CN211038839U - Regulating system for fuel gas inlet of gas turbine - Google Patents
Regulating system for fuel gas inlet of gas turbine Download PDFInfo
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- CN211038839U CN211038839U CN201922120016.7U CN201922120016U CN211038839U CN 211038839 U CN211038839 U CN 211038839U CN 201922120016 U CN201922120016 U CN 201922120016U CN 211038839 U CN211038839 U CN 211038839U
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Abstract
The utility model provides a regulating system for gas turbine fuel gas admits air, natural gas injection pipeline, synthetic gas heater, main synthetic gas counter-current valve, Laval spray tube, synthetic gas diffuse pipeline, main synthetic gas regulating valve and nozzle have set gradually on the main synthetic gas pipeline from its upper reaches to low reaches; the outlet of the steam injection pipeline is divided into two branches, and one branch is connected with the steam inlet of the synthesis gas heater; the other branch is connected with a steam inlet of the Laval nozzle; meanwhile, the natural gas injection pipeline, the synthesis gas diffusion pipeline and the steam injection pipeline are all provided with flow control devices for realizing flow control; the utility model provides a traditional IGCC because the regulation rate of gasifier gas production is slower, the requirement that the whole power generation load change rate of power plant hardly reaches the flexibility peak regulation, when leading to the extensive grid-connected of unstable renewable energy such as wind-powered electricity generation, traditional IGCC can not satisfy its technological requirement's defect.
Description
Technical Field
The utility model relates to an integrated gasification combined cycle power generation technical field, in particular to an governing system that is used for gas turbine fuel gas to admit air.
Background
Integrated Gasification Combined Cycle (IGCC) power generation is a clean and efficient coal-based power generation technology, in which coal is first converted into syngas by a gasification furnace, and the syngas is purified by desulfurization or the like and then used as fuel for a gas turbine to perform gas-steam combined cycle power generation. Unlike conventional natural gas-fired gas-steam combined cycle power generation, integrated coal gasification combined cycle power generation employs a gas turbine that is capable of handling low calorific value syngas with a high hydrogen content. This is because the composition and combustion characteristics of the syngas produced by the gasifier in the IGCC system are very different from natural gas. Combination of Chinese herbsThe main effective components in the formed gas are CO and H2And also contains a small amount of CH4、C2H6Etc. and N2、CO2And the like, which are non-combustible gas components, have a lower calorific value than natural gas, and are hydrogen-rich gas due to a higher hydrogen content. Compared with the main component of CH4The combustion flame propagation speed of the natural gas and the synthesis gas is higher, and in order to prevent the occurrence of backfire, the design of a burner of a gas turbine cannot adopt the mode of reducing NOxThe generated premixed combustion mode adopts a non-premixed combustion design. The non-premixed combustion method imposes a limit on the heating value of the fuel gas in order to prevent local excessive high temperature due to non-uniform combustion mixing. The calorific value of the syngas produced by the gasifier is usually higher than the requirement of the burner, and therefore, before the syngas is fed to the burner of the gas turbine, the calorific value of the syngas needs to be adjusted to a required range by a calorific value adjusting system.
In recent years, due to the large-scale grid connection of unstable renewable energy sources such as wind power and the like, the requirement of a power grid on the flexibility peak regulation of traditional power sources such as thermal power and the like is higher and higher, the regulation rate of the gas production of a gasification furnace of the traditional IGCC is lower, the change rate of the integral power generation load of a power plant is difficult to meet the requirement of the flexibility peak regulation, and particularly when the load needs to be quickly increased, the gas production of the gasification furnace cannot be increased to keep up with the increase of the gas production, so that the load. And a certain amount of natural gas is injected into the synthesis gas, so that the power generation load flexibility is improved, and the method is an important means for improving the peak regulation capacity of the IGCC. The utility model provides a take calorific value regulatory function's synthetic gas turbine fuel gas air intake system and calorific value regulatory method can inject the synthetic gas as the supplementary of quick load regulation with the natural gas to the calorific value of the synthetic gas that accurate control got into gas turbine, and the flexibility that improves the combined cycle electricity generation.
Disclosure of Invention
An object of the utility model is to provide a governing system for gas turbine fuel gas admits air has solved traditional IGCC because the governing rate of gasifier gas production is slower, and the requirement of flexibility peak shaving is hardly reached to the whole power generation load variation rate of power plant, when leading to the extensive grid-connected of unstable renewable energy such as wind-powered electricity generation, traditional IGCC can not satisfy its technological requirement's defect.
In order to achieve the above purpose, the utility model discloses a technical scheme is:
the utility model provides a governing system for gas turbine fuel gas admits air, including natural gas injection pipeline, main synthetic gas pipeline and steam injection pipeline, wherein, natural gas injection pipeline, synthetic gas heater, main synthetic gas counter-current valve, Laval spray tube, synthetic gas diffuse pipeline, main synthetic gas regulating valve and nozzle have set gradually on the main synthetic gas pipeline from its upper reaches to low reaches;
the outlet of the steam injection pipeline is divided into two branches, and one branch is connected with the steam inlet of the synthesis gas heater; the other branch is connected with a steam inlet of the Laval nozzle;
meanwhile, the natural gas injection pipeline, the synthesis gas diffusion pipeline and the steam injection pipeline are all provided with flow control devices for realizing flow control.
Preferably, a natural gas reflux valve, a natural gas stop valve and a natural gas regulating valve are arranged in sequence from the upstream to the downstream of the natural gas injection pipeline.
Preferably, the natural gas flow control device on the natural gas injection pipeline comprises a natural gas regulating valve, a natural gas injection regulating controller and a synthetic gas pressure measuring point, wherein the synthetic gas pressure measuring point is arranged on the main synthetic gas pipeline and is arranged at the upstream of the main synthetic gas regulating valve, the synthetic gas pressure measuring point is used for collecting the synthetic gas pressure injected into the nozzle of the gas turbine and transmitting the collected pressure to the natural gas injection regulating controller, and the natural gas injection regulating controller is used for comparing the received pressure with a preset threshold value and controlling the opening of the natural gas regulating valve according to the comparison result.
Preferably, a heating steam flow control device is arranged on a connecting pipeline between one branch of the steam injection pipeline and a steam inlet of the synthesis gas heater, the heating steam flow control device comprises a heating steam regulating valve, a heating steam controller and a temperature measuring point arranged on a main synthesis gas pipeline, the temperature measuring point is arranged at the downstream of the synthesis gas heater and used for collecting a temperature value of a synthesis gas outlet of the synthesis gas heater and transmitting the collected temperature value to the heating steam controller, and the heating steam controller is used for comparing the received temperature value with a preset threshold value so as to control the opening degree of the heating steam regulating valve.
Preferably, a steam flow control device is arranged on a connecting pipeline between the other branch of the steam injection pipeline and a steam inlet of the Laval nozzle, and comprises a steam regulating valve, a flow regulating valve, a heat value regulating controller, a synthetic gas flow measuring point, a synthetic gas component measuring point and a combustible gas component measuring point, wherein the synthetic gas flow measuring point, the synthetic gas component measuring point and the combustible gas component measuring point are all arranged on the main synthetic gas pipeline; the flow measuring points of the synthetic gas and the measuring points of the synthetic gas components are both arranged at the inlet of the synthetic gas heater and are used for collecting the flow of combustible gas and the volume fraction of the gas components and transmitting the collected data to the heat value adjusting controller; the combustible gas component measuring point is arranged at the outlet of the Laval nozzle and used for collecting the volume fraction of combustible gas components in the synthesis gas after steam injection and transmitting the collected data to the heat value adjusting controller; the heat value adjusting controller is used for calculating a flow target value of the injected steam according to the received data and transmitting the flow target value to the flow adjusting valve; the flow regulating valve is used for collecting the steam flow at the outlet of the steam regulating valve, comparing the collected steam flow with the received flow target value, and further controlling the opening of the steam regulating valve.
Preferably, the main synthesis gas main pipeline is further provided with a dirty nitrogen injection pipeline, and a dirty nitrogen backflow valve, a dirty nitrogen stop valve and a dirty nitrogen regulation valve are sequentially arranged from the upstream to the downstream of the dirty nitrogen injection pipeline.
Preferably, the synthesis gas diffusing pipeline consists of two parallel pipelines, and the two pipelines are both connected with the fire-reducing torch; the flow control device on the synthesis gas release pipeline comprises a release controller, a first release pipeline regulating valve, a second release pipeline regulating valve and a synthesis gas pressure measuring point arranged at the inlet of the main synthesis gas regulating valve, wherein the first release pipeline regulating valve and the second release pipeline regulating valve are respectively arranged on the two pipelines; the synthetic gas pressure measuring point is used for collecting synthetic gas pressure injected into a nozzle of the gas turbine and transmitting the collected pressure to the release controller, and the release controller is used for comparing the received pressure value with a preset threshold value so as to control the opening degrees of the first release pipeline regulating valve and the second release pipeline regulating valve.
Compared with the prior art, the beneficial effects of the utility model are that:
the utility model provides a governing system for gas turbine fuel gas admits air, main synthetic gas pipeline pressure adjustment is nimble before the gas turbine nozzle, can let out the decompression through letting out the pipeline when pressure is on the high side, when pressure is on the low side, can guarantee that main synthetic gas pipeline pressure stabilizes in the safety range before the gas turbine nozzle through increasing main synthetic gas supply and increasing the natural gas and pour into the boost pressure; the natural gas fuel is quickly and flexibly injected by using the natural gas injection pipeline, so that the problem that the yield of the synthesis gas of the gasification furnace is increased and the gas shortage of the slow gas turbine is solved when the power generation load is quickly increased, the flexibility of an IGCC power plant is greatly improved, and the requirement of quick load shifting of a power grid is met; the heat value of the synthetic gas is reduced by utilizing steam injection, and the heat value of the fuel gas entering the gas turbine is ensured to be stabilized in a relatively fixed range no matter how the components of the fuel gas are changed, so that the working condition of the gas turbine is ensured to be stable; the utility model provides a traditional IGCC because the regulation rate of gasifier gas production is slower, the requirement that the whole power generation load change rate of power plant hardly reaches the flexibility peak regulation, when leading to the extensive grid-connected of unstable renewable energy such as wind-powered electricity generation, traditional IGCC can not satisfy its technological requirement's defect.
Furthermore, the high-pressure sewage nitrogen of the IGCC power plant can be recycled, and the high-pressure sewage nitrogen is injected into a gas turbine to be used for power generation, so that the overall power generation efficiency of the whole plant is improved.
Drawings
Fig. 1 is a schematic structural diagram of an intake air adjusting system according to the present invention.
Detailed Description
The present invention will be described in further detail with reference to the accompanying drawings.
As shown in FIG. 1, the utility model provides a regulating system for gas turbine fuel gas admits air, including natural gas injection pipeline 1, main synthetic gas pipeline 2, dirty nitrogen gas injection pipeline 3, steam injection pipeline 4, natural gas reflux valve 5, natural gas stop valve 6, natural gas governing valve 7, natural gas injection regulating controller 8, dirty nitrogen gas reflux valve 10, dirty nitrogen gas stop valve 11, dirty nitrogen gas regulating valve 12, heating steam regulating valve 13, heating steam controller 14, synthetic gas heater 15, drainage system 16, steam reflux valve 17, steam stop valve 18, steam regulator 19, flow control valve 20, main synthetic gas reflux valve 21, Laval nozzle 22, main synthetic gas stop valve 23, main synthetic gas regulating valve 24, nozzle 25, synthetic gas diffuse pipeline 26, first purge pipeline governing valve 27, second purge pipeline governing valve 28, The system comprises a first release pipeline stop valve 29, a second release pipeline stop valve 30, a fire removing torch 31, a release controller 32 and a heat value adjusting controller 33, wherein a natural gas injection pipeline 1, a dirty nitrogen gas injection pipeline 3, a synthetic gas heater 15, a main synthetic gas reverse flow valve 21, a Laval nozzle 22, a synthetic gas release pipeline 26, a main synthetic gas stop valve 23, a main synthetic gas adjusting valve 24 and a burner 25 are sequentially arranged on a main synthetic gas pipeline 2 from upstream to downstream.
Flow measuring points are arranged on the natural gas injection pipeline 1, the dirty nitrogen gas injection pipeline 3 and the steam injection pipeline 4, and flow of various gases is measured in real time and used for flow control.
The heat source of the syngas preheater 15 is heated with medium pressure saturated steam.
The natural gas injection pipeline 1 is provided with a natural gas reflux valve 5, a natural gas stop valve 6 and a natural gas regulating valve 7 from the upstream to the downstream in sequence.
The natural gas regulating valve 7 is connected with a natural gas injection regulating controller 8, the natural gas injection regulating controller 8 is connected with a pressure measuring point arranged on the main synthetic gas pipeline 2, the pressure measuring point is arranged at the upstream of the main synthetic gas regulating valve 24 and used for collecting the synthetic gas pressure injected into a nozzle 25 of the gas turbine and transmitting the collected pressure to the natural gas injection regulating controller 8, and the natural gas injection regulating controller 8 is used for comparing the received pressure with a preset threshold value and controlling the opening of the natural gas regulating valve 7 according to the comparison result.
The waste nitrogen backflow valve 10, the waste nitrogen stop valve 11 and the waste nitrogen adjusting valve 12 are sequentially arranged from the upstream to the downstream of the waste nitrogen injection pipeline 3.
The steam injection pipeline 4 is divided into two paths, and one path is connected with a synthesis gas heater 15 through a heating steam regulating valve 13 for heat exchange; the other path is connected to a laval nozzle 22.
A steam reflux valve 17, a steam stop valve 18 and a steam regulating valve 19 are sequentially arranged on a connecting pipeline between the branch of the steam injection pipeline 4 and the Laval nozzle 22.
The heating steam regulating valve 13 is connected with a heating steam controller 14; the steam regulating valve 19 is connected to a flow regulating valve 20.
The synthetic gas diffusing pipeline 26 is composed of two parallel pipelines, two pipelines are connected with the fire-extinguishing torch 31, and meanwhile, a first release pipeline regulating valve 27 and a first release pipeline stop valve 29 are sequentially arranged on one pipeline from upstream to downstream; and the other path is provided with a second discharge pipeline regulating valve 28 and a second discharge pipeline stop valve 30 from the upstream to the downstream in sequence.
The two pipelines are used for ensuring the stable pressure of the synthetic gas in the main synthetic gas pipeline in front of the gas turbine burner regulating valve.
The first purge line regulator 27 and the second chamber line regulator 28 are both connected to a purge controller 32.
A fuel gas inlet adjusting method of a synthesis gas turbine with a heat value adjusting function comprises the following steps:
the dirty nitrogen is injected into the main synthetic gas pipeline 2 through a dirty nitrogen backflow valve 10, a dirty nitrogen stop valve 11 and a dirty nitrogen regulating valve 12 through a dirty nitrogen injection pipeline 3; the waste nitrogen stop valve 11 is used for preventing the synthesis gas from flowing back to enter the waste nitrogen injection pipeline 3 when the pressure of the synthesis gas main pipeline is higher than the pressure of the waste nitrogen; when the waste nitrogen is not injected, the waste nitrogen stop valve 11 is closed; the dirty nitrogen adjustment valve 12 is used for controlling the flow of the injected dirty nitrogen during normal injection.
The natural gas injection pipeline 1 is used for injecting natural gas, when the load of the gas turbine needs to be quickly increased, the main synthetic gas regulating valve 24 for gas inlet of the gas turbine burner 25 is rapidly opened, the pressure in front of the valve is rapidly reduced, and the yield of the synthetic gas cannot be rapidly increased, so that the synthetic gas of the main synthetic gas pipeline is insufficient to meet the requirement, and a fuel gas gap is met by the natural gas injection pipeline 1 through natural gas injection.
Natural gas is injected into the main synthetic gas pipeline 2 through a natural gas reflux valve 5, a natural gas stop valve 6 and a natural gas regulating valve 7; the natural gas check valve 5 is used for preventing the synthesis gas from flowing back to enter the natural gas pipeline when the pressure of the main synthesis gas pipeline 2 is higher than the pressure of the natural gas.
When the natural gas injection is not performed, the natural gas stop valve 6 is closed; the natural gas regulating valve 7 is used for controlling the flow of injected natural gas during normal injection.
The natural gas regulating valve 7 adopts a natural gas injection regulating controller 8 to control flow, the pre-valve pressure in front of a burner 25 of the gas turbine is used as a target value of the natural gas injection regulating controller 8, the target value of natural gas flow injection is determined according to the deviation degree of the pre-valve pressure and a normal value, and the natural gas injection regulating controller 8 gives the opening degree of the regulating valve according to the feedback of valve parameters and natural gas flow measurement.
When the load of the gas turbine is reduced, or the load of the gasification furnace is increased, the synthetic gas is sufficiently supplied, and the pressure before the gas inlet valve of the burner 25 of the gas turbine is increased, the natural gas injection amount is gradually reduced until the natural gas injection pipeline is completely closed.
The syngas preheater 15 is used to preheat syngas to a specific temperature; the heat source of the synthesis gas preheater 15 is medium-pressure saturated steam, and the synthesis gas is heated by using the latent heat of condensation of the medium-pressure saturated steam.
The medium pressure saturated steam becomes condensed water after the heat release of the synthesis gas preheater 15 and is sent to the drainage system 16.
The steam inlet of the synthetic gas preheater 15 is communicated with a branch of the steam injection pipeline 4, a heating steam regulating valve 13 is arranged on the branch pipeline, the heating steam regulating valve 13 is controlled by a heating steam controller 14, the synthetic gas outlet of the synthetic gas preheater 15 is provided with a temperature measuring point, and the measured value is used as the feedback quantity of the heating steam controller 14 and is used for controlling the opening degree of the heating steam regulating valve 13.
The steam injection is a key means for adjusting the heat value of the synthesis gas, a Laval nozzle 22 is installed on a main synthesis gas pipeline 2, the other branch of the steam injection pipeline 4 is connected with a steam extraction port of the Laval nozzle 22, and a main synthesis gas check valve 21 is installed on the main synthesis gas pipeline 2 in front of the Laval nozzle 22 to prevent steam from flowing back to the main synthesis gas pipeline due to overpressure of the steam.
Steam is injected into the Laval nozzle 22 through the steam injection pipeline 4 through the steam check valve 17, the steam stop valve 18 and the steam regulating valve 19, wherein the steam check valve 17 is used for preventing the synthesis gas from flowing backwards to enter the steam pipeline when the pressure of the main synthesis gas pipeline is higher than the pressure of the steam pipeline.
When the steam injection is not performed, the steam stop valve 18 is closed.
The steam control valve 19 is used for controlling the flow rate of the injected steam during the normal injection.
A synthetic gas component measuring point and a synthetic gas flow measuring point are arranged at the inlet of the synthetic gas heater 15, and the volume fraction (Vol) of the combustible gas component is obtained by real-time measurement1％,CO、H2、CH4、C2H6) And flow rate F1And transmits the measured data to the heat value adjusting controller 30;
the Laval nozzle 22 is afterloaded with gas component measuring points, and the volume fraction (Vol) of combustible gas components in the synthesis gas after steam injection is measured in real time2％,CO、H2、CH4、C2H6) And calculates the white value (volumetric heating value) of the synthesis gas and transmits the result as a feedback amount to the heating value adjusting controller 33.
The calorific value adjustment controller 33 is configured to calculate a target flow rate of the injected steam from the two measurement values of the flow rate measurement point and the gas component measurement point, and transmit the target flow rate to the flow rate adjustment valve 20 on the steam injection line 4.
The flow regulating valve 20 is configured to collect a steam flow measurement feedback value of a flow measurement point set at an outlet of the steam regulating valve 19, and regulate an opening of the steam regulating valve 19 in real time according to the received steam flow measurement feedback value and a flow target value.
The syngas discharging line 26 is composed of two parallel lines, and each line is connected in series with a first discharging line regulating valve 27, a first discharging line stop valve 29, a second discharging line regulating valve 28, and a second discharging line stop valve 30.
The pressure in front of an inlet valve of a burner 25 of the gas turbine is divided into six intervals of low two values, low one values, middle values, high one values, high two values and high three values; under normal conditions, the pressure in front of the inlet valve of the gas turbine burner 25 is in a normal range, namely a median value, and the first bleed line stop valve 29 and the second bleed line stop valve 30 are controlled to be closed by the bleed controller 32 on the synthesis gas bleed line 26.
When the load of the gas turbine suddenly drops and the required amount of the synthesis gas is reduced, and the pressure in front of the inlet valve of the burner 25 of the gas turbine rises to a high value, the bleed controller 32 on the synthesis gas bleed pipeline 26 controls the second bleed pipeline stop valve 30 to be opened, the second bleed pipeline regulating valve 28 is gradually opened, and the pressure of the main synthesis gas pipeline is bled.
When the pressure in the main syngas main 2 further increases to a high value, the bleed controller 32 on the syngas bleed line 26 controls the second bleed line adjustment valve 28 to open rapidly to more than 50% open, and at the same time, the first bleed line stop valve 29 opens, the first bleed line adjustment valve 27 opens gradually, and the main syngas main pressure is bled off.
If the pressure in the main synthesis gas line 2 rises further to three high values, the valves of the two lines of the synthesis gas discharge line 26 are fully open.
When the pressure in the main synthesis gas line 2 returns to a value lower by one, the valves of the other branch of the synthesis gas blow-off line 26 are closed.
The system parameters applied to this example are shown in the following table:
| serial number | Parameter(s) | Numerical value |
| 1 | Pressure MPa in front of burner valve of gas turbine | 2.5 |
| 2 | Synthetic gas heat value MJ/Nm3 | 10.7 |
| 3 | Front fuel gas heat value MJ/Nm of gas turbine inlet nozzle3 | 7 |
| 4 | Full main syngas flow Nm3/h | 170000 |
| 5 | Maximum flow Nm of waste nitrogen3/h | 5000 |
| 6 | Full load steam injection t/h | 85 |
| 7 | Heating steamSteam pressure MPa | 4.5 |
| 8 | Outlet temperature of synthesis gas heater | 247 |
| 9 | Full load output power MW of gas turbine | 170 |
Claims (7)
1. A regulating system for fuel gas inlet of a gas turbine is characterized by comprising a natural gas injection pipeline (1), a main synthetic gas pipeline (2) and a steam injection pipeline (4), wherein the natural gas injection pipeline (1), a synthetic gas heater (15), a main synthetic gas reverse flow valve (21), a Laval nozzle (22), a synthetic gas release pipeline (26), a main synthetic gas regulating valve (24) and a burner (25) are sequentially arranged on the main synthetic gas pipeline (2) from upstream to downstream;
the outlet of the steam injection pipeline (4) is divided into two branches, and one branch is connected with the steam inlet of the synthesis gas heater (15); the other branch is connected with a steam inlet of the Laval nozzle (22);
meanwhile, the natural gas injection pipeline (1), the synthesis gas diffusion pipeline (26) and the steam injection pipeline (4) are all provided with flow control devices for realizing flow control.
2. The system for regulating the admission of fuel gas to a gas turbine according to claim 1, characterized in that the natural gas injection line (1) is provided, upstream to downstream, in succession with a natural gas reflux valve (5), a natural gas stop valve (6) and a natural gas regulating valve (7).
3. The system for regulating fuel gas inlet of a gas turbine according to claim 1, wherein the natural gas flow rate control means on the natural gas injection line (1) comprises a natural gas regulating valve (7), a natural gas injection regulating controller (8) and a synthesis gas pressure measuring point, wherein the synthesis gas pressure measuring point is arranged on the main synthesis gas pipeline (2) and is arranged upstream of the main synthesis gas regulating valve (24), the synthesis gas pressure measuring point is used for collecting the synthesis gas pressure injected into the gas turbine burner (25) and transmitting the collected pressure to the natural gas injection regulating controller (8), and the natural gas injection regulating controller (8) is used for comparing the received pressure with a preset threshold value and controlling the opening degree of the natural gas regulating valve (7) according to the comparison result.
4. A conditioning system for fuel gas inlet to a gas turbine according to claim 1, it is characterized in that a heating steam flow control device is arranged on a connecting pipeline between one branch of the steam injection pipeline (4) and a steam inlet of the synthesis gas heater (15), the heating steam flow control device comprises a heating steam regulating valve (13), a heating steam controller (14) and a temperature measuring point arranged on a main synthetic gas pipeline (2), wherein the temperature measuring point is arranged at the downstream of a synthetic gas heater (15), the temperature control device is used for collecting a temperature value of a synthetic gas outlet of the synthetic gas heater (15) and transmitting the collected temperature value to the heating steam controller (14), and the heating steam controller (14) is used for comparing the received temperature value with a preset threshold value so as to control the opening degree of the heating steam regulating valve (13).
5. The regulating system for fuel gas admission to a gas turbine according to claim 1, characterized in that the connecting pipe between the other branch of the steam injection line (4) and the steam inlet of the laval nozzle (22) is provided with a steam flow control device comprising a steam regulating valve (19), a flow regulating valve (20), a calorific value regulating controller (33), a syngas flow rate point, a syngas component measuring point and a combustible gas component measuring point, wherein the syngas flow rate point, the syngas component measuring point and the combustible gas component measuring point are all arranged on the main syngas main line (2); both the flow measuring point of the synthetic gas and the measuring point of the synthetic gas component are arranged at the inlet of the synthetic gas heater (15) and are used for collecting the flow of combustible gas and the volume fraction of the gas component and transmitting the collected data to the heat value adjusting controller (33); a combustible gas component measuring point is arranged at the outlet of the Laval nozzle (22) and used for collecting the volume fraction of the combustible gas component in the synthesis gas after steam injection and transmitting the collected data to a heat value adjusting controller (33); the heat value adjusting controller (33) is used for calculating a flow target value of the injected steam according to the received data and transmitting the flow target value to the flow adjusting valve (20); the flow regulating valve (20) is used for collecting the steam flow at the outlet of the steam regulating valve (19), comparing the collected steam flow with the received flow target value, and further controlling the opening of the steam regulating valve (19).
6. The regulating system for fuel gas inlet of a gas turbine according to claim 1, wherein a dirty nitrogen gas injection pipeline (3) is further arranged on the main synthetic gas pipeline (2), and a dirty nitrogen gas reverse flow valve (10), a dirty nitrogen gas stop valve (11) and a dirty nitrogen gas regulating valve (12) are sequentially arranged from upstream to downstream of the dirty nitrogen gas injection pipeline (3).
7. A system for regulating the admission of fuel gas to a gas turbine according to claim 1, characterised in that the syngas discharge line (26) consists of two parallel lines, both connected to the torches (31); the flow control device on the synthesis gas diffusing pipeline (26) comprises a bleeding controller (32), a first bleeding pipeline regulating valve (27), a second bleeding pipeline regulating valve (28) and a synthesis gas pressure measuring point arranged at the inlet of the main synthesis gas regulating valve (24), wherein the first bleeding pipeline regulating valve (27) and the second bleeding pipeline regulating valve (28) are respectively arranged on the two branch pipelines; the synthetic gas pressure measuring point is used for collecting the synthetic gas pressure injected into a burner (25) of the gas turbine and transmitting the collected pressure to the release controller (32), and the release controller (32) is used for comparing the received pressure value with a preset threshold value so as to control the opening degrees of the first release pipeline regulating valve (27) and the second release pipeline regulating valve (28).
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| CN201922120016.7U CN211038839U (en) | 2019-11-28 | 2019-11-28 | Regulating system for fuel gas inlet of gas turbine |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110700945A (en) * | 2019-11-28 | 2020-01-17 | 中国华能集团有限公司 | Gas turbine fuel gas inlet adjusting system and method with combustion reference gas injection and heat value adjusting functions |
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Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN110700945A (en) * | 2019-11-28 | 2020-01-17 | 中国华能集团有限公司 | Gas turbine fuel gas inlet adjusting system and method with combustion reference gas injection and heat value adjusting functions |
| WO2021103935A1 (en) * | 2019-11-28 | 2021-06-03 | 中国华能集团有限公司 | Fuel gas inlet adjusting system and method for gas turbine with co-combustion gas injection and heat value adjustment functions |
| CN110700945B (en) * | 2019-11-28 | 2023-09-26 | 中国华能集团有限公司 | Gas turbine fuel gas inlet adjusting system and method with parameter combustion gas injection and heat value adjusting functions |
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