US20100132362A1 - Condensation method - Google Patents

Condensation method Download PDF

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Publication number
US20100132362A1
US20100132362A1 US12/063,175 US6317506A US2010132362A1 US 20100132362 A1 US20100132362 A1 US 20100132362A1 US 6317506 A US6317506 A US 6317506A US 2010132362 A1 US2010132362 A1 US 2010132362A1
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US
United States
Prior art keywords
condensate
condenser
condensation method
heating stage
flow
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Abandoned
Application number
US12/063,175
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English (en)
Inventor
Michael Herbermann
Raimund Witte
Heinz Wienen
Andras Mikovics
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GEA Energietchnik GmbH
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GEA Energietchnik GmbH
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
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Assigned to GEA ENERGIETECHNIK GMBH reassignment GEA ENERGIETECHNIK GMBH ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: HERBERMANN, MICHAEL, MIKOVICS, ANDRAS, WIENEN, HEINZ, WITTE, RAIMUND
Publication of US20100132362A1 publication Critical patent/US20100132362A1/en
Abandoned legal-status Critical Current

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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B9/00—Auxiliary systems, arrangements, or devices
    • F28B9/08—Auxiliary systems, arrangements, or devices for collecting and removing condensate
    • 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
    • F01K9/00—Plants characterised by condensers arranged or modified to co-operate with the engines
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B1/00—Condensers in which the steam or vapour is separate from the cooling medium by walls, e.g. surface condenser
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B1/00—Condensers in which the steam or vapour is separate from the cooling medium by walls, e.g. surface condenser
    • F28B1/06—Condensers in which the steam or vapour is separate from the cooling medium by walls, e.g. surface condenser using air or other gas as the cooling medium
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F28—HEAT EXCHANGE IN GENERAL
    • F28B—STEAM OR VAPOUR CONDENSERS
    • F28B9/00—Auxiliary systems, arrangements, or devices
    • F28B9/10—Auxiliary systems, arrangements, or devices for extracting, cooling, and removing non-condensable gases

Definitions

  • the invention relates to a condensation method according to the features set forth in the preamble of claim 1 .
  • the efficiency of a power plant is a crucial factor in relation to cost-effectiveness in particular when newly designed power plants are involved. Many efforts have thus been undertaken to optimize steam power processes in thermal power plants. Special attention is hereby directed to the condensation system.
  • the potential with respect to the power plant efficiency is not yet optimized when air-cooled condensers are involved, as oftentimes used in the event of water deficiency at the site of the power plant.
  • Air-cooled condensers have the basic drawback that the dry air temperature can be utilized only.
  • subcooling of the condensate is greater than when water-cooled surface condensers and especially small exhaust steam pressures are involved.
  • Air-cooled condensers have normally two condensation stages.
  • a first condensation stage involves a condensation of about 80-90% of exhaust steam of a turbine.
  • Process-based parameters such as, e.g., fluctuating outside temperatures, render a 100% condensation virtually impossible so that a second condensation stage for condensation of residual steam is always necessary.
  • air-cooled condensers are oftentimes combined with one other and operated in condenser mode and dephlegmator mode, with the condensation in dephlegmator mode being intended for condensation of residual steam, i.e. forming the second condensation stage.
  • the obtained condensate is typically fed directly to a condensate collector tank. Thereafter, the condensate is fed to a degasifier for addition of refined makeup feed water to replace leakage losses and for subsequent supply via a feed pump to an evaporator upstream of the turbine.
  • a degasifier for addition of refined makeup feed water to replace leakage losses and for subsequent supply via a feed pump to an evaporator upstream of the turbine.
  • the energy balance is adversely affected when the condensate has been excessively subcooled beforehand because it requires realization of increased energy supply through use of primary fuels. Efforts have thus been undertaken to keep subcooling as little as possible so as to minimize the use of primary fuels. At the same time, efforts are made to maintain a smallest possible energy amount for condensation of the turbine exhaust steam.
  • the invention is based on the object to provide a condensation method in which subcooling of the condensate is minimized to improve the power plant efficiency.
  • An essential feature of the method according to the invention resides in the heating of the condensate flow obtained in the condenser in an especially provided condensate heating stage before introduction into a condensate collector tank. Heating of the condensate flow is effected by the turbine exhaust steam within the condensate heating stage. At the same time, the partial steam flow exiting the condenser is fed to a degasifier in which the partial steam flow cools makeup feed water and fully condenses itself.
  • a condensate heating stage provided in addition to a degasifier permits the configuration according to the invention to significantly minimize condensate subcooling and thus to reduce the need for primary fuels.
  • Model computations have shown that subcooling of the condensate can be reduced from about 1-6 K as determined for an air-cooled condenser of conventional type to about 0.5 K in relation to the temperature in saturation state downstream of the turbine.
  • the power plant efficiency rises in dependence on the reduction of subcooling. When a 600 MW power plant is involved, the thermal efficiency may be improved by up to 25%, a value that should not be ignored when considering power plant dimensions.
  • the method according to the invention uses the thermal energy of the turbine exhaust steam flow significantly more efficiently as it is not released to the environment by the condensers but a major part thereof flows into the condensate, i.e. it is substantially retained in the heat cycle.
  • the reduced energy losses result in the desired improvement of the power plant efficiency.
  • part of the turbine exhaust steam flow is condensed at the same time so that less exhaust steam enters the condenser.
  • the condensers may thus be sized smaller in some circumstances.
  • the degasifier may require more heat in particular when greater amounts of refined makeup feed water are added into the material cycle.
  • the makeup feed water has normally a significantly lower temperature as the condensate, the energy balance of a condensation power plant is advantageously affected when the partial exhaust steam flow from the condenser is utilized to degasify the makeup feed water or at least to contribute thermally to degasification.
  • the heated makeup feed water from the degasifier is fed preferably also to the condensate heating stage so that the makeup feed water is heated in two stages.
  • the condensate flow from the condenser although sufficient to condense part of the turbine exhaust steam flow, a complete condensation of the partial steam flow exiting the condenser is, however, virtually impossible for reasons of the energy balance. Condensation of the partial steam flow can be absolutely ensured by a sufficient quantity of colder makeup feed water.
  • Provisions are made to contact the condensate in drop shape with the turbine exhaust steam flow in order to improve the heat transfer within the condensate heating stage.
  • This may be realized by conducting the condensate across formed bodies and causing it to contact the turbine exhaust steam flow in countercurrent flow.
  • the formed bodies may hereby be arranged in the form of a cascade.
  • the provision of a cascade-like disposition of metal sheets without use of formed bodies is, of course, also conceivable.
  • What is crucial is the optimization of the heat transfer from turbine exhaust steam flow onto the subcooled condensate.
  • the condensate can be introduced into the condensate heating stage with the aid of nozzles. Drops of subcooled condensate form condensation germs of low temperature within the condensate heating stage so that the condensation of the turbine exhaust steam flow is accelerated while the temperature of the condensate is raised in an energetically beneficial manner.
  • FIG. 1 shows a greatly simplified steam power process of a thermal power plant, having a turbine 1 for feeding turbine exhaust steam flow 2 to a condenser 3 via a line.
  • the condenser 3 involves an air-cooled condenser with heat exchanger elements 4 operated in condenser mode and heat exchanger elements 5 operating in dephlegmator mode.
  • a major part of the turbine exhaust steam flow condenses within the condenser 3 .
  • the obtained condensate K exits the condenser 3 and is fed to a condensate heating stage 6 in which the subcooled condensate K is contacting the turbine exhaust steam flow 2 .
  • the condensate K is heated so that a partial steam flow of the turbine exhaust steam flow 2 condenses before entry of the turbine exhaust steam flow K into the condenser 3 via the line 7 and is directly fed back into the material cycle as part of the condensate K 3 .
  • a degasifier 8 to which a partial steam flow T from the condenser 3 is fed.
  • the partial steam flow T is condensed by supply of colder makeup feed water W and degassed at the same time.
  • the degasifier 8 serves effectively as a downstream second condensate heating stage.
  • the condensate K from the degasifier 8 is fed to the condensate heating stage 6 in which the subcooled condensates K, K 1 are utilized to condense part of the turbine exhaust steam flow 2 .
  • FIG. 2 differs from the one in FIG. 1 primarily by the operation of the condenser 9 exclusively in dephlegmator mode. This can be seen on the steam entry at the lower peripheral area of the condenser 9 .
  • FIG. 3 illustrates the computed change of the thermal efficiency of the process (in %), plotted over the condensate subcooling (in K).
  • ⁇ th the efficiency
  • P the turbine output
  • Qin the heat input
  • ⁇ Qin the added heat for condensate heating
US12/063,175 2005-08-25 2006-06-27 Condensation method Abandoned US20100132362A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
DE102005040380.8 2005-08-25
DE102005040380A DE102005040380B3 (de) 2005-08-25 2005-08-25 Kondensationsverfahren
PCT/DE2006/001097 WO2007022738A1 (de) 2005-08-25 2006-06-27 Kondensationsverfahren

Publications (1)

Publication Number Publication Date
US20100132362A1 true US20100132362A1 (en) 2010-06-03

Family

ID=36650820

Family Applications (1)

Application Number Title Priority Date Filing Date
US12/063,175 Abandoned US20100132362A1 (en) 2005-08-25 2006-06-27 Condensation method

Country Status (18)

Country Link
US (1) US20100132362A1 (de)
EP (1) EP1917422B1 (de)
JP (1) JP4542187B2 (de)
KR (1) KR20080016628A (de)
CN (1) CN101208498A (de)
AP (1) AP2007004105A0 (de)
AT (1) ATE427413T1 (de)
AU (1) AU2006284266B2 (de)
CA (1) CA2610872A1 (de)
DE (2) DE102005040380B3 (de)
ES (1) ES2324798T3 (de)
IL (1) IL189649A0 (de)
MA (1) MA29562B1 (de)
MX (1) MX2007010783A (de)
RU (1) RU2355895C1 (de)
TN (1) TNSN07284A1 (de)
WO (1) WO2007022738A1 (de)
ZA (1) ZA200801846B (de)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20160138798A1 (en) * 2013-07-05 2016-05-19 Siemens Aktiengesellschaft Method for preheating feed water in steam power plants, with process steam outcoupling
US9951657B2 (en) 2013-11-08 2018-04-24 Siemens Aktiengesellschaft Module for condensing expelled vapors and for cooling turbine effluent

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3040528A (en) * 1959-03-22 1962-06-26 Tabor Harry Zvi Vapor turbines
US5165237A (en) * 1991-03-08 1992-11-24 Graham Corporation Method and apparatus for maintaining a required temperature differential in vacuum deaerators
US5765629A (en) * 1996-04-10 1998-06-16 Hudson Products Corporation Steam condensing apparatus with freeze-protected vent condenser
US5930998A (en) * 1995-12-29 1999-08-03 Asea Brown Boveri Ag Process and apparatus for preheating and deaeration of make-up water
US6336330B1 (en) * 1998-03-11 2002-01-08 Siemens Aktiengesellschaft Steam-turbine plant
US6746567B2 (en) * 2001-02-07 2004-06-08 3M Innovative Properties Company Microstructured surface film assembly for liquid acquisition and transport

Family Cites Families (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
DE2257369A1 (de) * 1972-11-23 1974-05-30 Deggendorfer Werft Eisenbau Kondensatoranlage
US4905474A (en) * 1988-06-13 1990-03-06 Larinoff Michael W Air-cooled vacuum steam condenser
GB2226962B (en) * 1989-01-06 1992-04-29 Birwelco Ltd Steam condensing apparatus
DE10333009B3 (de) * 2003-07-18 2004-08-19 Gea Energietechnik Gmbh Anordnung zur Kondensation von Wasserdampf
JP4155916B2 (ja) * 2003-12-11 2008-09-24 大阪瓦斯株式会社 排熱回収システム

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3040528A (en) * 1959-03-22 1962-06-26 Tabor Harry Zvi Vapor turbines
US5165237A (en) * 1991-03-08 1992-11-24 Graham Corporation Method and apparatus for maintaining a required temperature differential in vacuum deaerators
US5930998A (en) * 1995-12-29 1999-08-03 Asea Brown Boveri Ag Process and apparatus for preheating and deaeration of make-up water
US5765629A (en) * 1996-04-10 1998-06-16 Hudson Products Corporation Steam condensing apparatus with freeze-protected vent condenser
US6336330B1 (en) * 1998-03-11 2002-01-08 Siemens Aktiengesellschaft Steam-turbine plant
US6746567B2 (en) * 2001-02-07 2004-06-08 3M Innovative Properties Company Microstructured surface film assembly for liquid acquisition and transport

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20160138798A1 (en) * 2013-07-05 2016-05-19 Siemens Aktiengesellschaft Method for preheating feed water in steam power plants, with process steam outcoupling
US9890948B2 (en) * 2013-07-05 2018-02-13 Siemens Aktiengesellschaft Method for preheating feed water in steam power plants, with process steam outcoupling
US9951657B2 (en) 2013-11-08 2018-04-24 Siemens Aktiengesellschaft Module for condensing expelled vapors and for cooling turbine effluent

Also Published As

Publication number Publication date
CA2610872A1 (en) 2007-03-01
WO2007022738A1 (de) 2007-03-01
TNSN07284A1 (en) 2008-12-31
AP2007004105A0 (en) 2007-08-31
AU2006284266B2 (en) 2009-07-23
ES2324798T3 (es) 2009-08-14
ATE427413T1 (de) 2009-04-15
EP1917422B1 (de) 2009-04-01
MA29562B1 (fr) 2008-06-02
RU2355895C1 (ru) 2009-05-20
AU2006284266A1 (en) 2007-03-01
IL189649A0 (en) 2008-06-05
EP1917422A1 (de) 2008-05-07
DE502006003341D1 (de) 2009-05-14
JP2009506244A (ja) 2009-02-12
JP4542187B2 (ja) 2010-09-08
KR20080016628A (ko) 2008-02-21
MX2007010783A (es) 2007-11-07
ZA200801846B (en) 2010-06-30
CN101208498A (zh) 2008-06-25
DE102005040380B3 (de) 2006-07-27

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Owner name: GEA ENERGIETECHNIK GMBH,GERMANY

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:HERBERMANN, MICHAEL;WITTE, RAIMUND;WIENEN, HEINZ;AND OTHERS;REEL/FRAME:020477/0907

Effective date: 20070827

STCB Information on status: application discontinuation

Free format text: ABANDONED -- FAILURE TO RESPOND TO AN OFFICE ACTION