WO2012054049A1 - Moteur thermique et son procédé de fonctionnement - Google Patents

Moteur thermique et son procédé de fonctionnement Download PDF

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Publication number
WO2012054049A1
WO2012054049A1 PCT/US2010/053685 US2010053685W WO2012054049A1 WO 2012054049 A1 WO2012054049 A1 WO 2012054049A1 US 2010053685 W US2010053685 W US 2010053685W WO 2012054049 A1 WO2012054049 A1 WO 2012054049A1
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WO
WIPO (PCT)
Prior art keywords
thermal energy
fluid
heat engine
carbon dioxide
process fluid
Prior art date
Application number
PCT/US2010/053685
Other languages
English (en)
Inventor
Matthias Finkenrath
Gabor Ast
Michael Adam Bartlett
Vittorio Tola
Original Assignee
General Electric Company
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 General Electric Company filed Critical General Electric Company
Priority to PCT/US2010/053685 priority Critical patent/WO2012054049A1/fr
Publication of WO2012054049A1 publication Critical patent/WO2012054049A1/fr

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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
    • F01K25/00—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for
    • F01K25/08—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for using special vapours
    • F01K25/10—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for using special vapours the vapours being cold, e.g. ammonia, carbon dioxide, ether
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1456—Removing acid components
    • B01D53/1475—Removing carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/343—Heat recovery
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/064—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle in combination with an industrial process, e.g. chemical, metallurgical
    • 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
    • F01K25/00—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for
    • F01K25/08—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for using special vapours
    • F01K25/10—Plants or engines characterised by use of special working fluids, not otherwise provided for; Plants operating in closed cycles and not otherwise provided for using special vapours the vapours being cold, e.g. ammonia, carbon dioxide, ether
    • F01K25/103—Carbon dioxide
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/02—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
    • F22B1/16—Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers the heat carrier being hot liquid or hot vapour, e.g. waste liquid, waste vapour
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2259/00—Type of treatment
    • B01D2259/65—Employing advanced heat integration, e.g. Pinch technology
    • 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
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
    • Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
    • 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 disclosed herein relate generally to the field of power generation and, more particularly, to a system and method for recovering waste heat from a carbon dioxide removal process.
  • Carbon dioxide (CO 2 ) emissions from power plants utilizing fossil fuels are increasingly penalized by national and international regulations, such as the Kyoto protocol and the European Union Emission Trading Scheme.
  • national and international regulations such as the Kyoto protocol and the European Union Emission Trading Scheme.
  • overall power plant efficiency is reduced, in some cases by about 10 %.
  • Increasing the efficiency of power plants utilizing CO 2 emissions reduction technology is therefore of interest.
  • a system such as a power plant, the system including a process fluid cooler, a carbon dioxide removal system, a compression system, and a heat engine.
  • the process fluid cooler can be configured to receive a process fluid including carbon dioxide and to extract thermal energy from the process fluid.
  • the carbon dioxide removal system can include an absorber and a stripper.
  • the absorber can be configured to receive the process fluid from the process fluid cooler and to transfer carbon dioxide from the process fluid to a removal fluid (e.g., a solvent, such as amine).
  • the stripper can be configured to receive the removal fluid from the absorber and can include a reboiler and a stripper condenser.
  • the reboiler can be configured to heat the removal fluid (e.g., by receiving steam) so as to cause carbon dioxide to be released from the removal fluid and outputted as part of a reboiler output stream.
  • the reboiler can also output a heating fluid, such as water.
  • the stripper condenser can be configured to extract thermal energy from the reboiler output stream so as to cause condensation of water associated with the reboiler output stream and to remove carbon dioxide therefrom.
  • the compression system can be configured to receive carbon dioxide from the stripper condenser and to remove thermal energy from the carbon dioxide.
  • the heat engine can be configured to operate according to an organic Rankine cycle and further configured to receive thermal energy- from the heating fluid and/or extracted at the process fluid cooler, at the stripper condenser, and/or at the compression system.
  • the heat engine may include a working fluid such as, for example, carbon dioxide, R245fa, and or butane.
  • the heat engine may also include a secondary condenser configured to extract thermal energy from a working fluid.
  • a second heat engine can be included and configured to operate according to an organic Rankine cycle, receiving thermal energy extracted at the secondary condenser.
  • the system may also include a combustion chamber configured for combustion of a fossil fuel so as to produce the process fluid.
  • the combustion chamber may be configured to direct the process fluid to the process fluid cooler.
  • An exhaust gas recirculation system may also be provided.
  • the exhaust gas recirculation system may be configured to recirculate flue gases back to a main combustion zone of the combustion chamber.
  • the exhaust gas recirculation system can include an exhaust gas recirculation cooler configured to extract thermal energy from the recirculated flue gases, and the heat engine can be configured to receive thermal energy from the exhaust gas recirculation cooler.
  • the system may further include a primary heat engine configured to operate according to a Rankine cycle with water as a working fluid.
  • the primary heat engine may be configured to receive thermal energy from the combustion chamber, and may include a primary condenser configured to extract thermal energy from the working fluid of the primary heat engine. The heat engine can then be configured to receive thermal energy from the primary condenser.
  • another system is provided.
  • the system can include a process fluid cooler configured to receive a process fluid including carbon dioxide and to extract thermal energy from the process fluid.
  • the system can also include a carbon dioxide removal system including an absorber and a stripper.
  • the absorber can be configured to receive the process fluid from the process fluid cooler and to transfer carbon dioxide from the process fluid to a removal fluid.
  • the stripper can be configured to receive the removal fluid from the absorber.
  • the stripper can include a reboiler configured to heat the removal fluid so as to cause carbon dioxide to be released from the removal fluid and outputted as part of a reboiler output stream.
  • the reboiler may also output a heating fluid.
  • the stripper can also include a stripper condenser configured to extract thermal energy from the reboiler output stream so as to cause condensation of water associated therewith and to remove carbon dioxide therefrom.
  • the system can further include a compression system configured to receive carbon dioxide from the stripper condenser and to remove thermal energy from the carbon dioxide, and also a first heat engine configured to operate according to an organic Rankine cycle.
  • the first heat engine can include a first condenser configured to extract thermal energy from a first working fluid and a first evaporator configured to receive thermal energy from at least one of the heating fluid or the thermal energy extracted at the process fluid cooler or the stripper condenser or the compression system.
  • a second heat engine can be configured to operate according to an organic Rankine cycle and can include a second working fluid and a second evaporator configured to receive thermal energy from the first condenser and from at least one of the heating fluid or the thermal energy extracted at the process fluid cooler or the stripper condenser or the compression system.
  • the first heat engine can include at least one of
  • R245fa or butane as the first working fluid and the second heat engine can include carbon dioxide as the second working fluid.
  • the first evaporator is configured to receive at least some of the thermal energy extracted at the process fluid cooler and the second evaporator is configured to receive thermal energy from the heating fluid and the thermal energy extracted at the stripper condenser.
  • a method is provided, which method includes receiving a process fluid including carbon dioxide and extracting thermal energy from the process fluid.
  • the process fluid may be produced, for example, by combusting fossil fuel. Carbon dioxide can be transferred from the process fluid to a removal fluid.
  • the removal fluid can be heated so as to cause carbon dioxide to be released from the removal fluid and included as part of a mixture including steam and so as to produce an output stream of a heating fluid.
  • Thermal energy can be extracted from the mixture of carbon dioxide and steam so as to cause condensation of the steam and to remove carbon dioxide therefrom, creating a carbon dioxide gas stream.
  • Thermal energy can be extracted from the carbon dioxide gas stream.
  • a heat engine can be operated according to an organic Rankine cycle, and thermal energy can be provided to the heat engine from the heating fluid and from that extracted from the process fluid and the carbon dioxide gas stream.
  • thermal energy may be extracted from an exhaust gas recirculation cooler and provided to the heat engine.
  • a primary heat engine may be operated according to a Rankine cycle with water as a working fluid, and thermal energy may be provided from the combustion of fossil fuel to the primary heat engine.
  • Thermal en erg)' can be extracted thermal energy from the working fluid of the primary heat engine and provided to the heat engine.
  • Rankine cycle can include extracting thermal energy from a working fluid of the heat engine.
  • a second heat engine can be operated according to an organic Rankine cycle, and thermal energy extracted from the working fluid of the heat engine can be provided to the second heat engine.
  • the working fluid of the heat engine can be heated so as to cause evaporation thereof, and a working fluid of the second heat engine can be heated so as to cause evaporation thereof.
  • Thermal energy can be provided to the second heat engine from at least one of the heating fluid or the thermal energy extracted from the process fluid or the carbon dioxide gas stream.
  • FIG. 1 a schematic view of a power plant
  • FIG. 2 is a schematic view of a CO 2 removal system
  • FIG. 3 is a schematic view of a CO 2 compression system
  • FIG. 4 is a schematic view of a heat engine configured in accordance with an example embodiment
  • FIGS. 5 and 6 are schematic views of respective heat engines configured in accordance with other example embodiments and respectively including multiple evaporators in varying arrangements.
  • FIG. 7 is a schematic view of heat engines configured in a cascaded arrangement in accordance with an example embodiment.
  • the power plant 100 may include a combustion chamber 102 within which a combustion process takes place.
  • the combustion process may produce thermal energy 104 that can be used to drive a generator 106.
  • the power plant 100 may include a primary heat engine 108 that is configured to operate, say, according to a Rankine cycle, and may, for example, utilize water as the working fluid.
  • the primary heat engine 108 can include a primary condenser 110, a primary evaporator 112, and a pump 114 (e.g., a variable speed pump) that pumps the working fluid from the primary condenser to the primary evaporator.
  • Thermal energy generated by the combustion process taking place in the combustion chamber 102 may then be provided to the primary evaporator 112 as part of the Rankine cycle.
  • the primary evaporator 112 may receive thermal energy from the combustion process and generate a working fluid vapor, say, steam.
  • the working fluid vapor can be passed through an expander 115 (e.g., a screw type expander, an axial type expander, an impulse type expander, or a high temperature screw type expander) to drive the generator 106.
  • an expander 115 e.g., a screw type expander, an axial type expander, an impulse type expander, or a high temperature screw type expander
  • the working fluid vapor at a relatively lower pressure and lower temperature is passed through the primary condenser 110.
  • the working fluid vapor is condensed into a liquid, which is then pumped via the pump 114 to the primary evaporator 112. The cycle may then be repeated.
  • the primary function of the combustion process is to provide thermal energy 104 to the primary heat engine 108.
  • fossil fuels such as, for example, natural gas, coal, methane, and/or liquid petroleum
  • the power plant 100 may operate according to a natural gas-fuelled combined cycle (NGCC) or a coal-fuelled steam cycle.
  • NGCC natural gas-fuelled combined cycle
  • the combustion process is expected to produce a CO 2 - containing process fluid in the form of CO 2 -rich combustion exhaust gas/products 116.
  • the exhaust gas can be directed to and received by a CO 2 removal system 118.
  • CO 2 removal system 118 serves to separate much of the CO 2 from the aggregate exhaust products 116, thereby resulting in a CO 2 -lean exhaust gas 120 (which can then be emitted to the atmosphere with more limited environmental impact) and isolated CO 2 gas 122 (although the gas may also include relatively small amounts of nitrogen, water, and other compounds).
  • the isolated CO 2 can then be directed to a CO 2 compression system 124, where the CO 2 gas 122 can be compressed to produce liquid CO 2 126 to facilitate storage and subsequent utilization.
  • thermal energy 128 may be outputted and otherwise unused in the processes associated with the operation of the primary heat engine 108, the CO 2 removal system 118, and/or the CO 2 compression system 124.
  • the CO 2 -rich combustion exhaust gas/products 116 are at high temperature due to the combustion process.
  • the temperature of the exhaust gas products 116 is lowered by rejecting the high-grade heat content to the primary heat engine 108, typically to temperatures of about 80 °C for a NGCC-based process and up to 1 10 °C for a coal fuelled steam cycle-based process.
  • thermal energy is also available from the CO 2 removal and compression processes.
  • thermal energy 128 can be thought of as "waste thermal energy.” As will be discussed further below, however, it is to be understood that the "waste" thermal energy from one process may ⁇ be utilized as part of another process in order to extract useful work.
  • CO 2 -rich combustion exhaust gas/products 116 are directed from the combustion chamber 102 to the CO 2 removal system 118.
  • a schematic view of an embodiment of the CO 2 removal system 118 is provided in FIG. 2.
  • the CO 2 removal system 118 can include an absorber 130 configured to receive the CO 2 -rich combustion exhaust gas 116 and to transfer CO 2 from the exhaust gas to a removal fluid.
  • the absorber 130 may be configured to direct the exhaust gas 116 into contact with a stream of solvent 132, such as an amine ⁇ e.g., monoethanolamine, diglycolamine, diethanolamine, diisopropanolamine, and/or methyldiethanolamine), that has absorbed therein only a limited amount of CO 2 (“CO 2 -lean solvent").
  • solvent 132 such as an amine ⁇ e.g., monoethanolamine, diglycolamine, diethanolamine, diisopropanolamine, and/or methyldiethanolamine
  • CO 2 -lean solvent CO 2 from the exhaust gas is absorbed into and is carried away with the solvent, such that the outputs from the absorber 130 are CO 2 -rich solvent 134 and CO 2 -lean combustion exhaust gas 136.
  • the temperature of the exhaust gas 116 is often relatively high, and thermal energy 138 may be removed from the exhaust gas by a process fluid cooler 140 (e.g., a heat exchanger) in order to cool the exhaust gas prior to being received by the absorber 130.
  • a process fluid cooler 140 e.g., a heat exchanger
  • the CO 2 removal system can also include a stripper 142 configured to receive the CO 2 -rich solvent stream 134 from the absorber 130.
  • the stripper 142 can include a reboiler 150, and the CO 2 -rich solvent stream 134 can be directed to the reboiler.
  • the reboiler 150 can accept an input stream of heating fluid, such as steam 152, and can be used to heat the CO 2 -rich solvent stream 134, thereby producing a reboiler output stream, including a mixture of steam and CO 2 153 released from the solvent.
  • the mixture of steam and CO 2 153 that is released from the solvent may be found in the form of an acidic gas.
  • thermal energy is transferred from the steam 152 to the solvent 132, the steam condenses to form hot water 154. Subsequently, thermal energy 156 can be extracted from the hot water 154 using a heating fluid cooler 158, thereby producing an output stream of cold water 160.
  • the mixture of steam and CO 2 153 is then directed from the reboiler 150 to a stripper condenser 144, which is configured to extract thermal energy 146 (e.g., via a heat exchanger) from the mixture of steam and CO 2 153 so as to cause condensation of the steam and to correspondingly cause CO 2 gas 148 (possibly mixed with relatively small amounts of other compounds, such as about 2.5 % water, about 0.1 % nitrogen, and trace amounts of argon) to desorb out of the mixture.
  • thermal energy 146 e.g., via a heat exchanger
  • CO 2 gas 148 possibly mixed with relatively small amounts of other compounds, such as about 2.5 % water, about 0.1 % nitrogen, and trace amounts of argon
  • CO 2 -lean solvent 132 is directed back to the absorber 130 to repeat the process.
  • the CO 2 removal system 118 may further include one or more pumps 162 that act to move the solvent 132, 134 through the CO 2 removal system.
  • a heat exchanger 164 can be included to allow thermal energy to be transferred between the CO 2 -rich solvent stream 134 and the CO 2 -lean solvent stream 132.
  • a further cooler 165 can be included, and configured to remove thermal energy from the CO 2 -lean solvent stream 132 so as to cool the stream to the operational temperature of the absorber 130.
  • CO 2 gas 148 (including relatively small amounts of other compounds) outputted from the CO 2 removal system 118 is directed to the CO 2 compression system 124 that is configured to remove thermal energy from the CO 2 gas.
  • the CO 2 gas 148 may be sequentially passed through a series of compressors 166, compression chain intercoolers 168, and dryers 170a-c.
  • thermal energy 172 may be extracted.
  • liquid and gaseous products can be separated.
  • stages 170a, 170b water is removed from the CO 2 gas 148, while in others, liquefied CO 2 is separated from other gaseous impurities 176. Finally, a compressed, and more purified, liquid CO 2 178 can be outputted via a pump 180.
  • the "waste" thermal energy 128 of any single heat source or combination of multiple heat sources may be utilized in conjunction with a heat engine 182.
  • the heat engine 182 can be configured to operate according to an organic Rankine cycle (ORC), where the thermal energy 138, 146, 156, 172 (collectively the thermal energy or "waste” thermal energy 128) from any one or more of the process fluid cooler 140, the stripper condenser 144, the heating fluid cooler 158, and/or the compression chain intercoolers 168, respectively, are received and used to drive the ORC.
  • ORC organic Rankine cycle
  • the heat engine 182 can include a secondary evaporator 184 configured to receive at least some of the waste thermal energy 128.
  • the secondary evaporator 184 can receive heat from the waste thermal energy 128 and generate a vapor from an organic working fluid 185.
  • the organic working fluid vapor may be passed through an expander 186 to drive a generator unit 188.
  • the organic working fluid vapor 185 now at a relatively lower pressure and lower temperature, is passed through a secondary condenser 190 that can extract thermal energy 191 from the organic working fluid vapor 185.
  • the organic working fluid vapor is condensed into a liquid, which is then pumped via a pump 192 to the secondary evaporator 184.
  • the pump 192 may be a variable speed pump, and may supply the condensed organic working fluid 185 to the secondary evaporator 184 at a pressure of 11.3 bars and a temperature of 95 °C. The cycle may then be repeated. It should be noted herein that the temperature and pressure values discussed above and in subsequent paragraphs are exemplary values and should not be construed as limiting values. The values may vary depending on the applications.
  • the organic working fluid 185 may include CO 2 , cyclohexane, cyclopentane, thiophene, ketones, and/or aromatics.
  • the organic working fluid 185 may include propane, butane, pentafluoro-propane, pentafluoro-butane, pentafluoro-polyether, oil, R245fa, and/or other refrigerants. It should be noted herein that the above list of organic working fluids is not inclusive, and other organic working fluids applicable to ORCs are also envisaged.
  • the organic working fluid 185 may include a binary fluid, such as, for example, cyclohexane- propane, cyclohexane-butane, cyclopentane-butane, and/or cyclopentane- pentafluoropropane.
  • the organic working fluid 185 may include a mixture of working fluids and lubrication oil (that is, it may comprise a two-phase mixture).
  • the above described embodiments may facilitate effective use of waste thermal energy 128 produced through the operation of a CO 2 removal and compression process.
  • the waste thermal energy 128 can be converted into electricity via the ORC -based heat engine 182. It is noted that other sources of thermal energy may be available for driving the ORC, including other low-temperature thermal energy sources disposedwithin the CO 2 removal system 118,and/or within the power plant 100 generally.
  • thermal energy may be extracted from an exhaust gas recirculation (EGR) cooler (not shown), in which flue gases are recirculated back to the main combustion zone of the combustion process (e.g., in the case of a NGCC-based process, flue gases would typically be directed to the gas turbine compressor inlet), and directed to an ORC-based heat engine 182.
  • EGR exhaust gas recirculation
  • FIG. 5 therein is shown a schematic representation of a heat engine 282 configured in accordance with another example embodiment.
  • the heat engine 282 can include multiple secondary evaporators 284a, 284b that are serially arranged.
  • Each of the secondary evaporators 284a, 284b may receive waste thermal energy 128 (FIG. 1) produced through the operation of the CO 2 removal and compression process, and may sequentially impart that thermal energy to the organic working fluid 185.
  • a heat engine 382 can be configured so as to include multiple secondary evaporators 384a, 384b that are arranged in parallel with respect to the flow path of the organic working fluid 185.
  • the heat engine 182 may be a first heat engine, and may operate in conjunction with a second heat engine 482 that is similarly configured to operate according to an ORC.
  • the first heat engine 182 can include a first condenser 190 configured to extract thermal energy 191 from a first working fluid 185, and can also include a first evaporator 184 configured to receive at least some of the waste thermal energy 128.
  • the second heat engine 482 can include a second condenser 490 configured to extract thermal energy 491 from a second working fluid 485, and can also include a second evaporator 484.
  • the first condenser 190 and the second evaporator 484 can be replaced by a cascaded heat exchange unit that serves both as a condenser for the first heat engine 182 and as an evaporator for the second heat engine 482.
  • the second evaporator 484 can be configured to receive at least some of the thermal energy 191 from the first condenser 190 (and from the first organic working fluid 185) and generate a vapor of the second organic working fluid 485.
  • the second organic working fluid vapor may be at a pressure of 9 bars and temperature of 87 °C.
  • the second organic working fluid vapor can be passed through an expander 486 to drive a generator unit 488.
  • the expanders 186, 486 respectively associated with the first and second heat engines 182, 482 can be coupled to a single generator unit.
  • the first and second heat engines 182, 482 may utilize working fluids with higher and lower boiling points, respectively. As such, the first and second heat engines 182, 482 may be "cascaded," with the first heat engine 182 may operate thermodynamically as a "top cycle” and the second heat engine 482 may operate as a "bottom cycle.”
  • the first working fluid 185 may include R245fa and/or butane, while the second working fluid can include CO 2 .
  • the first working fluid may include cyclohexane, cyclopentane, thiophene, ketones, and/or aromatics
  • the second working fluid 485 may include propane, butane, pentafluoro-propane, pentafluoro-butane, pentafluoro-poly ether, and/or oil.
  • the second evaporator 484 can also be further configured to receive at least some of the waste thermal energy 128.
  • the first evaporator 184 may be configured to receive the thermal energy 138 extracted at the process fluid cooler 140 and the second evaporator 484 may be configured to receive the thermal energy 146, 156, 172 from the heating fluid 152, the stripper condenser 144, and the compression chain intercoolers 168, respectively.
  • the thermal energy extracted at the process fluid cooler 140 would be sufficient to have this qualify as a relatively higher grade energy source, while the latter energy sources would be considered relatively lower grade energy sources.
  • the cascading of the first and second heat engines 182, 482 operating according to ORCs facilitates heat recovery over a temperature range that is too large for a single ORC system to accommodate efficiently.
  • the illustrated embodiments may facilitate effective heat removal from the plurality of lower temperature heat sources. This may increase the effectiveness of the cooling systems and may provide effective conversion of waste heat into electricity.

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  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

Selon l'invention, un dispositif de refroidissement de fluide de traitement (140) peut extraire de l'énergie thermique d'un fluide de traitement comprenant du dioxyde de carbone. Un absorbeur (130) peut transférer du dioxyde de carbone du fluide de traitement vers un fluide d'élimination. Un rebouilleur (150) peut chauffer le fluide d'élimination de façon à provoquer la libération du dioxyde de carbone du fluide d'élimination et sa sortie en tant que partie d'un courant de sortie du rebouilleur. Le rebouilleur peut également produire un fluide de chauffage. Un condenseur de lavage (144) peut extraire de l'énergie thermique (128, 146) du courant de sortie du rebouilleur de façon à provoquer une condensation d'eau associée au courant de sortie du rebouilleur et à éliminer du dioxyde de carbone de celui-ci. Un système de compression peut extraire l'énergie thermique du dioxyde de carbone reçu du condenseur de lavage. Un moteur thermique peut être configuré de façon à fonctionner selon un cycle de Rankine organique, recevant de l'énergie thermique du fluide de chauffage et/ou extraite dans le dispositif de refroidissement de fluide de traitement, dans le condenseur de lavage et/ou dans le système de compression.
PCT/US2010/053685 2010-10-22 2010-10-22 Moteur thermique et son procédé de fonctionnement WO2012054049A1 (fr)

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR3006911A1 (fr) * 2013-06-12 2014-12-19 IFP Energies Nouvelles Procede de captage de co2 avec production d'electricite

Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3307350A (en) * 1964-07-02 1967-03-07 Arthur M Squires Top heat power cycle
US7007474B1 (en) * 2002-12-04 2006-03-07 The United States Of America As Represented By The United States Department Of Energy Energy recovery during expansion of compressed gas using power plant low-quality heat sources
WO2009112518A1 (fr) * 2008-03-13 2009-09-17 Shell Internationale Research Maatschappij B.V. Procédé pour l'élimination de dioxyde de carbone à partir d'un gaz
DE102008020414A1 (de) * 2008-04-24 2009-10-29 Leithner, Reinhard, Prof. Dr. techn. CO!2!-Abscheidung mit Energiegewinnung und andere Kreisläufe mit Adsorption und Absorption von Gasen
US20100242476A1 (en) * 2009-03-30 2010-09-30 General Electric Company Combined heat and power cycle system
WO2011003892A2 (fr) * 2009-07-10 2011-01-13 Hitachi Power Europe Gmbh Centrale thermique au charbon avec lavage des fumées et récupération de chaleur

Patent Citations (6)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3307350A (en) * 1964-07-02 1967-03-07 Arthur M Squires Top heat power cycle
US7007474B1 (en) * 2002-12-04 2006-03-07 The United States Of America As Represented By The United States Department Of Energy Energy recovery during expansion of compressed gas using power plant low-quality heat sources
WO2009112518A1 (fr) * 2008-03-13 2009-09-17 Shell Internationale Research Maatschappij B.V. Procédé pour l'élimination de dioxyde de carbone à partir d'un gaz
DE102008020414A1 (de) * 2008-04-24 2009-10-29 Leithner, Reinhard, Prof. Dr. techn. CO!2!-Abscheidung mit Energiegewinnung und andere Kreisläufe mit Adsorption und Absorption von Gasen
US20100242476A1 (en) * 2009-03-30 2010-09-30 General Electric Company Combined heat and power cycle system
WO2011003892A2 (fr) * 2009-07-10 2011-01-13 Hitachi Power Europe Gmbh Centrale thermique au charbon avec lavage des fumées et récupération de chaleur

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR3006911A1 (fr) * 2013-06-12 2014-12-19 IFP Energies Nouvelles Procede de captage de co2 avec production d'electricite

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