CN115619006A - Electricity-gas-hydrogen series-parallel connection comprehensive energy system optimization scheduling method considering auxiliary service - Google Patents
Electricity-gas-hydrogen series-parallel connection comprehensive energy system optimization scheduling method considering auxiliary service Download PDFInfo
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Abstract
The invention discloses an electric-gas-hydrogen hybrid comprehensive energy system optimal scheduling method considering auxiliary services, provides an electric-gas hybrid comprehensive energy system optimal scheduling model considering green hydrogen injection, and considers power grid auxiliary services to support high-proportion new energy consumption. Firstly, establishing a natural gas system operation model considering green hydrogen injection and pipeline storage, wherein the natural gas system operation model comprises an electrical hydrogen production model and a natural gas system operation model considering pipeline hydrogen mixing; and then, considering the electric hydrogen production and the electric network auxiliary service for providing peak regulation and flexible standby in a multi-energy cooperation mode, and constructing an electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling model considering the auxiliary service. The invention can not only support the consumption of new energy through the electrohydrogen production and the multi-energy coordination, but also improve the operation flexibility of the system, and is expected to provide technical reference for the economic operation and auxiliary service of the comprehensive energy system under the condition of high proportion of new energy and green hydrogen permeation.
Description
Technical Field
The invention relates to the technical field of optimization scheduling of an integrated energy system, in particular to an electricity-gas-hydrogen hybrid integrated energy system optimization scheduling method considering auxiliary services.
Background
The high-proportion new energy grid connection mainly based on wind power and photovoltaic is an important measure for supporting the strategic and novel power system construction of carbon peak reaching and carbon neutralization in China. However, traditional power grids have relatively limited flexibility regulation resources, and intermittent new energy output brings challenges to safe and economic operation of the power system. The gradual maturity of the electrical hydrogen production technology and the natural gas pipeline hydrogen-doping technology provides a new idea for solving the problem. Specifically, the electrical hydrogen production technology can convert surplus new energy into hydrogen (green hydrogen) to be injected into a natural gas pipeline, and the natural gas pipeline is utilized to realize remote transmission and efficient utilization of hydrogen energy, so that support is provided for high-proportion new energy consumption and low-carbon transformation in the power and natural gas industry. The electric conversion gas is used as an important coupling unit for connecting a power system and a natural gas system, has quick response capability and flexible regulation characteristic, and plays an important role in the aspects of improving the new energy consumption capability of the system, reducing the carbon emission of the system, supporting the peak load regulation of a power grid and the like. Compared with the electric gas conversion efficiency of 60-65%, the electric hydrogen production efficiency (generally reaching 70-80%) is higher, so the electric hydrogen production economic feasibility is better. It is worth noting that hydrogen energy is a flexible energy carrier which is free of carbon, clean and capable of being converted with electricity in a bidirectional mode, and is expected to play a role in adjusting all links of a power system. The hydrogen energy is developed, the energy structure can be effectively optimized, the dependence of the energy industry on the traditional fossil energy is reduced, and the low-carbon transformation of the energy structure is promoted. However, the current hydrogen transportation pipeline network is not mature, and the auxiliary service research for the scheduling of the integrated energy system considering the electricity and hydrogen production, simultaneously considering the peak shaving and the flexible standby is relatively less.
Based on the above, the optimal scheduling of the electricity-gas-hydrogen hybrid comprehensive energy system needs to fully consider the following two aspects: firstly, analyzing the influence of the electric hydrogen production on system peak regulation and standby on the basis of considering the optimized dispatching of the electric-gas parallel-serial comprehensive energy system for the electric hydrogen production; and secondly, considering the influence of green hydrogen injection on the scheduling of the gas transmission network, and further analyzing the influence of the new energy permeability and the pipeline hydrogen mixing ratio limit on the scheduling of the comprehensive energy system.
Disclosure of Invention
The technical problem is as follows: the invention aims to overcome the defects of the prior art and provide an optimized scheduling method of an electric-gas-hydrogen hybrid comprehensive energy system considering auxiliary service, the influence of green hydrogen injection on the optimized scheduling of the electric-gas hybrid comprehensive energy system is considered, the auxiliary service of a power grid is used for supporting high-proportion new energy consumption, the values of electric hydrogen production and multi-energy synergy on supporting the new energy consumption and improving the system operation flexibility are quantitatively evaluated, and the influence mechanism of new energy permeability and pipeline hydrogen mixing ratio limitation on the scheduling result of the comprehensive energy system is analyzed. The invention can realize timely and sufficient consumption of new energy, effective improvement of multi-energy flow cross-coupling and cross-coordination capability and stable system economy, and is expected to provide technical reference for economic operation and auxiliary service of a comprehensive energy system under the condition of high proportion of new energy and green hydrogen permeation.
The technical scheme is as follows: the invention provides an electricity-gas-hydrogen hybrid comprehensive energy system optimization scheduling method considering auxiliary services, which comprises the following steps:
step 2, obtaining scene information of electric load, gas load and wind-solar output;
and 6, based on the electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling model considering the auxiliary service, solving the model by using a nonlinear optimization solver with the minimum sum of the natural gas system operation cost, the electric power system operation cost and the peak regulation cost as an objective function, and performing optimization scheduling on the natural gas system and the electric power system to obtain an electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling scheme considering the auxiliary service.
Further, in step 3, the natural gas system model includes electrical hydrogen production operation constraints and natural gas network operation constraints considering green hydrogen injection;
1) Electrohydrogen production operating constraints
In the formula:
electric power consumed by electroproduction of hydrogen h at time tRate P P2H ；
Represents the energy E of the hydrogen produced by the electroproduction of hydrogen h at the time t P2H ；
Represents the hydrogen flow F generated by the electroproduction of hydrogen h at the time t P2H ；
The maximum hydrogen energy generated by the hydrogen production h at the moment t;
is a high heating value of hydrogen; eta P2H Energy conversion efficiency for electroproduction of hydrogen;
2) Natural gas network operational constraints accounting for green hydrogen injection
0≤α≤α max (B-14)
In the formula: subscript w represents the source of natural gas; subscripts m and n denote natural gas nodes; g w (m) is a set of gas source points connected to node m;
supplying energy E to the natural gas from source w at time t S (ii) a Subscript h represents electrohydrogen production; g h (m) is an electrohydrogen production set connected to node m; subscript e represents gas load; g e (m) is the air load set connected to node m;
actual power (energy) consumed E for the gas load E at time t D (ii) a Subscript v denotes a generator set; g g (m) is a gas turbine set connected with node m;
gas energy E consumed by gas turbine group v at time t G (ii) a Subscript k denotes a natural gas compressor; g k (m) is a set of compressors connected to node m; g (m) is a natural gas pipeline set connected with the node m; e mn,t The energy of the gas at the head end of the pipeline m-n at the time t;
energy E of gas flowing through compressor k for time t C ；
The gas energy consumed for compressor k is a percentage of the delivered energy;
the average gas flow through the pipeline m-n at the moment t; pi m,t Is the pressure at node m at time t; pi n,t Is the pressure at node n at time t; w mn Weymouth constant, F, for pipe m-n mn,t The gas flow rate at the head end of the pipeline m-n at the time t; f nm,t Is the gas flow at the m-n tail end of the pipeline at the moment t; l is a radical of an alcohol mn,t The pipe stock of the pipe m-n at the time t; k mn Is the inventory constant of the pipeline m-n; h m,t Is the calorific value of the node m at the time t; h n,t Is the heat value of the node n at time t;
is the gas heat value H at the head end of the pipeline m-n at the time t L ；
For the gas calorific value H at the m-n end of the pipeline at time t L ；
Natural gas supply flow F for gas source w at time t S ；H gas The natural gas has high heat value, and the value is 38.29MJ/m3;
flow rate F of gas flowing through compressor k at time t C ；
Energy E required for the gas load E at time t L ；
And
energy is supplied to the natural gas with the minimum and the maximum gas source w respectively;
is the climbing upper limit of the air source w;
for the transmitted energy of compressor k;
and
respectively are the upper and lower pressure limits of the node m;
the value of the k inlet pressure of the compressor at the moment t;
the value of the k outlet pressure of the compressor at the moment t;
and
the upper and lower limits of the compression ratio of the compressor k are respectively; alpha is the hydrogen mixing ratio; alpha is alpha max The maximum hydrogen mixing ratio is Gpi, and the Gpi is a natural gas pipeline set; l is min Is the minimum value, L, of natural gas system inventory mn,T Representing the inventory of pipes m-n during the last period T.
Further, in step 4, the power system operation constraint included in the power system model is as follows:
in the formula: subscripts i and j denote power buses; subscript r denotes the new energy bank; subscript d represents the electrical load; the subscript REF denotes a referenceA bus bar; u shape v (i) The generator set is connected with a bus i; u shape r (i) Is a new energy machine set connected with the bus i; u shape d (i) Is the set of electrical loads connected to bus i; u shape h (i) Is a set of electrical hydrogen production units connected with a bus i; u (i) is a line set connected with the bus i;
active power output P of unit v at time t G ；
The power P of the new energy unit r at the moment t W 。
Power demand P for electric load d at time t L ；
Actual absorbed power P of electrical load d for time t D ；θ i,t Is the voltage phase angle of the bus i at the moment t; theta j,t Is the voltage phase angle of the bus j at the moment t; x is the number of ij And
line ij susceptance and maximum transmission capacity, respectively;
and with
The upper limit and the lower limit of the generating power of the unit v are respectively set;
maximum value of regulating variable for machine set v
Predicting power P for the day ahead of the new energy bank r at time t cal ；
And with
The minimum and maximum conversion power of the electrohydrogen production h are respectively; theta.theta. REF,t The voltage phase angle of the reference bus REF at time t.
Further, in step 4, a technical scheme for meeting the peak shaving and standby requirements of the system is provided as follows:
1) Technical scheme for meeting peak regulation requirement
The peak regulation requirement is changed into peak regulation cost by introducing an economic conversion coefficient epsilon, the peak regulation cost and the system operation cost form a lowest comprehensive cost target, and the economy of system operation is considered while peak regulation.
minF＝F E +F G +F P (B-26)
In the formula, F E For the operating costs of the power system, F G For the operating costs of natural gas systems, F P The peak shaving cost;
in the formula: omega c Is a coal-fired unit set; omega g Is a gas turbine set; t represents the number of time sections;
generating cost coefficient for the coal burner unit;
the operation and maintenance cost coefficient of the gas turbine set is obtained;
is the cut electrical load cost factor;
is the gas supply cost coefficient of the gas source w;
a gas-cut load cost coefficient; ε is the economic conversion coefficient, P t NL And
respectively representing the net load P of the system at time t NL And average net load
The calculation formula is as follows:
2) Technical scheme for meeting standby requirement
The standby requirement of the system is provided by a conventional generator set and electrical hydrogen production to stabilize the power balance problem caused by load, wind power and photovoltaic power prediction deviation.
In the formula:
flexible backup R indicating system needs at time t U ；
Lower flexible backup R indicating system need at time t D ；
And with
Respectively representing the predicted power P of the wind power k and the photovoltaic s at the moment t in the day cal ；α k 、α s And alpha d Respectively representing the FR coefficients of the wind power k, the photovoltaic s and the load d,
representing the flexible reserve capacity P provided by the conventional unit v at time t G,U ；
Represents the lower flexible spare capacity P provided by the conventional unit v at the moment t G,D ；
Represents the upper flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,U ；
Represents the lower flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,D ；
Indication of constantThe ratio of the rate of ascent of the gauge set v to its maximum capacity
Representing the ratio of the down-hill rate of the conventional unit v to its maximum capacity
Represents the ratio of the uphill gradient rate of the electroproduction of hydrogen h to the maximum capacity thereof
Represents the ratio of the downward climbing rate of the electroproduction of hydrogen h to the maximum capacity thereof
Drawings
FIG. 1 is a flow chart of the method of the present invention;
FIG. 2 is an integrated energy system algorithm diagram;
FIG. 3 is an electrohydrogen and gas evolution diagram;
fig. 4 shows a flexible backup configuration for each time period.
Detailed Description
The present invention is further illustrated by the following detailed description in conjunction with the accompanying drawings, which are meant to be illustrative only and not limiting as to the scope of the invention, which is to be given the full breadth of the appended claims and any and all modifications within the scope of the appended claims.
The invention provides an electricity-gas-hydrogen hybrid comprehensive energy system optimization scheduling method considering auxiliary services, which comprises the following steps:
step 2, obtaining scene information of electric load, gas load and wind-solar output;
and 6, based on the electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling model considering the auxiliary service, solving the model by using a nonlinear optimization solver with the minimum sum of the natural gas system operation cost, the electric power system operation cost and the peak regulation cost as an objective function, and performing optimization scheduling on the natural gas system and the electric power system to obtain an electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling scheme considering the auxiliary service.
In step 3, the natural gas system model comprises an electrohydrogen production operation constraint and a natural gas network operation constraint considering green hydrogen injection;
1) Electrical hydrogen production operating constraints
In the formula:
electric power P representing consumption of hydrogen h by electroproduction at time t P2H ；
Represents the energy E of the hydrogen produced by the electroproduction of hydrogen h at the moment t P2H ；
Shows the hydrogen flow F generated by the electroproduction of hydrogen h at the time t P2H ；
The maximum hydrogen energy generated by the hydrogen production h at the moment t;
is a high heating value of hydrogen; eta P2H Energy conversion efficiency for electroproduction of hydrogen;
2) Natural gas network operating constraints accounting for green hydrogen injection
0≤α≤α max (B-14)
In the formula: subscript w represents the source of natural gas; subscripts m and n denote natural gas nodes; g w (m) is a set of gas source points connected to node m;
energy E for natural gas supply of gas source w at time t S (ii) a Subscript h represents electrohydrogen production; g h (m) is an electrohydrogen production assembly connected to node m; subscript e represents gas load; g e (m) is the air load set connected to node m;
actual power (energy) consumed E for the gas load E at time t D (ii) a Subscript v denotes a genset; g g (m) is a gas turbine set connected with node m;
gas energy E consumed by gas turbine set v at time t G (ii) a Subscript k denotes a natural gas compressor; g k (m) is a set of compressors connected to node m; g (m) is a natural gas pipeline set connected with the node m; e mn,t The energy of the gas at the head end of the pipeline m-n at the time t;
energy E of gas flowing through compressor k for time t C ；
The gas energy consumed for compressor k is a percentage of the delivered energy;
the average gas flow through the pipeline m-n at the moment t; pi m,t Is the pressure at node m at time t; pi n,t Is the pressure at node n at time t; w is a group of mn Weymouth constant, F, for pipe m-n mn,t The gas flow rate at the head end of the pipeline m-n at the time t; f nm,t Is the gas flow at the m-n tail end of the pipeline at the time t; l is a radical of an alcohol mn,t The pipe stock of the pipe m-n at the time t; k mn Is the inventory constant of the pipeline m-n; h m,t Is the heat value of the node m at the time t; h n,t Is the calorific value of the node n at the time t;
is the gas heat value H at the head end of the pipeline m-n at the time t L ；
For the gas calorific value H at the m-n end of the pipeline at the time t L ；
Natural gas supply flow F for gas source w at time t S ；H gas The natural gas has high heat value, and the value is 38.29MJ/m3;
flow rate F of gas flowing through compressor k for time t C ；
Energy E required for the air load E at time t L ；
And
energy is supplied to the natural gas with the minimum and the maximum gas source w respectively;
is the climbing upper limit of the gas source w;
energy transfer for compressor k;
and
respectively are the upper and lower pressure limits of the node m;
the value of the k inlet pressure of the compressor at the moment t;
the value of the k outlet pressure of the compressor at the moment t;
and
the upper and lower limits of the compression ratio of the compressor k are respectively; alpha is the hydrogen mixing ratio; alpha is alpha max The maximum hydrogen mixing ratio is Gpi, and the Gpi is a natural gas pipeline set; l is min Is the minimum value, L, of natural gas system inventory mn,T Representing the inventory of pipes m-n during the last period T.
In step 4, the power system operation constraint included in the power system model is as follows:
in the formula: subscripts i and j denote power buses; subscript r denotes the new energy bank; subscript d represents the electrical load; subscript REF denotes a reference bus; u shape v (i) The generator set is connected with the bus i; u shape r (i) Is a new energy machine set connected with the bus i; u shape d (i) Is the set of electrical loads connected to bus i; u shape h (i) Is a set of electric hydrogen production units connected with a bus i; u (i) is a line set connected with the bus i;
active power output P of unit v at time t G ；
The power P of the new energy unit r at the moment t W 。
Power demand P for electric load d at time t L ；
Actual absorbed power P of electrical load d for time t D ；θ i,t Is the voltage phase angle of the bus i at the moment t; theta j,t Is the voltage phase angle of the bus j at the moment t; x is a radical of a fluorine atom ij And
line ij susceptance and maximum transmission capacity, respectively;
and
upper and lower limits of generating power of unit v respectively；
Maximum value of regulating variable for machine set v
Predicting power P for new energy set r at t moment cal ；
And with
The minimum and maximum conversion power of the electrohydrogen production h are respectively; theta.theta. REF,t The voltage phase angle of the reference bus REF at time t.
In step 4, the technical scheme for meeting the peak regulation and standby requirements of the system is as follows:
1) Technical scheme for meeting peak regulation requirement
The peak regulation requirement is changed into peak regulation cost by introducing an economic conversion coefficient epsilon, the peak regulation cost and the system operation cost form a lowest comprehensive cost target, and the economy of system operation is considered while peak regulation.
minF＝F E +F G +F P (B-26)
In the formula, F E For the operating costs of the power system, F G For the operating costs of natural gas systems, F P The peak shaving cost;
in the formula: omega c Is a coal-fired unit set; omega g Is a gas turbine set; t represents the number of time sections;
for coal-fired machinesThe generating cost coefficient of the unit;
the operation and maintenance cost coefficient of the gas turbine set;
a power-off load cost factor;
is the gas supply cost coefficient of the gas source w;
a gas-cut load cost coefficient; ε is the economic conversion coefficient, P t NL And
respectively representing the net load P of the system at time t NL And average net load
The calculation formula is as follows:
2) Technical scheme for meeting standby requirement
The system's backup requirements are provided by conventional generator sets and electrical hydrogen production to stabilize power balance issues due to load, wind power, photovoltaic power forecast deviations.
In the formula:
flexible backup R indicating system needs at time t U ；
Lower flexible backup R indicating system need at time t D ；
And with
Respectively represents the predicted powers P of the wind power k and the photovoltaic s at the moment t cal ；α k 、α s And alpha d Respectively representing the FR coefficients of the wind power k, the photovoltaic s and the load d,
representing the flexible reserve capacity P provided by the conventional unit v at time t G,U ；
Represents the lower flexible spare capacity P provided by the conventional unit v at the moment t G,D ；
Represents the upper flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,U ；
Represents the lower flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,D ；
Representing the ratio of the rate of ascent of a conventional unit v to its maximum capacity
Representing the ratio of the down-hill rate of the conventional unit v to its maximum capacity
Represents the ratio of the uphill gradient rate of the electroproduction of hydrogen h to the maximum capacity thereof
Represents the ratio of the downward climbing speed of the electroproduction of hydrogen h to the maximum capacity thereof
Analysis of examples
The present invention employs a modified belgium 24-node power system and a 20-node natural gas system as shown in fig. 2; wherein the gas turbine groups of power nodes 2,6,8, 13, 15 and 22 are connected to gas nodes 4,6, 11 and 13, respectively. The total installed capacity of the electric power system is 19.95GW, wherein the installed capacities of the new energy and the gas turbine set account for 30% and 17% of the total installed capacity respectively. In addition, the input ends of the electrical hydrogen production equipment are respectively connected with the power grid nodes 2,3,5,6,7,8 and 9, and the output ends are respectively connected with the natural gas network nodes 2,3,4, 11,4 and 7. The method is realized through a GAMS optimization platform, and an IPOPT solver is adopted to solve the nonlinear programming problem.
Based on the calculation example, by comparing the electric hydrogen production and gas turbine unit output (fig. 3) of the scene 1 (without considering the auxiliary service model, the objective function is only the system operation cost target) and the scene 3 (with considering the auxiliary service model, and the objective function comprehensively considers the system operation cost target and the peak shaver target), and considering the flexible spare quantity (fig. 4) provided by each unit under the scene 3, the method simulates the value of the electric hydrogen production and the multi-energy synergy for supporting new energy consumption and improving the system operation flexibility (the result is shown in fig. 3 and 4) and the influence of green hydrogen injection on the system economic scheduling result (the result is shown in table 1). The electric hydrogen production and gas turbine set can provide important support for auxiliary service of a power grid, and particularly, the gas turbine set mainly undertakes flexible adjustment tasks by virtue of the rapid adjustment capacity of the gas turbine set. Increasing the maximum hydrogen loading ratio of the natural gas pipeline is beneficial to reducing the operation cost of the system (table 1).
TABLE 1 System cost at different Hydrogen Loading ratios
The invention can not only improve the capacity of the system for absorbing new energy through the synergistic action of the electrical hydrogen production and the gas turbine set, but also effectively utilize the operation flexibility of the electrical hydrogen production and the multi-energy synergy, improve the stable and flexible operation of the system, reduce the operation cost of the system and improve the low carbon property and the economy of the system.
The above description is only for the specific embodiment of the present invention, but the scope of the present invention is not limited thereto, and any changes or substitutions that can be easily conceived by those skilled in the art within the technical scope of the present invention are included in the scope of the present invention.
Claims (4)
1. An electric-gas-hydrogen hybrid comprehensive energy system optimal scheduling method considering auxiliary services is characterized by comprising the following steps:
step 1, obtaining operation parameters of a comprehensive energy system, wherein the operation parameters comprise parameter information of a generator set, an electric hydrogen production system, a circuit, an air source, a pipeline and a compressor;
step 2, obtaining scene information of electric load, gas load and wind-solar output;
step 3, based on the obtained scene information of the electric load, the gas load and the wind-light output, establishing a natural gas system model which meets the operation constraint of the electric hydrogen production and the natural gas network operation constraint considering the green hydrogen injection according to the operation mechanism of the natural gas pipeline containing the electric hydrogen production and the green hydrogen injection;
step 4, establishing a power system model meeting a plurality of power constraints, and providing a technical scheme meeting system peak shaving and standby requirements by considering the flexible regulation capacity required by a power system;
step 5, establishing an electricity-gas-hydrogen hybrid comprehensive energy system optimization scheduling model considering auxiliary services according to the natural gas system model, the electric power system model and the proposed technical scheme;
and 6, based on the electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling model considering the auxiliary service, solving the model by using a nonlinear optimization solver with the minimum sum of the operation cost of the natural gas system, the operation cost of the electric power system and the peak shaving cost as an objective function, and performing optimization scheduling on the natural gas system and the electric power system to obtain an electric-gas-hydrogen hybrid comprehensive energy system optimization scheduling scheme considering the auxiliary service.
2. The optimal scheduling method for the electric-gas-hydrogen hybrid integrated energy system considering the auxiliary service as claimed in claim 1, wherein in step 3, the natural gas system model includes electric hydrogen production operation constraints and natural gas network operation constraints considering green hydrogen injection;
1) Electrical hydrogen production operating constraints
In the formula:
electric power P representing consumption of hydrogen h by electroproduction at time t P2H ；
Represents the energy E of the hydrogen produced by the electroproduction of hydrogen h at the moment t P2H ；
Shows the hydrogen flow F generated by the electroproduction of hydrogen h at the time t P2H ；
The maximum hydrogen energy generated by the hydrogen production h at the moment t;
is a high heating value of hydrogen; eta P2H Energy conversion efficiency for electroproduction of hydrogen;
2) Natural gas network operational constraints accounting for green hydrogen injection
0≤α≤α max (-14)
In the formula: subscript w represents the source of natural gas; subscripts m and n denote natural gas nodes; g w (m) is a set of gas source points connected to node m;
supplying energy E to the natural gas from source w at time t S (ii) a Subscript h represents electrohydrogen production; g h (m) is an electrohydrogen production assembly connected to node m; subscript e represents gas load; g e (m) is the set of air loads connected to node m;
actual power (energy) consumed E for the gas load E at time t D (ii) a Subscript v denotes a generator set; g g (m) is a gas turbine set connected with node m;
gas energy E consumed by gas turbine set v at time t G (ii) a G (m) is a natural gas pipeline set connected with the node m; e mn,t The energy of the gas at the head end of the pipeline m-n at the time t; subscript k denotes a natural gas compressor; g k (m) is a set of compressors connected to node m;
energy E of gas flowing through compressor k for time t C ；θ k The gas energy consumed for compressor k is a percentage of the delivered energy;
the average gas flow through the pipeline m-n at the moment t; pi m,t Is the pressure at node m at time t; pi n,t Is the pressure at node n at time t; w mn Weymouth constant, F, for pipe m-n mn,t The gas flow at the head end of the pipeline m-n at the time t; f nm,t Is the gas flow at the m-n tail end of the pipeline at the moment t; l is a radical of an alcohol mn,t The pipe stock of the pipe m-n at the time t; k is mn Is the inventory constant of the pipeline m-n; h m,t Is the calorific value of the node m at the time t; h n,t Is the heat value of the node n at time t;
is the gas heat value H at the head end of the pipeline m-n at the time t L ；
For the gas calorific value H at the m-n end of the pipeline at the time t L ；
Natural gas supply flow F for gas source w at time t S ；H gas The natural gas has high heat value of 38.29MJ/m 3 ；
Flow rate F of gas flowing through compressor k at time t C ；
Energy E required for the air load E at time t L ；
And
energy is supplied to the natural gas with the minimum and the maximum gas source w respectively;
is the climbing upper limit of the gas source w;
for the transmitted energy of compressor k;
and with
Respectively are the upper and lower pressure limits of the node m;
the value of the k inlet pressure of the compressor at the moment t;
the value of the k outlet pressure of the compressor at the moment t;
and
the upper and lower limits of the compression ratio of the compressor k are respectively; alpha is the hydrogen mixing ratio; alpha (alpha) ("alpha") max The maximum hydrogen mixing ratio is Gpi, and the Gpi is a natural gas pipeline set; l is min For natural gas system inventory minimum, L mn,T Representing the inventory of pipes m-n during the last period T.
3. The optimal scheduling method for the electric-gas-hydrogen hybrid comprehensive energy system considering the auxiliary services as claimed in claim 1, wherein in step 4, the power system model includes power system operation constraints:
in the formula: subscripts i and j denote power buses; subscript r denotes the new energy bank; subscript d represents the electrical load; subscript REF denotes a reference bus; u shape v (i) The generator set is connected with the bus i; u shape r (i) Is a new energy machine set connected with the bus i; u shape d (i) Is the set of electrical loads connected to bus i; u shape h (i) Is a set of electric hydrogen production units connected with a bus i; u (i) is a line set connected with the bus i;
active power output P of unit v at time t G ；
The power P of the new energy unit r at the moment t W ；
Actual absorbed power P of electrical load d for time t D ；
Power demand P for electric load d at time t L ；θ i,t Is the voltage phase angle of the bus i at the moment t; theta j,t Is the voltage phase angle of the bus j at the moment t; x is the number of ij And
line ij susceptance and maximum transmission capacity, respectively;
and with
The upper limit and the lower limit of the generating power of the unit v are respectively set;
maximum value of regulating variable for unit v
Predicting power P for the day ahead of the new energy bank r at time t cal ；
And
respectively, the minimum and the minimum of the electroproduction of hydrogen hA large conversion power; theta REF,t The voltage phase angle of the reference bus REF at time t.
4. The optimal scheduling method for the electric-gas-hydrogen hybrid comprehensive energy system considering the auxiliary services as claimed in claim 3, wherein in step 4, a technical scheme for meeting the peak shaving and standby requirements of the system is provided as follows:
1) Technical scheme for meeting peak regulation requirement
The peak regulation demand is changed into peak regulation cost by introducing an economic conversion coefficient epsilon, and the peak regulation cost and the system operation cost form a comprehensive cost minimum target:
minF＝F E +F G +F P (A-26)
in the formula, F E For the operating costs of the power system, F G For the operating costs of natural gas systems, F P Peak shaving cost;
in the formula: omega c Is a coal-fired unit set; omega g Is a gas turbine set; t represents the number of time sections;
the power generation cost coefficient of the coal burner unit;
the operation and maintenance cost coefficient of the gas turbine set;
a power-off load cost factor;
is the gas supply cost coefficient of the gas source w;
a gas-cut load cost coefficient; ε is the economic conversion coefficient, P t NL And
respectively representing the net load P of the system at time t NL And average payload
The calculation formula is as follows:
2) Technical scheme for meeting standby requirement
The standby requirement of the system is provided by a conventional generator set and the electric hydrogen production so as to stabilize the power balance problem caused by the prediction deviation of load, wind power and photovoltaic power;
in the formula:
flexible backup R indicating system needs at time t U ；
Lower flexible backup R indicating system need at time t D ；
And
respectively representing the predicted power P of the wind power k and the photovoltaic s at the moment t in the day cal ；α k 、α s And alpha d Respectively representing the FR coefficients of the wind power k, the photovoltaic s and the load d,
representing the flexible reserve capacity P provided by the conventional unit v at time t G,U ；
Represents the lower flexible spare capacity P provided by the conventional unit v at the moment t G,D ；
Represents the upper flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,U ；
Represents the lower flexible reserve capacity P provided by the electroproduction of hydrogen h at the moment t P2H,D ；
Representing the ratio of the rate of ascent of a conventional unit v to its maximum capacity
Representing the ratio of the downhill rate of ascent to its maximum capacity for a conventional unit v
Represents the ratio of the uphill gradient rate of the electroproduction of hydrogen h to the maximum capacity thereof
Represents the ratio of the downward climbing rate of the electroproduction of hydrogen h to the maximum capacity thereof
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