CN115079564B - 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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CN115079564B
CN115079564B CN202210856118.9A CN202210856118A CN115079564B CN 115079564 B CN115079564 B CN 115079564B CN 202210856118 A CN202210856118 A CN 202210856118A CN 115079564 B CN115079564 B CN 115079564B
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CN115079564A (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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    • G05B—CONTROL OR REGULATING SYSTEMS IN GENERAL; FUNCTIONAL ELEMENTS OF SUCH SYSTEMS; MONITORING OR TESTING ARRANGEMENTS FOR SUCH SYSTEMS OR ELEMENTS
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    • 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
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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 generating 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 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 method for optimizing decarburization path planning of a regional hydrogen generation system.
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 difficult to decarbonize, such as steel, cement, petrochemical industry and the like, at the load end, and can realize the effect of 1+1 >.
Both power systems and hydrogen energy systems are very complex systems, and the interaction between the two systems further increases the complexity of the overall 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 generating 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 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 optional 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 in the planning period, and the time sections are one or more.
In an alternative embodiment, in S3, the variables to be optimized of 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, 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 running power of each hydrogen production module, the hourly hydrogen production rate of each 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 of a selected time section in the regional electric hydrogen system.
In an alternative embodiment, in S4, the objective function is optimized to minimize the total system cost in the time section, including the allocation of fixed investment, fixed operation and maintenance costs, variable operation costs, and carbon emission costs of each module in the system, which are expressed as:
Figure M_221010103217291_291556001
in the formula:
Figure M_221010103217528_528878001
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_221010103217560_560110002
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_221010103217591_591359003
the system refers to input and output modules of electric power and hydrogen energy;
Figure M_221010103217606_606987004
is a module
Figure M_221010103217638_638234005
Newly adding an installation machine from the last time section to the current time section;
Figure M_221010103217669_669467006
the module is put into operation from the last time section to the current time section
Figure M_221010103217703_703153007
Average unit capital investment of (1);
Figure M_221010103217718_718777008
is put into operation from the last time section to the current time section
Figure M_221010103217750_750050009
Average design life of (c);
Figure M_221010103217781_781298010
is a module
Figure M_221010103217812_812527011
Installing the existing machine on the section at the last time;
Figure M_221010103217828_828148012
is a module
Figure M_221010103217859_859403013
An installation to be decommissioned from a previous time section to the current time section;
Figure M_221010103217875_875032014
is a module
Figure M_221010103217910_910174015
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_221010103217941_941443016
is a module
Figure M_221010103217972_972719017
In the first place
Figure M_221010103217988_988308018
Generated power within an hour;
Figure M_221010103218019_019554019
is a module
Figure M_221010103218050_050822020
Average electrical fuel cost from last time section to present time section;
Figure M_221010103218083_083498021
is the first
Figure M_221010103218115_115262022
Input or output of electrical/hydrogen energy in hours;
Figure M_221010103218130_130902023
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_221010103218162_162148024
the annual carbon emission of the system;
Figure M_221010103218193_193425025
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 module constraint equation, and a system design constraint equation.
In an alternative embodiment, 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_221010103218224_224667001
in the formula:
Figure M_221010103218320_320361001
is the other power balance node connected with the power balance node
Figure M_221010103218351_351614002
In the first place
Figure M_221010103218367_367220003
Power exchange between an hour and the power balancing node;
Figure M_221010103218398_398475004
is a power supply module connected with the power balance node
Figure M_221010103218414_414108005
In the first place
Figure M_221010103218445_445350006
Power in hours;
Figure M_221010103218460_460981007
is a power input module connected with the power balance node
Figure M_221010103218493_493178008
In the first place
Figure M_221010103218524_524926009
Hourly delivered power;
Figure M_221010103218540_540565010
is a power load module connected with the power balance node
Figure M_221010103218571_571809011
In the first place
Figure M_221010103218587_587438012
Power in hours;
Figure M_221010103218618_618677013
is a power output module connected with the power balance node
Figure M_221010103218634_634323014
In the first place
Figure M_221010103218665_665581015
Hourly delivered power;
Figure M_221010103218685_685059016
is an electricity storage module connected with the power balance node
Figure M_221010103218716_716874017
In the first place
Figure M_221010103218748_748114018
Power in hours;
Figure M_221010103218763_763701019
is an electric hydrogen production module connected with the electric power balance node
Figure M_221010103218810_810594020
In the first place
Figure M_221010103218826_826221021
Power in hours;
Figure M_221010103218857_857453022
is a hydrogen power generation module connected with the power balance node
Figure M_221010103218890_890141023
In the first place
Figure M_221010103218906_906291024
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_221010103218937_937556001
in the formula:
Figure M_221010103219015_015658001
is the other hydrogen balance node connected to the hydrogen balance node
Figure M_221010103219046_046937002
In the first place
Figure M_221010103219078_078171003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_221010103219096_096669004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_221010103219128_128457005
In the first place
Figure M_221010103219159_159239006
Hydrogen production in hours;
Figure M_221010103219190_190975007
is a hydrogen power generation module connected with the hydrogen balance node
Figure M_221010103219321_321320008
In the first place
Figure M_221010103219352_352587009
Hydrogen consumption in hours;
Figure M_221010103219383_383830010
is a hydrogen input module connected with the hydrogen balance node
Figure M_221010103219415_415088011
In the first place
Figure M_221010103219446_446360012
Hydrogen input per hour;
Figure M_221010103219461_461916013
is a hydrogen load module connected with the hydrogen balance node
Figure M_221010103219498_498537014
In the first place
Figure M_221010103219514_514719015
Hydrogen usage in hours;
Figure M_221010103219545_545925016
is a hydrogen output module connected with the hydrogen balance node
Figure M_221010103219561_561548017
In the first place
Figure M_221010103219592_592806018
Hydrogen output per hour;
Figure M_221010103219608_608435019
is andthe hydrogen storage module connected with the hydrogen balance node
Figure M_221010103219639_639680020
In the first place
Figure M_221010103219670_670933021
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 electricity 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_221010103219688_688976001
in the formula:
Figure M_221010103219736_736388001
non-renewable power module
Figure M_221010103219752_752023002
In the first place
Figure M_221010103219798_798872003
Hourly generated power;
Figure M_221010103219830_830137004
non-renewable power module
Figure M_221010103220035_035234005
Installed capacity of (d);
Figure M_221010103220050_050829001
in the formula:
Figure M_221010103220099_099635001
is a renewable power module
Figure M_221010103220130_130906002
In the first place
Figure M_221010103220162_162155003
Hourly generated power;
Figure M_221010103220193_193401004
is a renewable power module
Figure M_221010103220224_224662005
In the first place
Figure M_221010103220255_255917006
Electric power discard of hours;
Figure M_221010103220271_271531007
is a renewable power module
Figure M_221010103220306_306186008
Installed capacity of (a);
Figure M_221010103220338_338947009
is a renewable power module
Figure M_221010103220370_370649010
In the first place
Figure M_221010103220401_401894011
The ratio of maximum hourly output to installed capacity;
the renewable energy power abandon rate constraint is as follows:
Figure M_221010103220417_417587001
in the formula:
Figure M_221010103220480_480960001
is a renewable power module
Figure M_221010103220512_512733002
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_221010103220544_544005001
in the formula:
Figure M_221010103220590_590878001
and
Figure M_221010103220622_622119002
are respectively an electricity storage module
Figure M_221010103220653_653362003
Lower and upper limits of the state of charge/energy storage;
Figure M_221010103220668_668970004
is an electricity storage module
Figure M_221010103220704_704625005
In the first place
Figure M_221010103220735_735887006
Hourly charge/energy storage state;
the charge and discharge power constraint is as follows:
Figure M_221010103220751_751492001
in the formula:
Figure M_221010103220798_798394001
is an electricity storage module
Figure M_221010103220829_829637002
The capacity of (a);
Figure M_221010103220860_860904003
is an electricity storage module
Figure M_221010103220893_893554004
Maximum charge rate of;
Figure M_221010103220925_925344005
is an electricity storage module
Figure M_221010103220940_940955006
Maximum discharge rate of (d);
the capacity balance constraint is:
if it is
Figure M_221010103220972_972220001
，
Figure M_221010103221003_003469001
If it is
Figure M_221010103221114_114793001
，
Figure M_221010103221130_130423001
In the formula:
Figure M_221010103221239_239787001
is an electricity storage module
Figure M_221010103221271_271024002
Energy conversion efficiency of charging;
Figure M_221010103221303_303735003
is an electricity storage module
Figure M_221010103221335_335010004
Energy conversion efficiency of the discharge;
Figure M_221010103221350_350609005
is an electricity storage module
Figure M_221010103221381_381970006
A ratio of leakage to capacity per hour;
Figure M_221010103221413_413121007
is an electricity storage module
Figure M_221010103221444_444410008
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_221010103221475_475645001
in the formula:
Figure M_221010103221508_508841001
is an electric hydrogen production module
Figure M_221010103221540_540110002
Installed capacity of (d);
the energy conversion constraint is:
Figure M_221010103221571_571320001
in the formula：
Figure M_221010103221618_618216001
Is an electric hydrogen production module
Figure M_221010103221649_649458002
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_221010103221682_682169001
in the formula:
Figure M_221010103221729_729576001
is a hydrogen power generation module
Figure M_221010103221760_760796002
Installed capacity of (a);
the energy conversion constraint is:
Figure M_221010103221792_792058001
in the formula:
Figure M_221010103221823_823301001
is a hydrogen power generation module
Figure M_221010103221854_854574002
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_221010103221887_887731001
in the formula:
Figure M_221010103221950_950744001
is a hydrogen load module
Figure M_221010103221981_981980002
The maximum possible amount of hydrogen used per year in the time section;
Figure M_221010103222013_013257003
is a hydrogen load module
Figure M_221010103222044_044493004
Annual production/traffic in time section;
Figure M_221010103222075_075769005
is a hydrogen load module
Figure M_221010103222108_108483006
Adopting the carbon emission factor of the prior art;
Figure M_221010103222140_140141007
is a hydrogen load module
Figure M_221010103222202_202699008
The proportion of emission reduction can be realized by replacing hydrogen in the carbon emission in the prior art;
Figure M_221010103222249_249547009
is a hydrogen load module
Figure M_221010103222282_282240010
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_221010103222314_314029001
in the formula:
Figure M_221010103222360_360898001
and
Figure M_221010103222392_392140002
are each a hydrogen storage module
Figure M_221010103222438_438987003
Lower and upper limits of the hydrogen storage state of (a);
Figure M_221010103222470_470250004
is a hydrogen storage module
Figure M_221010103222503_503441005
In the first place
Figure M_221010103222534_534772006
Hydrogen storage status of hours;
the hydrogen charging and discharging rate constraint is as follows:
Figure M_221010103222565_565954001
in the formula:
Figure M_221010103222612_612829001
is a hydrogen storage module
Figure M_221010103222644_644090002
The capacity of (a);
Figure M_221010103222675_675329003
is a hydrogen storage module
Figure M_221010103222691_691902004
Maximum hydrogen charge rate of;
Figure M_221010103222723_723659005
is a hydrogen storage module
Figure M_221010103222786_786173006
The maximum hydrogen release rate;
the capacity balance constraints are:
if it is
Figure M_221010103222864_864296001
，
Figure M_221010103222897_897005001
If it is
Figure M_221010103222990_990744001
，
Figure M_221010103223021_021997001
In the formula:
Figure M_221010103223133_133323001
is a hydrogen storage module
Figure M_221010103223164_164603002
The efficiency of the charging process;
Figure M_221010103223195_195835003
is a hydrogen storage module
Figure M_221010103223227_227084004
The efficiency of the hydrogen discharge process;
Figure M_221010103223258_258358005
is a hydrogen storage module
Figure M_221010103223294_294914006
The ratio of hydrogen leakage to capacity per hour;
Figure M_221010103223326_326695007
is a hydrogen storage module
Figure M_221010103223373_373594008
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 of installed capacity of the power supply module, upper and lower limit constraints of annual input power of the power input module, upper and lower limit constraints of annual output power of the power output module, upper and lower limit constraints of capacity of the power storage module, upper and lower limit constraints of installed capacity of the hydrogen production module, upper and lower limit constraints of installed capacity of the hydrogen generation module, upper and lower limit constraints of annual input hydrogen amount of the hydrogen input module, upper and lower limit constraints of annual hydrogen amount of the hydrogen load module, upper and lower limit constraints of annual output hydrogen amount of the hydrogen output module, and upper and lower limit constraints of capacity of the hydrogen storage module;
wherein the system carbon emission constraint is:
Figure M_221010103223404_404810001
in the formula:
Figure M_221010103223775_775929001
is a power supply module
Figure M_221010103223807_807175002
Carbon emission factor of (a);
Figure M_221010103223838_838425003
is a power input module
Figure M_221010103223854_854054004
Carbon emission factor of (a);
Figure M_221010103223887_887702005
is a power output module
Figure M_221010103223919_919469006
The carbon emission factor of (c);
Figure M_221010103223950_950720007
is a hydrogen input module
Figure M_221010103223981_981970008
The carbon emission factor of (c);
Figure M_221010103223997_997599009
is a hydrogen output module
Figure M_221010103224028_028850010
Carbon emission factor of (a);
Figure M_221010103224060_060101011
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 linear solver in the MATLAB according to the optimization objective function and the constraint condition 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 time-by-time maximum 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 electric 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 electric hydrogen system of the current time section further comprise the initial existing installed capacity of the electric hydrogen production module, the upper and lower limits of the installed capacity, the power consumption of unit hydrogen production, 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 power-hydrogen system 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 power generation, 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 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 total system cost in the process of advancing carbon neutralization of the electro-hydrogen system in the region;
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 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 local 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 units 5 may include battery modules 51, pumped-water energy storage modules 52, flywheel modules, 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 cells 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 contemplated 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 2020-2060 years, with a single time slice being a natural year within the planning period, with time slices selected to be 2025, 2030, 2035, 2040, 2050, 2060 years.
S3: variables to be optimized for the regional electro-hydrogen system 100 are established.
The variables to be optimized of the regional electric hydrogen system 100 include two types of real 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 type variables. The one-dimensional array variables include the hourly power generation power of each power module of the selected time section in the regional electrical hydrogen system 100, the hourly discarded electric power of each power module (this variable exists only for renewable energy), the hourly charge-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 electrical hydrogen production module, the hourly hydrogen production rate of each electrical hydrogen production module, the hourly power generation power of each hydrogen generation module, the hourly hydrogen consumption rate of each hydrogen storage module, and the hourly hydrogen storage state (ratio of stored hydrogen to charged-discharged 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 the time section, which includes the allocation of fixed investment, fixed operation and maintenance cost, variable operation cost, and carbon emission cost of each module in the system, and can be expressed as:
Figure M_221010103224092_092777001
in the formula:
Figure M_221010103224281_281727001
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_221010103224313_313519002
the modules refer to the modules with variable running cost in the system, and comprise a coal power module 11, a gas power module 12, a nuclear power module 13 and other power modules which need to consume fuel;
Figure M_221010103224344_344771003
an input module for power and hydrogen energy;
Figure M_221010103224376_376032004
is a module
Figure M_221010103224406_406787005
A newly-added installation machine is needed from the last time section to the current time section;
Figure M_221010103224438_438524006
is a module
Figure M_221010103224469_469768007
A newly-added installation machine is needed from the last time section to the current time section;
Figure M_221010103224485_485850008
the module is put into operation from the last time section to the current time section
Figure M_221010103224517_517632009
Average unit capital investment of (1);
Figure M_221010103224548_548884010
is the module commissioned from the last time section to the current time section
Figure M_221010103224673_673864011
Average design life of;
Figure M_221010103224707_707561012
is the module commissioned from the last time section to the current time section
Figure M_221010103224723_723176013
Average design life of (c);
Figure M_221010103224770_770086014
is a module
Figure M_221010103224801_801312015
Installing the existing machine on the section at the last time;
Figure M_221010103224832_832553016
is a module
Figure M_221010103224863_863800017
An installation to be decommissioned from a previous time section to the current time section;
Figure M_221010103224898_898963018
is a module
Figure M_221010103224945_945839019
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_221010103224977_977137020
is a module
Figure M_221010103225008_008349021
In the first place
Figure M_221010103225023_023963022
Generated power within an hour;
Figure M_221010103225055_055216023
is a module
Figure M_221010103225088_088403024
Average electrical fuel cost during the last time section to the present time section;
Figure M_221010103225120_120145025
is the first
Figure M_221010103225151_151436026
Input or output of electrical/hydrogen energy in hours;
Figure M_221010103225182_182663027
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_221010103225213_213911028
the annual carbon emission of the system;
Figure M_221010103225245_245142029
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 a power balance node equation and a hydrogen balance node equation.
The power balance node equation is as follows:
Figure M_221010103225276_276396001
in the formula:
Figure M_221010103225360_360378001
is the other power balance node connected with the power balance node
Figure M_221010103225391_391640002
In the first place
Figure M_221010103225422_422901003
Power exchange between an hour and the power balancing node;
Figure M_221010103225454_454157004
is a power supply module connected with the power balance node
Figure M_221010103225485_485847005
In the first place
Figure M_221010103225501_501989006
Power in hours;
Figure M_221010103225533_533246007
is a power input module connected with the power balance node
Figure M_221010103225564_564524008
In the first place
Figure M_221010103225595_595735009
Hourly delivered power;
Figure M_221010103225627_627009010
is a power load module connected with the power balance node
Figure M_221010103225658_658244011
In the first place
Figure M_221010103225673_673861012
Power in hours;
Figure M_221010103225706_706595013
is a power output module connected with the power balance node
Figure M_221010103225737_737842014
In the first place
Figure M_221010103225769_769067015
Hourly delivered power;
Figure M_221010103225784_784693016
is an electricity storage module connected with the power balance node
Figure M_221010103225831_831580017
In the first place
Figure M_221010103225862_862836018
Power in hours;
Figure M_221010103225878_878457019
is an electric hydrogen production module connected with the electric power balance node
Figure M_221010103225913_913613020
In the first place
Figure M_221010103225944_944881021
Power in hours;
Figure M_221010103225976_976126022
is a hydrogen power generation module connected with the power balance node
Figure M_221010103226006_006888023
In the first place
Figure M_221010103226022_022971024
Hourly 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_221010103226054_054231001
in the formula:
Figure M_221010103226151_151897001
is the other hydrogen balance node connected with the hydrogen balance node
Figure M_221010103226183_183147002
In the first place
Figure M_221010103226198_198763003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_221010103226230_230012004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_221010103226261_261259005
In the first place
Figure M_221010103226293_293952006
Hydrogen production in hours;
Figure M_221010103226341_341359007
is a hydrogen power generation module connected with the hydrogen balance node
Figure M_221010103226419_419461008
In the first place
Figure M_221010103226435_435090009
Hydrogen consumption in hours;
Figure M_221010103226466_466354010
is a hydrogen input module connected to the hydrogen balance node
Figure M_221010103226499_499063011
In the first place
Figure M_221010103226530_530302012
Hydrogen output per hour;
Figure M_221010103226545_545926013
is a hydrogen load module connected with the hydrogen balance node
Figure M_221010103226577_577170014
In the first place
Figure M_221010103226608_608444015
Hydrogen usage in hours;
Figure M_221010103226639_639690016
is a hydrogen output module connected with the hydrogen balance node
Figure M_221010103226670_670943017
In the first place
Figure M_221010103226690_690432018
Hydrogen input per hour;
Figure M_221010103226722_722215019
is a hydrogen storage module connected with the hydrogen balance node
Figure M_221010103226753_753445020
In the first place
Figure M_221010103226784_784716021
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_221010103226815_815965001
in the formula:
Figure M_221010103226847_847204001
non-renewable power module
Figure M_221010103226905_905283002
In the first place
Figure M_221010103226937_937051003
Hourly generated power;
Figure M_221010103227152_152874004
non-renewable power module
Figure M_221010103227184_184129005
Installed capacity of (c).
Figure M_221010103227215_215360001
In the formula:
Figure M_221010103227262_262273001
is a renewable power module
Figure M_221010103227295_295405002
In the first place
Figure M_221010103227327_327198003
Hourly generated power;
Figure M_221010103227358_358426004
is a renewable power module
Figure M_221010103227389_389715005
In the first place
Figure M_221010103227420_420928006
Electric power discard per hour;
Figure M_221010103227452_452186007
is a renewable power module
Figure M_221010103227485_485855008
Installed capacity of (d);
Figure M_221010103227501_501989009
is a renewable power module
Figure M_221010103227533_533228010
In the first place
Figure M_221010103227564_564485011
The ratio of maximum hourly output to installed capacity.
The renewable energy power abandon rate constraint is as follows:
Figure M_221010103227595_595750001
in the formula:
Figure M_221010103227642_642612001
is a renewable power module
Figure M_221010103227689_689910002
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_221010103227705_705105001
in the formula:
Figure M_221010103227751_751984001
and
Figure M_221010103227798_798870002
are respectively an electricity storage module
Figure M_221010103227830_830113003
Lower and upper limits of the state of charge/energy storage;
Figure M_221010103227861_861378004
is an electricity storage module
Figure M_221010103227894_894043005
In the first place
Figure M_221010103227925_925858006
Charge/storage state in hours.
The charge and discharge power constraint is as follows:
Figure M_221010103227941_941421001
in the formula:
Figure M_221010103227988_988296001
is an electricity storage module
Figure M_221010103228019_019554002
The capacity of (a);
Figure M_221010103228050_050829003
is an electricity storage module
Figure M_221010103228083_083490004
Maximum charge rate of (d);
Figure M_221010103228115_115269005
is an electricity storage module
Figure M_221010103228146_146521006
Maximum discharge rate of (d);
Figure M_221010103228177_177302007
is an electricity storage module
Figure M_221010103228209_209014008
The charge and discharge power of (1).
The capacity balance constraint is:
if it is
Figure M_221010103228240_240272001
，
Figure M_221010103228271_271525001
If it is
Figure M_221010103228368_368206001
，
Figure M_221010103228399_399482001
In the formula:
Figure M_221010103228495_495604001
is an electricity storage module
Figure M_221010103228527_527390002
Energy conversion efficiency of charging;
Figure M_221010103228558_558638003
is an electricity storage module
Figure M_221010103228589_589906004
Energy conversion efficiency of the discharge;
Figure M_221010103228621_621122005
is an electricity storage module
Figure M_221010103228652_652375006
A ratio of leakage to capacity per hour;
Figure M_221010103228684_684615007
is an electricity storage module
Figure M_221010103228701_701739008
Initial state of charge/energy storage.
The electrohydrogen production module constraint equations include an operating power constraint and an energy conversion constraint.
The operating power constraints are:
Figure M_221010103228732_732931001
in the formula:
Figure M_221010103228764_764208001
is an electric hydrogen production module
Figure M_221010103228795_795449002
Installed capacity of (d);
Figure M_221010103228826_826686003
is an electric hydrogen production module
Figure M_221010103228857_857944004
The operating power of (c).
The energy conversion constraint is:
Figure M_221010103228890_890630001
in the formula:
Figure M_221010103228938_938017001
is an electric hydrogen production module
Figure M_221010103228969_969272002
Electricity consumption per unit hydrogen production;
Figure M_221010103229000_000530003
is an electric hydrogen production module
Figure M_221010103229031_031770004
The amount of energy conversion.
The hydrogen power generation module constraint equations include an operating power constraint and an energy conversion constraint.
The operating power constraints are:
Figure M_221010103229063_063036001
in the formula:
Figure M_221010103229095_095706001
is a hydrogen power generation module
Figure M_221010103229127_127476002
The installed capacity of (c).
The energy conversion constraint is:
Figure M_221010103229158_158727001
in the formula:
Figure M_221010103229205_205615001
is a hydrogen power generation module
Figure M_221010103229236_236845002
Hydrogen consumption per unit of generated energy;
Figure M_221010103229268_268109003
is a hydrogen power generation module
Figure M_221010103229316_316432004
。
The hydrogen load module constraint equation includes a constraint with an amount of hydrogen.
The hydrogen dosage constraints are:
Figure M_221010103229394_394568001
in the formula:
Figure M_221010103229457_457057001
is a hydrogen load module
Figure M_221010103229492_492740002
The maximum possible amount of hydrogen used per year in the time section;
Figure M_221010103229524_524440003
is a hydrogen load module
Figure M_221010103229571_571356004
Annual production/traffic in time section;
Figure M_221010103229602_602616005
is a hydrogen load module
Figure M_221010103229633_633876006
Adopting the carbon emission factor of the prior art;
Figure M_221010103229665_665115007
is a hydrogen load module
Figure M_221010103229698_698299008
The proportion of emission reduction can be realized by replacing hydrogen in the carbon emission in the prior art;
Figure M_221010103229745_745154009
is a hydrogen load module
Figure M_221010103229776_776423010
Carbon reduction per unit hydrogen application;
Figure M_221010103229807_807680011
。
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_221010103229870_870153001
in the formula:
Figure M_221010103229938_938516001
and
Figure M_221010103229985_985431002
are each a hydrogen storage module
Figure M_221010103230016_016657003
The lower limit and the upper limit of the hydrogen storage state of (a);
Figure M_221010103230047_047916004
is a hydrogen storage module
Figure M_221010103230080_080566005
In the first place
Figure M_221010103230112_112342006
Hydrogen storage state in hours.
The hydrogen charging and discharging rate constraint is as follows:
Figure M_221010103230143_143594001
in the formula:
Figure M_221010103230190_190458001
is a hydrogen storage module
Figure M_221010103230237_237351002
The capacity of (a);
Figure M_221010103230268_268606003
is a hydrogen storage module
Figure M_221010103230302_302761004
Maximum hydrogen charge rate of;
Figure M_221010103230335_335455005
is a hydrogen storage module
Figure M_221010103230382_382843006
The maximum hydrogen release rate;
Figure M_221010103230414_414088007
。
the capacity balance constraint is:
if it is
Figure M_221010103230460_460968001
，
Figure M_221010103230657_657282001
If it is
Figure M_221010103230752_752968001
，
Figure M_221010103230784_784214001
In the formula:
Figure M_221010103230909_909206001
is a hydrogen storage module
Figure M_221010103230955_955626002
The efficiency of the charging process;
Figure M_221010103230987_987343003
is a hydrogen storage module
Figure M_221010103231034_034219004
The efficiency of the hydrogen discharge process;
Figure M_221010103231065_065014005
is a hydrogen storage module
Figure M_221010103231098_098182006
The ratio of hydrogen leakage to capacity per hour;
Figure M_221010103231129_129467007
is a hydrogen storage module
Figure M_221010103231176_176345008
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_221010103231207_207627001
in the formula:
Figure M_221010103231412_412194001
is a power supply module
Figure M_221010103231443_443923002
The carbon emission factor of (c);
Figure M_221010103231475_475122003
is a power input module
Figure M_221010103231507_507894004
The carbon emission factor of (c);
Figure M_221010103231539_539581005
is a power output module
Figure M_221010103231586_586469006
The carbon emission factor of (c);
Figure M_221010103231617_617745007
is a hydrogen input module
Figure M_221010103231649_649004008
Carbon emission factor of (a);
Figure M_221010103231683_683130009
is a hydrogen output module
Figure M_221010103231730_730498010
The carbon emission factor of (c);
Figure M_221010103231761_761749011
is the upper carbon emission limit of the regional electro-hydrogen system over 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 linear solver in the MATLAB according to the optimization objective function and the constraint 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 electro-hydrogen system 100 for the current time section also include the time-by-time 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 volume, the carbon emission factor of the existing process, the proportion of the existing process for realizing emission reduction by hydrogen substitution in carbon emission, 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 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, 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 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 the types and the number of elements and modules considered in the system can be selected and determined 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 included in 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 (8)

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: judging whether the current time section is the selected last time section or not, if not, returning to S7, and if so, ending the process;
in S4, the optimization objective function is to minimize the total system cost in the time section, including the allocation of fixed investment, fixed operation and maintenance cost, variable operation cost, and carbon emission cost of each module in the system, and is expressed as:
Figure M_221010103151861_861855001
in the formula:
Figure M_221010103152237_237832001
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_221010103152286_286128002
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_221010103152474_474147003
the input and output module refers to electric power and hydrogen energy;
Figure M_221010103152649_649964004
is a module
Figure M_221010103152705_705603005
A newly-added installation machine is needed from the last time section to the current time section;
Figure M_221010103152736_736855006
is a module
Figure M_221010103152814_814968007
Newly adding an installation machine from the last time section to the current time section;
Figure M_221010103152877_877467008
the module is put into operation from the last time section to the current time section
Figure M_221010103153089_089890009
Average unit fixed investment of (2);
Figure M_221010103153334_334504010
the module is put into operation from the last time section to the current time section
Figure M_221010103153365_365769011
Average unit capital investment of (1);
Figure M_221010103153492_492204012
is put into operation from the last time section to the current time section
Figure M_221010103153539_539586013
Average design life of (c);
Figure M_221010103153602_602095014
is put into operation from the last time section to the current time section
Figure M_221010103154200_200237015
Average design life of (c);
Figure M_221010103154262_262722016
is a module
Figure M_221010103154329_329126017
Installing the existing machine on the section at the last time;
Figure M_221010103154391_391652018
is a module
Figure M_221010103154422_422896019
An installation to be decommissioned from a previous time section to the current time section;
Figure M_221010103154454_454136020
is a module
Figure M_221010103154884_884767021
Year fixed operation and maintenance cost and fixed investment ratio
Figure M_221010103154916_916553022
Is a module
Figure M_221010103154947_947802023
The ratio of year fixed operation and maintenance cost to fixed investment;
Figure M_221010103154994_994654024
is a module
Figure M_221010103155025_025912025
In the first place
Figure M_221010103155057_057177026
Generated power in hours;
Figure M_221010103155072_072805027
is a module
Figure M_221010103155111_111362028
Average electrical fuel cost during the last time section to the present time section;
Figure M_221010103155158_158248029
is the first
Figure M_221010103155189_189489030
Input or output of electrical/hydrogen energy in hours;
Figure M_221010103155236_236356031
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_221010103155267_267629032
the annual carbon emission of the system;
Figure M_221010103155361_361356033
is the average carbon number from the last time slice to the present time slice;
in S5, the constraint condition equations comprise a system balance constraint equation, a system module constraint equation and a system design constraint equation;
in S5, the system balance constraint equation comprises a power balance node equation and a hydrogen balance node equation;
the power balance node equation is as follows:
Figure M_221010103155455_455108001
in the formula:
Figure M_221010103155587_587458001
is the other power balance node connected with the power balance node
Figure M_221010103155762_762252002
In the first place
Figure M_221010103156221_221706003
Power exchange between an hour and the power balancing node;
Figure M_221010103156343_343325004
is a power supply module connected with the power balance node
Figure M_221010103156390_390173005
In the first place
Figure M_221010103156405_405796006
Power in hours;
Figure M_221010103156437_437064007
is a power input module connected with the power balance node
Figure M_221010103156485_485380008
In the first place
Figure M_221010103156517_517135009
Hourly delivered power;
Figure M_221010103156548_548378010
is a power load module connected with the power balance node
Figure M_221010103156579_579638011
In the first place
Figure M_221010103156610_610901012
Power in hours;
Figure M_221010103156673_673373013
is a power output module connected with the power balance node
Figure M_221010103156738_738335014
In the first place
Figure M_221010103156816_816469015
Hourly delivered power;
Figure M_221010103156847_847702016
is an electricity storage module connected with the power balance node
Figure M_221010103156881_881353017
In the first place
Figure M_221010103156913_913135018
Power in hours;
Figure M_221010103156944_944374019
is an electric hydrogen production module connected with the electric power balance node
Figure M_221010103156975_975626020
In the first place
Figure M_221010103157022_022520021
Power in hours;
Figure M_221010103157038_038114022
is a hydrogen generating module connected with the power balance node
Figure M_221010103157104_104054023
In the first place
Figure M_221010103157197_197812024
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_221010103157229_229035001
in the formula:
Figure M_221010103157338_338426001
is the other hydrogen balance node connected with the hydrogen balance node
Figure M_221010103157538_538622002
In the first place
Figure M_221010103157875_875053003
Hydrogen mass exchange between hours and the hydrogen balance node;
Figure M_221010103158071_071812004
is an electric hydrogen production module connected with the hydrogen balance node
Figure M_221010103158121_121609005
In the first place
Figure M_221010103158152_152902006
Hydrogen production in hours;
Figure M_221010103158184_184135007
is a hydrogen generating module connected with the hydrogen balance node
Figure M_221010103158215_215369008
In the first place
Figure M_221010103158230_230984009
Hydrogen consumption in hours;
Figure M_221010103158262_262279010
is a hydrogen input module connected with the hydrogen balance node
Figure M_221010103158311_311571011
In the first place
Figure M_221010103158342_342841012
Hydrogen output per hour;
Figure M_221010103158374_374082013
is the hydrogen load connected to the hydrogen balance nodeModule
Figure M_221010103158405_405326014
In the first place
Figure M_221010103158436_436550015
Hydrogen usage in hours;
Figure M_221010103158467_467833016
is a hydrogen output module connected with the hydrogen balance node
Figure M_221010103158504_504455017
In the first place
Figure M_221010103158583_583043018
Hydrogen input per hour;
Figure M_221010103158787_787597019
is a hydrogen storage module connected with the hydrogen balance node
Figure M_221010103158960_960483020
In the first place
Figure M_221010103158991_991745021
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 S5, 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 power generation power constraint and renewable energy power curtailment constraint;
the generated power constraint is as follows:
Figure M_221010103159038_038597001
in the formula:
Figure M_221010103159069_069966001
non-renewable power module
Figure M_221010103159120_120162002
In the first place
Figure M_221010103159151_151444003
Hourly generated power;
Figure M_221010103159182_182655004
non-renewable power module
Figure M_221010103159213_213913005
Installed capacity of (d);
Figure M_221010103159245_245147001
in the formula:
Figure M_221010103159295_295407001
is a renewable power module
Figure M_221010103159342_342844002
In the first place
Figure M_221010103159374_374096003
Hourly generated power;
Figure M_221010103159405_405310004
is a renewable power module
Figure M_221010103159436_436565005
In the first place
Figure M_221010103159467_467842006
Electric power discard per hour;
Figure M_221010103159518_518127007
is a renewable power module
Figure M_221010103159549_549364008
Installed capacity of (d);
Figure M_221010103159596_596239009
is a renewable power module
Figure M_221010103159627_627488010
In the first place
Figure M_221010103159658_658720011
The ratio of maximum hourly output to installed capacity;
the renewable energy power abandon rate constraint is as follows:
Figure M_221010103159691_691908001
in the formula:
Figure M_221010103159754_754927001
is a renewable power module
Figure M_221010103159817_817431002
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 state of charge/energy storage constraints are:
Figure M_221010103159848_848681001
in the formula:
Figure M_221010103159912_912626001
and
Figure M_221010103159990_990782002
are respectively an electricity storage module
Figure M_221010103200272_272985003
Lower and upper limits of the state of charge/energy storage;
Figure M_221010103200291_291996004
is an electricity storage module
Figure M_221010103200343_343788005
In the first place
Figure M_221010103200375_375031006
Hourly charge/energy storage state;
the charge and discharge power constraint is as follows:
Figure M_221010103200421_421930001
in the formula:
Figure M_221010103200889_889652001
is an electricity storage module
Figure M_221010103200921_921428002
The capacity of (a);
Figure M_221010103200983_983916003
is an electricity storage module
Figure M_221010103201030_030789004
Maximum charge rate of;
Figure M_221010103201194_194393005
is an electricity storage module
Figure M_221010103201225_225635006
Maximum discharge rate of (d);
Figure M_221010103201303_303748007
is an electricity storage module
Figure M_221010103201460_460008008
The charging and discharging power of (1);
the capacity balance constraint is:
if it is
Figure M_221010103201497_497568001
，
Figure M_221010103201544_544975001
If it is
Figure M_221010103201790_790548001
，
Figure M_221010103201965_965857001
In the formula:
Figure M_221010103202126_126517001
is an electricity storage module
Figure M_221010103202173_173452002
Energy conversion efficiency of charging;
Figure M_221010103202189_189014003
is an electricity storage module
Figure M_221010103202549_549343004
Energy conversion efficiency of the discharge;
Figure M_221010103202627_627496005
is an electricity storage module
Figure M_221010103202674_674346006
A ratio of leakage to capacity per hour;
Figure M_221010103202705_705621007
is an electricity storage module
Figure M_221010103202752_752463008
Initial state of charge/energy storage;
the constraint equation of the electrical hydrogen production module comprises an operation power constraint and an energy conversion constraint;
the operating power constraint is:
Figure M_221010103202799_799363001
in the formula:
Figure M_221010103202830_830612001
is an electric hydrogen production module
Figure M_221010103202877_877474002
Installed capacity of (d);
Figure M_221010103202913_913104003
is an electric hydrogen production module
Figure M_221010103202960_960011004
The operating power of (c);
the energy conversion constraint is:
Figure M_221010103203006_006878001
in the formula:
Figure M_221010103203069_069374001
is an electric hydrogen production module
Figure M_221010103203107_107461002
Electricity consumption per unit hydrogen production;
Figure M_221010103203421_421947003
is an electric hydrogen production module
Figure M_221010103203632_632821004
The amount of energy conversion of (a);
the hydrogen power generation module constraint equation comprises an operating power constraint and an energy conversion constraint;
the operating power constraint is:
Figure M_221010103203794_794486001
in the formula:
Figure M_221010103204614_614285001
is a hydrogen power generation module
Figure M_221010103204645_645547002
Installed capacity of (a);
the energy conversion constraint is:
Figure M_221010103204676_676781001
in the formula:
Figure M_221010103204727_727096001
is a hydrogen power generation module
Figure M_221010103204773_773977002
Hydrogen consumption per unit of generated energy;
Figure M_221010103204820_820873003
is a hydrogen power generation module
Figure M_221010103204852_852099004
The amount of energy conversion of (a);
the hydrogen load module constraint equation comprises a hydrogen usage constraint;
the hydrogen usage constraint is:
Figure M_221010103204980_980519001
in the formula:
Figure M_221010103205058_058624001
is a hydrogen load module
Figure M_221010103205093_093261002
The maximum possible amount of hydrogen used per year within said time section;
Figure M_221010103205328_328617003
is a hydrogen load module
Figure M_221010103205360_360401004
Annual production/traffic within the time section;
Figure M_221010103205391_391619005
is a hydrogen load module
Figure M_221010103205438_438511006
Adopting the carbon emission factor of the prior art;
Figure M_221010103205469_469771007
is a hydrogen load module
Figure M_221010103205504_504430008
The proportion of emission reduction is realized by hydrogen substitution in the existing process carbon emission;
Figure M_221010103205535_535698009
is a hydrogen load module
Figure M_221010103205566_566914010
Carbon reduction per unit hydrogen application;
Figure M_221010103205598_598198011
；
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_221010103205676_676317001
in the formula:
Figure M_221010103205725_725621001
and
Figure M_221010103206013_013710002
are each a hydrogen storage module
Figure M_221010103206060_060585003
The lower limit and the upper limit of the hydrogen storage state of (a);
Figure M_221010103206076_076201004
is a hydrogen storage module
Figure M_221010103206125_125075005
In the first place
Figure M_221010103206156_156287006
Hydrogen storage status of hours;
the hydrogen charging and discharging rate constraint is as follows:
Figure M_221010103206203_203176001
in the formula:
Figure M_221010103206282_282720001
is a hydrogen storage module
Figure M_221010103206314_314487002
The capacity of (c);
Figure M_221010103206345_345741003
is a hydrogen storage module
Figure M_221010103206685_685061004
Maximum hydrogen charge rate of;
Figure M_221010103207054_054227005
is a hydrogen storage module
Figure M_221010103207103_103552006
The maximum hydrogen release rate;
Figure M_221010103207150_150421007
；
the capacity balance constraint is:
if it is
Figure M_221010103207291_291612001
，
Figure M_221010103207324_324272001
If it is
Figure M_221010103207449_449248001
，
Figure M_221010103207499_499047001
In the formula:
Figure M_221010103207624_624055001
is a hydrogen storage module
Figure M_221010103207670_670951002
The efficiency of the charging process;
Figure M_221010103207709_709508003
is a hydrogen storage module
Figure M_221010103207756_756416004
The efficiency of the hydrogen discharge process;
Figure M_221010103207787_787636005
is a hydrogen storage module
Figure M_221010103207834_834514006
The ratio of hydrogen leakage to capacity per hour;
Figure M_221010103207865_865763007
is a hydrogen storage module
Figure M_221010103208025_025424008
The initial hydrogen storage state of (a);
in S5, the system design constraint equation comprises system carbon emission constraints, upper and lower limit constraints of installed capacity of a power supply module, upper and lower limit constraints of annual input electric quantity of a power input module, upper and lower limit constraints of annual output electric quantity of a power output module, upper and lower limit constraints of capacity of an electricity storage module, upper and lower limit constraints of installed capacity of an electrical hydrogen production module, upper and lower limit constraints of installed capacity of a hydrogen generation module, upper and lower limit constraints of annual input hydrogen quantity of a hydrogen input module, upper and lower limit constraints of annual hydrogen quantity of a hydrogen load module, upper and lower limit constraints of annual output hydrogen quantity of a hydrogen output module, and upper and lower limit constraints of capacity of a hydrogen storage module;
wherein the system carbon emission constraints are:
Figure M_221010103208096_096680001
in the formula:
Figure M_221010103208315_315969001
is a power supply module
Figure M_221010103208331_331611002
Carbon emission factor of (a);
Figure M_221010103208362_362837003
is a power input module
Figure M_221010103208394_394085004
Carbon emission factor of (a);
Figure M_221010103208425_425322005
is a power output module
Figure M_221010103208456_456568006
The carbon emission factor of (c);
Figure M_221010103208472_472211007
is a hydrogen input module
Figure M_221010103208510_510778008
Carbon emission factor of (a);
Figure M_221010103208526_526416009
is a hydrogen output module
Figure M_221010103208557_557669010
Carbon emission factor of (a);
Figure M_221010103208588_588892011
is the upper carbon emission limit of the regional electro-hydrogen system at the time section;
Figure M_221010103208635_635783012
efficiency;
Figure M_221010103208699_699727013
is a power input module
Figure M_221010103208730_730981014
Carbon emission efficiency of;
Figure M_221010103208793_793482015
is a power output module
Figure M_221010103208824_824768016
Carbon emission efficiency of;
Figure M_221010103208871_871629017
is a hydrogen input module
Figure M_221010103208904_904320018
Carbon emission efficiency of;
Figure M_221010103208919_919963019
is a hydrogen output module
Figure M_221010103208951_951202020
Carbon emission efficiency of;
Figure M_221010103208982_982467021
is a hydrogen load module
Figure M_221010103209013_013695022
Annual production/traffic in time section;
Figure M_221010103209029_029332023
is a hydrogen load module
Figure M_221010103209060_060589024
Adopting the carbon emission factor of the prior art;
Figure M_221010103209093_093752025
is a hydrogen load module
Figure M_221010103209125_125526026
The proportion of emission reduction can be realized by replacing hydrogen in the carbon emission in the prior art;
Figure M_221010103209172_172400027
is a hydrogen load module
Figure M_221010103209203_203639028
The amount of carbon reduction per unit of hydrogen application.
2. The regional electric hydrogen system decarburization path planning optimization method according to 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 optimization method according to claim 2, wherein in 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 the power balance units (3) are connected with each other in a bidirectional or unidirectional manner; 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 and hydrogen system decarburization path planning optimization method of claim 1, wherein in S2, the planning period spans a plurality of consecutive natural years, a single time section is a natural year in the planning period, and the time sections are one or more.
5. The method for optimizing a regional electro-hydrogen system decarburization path planning 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 optimization method according to claim 5, wherein the real type variables include installed capacity of each power 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 electric hydrogen production module, installed capacity of each hydrogen generation module, annual input hydrogen of each hydrogen input module, annual hydrogen usage of each hydrogen load module, annual output hydrogen of each hydrogen output module, and capacity of each hydrogen storage module for 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 electro-hydrogen system decarburization path planning and optimizing method according to claim 1, wherein in S6, the configuration optimization algorithm selects a linprog solver in MATLAB according to the optimization objective function and the constraint condition equation.
8. The regional electric hydrogen system decarburization path planning optimization method according to 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, electric 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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