CN112943452A - Total process NO for controlling gas turbine unit to operate on gas turbine sideXSystem for discharging - Google Patents
Total process NO for controlling gas turbine unit to operate on gas turbine sideXSystem for discharging Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 44
- 230000008569 process Effects 0.000 title claims abstract description 38
- 238000007599 discharging Methods 0.000 title claims abstract description 10
- 239000007789 gas Substances 0.000 claims abstract description 116
- 239000000446 fuel Substances 0.000 claims abstract description 69
- 238000007405 data analysis Methods 0.000 claims abstract description 42
- MWUXSHHQAYIFBG-UHFFFAOYSA-N Nitric oxide Chemical compound O=[N] MWUXSHHQAYIFBG-UHFFFAOYSA-N 0.000 claims abstract description 39
- 239000003546 flue gas Substances 0.000 claims abstract description 32
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims abstract description 28
- 238000005507 spraying Methods 0.000 claims abstract description 18
- 239000000779 smoke Substances 0.000 claims abstract description 16
- 238000002156 mixing Methods 0.000 claims abstract description 13
- 238000010977 unit operation Methods 0.000 claims abstract description 13
- 238000012544 monitoring process Methods 0.000 claims abstract description 7
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 64
- 238000002485 combustion reaction Methods 0.000 claims description 44
- 239000003570 air Substances 0.000 claims description 40
- 229910052757 nitrogen Inorganic materials 0.000 claims description 32
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 20
- 238000009792 diffusion process Methods 0.000 claims description 15
- 230000009467 reduction Effects 0.000 claims description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 12
- 239000003345 natural gas Substances 0.000 claims description 10
- 239000000523 sample Substances 0.000 claims description 9
- 238000005070 sampling Methods 0.000 claims description 9
- 238000012545 processing Methods 0.000 claims description 7
- 239000007921 spray Substances 0.000 claims description 7
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 6
- 239000002918 waste heat Substances 0.000 claims description 6
- 239000012080 ambient air Substances 0.000 claims description 4
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 3
- 239000001569 carbon dioxide Substances 0.000 claims description 3
- 230000009466 transformation Effects 0.000 claims description 3
- 230000000116 mitigating effect Effects 0.000 abstract 1
- JCXJVPUVTGWSNB-UHFFFAOYSA-N nitrogen dioxide Inorganic materials O=[N]=O JCXJVPUVTGWSNB-UHFFFAOYSA-N 0.000 description 14
- 230000001276 controlling effect Effects 0.000 description 11
- 229910002089 NOx Inorganic materials 0.000 description 8
- MGWGWNFMUOTEHG-UHFFFAOYSA-N 4-(3,5-dimethylphenyl)-1,3-thiazol-2-amine Chemical compound CC1=CC(C)=CC(C=2N=C(N)SC=2)=C1 MGWGWNFMUOTEHG-UHFFFAOYSA-N 0.000 description 3
- 238000006243 chemical reaction Methods 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- 238000013022 venting Methods 0.000 description 3
- 239000003344 environmental pollutant Substances 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 231100000719 pollutant Toxicity 0.000 description 2
- 238000011160 research Methods 0.000 description 2
- RZCJYMOBWVJQGV-UHFFFAOYSA-N 2-naphthyloxyacetic acid Chemical compound C1=CC=CC2=CC(OCC(=O)O)=CC=C21 RZCJYMOBWVJQGV-UHFFFAOYSA-N 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000012937 correction Methods 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000009533 lab test Methods 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- RJIWZDNTCBHXAL-UHFFFAOYSA-N nitroxoline Chemical compound C1=CN=C2C(O)=CC=C([N+]([O-])=O)C2=C1 RJIWZDNTCBHXAL-UHFFFAOYSA-N 0.000 description 1
- 231100001143 noxa Toxicity 0.000 description 1
- 238000010248 power generation Methods 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 238000012827 research and development Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
- 238000012360 testing method Methods 0.000 description 1
Images
Classifications
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
- F02C3/22—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products the fuel or oxidant being gaseous at standard temperature and pressure
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
- F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
- F02C3/30—Adding water, steam or other fluids for influencing combustion, e.g. to obtain cleaner exhaust gases
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
- F02C6/18—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
- F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
- F02C9/00—Controlling gas-turbine plants; Controlling fuel supply in air- breathing jet-propulsion plants
- F02C9/48—Control of fuel supply conjointly with another control of the plant
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- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Engine Equipment That Uses Special Cycles (AREA)
Abstract
The invention relates to a gas turbine side control gas unit operation overall process NOXThe system for discharging mainly comprises a flue gas analyzer, a data analysis control module, a plant-level monitoring system of a power plant, a gas turbine operation control unit, a fuel component mixing and heat value adjusting device and a gas compressor inlet gas spraying unit. The whole system can control parameters such as air-fuel ratio, fuel components, air temperature and humidity and the like of the gas turbine based on the nitrogen oxide emission rule of the gas turbine at different load stages so as to reduce NO of the unit in the whole operation processXEmission concentration and mitigation unit "Yellow smoke is emitted.
Description
Technical Field
The invention relates to the field of chemical industry, in particular to a gas turbine side control gas turbine set operation overall process NOXA system for venting.
Background
At present, most of domestic heavy-duty gas-steam combined cycle units generally have the problem of yellow smoke emission under the working conditions of starting and low load. For a gas and steam combined cycle unit mainly starting and stopping day and night and regulating peak, how to scientifically and reasonably solve the problem of yellow smoke still remains a technical problem troubling a gas turbine power plant at present. It can be seen by monitoring that yellow smoke is caused by NO in the smoke2The increase in the content results in, as shown in Table 1, the start-up phase, NO2The proportion of the total nitrogen is up to 95 percent, and the emission concentration of CO is up to 2800 ppm.
TABLE 1 relationship between pollutant emission and unit load for certain type of gas turbine
The relevant emission data of the start-up stage of 3 times is obtained through the pollutant emission test in the chimney of the waste heat boiler on the site of a certain gas turbine set, as shown in fig. 2. At 30% and 50% of the load in the starting stage, the proportion of the nitrogen dioxide in the total nitrogen can reach 75% at most; when the normal load of 80% -100% is reached, the proportion of nitrogen dioxide in the total nitrogen is reduced to stable 20% -30%. Meanwhile, other host manufacturers and models also have similar emission laws in the starting stage.
Meanwhile, NO is converted into NO under certain conditions2The phenomenon of yellow smoke is aggravated by transformation. NOXIn NO and NO2The ratio is influenced by various factors, e.g. CO concentration, H2The O concentration, the residence time in the waste heat boiler, the starting process of the combustion engine and the like.
According to the results of laboratory experiments and numerical simulation calculation, if CO exists in the flue gas, NO is converted into NO2The chance of conversion is greater as shown in figure 3.
Meanwhile, according to related research, the final NO of the gas power plant is shownXThe discharge is related to unit load, combustion mode, environment temperature and humidity and natural gas heat value, taking a certain power plant 9FA unit as an example, the opening degree of a D5 fuel nozzle and the atmospheric humidity to NOXThe effect is shown in the following table:
TABLE 2 variation of NOx in a gas turbine power plant with Fuel calorific value
Set NO as shown in Table 2XEmissions decrease with decreasing fuel calorific value, and thus to reduce NOXThe unit can control the heat value of the fuel.
Therefore, in order to comprehensively research the nitrogen oxide emission problem in the whole operation process of the gas power plant, monitor and control the nitrogen oxide emission and inhibit the phenomenon of yellow smoke emission in the power plant, research and development of NO in the whole operation process of the gas turbine side control gas turbine unit are urgently neededXAn apparatus and method for draining.
Disclosure of Invention
The present invention is directed to the above-mentioned deficiencies of the prior art and providesProvides a gas turbine side control gas turbine unit operation overall process NOXThe system for discharging is realized by the following technical scheme:
the side of the gas engine controls the whole process NO of the operation of the gas unitXA system for venting, comprising:
a water-cooled flue gas sampling probe is adopted in a flue gas analyzer, the probe is placed in a flue gas flow passage of a waste heat boiler during flue gas sampling, a sampling hole is opposite to the incoming flow direction of the flue gas, and an electrochemical sensor of the flue gas analyzer analyzes O in the flue gas2、CO、H 20. NO and NO2Content (c);
a fuel component mixing and calorific value adjusting device for adjusting the calorific value of the fuel entering the combustion engine by mixing a controllable non-combustible component into the natural gas;
the air compressor air inlet spraying unit is used for increasing the humidity of air entering the gas turbine and reducing the front temperature of a combustion turbine in the gas turbine by spraying and isenthalpic humidification on the air;
the data analysis control module controls the water spraying amount of the spraying system to control NO in the flue gas2And NH3The discharge amount of (c); and according to NO collected by the probe of the flue gas analyzer2And NH3The concentration of the water is analyzed and processed through data, and a control instruction is sent out;
the power plant level monitoring system acquires the operation data of the unit in real time and transmits the operation data to the data analysis control module in real time;
and the gas turbine operation control unit receives the control instruction and controls corresponding parameters of the gas turbine, the gas compressor air inlet spraying unit and the fuel component mixing and heat value adjusting device according to the control instruction.
The side of the gas engine controls the whole process NO of the operation of the gas unitXThe system for emission is further designed in such a way that the logical process of data analysis and processing in the data analysis control module is specifically as follows:
in the starting or stopping stage or the low-load stage of the combustion engine, the data analysis control module controls the combustion engine operation control unit to increase the air-fuel ratio A% of the diffusion combustion mode every time, and when the air-fuel ratio reaches the safety critical range of the unit, the operation is stopped; then, controlling the combustion engine to enter a premixed combustion mode from a diffusion combustion mode;
when the combustion engine reaches the normal load stage, the data analysis control module controls the air-fuel ratio by adjusting the proportion of air and natural gas of the diffusion and premixing fuel nozzle; meanwhile, the heat value of the fuel is controlled by adjusting the proportion of non-combustible components in the fuel, and the amount of water sprayed and humidified in front of the air compressor is used for realizing the nitrogen reduction operation.
The system for controlling the NOx emission in the whole process of the operation of the gas turbine set by the gas turbine side is further designed in the way that A belongs to [0.5, 1.5 ].
The side of the gas engine controls the whole process NO of the operation of the gas unitXThe system for discharging is further designed in that in the logic process of data analysis and processing in the data analysis control module, when the load of the combustion engine is less than or equal to 50% of the basic load, the combustion engine is judged to be in a starting or stopping stage or a low-load stage; otherwise, it is in the normal load stage.
The system for controlling the overall process NOx emission of the gas turbine unit by the fuel side is further designed in such a way that the noncombustible component comprises carbon dioxide.
The system for controlling the overall process NOx emission of the gas turbine set to operate at the side of the gas turbine is further designed in such a way that the nitrogen reduction operation aims at two nitrogen oxide emission standards, and the control logic of the data analysis control module specifically comprises the following steps:
the total nitrogen concentration is required to be less than or equal to 50mg/m3The data analysis control module sends a nitrogen reduction instruction to the gas turbine operation control unit to control the gas turbine operation control unit to spray before the gas compressor, and calculates the amount of water required to be sprayed and humidified when the relative humidity of the air is increased by 10% each time on the existing basis under the condition of isenthalpic humidification according to the relative humidity of ambient air, the air temperature and the flow rate of the gas compressor until the relative humidity is increased to 90% or the total nitrogen emission meets the current standard;
the total nitrogen concentration is required to be less than or equal to 30mg/m3The data analysis control module sends the nitrogen reduction instruction to the gas turbine operation control unit, and controls the gas turbine operation control unit to repeat the operation until the relative humidity is increased to 90% or the total nitrogen emission meets the current standard, and if the relative humidity is not increased, the total nitrogen emission meets the current standardWhen the method realizes that the current nitrogen oxide reaches the standard and is discharged, the data analysis control module controls the fuel calorific value to be adjusted through the gas turbine operation control device, and the lower calorific value of the fuel is reduced within the Wobbe index fluctuation range of-5% by adding the non-combustible components with set weight into the fuel until the total nitrogen discharge meets the current standard.
The system for controlling the overall process NOx emission of the gas unit to operate by the gas engine is further designed in such a way that if the NOx emission can not reach the standard, the gas unit is upgraded and modified by additionally installing an SCR denitration system or upgrading and modifying a combustion system of the gas engine.
The system for controlling the NOx emission in the whole process of the operation of the gas unit by the gas engine side is further designed in such a way that the set amount meets the increase amount each time, so that the heat value of the fuel can be reduced by 1%.
The system for controlling the NOx emission in the whole process of the operation of the gas turbine unit by the fuel side is further designed in that the operation data comprises the operation load of the unit, the premixed fuel ratio, the diffusion fuel ratio, the ambient temperature and humidity and the natural gas fuel calorific value.
The system for controlling the whole process NOX emission of the gas turbine set in the operation process at the side of the gas turbine is further designed in a way that a Testo350 flue gas analyzer is adopted as the flue gas analyzer.
The invention has the following advantages:
the invention discloses a gas turbine side control gas unit operation overall process NOXThe system for discharging nitrogen oxides can control parameters such as air-fuel ratio, fuel components, air temperature and humidity of the gas turbine based on the nitrogen oxide discharge law of the gas turbine at different load stages so as to reduce NO of the unit in the whole operation processXThe concentration is discharged and the phenomenon of yellow smoke emission of the unit is relieved.
Drawings
FIG. 1 shows the overall process NO of the gas turbine side control gas turbine unit operation of the inventionXA block schematic of a system for venting. Wherein, A: gas turbine, B: plant-level monitoring system of power plant, C: fuel component mixing and calorific value adjusting device, D: compressor intake air spray unit, E: combustion engine operation control unit, F: exhaust-heat boiler, G: data analysis controlModule, H: flue gas analyzer.
FIG. 2 is a schematic illustration of a certain class 9F gas-steam combined cycle nitrogen dioxide to total nitrogen ratio.
FIG. 3 is a graphical representation of NO conversion as a function of temperature for experiments without CO.
FIG. 4 is a logic diagram of the data analysis control module during a start-up or shut-down phase or a low load phase of the combustion engine.
FIG. 5 is a logic diagram of the data analysis control module during the normal load phase.
Detailed Description
The technical scheme of the invention is further explained by combining the attached drawings.
Referring to fig. 1, the system for controlling NOX emission in the whole process of the operation of the gas turbine unit on the side of the combustion engine of the embodiment mainly comprises: the system comprises a flue gas analyzer, a fuel component mixing and heat value adjusting device, a gas compressor air inlet spraying unit, a data analysis control module, a power plant level monitoring system and a gas turbine operation control unit.
The flue gas analyzer adopts a water-cooled flue gas sampling probe, the probe is placed in a flue gas flow channel of the waste heat boiler during flue gas sampling, a sampling hole is opposite to the flue gas inflow direction, and an electrochemical sensor of the flue gas analyzer analyzes the contents of O2, CO, H20, NO and NO2 in flue gas.
The fuel component mixing and heating value adjusting apparatus of the present embodiment adjusts the heating value of the fuel to be fed to the combustion engine by mixing a controllable non-combustible component into the natural gas. The air compressor air inlet spraying unit increases the humidity of air entering the gas turbine and reduces the front temperature of a combustion turbine in the gas turbine by spraying and isenthalpic humidification of the air.
The data analysis control module of the embodiment controls the water spraying amount of the spraying system to control the discharge amount of NO2 and NH3 in the flue gas; and a control command is sent out through data analysis and processing according to the concentrations of NO2 and NH3 collected by a probe of the smoke analyzer.
The plant-level monitoring system of the power plant of the embodiment collects the operation data of the unit in real time and transmits the operation data to the data analysis control module in real time. And the gas turbine operation control unit receives the control instruction and controls corresponding parameters of the gas turbine, the gas compressor air inlet spraying unit and the fuel component mixing and heat value adjusting device according to the control instruction. The operation data of the embodiment includes the operation load of the unit, the premixed fuel ratio, the diffusion fuel ratio, the ambient temperature and humidity, the natural gas fuel calorific value and other numerical values.
The logical process of data analysis and processing in the data analysis control module of this embodiment is specifically:
referring to fig. 4, during the start-up or shutdown phase or low load phase of the internal combustion engine, the unit generates the phenomenon of yellow smoke (NO) due to the adoption of the diffusion combustion mode2Concentration is more than or equal to 15ppm), the data analysis control module controls the gas turbine operation control unit to improve the air-fuel ratio of the diffusion combustion mode by 1% every time, CO generation is reduced by increasing air, and NO in the waste heat boiler is further reduced to NO2Conversion rate, and yellow smoke phenomenon alleviation. However, due to the fact that flame temperature stability needs to be kept to avoid flameout in the starting stage of the gas turbine body, the air-fuel ratio of the unit cannot be increased without limit (the air-fuel ratio of the diffusion combustion mode is increased by 1% every time), and when the air-fuel ratio reaches the safety critical range of the unit, the operation is stopped; and then, controlling the internal combustion engine to enter a premixed combustion mode from the diffusion combustion mode, and reducing the running time of the diffusion combustion mode in the starting or stopping or low-load stage so as to reduce the occurrence time of the phenomenon of yellow smoke.
Referring to FIG. 5, when the engine reaches the normal load phase, the data analysis control module controls the air-fuel ratio by adjusting the ratio of air and natural gas from the diffusion and premixing fuel nozzles; meanwhile, the heat value of the fuel is controlled by adjusting the proportion of non-combustible components in the fuel, and the amount of water sprayed and humidified in front of the air compressor is used for realizing the nitrogen reduction operation.
In the logic process of data analysis and processing in the data analysis control module, when the load of the combustion engine is less than or equal to 50% of the basic load, the combustion engine is judged to be in a starting or stopping stage or a low-load stage; otherwise (i.e. engine load > 50% Base load), it is in the normal load phase.
The nitrogen reduction operation mentioned in this embodiment, for two nitrogen oxide emission standards, the data analysis control module control logic specifically includes:
first nitrogen oxide emission standard: the total nitrogen concentration is required to be less than or equal to 50mg/m3Currently, the gas turbine power generation technology can basically realize NO under normal load (more than 50% Base load) basicallyXThe emission reaches the standard, but is influenced by factors such as external environment change and the like, such as environment temperature rise and sometimes unit NOXThe discharge will slightly exceed 50mg/m3(Up to 60mg/m is possible)3). The data analysis control module sends an instruction to the gas turbine operation control system, and the gas turbine operation control system sprays the front of the gas compressor to reduce nitrogen. The data analysis control module sends a nitrogen reduction instruction to the gas turbine operation control unit, controls the gas turbine operation control unit to spray before the gas compressor, and calculates the amount of water required to be sprayed and humidified when the relative humidity of the air is increased by 10% each time on the existing basis under the condition of isenthalpic humidification according to the relative humidity of ambient air, the air temperature and the flow rate of the gas compressor until the relative humidity is increased to 90% or the total nitrogen emission meets the current standard;
second nitrogen oxide emission standard: the total nitrogen concentration is required to be less than or equal to 30mg/m3Firstly, the data analysis control module sends an instruction to the gas turbine operation control system, and the gas turbine operation control system sprays the front of the gas compressor to reduce nitrogen and improve air humidity. According to the relative humidity of the ambient air, the air temperature and the flow rate of the compressor, the spraying amount required to be carried out on the basis of the prior art when the relative humidity of the air is increased by 10% each time (until the relative humidity is increased to 90%) under the condition of isenthalpic humidification can be calculated. For example, the relative humidity of the existing air is 30%, the temperature is 30 ℃, and the moisture content is 7.92 g/kg: the air flow rate of the air compressor is 100 kg/s; then in the case of first isenthalpic humidification: when the relative humidity of air is changed to 40%, the temperature is changed to 27.25 ℃ according to an enthalpy-humidity diagram, and the moisture content is changed to 9.02g/kg, the amount of water needing spray humidification is 100 (9.02-7.92) g/s-110 g/s. If the total nitrogen emission still exceeds the standard in the first isenthalpic humidification, the humidification quantity required when the humidification is carried out to the relative humidity of 50% is continuously calculated on the basis, the air compressor is sprayed by the gas turbine operation control system, and the humidification is carried out to the condition of 60% -90%, and the like.
Then, if the nitrogen oxide emission reaching the standard (less than or equal to 30 mg/m) can not be realized3) The data analysis control module controls the adjustment of the fuel heat value through the combustion engine operation control system, and reduces the lower heat value of the fuel by adding a proper amount of non-combustible components (such as carbon dioxide) into the fuel, but the mode is limited within a certain range by the lower heat value of the unit fuel, otherwise, the fluctuation of the Wobbe index MWI (see the following formula) is beyond the range of +/-5%, and the unit generates vibration failure beyond the range.
Wherein MWI is the Wobbe index after temperature correction; LHV is fuel low-level calorific value, Btu/scft; t isgIs the gas absolute temperature, Rankine temperature scale, ° R; SG is the specific gravity of fuel relative to air under ISO condition;
the fluctuation range of the Wobbe index caused by adding pure non-combustible components in the fuel (the calorific value of the fuel can be reduced by 1 percent by adding the pure non-combustible components in each time) is generally recommended to be safe when the fluctuation range of the Wobbe index is within-5 percent. Meanwhile, because components which are not blended in the fuel are easy to cause the problem of combustion flameout of a unit due to uneven blending, the method is used for reaching the emission standard (less than or equal to 30 mg/m)3) Alternative methods of (1).
Finally, if the above two schemes cannot achieve the emission meeting the standard, the upgrading and the modification of the gas turbine set (for example, the exhaust-heat boiler is additionally provided with an SCR denitration system or a combustion system of the gas turbine is upgraded and modified) must be considered.
The smoke analyzer in this embodiment is a Testo350 smoke analyzer.
The above description is only for the preferred embodiment of the present invention, but the scope of the present invention is not limited thereto, and any changes or substitutions that can be easily conceived by those skilled in the art within the technical scope of the present invention are included in the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.
Claims (10)
1. Total process NO for controlling gas turbine unit to operate on gas turbine sideXA system for discharging, characterized by comprising:
a water-cooled flue gas sampling probe is adopted in a flue gas analyzer, the probe is placed in a flue gas flow passage of a waste heat boiler during flue gas sampling, a sampling hole is opposite to the incoming flow direction of the flue gas, and an electrochemical sensor of the flue gas analyzer analyzes O in the flue gas2、CO、H20. NO and NO2Content (c);
a fuel component mixing and calorific value adjusting device for adjusting the calorific value of the fuel entering the combustion engine by mixing a controllable non-combustible component into the natural gas;
the air compressor air inlet spraying unit is used for increasing the humidity of air entering the gas turbine and reducing the front temperature of a combustion turbine in the gas turbine by spraying and isenthalpic humidification on the air;
the data analysis control module controls the water spraying amount of the spraying system to control NO in the flue gas2And NH3The discharge amount of (c); and according to NO collected by the probe of the flue gas analyzer2And NH3The concentration of the water is analyzed and processed through data, and a control instruction is sent out;
the power plant level monitoring system acquires the operation data of the unit in real time and transmits the operation data to the data analysis control module in real time;
and the gas turbine operation control unit receives the control instruction and controls corresponding parameters of the gas turbine, the gas compressor air inlet spraying unit and the fuel component mixing and heat value adjusting device according to the control instruction.
2. Gas turbine side control gas unit operation overall process NO according to claim 1XThe system for discharging is characterized in that the logical process of data analysis and processing in the data analysis control module is as follows:
in the starting or stopping stage or the low-load stage of the combustion engine, the data analysis control module controls the combustion engine operation control unit to increase the air-fuel ratio A% of the diffusion combustion mode every time, and when the air-fuel ratio reaches the safety critical range of the unit, the operation is stopped; then, controlling the combustion engine to enter a premixed combustion mode from a diffusion combustion mode;
when the combustion engine reaches the normal load stage, the data analysis control module controls the air-fuel ratio by adjusting the proportion of air and natural gas of the diffusion and premixing fuel nozzle; meanwhile, the heat value of the fuel is controlled by adjusting the proportion of non-combustible components in the fuel, and the amount of water sprayed and humidified in front of the air compressor is used for realizing the nitrogen reduction operation.
3. Gas turbine side control gas unit operation overall process NO according to claim 2XThe system of discharge is characterized in that A is 0.5, 1.5]。
4. Gas turbine side control gas unit operation overall process NO according to claim 2XThe system for discharging is characterized in that in the logic process of data analysis and processing in the data analysis control module, when the load of the combustion engine is less than or equal to 50% of the basic load, the combustion engine is judged to be in a starting or stopping stage or a low-load stage; otherwise, it is in the normal load stage.
5. Gas turbine side control gas unit operation overall process NO according to claim 2XA system for emission, characterized in that said non-combustible component comprises carbon dioxide.
6. Gas turbine side control gas unit operation overall process NO according to claim 2XThe system for emission is characterized in that the nitrogen reduction operation is performed by aiming at two nitrogen oxide emission standards, and the data analysis control module comprises control logic specifically as follows:
the total nitrogen concentration is required to be less than or equal to 50mg/m3The data analysis control module sends a nitrogen reduction instruction to the gas turbine operation control unit to control the gas turbine operation control unit to spray before the gas compressor, and calculates the amount of water required to be sprayed and humidified when the relative humidity of the air is increased by 10% each time on the existing basis under the condition of isenthalpic humidification according to the relative humidity of ambient air, the air temperature and the flow rate of the gas compressor until the relative humidity is increased to 90% or the total nitrogen emission meets the current standard;
the total nitrogen concentration is required to be less than or equal to 30mg/m3The data analysis control module sends the nitrogen reduction instruction to the engine operation control unit, controls the engine operation control unit to repeat the operation until the relative humidity is increased to 90% or the total nitrogen emission meets the current standard, controls the fuel heat value to be adjusted through the engine operation control device if the current nitrogen oxide emission can not meet the standard, and reduces the fuel low heat value within the fluctuation range of the Wobbe index of-5% by adding the non-combustible components with the set amount into the fuel until the total nitrogen emission meets the current standard.
7. Gas turbine side control gas unit operation overall process NO according to claim 6XThe system of emission, if can't realize discharge up to standard, then contain exhaust-heat boiler and install SCR deNOx systems additional or carry out the upgrading transformation of upgrading transformation to the combustion system of fuel machine to the gas module.
8. Gas turbine side control gas unit operation overall process NO according to claim 6XA system for emissions characterized in that said set portion satisfies the fuel calorific value reduction by 1% for each increment.
9. Gas turbine side control gas unit operation overall process NO according to claim 1XThe system for discharging is characterized in that the operation data comprises the operation load of the unit, the premixed fuel ratio, the diffusion fuel ratio, the ambient temperature and humidity and the natural gas fuel heat value.
10. Gas turbine side control gas unit operation overall process NO according to claim 1XThe system for emission is characterized in that the smoke analyzer adopts a Testo350 smoke analyzer.
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