CN115079564A - Decarburization path planning optimization method for regional hydrogen generation system - Google Patents

Decarburization path planning optimization method for regional hydrogen generation system Download PDF

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CN115079564A
CN115079564A CN202210856118.9A CN202210856118A CN115079564A CN 115079564 A CN115079564 A CN 115079564A CN 202210856118 A CN202210856118 A CN 202210856118A CN 115079564 A CN115079564 A CN 115079564A
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hydrogen
power
module
constraint
time section
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CN115079564B (en
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林瑞霄
滕威
刘毅
徐华池
田兴国
周琪
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Sichuan Energy Internet Research Institute EIRI Tsinghua University
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Sichuan Energy Internet Research Institute EIRI Tsinghua University
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    • G—PHYSICS
    • G05—CONTROLLING; REGULATING
    • G05B—CONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
    • G05B13/00—Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion
    • G05B13/02—Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
    • G05B13/0205—Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric not using a model or a simulator of the controlled system
    • G05B13/024—Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric not using a model or a simulator of the controlled system in which a parameter or coefficient is automatically adjusted to optimise the performance
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S10/00—Systems supporting electrical power generation, transmission or distribution
    • Y04S10/50—Systems or methods supporting the power network operation or management, involving a certain degree of interaction with the load-side end user applications

Abstract

The invention provides a method for planning and optimizing a decarburization path of a regional hydrogen generation system, and relates to the technical field of planning and optimizing an energy system. The method comprises the following steps: s1: establishing a framework of a regional electric hydrogen system; s2: selecting a planning period and a time section; s3: establishing variables to be optimized of a regional hydrogen generation system; s4: establishing an optimization objective function; s5: establishing a constraint condition equation; s6: configuring an optimization algorithm; s7: updating the input parameters of the regional hydrogen generation system of the current time section; s8: solving an optimization problem; s9: outputting an optimization result of the regional hydrogen-electricity system of the current time section, and feeding back each equipment installation in the optimization result to the next time section optimization as an existing equipment installation; s10: and judging whether the current time section is the selected last time section or not, if not, returning to the step S7, and if so, ending. The method can obtain the cost-optimal capacity configuration and operation parameter development path in the decarburization process of the regional hydrogen generation system.

Description

Decarburization path planning optimization method for regional hydrogen generation system
Technical Field
The invention relates to the technical field of energy system planning optimization, in particular to a regional electric hydrogen system decarburization path planning optimization method.
Background
Decarburization in the power industry is the most important link in achieving the dual carbon goal. Because new energy such as wind, light have the characteristics that volatility is strong, difficult prediction and regulation, consequently novel electric power system will need to dispose large-scale energy storage and the adjustable load of magnanimity and provide services such as peak shaver, frequency modulation to guarantee electric power system safety, satisfy the electric power load demand.
Hydrogen energy is a clean and efficient secondary energy, can be produced in a large scale by electrolyzing water, can be stored, and can be used for generating electricity by equipment such as a fuel cell, a hydrogen gas turbine and the like. In addition to the electric industry, steel, cement, petrochemical and chemical industries are the fine industries with the highest carbon emission ratio, and are also important for decarburization in these industries. The three industries are difficult to realize large-scale decarburization directly through electrification, while hydrogen green is applied to the steel industry to replace coal/natural gas to provide reducing agent and high-temperature industrial heat, the cement industry to replace coal/natural gas to provide high-temperature industrial heat, and the petrochemical and chemical industries to replace coal/natural gas to prepare hydrogen, and is an important even necessary path for decarburization in the industries. Therefore, the hydrogen energy can support the large-scale development of renewable energy sources at the source end, can realize the deep decarburization of industries such as steel, cement, petrochemical industry and the like which are difficult to decarbonize at the load end, and can realize the effect of 1+1>2 in the process of realizing the common support of the double-carbon target by the efficient complementary cooperation with the electric power.
Both the power system and the hydrogen energy system are very complex systems, and the interaction between the two systems further increases the complexity of the whole system. For the electric power system, a large amount of planning, research and design work can be developed by relevant units every year, and clean, low-carbon, safe and efficient operation and development of the electric power system are powerfully guaranteed. Due to the improvement of the complexity of the system, the electric hydrogen system is planned as a whole, and the electric hydrogen system is more important for clean, low-carbon, safe and efficient operation of the future electric power-hydrogen energy system.
Therefore, an optimization method for planning a decarburization path of a regional hydrogen generation system is urgently needed to obtain a cost optimization path for the collaborative decarburization of the regional hydrogen generation system, and meet the requirements of planning a carbon peak reaching path and a carbon neutralization path.
Disclosure of Invention
The invention aims to provide a regional electric hydrogen system decarburization path planning optimization method which can obtain the most cost-effective capacity configuration and operation parameter development path in the regional electric hydrogen system decarburization process and meet the requirements of carbon peak reaching, carbon neutralization and path planning.
Embodiments of the invention may be implemented as follows:
the invention provides a regional hydrogen generation system decarburization path planning and optimizing method, which comprises the following steps:
s1: establishing a framework of a regional electric hydrogen system;
s2: selecting a planning period and a time section;
s3: establishing variables to be optimized of a regional hydrogen generation system;
s4: establishing an optimization objective function;
s5: establishing a constraint condition equation;
s6: configuring an optimization algorithm;
s7: updating the input parameters of the regional hydrogen generation system of the current time section;
s8: solving an optimization problem;
s9: outputting an optimization result of the regional hydrogen generation system of the current time section, and feeding back each equipment installation in the optimization result to the next time section optimization as an existing equipment installation;
s10: and judging whether the current time section is the selected last time section or not, if not, returning to the step S7, and if so, ending the process.
In an alternative embodiment, in S1, the regional electric hydrogen system includes a power supply unit, a power input unit, a power balancing unit, a power load unit, an electricity storage unit, an electric hydrogen production unit, a hydrogen power generation unit, a hydrogen input unit, a hydrogen storage unit, a hydrogen balancing unit, a hydrogen load unit, a power output unit, and a hydrogen output unit;
the power supply unit, the power input unit, the power output unit, the power load unit, the electricity storage unit, the hydrogen production unit and the hydrogen generation unit are all connected with the power balance unit, and the hydrogen production unit, the hydrogen input unit, the hydrogen output unit, the hydrogen generation unit, the hydrogen storage unit and the hydrogen load unit are all connected with the hydrogen balance unit.
In an alternative embodiment, in S1, there are one or more power balancing units, the power balancing units are connected to each other, and there is bidirectional or unidirectional power transmission between the power balancing units connected to each other; the hydrogen balance units are connected with each other, and bidirectional or unidirectional hydrogen transmission is carried out between the hydrogen balance units connected with each other.
In an alternative embodiment, in S2, the planning period spans a plurality of consecutive natural years, the single time section is one natural year within the planning period, and the time sections are one or more.
In an alternative embodiment, in S3, the variables to be optimized for the regional electro-hydrogen system include real variables and one-dimensional array variables.
In an alternative embodiment, the real-type variables include installed capacity of each power module, installed capacity of each power input module, installed capacity of each power output module, installed capacity of each power storage module, installed capacity of each hydrogen production module, installed capacity of each hydrogen generation module, installed capacity of each hydrogen input module, installed hydrogen amount of each hydrogen load module, installed hydrogen amount of each hydrogen output module, and installed capacity of each hydrogen storage module for a selected time cross-section in the regional electric hydrogen system;
each one-dimensional array variable comprises 8760 real-type variables, and the one-dimensional array variables comprise the hourly power generation power of each power module of a selected time section in the regional electric hydrogen system, the hourly power rejection power of each power module, the hourly charge and discharge power of each power storage module, the hourly charge/energy storage state of each power storage module, the hourly operating power of each electric hydrogen production module, the hourly hydrogen production rate of each electric hydrogen production module, the hourly power generation power of each hydrogen generation module, the hourly hydrogen consumption rate of each hydrogen generation module, the hourly charge and discharge hydrogen rate of each hydrogen storage module and the hourly hydrogen storage state of each hydrogen storage module.
In an alternative embodiment, in S4, the objective function is optimized to minimize the total cost of the system in time section, including the fixed investment split, fixed operation and maintenance costs, variable operation costs, and carbon emission costs for each module in the system, expressed as:
Figure M_220719091210931_931773001
in the formula:
Figure M_220719091211152_152509001
modules indicating unchanged operating costs in the system include a power module, an electricity storage module, an electrical hydrogen production module, a hydrogen storage module, a hydrogen generation module and the like which do not need to consume fuel;
Figure M_220719091211168_168149002
the modules indicating the variable running cost in the system comprise a coal power module, a gas power module, a nuclear power module and other power modules which need to consume fuel;
Figure M_220719091211199_199383003
the system refers to input and output modules of electric power and hydrogen energy;
Figure M_220719091211230_230642004
is a module
Figure M_220719091211262_262821005
A newly-added installation machine is needed from the last time section to the current time section;
Figure M_220719091211294_294589006
the module is put into operation from the last time section to the current time section
Figure M_220719091211310_310194007
OfThe unit fixed investment is equalized;
Figure M_220719091211341_341448008
is put into operation from the last time section to the current time section
Figure M_220719091211357_357066009
Average design life of;
Figure M_220719091211388_388325010
is a module
Figure M_220719091211419_419578011
Installing the existing machine on the section at the last time;
Figure M_220719091211435_435249012
is a module
Figure M_220719091211467_467886013
An installation to be decommissioned from a previous time section to the current time section;
Figure M_220719091211499_499707014
is a module
Figure M_220719091211546_546532015
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_220719091211577_577782016
is a module
Figure M_220719091211608_608572017
In the first place
Figure M_220719091211624_624658018
Generated power within an hour;
Figure M_220719091211655_655904019
is a module
Figure M_220719091211688_688601020
Average electrical fuel cost during the last time section to the present time section;
Figure M_220719091211704_704259021
is the first
Figure M_220719091211735_735553022
Input or output of electrical/hydrogen energy in hours;
Figure M_220719091211766_766776023
is the average unit price of input or output electric power/hydrogen energy from the last time section to the present time section;
Figure M_220719091211798_798027024
the annual carbon emission of the system;
Figure M_220719091211829_829273025
is the average carbon number from the last time slice to this time slice.
In an alternative embodiment, in S5, the constraint equations include a system balance constraint equation, a system block constraint equation, and a system design constraint equation.
In an alternative embodiment, at S5, the system balance constraint equations include a power balance node equation and a hydrogen balance node equation;
the power balance node equation is as follows:
Figure M_220719091211861_861481001
in the formula:
Figure M_220719091211971_971360001
is the other power balance node connected with the power balance node
Figure M_220719091212002_002607002
In the first place
Figure M_220719091212018_018245003
Power exchange between an hour and the power balancing node;
Figure M_220719091212049_049463004
is a power supply module connected with the power balance node
Figure M_220719091212100_100787005
In the first place
Figure M_220719091212132_132017006
Power in hours;
Figure M_220719091212163_163265007
is a power input module connected with the power balance node
Figure M_220719091212194_194535008
In the first place
Figure M_220719091212225_225764009
Hourly delivered power;
Figure M_220719091212257_257013010
is a power load module connected with the power balance node
Figure M_220719091212289_289715011
In the first place
Figure M_220719091212305_305354012
Power in hours;
Figure M_220719091212336_336596013
is a power output module connected with the power balance node
Figure M_220719091212367_367852014
In the first place
Figure M_220719091212383_383465015
Hourly delivered power;
Figure M_220719091212414_414717016
is an electricity storage module connected with the power balance node
Figure M_220719091212445_445940017
In the first place
Figure M_220719091212464_464472018
Power in hours;
Figure M_220719091212496_496281019
is an electric hydrogen production module connected with the electric power balance node
Figure M_220719091212527_527500020
In the first place
Figure M_220719091212543_543111021
Power in hours;
Figure M_220719091212574_574374022
is a hydrogen power generation module connected with the power balance node
Figure M_220719091212605_605643023
In the first place
Figure M_220719091212621_621226024
Hourly power. The power flowing into the power balance node is positive, and the power flowing out of the power balance node is negative;
the hydrogen equilibrium node equation is:
Figure M_220719091212652_652509001
in the formula:
Figure M_220719091212732_732587001
is the other hydrogen balance node connected with the hydrogen balance node
Figure M_220719091212763_763817002
In the first place
Figure M_220719091212779_779463003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_220719091212810_810715004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_220719091212841_841948005
In the first place
Figure M_220719091212857_857574006
Hydrogen production in hours;
Figure M_220719091212875_875592007
is a hydrogen power generation module connected with the hydrogen balance node
Figure M_220719091212907_907368008
In the first place
Figure M_220719091212923_923003009
Hydrogen consumption in hours;
Figure M_220719091212954_954237010
is a hydrogen input module connected to the hydrogen balance node
Figure M_220719091212969_969861011
In the first place
Figure M_220719091213001_001128012
Hydrogen output per hour;
Figure M_220719091213016_016739013
is hydrogen connected to the hydrogen balance nodeLoad module
Figure M_220719091213048_048000014
In the first place
Figure M_220719091213081_081687015
Hydrogen usage in hours;
Figure M_220719091213097_097328016
is a hydrogen output module connected with the hydrogen balance node
Figure M_220719091213128_128588017
In the first place
Figure M_220719091213144_144256018
Hydrogen output per hour;
Figure M_220719091213175_175471019
is a hydrogen storage module connected with the hydrogen balance node
Figure M_220719091213206_206692020
In the first place
Figure M_220719091213222_222324021
Hydrogen charge/discharge amount per hour. The amount of hydrogen flowing into the hydrogen balance node is positive and the amount of hydrogen flowing out of the hydrogen balance node is negative.
In an alternative embodiment, in S5, the system module constraint equations include a power module constraint equation, an electricity storage module constraint equation, an electrical hydrogen production module constraint equation, a hydrogen generation module constraint equation, a hydrogen load module constraint equation, and a hydrogen storage module constraint equation; the power module constraint equation comprises power generation power constraint and renewable energy power abandon rate constraint;
the generated power constraint is as follows:
Figure M_220719091213253_253600001
in the formula:
Figure M_220719091213287_287276001
non-renewable power module
Figure M_220719091213302_302870002
In the first place
Figure M_220719091213334_334172003
Hourly generated power;
Figure M_220719091213349_349767004
non-renewable power module
Figure M_220719091213380_380523005
Installed capacity of (d);
Figure M_220719091213412_412259001
in the formula:
Figure M_220719091213443_443536001
is a renewable power module
Figure M_220719091213478_478637002
In the first place
Figure M_220719091213494_494774003
Hourly generated power;
Figure M_220719091213526_526034004
is a renewable power module
Figure M_220719091213541_541640005
In the first place
Figure M_220719091213572_572917006
Electric power discard of hours;
Figure M_220719091213588_588553007
is a renewable power module
Figure M_220719091213619_619776008
Installed capacity of (a);
Figure M_220719091213635_635416009
is a renewable power module
Figure M_220719091213668_668572010
In the first place
Figure M_220719091213684_684705011
The ratio of maximum hourly output to installed capacity;
the renewable energy power abandon rate constraint is as follows:
Figure M_220719091213715_715968001
in the formula:
Figure M_220719091213778_778480001
is a renewable power module
Figure M_220719091213794_794087002
The annual average power abandonment rate upper limit;
the electric storage module constraint equation comprises charge/energy storage state constraint, charge and discharge power constraint and capacity balance constraint;
the charge/storage state constraints are:
Figure M_220719091213825_825376001
in the formula:
Figure M_220719091213874_874629001
and
Figure M_220719091213906_906389002
are respectively an electricity storage module
Figure M_220719091213937_937638003
Lower and upper limits of the state of charge/energy storage;
Figure M_220719091213968_968897004
is an electricity storage module
Figure M_220719091214000_000149005
In the first place
Figure M_220719091214015_015760006
Hourly charge/energy storage state;
the charge and discharge power constraint is as follows:
Figure M_220719091214031_031400001
in the formula:
Figure M_220719091214080_080226001
is an electricity storage module
Figure M_220719091214111_111482002
The capacity of (a);
Figure M_220719091214142_142722003
is an electricity storage module
Figure M_220719091214173_173983004
Maximum charge rate of;
Figure M_220719091214189_189620005
is an electricity storage module
Figure M_220719091214220_220836006
Maximum discharge rate of (d);
the capacity balance constraint is:
if it is
Figure M_220719091214236_236480001
，
Figure M_220719091214268_268151001
If it is
Figure M_220719091214377_377101001
，
Figure M_220719091214392_392758001
In the formula:
Figure M_220719091214503_503580001
is an electricity storage module
Figure M_220719091214534_534820002
Energy conversion efficiency of charging;
Figure M_220719091214550_550466003
is an electricity storage module
Figure M_220719091214581_581713004
Energy conversion efficiency of the discharge;
Figure M_220719091214612_612964005
is an electricity storage module
Figure M_220719091214628_628574006
A ratio of leakage to capacity per hour;
Figure M_220719091214659_659841007
is an electricity storage module
Figure M_220719091214692_692540008
Initial state of charge/energy storage;
the constraint equation of the electrohydrogen production module comprises operation power constraint and energy conversion constraint;
the operating power constraints are:
Figure M_220719091214708_708181001
in the formula:
Figure M_220719091214739_739424001
is an electric hydrogen production module
Figure M_220719091214770_770677002
Installed capacity of (d);
the energy conversion constraint is:
Figure M_220719091214801_801909001
in the formula:
Figure M_220719091214833_833180001
is an electric hydrogen production module
Figure M_220719091214866_866353002
Electricity consumption per unit hydrogen production;
the hydrogen power generation module constraint equation comprises an operating power constraint and an energy conversion constraint;
the operating power constraints are:
Figure M_220719091214882_882464001
in the formula:
Figure M_220719091214913_913706001
is a hydrogen power generation module
Figure M_220719091214944_944994002
Installed capacity of (d);
the energy conversion constraint is:
Figure M_220719091214976_976228001
in the formula:
Figure M_220719091215023_023072001
is a hydrogen power generation module
Figure M_220719091215054_054333002
Hydrogen consumption per unit of generated energy;
the hydrogen load module constraint equation comprises a hydrogen usage constraint;
the hydrogen dosage constraints are:
Figure M_220719091215087_087548001
in the formula:
Figure M_220719091215134_134406001
is a hydrogen load module
Figure M_220719091215165_165669002
The maximum possible amount of hydrogen used per year in the time section;
Figure M_220719091215196_196935003
is a hydrogen load module
Figure M_220719091215228_228174004
Annual production/traffic in time section;
Figure M_220719091215243_243802005
is a hydrogen load module
Figure M_220719091215276_276471006
Adopting the carbon emission factor of the prior art;
Figure M_220719091215292_292611007
is a hydrogen load module
Figure M_220719091215355_355123008
The proportion of emission reduction can be realized by replacing hydrogen in the carbon emission in the prior art;
Figure M_220719091215370_370739009
is a hydrogen load module
Figure M_220719091215402_402006010
Carbon reduction per unit hydrogen application;
the hydrogen storage module constraint equation comprises hydrogen storage state constraint, hydrogen charging and discharging rate constraint and capacity balance constraint;
the hydrogen storage state constraints are as follows:
Figure M_220719091215433_433244001
in the formula:
Figure M_220719091215465_465951001
and
Figure M_220719091215497_497708002
are each a hydrogen storage module
Figure M_220719091215528_528944003
Lower and upper limits of the hydrogen storage state of (a);
Figure M_220719091215560_560211004
is a hydrogen storage module
Figure M_220719091215591_591478005
In the first place
Figure M_220719091215622_622702006
Hydrogen storage status of hours;
the hydrogen charging and discharging rate constraint is as follows:
Figure M_220719091215638_638362001
in the formula:
Figure M_220719091215706_706201001
is a hydrogen storage module
Figure M_220719091215737_737444002
The capacity of (a);
Figure M_220719091215753_753066003
is a hydrogen storage module
Figure M_220719091215784_784336004
Maximum hydrogen charge rate of;
Figure M_220719091215815_815563005
is a hydrogen storage module
Figure M_220719091215846_846828006
The maximum hydrogen release rate;
the capacity balance constraint is:
if it is
Figure M_220719091215879_879996001
，
Figure M_220719091215895_895651001
If it is
Figure M_220719091216005_005056001
，
Figure M_220719091216036_036273001
In the formula:
Figure M_220719091216131_131992001
is a hydrogen storage module
Figure M_220719091216163_163259002
The efficiency of the charging process;
Figure M_220719091216194_194500003
is a hydrogen storage module
Figure M_220719091216225_225741004
The efficiency of the hydrogen discharge process;
Figure M_220719091216257_257105005
is a hydrogen storage module
Figure M_220719091216274_274054006
The ratio of hydrogen leakage to capacity per hour;
Figure M_220719091216305_305793007
is a hydrogen storage module
Figure M_220719091216337_337059008
Initial hydrogen storage state.
In an optional embodiment, in S5, the system design constraint equation includes system carbon emission constraints, upper and lower limit constraints on installed capacity of the power supply module, upper and lower limit constraints on annual input power of the power input module, upper and lower limit constraints on annual output power of the power output module, upper and lower limit constraints on capacity of the power storage module, upper and lower limit constraints on installed capacity of the hydrogen production module, upper and lower limit constraints on installed capacity of the hydrogen generation module, upper and lower limit constraints on annual input hydrogen amount of the hydrogen input module, upper and lower limit constraints on annual hydrogen amount of the hydrogen load module, upper and lower limit constraints on annual output hydrogen amount of the hydrogen output module, and upper and lower limit constraints on capacity of the hydrogen storage module;
wherein the system carbon emission constraint is:
Figure M_220719091216352_352703001
in the formula:
Figure M_220719091216573_573382001
is a power supply module
Figure M_220719091216604_604659002
Carbon emission factor of (a);
Figure M_220719091216620_620250003
is a power input module
Figure M_220719091216651_651553004
The carbon emission factor of (c);
Figure M_220719091216686_686664005
is a power output module
Figure M_220719091216717_717909006
Carbon emission factor of (a);
Figure M_220719091216733_733558007
is a hydrogen input module
Figure M_220719091216780_780450008
The carbon emission factor of (c);
Figure M_220719091216796_796041009
is a hydrogen output module
Figure M_220719091216827_827304010
Carbon emission factor of (a);
Figure M_220719091216858_858547011
is the upper carbon emission limit of the regional electro-hydrogen system over the time section.
In an optional implementation manner, in S6, the configuration optimization algorithm selects a linux solver in MATLAB according to the optimization objective function and the constraint equation.
In an alternative embodiment, in S7, the input parameters of the regional electric hydrogen system of the current time section include an initial existing installed capacity of each power module, upper and lower limits of the installed capacity, a carbon emission factor, a unit fixed investment, an average design life, a ratio of an annual fixed operation and maintenance cost to a fixed investment, a fuel cost of the electric fuel, and a ratio of a maximum hourly output of renewable energy to the installed capacity;
the input parameters of the regional electro-hydrogen system of the current time section further comprise the ratio of the time-by-time transmission power to the peak transmission power of the power input module;
the input parameters of the regional hydrogen power system of the current time section further comprise the time-by-time power of the power load module;
the input parameters of the regional electro-hydrogen system of the current time section further comprise the ratio of the time-by-time transmission power to the peak transmission power of the power output module;
the input parameters of the regional hydrogen-electricity system of the current time section further comprise the initial existing installed capacity of each electricity storage module, the upper and lower limits of the installed capacity, the maximum charging multiplying factor, the maximum discharging multiplying factor, the energy conversion efficiency in the charging process, the energy conversion efficiency in the discharging process, the ratio of the leakage quantity per hour to the capacity, the unit fixed investment, the average design life and the ratio of the annual fixed operation and maintenance cost to the fixed investment;
the input parameters of the regional hydrogen generation system of the current time section further comprise the initial existing installed capacity of the hydrogen generation module, the upper and lower limits of the installed capacity, the power consumption of unit hydrogen generation amount, unit fixed investment, the average design life and the ratio of annual fixed operation and maintenance cost to fixed investment;
the input parameters of the regional hydrogen power system of the current time section further comprise the initial existing installed capacity of each hydrogen power generation module, the upper and lower limits of the installed capacity, the hydrogen consumption of unit generated energy, unit fixed investment, average design life and the ratio of annual fixed operation and maintenance cost to fixed investment;
the input parameters of the regional electric hydrogen system of the current time section further comprise the ratio of the hourly hydrogen output to the peak hydrogen output of the hydrogen input module;
the input parameters of the regional electric hydrogen system of the current time section further comprise the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of each hydrogen load module, the annual output/transport capacity, a carbon emission factor adopting the prior art, the ratio of realizing emission reduction by hydrogen substitution in the carbon emission of the prior art, the carbon reduction amount brought by each unit of hydrogen application and the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of the hydrogen output module;
the input parameters of the regional hydrogen power system of the current time section further comprise the ratio of the hourly hydrogen output quantity to the peak hydrogen output quantity of each hydrogen output module;
the input parameters of the regional hydrogen power system of the current time section further comprise initial existing installed capacity of each hydrogen storage module, upper and lower limits of the installed capacity, maximum hydrogen charging rate, maximum hydrogen discharging rate, efficiency of a hydrogen charging process, efficiency of a hydrogen discharging process, a ratio of hydrogen leakage amount per hour to capacity, unit fixed investment, average design life and a ratio of annual fixed operation and maintenance cost to fixed investment.
The method for optimizing the decarburization path planning of the regional hydrogen generation system provided by the embodiment of the invention has the beneficial effects that:
1. the method and the tool are provided for planning the decarburization path of the regional hydrogen generation system;
2. the method can realize the optimization of the capacity allocation of each component element with the optimal system total cost in the process of advancing carbon neutralization of the electro-hydrogen system in the area;
3. the method can obtain the hourly operation parameters of each component element of the hydrogen power system in the region in the selected planning period and the time section, and can guide the selection of the future operation mode and the operation scheduling arrangement of the hydrogen power system;
4. the method has higher flexibility, and can select and determine the types and the number of elements and modules considered in the system according to the characteristics of the planning area and the requirement on the spatial resolution.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present invention, the drawings needed to be used in the embodiments will be briefly described below, it should be understood that the following drawings only illustrate some embodiments of the present invention and therefore should not be considered as limiting the scope, and for those skilled in the art, other related drawings can be obtained according to the drawings without inventive efforts.
Fig. 1 is a flowchart of a method for optimizing a decarburization path planning of a regional hydrogen generation system according to an embodiment of the present invention;
fig. 2 is a schematic diagram of a regional electro-hydrogen system according to an embodiment of the present invention.
Icon: 100-regional hydrogen generation system; 1-a power supply unit; 11-a coal electric module; 12-a gas electric module; 13-a nuclear power module; 14-a hydro-electric module; 15-offshore wind power module; 16-an onshore wind power module; 17-a photovoltaic module; 2-a power input unit; 3-a power balancing unit; 4-an electrical load unit; 5-an electricity storage unit; 51-a battery module; 52-a water pumping energy storage module; 6-an electrohydrogen production unit; 7-a hydrogen power generation unit; 71-a fuel cell module; 72-a hydrogen-fired turbine module; an 8-hydrogen input unit; 9-a hydrogen storage unit; 91-salt cavern hydrogen storage module; 92-a high pressure tank module; a 10-hydrogen equilibrium unit; an 18-hydrogen load cell; 181-steel module; 182-a cement module; 183-chemical module; 184-road freight module; 185-shipping module; 186-an aviation module; 19-a power output unit; 20-hydrogen output unit.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all embodiments of the present invention. The components of embodiments of the present invention generally described and illustrated in the figures herein may be arranged and designed in a wide variety of different configurations.
Thus, the following detailed description of the embodiments of the present invention, presented in the figures, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be obtained by a person skilled in the art without inventive step based on the embodiments of the present invention, are within the scope of protection of the present invention.
It should be noted that: like reference numbers and letters refer to like items in the following figures, and thus, once an item is defined in one figure, it need not be further defined and explained in subsequent figures.
In the description of the present invention, it should be noted that if the terms "upper", "lower", "inside", "outside", etc. indicate an orientation or a positional relationship based on that shown in the drawings or that the product of the present invention is used as it is, this is only for convenience of description and simplification of the description, and it does not indicate or imply that the device or the element referred to must have a specific orientation, be constructed in a specific orientation, and be operated, and thus should not be construed as limiting the present invention.
Furthermore, the appearances of the terms "first," "second," and the like, if any, are used solely to distinguish one from another and are not to be construed as indicating or implying relative importance.
It should be noted that the features of the embodiments of the present invention may be combined with each other without conflict.
Referring to fig. 1, the present embodiment provides a method for optimizing a decarburization path planning of a regional hydrogen generation system 100, which includes the following steps:
s1: the architecture of the regional power hydrogen system 100 is established.
Referring to fig. 2, the regional hydrogen generation system 100 includes a power supply unit 1, a power input unit 2, a power balance unit 3, a power load unit 4, a power storage unit 5, an electrical hydrogen production unit 6, a hydrogen power generation unit 7, a hydrogen input unit 8, a hydrogen storage unit 9, a hydrogen balance unit 10, a hydrogen load unit 18, a power output unit 19, and a hydrogen output unit 20.
The number of the power balance units 3 is one or more, the power balance units 3 are connected with each other, and bidirectional or unidirectional power transmission is performed between the power balance units 3 connected with each other; the number of the hydrogen balance units 10 is one or more, the hydrogen balance units 10 are connected with each other, and bidirectional or unidirectional hydrogen transmission exists between the hydrogen balance units 10 connected with each other.
The power supply unit 1 may include a coal electric module 11, a gas electric module 12, a nuclear electric module 13, a hydroelectric module 14, an offshore wind electric module 15, an onshore wind electric module 16, a photovoltaic module 17, and other power supply module types considered within the planning area. Each power module type may comprise one or more modules, each power module being connected to one power balancing unit 3.
The power input unit 2 may comprise one or more power input modules, each connected to one power balancing unit 3;
the power load unit 4 may comprise one or more power load modules, each connected to one of the power balancing units 3.
The power output unit 19 may comprise one or more power output modules, each connected to one of the power balancing units 3.
The electrical storage unit 5 may include a battery module 51, a pumped-water energy storage module 52, a flywheel module, and other electrical storage unit types considered within the planning area. Each power storage unit may contain one or more modules, each connected to the power balancing unit 3.
The electrical hydrogen production units 6 include alkaline water electrolysis hydrogen production, proton exchange membrane water electrolysis hydrogen production and other electrical hydrogen production module types considered in the planned region, each electrical hydrogen production unit 6 may include one or more modules, and each electrical hydrogen production module is respectively connected with one power balance unit 3 and one hydrogen balance unit 10.
The hydrogen power generation unit 7 may include a fuel cell module 71, a hydrogen turbine module 72, and other hydrogen power generation module types considered within the planning area. Each hydrogen generating unit 7 may comprise one or more modules, each of which is connected to the power balancing unit 3 and the hydrogen balancing unit 10, respectively.
The hydrogen input unit 8 may comprise one or more hydrogen input modules, each of which is connected to a hydrogen balancing unit 10.
The hydrogen output unit 20 may comprise one or more hydrogen output modules, each of which is connected to one of the hydrogen balancing units 10.
The hydrogen load units 18 may include steel modules 181, cement modules 182, chemical modules 183, road freight modules 184, shipping modules 185, aviation modules 186, and other hydrogen load module types considered within the planning area. Each hydrogen load unit 18 may comprise one or more modules, each hydrogen load module being connected to the hydrogen balancing unit 10.
The hydrogen storage unit 9 may include a salt cavern hydrogen storage module 91, a high pressure storage tank module 92, and other hydrogen storage module types contemplated within the planned region. Each hydrogen storage unit 9 may comprise one or more modules, each connected to a hydrogen balancing unit 10.
S2: and selecting a planning period and a time section.
The planning period may span 2020-.
S3: variables to be optimized for the regional electro-hydrogen system 100 are established.
The variables to be optimized for the regional electro-hydrogen system 100 include both real type variables and one-dimensional array variables.
The real-type variables include the installed capacity of each power module, the annual input power of each power input module, the annual output power of each power output module, the capacity of each power storage module, the installed capacity of each hydrogen production module, the installed capacity of each hydrogen generation module, the annual input hydrogen amount of each hydrogen input module, the annual hydrogen usage amount of each hydrogen load module, the annual output hydrogen amount of each hydrogen output module, and the capacity of each hydrogen storage module for a selected time section in the regional electric hydrogen system 100.
Each one-dimensional array variable consists of 8760 real-form variables. The one-dimensional array variables include the hourly power generation power of each power module of the selected time section in the regional electric hydrogen generation system 100, the hourly power rejection power of each power module (this variable exists only for renewable energy), the hourly charge and discharge power of each power storage module, the hourly charge/energy storage state (ratio of stored energy to capacity) of each power storage module, the hourly operating power of each electric hydrogen generation module, the hourly hydrogen production rate of each electric hydrogen generation module, the hourly power generation power of each hydrogen generation module, the hourly hydrogen consumption rate of each hydrogen generation module, the hourly hydrogen charging and discharge rate of each hydrogen storage module, and the hourly hydrogen storage state (ratio of stored hydrogen to capacity) of each hydrogen storage module.
S4: and establishing an optimization objective function.
The objective function is optimized to minimize the total system cost in time section, including the fixed investment amortization, fixed operation and maintenance costs, variable operation costs, and carbon emission costs of each module in the system, which can be expressed as:
Figure M_220719091216892_892722001
in the formula:
Figure M_220719091217097_097361001
the modules indicating the running cost without change in the system comprise a power module, an electricity storage module, an electricity hydrogen production module, a hydrogen storage module, a hydrogen generation module and the like which do not need to consume fuel;
Figure M_220719091217112_112954002
the modules indicating the variable running cost exist in the system, and comprise a coal-electricity module 11, a gas-electricity module 12, a nuclear power module 13 and other power modules needing to consume fuel;
Figure M_220719091217144_144189003
an input module for power and hydrogen energy;
Figure M_220719091217175_175450004
is a module
Figure M_220719091217206_206691005
Newly adding an installation machine from the last time section to the current time section;
Figure M_220719091217237_237929006
the module is put into operation from the last time section to the current time section
Figure M_220719091217270_270619007
Average unit capital investment of (1);
Figure M_220719091217286_286752008
is put into operation from the last time section to the current time section
Figure M_220719091217318_318009009
Average design life of;
Figure M_220719091217349_349258010
is a module
Figure M_220719091217380_380529011
Installing the existing machine on the section at the last time;
Figure M_220719091217411_411760012
is a module
Figure M_220719091217443_443002013
An installation to be decommissioned from a previous time section to the current time section;
Figure M_220719091217481_481088014
is a module
Figure M_220719091217512_512857015
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_220719091217544_544131016
is a module
Figure M_220719091217575_575338017
In the first place
Figure M_220719091217606_606592018
Generated power within an hour;
Figure M_220719091217637_637853019
is a module
Figure M_220719091217670_670845020
Average electrical fuel cost during the last time section to the present time section;
Figure M_220719091217687_687659021
is the first
Figure M_220719091217718_718922022
Input or output of electrical/hydrogen energy in hours;
Figure M_220719091217750_750156023
is the average unit price of input or output electric power/hydrogen energy from the last time section to the present time section;
Figure M_220719091217781_781432024
is the annual carbon emission of the system;
Figure M_220719091217812_812651025
is the average carbon number from the last time slice to this time slice.
S5: and establishing a constraint condition equation.
The constraint condition equations comprise a system balance constraint equation, a system module constraint equation and a system design constraint equation. The system balance constraint equation comprises two types of power balance node equations and hydrogen balance node equations.
The power balance node equation is as follows:
Figure M_220719091217843_843925001
in the formula:
Figure M_220719091217941_941058001
is the other power balance node connected with the power balance node
Figure M_220719091217972_972308002
In the first place
Figure M_220719091218003_003570003
Power exchange between an hour and the power balancing node;
Figure M_220719091218034_034821004
is a power supply module connected with the power balance node
Figure M_220719091218067_067984005
In the first place
Figure M_220719091218084_084129006
Power in hours;
Figure M_220719091218115_115383007
is a power input module connected with the power balance node
Figure M_220719091218146_146632008
In the first place
Figure M_220719091218177_177887009
Hourly delivered power;
Figure M_220719091218209_209146010
is a power load module connected with the power balance node
Figure M_220719091218240_240387011
In the first place
Figure M_220719091218273_273055012
Power in hours;
Figure M_220719091218289_289207013
is a power output module connected with the power balance node
Figure M_220719091218320_320472014
In the first place
Figure M_220719091218351_351711015
Hourly delivered power;
Figure M_220719091218525_525535016
is an electricity storage module connected with the power balance node
Figure M_220719091218572_572418017
In the first place
Figure M_220719091218603_603680018
Power in hours;
Figure M_220719091218619_619300019
is an electric hydrogen production module connected with the electric power balance node
Figure M_220719091218650_650526020
In the first place
Figure M_220719091218683_683737021
Power in hours;
Figure M_220719091218714_714999022
is a hydrogen power generation module connected with the power balance node
Figure M_220719091218746_746251023
In the first place
Figure M_220719091218777_777505024
Hour power. The power flowing into the power balancing node is positive and the power flowing out of the power balancing node is negative.
The hydrogen balance node equation is:
Figure M_220719091218793_793099001
in the formula:
Figure M_220719091218888_888328001
is the other hydrogen balance node connected to the hydrogen balance node
Figure M_220719091218919_919560002
In the first place
Figure M_220719091218950_950837003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_220719091218966_966462004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_220719091218997_997694005
In the first place
Figure M_220719091219028_028947006
Hydrogen production in hours;
Figure M_220719091219060_060196007
is a hydrogen power generation module connected with the hydrogen balance node
Figure M_220719091219093_093404008
In the first place
Figure M_220719091219124_124655009
Hydrogen consumption in hours;
Figure M_220719091219140_140281010
is a hydrogen input module connected with the hydrogen balance node
Figure M_220719091219187_187164011
In the first place
Figure M_220719091219218_218407012
Hydrogen output per hour;
Figure M_220719091219249_249669013
is hydrogen connected to the hydrogen balance nodeLoad module
Figure M_220719091219268_268663014
In the first place
Figure M_220719091219300_300436015
Hydrogen usage in hours;
Figure M_220719091219331_331702016
is a hydrogen output module connected with the hydrogen balance node
Figure M_220719091219362_362945017
In the first place
Figure M_220719091219378_378580018
Hydrogen output per hour;
Figure M_220719091219409_409812019
is a hydrogen storage module connected with the hydrogen balance node
Figure M_220719091219441_441075020
In the first place
Figure M_220719091219456_456680021
Hydrogen charge/discharge amount per hour. The amount of hydrogen flowing into the hydrogen balance node is positive and the amount of hydrogen flowing out of the hydrogen balance node is negative.
The system module constraint equations comprise a power module constraint equation, an electricity storage module constraint equation, an electricity hydrogen production module constraint equation, a hydrogen generation module constraint equation, a hydrogen load module constraint equation and a hydrogen storage module constraint equation.
The power module constraint equation comprises a power generation power constraint and a renewable energy curtailment rate constraint.
The generated power constraint is as follows:
Figure M_220719091219489_489882001
in the formula:
Figure M_220719091219521_521128001
non-renewable power module
Figure M_220719091219552_552393002
In the first place
Figure M_220719091219583_583644003
Hourly generated power;
Figure M_220719091219599_599256004
non-renewable power module
Figure M_220719091219630_630525005
The installed capacity of (c).
Figure M_220719091219662_662705001
In the formula:
Figure M_220719091219710_710111001
is a renewable power module
Figure M_220719091219741_741368002
In the first place
Figure M_220719091219772_772614003
Hourly generated power;
Figure M_220719091219788_788231004
is a renewable power module
Figure M_220719091219819_819485005
In the first place
Figure M_220719091219850_850741006
Electric power discard of hours;
Figure M_220719091219881_881985007
is a renewable power module
Figure M_220719091219913_913223008
Installed capacity of (a);
Figure M_220719091219928_928903009
is a renewable power module
Figure M_220719091219960_960125010
In the first place
Figure M_220719091219991_991369011
The ratio of maximum hourly output to installed capacity.
The renewable energy power abandonment rate constraint is as follows:
Figure M_220719091220022_022603001
in the formula:
Figure M_220719091220070_070901001
is a renewable power module
Figure M_220719091220102_102689002
The annual average power loss rate upper limit of (c).
The energy storage module constraint equation comprises charge/energy storage state constraint, charge and discharge power constraint and capacity balance constraint.
The charge/storage state constraints are:
Figure M_220719091220133_133942001
in the formula:
Figure M_220719091220180_180819001
and
Figure M_220719091220212_212061002
are respectively an electricity storage module
Figure M_220719091220243_243298003
Lower and upper limits of the state of charge/energy storage;
Figure M_220719091220275_275992004
is an electricity storage module
Figure M_220719091220307_307776005
In the first place
Figure M_220719091220339_339011006
Charge/storage state in hours.
The charge and discharge power constraint is as follows:
Figure M_220719091220370_370270001
in the formula:
Figure M_220719091220417_417152001
is an electricity storage module
Figure M_220719091220448_448390002
The capacity of (a);
Figure M_220719091220466_466909003
is an electricity storage module
Figure M_220719091220498_498678004
Maximum charge rate of;
Figure M_220719091220529_529947005
is an electricity storage module
Figure M_220719091220561_561193006
The maximum discharge rate of (3).
The capacity balance constraint is:
if it is
Figure M_220719091220576_576801001
，
Figure M_220719091220608_608041001
If it is
Figure M_220719091220703_703771001
，
Figure M_220719091220750_750631001
In the formula:
Figure M_220719091220844_844380001
is an electricity storage module
Figure M_220719091220878_878091002
Energy conversion efficiency of charging;
Figure M_220719091220909_909799003
is an electricity storage module
Figure M_220719091220941_941052004
Energy conversion efficiency of the discharge;
Figure M_220719091220972_972324005
is an electricity storage module
Figure M_220719091221003_003578006
Leakage to capacity ratio per hour;
Figure M_220719091221034_034812007
is an electricity storage module
Figure M_220719091221067_067990008
Initial charge/energy storage state.
The electrohydrogen production module constraint equations include an operating power constraint and an energy conversion constraint.
The operating power constraints are:
Figure M_220719091221084_084132001
in the formula:
Figure M_220719091221115_115383001
is an electric hydrogen production module
Figure M_220719091221146_146624002
Installed capacity of (c).
The energy conversion constraint is:
Figure M_220719091221177_177901001
in the formula:
Figure M_220719091221224_224771001
is an electric hydrogen production module
Figure M_220719091221256_256017002
And the unit hydrogen production amount is consumed.
The hydrogen power generation module constraint equations include an operating power constraint and an energy conversion constraint.
The operating power constraints are:
Figure M_220719091221290_290671001
in the formula:
Figure M_220719091221321_321930001
is a hydrogen power generation module
Figure M_220719091221353_353182002
Installed capacity of (c).
The energy conversion constraint is:
Figure M_220719091221384_384444001
in the formula:
Figure M_220719091221431_431293001
is a hydrogen power generation module
Figure M_220719091221446_446914002
Hydrogen consumption per unit of electricity generation.
The hydrogen load module constraint equation includes a constraint with an amount of hydrogen.
The hydrogen dosage constraints are:
Figure M_220719091221483_483082001
in the formula:
Figure M_220719091221546_546042001
is a hydrogen load module
Figure M_220719091221592_592965002
The maximum possible amount of hydrogen used per year in the time section;
Figure M_220719091221624_624191003
is a hydrogen load module
Figure M_220719091221639_639798004
Annual production/traffic in time section;
Figure M_220719091221672_672483005
is a hydrogen load module
Figure M_220719091221704_704230006
Adopting the carbon emission factor of the prior art;
Figure M_220719091221735_735519007
is a hydrogen load module
Figure M_220719091221766_766761008
The proportion of emission reduction can be realized by replacing hydrogen in the carbon emission in the prior art;
Figure M_220719091221797_797996009
is a hydrogen load module
Figure M_220719091221829_829247010
The amount of carbon reduction per unit hydrogen application.
The hydrogen storage module constraint equation comprises hydrogen storage state constraint, hydrogen charging and discharging rate constraint and capacity balance constraint.
The hydrogen storage state constraints are as follows:
Figure M_220719091221861_861933001
in the formula:
Figure M_220719091221909_909336001
and
Figure M_220719091221940_940631002
are each a hydrogen storage module
Figure M_220719091221971_971846003
Lower and upper limits of the hydrogen storage state of (a);
Figure M_220719091222003_003092004
is a hydrogen storage module
Figure M_220719091222034_034331005
In the first place
Figure M_220719091222067_067984006
Hydrogen storage state in hours.
The hydrogen charging and discharging rate constraint is as follows:
Figure M_220719091222130_130999001
in the formula:
Figure M_220719091222177_177877001
is a hydrogen storage module
Figure M_220719091222224_224757002
The capacity of (a);
Figure M_220719091222256_256012003
is a hydrogen storage module
Figure M_220719091222292_292132004
Maximum hydrogen charge rate of;
Figure M_220719091222307_307779005
is a hydrogen storage module
Figure M_220719091222339_339002006
The maximum hydrogen release rate.
The capacity balance constraint is:
if it is
Figure M_220719091222370_370294001
，
Figure M_220719091222401_401520001
If it is
Figure M_220719091222518_518235001
，
Figure M_220719091222564_564602001
In the formula:
Figure M_220719091222658_658858001
is a hydrogen storage module
Figure M_220719091222694_694024002
The efficiency of the charging process;
Figure M_220719091222740_740870003
is a hydrogen storage module
Figure M_220719091222787_787743004
The efficiency of the hydrogen discharge process;
Figure M_220719091222818_818985005
is a hydrogen storage module
Figure M_220719091222850_850231006
The ratio of hydrogen leakage to capacity per hour;
Figure M_220719091222883_883448007
is a hydrogen storage module
Figure M_220719091222914_914692008
Initial hydrogen storage state.
The system design constraint equation comprises system carbon emission constraint, upper and lower limit constraint of installed capacity of a power supply module, upper and lower limit constraint of annual input electric quantity of a power input module, upper and lower limit constraint of annual output electric quantity of a power output module, upper and lower limit constraint of capacity of an electricity storage module, upper and lower limit constraint of installed capacity of an electricity hydrogen production module, upper and lower limit constraint of installed capacity of a hydrogen power generation module, upper and lower limit constraint of annual input hydrogen quantity of a hydrogen input module, upper and lower limit constraint of annual hydrogen quantity of a hydrogen load module, upper and lower limit constraint of annual output hydrogen quantity of a hydrogen output module and upper and lower limit constraint of capacity of a hydrogen storage module.
The system carbon emission constraints are:
Figure M_220719091222945_945960001
in the formula:
Figure M_220719091223166_166655001
is a power supply module
Figure M_220719091223197_197909002
Carbon emission factor of (a);
Figure M_220719091223229_229179003
is a power input module
Figure M_220719091223262_262320004
Carbon emission factor of (a);
Figure M_220719091223294_294088005
is a power output module
Figure M_220719091223325_325361006
The carbon emission factor of (c);
Figure M_220719091223356_356581007
is a hydrogen input module
Figure M_220719091223387_387833008
Carbon emission factor of (a);
Figure M_220719091223419_419134009
is a hydrogen output module
Figure M_220719091223450_450340010
The carbon emission factor of (c);
Figure M_220719091223487_487455011
is the upper carbon emission limit of the regional electro-hydrogen system at the time section.
S6: and configuring an optimization algorithm.
The configuration optimization algorithm comprises the steps of selecting a solver in commercial software or self-writing a solving algorithm according to an optimization objective function and a constraint condition equation (linear programming problem). In this embodiment, the configuration optimization algorithm selects a linux solver in the MATLAB according to the optimization objective function and the constraint condition equation.
S7: the input parameters of the regional electro-hydrogen system 100 for the current time section are updated.
The input parameters of the regional electric hydrogen system 100 of the current time section include the initial existing installed capacity of each power module, the upper and lower limits of the installed capacity, carbon emission factors, unit fixed investment, average design life, the ratio of annual fixed operation and maintenance cost to fixed investment, the cost of electric fuel, and the ratio of the hourly maximum output of renewable energy to the installed capacity;
the input parameters of the regional electro-hydrogen system 100 for the current time section also include the ratio of the time-to-time delivered power to the peak delivered power of the power input module;
the input parameters of the regional power-hydrogen system 100 of the current time section also include the hourly power of the power load modules;
the input parameters of the regional electro-hydrogen system 100 for the current time section also include the ratio of the time-to-time delivered power to the peak delivered power of the power output module;
the input parameters of the regional hydrogen generation system 100 of the current time section further include the initial existing installed capacity of each electricity storage module, the upper and lower limits of the installed capacity, the maximum charging rate, the maximum discharging rate, the energy conversion efficiency in the charging process, the energy conversion efficiency in the discharging process, the ratio of the leakage amount per hour to the capacity, the unit fixed investment, the average design life, and the ratio of the annual fixed operation and maintenance cost to the fixed investment;
the input parameters of the regional hydrogen generation system 100 of the current time section further include the initial existing installed capacity of the hydrogen generation module, the upper and lower limits of the installed capacity, the power consumption of the unit hydrogen generation amount, the unit fixed investment, the average design life and the ratio of the annual fixed operation and maintenance cost to the fixed investment;
the input parameters of the regional hydrogen generation system 100 of the current time section further include the initial existing installed capacity of each hydrogen generation module, the upper and lower limits of the installed capacity, the hydrogen consumption of unit generated energy, unit fixed investment, average design life, and the ratio of annual fixed operation and maintenance cost to fixed investment;
the input parameters of the regional electrical hydrogen system 100 of the current time section further include the ratio of the hourly hydrogen output to the peak hydrogen output of the hydrogen input module;
the input parameters of the regional electric hydrogen system 100 of the current time section further include the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of each hydrogen load module, the annual output/transport capacity, the carbon emission factor using the prior art, the ratio of the carbon emission reduction achieved by hydrogen substitution in the prior art carbon emission, the carbon reduction amount brought by each unit hydrogen application, and the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of the hydrogen output module;
the input parameters of the regional electrical hydrogen system 100 of the current time section further include the ratio of the hourly hydrogen output to the peak hydrogen output of each hydrogen output module;
the input parameters of the regional hydrogen generation system 100 of the current time section further include the initial installed capacity of each hydrogen storage module, the upper and lower limits of the installed capacity, the maximum hydrogen charging rate, the maximum hydrogen discharging rate, the efficiency of the hydrogen charging process, the efficiency of the hydrogen discharging process, the ratio of the hydrogen leakage amount per hour to the capacity, the unit fixed investment, the average design life, and the ratio of the annual fixed operation and maintenance cost to the fixed investment. S8: and (5) solving an optimization problem.
S9: and outputting an optimization result of the regional hydrogen generation system 100 of the current time section, wherein each equipment installation in the optimization result is fed back to the next time section optimization as an existing equipment installation.
S10: and judging whether the current time section is the selected last time section or not, if not, returning to the step S7, and if so, ending the process.
The method for optimizing the decarburization path planning of the regional hydrogen generation system 100 provided by the embodiment has the beneficial effects that:
1. the method has the advantages that various elements such as a power supply, a load, energy storage, hydrogen production and hydrogen storage in the system are fully considered, the fixed investment cost, the operation and maintenance cost and the carbon emission cost in the whole system are considered, the constraints of the aspects such as electric balance, hydrogen balance, carbon emission and equipment operation are considered, the optimal cost capacity configuration and the optimal cost operation parameter development path in the decarburization process of the regional hydrogen-electricity system 100 are obtained, and the method has certain practical significance;
2. a set of methods and tools are provided for planning a decarbonization path for the regional electro-hydrogen system 100;
3. the method can realize the optimization of the capacity allocation of each component element with the optimal total system cost in the process of advancing carbon neutralization of the electro-hydrogen system in the region;
4. the method can obtain the hourly operation parameters of each component element of the hydrogen power system in the region in the selected planning period and the time section, and can guide the selection of the future operation mode and the operation scheduling arrangement of the hydrogen power system;
5. the method has higher flexibility, and can select and determine the types and the number of elements and modules considered in the system according to the characteristics of the planning area and the requirement on the spatial resolution.
The above description is only for the specific embodiments 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 also within the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.

Claims (13)

1. A regional electric hydrogen system decarburization path planning optimization method is characterized by comprising the following steps:
s1: establishing a framework of a regional electric hydrogen system (100);
s2: selecting a planning period and a time section;
s3: establishing variables to be optimized for a regional electro-hydrogen system (100);
s4: establishing an optimization objective function;
s5: establishing a constraint condition equation;
s6: configuring an optimization algorithm;
s7: updating input parameters of the regional electric hydrogen system (100) of the current time section;
s8: solving an optimization problem;
s9: outputting an optimization result of the regional hydrogen generation system (100) of the current time section, wherein each equipment installation in the optimization result is used as an existing equipment installation and fed back to the next time section for optimization;
s10: and judging whether the current time section is the selected last time section or not, if not, returning to the step S7, and if so, ending the process.
2. The regional electric hydrogen system decarburization path planning optimization method of claim 1, wherein in S1, the regional electric hydrogen system (100) comprises a power supply unit (1), a power input unit (2), a power balancing unit (3), a power load unit (4), an electricity storage unit (5), an electricity hydrogen production unit (6), a hydrogen generation unit (7), a hydrogen input unit (8), a hydrogen storage unit (9), a hydrogen balancing unit (10), a hydrogen load unit (18), a power output unit (19), and a hydrogen output unit (20);
the power supply unit (1), the power input unit (2), the power output unit (19), the power load unit (4), the electricity storage unit (5), the electricity hydrogen production unit (6), the hydrogen power generation unit (7) all link to each other with the power balance unit (3), the electricity hydrogen production unit (6), the hydrogen power generation unit (7), the hydrogen input unit (8), the hydrogen storage unit (9), the hydrogen output unit (20), the hydrogen load unit (18) all link to each other with the hydrogen balance unit (10).
3. The regional electric hydrogen system decarburization path planning optimizing method according to claim 2, wherein at S1, the number of the power balance units (3) is one or more, a plurality of the power balance units (3) are connected with each other, and there is bidirectional or unidirectional power transmission between the power balance units (3) connected with each other; the number of the hydrogen balance units (10) is one or more, the hydrogen balance units (10) are connected with each other, and bidirectional or unidirectional hydrogen transmission exists between the hydrogen balance units (10) which are connected with each other.
4. The regional power-hydrogen system decarburization path planning optimizing method according to claim 1, wherein in S2, the planning period spans a plurality of consecutive natural years, a single time section is one natural year in the planning period, and the time sections are one or more.
5. The regional electro-hydrogen system decarburization path planning optimizing method of claim 1, wherein in S3, the variables to be optimized of the regional electro-hydrogen system (100) include real variables and one-dimensional array variables.
6. The regional electric hydrogen system decarburization path planning optimizing method according to claim 5, wherein the real-type variables include installed capacity of each power supply module, annual input power of each power input module, annual output power of each power output module, capacity of each power storage module, installed capacity of each electrical hydrogen production module, installed capacity of each hydrogen generation module, annual input hydrogen amount of each hydrogen input module, annual hydrogen amount of each hydrogen load module, annual output hydrogen amount of each hydrogen output module, and capacity of each hydrogen storage module at a selected time section in the regional electric hydrogen system (100);
each of the one-dimensional array variables includes 8760 real-type variables, and the one-dimensional array variables include a hourly power generation power of each power module, a hourly discarded electric power of each power module, a hourly charge and discharge electric power of each power module, a hourly charge/energy storage state of each power storage module, a hourly operation power of each hydrogen production module, a hourly hydrogen production rate of each hydrogen production module, a hourly power generation power of each hydrogen generation module, a hourly hydrogen consumption rate of each hydrogen generation module, a hourly charge and discharge hydrogen rate of each hydrogen storage module, and a hourly hydrogen storage state of each hydrogen storage module in a selected time section of the regional hydrogen power generation system (100).
7. The regional power-hydrogen system decarburization path planning optimizing method according to claim 1, wherein in S4, the optimizing objective function is to minimize the total system cost in time section, including the fixed investment allocation, fixed operation and maintenance cost, variable operation cost and carbon emission cost of each module in the system, and is expressed as:
Figure M_220719091158889_889791001
in the formula:
Figure M_220719091159235_235013001
modules indicating operating costs within the system that are not varied include a power module, an electricity storage module, an electrical hydrogen production module, a hydrogen storage module, and a hydrogen generation module that do not require fuel consumption;
Figure M_220719091159250_250630002
the modules refer to the modules with variable running cost in the system, and comprise a coal-electricity module (11), a gas-electricity module (12) and a nuclear power module (13);
Figure M_220719091159377_377592003
the input and output module refers to electric power and hydrogen energy;
Figure M_220719091159536_536290004
is a module
Figure M_220719091159645_645654005
A newly-added installation machine is needed from the last time section to the current time section;
Figure M_220719091159679_679374006
the module is put into operation from the last time section to the current time section
Figure M_220719091159726_726720007
Average unit capital investment of (1);
Figure M_220719091159836_836085008
is at the last timeThe module is put into operation from section to the present time
Figure M_220719091159962_962543009
Average design life of;
Figure M_220719091200136_136863010
is a module
Figure M_220719091200310_310678011
Installing the existing machine on the section at the last time;
Figure M_220719091200341_341946012
is a module
Figure M_220719091200389_389176013
An installation to be decommissioned from a previous time section to the current time section;
Figure M_220719091200404_404407014
is a module
Figure M_220719091200435_435684015
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_220719091200470_470320016
is a module
Figure M_220719091200502_502092017
In the first place
Figure M_220719091200517_517713018
Generated power in hours;
Figure M_220719091200548_548982019
is a module
Figure M_220719091200580_580231020
Average electrical fuel cost during the last time section to the present time section;
Figure M_220719091200595_595845021
is the first
Figure M_220719091200627_627102022
Input or output of electrical/hydrogen energy in hours;
Figure M_220719091200642_642735023
is the average unit price of input or output electric power/hydrogen energy from the last time section to the present time section;
Figure M_220719091200679_679309024
the annual carbon emission of the system;
Figure M_220719091200742_742337025
is the average carbon number from the last time slice to this time slice.
8. The regional electric hydrogen system decarburization path planning optimizing method of claim 1, wherein in S5, the constraint equations include a system balance constraint equation, a system module constraint equation and a system design constraint equation.
9. The regional electric hydrogen system decarburization path planning optimizing method of claim 8, wherein in S5, the system balance constraint equations include a power balance node equation and a hydrogen balance node equation;
the power balance node equation is as follows:
Figure M_220719091200773_773098001
in the formula:
Figure M_220719091200869_869257001
is the other power balance node connected with the power balance node
Figure M_220719091200916_916671002
In the first place
Figure M_220719091200932_932259003
Power exchange between an hour and the power balancing node;
Figure M_220719091200963_963560004
is a power supply module connected with the power balance node
Figure M_220719091200979_979156005
In the first place
Figure M_220719091201010_010441006
Power in hours;
Figure M_220719091201041_041200007
is a power input module connected with the power balance node
Figure M_220719091201057_057269008
In the first place
Figure M_220719091201088_088532009
Hourly delivered power;
Figure M_220719091201104_104160010
is a power load module connected with the power balance node
Figure M_220719091201135_135398011
In the first place
Figure M_220719091201166_166644012
Power in hours;
Figure M_220719091201182_182286013
is a power output module connected with the power balance node
Figure M_220719091201213_213536014
In the first place
Figure M_220719091201244_244792015
Hourly delivered power;
Figure M_220719091201263_263780016
is an electricity storage module connected with the power balance node
Figure M_220719091201295_295557017
In the first place
Figure M_220719091201342_342443018
Power in hours;
Figure M_220719091201389_389317019
is an electric hydrogen production module connected with the electric power balance node
Figure M_220719091201420_420573020
In the first place
Figure M_220719091201435_435729021
Power in hours;
Figure M_220719091201469_469868022
is a hydrogen power generation module connected with the power balance node
Figure M_220719091201501_501667023
In the first place
Figure M_220719091201517_517239024
Power in hours; the power flowing into the power balance node is positive, and the power flowing out of the power balance node is negative;
the hydrogen equilibrium node equation is:
Figure M_220719091201548_548517001
in the formula:
Figure M_220719091201642_642262001
is the other hydrogen balance node connected to the hydrogen balance node
Figure M_220719091201675_675941002
In the first place
Figure M_220719091201707_707676003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_220719091201738_738928004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_220719091201754_754545005
In the first place
Figure M_220719091201785_785801006
Hydrogen production in hours;
Figure M_220719091201817_817043007
is a hydrogen power generation module connected with the hydrogen balance node
Figure M_220719091201832_832679008
In the first place
Figure M_220719091201866_866323009
Hydrogen consumption in hours;
Figure M_220719091201882_882478010
is a hydrogen input module connected with the hydrogen balance node
Figure M_220719091201913_913743011
In the first place
Figure M_220719091201944_944978012
Hydrogen output per hour;
Figure M_220719091201960_960600013
is a hydrogen load module connected with the hydrogen balance node
Figure M_220719091201991_991863014
In the first place
Figure M_220719091202023_023108015
Hydrogen usage in hours;
Figure M_220719091202038_038738016
is a hydrogen output module connected with the hydrogen balance node
Figure M_220719091202072_072385017
In the first place
Figure M_220719091202088_088551018
Hydrogen output per hour;
Figure M_220719091202119_119791019
is a hydrogen storage module connected with the hydrogen balance node
Figure M_220719091202151_151025020
In the first place
Figure M_220719091202166_166666021
Hydrogen charge/discharge amount per hour; the amount of hydrogen flowing into the hydrogen balance node is positive and the amount of hydrogen flowing out of the hydrogen balance node is negative.
10. The regional electric hydrogen system decarburization path planning optimizing method of claim 8, wherein in S5, the system module constraint equations include a power module constraint equation, an electricity storage module constraint equation, an electrical hydrogen production module constraint equation, a hydrogen generation module constraint equation, a hydrogen load module constraint equation and a hydrogen storage module constraint equation;
the power module constraint equation comprises power generation power constraint and renewable energy power curtailment constraint;
the generated power constraint is as follows:
Figure M_220719091202197_197893001
in the formula:
Figure M_220719091202229_229159001
non-renewable power module
Figure M_220719091202261_261832002
In the first place
Figure M_220719091202277_277511003
Hourly generated power;
Figure M_220719091202309_309233004
non-renewable power module
Figure M_220719091202324_324872005
Installed capacity of (d);
Figure M_220719091202356_356142001
in the formula:
Figure M_220719091202402_402505001
is a renewable power module
Figure M_220719091202418_418636002
In the first place
Figure M_220719091202449_449855003
Hourly generated power;
Figure M_220719091202485_485544004
is a renewable power module
Figure M_220719091202517_517239005
In the first place
Figure M_220719091202532_532865006
Electric power discard of hours;
Figure M_220719091202564_564118007
is a renewable power module
Figure M_220719091202595_595373008
Installed capacity of (d);
Figure M_220719091202626_626612009
is a renewable power module
Figure M_220719091202642_642228010
In the first place
Figure M_220719091202675_675429011
The ratio of maximum hourly output to installed capacity;
the renewable energy power abandon rate constraint is as follows:
Figure M_220719091202707_707208001
in the formula:
Figure M_220719091202769_769687001
is a renewable power module
Figure M_220719091202800_800941002
The annual average power abandonment rate upper limit;
the electric storage module constraint equation comprises charge/energy storage state constraint, charge and discharge power constraint and capacity balance constraint;
the charge/storage state constraints are:
Figure M_220719091202832_832175001
in the formula:
Figure M_220719091202865_865345001
and
Figure M_220719091202897_897122002
are respectively an electricity storage module
Figure M_220719091202928_928393003
Lower and upper limits of the state of charge/energy storage;
Figure M_220719091202959_959617004
is an electricity storage module
Figure M_220719091202975_975237005
In the first place
Figure M_220719091203006_006555006
Hourly charge/energy storage state;
the charge and discharge power constraint is as follows:
Figure M_220719091203022_022135001
in the formula:
Figure M_220719091203069_069939001
is an electricity storage module
Figure M_220719091203101_101701002
The capacity of (a);
Figure M_220719091203133_133001003
is an electricity storage module
Figure M_220719091203148_148586004
Maximum charge rate of;
Figure M_220719091203179_179844005
is an electricity storage module
Figure M_220719091203211_211101006
Maximum discharge rate of (d);
the capacity balance constraint is:
if it is
Figure M_220719091203226_226715001
，
Figure M_220719091203257_257946001
If it is
Figure M_220719091203385_385421001
，
Figure M_220719091203416_416647001
In the formula:
Figure M_220719091203535_535295001
is an electricity storage module
Figure M_220719091203566_566555002
Energy conversion efficiency of charging;
Figure M_220719091203582_582191003
is an electricity storage module
Figure M_220719091203613_613446004
Energy conversion efficiency of the discharge;
Figure M_220719091203629_629054005
is an electricity storage module
Figure M_220719091203660_660316006
Leakage to capacity ratio per hour;
Figure M_220719091203679_679802007
is an electricity storage module
Figure M_220719091203711_711572008
Initial state of charge/energy storage;
the constraint equation of the electrohydrogen production module comprises an operation power constraint and an energy conversion constraint;
the operating power constraints are:
Figure M_220719091203742_742825001
in the formula:
Figure M_220719091203774_774070001
is an electric hydrogen production module
Figure M_220719091203805_805333002
Installed capacity of (d);
the energy conversion constraint is:
Figure M_220719091203852_852211001
in the formula:
Figure M_220719091203885_885874001
is an electric hydrogen production module
Figure M_220719091203917_917174002
Electricity consumption per unit hydrogen production;
the hydrogen power generation module constraint equation comprises an operating power constraint and an energy conversion constraint;
the operating power constraint is:
Figure M_220719091203948_948419001
in the formula:
Figure M_220719091203979_979642001
is a hydrogen power generation module
Figure M_220719091204010_010911002
Installed capacity of (d);
the energy conversion constraint is:
Figure M_220719091204026_026539001
in the formula:
Figure M_220719091204057_057759001
is a hydrogen power generation module
Figure M_220719091204090_090949002
Hydrogen consumption per unit of generated energy;
the hydrogen load module constraint equation comprises a hydrogen usage constraint;
the hydrogen usage constraint is:
Figure M_220719091204106_106605001
in the formula:
Figure M_220719091204169_169087001
is a hydrogen load module
Figure M_220719091204200_200331002
The maximum possible amount of hydrogen used per year within said time section;
Figure M_220719091204247_247219003
is a hydrogen load module
Figure M_220719091204282_282826004
Annual production/traffic within the time section;
Figure M_220719091204314_314128005
is a hydrogen load module
Figure M_220719091204329_329723006
Adopting the carbon emission factor of the prior art;
Figure M_220719091204360_360979007
is a hydrogen load module
Figure M_220719091204392_392249008
The proportion of emission reduction is realized by hydrogen substitution in the carbon emission of the prior art;
Figure M_220719091204407_407878009
is a hydrogen load module
Figure M_220719091204439_439122010
Carbon reduction per unit hydrogen application;
the hydrogen storage module constraint equation comprises hydrogen storage state constraint, hydrogen charging and discharging rate constraint and capacity balance constraint;
the hydrogen storage state constraints are:
Figure M_220719091204471_471791001
in the formula:
Figure M_220719091204519_519185001
and
Figure M_220719091204534_534823002
are each a hydrogen storage module
Figure M_220719091204581_581733003
The lower limit and the upper limit of the hydrogen storage state of (a);
Figure M_220719091204612_612945004
is a hydrogen storage module
Figure M_220719091204628_628545005
In the first place
Figure M_220719091204659_659808006
Hydrogen storage status of hours;
the hydrogen charging and discharging rate constraint is as follows:
Figure M_220719091204676_676865001
in the formula:
Figure M_220719091204739_739885001
is a hydrogen storage module
Figure M_220719091204771_771143002
The capacity of (a);
Figure M_220719091204802_802395003
is a hydrogen storage module
Figure M_220719091204833_833663004
Maximum hydrogen charge rate of;
Figure M_220719091204867_867788005
is a hydrogen storage module
Figure M_220719091204915_915210006
The maximum hydrogen release rate;
the capacity balance constraint is:
if it is
Figure M_220719091204930_930807001
，
Figure M_220719091204962_962068001
If it is
Figure M_220719091205055_055809001
，
Figure M_220719091205089_089993001
In the formula:
Figure M_220719091205199_199386001
is a hydrogen storage module
Figure M_220719091205214_214995002
The efficiency of the charging process;
Figure M_220719091205246_246286003
is a hydrogen storage module
Figure M_220719091205280_280954004
The efficiency of the hydrogen discharge process;
Figure M_220719091205296_296524005
is a hydrogen storage module
Figure M_220719091205327_327786006
The ratio of hydrogen leakage to capacity per hour;
Figure M_220719091205359_359052007
is a hydrogen storage module
Figure M_220719091205390_390312008
Initial hydrogen storage state.
11. The regional electric hydrogen system decarburization path planning and optimizing method according to claim 8, wherein in S5, the system design constraint equation includes system carbon emission constraints, upper and lower limit constraints on installed capacity of a power supply module, upper and lower limit constraints on annual input electric quantity of a power input module, upper and lower limit constraints on annual output electric quantity of a power output module, upper and lower limit constraints on capacity of a power storage module, upper and lower limit constraints on installed capacity of an electric hydrogen production module, upper and lower limit constraints on installed capacity of a hydrogen generation module, upper and lower limit constraints on annual input hydrogen quantity of a hydrogen input module, upper and lower limit constraints on annual hydrogen quantity of a hydrogen load module, upper and lower limit constraints on annual output hydrogen quantity of a hydrogen output module, upper and lower limit constraints on capacity of a hydrogen storage module;
wherein the system carbon emission constraints are:
Figure M_220719091205405_405928001
in the formula:
Figure M_220719091205612_612495001
is a power supply module
Figure M_220719091205643_643719002
The carbon emission factor of (c);
Figure M_220719091205659_659329003
is a power input module
Figure M_220719091205693_693017004
Carbon emission factor of (a);
Figure M_220719091205724_724278005
is a power output module
Figure M_220719091205755_755545006
The carbon emission factor of (c);
Figure M_220719091205771_771170007
is a hydrogen input module
Figure M_220719091205803_803697008
Carbon emission factor of (a);
Figure M_220719091205833_833656009
is a hydrogen output module
Figure M_220719091205866_866326010
Carbon emission factor of (a);
Figure M_220719091205882_882468011
is the upper carbon emission limit of the regional electro-hydrogen system over the time section.
12. The method for optimizing the regional electro-hydrogen system decarburization path planning of claim 1, wherein in S6, the configuration optimization algorithm selects a linux solver in MATLAB according to the optimization objective function and the constraint equation.
13. The regional electric hydrogen system decarburization path planning optimization method of claim 1, wherein in S7, the input parameters of the regional electric hydrogen system (100) of the current time section include initial existing installed capacity of each power module, upper and lower limits of installed capacity, carbon emission factor, unit fixed investment, average design life, ratio of annual fixed operation and maintenance cost to fixed investment, kilowatt-hour fuel cost, ratio of hourly maximum output of renewable energy to installed capacity;
the input parameters of the regional electro-hydrogen system (100) of the current time section further comprise a ratio of a time-wise delivered power to a peak delivered power of the power input module;
the input parameters of the regional electro-hydrogen system (100) of the current time section further comprise the time-by-time power of the power load module;
the input parameters of the regional electro-hydrogen system (100) of the current time section further comprise a ratio of a time-wise delivered power to a peak delivered power of the power output module;
the input parameters of the regional hydrogen generation system (100) of the current time section further comprise the initial existing installed capacity of each electricity storage module, the upper and lower limits of the installed capacity, the maximum charging multiplying factor, the maximum discharging multiplying factor, the energy conversion efficiency in the charging process, the energy conversion efficiency in the discharging process, the ratio of the hourly leakage amount to the capacity, the unit fixed investment, the average design life and the ratio of the annual fixed operation and maintenance cost to the fixed investment;
the input parameters of the regional hydrogen generation system (100) of the current time section further comprise the initial existing installed capacity of the hydrogen generation module, the upper and lower limits of the installed capacity, the power consumption of unit hydrogen production, unit fixed investment, average design life and the ratio of annual fixed operation and maintenance cost to fixed investment;
the input parameters of the regional hydrogen power system (100) of the current time section further comprise the initial existing installed capacity of each hydrogen power generation module, the upper limit and the lower limit of the installed capacity, the hydrogen consumption of unit generated energy, unit fixed investment, average design life and the ratio of annual fixed operation and maintenance cost to fixed investment;
the input parameters of the regional electric hydrogen system (100) of the current time section further comprise the ratio of the hourly hydrogen output to the peak hydrogen output of the hydrogen input module;
the input parameters of the regional electro-hydrogen system (100) of the current time section further comprise the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of each hydrogen load module, the annual output/transport capacity, a carbon emission factor adopting the prior art, the ratio of realizing emission reduction by hydrogen substitution in the carbon emission of the prior art, the carbon reduction amount brought by each unit of hydrogen application and the ratio of the hourly hydrogen consumption to the peak hydrogen consumption of the hydrogen output module;
the input parameters of the regional electric hydrogen system (100) of the current time section further comprise the ratio of the hourly hydrogen output quantity to the peak hydrogen output quantity of each hydrogen output module;
the input parameters of the regional hydrogen power system (100) of the current time section further comprise initial existing installed capacity of each hydrogen storage module, upper and lower limits of the installed capacity, maximum hydrogen charging rate, maximum hydrogen discharging rate, efficiency of a hydrogen charging process, efficiency of a hydrogen discharging process, a ratio of hydrogen leakage amount per hour to capacity, unit fixed investment, average design life and a ratio of annual fixed operation and maintenance cost to fixed investment.
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