and the energy consumption process changes from t=1 to t=T, Δt=1 second.

[0013] Preferably, the optimization objective function F1(x) of the day-ahead scheduling and the optimization objective function F2(x) of the real-time scheduling both satisfy the following constraints, including: power transmission constraints, natural gas operation constraints, generator set output constraints, generator set ramping constraints, natural gas pipeline flow constraints, and natural gas generator set capacity constraints;

[0014] The power transfer constraints are:

[0015] Among them, P L,max is the upper limit of the maximum power flow of power system line L; is the input power range of line L;

[0016] The natural gas operation constraints are: F s,m +F P2G,m +C G,m -FD,m -F GPG,m -F m =0

[0017] Among them, F P2G,m is the natural gas injected by the power-to-gas equipment of the natural gas node; F D,m is the natural gas load demand of the natural gas node; F GPG,m F is the natural gas flow consumed by the natural gas generator at the natural gas node; m is the natural gas flow rate injected into the natural gas node; F s,m is the gas source flow rate at the natural gas node; C G,m is the natural gas load reduction at the natural gas system node;

[0018] The natural gas pipeline flow constraint is:

[0019]

[0020] Among them, C mn is the Weymouth constant of the natural gas transmission pipeline mn; π m , π n are the gas pressure values of m and n at the natural gas nodes respectively; F mm is the natural gas flow rate of the natural gas pipeline mn;

[0021] The capacity constraint of the natural gas generator set is:

[0022] F GPG,min,m ≤F GPG,m ≤F GPG,max,m

[0023] Among them, F GPG,min,m and F GPG,max,m They are the lower limit and upper limit of the natural gas flow consumed by the natural gas generator of the natural gas node.

[0024] The capacity utilization rate of the natural gas generator set is:

[0025]

[0026] Among them, GCU k and P r,GPG,k are the capacity utilization rate and rated capacity of the natural gas generator set; P GPG,k is the actual output value of the natural gas generator device; G s,k It is the set of states of the natural gas generator unit in operation;

[0027] The generator set output constraint is:

[0028]

[0029] in, is the power output of generator set k at time t; and are the minimum output and maximum power generation output respectively;

[0030] The generator set climbing constraint is:

[0031]

[0032] in, is the power output of generator set k at time t-1; and is the maximum rate of increase and the minimum rate of decrease of the output of the k generator set.

[0033] The embodiments of the present invention can improve the economic efficiency of gas-electricity complementarity, the gas storage reserve and overall energy efficiency in the natural gas network. In addition to solving the day-ahead scheduling optimization model to obtain the optimal day-ahead scheduling solution, the day-ahead scheduling data of energy exchange between the natural gas-electricity complementarity network and the main grid can be stored for use in actual scheduling. BRIEF DESCRIPTION OF THE DRAWINGS

[0034] In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0035] Figure 1 Schematic diagram of a natural gas and electricity complementary energy management system in an embodiment of the present invention. DETAILED DESCRIPTION

[0036] Various exemplary embodiments, features, and aspects of the present disclosure will be described in detail below with reference to the accompanying drawings. In addition, numerous specific details are provided in the following specific examples to better illustrate the present invention. Those skilled in the art will appreciate that the present invention can be practiced without certain specific details. In some instances, means well known to those skilled in the art are not described in detail in order to highlight the main points of the present invention.

[0037] See Figure 1 , an embodiment of the present invention proposes a natural gas and electricity complementary energy management system, including a day-ahead scheduling optimization module 1 and a real-time scheduling optimization module 2;

[0038] The day-ahead scheduling optimization module 1 includes a day-ahead prediction unit 11 and a day-ahead energy allocation unit 12. The day-ahead prediction unit 11 is used to predict the energy load curve of the next day. The day-ahead energy allocation unit 12 is used to optimize the gas-electric complementary energy allocation plan for the next day according to the energy load curve of the next day, including the output of the gas turbine generator set for the next day, the natural gas injection flow rate of the gas source node for the next day, and the gas pressure at the adjustable point of the natural gas network for the next day;

[0039] The real-time scheduling optimization unit 2 includes a real-time prediction unit 21 and a real-time energy allocation unit 22. The real-time prediction unit 21 is used to predict the short-term energy load curve of the day. The real-time energy allocation unit 22 is used to optimize the short-term gas-electricity complementary energy allocation plan of the day according to the short-term energy load curve of the day, including the short-term gas turbine generator output of the day, the short-term gas source node natural gas injection plan of the day, and the short-term natural gas network adjustable point gas pressure of the day.

[0040] Specifically, in this embodiment, the gas-electricity complementary energy allocation plan for the next day is first optimized, and then the gas-electricity complementary energy allocation plan optimized the day before is operated and production is carried out on the same day; real-time optimization is also performed on the same day, and real-time optimization refers to optimizing the short-term gas-electricity complementary energy allocation plan, for example, the gas-electricity complementary energy allocation plan for the next 1 to 2 hours.

[0041] Specifically, the optimization objective function F1(x) of day-ahead scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and maximizing the natural gas pipeline network gas storage reserve function maxf3;

[0042]

[0043] Where N is the total number of components of the natural gas pipeline network, i represents the i-th component of the natural gas pipeline network, and F in is the energy supply income, F om is the operation and maintenance cost, F el is the electricity cost, F ga is the gas cost, F de is the equipment depreciation cost; C represents the primary energy consumption of the gas-electricity complementary integrated energy system, W i , Q i and R i They represent the electric power, thermal power and cooling power of the i-th component of the natural gas pipeline network; G3 represents the pipeline set of the i-th component, LR i (k) represents the kth natural gas pipeline for gas storage and standby of the i-th component of the natural gas pipeline network, and S(k) represents the operating status of the kth natural gas pipeline, which is one of the two status values of being able to operate or not being able to operate. In this embodiment, S(k) = 0 or 1.

[0044] Specifically, the optimization objective function F2(x) of real-time scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and minimizing the energy exchange offset minf3:

[0045]

[0046] Where P1(t) is the energy consumption process W in the day-ahead scheduling optimization model. i , Q i 、R i The intermediate solution value of the sum, P2(t+Δt) is the actual value of energy exchange, t is time, and the energy consumption process changes from t=1 to t=T, Δt=1 second.

[0047] Specifically, the optimization objective function F1(x) of the day-ahead scheduling and the optimization objective function F2(x) of the real-time scheduling both satisfy the following constraints, including: power transmission constraints, natural gas operation constraints, generator output constraints, generator ramp constraints, natural gas pipeline flow constraints, and natural gas generator capacity constraints;

[0048] The power transfer constraints are:

[0049] Among them, P L,max is the upper limit of the maximum power flow of power system line L; is the input power range of line L;

[0050] The natural gas operation constraints are: F s,m +F P2G,m +C G,m -F D,m -F GPG,m -F m =0

[0051] Among them, F P2G,m is the natural gas injected by the power-to-gas equipment of the natural gas node; F D,m is the natural gas load demand of the natural gas node; F GPG,m F is the natural gas flow consumed by the natural gas generator at the natural gas node; m is the natural gas flow rate injected into the natural gas node; F s,m is the gas source flow rate at the natural gas node; C G,m is the natural gas load reduction at the natural gas system node;

[0052] The natural gas pipeline flow constraint is:

[0053]

[0054] Among them, C mnis the Weymouth constant of the natural gas transmission pipeline mn; π m , π n are the gas pressure values of m and n at the natural gas nodes respectively; F mn is the natural gas flow rate of the natural gas pipeline mn;

[0055] The capacity constraint of the natural gas generator set is:

[0056] F GPG,min,m ≤F GPG,m ≤F GPG,max,m

[0057] Among them, F GPG,min,m and F GPG,max,m They are the lower limit and upper limit of the natural gas flow consumed by the natural gas generator of the natural gas node.

[0058] The capacity utilization rate of the natural gas generator set is:

[0059]

[0060] Among them, GCU k and P r,GPG,k are the capacity utilization rate and rated capacity of the natural gas generator set; P GPG,k is the actual output value of the natural gas generator device; G s,k It is the set of states of the natural gas generator unit in operation;

[0061] The generator set output constraint is:

[0062]

[0063] in, is the power output of generator set k at time t; and are the minimum output and maximum power generation output respectively;

[0064] The generator set climbing constraint is:

[0065]

[0066] in, is the power output of generator set k at time t-1; and is the maximum rate of increase and the minimum rate of decrease of the output of the k generator set.

[0067] The embodiments of the present invention can improve the economic efficiency of gas-electricity complementarity, the gas storage reserve and overall energy efficiency in the natural gas network. In addition to solving the day-ahead scheduling optimization model to obtain the optimal day-ahead scheduling solution, the day-ahead scheduling data of energy exchange between the natural gas-electricity complementarity network and the main grid can be stored for use in actual scheduling.

[0068] While various embodiments of the present invention have been described above, the above descriptions are intended to be illustrative, non-exhaustive, and not limited to the disclosed embodiments. Many modifications and variations will be apparent to those skilled in the art without departing from the scope and spirit of the described embodiments. The terminology used herein is selected to best explain the principles of the embodiments, their practical applications, or technological improvements in the marketplace, or to enable others skilled in the art to understand the embodiments disclosed herein.

Claims

1. A natural gas and electricity complementary energy management system, characterized in that: Includes day-ahead scheduling optimization module and real-time scheduling optimization module; The day-ahead scheduling optimization module includes a day-ahead prediction unit and a day-ahead energy allocation unit. The day-ahead prediction unit is used to predict the energy load curve for the next day. The day-ahead energy allocation unit is used to optimize the gas-electric complementary energy allocation plan for the next day based on the energy load curve for the next day, including the output of the gas turbine generator set for the next day, the natural gas injection flow rate at the gas source node for the next day, and the gas pressure at the adjustable point of the natural gas network for the next day. The optimization objective function F1(x) of day-ahead scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and maximizing the natural gas pipeline network storage reserve function maxf3; Where N is the total number of components of the natural gas pipeline network, i represents the i-th component of the natural gas pipeline network, and F in is the energy supply income, F om is the operation and maintenance cost, F el is the electricity cost, F ga is the gas cost, F de is the equipment depreciation cost; C represents the primary energy consumption of the gas-electricity complementary integrated energy system, W i , Q i and R i They represent the electric power, thermal power and cooling power of the i-th component of the natural gas pipeline network; G3 represents the pipeline set of the natural gas pipeline network, LR i (k) represents the k-th natural gas pipeline for gas storage and standby in the i-th component of the natural gas pipeline network, and S(k) represents the operating status of the k-th natural gas pipeline, which is one of the two status values of being able to operate or not being able to operate; The real-time scheduling optimization unit includes a real-time prediction unit and a real-time energy allocation unit. The real-time prediction unit is used to predict the short-term energy load curve of the day. The real-time energy allocation unit is used to optimize the short-term gas-electricity complementary energy allocation plan of the day based on the short-term energy load curve of the day, including the short-term gas turbine generator output of the day, the short-term natural gas injection plan of the day's gas source node, and the short-term gas pressure of the day's adjustable point of the natural gas network; The optimization objective function F2(x) of real-time scheduling includes: maximizing the operating profit function maxf1, maximizing the energy utilization efficiency function maxf2, and minimizing the energy exchange offset minf3: Where P1(t) is the energy consumption process W in the day-ahead scheduling optimization model. i , Q i 、R i The intermediate solution value of the sum, P2(t+Δt) is the actual value of energy exchange, t is time, and the energy consumption process changes from t=1 to t=T, Δt=1 second; The optimization objective function F1(x) of the day-ahead scheduling and the optimization objective function F2(x) of the real-time scheduling both satisfy the following constraints, including: power transmission constraints, natural gas operation constraints, generator set output constraints, generator set ramping constraints, natural gas pipeline flow constraints, and natural gas generator set capacity constraints.

2. The system according to claim 1, wherein: The power transfer constraints are: Among them, P L,max is the upper limit of the maximum power flow of power system line L; is the input power range of line L; The natural gas operation constraints are: F s,m +F P2g,m +C G,m -F D,m -F GPG,m -F m =0 Among them, F P2G,m is the natural gas injected by the power-to-gas equipment of the natural gas node; F D,m is the natural gas load demand of the natural gas node; F GPG,m F is the natural gas flow consumed by the natural gas generator at the natural gas node; m is the natural gas flow rate injected into the natural gas node; F s,m is the gas source flow rate at the natural gas node; C G,m is the natural gas load reduction at the natural gas system node; The natural gas pipeline flow constraint is: Among them, C mn is the Weymouth constant of the natural gas transmission pipeline mn; π m , π n are the gas pressure values of m and n at the natural gas nodes respectively; F mn is the natural gas flow rate of the natural gas pipeline mn; The capacity constraint of the natural gas generator set is: F GPG,min,m ≤F GPG,m ≤F GPG,max,m Among them, F GPG,min,m and F GPG,max,m are the lower limit of the natural gas flow consumed by the natural gas generator of the natural gas node and the upper limit of the natural gas flow consumed by the natural gas generator; The capacity utilization rate of the natural gas generator set is: Among them, GCU k and P r,GPG,k are the capacity utilization rate and rated capacity of the natural gas generator set; P GPG,k is the actual output value of the natural gas generator device; G s,k It is the set of states of the natural gas generator unit in operation; The generator set output constraint is: in, is the power output of generator set k at time t; and are the minimum output and maximum power generation output respectively; The generator set climbing constraint is: in, is the power output of generator set k at time t-1; and is the maximum rate of increase and the minimum rate of decrease of the output of the k generator set.

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