US20140033716A1 - Steam turbine plant, control method of same, and control system of same - Google Patents

Steam turbine plant, control method of same, and control system of same Download PDF

Info

Publication number
US20140033716A1
US20140033716A1 US13/944,214 US201313944214A US2014033716A1 US 20140033716 A1 US20140033716 A1 US 20140033716A1 US 201313944214 A US201313944214 A US 201313944214A US 2014033716 A1 US2014033716 A1 US 2014033716A1
Authority
US
United States
Prior art keywords
steam
turbine
pressure
pipe
exhausted
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
US13/944,214
Other languages
English (en)
Inventor
Shinsuke ITOU
Masahiko Sanada
Norihide Egami
Kensuke Suzuki
Kiyohiko Iwasa
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Toshiba Corp
Original Assignee
Toshiba Corp
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
Application filed by Toshiba Corp filed Critical Toshiba Corp
Assigned to KABUSHIKI KAISHA TOSHIBA reassignment KABUSHIKI KAISHA TOSHIBA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: EGAMI, NORIHIDE, ITOU, SHINSUKE, IWASA, KIYOHIKO, SANADA, MASAHIKO, SUZUKI, KENSUKE
Publication of US20140033716A1 publication Critical patent/US20140033716A1/en
Abandoned legal-status Critical Current

Links

Images

Classifications

    • 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
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/02—Controlling, e.g. stopping or starting
    • 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
    • F01K17/00—Using steam or condensate extracted or exhausted from steam engine plant
    • 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
    • F01K17/00—Using steam or condensate extracted or exhausted from steam engine plant
    • F01K17/02—Using steam or condensate extracted or exhausted from steam engine plant for heating purposes, e.g. industrial, domestic
    • 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
    • F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
    • F01K7/16—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
    • F01K7/22—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type the turbines having inter-stage steam heating
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B37/00—Component parts or details of steam boilers
    • F22B37/008—Adaptations for flue gas purification in steam generators
    • 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
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2
    • 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
    • Y02E20/32—Direct CO2 mitigation

Definitions

  • Embodiments described herein relate to a steam turbine plant, a control method of the same, and a control system of the same.
  • a steam turbine plant such as a thermal power plant has often included a carbon dioxide capturing system for capturing carbon dioxide in a flue gas.
  • the carbon dioxide capturing system includes a reboiler configured to heat an absorbing liquid which has absorbed the carbon dioxide with steam from the plant to cause the absorbing liquid to release the carbon dioxide.
  • a reboiler configured to heat an absorbing liquid which has absorbed the carbon dioxide with steam from the plant to cause the absorbing liquid to release the carbon dioxide.
  • FIG. 1 is a schematic view showing a configuration of a steam turbine plant of a first embodiment
  • FIG. 2 is a schematic view showing a configuration of a carbon dioxide capturing system of the first embodiment
  • FIG. 3 is a schematic view showing a configuration of a steam turbine plant of a modification of the first embodiment
  • FIG. 4 is a schematic view showing a configuration of a steam turbine plant of a second embodiment.
  • FIGS. 5 to 7 are schematic views showing configurations of steam turbine plants of modifications of the second embodiment
  • FIGS. 1 to 7 show only major facilities and do not show ancillary facilities.
  • a steam turbine plant in one embodiment, includes a boiler configured to heat water to change the water into steam, a first turbine configured to be driven by the steam from the boiler, a reheater configured to heat the steam exhausted from the first turbine, a second turbine configured to driven by the steam from the reheater, and a third turbine configured to driven by the steam exhausted from the second turbine.
  • the plant further includes a carbon dioxide capturing system including an absorbing tower configured to cause an absorbing liquid to absorb carbon dioxide, a regeneration tower configured to cause the absorbing liquid to release the carbon dioxide, and a reboiler configured to heat the absorbing liquid with heat of the steam exhausted or extracted from the second turbine.
  • the plant further includes a steam pipe configured to feed the steam exhausted from the second turbine to the third turbine, and a first steam extraction pipe configured to send the steam exhausted or extracted from the second turbine to the reboiler.
  • the plant further includes a pressure detector configured to detect a pressure of the steam flowing through the steam pipe or the first steam extraction pipe, a pressure adjustment valve provided on the steam pipe, and a controller configured to control the pressure adjustment valve based on the pressure detected by the pressure detector.
  • FIG. 1 is a schematic view showing a configuration of a steam turbine plant of a first embodiment.
  • the steam turbine plant of FIG. 1 includes a boiler 1 , a reheater 2 , a high-pressure turbine 3 as an example of a first turbine, an intermediate-pressure turbine 4 as an example of a second turbine, a low-pressure turbine 5 as an example of a third turbine, a power generator 6 , a condenser 7 , high-pressure feed water heaters 8 , low-pressure feed water heaters 9 , and a deaerator 10 .
  • the boiler 1 heats water to change the water into steam, and the high-pressure turbine 3 is driven by the steam from the boiler 1 .
  • the steam exhausted from the high-pressure turbine 3 is heated by the reheater 2 , and the intermediate-pressure turbine 4 is driven by the steam from the reheater 2 .
  • the low-pressure turbine 5 is driven by the steam exhausted from the intermediate-pressure turbine 4 .
  • the power generator 6 generates power by the rotation of a rotation shaft to which the high-pressure turbine 3 , the intermediate-pressure turbine 4 , and the low-pressure turbine 5 are attached.
  • the steam exhausted from the low-pressure turbine 5 is condensed by the condenser 7 so as to be condensed water.
  • the condensed water exhausted from the condenser 7 is heated while passing through the low-pressure feed water heaters 9 , the deaerator 10 , and the high-pressure feed water heaters 8 , and is then introduced to the boiler 1 again to be changed into the steam.
  • the high-pressure feed water heaters 8 heat of the steam exhausted and extracted from the high-pressure turbine 3 is used.
  • heat of the steam exhausted from the intermediate-pressure turbine 4 is used.
  • the steam turbine plant of FIG. 1 further includes a steam pipe 11 , a control system 12 , an intermediate-pressure steam extraction pipe 21 as an example of a first steam extraction pipe, a carbon dioxide capturing system 22 , and a boiler feed water pump turbine 23 .
  • the steam exhausted from the intermediate-pressure turbine 4 is fed to the low-pressure turbine 5 through the steam pipe 11 , and is sent to the deaerator 10 , the carbon dioxide capturing system 22 , and the boiler feed water pump turbine 23 through the intermediate-pressure steam extraction pipe 21 .
  • the control system 12 is connected to the steam pipe 11 , and includes a pressure detector 13 , a pressure adjustment valve 14 , and a controller 15 . Details of the control system 12 will be described later.
  • the intermediate-pressure steam extraction pipe 21 includes a pipe 21 a connecting the intermediate-pressure turbine 4 and the deaerator 10 , a pipe 21 b branched from the pipe 21 a and connected to the carbon dioxide capturing system 22 , and a pipe 21 c branched from the pipe 21 a and connected to the boiler feed water pump turbine 23 .
  • the steam fed to the carbon dioxide capturing system 22 is sent to the deaerator 10 after heat of the steam is used.
  • the steam fed to the boiler feed water pump turbine 23 is used for driving the turbine 23 , and is then collected in the condenser 7 .
  • FIG. 2 is a schematic view showing a configuration of the carbon dioxide capturing system 22 of the first embodiment.
  • the carbon dioxide capturing system 22 includes an absorbing tower 101 , a flue gas introduction port 102 , a rich liquid circulation pump 103 , a heat exchanger 104 , a regeneration tower 105 , a reboiler 106 , a lean liquid circulation pump 107 , a regeneration tower condenser 108 , a gas-liquid separator 109 , and a carbon dioxide capturing apparatus 110 .
  • the reference sign 111 denotes an absorbing liquid circulated in the system 22 .
  • the absorbing tower 101 includes the flue gas introduction port 102 for introducing a flue gas exhausted from the boiler 1 and the reheater 2 .
  • the absorbing tower 101 brings this flue gas and the absorbing liquid 111 into gas-liquid contact with each other, so that carbon dioxide in the flue gas is absorbed into the absorbing liquid 111 .
  • the absorbing liquid (rich liquid) 111 which has absorbed the carbon dioxide is exhausted from a lower part of the absorbing tower 101 and sent to the regeneration tower 105 by the rich liquid circulation pump 103 via the heat exchanger 104 .
  • the flue gas from which the carbon dioxide is removed is emitted to the atmosphere from an upper part of the absorbing tower 101 .
  • the absorbing liquid 111 introduced into the regeneration tower 105 is circulated between the regeneration tower 105 and the reboiler 106 .
  • the reboiler 106 heats the absorbing liquid 111 with the heat of the steam from the pipe 21 b .
  • a water vapor and a carbon dioxide gas are generated from the absorbing liquid 111 , and these gases are returned into the regeneration tower 105 together with the absorbing liquid 111 .
  • the regeneration tower 105 causes the absorbing liquid 111 to release the carbon dioxide gas to regenerate the absorbing liquid 111 .
  • the absorbing liquid (lean liquid) 111 regenerated in the regeneration tower 105 is exhausted from a lower part of the regeneration tower 105 and returned to the absorbing tower 101 again by the lean liquid circulation pump 107 via the heat exchanger 104 .
  • the low-temperature rich liquid is heated by heat of the high-temperature lean liquid.
  • the steam fed from the pipe 21 b and used in the reboiler 106 is fed to the deaerator 10 so as to serve as part of feed water heading to the boiler 1 .
  • the carbon dioxide gas generated in the regeneration tower 105 is exhausted from an upper part of the regeneration tower 105 together with the water vapor generated in the regeneration tower 105 .
  • the carbon dioxide gas is captured by the carbon dioxide capturing apparatus 110 .
  • the carbon dioxide capturing apparatus 110 includes, for example, a compressing and capturing machine which compresses and captures the carbon dioxide gas.
  • the condensed water separated in the gas-liquid separator 109 is returned to the regeneration tower 105 .
  • the absorbing liquid 111 may be any liquid as long as the liquid is capable of absorbing carbon dioxide and releasing the absorbed carbon dioxide under a predetermined condition.
  • An example of the absorbing liquid 111 includes an amine aqueous solution.
  • a specific example of the amine aqueous solution includes an aqueous solution containing one or more types of alkanolamines such as monoethanolamine, diethanolamine, triethanolamine, methyldiethanolamine, diisopropanolamine, and diglycolamine.
  • control system 12 is connected to the steam pipe 11 which feeds the steam exhausted from the intermediate-pressure turbine 4 to the low-pressure turbine 5 , and includes the pressure detector 13 , the pressure adjustment valve 14 , and the controller 15 .
  • the pressure detector 13 is connected to the steam pipe 11 and detects the pressure of the steam flowing through the steam pipe 11 .
  • the detected value of the pressure by the pressure detector 13 is supplied to the controller 15 .
  • the pressure adjustment valve 14 is a valve provided on the steam pipe 11 for adjusting the pressure of the steam flowing through the steam pipe 11 .
  • the controller 15 controls the pressure adjustment valve 14 based on the detected value of the pressure supplied from the pressure detector 13 so as to adjust the pressure of the steam flowing through the steam pipe 11 .
  • an outlet steam pressure of the intermediate-pressure turbine 4 i.e., a pressure of the steam flowing through the steam pipe 11 and the intermediate-pressure steam extraction pipe 21
  • a load change of the plant i.e., a pressure of the steam flowing through the steam pipe 11 and the intermediate-pressure steam extraction pipe 21
  • the carbon dioxide capturing system 22 there is a need for stabilizing the pressure of the steam fed to the reboiler 106 of the carbon dioxide capturing system 22 . Therefore, there is a need for stabilizing the outlet steam pressure of the intermediate-pressure turbine 4 .
  • the outlet steam pressure of the intermediate-pressure turbine 4 is detected by the pressure detector 13 . Furthermore, the pressure adjustment valve 14 is controlled based on this pressure. Thereby, the outlet steam pressure of the intermediate-pressure turbine 4 can be stabilized even in the partial load operation. Therefore, according to the present embodiment, an operation of the carbon dioxide capturing system 22 can be stably continued.
  • the controller 15 of the present embodiment controls the pressure adjustment valve 14 so that the outlet steam pressure of the intermediate-pressure turbine 4 becomes a pressure which is suitable for the operation of the carbon dioxide capturing system 22 .
  • the controller 15 controls the pressure adjustment valve 14 so that the detected value of the pressure by the pressure detector 13 is maintained to be a constant value or within a constant range.
  • this constant value or the constant range is the pressure which is suitable for the operation of the carbon dioxide capturing system 22 , a favorable operation of the carbon dioxide capturing system 22 can be continued.
  • An example of the constant value is 490 kPa for example, and an example of the constant range is 480 to 500 kPa for example.
  • FIG. 3 is a schematic view showing a configuration of a steam turbine plant of a modification of the first embodiment. According to this modification, the pressure adjustment valve 14 can be controlled based on the outlet steam pressure of the intermediate-pressure turbine 4 as similarly to the case of FIG. 1 .
  • the present embodiment detects the pressure of the steam flowing through the steam pipe 11 or the intermediate-pressure steam extraction pipe 21 , and controls the pressure adjustment valve 14 based on this pressure. Therefore, according to the present embodiment, the pressure of the steam fed to the reboiler 106 of the carbon dioxide capturing system 22 can be stabilized even in the partial load operation. Furthermore, according to the present embodiment, such stabilization of the pressure can be realized not with a large configuration such as a separately-placed turbine and a separately-placed generator but with a simple configuration such as the pressure detector 13 , the pressure adjustment valve 14 , and the controller 15 .
  • FIG. 4 is a schematic view showing a configuration of a steam turbine plant of a second embodiment.
  • the reference signs 31 , 32 denote high-pressure steam extraction pipes for sending the steam from the high-pressure turbine 3 to the high-pressure feed water heaters 8 and the reheater 2 .
  • the former high-pressure steam extraction pipe 31 sends the steam exhausted from an outlet of the high-pressure turbine 3 to the high-pressure feed water heater 8 and the reheater 2 .
  • the latter high-pressure steam extraction pipe 32 sends the steam extracted from an extraction port in a middle stage of the high-pressure turbine 3 to the high-pressure feed water heater 8 .
  • the high-pressure steam extraction pipe includes a pipe 31 a branched in the middle from the high-pressure turbine 3 toward the high-pressure feed water heater 8 .
  • the pipe 31 a is connected to the carbon dioxide capturing system 22 as well as the pipe 21 b. Therefore, the steam exhausted from the high-pressure turbine 3 is sent not only to the high-pressure feed water heaters 8 and the reheater 2 but also to the carbon dioxide capturing system 22 .
  • the high-pressure steam extraction pipe 31 of FIG. 4 is an example of a second steam extraction pipe.
  • the pipe 31 a is connected to the reboiler 106 of the carbon dioxide capturing system 22 as well as the pipe 21 b.
  • the steam turbine plant of FIG. 4 includes a first switching valve 41 provided on the pipe 21 b, and a second switching valve 42 provided on the pipe 31 a in addition to the components shown in FIG. 1 . Opening and closing of the switching valves 41 , 42 and an opening degree of the switching valves 41 , 42 are controlled by the controller 15 .
  • the first and second switching valves 41 , 42 are examples of first and second valves, respectively.
  • outlet steam of the low-pressure turbine 5 is desirably wet steam of several percent.
  • a minimum load for feeding the steam from the outlet of the intermediate-pressure turbine 4 to the carbon dioxide capturing system 22 is set to be such a load that the exhausted steam of the low-pressure turbine 5 is not in an excessively dry range. This minimum load is called as a limit value of a generator load.
  • the controller 15 controls the pressure adjustment valve 14 so that the outlet steam pressure of the intermediate-pressure turbine 4 is maintained constant or within a constant range.
  • the controller 15 controls the first and second switching valves 41 , 42 so as to close the steam sending from the intermediate-pressure turbine 4 via the first switching valve 41 , open the steam sending from the high-pressure turbine 3 via the second switching valve 42 , and fully open the pressure adjustment valve 14 .
  • the steam sending from the high-pressure turbine 3 via the second switching valve 42 is controlled by a pressure adjustment valve (not shown) and fed to the carbon dioxide capturing system 22 .
  • a condition to determine which of the switching valves 41 , 42 is brought into an opened state in accordance with an extent of the generator load may be set in any ways. For example, in order to surely avoid a situation that the outlet steam of the low-pressure turbine 5 becomes dry steam, a switching valve which is selected from the switching valves 41 , 42 to be brought into an opened state may be switched while the generator load is sufficiently high.
  • the limit value of the generator load can be calculated, for example, by measuring a temperature or a pressure of the outlet steam of the low-pressure turbine 5 as well as it is set to be a preliminarily fixed value.
  • the limit value can also be calculated, for example, by measuring a pressure or a temperature of the outlet steam of the high-pressure turbine 3 or the intermediate-pressure turbine 4 and the pressure of the outlet steam of the low-pressure turbine 5 and converting this measurement result into the temperature of the outlet steam of the low-pressure turbine 5 .
  • a temperature measurement instrument or a pressure measurement instrument which measures the temperatures or the pressures is installed and the limit value is calculated for example by the controller 15 .
  • FIGS. 5 to 7 are schematic views showing configurations of steam turbine plants of modifications of the second embodiment.
  • the high-pressure steam extraction pipe 32 includes a pipe 32 a branched in the middle from the high-pressure turbine 3 toward the high-pressure feed water heater 8 , and this pipe 32 a is connected to the carbon dioxide capturing system 22 . Therefore, in FIG. 5 , the steam extracted from the high-pressure turbine 3 is sent to the carbon dioxide capturing system 22 .
  • the high-pressure steam extraction pipe 32 of FIG. 5 is an example of the second steam extraction pipe, as well as the high-pressure steam extraction pipe 31 of FIG. 4 .
  • feeding the extracted steam from the high-pressure turbine 3 to the carbon dioxide capturing system 22 has an advantage that higher-pressure steam can be fed in comparison to a case where the exhausted steam is fed.
  • feeding the exhausted steam from the high-pressure turbine 3 to the carbon dioxide capturing system 22 has an advantage that turbine efficiency of the high-pressure turbine 3 becomes higher in comparison to a case where the extracted steam is fed.
  • the intermediate-pressure steam extraction pipe sends not the steam exhausted from the outlet of the intermediate-pressure turbine 4 but the steam extracted from an extraction port in the middle step of the intermediate-pressure turbine 4 .
  • the pressure of the steam flowing through the intermediate-pressure steam extraction pipe 21 becomes a higher pressure than the pressure of the steam flowing through the steam pipe 11 . Therefore, the pressure detector 13 detects the pressure of the steam flowing through the intermediate-pressure steam extraction pipe 21 more desirably than the pressure of the steam flowing through the steam pipe 11 .
  • the high-pressure steam extraction pipe 31 includes the pipe 31 a branched in the middle from the high-pressure turbine 3 toward the high-pressure feed water heater 8
  • the high-pressure steam extraction pipe 32 includes a pipe 32 a branched in the middle from the high-pressure turbine 3 toward the high-pressure feed water heater 8 .
  • the pipe 31 a is connected to the carbon dioxide capturing system 22 . Therefore, in FIG. 7 , the steam exhausted from the high-pressure turbine 3 is sent to the carbon dioxide capturing system 22 .
  • the second switching valve 42 in which the opening and closing and the opening degree are controlled by the controller 15 is provided on the pipe 31 a.
  • the high-pressure steam extraction pipe 31 of FIG. 7 is an example of the second steam extraction pipe, as well as the high-pressure steam extraction pipe 31 of FIG. 4 .
  • the pipe 21 b and the pipe 32 a are connected to the carbon dioxide capturing system 22 via a steam ejector 51 .
  • the steam ejector 51 can mix the steam extracted from the high-pressure turbine 3 and the steam exhausted from the intermediate-pressure turbine 4 to send the mixed steam to the carbon dioxide capturing system 22 .
  • the steam ejector 51 can boost the pressure by mixing it with the extracted steam from the high-pressure turbine 3 .
  • First and third switching valves 41 , 43 in which opening and closing and an opening degree are controlled by the controller 15 are provided on the pipes 21 b, 32 a, respectively.
  • the high-pressure steam extraction pipe 32 of FIG. 7 is an example of a third steam extraction pipe.
  • the intermediate-pressure steam extraction pipe 21 of FIG. 7 may send not the steam exhausted from the outlet of the intermediate-pressure turbine 4 but the steam extracted from the extraction port in the middle step of the intermediate-pressure turbine 4 , as well as the intermediate-pressure steam extraction pipe 21 of FIG. 6 .
  • the configuration that the steam is fed from the intermediate-pressure steam extraction pipe 21 and the high-pressure steam extraction pipes 31 , 32 to the carbon dioxide capturing system 22 is adopted, and the first and second switching valves 41 , 42 are provided on the intermediate-pressure steam extraction pipe 21 and the high-pressure steam extraction pipes 31 , 32 , respectively.
  • the pressure of the steam fed to the reboiler 106 of the carbon dioxide capturing system 22 can be stabilized. Further, according to the present embodiment, such stabilization of the pressure can be realized with a simple configuration such as the first and second switching valves 41 , 42 .

Landscapes

  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Physics & Mathematics (AREA)
  • Thermal Sciences (AREA)
  • Treating Waste Gases (AREA)
  • Gas Separation By Absorption (AREA)
  • Control Of Turbines (AREA)
US13/944,214 2012-07-31 2013-07-17 Steam turbine plant, control method of same, and control system of same Abandoned US20140033716A1 (en)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2012170060A JP5885614B2 (ja) 2012-07-31 2012-07-31 蒸気タービンプラント、その制御方法、およびその制御システム
JP2012-170060 2012-07-31

Publications (1)

Publication Number Publication Date
US20140033716A1 true US20140033716A1 (en) 2014-02-06

Family

ID=48793065

Family Applications (1)

Application Number Title Priority Date Filing Date
US13/944,214 Abandoned US20140033716A1 (en) 2012-07-31 2013-07-17 Steam turbine plant, control method of same, and control system of same

Country Status (5)

Country Link
US (1) US20140033716A1 (de)
EP (1) EP2703609B1 (de)
JP (1) JP5885614B2 (de)
CN (1) CN103573305A (de)
AU (1) AU2013207587A1 (de)

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20120255305A1 (en) * 2011-04-06 2012-10-11 Mitsubishi Heavy Industries, Ltd. Carbon dioxide recovery system and method
US20140366537A1 (en) * 2013-06-17 2014-12-18 Alstom Technology Ltd Steam power plant turbine and control method for operating at low load
CN108868923A (zh) * 2018-07-05 2018-11-23 大连亨利测控仪表工程有限公司 一种用于热网供热的三通射流减温减压控制系统
CN109611166A (zh) * 2018-11-20 2019-04-12 华电电力科学研究院有限公司 一种用于多低压缸汽轮机变工况的凝抽背供热系统及运行方法
CN114076005A (zh) * 2021-11-02 2022-02-22 神华国华寿光发电有限责任公司 一种中压供热系统、控制装置及中压供热方法

Families Citing this family (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN105020109A (zh) * 2014-04-21 2015-11-04 北京兆阳光热技术有限公司 一种太阳能光热电站蒸汽动力循环运行方式
CN105863757B (zh) * 2015-08-26 2018-06-05 北京逸智联科技有限公司 一种发电系统的电网负荷运行方法
CN106150567B (zh) * 2016-07-26 2017-11-14 中国神华能源股份有限公司 汽轮机增效系统及汽轮机的增效方法
CN106761991A (zh) * 2016-12-31 2017-05-31 上海康恒环境股份有限公司 一种适用于垃圾焚烧发电蒸汽循环再热提高热利用率系统
CN109908757A (zh) * 2019-04-18 2019-06-21 国电环境保护研究院有限公司 一种炭基催化剂再生装置及再生方法
CN112814751A (zh) * 2020-12-30 2021-05-18 东方电气集团东方汽轮机有限公司 基于二次再热煤电机组的双机耦合热力系统及耦合方法

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4051680A (en) * 1973-12-26 1977-10-04 Hall Carroll D Modified rankine cycle engine apparatus
WO2011104759A1 (ja) * 2010-02-26 2011-09-01 株式会社 日立製作所 火力発電システム、およびその運転方法，火力発電システムの改造方法，火力発電システムに用いられる蒸気タービン設備，二酸化炭素分離回収装置，過熱低減器
US20120096865A1 (en) * 2010-10-22 2012-04-26 Kabushiki Kaisha Toshiba Carbon dioxide recovery method and carbon-dioxide-recovery-type steam power generation system
US20120096861A1 (en) * 2010-10-21 2012-04-26 Kabushiki Kaisha Toshiba Carbon dioxide recovery method and carbon-dioxide-recovery-type steam power generation system
US20120240579A1 (en) * 2011-03-23 2012-09-27 Kabushiki Kaisha Toshiba Carbon-dioxide-recovery-type thermal power generation system and method of operating the same
US8656719B2 (en) * 2011-03-07 2014-02-25 Hitachi, Ltd. Thermal power plant, steam turbine and control method for a thermal power plant

Family Cites Families (10)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3242678A (en) * 1963-09-20 1966-03-29 Combustion Eng Apparatus and method for obtaining high temperature low pressure vapor from a high temperature high pressure vapor source
JPH1193694A (ja) * 1997-09-18 1999-04-06 Toshiba Corp ガスタービンプラント
JP2001342808A (ja) * 2000-05-31 2001-12-14 Mitsubishi Heavy Ind Ltd コンバインドプラントおよびその起動方法
JP4521202B2 (ja) * 2004-02-24 2010-08-11 株式会社東芝 蒸気タービン発電プラント
EP2136037A3 (de) * 2008-06-20 2011-01-05 Siemens Aktiengesellschaft Verfahren und Vorrichtung zum Betreiben einer Dampfkraftwerksanlage mit Dampfturbine und Prozessdampfverbraucher
JP5221443B2 (ja) * 2009-05-08 2013-06-26 株式会社東芝 一軸型複合サイクル発電プラントの起動方法および一軸型複合サイクル発電プラント
JP5205365B2 (ja) * 2009-12-25 2013-06-05 株式会社日立製作所 二酸化炭素分離回収装置を備えた化石燃料焚き火力発電システム
CN102003419A (zh) * 2010-10-21 2011-04-06 重庆智得热工工业有限公司 一种蒸汽喷射器组合装置
CN102322301B (zh) * 2011-06-01 2014-06-25 华北电力大学 一种实现燃煤发电-co2捕获-供热一体化的方法
CN102518478B (zh) * 2011-12-27 2015-09-23 杭州中能汽轮动力有限公司 用于海水淡化的汽轮机及其控制方法

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4051680A (en) * 1973-12-26 1977-10-04 Hall Carroll D Modified rankine cycle engine apparatus
WO2011104759A1 (ja) * 2010-02-26 2011-09-01 株式会社 日立製作所 火力発電システム、およびその運転方法，火力発電システムの改造方法，火力発電システムに用いられる蒸気タービン設備，二酸化炭素分離回収装置，過熱低減器
US20120096861A1 (en) * 2010-10-21 2012-04-26 Kabushiki Kaisha Toshiba Carbon dioxide recovery method and carbon-dioxide-recovery-type steam power generation system
US20120096865A1 (en) * 2010-10-22 2012-04-26 Kabushiki Kaisha Toshiba Carbon dioxide recovery method and carbon-dioxide-recovery-type steam power generation system
US8656719B2 (en) * 2011-03-07 2014-02-25 Hitachi, Ltd. Thermal power plant, steam turbine and control method for a thermal power plant
US20120240579A1 (en) * 2011-03-23 2012-09-27 Kabushiki Kaisha Toshiba Carbon-dioxide-recovery-type thermal power generation system and method of operating the same

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US20120255305A1 (en) * 2011-04-06 2012-10-11 Mitsubishi Heavy Industries, Ltd. Carbon dioxide recovery system and method
US9233336B2 (en) * 2011-04-06 2016-01-12 Mitsubishi Heavy Industries, Ltd. Carbon dioxide recovery system and method
US20140366537A1 (en) * 2013-06-17 2014-12-18 Alstom Technology Ltd Steam power plant turbine and control method for operating at low load
US9617874B2 (en) * 2013-06-17 2017-04-11 General Electric Technology Gmbh Steam power plant turbine and control method for operating at low load
CN108868923A (zh) * 2018-07-05 2018-11-23 大连亨利测控仪表工程有限公司 一种用于热网供热的三通射流减温减压控制系统
CN109611166A (zh) * 2018-11-20 2019-04-12 华电电力科学研究院有限公司 一种用于多低压缸汽轮机变工况的凝抽背供热系统及运行方法
CN114076005A (zh) * 2021-11-02 2022-02-22 神华国华寿光发电有限责任公司 一种中压供热系统、控制装置及中压供热方法

Also Published As

Publication number Publication date
EP2703609A2 (de) 2014-03-05
EP2703609A3 (de) 2016-11-30
JP2014029139A (ja) 2014-02-13
JP5885614B2 (ja) 2016-03-15
AU2013207587A1 (en) 2014-02-20
EP2703609B1 (de) 2019-08-28
CN103573305A (zh) 2014-02-12

Similar Documents

Publication Publication Date Title
EP2703609B1 (de) Dampfturbinenanlage und Regelverfahren dafür
EP2375012B1 (de) Kesselvorrichtung
US8806870B2 (en) Carbon-dioxide-recovery-type thermal power generation system and method of operating the same
JP5320423B2 (ja) 火力発電プラント，蒸気タービン設備、およびその制御方法
JP5704937B2 (ja) 二酸化炭素分離回収装置を備えた火力発電システム
US20100326074A1 (en) Steam turbine power plant and operation method thereof
JP5734883B2 (ja) 二酸化炭素分離回収装置、二酸化炭素回収型汽力発電システム、及び二酸化炭素回収型汽力発電システムの運転方法
KR101907257B1 (ko) 배기 가스로부터 습분을 회수하는 화력 발전 설비 및 그 화력 발전 설비의 회수수의 처리 방법
CN106943848B (zh) 二氧化碳捕获系统和操作二氧化碳捕获系统的方法
JP7412102B2 (ja) ガスタービンプラント
JP7330718B2 (ja) ガスタービンプラント、及びその排出二酸化炭素回収方法
EP3037152A2 (de) Kohlendioxidabscheidungssystem und verfahren zum betrieb davon
CA2883111C (en) Heat recovery system and heat recovery method
JP5355358B2 (ja) 二酸化炭素分離回収装置を備えた化石燃料焚き火力発電システム
WO2014058007A1 (ja) 二酸化炭素回収システム
TW201247995A (en) System and method for controlling waste heat for CO2 capture

Legal Events

Date Code Title Description
AS Assignment

Owner name: KABUSHIKI KAISHA TOSHIBA, JAPAN

Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNORS:ITOU, SHINSUKE;SANADA, MASAHIKO;EGAMI, NORIHIDE;AND OTHERS;REEL/FRAME:031435/0701

Effective date: 20130820

STCB Information on status: application discontinuation

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