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Publication numberUS20010029732 A1
Publication typeApplication
Application numberUS 09/758,186
Publication dateOct 18, 2001
Filing dateApr 12, 2001
Priority dateJan 13, 2000
Also published asDE10001110A1, US6449954
Publication number09758186, 758186, US 2001/0029732 A1, US 2001/029732 A1, US 20010029732 A1, US 20010029732A1, US 2001029732 A1, US 2001029732A1, US-A1-20010029732, US-A1-2001029732, US2001/0029732A1, US2001/029732A1, US20010029732 A1, US20010029732A1, US2001029732 A1, US2001029732A1
InventorsRolf Bachmann
Original AssigneeRolf Bachmann
Export CitationBiBTeX, EndNote, RefMan
External Links: USPTO, USPTO Assignment, Espacenet
Process for the recovery of water from the flue gas of a combined cycle power station, and combined cycle power station for performing the process
US 20010029732 A1
Abstract
In a process for the recovery of water, which arises from the combustion of a fuel (19), particularly natural gas, in a combined cycle power station (101) comprising a gas turbine plant (11), a waste heat boiler (33), and a steam turbine (25) arranged in a water/steam circuit with the waste heat boiler (33), and/or which is added in the form of water or steam (36), the water is condensed out from the flue gas (42) arising from the combustion of the fuel (19) and containing water in the form of water vapor after flowing through the waste heat boiler (33), and is separated in liquid form, in particular by expansion in a utilization turbine (20).
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Claims(14)
1. Process for the recovery of water which arises in a combined cycle power station (10; 101, . . . ,103) comprising a gas turbine plant (11), a waste heat boiler (33), and a steam turbine (25) arranged in a water/steam circuit with the waste heat boiler (33), during the combustion of fuel (19), in particular natural gas, and/or is added in the form of water or steam (36), wherein the water is condensed out and is separated in liquid form from the flue gas (42) arising from the combustion of the fuel (19) and containing water in the form of water vapor, after passage through the waste heat boiler (33).
2. Process according to
claim 1
, wherein the flue gas (42) is expanded to condense the water out, with an output of work.
3. Process according to
claim 2
, wherein the expansion is carried out by means of a utilization turbine (20).
4. Process according to one of claims 2 and 3, wherein the waste heat boiler (33) is operated with respect to the flue gas (42) at a pressure exceeding the ambient air pressure by a few bar, preferably 2-5 bar, and wherein the flue gas (42) is brought to ambient air pressure by the subsequent expansion.
5. Process according to one of claims 2 and 3, wherein the waste heat boiler (33) is operated with respect to the flue gas (42) at about ambient air pressure, the flue gas (42) is subsequently expanded in a vacuum, and the flue gas (43) after water removal is compressed again to ambient air pressure.
6. Process according to one of claims 2-5, wherein the water is separated from the flue gas (42) during the expansion or in the utilization turbine (20) itself.
7. Process according to one of claims 2-5, wherein the water is separated from the flue gas (42) in one of the expansion or the droplet separator (23) which follows the utilization turbine (20).
8. Process according to
claim 1
, wherein the waste heat boiler (33) is operated with respect to the flue gas (42) at a pressure exceeding the ambient air pressure by in particular a few bar, preferably 2-5 bar; that the water is condensed out of the flue gas (42) after leaving the waste heat boiler on cold surfaces, in particular, the cold tubes of a heat exchanger (45), and that the dewatered flue gas (43) is brought to ambient air pressure by a subsequent expansion.
9. Process according to
claim 8
, wherein the expansion is carried out by means of a utilization turbine (20).
10. Combined cycle power station (10, . . . ,103) for carrying out the process according to
claim 1
, which combined cycle power station (101 . . . ,103) comprises a gas turbine plant (11) with a combustion chamber (15) for the combustion of the fuel (19), a waste heat boiler (33) connected to the gas turbine plant (11) for the production of steam by means of the hot flue gases (42) of the gas turbine plant (11), and a steam turbine (25) arranged together with the waste heat boiler (33) in a water/steam circuit, wherein means (20, 23, 44, 45) for the condensation of water vapor contained in the flue gas (42) and separation of the condensed water follow the waste heat boiler (33).
11. Combined cycle power station according to
claim 10
, wherein the condensation and separation means comprise means for the expansion of the flue gas (42), preferably in the form of a utilization turbine (18, 20).
12. Combined cycle power station according to
claim 11
, wherein a droplet separator (23) follows the expansion means or the utilization turbine (18, 20).
13. Combined cycle power station according to
claim 11
, wherein the expansion means comprises a utilization turbine (18) expanding into vacuum, and wherein a compressor (44) follows the utilization turbine (18).
14. Combined cycle power station according to
claim 11
, wherein condensation means, in particular in the form of a heat exchanger (45), are arranged between the waste heat boiler (33) and the expansion means or the utilization turbine (20).
Description
FIELD OF TECHNOLOGY

[0001] The present invention relates to the field of combined cycle power stations (combined plant). It relates to a process according to the preamble of claim 1 and also to a combined cycle power station for carrying out the process according to the preamble of claim 10.

STATE OF THE ART

[0002] Combined cycle power stations normally burn natural gas, which produces water vapor during combustion. 1 kg of natural gas burns to about 2 kg of water and also CO2. The flue gas with the water contained therein is usually discharged through a chimney at elevated temperatures, without the water being used to advantage. The same also holds for water or steam, which in other cases is injected or sprayed in during combustion and thus becomes a component of the flue gas. On the other hand, water already forms an increasingly valuable resource at the present time.

[0003] The simplified diagram of an exemplary combined cycle power station from the state of the art is reproduced in FIG. 1. The combined cycle power station 10 essentially comprises a gas turbine plant 11, a waste heat boiler (heat recovery steam generator HRSG) 33, and a steam turbine 25, which are connected together. The gas turbine plant 11 consists of a compressor 14 and a turbine 17, which are arranged on a rotor 16, and also a combustion chamber 15. In operation, the compressor 14 sucks in air through an air inlet 12, compresses it, and delivers the compressed air to the combustion chamber 15, where it enters combustion as combustion air, together with a liquid or gaseous fuel 19 (e.g., natural gas) which is fed in through a fuel supply duct 21. In addition, water or steam 36 can be injected or sprayed into the combustion chamber 15 to reduce the combustion temperature. The hot combustion gases are conducted from the combustion chamber 15 into the turbine 17, where they set the rotor 16 in rotation. The flue gas 42 exiting the turbine 17 is then conducted through the waste heat boiler 33 for the production of steam, where it flows in succession through a superheater 40, an evaporator 39, and a preheater (economizer) 34, and gives up heat stepwise. The cooled flue gas 42 finally leaves the waste heat boiler 33 and is usually, possibly after a flue gas cleaning, discharged from a chimney.

[0004] The superheater 40, evaporator 39 and preheater 34 are connected in series as part of a water/steam circuit, in which the steam turbine is also connected. The exhaust steam from the steam turbine 25 passes into a condenser 26 and condenses there. The condensate is pumped by a condensate pump 28, possibly with the addition of additional water 27, through a feed water duct 29 to a feed water container 30 with degasser. The degassed condensate is then pumped as feed water 32 through the preheater 34 by a boiler feed pump 31, and as pressurized feed water 35 to a steam drum 37 with the connected evaporator 39. The steam then passes to the superheater 40, where it is superheated, and finally drives the steam turbine 25 as superheated steam 41. Both the steam turbine 25 and also the gas turbine plant 11 respectively drive a generator 13 or 24 which produces electrical current. Means for the recovery of water or water vapor contained in the flue gas are not provided here.

DESCRIPTION OF THE INVENTION

[0005] The invention therefore has as its object to provide a process and also a combined cycle power station with which the water contained in the flue gas is recovered and can be advantageously reused.

[0006] The object is attained by means of the entirety of the features of claims 1 and 10. The core of the invention consists of configuring the combined cycle power station and conducting the process so that the water is condensed out of the flue gas after leaving the waste heat boiler and is separated in liquid form.

[0007] A first preferred embodiment of the process according to the invention is characterized in that the flue gas is expanded for condensing the water out, with output of work. The expansion is preferably carried out by means of a utilization turbine. In particular, the waste heat boiler is operated for this purpose at a pressure exceeding the ambient air pressure by several bar, preferably 2-5 bar, and the flue gas is brought to the ambient air pressure by the subsequent expansion. Alternatively to this, the waste heat boiler can be operated at about the ambient pressure with respect to the flue gas, the flue gas subsequently being expanded into a vacuum, and the flue gas being compressed again to ambient air pressure after the separation of water. In both cases, the water is separated from the flue gas particularly during the expansion or in the utilization turbine itself, and/or in a droplet separator following the expansion or the utilization turbine.

[0008] A second preferred embodiment of the process according to the invention is characterized in that the waste heat boiler is operated with respect to the flue gas at a pressure exceeding the ambient air pressure by several bar, preferably 2-5 bar, in that the water is condensed out of the flue gas on cold surfaces after leaving the waste heat boiler, in particular on the cold tubes of a heat exchanger, and in that the dewatered flue gas is brought to the ambient air pressure by a subsequent expansion; here also, the expansion is preferably carried out by means of a utilization turbine.

[0009] A preferred embodiment of the combined cycle power station according to the invention is distinguished in that the means for condensation and separation comprise means for the expansion of the flue gas, preferably in the form of a utilization turbine.

[0010] A first development of this embodiment is characterized in that the expansion means or the utilization turbine is followed by a droplet separator.

[0011] A second development of this embodiment is characterized in that the expansion means comprises a utilization turbine working in vacuum, and that a compressor follows the utilization turbine.

[0012] A third development of this embodiment is characterized in that condensation means, particularly in the form of a heat exchanger, is arranged between the waste heat boiler and the expansion means.

BRIEF DESCRIPTION OF THE DRAWINGS

[0013] The invention will be explained in detail hereinafter using embodiment examples in combination with the accompanying drawings.

[0014]FIG. 1 is a simplified diagram of an exemplary combined cycle power station from the state of the art, to which the invention can be applied;

[0015]FIG. 2 is a T-S [temperature-entropy] diagram illustrating the conduct of the process in a preferred embodiment example of the process according to the invention;

[0016]FIG. 3 is a diagram of a combined cycle power station comparable to FIG. 1, according to a first embodiment example of the invention, with an expansion of the flue gas to ambient air pressure;

[0017]FIG. 4 is a diagram of a combined cycle power station comparable to FIG. 1, according to a second embodiment example of the invention, with an expansion of the flue gas into vacuum and subsequent compression to ambient air pressure;

[0018]FIG. 5 is a diagram of a combined cycle power station comparable to FIG. 1, according to a third embodiment example of the invention, with an expansion of the flue gas to ambient air pressure after a preceding condensation of the water vapor.

PREFERRED EMBODIMENTS OF THE INVENTION

[0019] The basic idea of the invention can be characterized as “supercharged waste heat boiler of a combined cycle power station with water separation by way of temperature drop or partial pressure”. The idea can be explained using the T-S diagram shown in FIG. 2 of an example of the performance of the process. From the point P1 on the isobar of the ambient air pressure pA, the air sucked in by the compressor (14 in FIG. 1) is compressed along the curve a to the combustion chamber pressure (isobar PBK) and is heated in the combustion chamber at constant pressure (curve b). The gas turbine (17 in FIG. 1) in a combined plant now expands the flue gas along the curve c to a pressure pK in the waste heat boiler (33 in FIG. 1), which is at several bar, e.g., 2-5 bar, above the ambient air pressure pA. The “supercharged” waste heat boiler removes heat from the flue gas for the production of steam, and thus cools the flue gas to about 80-90° C. (curve d).

[0020] If now this flue gas is expanded (along the curve e) by means of a utilization turbine or comparable means, low temperatures arise at the point P2 after the turbine, corresponding to the pressure before the turbine. The water content of the flue gas condenses, particles which may be present in the flue gas serve as condensation nuclei. The water can then be separated in the turbine itself or in a subsequent droplet separator, and subsequently drawn off.

[0021] A combined cycle power station 101 designed for the performance of this process is reproduced in FIG. 3, which is comparable to the illustration of FIG. 1 (the same parts are given the same reference numerals). The combined cycle power station 101 of FIG. 3 differs from the combined cycle power station 10 of FIG. 1 in the flue gas sequence following the waste heat boiler 33. In the combined cycle power station 101, a utilization turbine 20 (which for example drives a generator 22) for the exiting flue gas 42 containing water vapor, and also a droplet separator 23, follow the waste heat boiler 33. The flue gas 42 under pressure is cooled in the utilization turbine 20 by expansion. The water vapor then condenses and can be removed either already at the utilization turbine 20 or in the following droplet separator 23. The “dewatered” flue gas 43 then leaves the droplet separator 23. This kind of water recovery has the following advantages:

[0022] The plant is very compact; the gas turbine can, e.g., be embodied as a variant of a standard machine without end stage;

[0023] good heat transfer coefficients are obtained in the waste heat boiler;

[0024] a chimney can be omitted, since the “dewatered” flue gas leaves the plant at low temperatures;

[0025] the “cold” of the flue gases can be further utilized, e.g., for cooling purposes or at the intake side of the gas turbine (booster).

[0026] On the other hand, a slight performance loss results, since the expansion line of the gas turbine is made smaller, and this is only partially compensated by the recuperation in the steam turbine and in the utilization turbine after the waste heat boiler. In order to remedy it, the water recovery can also be carried out in a modified form:

[0027] In an alternative manner of conducting the process, for which the combined cycle power station 102 according to FIG. 4 is designed, the waste heat boiler 33 is not “supercharged”, but operates at about atmospheric pressure. The following utilization turbine 18 (with generator 22) expands the flue gas 42 into a vacuum. After the separation of the water (H2O) in the utilization turbine 18 or in a following droplet separator 23, the “dewatered” flue gas 43 is again compressed to ambient air pressure in a compressor 44 (with a reduced flue gas mass flow).

[0028] In another alternative manner of conducting the process, for which the combined cycle power station 103 according to FIG. 5 is designed, the waste heat boiler 33—as in the combined cycle power station 101 of FIG. 3—is run “supercharged”. After leaving the waste heat boiler, the water vapor of the flue gas 42 is condensed on cold surfaces or tubes of a heat exchanger 45, making use of the high partial pressure. An expansion of the “dewatered” flue gas 43 takes place thereafter in a utilization turbine 20.

List of Reference Numbers
10, 101-103 combined cycle power station
11 gas turbine plant
12 air inlet
13, 22, 24 generator
14 compressor
15 combustion chamber
16 rotor
17 turbine
18, 20 utilization turbine
19 fuel
21 fuel supply duct
23 droplet separator
25 steam turbine
26 condenser
27 additional water
28 condensate pump
29 feed water duct
30 feed water container
31 boiler feed pump
32 feed water
33 waste heat boiler (HRSG)
34 preheater
35 pressurized feed water
36 water or steam
37 steam drum
38 saturated steam
39 evaporator
40 superheater
41 superheated steam
42 flue gas (water vapor containing)
43 flue gas (dewatered)
44 compressor
45 heat exchanger
PA ambient air pressure
PBK combustion chamber pressure
PK boiler pressure
P1, P2 point
a-e curves

Referenced by
Citing PatentFiling datePublication dateApplicantTitle
US6715916 *Feb 8, 2001Apr 6, 2004General Electric CompanySystem and method for determining gas turbine firing and combustion reference temperatures having correction for water content in fuel
US7073337 *May 30, 2003Jul 11, 2006General Electric CompanyCombined power generation and desalinization apparatus and related method
US7089727 *Jul 8, 2003Aug 15, 2006Siemens AktiengesellschaftGas turbine plant with an exhaust gas chimney
US7272932 *Dec 8, 2003Sep 25, 2007Dresser, Inc.System and method of use of expansion engine to increase overall fuel efficiency
US8317982Mar 15, 2007Nov 27, 2012Subrahmanyam KumarFGEPSC (flared, gas exhaust, pneumatic, saturation and condensation) process and system
US8495859 *Jul 24, 2012Jul 30, 2013Modine Manufacturing CompanyHeat recovery system and method
Classifications
U.S. Classification60/772, 60/39.182
International ClassificationB01D53/00, B01D5/00
Cooperative ClassificationB01D5/0039, B01D53/002
European ClassificationB01D53/00C, B01D5/00F12
Legal Events
DateCodeEventDescription
Nov 14, 2006FPExpired due to failure to pay maintenance fee
Effective date: 20060917
Sep 18, 2006LAPSLapse for failure to pay maintenance fees
Apr 5, 2006REMIMaintenance fee reminder mailed
Dec 8, 2003ASAssignment
Owner name: ALSTOM TECHNOLOGY LTD, SWITZERLAND
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:ALSTOM (SWITZERLAND) LTD;REEL/FRAME:014770/0783
Effective date: 20031101
Owner name: ALSTOM TECHNOLOGY LTD BROWN BOVERI STRASSE 7CH-540
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:ALSTOM (SWITZERLAND) LTD /AR;REEL/FRAME:014770/0783
Jun 14, 2002ASAssignment
Owner name: ALSTOM (SWITZERLAND) LTD, SWITZERLAND
Free format text: CHANGE OF NAME;ASSIGNOR:ALSTOM POWER (SCHWEIZ) AG;REEL/FRAME:012994/0787
Effective date: 20011214
Owner name: ALSTOM (SWITZERLAND) LTD BROWN BOVERI STRASSE 7 CH
Owner name: ALSTOM (SWITZERLAND) LTD BROWN BOVERI STRASSE 7CH-
Free format text: CHANGE OF NAME;ASSIGNOR:ALSTOM POWER (SCHWEIZ) AG /AR;REEL/FRAME:012994/0787
Apr 12, 2001ASAssignment
Owner name: ALSTOM POWER (SCHWEIZ) AG, SWITZERLAND
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:BACHMANN, ROLF;REEL/FRAME:011733/0628
Effective date: 20010403
Owner name: ALSTOM POWER (SCHWEIZ) AG HASELSTRASSE 16 CH-5400
Owner name: ALSTOM POWER (SCHWEIZ) AG HASELSTRASSE 16CH-5400 B
Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:BACHMANN, ROLF /AR;REEL/FRAME:011733/0628