Combined cycle electric power plant having a control system which enables dry steam generator operation during gas turbine operation

• US 3,953,966 A
• Filed: 08/08/1974
• Issued: 05/04/1976
• Est. Priority Date: 08/08/1974
• Status: Expired due to Term

• Current Assignee: Westinghouse Electric Company LLC (Brookfield Asset Management Incorporated)
• Original Assignee: Westinghouse Electric Company LLC (Brookfield Asset Management Incorporated)
• Inventors: Martz, Lyle F., Plotnick, Richard J.
• Primary Examiner(s): Ostrager, Allen M.
• Application Number:
  US05/495,765
• Time in Patent Office: 635 Days
• Field of Search: 60/39.02, 60/39.03, 60/39.18 R, 60/39.18 B
• US Class Current: 60/783
• CPC Class Codes: F01K 13/02 Controlling, e.g. stopping or starting
• CPC Class Codes: F01K 23/108 Regulating means specially adapted therefor
• CPC Class Codes: Y02E 20/16 Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
• CPC Class Codes: Y02P 80/15 On-site combined power, heat or cool generation or distribution, e.g. combined heat and power [CHP] supply

Abstract

A combined cycle electric power plant includes gas and steam turbines and a steam generator for recovering the heat in the exhaust gases exited from the gas turbine and for using the recovered heat to produce and supply steam to the steam turbine. A condenser is associated with the steam turbine for converting the spent steam from the steam turbine into condensate to be supplied to the steam generator. The steam generator includes a low pressure storage tank, a first heat exchange tube, a boiler feedwater pump for directing fluid from the low pressure storage tank through the first heat exchange tube, a main storage drum, a second heat exchange tube, and a high pressure recirculation pump for directing water from the main storage drum through the second heat exchange tube. An afterburner further heats the exhaust gas turbine gases passed to the first and second heat exchange tubes. Method and apparatus are provided for controlling the transfer of the operation of the steam generator from a WET mode of operation to a DRY mode of operation. In particular, the heat supplied to the gas turbine exhaust gases is reduced, the fluid introduced into the steam generator is cut off, a blowdown valve for directing fluid from the steam generator is opened to further drain fluid therefrom, heat is continued to be supplied to the first and second heat exchange tubes whereby steam is continued to be generated within said generator and directed to the steam turbine, and finally the outlets associated with the steam generator are closed and the steam generator is filled with a suitable non-corrosive fluid such as nitrogen gas.

Claims

1. A method of operating a heat recovery steam generator of a combined cycle electric power plant, wherein said heat recovery steam generator is transferred from a first, steam generating mode of operation to a second, dry mode of operation, said combined cycle electric power plant comprising at least one gas turbine including an exit through which heated exhaust gases pass, said heat recovery steam generator being coupled to said gas turbine exit for transferring heat from the exhaust gases to a fluid passing through said heat recovery steam generator, a steam turbine coupled to receive superheated steam generated by said heat recovery steam generator, a first electric generator coupled to said gas turbine and driven thereby, a second electric generator coupled to said steam turbine and driven thereby, an afterburner for supplying additional heat to the exhaust gases passing from said gas turbine to said heat recovery steam generator, valve means for controlling the flow of fuel to said afterburner, condenser means for receiving and converting the spent steam from said steam turbine into condensate, first valve means for controlling the flow of condensate fluid to said heat recovery steam generator, second value means for controlling the flow of superheated steam to said steam turbine, said heat recovery steam generator comprising a low pressure storage tank, a first heat exchange tube, a boiler feedwater pump for supplying fluid from said low pressure storage tank to said first heat exchange tube, a main storage drum for receiving and storing water from said first heat exchange tube, a second heat exchange tube, and a high pressure pump for directing water from said main storage drum through said second heat exchange tube, said aforementioned elements of said heat recovery steam generator being interconnected to form a fluid flow path from said first to said second valve means, said method comprising the steps of:

a. closing said first valve means to terminate the flow of condensate from said condenser to said heat recovery steam generator, while maintaining said second valve means open;

b. reducing the load demand signal applied to said gas turbine to a point sufficient so that the temperature of the exhaust gas turbine gases directed to said heat recovery steam generator does not exceed a predetermined maximum limit;

c. operating said heat recovery steam generator to generate steam therefrom as by the transfer of heat from the exhaust gas turbine gases to the fluid previously circulated thereto and directing the generated steam through said opened second valve means from said heat recovery steam generator, while extracting fluid from said low pressure storage tank, said main storage drum and said first and second heat exchange tubes; and

d. closing said second valve means, thus terminating the flow of superheated steam from said heat recovery steam generator, while containuing to operate said gas turbine at reduced load levels.

2. The method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator further includes a blowdown conduit and a blowdown valve by which fluid may be extracted from said heat recovery steam generator, and wherein said method comprises the further step of opening said blowdown valve to extract fluid from said heat recovery steam generator.

3. The method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator includes a fuel supply valve means whereby fuel may be regulated to said afterburner, and wherein after step (b), said afterburner valve is closed.

4. The method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator includes a feed system for injecting corrosion inhibiting substances into the fluid directed through said heat recovery steam generator, and where, in said method before step (c), the supply of inhibiting substances from said feed system is terminated.

5. A method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator includes a steam extraction conduit interconnecting said steam turbine and said low pressure storage tank, and a valve for controlling the flow of extraction steam from said steam turbine to said low pressure storage tank, and where, in said method before step (c), said extraction steam control valve is closed.

6. The method as claimed in claim 1, wherein during step (c), the fluid level of said low pressure storage tank is measured and compared with a predetermined minimum limit thereof, and as the fluid is being drained from said low pressure storage tank, deactivating said boiler feed pump when the fluid level within said low pressure storage tank is less than the predetermined minimum limit.

7. The method of operating a heat recovery steam generator as claimed in claim 6, wherein said heat recovery steam generator further includes a deaerator, a third heat exchange tube for directing fluid from said low pressure storage tank to said deaerator, and a low pressure circulation pump, and wherein said method further comprises the step of closing said low pressure circulation valve.

8. The method as claimed in claim 6, wherein during step (c), said high pressure circulation pump means continues to run, and there is included the step of sensing the fluid level within said main drum and upon sensing a fluid level therein below a predetermined minimum limit, deactuating said high pressure circulation pump.

9. The method of controlling said heat recovery steam generator as claimed in claim 8, wherein said heat recovery steam generator further includes a seal chamber for said high pressure circulation pump means, and wherein said method comprises the step of measuring the temperature within said seal chamber and upon exceeding a predetermined maximum limit, deactuating said high pressure circulating pump.

10. The method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator includes a bypass conduit from said heat recovery steam generator to said condenser and a bypass control valve, and wherein said method further comprises the step of measuring the flow of steam to said steam turbine and upon sensing a steam flow less than a predetermined minimum limit, opening said bypass control valve to permit the flow of superheated steam directly to said condenser.

11. The method of operating a heat recovery steam generator as claimed in claim 10, wherein upon sensing a steam flow less than the predetermined minimum, closing said second valve means.

12. The method of operating a heat recovery steam generator as claimed in claim 1, wherein there is further included the step of measuring the steam flow to said steam generator and upon sensing a steam flow less than a predetermined minimum, closing said second valve means.

13. The method of operating a heat recovery steam generator as claimed in claim 1, wherein said heat recovery steam generator includes a blowdown conduit and a blowdown control valve wherein for regulating the flow of fluid from said heat recovery steam generator, and wherein said method includes the step of measuring the pressure within said heat recovery steam generator and upon detecting a pressure less than a predetermined minimum closing said blowdown valve.

14. The method of operating a heat recovery steam generator as claimed in claim 13, wherein said heat recovery steam generator includes a deaerator vent, and wherein said method comprises the step of, upon sensing pressure within said main storage drum less than a predetermined minimum limit, closing said blowdown valve.

15. The method of operating a heat recovery steam generator as claimed in claim 13, wherein said heat recovery steam generator further includes a supply of non-corroding fluid, and wherein said method comprises the step of, upon sensing a pressure within said heat recovery steam generator les than a predetermined minimum, introducing the non-corroding fluid into said heat recovery steam generator.

16. The method as claimed in claim 15, wherein the non-corroding fluid comprises nitrogen.

17. The method of operating a heat recovery steam generator as claimed in claim 15, wherein said heat recovery steam generator includes a bypass conduit from said heat recovery steam generator to said steam turbine and a bypass flow control valve therein, and wherein said method comprises the step of, upon sensing a fluid pressure within said heat recovery steam generator below the predetermined minimum limit, closing said bypass valve control means.

18. The method of operating a heat recovery steam generator as claimed in claim 1, wherein there is further included the step of measuring the temperature of the exhaust gas turbine gases as supplied to said heat recovery steam generator and upon sensing such a temperature in excess of a predetermined maximum limit, removing said gas turbine from operation.

19. The method of operating said heat recovery steam generator as claimed in claim 18, wherein said heat recovery steam generator includes a duct interconnecting said gas turbine and said heat recovery steam generator, and wherein said method includes the step of measuring the pressure within said duct and upon sensing such a pressure above a predetermined maximum limit, causing said gas turbine to be removed from service.

20. The method of operating a heat recovery steam generator as claimed in claim 18, wherein said heat recovery steam generator includes a stack cover disposable to a first position to close an opening within the topmost portion of said heat recovery steam generator and to a second position for permitting the flow of the gas turbine exhaust gases through said opening, and wherein said method further includes the step of determining whether said stack cover is closed and if so, removing said gas turbine from service.

21. A method of operating a combined cycle electric power plant comprising a heat recovery steam generator, wherein said heat recovery system generator is transferred from a first, steam generating mode of operation to a second, dry mode of operation, said combined cycle electric power plant further comprising at least one gas turbine including an exit through which heated exhaust gases pass to said heat recovery steam generator, a steam turbine coupled to said heat recovery steam generator and driven by the steam supply therefrom, means for generating electric power by the driving power of said turbines, said heat recovery steam generator having inlets for permitting the flow of fluid from said steam turbine thereto and outlets for permitting the flow of fluid to said steam turbine, said method comprising the steps of:

a. reducing the heat supplied to the gas turbine exhaust gases as directed to said heat recovery steam generator;

b. closing the fluid inlets to said heat recovery steam generator;

c. continuing to supply heat to said gas turbine exhaust gases whereby steam is continued to be generated by said heat recovery steam generator; and

d. closing said outlets of said heat recovery steam generator.

22. The method of operating a combined cycle power plant as claimed in claim 21, wherein said plant includes a blowdown conduit and a blowdown control valve, and where, in said method after step (b), said blowdown valve is opened to permit further draining of the fluid from said heat recovery steam generator.

23. The method of operating a combined cycle power plant as claimed in claim 21, wherein said plant further includes a supply of non-corroding fluid, and where, in said method after step (d), permitting a flow of the non-corrosive fluid from said supply into said heat recovery steam generator.

24. A control system for a combined cycle electric power plant comprising at least one gas turbine including an exit through which heated exhaust gases pass, means for generating steam coupled to said gas turbine exit for transferring heat from the exhaust gases to a fluid passing through said steam generating means, a steam turbine coupled to said steam generating means and driven by the steam supplied thereby, means for generating electric power by the driving power of said turbines, condenser means for receiving and converting the spent steam from said steam turbine into condensate, and said steam generating means comprising a low pressure storage tank, a first heat exchange tube, a boiler feedwater pump for directing fluid from said low pressure storage tank through said first heat exchange tube, a main storage drum, a second heat exchange tube, and a high pressure recirculation pump for directing fluid from said main storage pump through said second heat exchange tube, said control system comprising:

monitoring means for measuring the temperature of the exhaust gas turbine gases as directed to said steam generating means and responsive to such a temperature above a predetermined level, for deactuating said steam turbine.

25. The control system for a combined cycle electric power plant as claimed in claim 24, wherein said steam generating means includes a duct to direct the gas turbine exhaust gases from said gas turbine to said steam generating means, and wherein said control system further comprises said monitoring means including further means for measuring the pressure within said duct and responsive to such a pressure above a predetermined limit, for deactuating the operation of said gas turbine.

26. The control system for a combined cycle electric power plant as claimed in claim 24, wherein said steam generating means includes a stack cover for selectively opening and closing an opening in a top portion of said steam generating means,

27. The control system for a combined cycle electric power plant as claimed in claim 24, wherein said monitoring means includes means for measuring the fluid level within said lower pressure storage tank and responsive to such a measurement below a predetermined level, for deactuating the operation of said boiler feedwater pump.

28. The control system for a combined cycle electric power plant as claimed in claim 24, wherein said monitoring means includes means for measuring the fluid level within said main storage drum and responsive to a measurement thereof below a predetermined minimum limit, or deactuating the operation of said high pressure recirculation pump.

29. A combined cycle electric power plant comprising:

a. at least one gas turbine including an exit through which heated exhaust gases pass;

b. means for generating steam coupled to said gas turbine exit for transferring heat from the exhaust gases to a fluid passing through said steam generating means;

c. a steam turbine coupled to said steam generating means and driven by the steam supplied thereby;

d. means for generating electric power by the driving power of said turbines;

e. condenser means for receiving and converting the spent steam from said steam turbine into condensate;

f. said steam generating means comprising a low pressure storage tank, a first heat exchange tube, a boiler feedwater pump for directing fluid from said low pressure storage tank through said first heat exchange tube, a main storage drum, a second heat exchange tube, and a high pressure recirculation pump for directing fluid from said main storage pump through said second heat exchange tube; and

g. control means for transferring the operation of said steam generating means from a wet to a dry mode of operation, said transfer control means comprising means for measuring the temperature of the exhaust gas turbine gases as directed to said steam generating means and responsive to a temperature above a predetermined level, for deactuating said steam turbine.

30. The combined cycle electric power plant as claimed in claim 29, wherein said power plant comprises a duct to direct the gas turbine exhaust gases from said gas turbine to said steam generating means, and said control means includes means for measuring the pressure within said duct and responsive to such a pressure above a predetermined limit, for deactuating the operation of said gas turbine.

31. The combined cycle electric power plant as claimed in claim 29, wherein said steam generating means comprises a louvre for selectively opening and closing an opening in a top portion of said steam generating means, and said control means comprises means for detecting that said louvre is not fully open and reponsive thereto for deactuating said gas turbine.

32. The combined cycle electric power plant as claimed in claim 29, wherein said control means includes means for measuring the fluid level within said low pressure storage tank and responsive to such a measurement below a predetermined level, for deactuating the operation of said boiler feedwater pump.

33. The combined cycle electric power plant as claimed in claim 29, wherein said control means includes means for measuring the fluid level within said main storage drum and responsive to a measurement thereof below a predetermined minimum limit, for deactuating the operation of said high pressure recirculation pump.