GB2352778A - Run-up of a combined power station by determining a load gradient of a gas turbine from parameters of a steam turbine - Google Patents
Run-up of a combined power station by determining a load gradient of a gas turbine from parameters of a steam turbine Download PDFInfo
- Publication number
- GB2352778A GB2352778A GB0018754A GB0018754A GB2352778A GB 2352778 A GB2352778 A GB 2352778A GB 0018754 A GB0018754 A GB 0018754A GB 0018754 A GB0018754 A GB 0018754A GB 2352778 A GB2352778 A GB 2352778A
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- Prior art keywords
- steam
- gas turbine
- turbine
- steam turbine
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- 239000007789 gas Substances 0.000 claims abstract description 105
- 238000000034 method Methods 0.000 claims abstract description 22
- 239000002918 waste heat Substances 0.000 claims abstract description 14
- 238000005259 measurement Methods 0.000 claims abstract description 12
- 230000003416 augmentation Effects 0.000 claims description 27
- 238000002485 combustion reaction Methods 0.000 claims description 11
- 239000000446 fuel Substances 0.000 claims description 8
- 238000011156 evaluation Methods 0.000 claims description 6
- 230000001747 exhibiting effect Effects 0.000 claims description 2
- 238000009434 installation Methods 0.000 description 19
- 238000011161 development Methods 0.000 description 3
- 238000010586 diagram Methods 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 101150094949 APRT gene Proteins 0.000 description 2
- 238000009529 body temperature measurement Methods 0.000 description 2
- 239000000567 combustion gas Substances 0.000 description 2
- 238000013461 design Methods 0.000 description 2
- 238000012937 correction Methods 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 230000000977 initiatory effect Effects 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
Classifications
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- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
- F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
- F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
- F01K23/10—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle with exhaust fluid of one cycle heating the fluid in another cycle
- F01K23/101—Regulating means specially adapted therefor
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E20/00—Combustion technologies with mitigation potential
- Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
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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)
- Control Of Turbines (AREA)
Abstract
A combined power station 30 comprises at least one gas turbine 11 and one steam turbine 13, live steam for operating the steam turbine 13 being generated by means of the hot exhaust gases of the gas turbine 11 in a waste-heat boiler 16 and being fed to the steam turbine 13 and surplus live steam being guided via a controllable bypass line 24 and bypass valve 25 past the steam turbine 13 directly to a condenser 26. A cost-effective and environmentally friendly start-up method of operation is achieved if, in order to reduce the surplus steam flowing via the bypass, the gas turbine is initially run up to its minimum load, and if the gas turbine is subsequently run up with a load gradient (P<SB>GT</SB>, fig 3) which is determined by parameter/parameters of the steam cycle, such as live steam temperature, bypass steam pressure, steam turbine flange temperature and/or bypass valve lifting measurement.
Description
2352778 99/169 Run-up method for a combined power station and combined
power station for carrying out the method The present invention refers to the field of combined power stations. It. relates to a run-up method for a combined power station, in accordance with the preamble to claim 1, and to a combined power station for carrying out the method.
A combined power station or a combined installation of the known type is diagrammatically shown as excerpt in Fig. I using an installation plan. The combined power station 10 comprises a gas turbine 11 and a steam turbine 13, which jointly drive a generator 12. The gas turbine 11 is directly connected to the generator 12 by means of a shaf t 14 whereas the steam turbine 13 is connected to it by means of an intermediate clutch 15. The installation can also, of course, be configured as a multi-shaft installation. In the example shown, the gas turbine 11 is equipped with a sequential combustion system in which two combustion chambers le and 20 are arranged one behind the other. The combustion air is induced and compressed by a compressor 17, is mixed with fuel (liquid and/or gaseous) and is burnt in a first combustion chamber 18. The hot combustion gases drive a first turbine stage 19. Fuel and/or a fuel/air mixture is in turn injected into the hot exhaust gases of the first turbine stage in a second combustion chamber 20 and is made to ignite. The combustion gases of the second combustion chamber 20 drive a second turbine stage 21.
After leaving the ga s turbine 11, the hot exhaust gases are used to generate live steam for the steam turbine 13 by means of a waste-heat boiler (heat recovery steam generator HR SG) 16, which is known per se, as part of a water/steam circuit and is only partially shown in Fig. 1. The live steam f rom the superheater of the waste-heat boiler 16 is fed via a 99/169 2 live steam line 29 to the steam turbine 13 where depending on the setting of a live steam valve 23 and of a bypass valve 25 arranged in a bypass line 24 - it is used partly for driving the steam turbine 13 and partly for a direct supply to a condenser 26, via the bypass line 24 of the steam turbine 13. The steam emerging from the steam turbine 13 and that flowing via the bypass line 24 are condensed in the condenser 26 and the condensate is pumped back to the waste-heat boiler 16 by means of a condensate pump 27.
In order to run up the combined installation of Fig. 1, it is necessary to run up both the steam turbine 13 and the gas turbine 11. An automatic run-up system 28 (of the applicant's Type TURBOTROL/TURBOMAX, for example) is provided for running up the steam turbine. This system is connected, at its input end, to a flange temperature measurement 38 on the steam turbine 13 and transmits, at its output end, a power augmentation signal to control the live steam valve 23.
A control system 22 is provided for running up the gas turbine 11 and this, employing a load gradient in each case which is characteristic of the gas turbine 11, successively runs the gas turbine 11 up to certain rest points (see Fig. 2).
Combined installations in accordance with Fig. 1 are run up by f irst starting the gas turbine 11 (rotational speed nGT curve in Fig. 2) and heating the water/steam circuit and the waste-heat boiler 16; the steam turbine 13 is then started from rest and put under load. The steam quantity which cannot be absorbed by the steam turbine 13 is rejected via the bypass 24, 25 to the condenser 26. During a cold start and a hot start of the installation, the gas turbine 11 is loaded to a rest point (horizontal levels of the solid-line curve of gas turbine power P.,, in Fig. 2) in order to produce sufficient excess steam for the steam turbine 13. As soon as the steam turbine 13 can absorb 99/169 3 more steam, the gas turbine 11 is run up to full load and takes the steam turbine 13 with it (chain-dotted curve of the steam turbine power PDT in Fig. 2), excess steam being always rejected to the condenser 26 (interrupted curve of the steam bypass mass flow SBF (steam bypass flow) in Fig. 2.
A disadvantageous feature of this arrangement is that the steam quantity rejected to the condenser 26 via the bypass 24, 25 represents fuel energy which, although it is converted into steam, is then rejected unused.
The object of the invention is, therefore, to provide a run-up method for a combined installation which can be simply realized and which has the result that little, or indeed no, steam now needs to be rejected.
The object is achieved by the totality of the features of claim 1. The core of the invention consists in no longer running the gas turbine up to a f ixed rest point and then running it up with the load gradient peculiar to the gas turbine but, rather, in initially running the gas turbine up to its minimum load and then in running it up with a load gradient which is based on the condition parameters of the steam turbine.
A first preferred embodiment of the method according to the invention is characterized in that the steam turbine is run up by means of an automatic run-up system, which transmits a power augmentation signal APDT for the steam turbine as a function of the respective load condition or load gradient of the steam turbine, in that the additional steam quantity Am necessary for the power augmentation is I derived from the power augmentation signal APDT, in that a power augmentation signal ApGT of the gas turbine, which is necessary for the generation of the additional steam quantity Am, is derived from the additional steam quantity Am which has 99/169 4 been determined, and in that the gas turbine is run up as a function of this gas turbine power augmentation signal APGT. By this means, the power of the gas turbine is aligned closely with the power of the steam turbine in each case so that only very little excess steam has to be rejected.
A preferred development of this embodiment is characterized in that any existing pressure limitations for the waste-heat boiler and/or temperature limitations for the waste-heat boiler and/or the steam turbine are taken into account when running up the gas turbine, and in that the adjustment to the optimum exhaust gas temperatures and exhaust gas mass flows of the gas turbine necessary for the steam data present is obtained both by controlling the fuel quantity to the combustion chamber or the combustion chambers of the gas turbine and by influencing the guide vane setting of the gas turbine.
Another preferred development is characterized in that the setting of the bypass is additionally employed for the fine control of the gas turbine, the f ine control of the gas turbine taking place in such a way that a bypass valve arranged in the bypass always exhibits a minimum opening. 25 Another development is characterized in that the bypass is kept closed, and in that the control of the gas turbine takes place along a required curve as a function of the live steam pressure. A second preferred embodiment of the invention is characterized in that the steam turbine is run up by means of an automatic run-up system which transmits a power augmentation signal APDT for the steam turbine as a function of the respective load condition or load gradient of the steam turbine, and in that the gas turbine is only loaded as a function of the setting of the bypass, with the bypass valve arranged in the bypass always exhibiting a minimum opening.
99/169 in a third preferred embodiment of the method according to the invention, the steam turbine is run up by means of an automatic run-up system which transmits a power augmentation signal AP1DT for the steam turbine as a function of the respective load'condition or load gradient of the steam turbine, and the control of the gas turbine takes place along a required curve as a function of the live steam pressure.
A fourth preferred embodiment is characterized in that a condition parameter, in particular the flange temperature of the steam turbine, is measured before the steam turbine is started, and in that the gas turbine is run up along a specified load curve as a function of this condition parameter, such that the steam turbine is not overloaded by the starting stresses and the whole of the live steam is absorbed by the steam turbine.
The combined power station according to the invention for carrying out the method according to the invention is distinguished in that a control system is provided for running up or operating the gas turbine, in that first means are provided for measuring and evaluating condition parameters of the steam turbine and/or of the steam circuit connected to the steam turbine, and in that the control system of the gas turbine is in effective connection at the input end to the measurement and evaluation means.
A preferred embodiment of the combined power station according to the invention is distinguished in that the first measurement and evaluation means comprise an automatic run- up System for the steam turbiner which system is supplied, at the input end, with the flange temperature of the steam turbine as the condition parameter, and which system transmits at the output-end, a power augmentation signal APDT for the steam turbine and in that the output of the automatic run-up system is connected via functional blocks to the 99/169 input of the gas turbine control system, which functional blocks associate a corresponding power augmentation signal APrT for the gas turbine with the power augmentation signal APDT for the steam turbine in 5 accordance with specified functions.
Further embodiments are provided by the sub- claims.
The invention is explained in more detail below in association with the drawing, using embodiment examples. In the drawing:
Fig. I shows, as excerpt, the diagrammatic representation of a combined power station (a combined installation) of the prior art;
Fig. 2 shows a diagram of the run-up curves f or the gas turbine and the steam turbine in the case of conventional run-up of an installation as shown in Fig. 1; Fig. 3 shows the curves comparable with Fig. 2# such as occur, as an example, for a run-up method in accordance with the invention; Fig.. 4 shows an installation plan comparable with Fig. I for a combined installation in accordance with a first preferred embodiment example of the invention with thesteam turbine and gas turbine control systems connected by means of functional blocks; Fig. 5 shows an embodiment example differing from Fig. 4 to the extent that the gas turbine control system is additionally acted upon, as an input parameter, by the valve lift of a bypass valve; Fig. 6 shows another embodiment example in which the gas turbine control system is acted upon, as an input parameter, only by the valve lift of a bypass valve; 99/169 7 Fig. 7 shows an embodiment example differing from Fig. 4 to the extent that the gasturbine control system is additionally acted upon, as an input parameter, by the pressure in the bypass line or t he pressure of the live steam; Fig. 8 shows an embodiment example comparable with Fig. 6 in which the gas turbine control system is acted upon, as an input parameter, only by the pressure in the bypass line or by the pressure of the live steam; and Fig. 9 shows another embodiment example in which an adapted run-up curve for the gas turbine is derived from the flange temperature is measurement on the steam turbine before starting and is used for controlling the gas turbine.
A combined power station of single-'shaft type, in which one gas turbine and one steam turbine act on a common generator, is shown in all the embodiment examples. In all the sketches illustrating principles, furthermore, a gas turbine with sequential. combustion is shown. This design is not. of CO urse, essential to the invention. The invention can also be realized without difficulty with a different arrangement of gas turbine and steam turbine and with any given gas turbine design. Within the framework of the nonrestrictive embodiment examples, however, the invention is shown in association with the most modern installation technology.
The solution according to the invention leads to an exemplary diagram, which is reproduced in Fig. 3 and can be compared with the diagram of Fig. 2. Due to the method according to the invention, the power Pcr of the gas turbine is initially driven to minimum load and then run up along a curve which clings closely to the 99/169 associated curve for the power PDT Of the steam turbine.
In consequence, the steam bypass mass flow SBF is reduced to a minimum, which markedly increases the efficiency of the installation.
The load gradient determining the run-up of the gas turbine can be influenced by the condition parameters of the steam turbine or of the water/steam circuit in various ways within the scope of the invention, as shown in Figures 4 to 9 (the same parts of the installation are always provided with the same designations, which have also been. used in Fig. 1).
In a first realization, as shown in Fig. 4, the control system 22 of the gas turbine 11 in the combined power station 30 receives a signal from the automatic run-up system 28 of the steam turbine 13. In this arrangement, the additional steam quantity Am necessary for the power augmentation is associated by a first functional block 32 with the power augmentation signal APDT Of the steam turbine 13 from the automatic run-up system 2B and, in a second functional block 33, a power augmentation signal APw of the gas turbine 11 necessary for the generation of the steam quantity Am which has been determined is associated with this additional steam quantity Am which has been determined, which power augmentation signal APGT then reaches the control system 22. Both functional blocks 32 and 33 can be effected by a simple computer. In addition, temperature and pressure limitations in the waste-heat bciler 16 and temperature limitations to the steam turbine 14 can also be taken into account during the run-up of the gas turbine 11, the optimum exhaust gas temperatures and exhaust gas mass flows of the gas turbine 11 which are necessary for the steam data present can be set both by controlling the fuel quantity and by influencing the guide vane setting of the gas turbine 11. it is thus conceivable, as shown in Fig. 4, to measure the temperature of the live steam 99/169 in the live steam line 29 by means of a temperature sensor 31 and to supply the measured temperature values to the gas turbine control system 22 (interrupted line in Fig. 4). During the run-up of the gas turbine, furthermore, it is also possible to take account of the time and the quantity of steam which are necessary to evacuate the condenser 26.
In a second realization of the invention, as shown in Fig. 5, the connection between the steam turbine 13 and the gas turbine 11 takes place by means of the automatic run-up system 28 and the functional blocks 32 and 33, in the same manner as in Fig. 4. As a departure from the latter, however, the setting of the bypass 24, 25 or the setting of the bypass valve 25 is additionally used by means of a valve lift measurement 34 for the fine control ("fine tuning") of the gas turbine 11, correction taking place in such a way that the bypass valve 25 is at minimum lift.
In a third realization, as shown in Fig. 6, the steam turbine 13 is loaded in accordance with its automatic run-up system 28 whereas the gas turbine 11 is only loaded to correspond with the setting of the bypass valve 25 (valve lift measurement 34). In this arrangement, the bypass valve 25 always remains at minimum lift so that only a minimum steam quantity is rejected.
A fourth realization, as shown in Fig. 77, is similar to the installation of Fig. 5. In this case, however, the live steam pressure is measured by a pressure sensor 35 instead of the setting of the bypass valve 25 and a required variation, corresponding to the live steam pressure variation, is followed by the gas turbine 11. In this arrangement, the steam bypass 24, 25 remains closed. The required live steam pressure variation can then be dependent, in particular, on the loading gradient of the waste-heat boiler 16.
99/169 In a fifth realization, which is similar to Fig. 6 and is shown in Fig. 8, the steam turbine 13 is loaded in accordance with its automatic run-up system 28 whereas the gas turbine 11 is driven in such a way that it follows a required steam pressure variation, which is measured by means of the pressure sensor 35.
Finally, as is shown in Fig. 9, simplified runup of the installation can be effected within the framework of the invention by economizing in the automatic run-up system. Using a flange temperaiure measurement 38 on the steam turbine 13 (or another condition parameter of the steam turbine 13) before the start, the gas turbine runs up along a load curve in such a way that the steam turbine is not overloaded by starting stresses and the whole of the steam production is absorbed by the steam turbine 13. From the initiation of the starting of the steam turbine 13, the latter controls the variation of the live, steam pressure (live steam valve 23 with pressure sensor 36) whereas the gas turbine 11 follows a preset load curve, which is transmitted by a curve generator 37 in accordance with the previously measured flange temperature. In this arrAngement, the steam bypass 24, remains closed.
Overall, the invention provides a mode of operation for the run-up of combined installations which is characterized by a minimum of rejected live steam. Although the starting time is not affected, less fuel is used in this arrangement, thus providing lower starting costs and fewer environmental effects.
99/169 List of designations 10, 30 Combined power station (combined installation) 11 Gas turbine (GT) 12 Generator 13 Steam turbine (DT) 14 Shaft is Clutch 16 Waste-heat boiler (HRSG) 17 Compressor 18, 20 Combustion chamber 19, 22 Turbine stage 22 Control system (gas turbine) 23 Live steam valve 24 Bypass line Bypass valve 26 Condenser 27 Condensate pump 28 Automatic run-up system (steam turbine) 29 Live steam line 31 Temperature sensor 32 Functional block Am (APDT) 33 Functional block APrT (Am) 34 Valve lift measurement 35, 36 Pressure sensor 37 Curve generator 38 Flange temperature measurement nGT Rotational speed (gas turbine) PG? Power (gas turbine) PDT Power (steam turbine) SBF Steam bypass ma ss flow 99/169
Claims (18)
1. A run-up method for a combined power station (30) which comprises at least one gas turbine (11) and one steam turbine (13), live steam for operating the steam turbine (13) being generated by means of the hot exhaust gases of the gas turbine (11) in a waste-heat boiler (16) and being fed to the steam turbine (13) and surplus live stearn being guided via a cont rollable bypass (24, 25) past the steam turbine (13) directly to a condenser (26), wherein, in order to reduce the surplus steam flowing via the bypass (24, 25), the gas turbine (11) is initially run up to its minimum load, and the gas turbine (11) is subsequently run up with a load gradient which is determined by condition parameters of the steam turbine (13).
2. The method as claimed in claim 1, wherein the steam turbine (13) is run up by means of an automatic run-up system (28), which transmits a power augmentation signal (APDT) for the steam turbine (13) as a function of the respective load condition or load gradient of the steam turbine (13), the additional steam quantity (AM) necessary for the power augmentation is derived from the power augmentation signal (APDT), a power augmentation signal (APGT) of the gas turbine (11), which is necessary for the generation of the additional steam quantity (Am), is derived from the additional steam quantity USM) which has been determined, and the gas turbine (11) is run up as a function of this gas turbine power augmentation signal (APw)
3. The method as claimed in claim 2, wherein any existing pressure limitations present fox the wasteheat boiler (16) and/or temperature limitations for the waste-heat boiler (16) and/or the steam turbine (13) are taken into account when running up the gas turbine (11).
99/169
4. The method as claimed in claim 3, wherein adjustment to the optimum exhaust gas temperatures and exhaust gas mass flows of the gas turbine (11) necessary for the steam data present is obtained both by controlling the fuel quantity to thecombustion chamber or the combustion chambers (16, 20) of the gas turbine (11) and by influencing the guide vane sett ing of the gas turbine (11).
5. The method as claimed in one of claims 2 to 4, wherein the setting of the bypass (24, 25) is additionally employed for the fine control of the gas turbine (11), the fine control of the gas turbine (11) taking place in such a way that a bypass valve (25) arranged in the bypass always exhibits a minimum opening lift.
6. The method as claimed in one of claims 2 to 4, wherein the bypass (24, 25) is kept closed, and the control of the gas turbine (11) takes place along a required curve as a function of the live steam pressure.
7. The method as claimed in claim 6, wherein the required live steam pressure curve depends on the load gradient of the waste-heat boiler (16).
8. The method as claimed in claim 1, wherein the steam turbine (13) is run up by means of an automatic run-up system (28) which transmits a power augmentation signal (APDT) for the steam turbine (13) as a function of the respective load condition or load gradient of the steam turbine (13), and the gas turbine (11) is only loaded as a function of the setting of the bypass (24, 25), with the bypass valve (25) arranged in the bypass always exhibiting a minimum opening lift.
9. The method as claimed in claim 1, wherein the steam turbine (13) is run up by means of an automatic run-up - system (28) which transmits a power augmentation signal (APDT) for the steam turbine (13) as a function of the respective load condition or load gradient of 99/169 the steam turbine (13), and the control of the gas turbine (11) takes place along a required curve as a function of the live steam pressure.
10. The method as claimed in claim 1, wherein a condition parameter, in particular the flange temperature of the steam turbine (13), is measured before the steam turbine (13) is started, and the gas turbine (11) is run up along a specified load curve as a function of this condition parameter, such that the steam turbine (13) is not overloaded by the starting stresses and the whole of the live steam is absorbed by the steam turbine (13).
11. A combined power station for carrying out the method as claimed in claim 1, wherein a control system (22) is provided for running up or operating the gas turbine (11), first means (28, 31, 34, 35, 38) are provided for measuring and evaluating condition parameters of the steam turbine (13) and/or of the steam circuit (24, 25, 29) connected to the steam turbine (13), and the control system (22) of the gas turbine (11) is in operational connection at the input end to the measurement and evaluation means (28, 31, 34, 35, 3B).
12. The combined power station as claimed in claim 11, wherein the first measurement and evaluation means comprise an automatic run-up system (28) for the steam turbine (13), which system is supplied, at the input end, with the flange temperature of the steam turbine (13) as the condition parameter, and which system transmits, at the output end, a power augmentation signal (APDT) for the steam turbine (13) and the output of the automatic run-up system (28) is connected via functional blocks (32, 33) to the input of the gas turbine control system (22), which functional blocks associate a corresponding power augmentation signal (APGT) for the gas turbine (11) with 99/169 - the power augmentation signal (APDT) f or the steam turbine (13) in accordance with specified functions.
13. The combined power station as claimed in claim 12, wherein a temperature sensor (31) is provided for measuring the temperature of thelive steam, and the temperature sensor (31) is connected to the input of the gas turbine control system (22).
14. The combined power station as claimed in one of claims 12 and 13, wherein a pressure sensor (35) is provided for measuring the pressure of the live steam, and the pressure sensor (35) is connected to the input of the gas turbine control system (22).
15. The combined power station as claimed in one of claims 12 and 13, wherein a bypass valve (25) is arranged in the bypass (24, 25) of the steam turbine (13), second means are provided for measuring the valve lift of the bypass valve (25), and the second means are connected to the input of the gas turbine control system (22).
16. The combined power station as claimed in claim 11, wherein the first measurement and evaluation means comprise an automatic run-up system (28) for the steam turbine (13),: which system is supplied, at the input end, with the flange temperature of the steam turbine (13) as the condition parameter, and which system transmits, at the output end, a power augmentation signal (APDT) for the steam turbine (13) in order to control a live steam valve (23), a bypass valve (25) is arranged in the bypass (24, 25) of the steam turbine (13), second means are provided for measuring the valve lift of the bypass valve (25), and the second means are connected with the input of the gas turbine control system (22).
17. The combined power station as claimed in claim 11, wherein the first measurement and evaluation means comprise an automatic run-up system (28) for the steam turbine (13), which system is 99/169 supplied, at the input end, with the flange temperature of the steam turbine (13) as the input parameter and which system, at the output end, transmits a power augmentation signal (APDT) for the steam turbine (13) to control a live steam valve (23), a pressure sensor (35) is provided to measure the pressure of the live steam, and the pressure sensor (35) is connected to the input of the gas turbine control system (22).
18. The combined power station as claimed in claim 11, wherein the first means are designed for measuring the flange temperature of the steam turbine (13), and the first means are in operational connection, via a curve generator (37), with the gas turbine control system (22), which curve generator (37) transmits a predetermined load curve to the gas turbine control system (22) as a function of a flange temperature input present during the starting of the steam turbine (13).
I
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| EP99810689A EP1072760A1 (en) | 1999-07-30 | 1999-07-30 | Method of starting a combined power plant and combined power plant for carrying out the method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| GB0018754D0 GB0018754D0 (en) | 2000-09-20 |
| GB2352778A true GB2352778A (en) | 2001-02-07 |
Family
ID=8242954
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB0018754A Withdrawn GB2352778A (en) | 1999-07-30 | 2000-07-28 | Run-up of a combined power station by determining a load gradient of a gas turbine from parameters of a steam turbine |
Country Status (2)
| Country | Link |
|---|---|
| EP (1) | EP1072760A1 (en) |
| GB (1) | GB2352778A (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JP2008534860A (en) * | 2005-04-05 | 2008-08-28 | シーメンス アクチエンゲゼルシヤフト | Start-up method of gas / steam combined turbine equipment |
| US11591955B2 (en) | 2018-06-22 | 2023-02-28 | Siemens Energy Global GmbH & Co. KG | Method for operating a power plant |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| DE10056231B4 (en) | 2000-11-13 | 2012-02-23 | Alstom Technology Ltd. | Method for operating a combined cycle power plant |
| EP1736638A1 (en) * | 2005-06-21 | 2006-12-27 | Siemens Aktiengesellschaft | Method of starting up a gas and steam turbine plant |
| CN109915221A (en) * | 2019-01-31 | 2019-06-21 | 西安西热节能技术有限公司 | A kind of internal bypass steamer dragging system and method applied to cogeneration units |
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| GB1517906A (en) * | 1976-05-13 | 1978-07-19 | Gen Electric | Combined gas turbine and steam turbine power plant |
| JPS5870008A (en) * | 1981-10-23 | 1983-04-26 | Toshiba Corp | Apparatus for controlling steam control valve of compound power plant |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3879616A (en) * | 1973-09-17 | 1975-04-22 | Gen Electric | Combined steam turbine and gas turbine power plant control system |
| JPS5870007A (en) * | 1981-10-21 | 1983-04-26 | Toshiba Corp | Apparatus for controlling combined cycle power plant |
| JPS58192908A (en) * | 1982-05-07 | 1983-11-10 | Toshiba Corp | Control device of combined cycle turbine plant |
| JPS58197408A (en) * | 1982-05-12 | 1983-11-17 | Hitachi Ltd | Starting device for combined plant |
| US4589255A (en) * | 1984-10-25 | 1986-05-20 | Westinghouse Electric Corp. | Adaptive temperature control system for the supply of steam to a steam turbine |
| JP2692973B2 (en) * | 1989-08-09 | 1997-12-17 | 株式会社東芝 | Steam cycle startup method for combined cycle plant |
-
1999
- 1999-07-30 EP EP99810689A patent/EP1072760A1/en not_active Withdrawn
-
2000
- 2000-07-28 GB GB0018754A patent/GB2352778A/en not_active Withdrawn
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB1517906A (en) * | 1976-05-13 | 1978-07-19 | Gen Electric | Combined gas turbine and steam turbine power plant |
| JPS5870008A (en) * | 1981-10-23 | 1983-04-26 | Toshiba Corp | Apparatus for controlling steam control valve of compound power plant |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JP2008534860A (en) * | 2005-04-05 | 2008-08-28 | シーメンス アクチエンゲゼルシヤフト | Start-up method of gas / steam combined turbine equipment |
| JP4818353B2 (en) * | 2005-04-05 | 2011-11-16 | シーメンス アクチエンゲゼルシヤフト | Start-up method of gas / steam combined turbine equipment |
| US11591955B2 (en) | 2018-06-22 | 2023-02-28 | Siemens Energy Global GmbH & Co. KG | Method for operating a power plant |
Also Published As
| Publication number | Publication date |
|---|---|
| EP1072760A1 (en) | 2001-01-31 |
| GB0018754D0 (en) | 2000-09-20 |
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| Date | Code | Title | Description |
|---|---|---|---|
| WAP | Application withdrawn, taken to be withdrawn or refused ** after publication under section 16(1) |