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WO2025128110A1 - Système et procédé de capture de gaz à l'aide de la vapeur provenant d'une turbine à vapeur supportée par une chaudière auxiliaire - Google Patents

Système et procédé de capture de gaz à l'aide de la vapeur provenant d'une turbine à vapeur supportée par une chaudière auxiliaire Download PDF

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Publication number
WO2025128110A1
WO2025128110A1 PCT/US2023/084097 US2023084097W WO2025128110A1 WO 2025128110 A1 WO2025128110 A1 WO 2025128110A1 US 2023084097 W US2023084097 W US 2023084097W WO 2025128110 A1 WO2025128110 A1 WO 2025128110A1
Authority
WO
WIPO (PCT)
Prior art keywords
steam
gas
steam turbine
auxiliary boiler
pressure
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.)
Pending
Application number
PCT/US2023/084097
Other languages
English (en)
Inventor
Majed Sammak
Parag P. Kulkarni
Peter J. Murphy
Gian-Luigi Agostinelli
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.)
GE Vernova GmbH
GE Vernova Infrastructure Technology LLC
Original Assignee
General Electric Technology GmbH
GE Infrastructure Technology LLC
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 Technology GmbH, GE Infrastructure Technology LLC filed Critical General Electric Technology GmbH
Priority to PCT/US2023/084097 priority Critical patent/WO2025128110A1/fr
Publication of WO2025128110A1 publication Critical patent/WO2025128110A1/fr
Pending legal-status Critical Current
Anticipated expiration legal-status Critical

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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
    • F01K3/00—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein
    • F01K3/18—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters
    • F01K3/24—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by separately-fired heaters
    • 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
    • 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
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]

Definitions

  • the present application relates generally to a system and method supporting a gas capture system with steam accounting for variations in steam supply in full load versus part load operating conditions.
  • An industrial plant such as a combustion-driven power plant, may produce a variety of gases, such as an exhaust gas of a combustion system.
  • the combustion system may include a gas turbine engine, a reciprocating piston-cylinder engine, a furnace, a boiler, or other industrial equipment.
  • These exhaust gases may include one or more undesirable gases, such as acid gases and/or greenhouse gases.
  • the undesirable gases may include carbon oxides (COx) such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NOx) such as nitrogen dioxide (NO2), and/or sulfur oxides (SOx) such as sulfur dioxide (SO2).
  • CO2 is both an acid gas and a greenhouse gas.
  • a system includes a heat recovery steam generator (HRSG) configured to generate a first steam using heat from an exhaust gas.
  • HRSG heat recovery steam generator
  • the system further includes an auxiliary boiler configured to generate a second steam and a steam turbine system configured to receive the first steam, the second steam, or a combination thereof.
  • the system further includes a gas capture system configured to capture an undesirable gas from an exhaust gas.
  • the gas capture system is configured to receive the second steam from the auxiliary boiler, a third steam from the steam turbine system while the steam turbine system receives the second steam from the auxiliary boiler, or a combination thereof.
  • a system includes a controller having a processor, a memory, and instructions stored on the memory and executable by the processor to control a supply of a first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG generates the first steam using heat from an exhaust gas.
  • the controller is further configured to control a supply of a second steam from an auxiliary boiler to the steam turbine system and/or a gas capture system, wherein the gas capture system is configured to capture an undesirable gas from the exhaust gas.
  • the controller is further configured to control a supply of a third steam from the steam turbine system to the gas capture system while the steam turbine system receives the second steam from the auxiliary boiler.
  • a method includes supplying a first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG generates the first steam using heat from an exhaust gas.
  • the method further includes supplying a second steam from an auxiliary boiler to the steam turbine system and/or a gas capture system, wherein the gas capture system is configured to capture an undesirable gas from the exhaust gas.
  • the method further includes supplying a third steam from the steam turbine system to the gas capture system while the steam turbine system receives the second steam from the auxiliary boiler.
  • FIG. 1 is a block diagram of an embodiment of a combined cycle system having a gas turbine system, a steam turbine system, a heat recovery steam generator (HRSG), a gas treatment system having one or more gas capture systems, and an auxiliary boiler (i.e., auxboiler) configured to provide steam to the steam turbine system, the gas treatment system, or both.
  • HRSG heat recovery steam generator
  • auxboiler auxiliary boiler
  • FIG. 2 is a schematic of an embodiment of a gas capture system of the gas treatment system of FIG. 1, illustrating a sorbent-based gas capture system having an adsorption mode, a desorption mode, and an auxiliary boiler configured to provide steam to a steam turbine system, the gas treatment system, or both.
  • FIG. 3 is a schematic of an embodiment of a gas capture system of the gas treatment system of FIG. 1 , illustrating a solvent-based gas capture system having an absorber and a stripper, and an auxiliary boiler configured to provide steam to a steam turbine system, the gas treatment system, or both.
  • FIG. 4 is a schematic of an embodiment of an auxiliary boiler as part of a gas treatment system, wherein the auxiliary boiler is configured to provide steam to the steam turbine system, the gas treatment system, or both.
  • the disclosed embodiments include systems and methods to reduce the carbon footprint of combustion systems, such as combustion-driven power plants and/or combined cycle power plants, using a gas treatment system having one or more gas capture systems.
  • the disclosed embodiments provide an arrangement of a heat recovery steam generator (HRSG), a steam turbine system driven by the HRSG, and an auxiliary boiler providing variable steam to the steam turbine system, wherein steam is provided by the steam turbine system and/or the auxiliary boiler as a heat source (e.g., steam) for the gas capture systems.
  • the gas capture systems are configured to remove undesirable gases (e.g., CO2) from the intake air and/or the exhaust gas of the combustion systems.
  • the gas capture systems may include sorbent-based gas capture systems, solvent-based gas capture systems, cryogenic gas capture systems, membrane-based gas capture systems, or a combination thereof.
  • the gas capture systems e.g., sorbent-based gas capture systems
  • TSA temperature swing adsorption
  • the gas capture systems generally use a heat source (e.g., steam) to support the gas capture process.
  • a heat source e.g., steam
  • the sorbent-based gas capture systems are configured to adsorb the undesirable gases into a sorbent material, and then subsequently desorb the undesirable gases from the sorbent material using a heat source (e.g., steam from the HRSG, steam from the steam turbine system at least partially supported by the HRSG and an auxiliary boiler, steam from the auxiliary boiler, or other steam source).
  • a heat source e.g., steam from the HRSG, steam from the steam turbine system at least partially supported by the HRSG and an auxiliary boiler, steam from the auxiliary boiler, or other steam source.
  • the adsorption process is exothermic, while the desorption process is endothermic.
  • the solvent-based gas capture systems may include an absorber configured to absorb the undesirable gas into a solvent, and a stripper configured to strip the undesirable gas from the solvent using steam (e.g., steam from the HRSG, steam from the steam turbine system at least partially supported by the HRSG and an auxiliary boiler, steam from the auxiliary boiler, or other steam source).
  • steam e.g., steam from the HRSG, steam from the steam turbine system at least partially supported by the HRSG and an auxiliary boiler, steam from the auxiliary boiler, or other steam source.
  • steam e.g., steam from the HRSG, steam from the steam turbine system at least partially supported by the HRSG and an auxiliary boiler, steam from the auxiliary boiler, or other steam source.
  • the gas capture system may use steam at certain pressure levels and temperatures for gas capture, such as carbon capture (e.g., CO2 capture).
  • gas capture such as carbon capture (e.g., CO2 capture).
  • the steam may be extracted from a steam turbine system at least partially supported by the HRSG and an auxiliary boiler, an auxiliary boiler, or from both.
  • the present disclosure describes a concept of integrating the auxiliary boiler with the steam turbine system, wherein the steam turbine system may receive a main supply of steam from the HRSG while receiving additional steam from the auxiliary boiler, such that steam may be extracted from the steam turbine system for use in the gas capture system regardless of the operating mode (e.g., part load or full load operating conditions).
  • integrating the auxiliary boiler steam with the steam turbine may improve the steam turbine system output by 2.5%-5% and the efficiency with 0.2%, such that steam can be extracted from the steam turbine system for use in the gas capture system.
  • the steam turbine system may face operational challenges that result in less efficient output.
  • the auxiliary boiler integration with the steam turbine system helps to increase the output and efficiency of the steam turbine system during the part load operation, such that steam can be extracted from the steam turbine system for use in the gas capture system.
  • the auxiliary boiler may vary the pressure of steam supplied to the steam turbine system and/or vary the location of steam supply to the steam turbine system, such as by supplying steam to multiple steam turbine stages (e.g., high pressure and intermediate pressure steam turbine stages) of the steam turbine system.
  • the auxiliary boiler integrated with the steam turbine system may be used in a variety of configurations with the gas capture systems. Although specific examples are provided below, the auxiliary boiler integrated with the steam turbine system may be used in any suitable manner to support various gas capture systems, including but not limited to, sorbent-based gas capture systems, solvent-based gas capture systems, and cryogenic gas capture systems.
  • FIG. 1 is a block diagram of an embodiment of a combined cycle system 10 having a gas turbine system 12, a steam turbine system 14, a heat recovery steam generator (HRSG) 16, a gas treatment system 18 having one or more gas capture systems 20, a waste heat recovery (WHR) system 22, and an auxiliary boiler 24.
  • the WHR 22 is excluded from the combined cycle system 10.
  • the auxiliary boiler 24 may be completely separate from the HRSG 16, such that the auxiliary boiler 24 and the HRSG 16 operate separate or independent from one another.
  • the gas turbine system 12 is driven by hot combustion gases, and outputs an exhaust gas 152.
  • the HRSG 16 recovers heat from the exhaust gas 152 to generate steam, which then drives the steam turbine system 14.
  • the auxiliary boiler 24 may be integrated into the combined cycle system 10 as an additional source of steam to support the steam turbine system 14 and/or otherwise meet the steam demands of the combined cycle system 10.
  • the auxiliary boiler 24 is integrated with the steam turbine system 14, wherein the steam turbine system 14 may receive a main supply of steam from the HRSG 16 while receiving additional steam from the auxiliary boiler 24, such that steam may be extracted from the steam turbine system 14 for use in the gas treatment system 18 (e.g., one or more gas capture systems 20) regardless of the operating mode (e.g., part load or full load operating conditions of the combined cycle system 10). Integration of the auxiliary boiler 24 with the steam turbine system 14 is discussed in more detail below.
  • the combined cycle system 10 may or may not also include the WHR system 22, which may recover heat from the exhaust gas 184 to obtain heated fluid 26 for use in the gas treatment system 18.
  • the one or more gas capture systems 20 of the gas treatment system 18 are configured to capture an undesirable gas (e.g., CO ) from a gas, such as the exhaust gas 152 and/or air.
  • the gas capture systems 20 may include sorbent-based gas capture systems, solvent-based gas capture systems, cryogenic gas capture systems, or any combination thereof.
  • the gas turbine system 12 may include an intake section 40, a compressor or compressor section 42, a combustor section 44, a gas turbine or turbine section 46, and an exhaust section 48.
  • the exhaust section 48 includes an exhaust stack and/or exhaust duct coupled to the HRSG 16.
  • the compressor section 42 may include at least one shaft 50 disposed along the rotational axis 36, a casing 52 (e.g., annular casing) disposed circumferentially about the at least one shaft 50, a plurality of rotating compressor blades 54 extending radially outward from the at least one shaft 50, and a plurality of stationary compressor vanes 56 extending radially inward from the casing 52 toward the at least one shaft 50.
  • the compressor section 42 may include a plurality of compressor stages 58, each having a plurality of the compressor vanes 56 spaced circumferentially about the at least one shaft 50 at an axial position, and a plurality of the compressor blades 54 spaced circumferentially about the at least one shaft 50 at a different axial position (i.e., the compressor vanes 56 and the compressor blades 58 are axially spaced apart).
  • the compressor section 42 is configured to receive a flow of an intake gas 60 from the intake section 40 and to progressively compress the intake gas 60 through the plurality of compressor stages 58.
  • the intake gas 60 may include an intake air, an exhaust gas recirculation (EGR) flow or recirculated exhaust gas, or a combination thereof.
  • EGR exhaust gas recirculation
  • the combustor section 44 may include one or more combustors 62, such as a single annular combustor disposed circumferentially about the rotational axis 36 or a plurality of combustors 62 circumferentially spaced about the rotational axis 36.
  • each combustor 62 includes a head end portion 64 coupled to a combustion portion 66.
  • the combustion portion 66 includes a combustion chamber 68, a combustor liner 70 disposed circumferentially about the combustion chamber 68, a flow sleeve 72 disposed circumferentially about the combustor liner 70, and a passage 74 extending between the combustor liner 70 and the flow sleeve 72.
  • the passage 74 is configured to route a compressed gas flow in an upstream direction 76 toward a head end chamber 78 disposed in the head end portion 64.
  • the head end chamber 78 and the combustion chamber 68 of the combustor 62 are separated or divided from one another by an intermediate plate 80.
  • a plurality of fuel nozzles 82 are coupled to the intermediate plate 80 and an end plate 84 of the head end portion 64.
  • each combustor 62 receives a compressed gas 86 (e.g., air, EGR, etc.) from the compressor section 42, routes the compressed gas 86 along the passage 74 toward the head end chamber 78 as indicated by arrow 76, and routes the compressed gas through the fuel nozzles 82 into the combustion chamber 68.
  • a compressed gas 86 e.g., air, EGR, etc.
  • each combustor 62 may receive one or more fuel flows from a fuel system 88 coupled to the fuel nozzles 82, wherein the fuel system 88 includes a fuel supply system 90 coupled to one or more fuel circuits 92.
  • the fuel circuits 92 may include fuel circuits 94, 96, and 98 coupled to different sets of the fuel nozzles 82.
  • the fuel circuits 92 (e.g., 94, 96, and 98) may include fuel conduits, fuel manifolds, fuel valves, pressure regulators, and other flow controls.
  • the fuel system 88 is configured to supply one or more fuels, such as liquid and/or gas fuels, into each of the fuel nozzles 82 for injection into the combustion chamber 68.
  • the fuels may include natural gas, syngas generated from a gasifier, methane, hydrogen, biofuel, fuel oils, or any combination thereof.
  • the fuel supply system 90 may include a plurality of components to control flows of the various fluids to the combustor 62.
  • the fuel supply system 90 may include one or more components 100.
  • the components 100 may include one or more fuel tanks, fuel pumps, valves, pressure regulators, flow regulators, filters, water removal units, particulate removal units, manifolds, flow controllers, or any combination thereof.
  • the fuel nozzles 82 are configured to inject one or more fuels from the fuel system 88 and the compressed gas 86 from the compressor section 42.
  • the fuel nozzles 82 are configured to inject a compressed air 104 from a compressor system 106 having an air compressor 108 coupled to a drive 110, such as an electric motor, a combustion engine, a shaft coupled to the gas turbine system 12, or another suitable drive.
  • the compressor system 106 may be configured to receive air from ambient and/or from the intake section 40. Additionally, the compressor system 106 may be configured to enable multiple modes of operation, such as EGR mode or non-EGR mode.
  • the compressor section 42 supplies the compressed gas 86 (e.g., compressed exhaust gas) to each combustor 62, while the compressor system 106 supplies the compressed air 104 to each combustor 62.
  • the compressed gas 86 e.g., compressed exhaust gas
  • the compressor section 42 supplies the compressed gas 86 (e.g., compressed air) to each combustor 62 without any need for additional air supplies.
  • the compressor system 106 may optionally supply the compressed air 104 to each combustor 62.
  • the fuel may be combusted with the air in the combustion chamber 68 of each combustor 62, thereby generating a hot combustion gas 112 for delivery from the combustion chamber 68 into the turbine section 46.
  • the turbine section 46 includes at least one shaft 114 disposed along the rotational axis 36, a casing 116 (e.g., annular casing) disposed circumferentially about the at least one shaft 1 14, a plurality of rotating turbine blades 1 18 extending radially outward from the at least one shaft 114, and a plurality of stationary turbine vanes 120 extending radially inward from the casing 116 toward the at least one shaft 114.
  • a casing 116 e.g., annular casing
  • the turbine section 46 may include a plurality of turbine stages 122, each having a plurality of the turbine vanes 120 spaced circumferentially about the at least one shaft 114 at an axial position, and a plurality of the turbine blades 118 spaced circumferentially about the at least one shaft 114 at a different axial position (i.e., the turbine vanes 120 and the turbine blades 118 are axially spaced apart).
  • the at least one shaft 114 also may be coupled to the at least one shaft 50 of the compressor section 42 via at least one intermediate shaft 124. Additionally, the at least one shaft 114 may be coupled to a load 126 via a shaft 128.
  • the load 126 may include an electrical generator, a machine, a propulsion system for a vehicle, or any other suitable load.
  • the load 126 may be an electrical generator, such that the combined cycle system 10 is a combined cycle power plant.
  • the combustion gas 112 flows from the combustor 62 into the turbine section 46, wherein the combustion gas 112 progressively expands and drives rotation of the turbine blades 118 coupled to the at least one shaft 114 in each of the turbine stages 122.
  • the combustion gas 112 drives the turbine section 46, which in turn drives the compressor section 42 and the load 126 via the interconnected shafts 50, 124, 114, and 128.
  • the gas turbine system 12 may be configured with a common rotational direction of the shafts 50, 114, 124, and 128 and the connected compressor blades 54 and turbine blades 118.
  • the shafts 50, 114, 124, and 128 may be removably coupled together with shaft connections, such as flanged joints.
  • some of the shafts may be combined to reduce the number of shafts.
  • all of the illustrated shafts 50, 114 and 124 may represent a common shaft rotating in the common rotational direction, such as a clockwise or counter-clockwise rotational direction.
  • the gas turbine system 12 can be configured with or without the compressor system 106 and an exhaust gas recirculation (EGR) system 150.
  • the EGR system 150 is configured to recirculate an exhaust gas 152 output by the turbine section 46 back into the compressor section 42 (e.g., via intake section 40) for compression and delivery to the combustor section 44.
  • the gas turbine system 12 may exclude the EGR system 150 and intake only an airflow into the intake section 40 for compression by the compressor section 42.
  • the recirculated exhaust gas 152 flows through the intake section 40 and each of the compressor stages 58 of the compressor section 42, thereby compressing the recirculated exhaust gas as the compressed gas 86 for delivery into combustor section 44.
  • the combustor section 44 may receive compressed air 104 from the air compressor 108 of the compressor system 106 through the fuel nozzles 82.
  • the combustor section 44 also receives the fuel from the fuel system 88, such as through the fuel nozzles 82.
  • the fuel from the fuel system 88 then combusts with the air from the compressor system 106 to generate the combustion gases 112, which then flow through the turbine section 46 to drive rotation of the turbine blades 118 in each of the turbine stages 122.
  • the recirculated exhaust gas helps to reduce the temperature and formation of certain emissions (e.g., nitrogen oxides (NOx)) associated with combustion in the combustor section 44.
  • NOx nitrogen oxides
  • the compressor section 42 receives an airflow from the intake section 40, progressively compresses the airflow via the compressor stages 58, and delivers the compressed airflow as the compressed gas 86 into the combustor section 44.
  • the compressed airflow then facilitates combustion of the fuel from the fuel system 88, thereby generating the hot combustion gases 112 for delivery to the turbine section 46.
  • the compressor system 106 may be excluded or included to provide additional compressed air 104 to the combustor section 44.
  • the combustion gas 112 drives rotation of the turbine blades 118 in the turbine stages 122, thereby rotating the at least one shaft 114 coupled to the at least one shaft 50 of the compressor section 42 and the shaft 128 driving the load 126.
  • the exhaust gas 152 output by the turbine section 46 may then pass through the HRSG 16 for transfer of heat from the exhaust gas into water to generate steam for the steam turbine system 14.
  • the HRSG 16 may include a first pressure section 160 (e.g., high-pressure (HP) section), a second pressure section 162 (e.g., intermediate-pressure (IP) section), and a third pressure section 164 (e.g., low-pressure (LP) section) in a series arrangement, thereby generating a high-pressure steam 166, an intermediate-pressure steam 168 and a low-pressure steam 170.
  • HP high-pressure
  • IP intermediate-pressure
  • LP low-pressure
  • the heat recovery steam generator 16 may route the high-pressure steam 166 to a high-pressure steam turbine 172, the intermediate-pressure steam 168 to an intermediate-pressure steam turbine 174, and the low-pressure steam 170 to a low- pressure steam turbine 176 of the steam turbine system 14.
  • the auxiliary boiler 24 may be integrated with the steam turbine system 14 to provide supplemental steam at variable steam pressures, depending on energy and load demands.
  • the auxiliary boiler 24 may include multiple steam injection or supply points for steam injection to the high-pressure steam turbine 172, the intermediate-pressure steam turbine 174, or both, as depicted in FIG. 1.
  • the auxiliary boiler 24 may be configured to have a steam outlet directly to the gas treatment system 18.
  • supplemental steam directly from the auxiliary boiler 24 and/or excess steam from the steam turbine system 14 may be directed to the gas treatment system 14 to help support gas capture in the gas treatment system 14. In this way, excess or waste steam may be used to support the one or more gas capture systems 20 of the gas treatment system 18.
  • the steam drives rotation of blades within each of the steam turbines 172, 174, 176, thereby driving a shaft 178 coupled to a load 180, such as an electrical generator.
  • the low-pressure steam turbine 176 also may return a condensate 182 through a return line 181 back to the low-pressure section 164 of the HRSG 16 via a pump 183. Additionally, the low-pressure steam turbine 176 may return the condensate 182 to the auxiliary boiler 24.
  • the HRSG 16 may then output the exhaust gas 152 as a partially-cooled exhaust gas 184.
  • the exhaust gas 184 may he partially or entirely directed through an exhaust stack, the gas treatment system 18, the EGR system 150, or a combination thereof.
  • the combined cycle system 10 may include an exhaust stack downstream from the gas turbine system 12, the HRSG 16, the gas treatment system 18, or any combination thereof. However, in certain embodiments, the combined cycle system 10 excludes the HRSG 16 and/or the steam turbine system 14.
  • the exhaust gas 152 output by the turbine section 46 and/or the exhaust gas 184 output by the HRSG 16 may pass through the WHR system 22 for transfer of heat from the exhaust gas into the gas treatment system 18.
  • the gas treatment system 18 includes one or more gas capture systems 20.
  • the gas capture systems 20 may include any one or any combination of gas capture systems 190, 192, and 194, each having a plurality of components (e.g., components 196, 198, 200, and 202).
  • the gas capture systems 20 (e.g., 190, 192, and 194) are configured to obtain a captured gas 204 from the intake gas 60 and/or the exhaust gas 152, 184.
  • the gas capture systems 20 may capture and output carbon dioxide (CO2) as the captured gas 204, which may further be directed to a compression system 206.
  • the compression system 206 may include one or more compressors configured to compress the captured gas 204 (e.g., CO2) and deliver the captured gas to storage and/or a pipeline 208.
  • the gas capture system 190 is disposed at, in, or upstream of the intake section 40 for capturing undesirable gases from the intake air.
  • the gas capture systems 192 and 194 are disposed downstream of the gas turbine system 12 and/or the HRSG 16 for capturing undesirable gases from the exhaust gas 152, 184.
  • the gas capture systems 20 (e.g., 190, 192, and 194) may include sorbent-based gas capture systems, solvent-based gas capture systems, cryogenic gas capture systems, or any combination thereof, configured to remove and capture undesirable gases.
  • the gas capture systems 20 may be configured to remove and capture undesirable gases, such as carbon oxides (COx) (e.g., carbon dioxide (CO2) and carbon monoxide (CO)), and thus the gas capture systems 20 may be described as carbon capture systems.
  • COx carbon oxides
  • CO2 carbon dioxide
  • CO2 carbon monoxide
  • the gas capture systems 20 may be configured to remove and capture undesirable gases, such as nitrogen oxides (NOx) (e.g., nitrogen dioxide (NO2)), and thus the gas capture systems 20 may be described as NOx capture systems.
  • NOx nitrogen oxides
  • the gas capture systems 20 may be configured to remove and capture undesirable gases, such as sulfur oxides (SOx) (e.g., sulfur dioxide (SO2)), and thus the gas capture systems 20 may be described as SOx capture systems.
  • SOx sulfur oxides
  • the gas capture systems 20 e.g., 190, 192, and 194 may be described as sorbent-based carbon capture systems using sorbent materials as an example and/or solvent based carbon capture systems using liquid absorbents (e.g., solvents) as an example.
  • the carbon capture systems may include membrane-based carbon capture systems, cryogenic based carbon capture systems, or any combination thereof.
  • the embodiments disclosed herein may use any type or configuration of gas capture systems 20 (e.g., 190, 192, and 194) as noted above.
  • Each of the gas capture systems 20 may include components 196, 198, 200, and 202. Additionally, one or more components 210 (e.g., WHR system 22 and components 212, 214, and 216) may be disposed upstream from the gas capture systems 192 and 194.
  • the components 196, 198, 200, and 202 may include sorbent materials disposed on or in ducts (e.g., adsorption duct, desorption duct, and cooling duct), contactors, cartridges, moving beds, rotating wheels, cartridges, or any combination thereof, along a flow path of the intake gas 60 and/or the exhaust gas 152, 184.
  • the sorbent-based gas capture systems 20 are configured to adsorb the undesirable gases (e.g., CO2) into the sorbent materials in an adsorption mode and desorb the undesirable gases from the sorbent materials in a desorption mode.
  • the components 196, 198, 200, and 202 may include cooling systems to help control the temperature of the sorbent materials (e.g., maintain sorbent temperatures within upper and lower temperature thresholds) to improve efficiency of the adsorption mode.
  • the cooling systems may include heat exchangers (e.g., fin and tube heat exchangers), heat pipes, and other thermal control systems coupled to the sorbent materials to help control the temperature of the sorbent materials.
  • the components 196, 198, 200, and 202 also may include heating systems, such as heated fluid systems (e.g., steam systems, electrical heaters, waste heat systems, etc.), configured to apply heat to the sorbent materials to desorb the undesirable gases from the sorbent materials during the desorption mode.
  • heated fluid systems e.g., steam systems, electrical heaters, waste heat systems, etc.
  • the auxiliary boiler 24 is configured to provide supplemental steam to the steam turbine system 14, the gas treatment system 18, or both.
  • the components 196, 198, 200, and 202 also may include cooling systems, such as cooling fluid systems (e.g., gas cooling systems, liquid cooling systems, etc.), configured to apply a cooling fluid to the sorbent materials during a cooling mode.
  • the sorbent-based gas capture systems 20 also may include other suitable components 196, 198, 200, and 202 in support of the sorbent materials.
  • the components 196, 198, 200, and 202 may include one or more absorbers, one or more strippers, and a solvent circuit through the absorbers and strippers.
  • the absorber is configured to absorb the undesirable gases (e.g., CO2) into a solvent in an absorption mode, thereby outputting a treated gas (e.g., treated air or treated exhaust gas) and a gas-rich solvent (e.g., CO2 rich solvent).
  • the stripper is configured to strip the undesirable gases from the gas-rich solvent in a desorption mode, thereby outputting a gas-lean solvent (e.g., CO2 lean solvent) back to the absorber and outputting the captured gas 204.
  • the components 196, 198, 200, and 202 may include cooling systems coupled to the absorber, wherein the cooling systems are configured to extract heat generated by the absorption mode to help control the temperature of the solvent (e.g., maintain solvent temperatures within upper and lower temperature thresholds) to improve efficiency of the absorption mode.
  • the cooling systems may include heat exchangers (e.g., fin and tube heat exchangers), heat pipes, and other thermal control systems coupled to the absorber to help control the temperature of the solvent.
  • the components 196, 198, 200, and 202 also may include heating systems, such as heated fluid systems (e.g., steam systems, electrical heaters, waste heat systems, etc.), coupled to the strippers, wherein the heating systems are configured to apply heat to the gasrich solvent to desorb the undesirable gases from the gas-rich solvent during the desorption mode.
  • heated fluid systems e.g., steam systems, electrical heaters, waste heat systems, etc.
  • the auxiliary boiler 24 may provide heat in the form of steam directly to the gas treatment system 18, steam indirectly to the gas treatment system 18 via the steam turbine system 14, or a combination thereof, including steam to the gas-rich solvent during the desorption mode.
  • the WHR 22 may also configured to provide excess heat as the heated fluid 26 to the gas-rich solvent during the desorption mode.
  • the components 196, 198, 200, and 202 also may include a reboiler coupled to the stripper, pumps and valves to control a flow of the solvent through the solvent circuit between the absorber and the stripper, and heat exchangers to cool the gas-lean solvent supplied to the absorber and to heat the gas-rich solvent supplied to the stripper.
  • the solvent-based gas capture systems 20 also may include other suitable components 196, 198, 200, and 202 in support of the absorbers and strippers.
  • the components 196, 198, 200, and 202 of the gas capture system 20 and/or the components 210 (e.g., WHR system 22 and components 212, 214, and 216) upstream from the gas capture systems 192 and 194 may include one or more of a dryer or water removal system (e.g., water gas separator), a particulate removal system (e.g., filter and/or solid gas separator), one or more booster fans configured to boost a flow of the gas being treated, one or more coolers, one or more valves to control a flow of gas to the gas capture system 20, a bypass system configured to bypass the gas capture system 20, or any combination thereof.
  • a dryer or water removal system e.g., water gas separator
  • a particulate removal system e.g., filter and/or solid gas separator
  • booster fans configured to boost a flow of the gas being treated
  • coolers e.g., one or more coolers
  • valves e.g., one or more valves to control a
  • the cooler may include a heat exchanger, a direct contact cooler (DCC), or a combination thereof.
  • the heat exchanger is configured to indirectly cool the exhaust gas 184 via heat exchange between the exhaust gas 184 and a cooling fluid (e.g., cooling water).
  • the direct contact cooler is configured to directly cool the exhaust gas 184 via direct injection of a cooling fluid (e.g., cooling water) into the exhaust gas 184.
  • the separators may include gravity separators, centrifugal separators, or a combination thereof.
  • the gas capture systems 20 (e.g., 190, 192, and 194) may be described as multiple gas capture stages.
  • the gas treatment system 18 may include only a single stage and/or gas capture system 20.
  • the gas capture systems 20 may include only one, two, or all three of the gas capture systems 190, 192, and/or 194.
  • the exhaust gas 184 may partially or entirely bypass the gas treatment system 18 and flow to the EGR system 150, and/or the exhaust gas 184 may partially or entirely flow through the gas treatment system 18 before flowing to the EGR system 150.
  • the EGR system 150 may include one or more conduits, valves, flow controls, coolers, blowers, or any combination thereof, configured to provide at least a portion of the exhaust gas 152, 184 (e.g., EGR flow) to the intake section 40 for recirculation through the compressor section 42.
  • the cooler may be configured to cool the exhaust gas 152, 184 to a lower temperature (e.g., approximately ambient temperature) prior to recirculation into the compressor section 42.
  • the combined cycle system 10 also includes a controller 220 coupled to the gas turbine system 12, the steam turbine system 14, the HRSG 16, the gas treatment system 18, the fuel system 88, the EGR system 150, the compression system 106, and various sensors 222 distributed throughout the combined cycle system 10.
  • the controller 220 includes one or more processors 224, memory 226, instructions 228 stored on the memory 226 and executable by the processor 224, and communication circuitry 230 configured to communicate with the sensors 222 and various equipment throughout the combined cycle system 10.
  • the controller 220 is configured to control the fuel delivery and distribution from the fuel system 88 to the fuel nozzles 82 in the combustor section 44.
  • the controller 220 is configured to control operation of the gas capture systems 20 (e.g., 190, 192, and 194), such by controlling modes of operation (e.g., adsorption mode, desorption mode, cooling mode), controlling the WHR system 22, the steam turbine system 14, and the auxiliary boiler 24 (e.g., integrated with the steam turbine system 14) to control the flow and temperature of the excess heat or steam provided to the gas capture systems 20, controlling flows of various fluids through the gas capture systems 20, or any combination thereof.
  • modes of operation e.g., adsorption mode, desorption mode, cooling mode
  • controlling the WHR system 22 e.g., the steam turbine system 14
  • the auxiliary boiler 24 e.g., integrated with the steam turbine system 14
  • the sensors 222 are configured to monitor various operational parameters of the combined cycle system 10.
  • the sensors 222 include temperature sensors, pressure sensors, flow rate sensors, fluid composition sensors (e.g., gas composition sensors), vibration sensors, clearance sensors, speed sensors, humidity and/or moisture sensors, or any combination thereof.
  • the sensors 222 may monitor the parameters (e.g., temperature, pressure, flow rate, and fluid composition) at one or more locations of the compressor section 42, the combustor section 44, the turbine section 46, the gas treatment system 18, the WHR system 22, the auxiliary boiler 24, the steam turbine system 14, the heated fluid 26, or any combination thereof.
  • the sensors 222 may monitor compressor parameters (e.g., pressure ratio between the inlet and outlet of the compressor section 42), combustion gas parameters (e.g., firing temperature and combustion dynamics), turbine parameters (e.g., temperature and pressure at each turbine stage, the turbine inlet, and the turbine exhaust), and exhaust gas emissions.
  • the exhaust gas emissions monitored by the sensors 222 may include carbon oxides (COx) such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NOx) such as nitrogen dioxide (NO2), sulfur oxides (SOx) such as sulfur dioxide (SO2), unbumt hydrocarbons, particulate matter, and other undesirable exhaust emissions.
  • COx carbon oxides
  • NOx nitrogen oxides
  • SOx sulfur oxides
  • SO2 sulfur oxides
  • the sensors 222 may monitor the temperature, pressure, and flow rate of the heated fluid 26 provided to the gas capture systems 20, the temperature, pressure, and flow rate of steam provided to the gas capture systems 20 via the steam turbine system 14 and/or the auxiliary boiler 24, the temperature of the sorbent materials in sorbent-based gas capture systems, the temperature of solvent in solvent-based gas capture systems, or any combination thereof.
  • the controller 220 may adjust the operating mode, fluid flows, heating, cooling, or any combination thereof, in the gas capture systems 20.
  • the controller 220 may adjust the supply of steam from the auxiliary boiler 24 to the steam turbine system 14 and the supply of steam from the auxiliary boiler 24 and/or the steam turbine system 14 to the gas capture systems 20. For example, in a full load operating mode, the controller 220 may control the auxiliary boiler 24 to provide the steam to the high-pressure steam turbine 172, and vary the steam parameters (e.g., temperature, pressure, and flow rate) to accommodate the full load operating mode).
  • the controller 220 may control the auxiliary boiler 24 to provide the steam to the high-pressure steam turbine 172, and vary the steam parameters (e.g., temperature, pressure, and flow rate) to accommodate the full load operating mode).
  • the controller 220 may control the auxiliary boiler 24 to provide the steam to the high-pressure steam turbine 172, the intermediate-pressure steam turbine 174, or a combination thereof, and vary the steam parameters (e.g., temperature, pressure, and flow rate) to accommodate the part load operating mode).
  • the controller 220 may control the auxiliary boiler 24 to provide the steam only to the steam turbine system 14 for indirect supply to the gas capture systems 20, only directly to the gas capture systems 20, or a combination of supply to both the steam turbine system 14 and the gas capture systems 20.
  • the controller 220 may control an extraction of steam (e.g., via control of valves) from the steam turbine system 14 to the gas capture systems 20.
  • the controller 220 may control an extraction of the steam from one or more extraction points of the steam turbine system 14 via one or more valves along steam extraction conduits, such as from the intermediate-pressure steam turbine 174, the low-pressure steam turbine 176, or from between the steam turbines 174 and 176.
  • the controller 220 may control the auxiliary boiler 24 to adjust (e.g., increase or decrease) the steam temperature, pressure, and flow rate depending on the operating mode of the combined cycle system 10, the conditions in the steam turbine system 14, the main steam supply by the HRSG 16, the demands of the gas capture systems 20, and the steam injection locations from the auxiliary boiler 24 to the steam turbine system 14 and the gas capture systems 20.
  • the auxiliary boiler 24 comprises a variable pressure boiler to accommodate the different pressure needs during the different operating modes of the combined cycle system 10.
  • one or more constant pressure boilers 24 may be coupled to the steam turbine system 14.
  • the auxiliary boiler 24 may supply the steam only to the steam turbine system 14 for indirect supply from the steam turbine system 14 to the gas capture systems 20.
  • FIGS. 2 and 3 present embodiments of the sorbent-based and solvent-based gas capture systems using steam from the integrated steam turbine system 14 and auxiliary boiler 24.
  • FIG. 2 is a schematic of an embodiment of a gas capture system 20 of the gas treatment system 18 of FIG. 1, illustrating a sorbent-based gas capture system 250 using steam from the integrated steam turbine system 14 and auxiliary boiler 24.
  • the sorbent-based gas capture system 250 includes a plurality of sorbent-based gas capture assemblies or units 252 (e.g., adsorbers or adsorption units) associated with a plurality of respective conduits 254, such as conduits 256, 258, and 260 (e.g., sorbent-containing conduits).
  • the sorbent-based gas capture units 252 may include temperature swing adsorption (TSA) units or adsorbers, wherein a temperature swing or change is used to alternatively operate in an adsorption mode at a first temperature and a desorption mode at a second temperature.
  • TSA temperature swing adsorption
  • the first temperature is lower than the second temperature.
  • the lower first temperature enables the sorbent-based gas capture units 252 to adsorb the undesirable gas, where lower temperatures generally increase a capacity for adsorbing the undesirable gas.
  • the higher second temperature enables the sorbent-based gas capture units 252 to desorb the undesirable gas, which can then be captured and used in other downstream processes.
  • the sorbent-based gas capture units 252 include sorbent-based gas capture units 252A, 252B, and 252C associated with the conduits 256, 258, and 260.
  • the conduits 254 e.g., 256, 258, and 260
  • the conduits 254 may be sorbent- lined along interior surfaces, sorbent-packed within interior volumes, or generally filled with at least 10, 20, 30, 40, 50, 60, 70, 80, 90, or more percent by volume of sorbent material.
  • the sorbent-based gas capture unit 252 may include any number of conduits 254, such as 2, 3, 4, 5, 6, 7, 8, 9, 10, or more, which are configured in parallel and/or series.
  • Each of the conduits 254 (e.g., 256, 258, and 260) includes an outer conduit wall 262 disposed circumferentially about a flow path 264 (e.g., fluid passage or bore) along a central axis 266 from an inlet 268 to an outlet 270, wherein a sorbent material 272 is disposed along an interior surface 274 of the outer conduit wall 262 and/or along an exterior surface 276 of a plurality of contactors 280 (e.g., contactor plates, panels, or fins).
  • the contactors 280 are arranged parallel to one another and parallel to the central axis 266.
  • Each of the conduits 254 (e.g., 256, 258, and 260) may include a contactor assembly 278 having any number of the contactors 280, such as 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, or more contactors 280.
  • Each of the contactors 280 has a body 284 with the exterior surface 276 disposed about an interior portion 286.
  • the sorbent material 272 is disposed along the exterior surface 276, while the interior portion 286 includes a material 282 different than the sorbent material 272.
  • the body 284 may be a solid body throughout the interior portion 286, wherein the body 284 is at least substantially or completely made with the sorbent material 272 throughout the interior portion 286 to the exterior surface 276.
  • the body 284 may be a hollow body in the interior portion 286 (e.g., interior chamber or cavity), wherein the body 284 has an outer wall 288 disposed about the interior portion 286.
  • the interior portion 286 may include a heat exchange circuit or flow path extending throughout the body 284 between a fluid inlet and a fluid outlet, which may be coupled to a heat exchange circuit for cooling and/or heating.
  • the interior portion 286 may be configured to circulate a cooling fluid during an adsorption mode, a heating fluid (e.g., steam from the WHR 22, steam from the steam turbine system 14, and/or steam from the auxiliary boiler 24) during a desorption mode, and a cooling fluid during a cooling mode of the sorbent-based gas capture system 250.
  • a heating fluid e.g., steam from the WHR 22, steam from the steam turbine system 14, and/or steam from the auxiliary boiler 24
  • the gas capture system 20 is configured to sequentially and repeatedly operate in a cycle of: (1) an adsorption mode, (2) a desorption mode, and (3) a cooling mode for each of the sorbent-based gas capture units 252A, 252B, and 252C.
  • the temperature of the sorbent material 272 directly affects the adsorption efficiency of the sorbent material 272 during the adsorption mode.
  • the sorbent material 272 may have an optimal temperature or temperature range for efficient adsorption of the undesirable gases.
  • the adsorption of the undesirable gases into the sorbent material 272 is an exothermic process, which generates heat that generally increases the temperature of the sorbent material 272 and reduces its adsorption efficiency without any cooling of the sorbent material 272.
  • the disclosed embodiments may control the cooling of the sorbent material 272 during the adsorption mode to improve the adsorption efficiency.
  • the temperature of the sorbent material 272 directly affects the desorption efficiency of the sorbent material 272 during the desorption mode.
  • the sorbent material 272 may have an optimal temperature or temperature range for efficient desorption of the undesirable gases.
  • the disclosed embodiments may control the heating of the sorbent material 272 during the desorption mode to improve the desorption efficiency.
  • the controller 220 may be configured to control the WHR system 22, the steam turbine system 14, and the auxiliary boiler 24 to control the heated gas and/or steam supplied to each of the sorbent-based gas capture units 252A, 252B, and 252C during the desorption mode alone or in combination with other heated fluids.
  • the temperatures in the adsorption mode, the desorption mode, and the cooling mode may vary depending on the particular application.
  • the adsorption mode may be configured to adsorb undesirable gas from a gas 340 into the sorbent material 272 at a first temperature
  • the desorption mode may be configured to desorb the undesirable gas from the sorbent material 272 using a heat source (e.g., steam from the steam turbine system 14 and/or the auxiliary boiler 24) at a second temperature
  • the cooling mode may be configured to cool the sorbent material 272 using a cooling source (e.g., cooling fluid) at a third temperature, wherein the second temperature is greater than the first and third temperatures, and the third temperature is lesser than the first and third temperatures.
  • a cooling source e.g., cooling fluid
  • the first temperature may be approximately 40 degrees Celsius (e.g., plus or minus 5, 10, 15, or 20 degrees Celsius)
  • the second temperature may be equal to or greater than approximately 100, 110, 120, 130, 140, or 150 degrees Celsius
  • the third temperature may be less than or equal to approximately 0, 5, 10, 15, 20, 25, or 30 degrees Celsius.
  • the gas capture system 20 includes a thermal control system 290 having a fluid circulation system 292, one or more fluid circulation circuits 294 (e.g., fluid conduits, manifolds, valves, etc.), and one or more heat exchangers 296 coupled to each contactor assembly 278 in the sorbent-based gas capture units 252A, 252B, and 252C.
  • the heat exchangers 296 may include one or more heat exchange flow paths coupled to and/or extending through each contactor assembly 278.
  • the heat exchangers 296 also may include a plurality of heat pipes 298, wherein each contactor assembly 278 includes one or more heat pipes 298 coupled to and/or extending through each contactor 280 in the contactor assembly 278.
  • the fluid circulation system 292 may include a plurality of components, such as components 300, 302, and 304, such as heat exchangers, pumps, valves, coolant supplies, or any combination thereof.
  • the thermal control system 290 may circulate a thermal fluid (e.g., liquid or gas thermal fluid) from the fluid circulation system 292 through the fluid circulation circuits 294 and the heat exchangers 296 to exchange heat between the thermal fluid and the contactors 280 and the sorbent materials 272 during any one or all of the operating modes (e.g., adsorption mode, desorption mode, and/or cooling mode).
  • a thermal fluid e.g., liquid or gas thermal fluid
  • the fluid circulation circuits 294 may include independent fluid circulation circuits for each of the contactor assemblies 278, such that the thermal control system 290 can independently control the temperature for each of the contactor assemblies 278 depending on the operating modes (e.g., adsorption mode, desorption mode, and/or cooling mode) of the sorbent-based gas capture units 252A, 252B, and 252C.
  • the thermal control system 290 is configured to circulate the thermal fluid (e.g., coolant or cooling fluid at a relatively lower temperature) during the adsorption mode and the cooling mode, thereby cooling the contactors 280 and the sorbent materials 272.
  • the thermal control system 290 is configured to circulate the thermal fluid (e.g., heated or heating fluid at a relatively higher temperature) during the desorption mode, thereby heating the contactors 280 and the sorbent materials 272 to facilitate desorption.
  • the thermal fluid may include the steam from the steam turbine system 14 and/or steam from the auxiliary boiler 24, for example, during the desorption mode.
  • the sorbent material 272 may cover, coat, or generally line at least 50, 60, 70, 80, 90, 95, or 100 percent of the interior surface 274 of the outer conduit wall 262, the exterior surface 276 of the contactors 280, and/or other structures within the conduits 254.
  • the contactors 280 may include rectangular plates, airfoil shaped panels, a parallel arrangement of tubes, a grid arrangement of tubes, a plurality of cartridges, radial projections, baffles, fins, honeycomb structures, a plurality of contactor elements supported in a bundle, or any combination thereof.
  • the plurality of contactor elements may include a plurality of particles, beads, strips, strands, mesh, or other distributed structures, which leave voids for fluid flow. Additionally or alternatively, the sorbent material 272 may at least partially fill or pack an interior volume of the central bore or interior surface 274, such that voids remain to facilitate fluid flow (e.g., a void fraction of less than or equal to 10, 20, 30, 40, or 50 percent).
  • the central axis 266 extending from the inlet 268 to the outlet 270 may define the flow path 264 as a linear flow path, a curved flow path, a winding or serpentine flow path, a spiral or helical flow path, a tortuous flow path, an expanding and contracting flow path, a flow path with splits and/or unions, or any combination thereof.
  • the flow path 264 may be defined as a tortuous flow path and include any number or configuration of the foregoing flow paths.
  • the sorbent material 272 may include one or more sorbent materials configured to adsorb the undesirable gases, such as sorbent materials designed or suitable for adsorption of carbon oxides (COx) such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NOx), sulfur oxides (SOx) such as sulfur dioxide (SO2), methane (CH4), or any other undesirable gases as described herein or subject to regulations and/or considered greenhouse gases.
  • the sorbent materials 272 may include porous, solid-phase materials, including mesoporous silicas, zeolites (e.g., aluminosilicates), and metal-organic frameworks (MOFs) and covalent organic frameworks (COFs).
  • the foregoing sorbent materials 272 may be particularly well- suited for CO2 adsorption in the sorbent-based gas capture unit 252. However, any suitable sorbent materials 272 may be used depending on the desired target for gas capture of undesirable gases. In certain embodiments, a plurality of the sorbent-based gas capture systems 250 may be used in series, wherein each of the sorbent-based gas capture system 250 uses the same or different sorbent materials 272 to remove and capture the same or different undesirable gases in stages.
  • the sorbent-based gas capture system 250 may be configured to alternate each of the sorbent-based gas capture units 252A, 252B, and 252C associated with the conduits 256, 258, and 260 between the adsorption mode (e.g., adsorbing the undesirable gases into the sorbent material 272), the desorption mode (e.g., desorbing the undesirable gases from the sorbent material 272), and the cooling mode (e.g., cooling the sorbent material 272) using the controller 220 and the sensors 222.
  • the adsorption mode e.g., adsorbing the undesirable gases into the sorbent material 272
  • the desorption mode e.g., desorbing the undesirable gases from the sorbent material 272
  • the cooling mode e.g., cooling the sorbent material 272
  • the controller 220 is configured to control the sorbent-based gas capture system 250 to perform a staggered operational cycle of the sorbent-based gas capture units 252A, 252B, and 252C between the different operating modes (e.g., adsorption mode, desorption mode, and cooling mode). For example, for a first duration of time, the controller 220 may operate the sorbent-based gas capture unit 252A in the adsorption mode, the sorbent-based gas capture unit 252B in the desorption mode, and the sorbentbased gas capture unit 252C in the cooling mode.
  • the controller 220 may operate the sorbent-based gas capture unit 252A in the adsorption mode, the sorbent-based gas capture unit 252B in the desorption mode, and the sorbentbased gas capture unit 252C in the cooling mode.
  • the controller 220 may operate the sorbent-based gas capture unit 252A in the desorption mode, the sorbent-based gas capture unit 252B in the cooling mode, and the sorbent-based gas capture unit 252C in the adsorption mode.
  • the controller 220 may operate the sorbent-based gas capture unit 252A in the cooling mode, the sorbent-based gas capture unit 252B in the adsorption mode, and the sorbent-based gas capture unit 252C in the desorption mode.
  • the sorbent-based gas capture system 250 also may be configured to simultaneously operate multiple units (e.g., 2, 3, 4, or more) of the sorbent-based gas capture units 252 in each of the operating modes, such as multiple units 252 in the adsorption mode, multiple units 252 in the desorption mode, and multiple units 252 in the cooling mode.
  • the multiple units 252 may be arranged in series, in parallel, or a combination thereof.
  • the controller 220 is configured to alternate the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) between the adsorption, desorption, and the cooling modes via a plurality of support systems.
  • the support systems may include the thermal control system 290, an upstream flow distribution system 310, and a downstream flow distribution system 312.
  • the upstream flow distribution system 310 includes a gas supply system 314 (or gas intake system), a heating fluid supply system 316 (e.g., heated gas and/or heated liquid supply system), and a cooling fluid supply system 318, while the downstream flow distribution system 312 includes a post-adsorption processing system 320 (e.g., after the adsorption mode), a post-desorption processing system 322 (e.g., fluid processing system after the desorption mode), and a post-cooling system 324 (e.g., after the cooling mode).
  • the gas supply system 314 of the upstream flow distribution system 10 is configured to provide a gas 340 (e.g., intake gas 60 or exhaust gas 152, 184) to enable the adsorption mode when selectively operating each of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) in the adsorption mode via the controller 220.
  • a gas 340 e.g., intake gas 60 or exhaust gas 152, 184
  • each of the sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the gas supply system 314 includes a gas pre-treatment system 330 having one or more gas pre-treatment components 332, 334, and 336, which may be configured to process, adjust, and/or control characteristics of the gas 340 upstream from the conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., units 252A, 252B, and 252C).
  • the gas pre-treatment component 332 may include a thermal control component (e.g., gas temperature control component), such as a heat exchanger, a heater, a cooler, or any combination thereof, configured to adjust (e.g., increase or decrease) a temperature of the gas 340.
  • a thermal control component e.g., gas temperature control component
  • the heat exchanger may exchange heat with steam, water, exhaust gas, compressor bleed flow, waste heat, or some other thermal fluid.
  • a waste heat recovery system may be used for heat transfer in the heat exchanger.
  • the gas pre-treatment component 334 may include a pressure control component, such as a pressure regulator, an expander or expansion chamber, a constrictor or constriction chamber, a fan or pump to add energy, a turbine to extract energy, or another suitable pressure controller.
  • the gas pre-treatment component 336 may include one or more contaminant removal units, such as a particulate filter, a moisture removal unit or dryer, a chemical removal unit, and/or other removal units configured clean the gas 340.
  • the gas pre-treatment component 336 may include a humidity controller configured to maintain a desired relative humidity of the gas 340 being received into the sorbent-based gas capture system 250.
  • the gas supply system 314 also may include one or more valves 342 configured to control the distribution of the gas 340 to the plurality of conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 344, 346, and 348.
  • valves 342 configured to control the distribution of the gas 340 to the plurality of conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 344, 346, and 348.
  • valves 342 may include one or more multi-way valves and/or distribution manifolds to independently distribute the gas 340 through the distribution conduits 344, 346, and/or 348 to the respective sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) when operating in an adsorption mode in response to control signals from the controller 220.
  • the respective sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the heating fluid supply system 316 of the upstream flow distribution system 310 is configured to supply a heating fluid to enable the desorption mode when selectively operating each of the sorbent-based gas capture units 252 (e.g., 252 A, 252B, and 252C) in the desorption mode via the controller 220.
  • the heating fluid supply system 316 also may coordinate with a vacuum system of the post-desorption processor 442.
  • the heating fluid supply system 316 includes one or more heating fluid supplies 350, such as one or more steam supplies, heated water supplies, heated gas supplies, and/or waste heat supplies.
  • the heating fluids also may be described as sweep fluids, such as a sweep gas or a sweep steam.
  • the heating fluid supplies 350 may include the steam turbine system 14, the HRSG 16, the waste heat recovery system 22 (e.g., recovering heat from compressors, pumps, generators, reactors, or other power plant equipment), the auxiliary boiler 24 (e.g., directly or indirectly through the steam turbine system 14), or any combination thereof.
  • the WHR 22 uses waste heat recovered from the exhaust gas 152, 184 and provides the heated fluid 26 for use as the heating fluid 354.
  • the heated fluid 26 (e.g., waste heat recovery fluid) also may be described as an excess heat or waste heat recovered for use in the heating fluid supply system 316 of the sorbent-based gas capture units 252.
  • the heating fluid supplies 350 may be configured to supply a heating fluid 352 (e.g., steam and/or heated water) and/or a heating fluid 354 (e.g., waste heat recovery fluid, such as heated fluid 26) to a heating fluid control 356 of the heating fluid supply system 316.
  • a heating fluid 352 e.g., steam and/or heated water
  • a heating fluid 354 e.g., waste heat recovery fluid, such as heated fluid 26
  • the heating fluid 352 may include a heated liquid and/or a heated gas, such as heated CO2, air, inert gas such as nitrogen, water, oil, or any combination thereof.
  • the heating fluid control 356 includes one or more heating fluid control components 358, 360, and 362, which may be configured to process, adjust, and/or control characteristics of the heating fluid 352 and/or heating fluid 354 upstream from the conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C).
  • the heating fluid control component 358 may include a thermal control component (e.g., temperature control component), such as a heat exchanger, a heater, a cooler, or any combination thereof, configured to adjust (e.g., increase or decrease) a temperature of the heating fluid 352 and/or the heating fluid 354.
  • the heat exchanger may exchange heat with steam, water, lubricant, coolant, refrigerant, or some other thermal fluid.
  • a waste heat recovery system may be used for heat transfer in the heat exchanger.
  • the heating fluid control component 360 may include a pressure control component, such as a pressure regulator, an expander or expansion chamber, a constrictor or constriction chamber, a fan or pump to add energy, a turbine to extract energy, or another suitable pressure controller.
  • the heating fluid control component 362 may include a pre- treatment component, such as a particulate filter, a cold water drain, and/or other pre-treatment components configured to alter characteristics of the heating fluid 352 and/or the heating fluid 354 or remove contaminants.
  • the heating fluid supply system 316 also may include one or more valves 364 configured to control the distribution of the heating fluid 352 (e.g., steam and/or heated water) and/or the heating fluid 354 (e.g., waste heat recovery fluid) to the plurality of conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 366, 368, and 370.
  • the heating fluid 352 e.g., steam and/or heated water
  • the heating fluid 354 e.g., waste heat recovery fluid
  • valves 364 may include one or more multi-way valves and/or distribution manifolds to independently distribute the heating fluid 352 and/or the heating fluid 354 through the distribution conduits 366, 368, and 370 to the respective sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) when operating in a desorption mode in response to control signals from the controller 220.
  • the respective sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the cooling fluid supply system 318 of the upstream flow distribution system 310 is configured to supply a cooling fluid to enable the cooling mode when selectively operating each of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) in the cooling mode via the controller 220.
  • the cooling fluid supply system 318 includes one or more cooling fluid supplies 372, such as one or more water supplies, cooled air supplies, cooled inert gas (e.g., nitrogen) supplies, cooled CO2 supplies, or any combination thereof.
  • the cooling fluid supplies 372 may be configured to supply a coolant or cooling fluid 374 (e.g., liquid or gas coolant) to a cooling fluid control 376 of the cooling fluid supply system 318.
  • the cooling fluid control 376 includes one or more cooling fluid control components 378, 380, and 382, which may be configured to process, adjust, and/or control characteristics of the cooling fluid 374 upstream from the conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C).
  • the cooling fluid control component 378 may include a thermal control component (e.g., temperature control component), such as a heat exchanger, a heater, a cooler, or any combination thereof, configured to adjust (e.g., increase or decrease) a temperature of the cooling fluid 374.
  • the heat exchanger may exchange heat with steam, water, lubricant, coolant, refrigerant, or some other thermal fluid.
  • the cooling fluid control component 380 may include a pressure control component, such as a pressure regulator, an expander or expansion chamber, a constrictor or constriction chamber, a fan or pump to add energy, a turbine to extract energy, or another suitable pressure controller.
  • the cooling fluid control component 382 may include a pretreatment component, such as a particulate filter and/or other pre-treatment components, configured to alter characteristics of the cooling fluid 374 or remove contaminants.
  • the cooling fluid supply system 318 also may include one or more valves 384 configured to control the distribution of the cooling fluid 374 (e.g., liquid or gas coolant) to the plurality of conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 386, 388, and 390.
  • the cooling fluid 374 e.g., liquid or gas coolant
  • conduits 254 e.g., 256, 258, and 260
  • the sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • valves 384 may include one or more multi-way valves and/or distribution manifolds to independently distribute the cooling fluid 374 through the distribution conduits 386, 388, and 390 to the respective sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) when operating in a cooling mode in response to control signals from the controller 220.
  • the respective sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the controller 220 is configured to control the upstream flow distribution system 310 to altematingly distribute flows of the gas 340 during the adsorption mode, the heating fluid 352 and/or the heating fluid 354 in the desorption mode, and the cooling fluid 374 in the cooling mode to the different sorbentbased gas capture units 252 (e.g., 252A, 252B, and 252C) having sorbent material 272.
  • the different sorbentbased gas capture units 252 e.g., 252A, 252B, and 252C having sorbent material 272.
  • the gas 340 (e.g., intake gas 60 or exhaust gas 152, 184) flows through the conduit 254 of the selected sorbent-based gas capture unit 252 (e.g., 252 A, 252B, or 252C) and contacts the sorbent material 272 disposed on the interior surface 274 of the outer conduit wall 262 and/or the exterior surface 276 of the contactors 280, such that the sorbent material 272 adsorbs the undesirable gases (e.g., CO2) from the gas 340.
  • the thermal control system 290 may circulate a coolant through the heat exchanger 296 to provide cooling of the contactors 280 and the sorbent material 272 during the adsorption mode.
  • the thermal control system 290 also may facilitate heat transfer to the coolant via a plurality of heat pipes 298 of the heat exchanger 296.
  • the sorbent-based gas capture unit 252 then discharges a treated gas 400 (e.g., lean or substantially free of the undesirable gases) to the post-adsorption processing system 320.
  • the heating fluid 352 and/or the heating fluid 354 flows through the conduit 254 of the selected sorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) and contacts the sorbent material 272 disposed on the interior surface 274 of the outer conduit wall 262 and/or the exterior surface 276 of the contactors 280, thereby heating the sorbent material 272 to facilitate desorption of the undesirable gases (e.g., CO2) from the sorbent material 272.
  • the desorption mode may be configured to indirectly heat the sorbent material 272 via a heating circuit (e.g., heating conduit) extending through the sorbent-based gas capture unit 252.
  • the thermal control system 290 may circulate a heating fluid (e.g., heating fluid 352 and/or heating fluid 354) through the heat exchanger 296 to provide heating of the contactors 280 and the sorbent material 272.
  • a heating fluid e.g., heating fluid 352 and/or heating fluid 354
  • the heating fluid 354 may include the heated fluid 26 from the WHR 22, and the heating fluid 352 may include the steam from the steam turbine system 14 and/or the auxiliary boiler 24 (e.g., supporting the steam turbine system 14).
  • the thermal control system 290 also may facilitate heat transfer from the heating fluid across the contactors 280 via the plurality of heat pipes 298 of the heat exchanger 296.
  • the sorbent-based gas capture unit 252 then discharges a fluid flow 402 including the undesirable gas, the heating fluid 352, and/or the heating fluid 354 for further processing by the post-desorption processing system 322.
  • the cooling fluid 374 flows through the conduit 254 of the selected sorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) and contacts the sorbent material 272 disposed on the interior surface 274 of the outer conduit wall 262 and/or the exterior surface 276 of the contactors 280, thereby cooling the sorbent material 272 and the contactors 280.
  • the cooling mode may be configured to indirectly cool the sorbent material 272 and the contactors 280 via a cooling circuit (e.g., cooling conduit) extending through the sorbent-based gas capture unit 252.
  • the thermal control system 290 may circulate a cooling fluid through the heat exchanger 296 to provide cooling of the contactors 280 and the sorbent material 272.
  • the thermal control system 290 also may facilitate heat transfer away from the contactors 280 and the sorbent material 272 via the plurality of heat pipes 298 of the heat exchanger 296.
  • the cooling mode is configured to cool and regenerate the sorbent material 272 prior to a subsequent adsorption mode.
  • the sorbent-based gas capture unit 252 then discharges a fluid flow 404 (e.g., cooling fluid 374) for handling by the post-cooling system 324.
  • the sorbent-based gas capture system 250 includes a movable sorbent system configured to continuously or periodically move the sorbent material 272 between the adsorption mode, the desorption mode, and the cooling mode.
  • the sorbent-based gas capture system 250 may include a rotating contactor assembly or wheel (e.g., rotating contactors with sorbent material 272) configured to rotate from adsorption, desorption and cooling, thereby providing a continuous stream of captured undesirable gases.
  • the wheel e.g., rotating contactors with sorbent material 272
  • the wheel may extend into each of the plurality of conduits 254, and continuously rotate through the conduits 254.
  • one or more of the conduits 254 flow the gas 340 being treated to remove the undesirable gases, while one or more of the conduits 254 simultaneously flow the heating fluid 352 and/or heating fluid 354 to remove and capture the undesirable gas (e.g., CO2) to generate the captured gas 204, and while one or more of the conduits 254 simultaneously flow the cooling fluid 374 to regenerate the sorbent material 272.
  • the heating fluid 352 and/or heating fluid 354 may be routed or generally configured to provide direct heat transfer and/or indirect heat transfer to the sorbent material 272, thereby helping to separate and capture the undesirable gas.
  • the controller 220 is configured to control the downstream flow distribution system 312 to alternatingly distribute flows from each sorbent-based gas capture unit 252 (e.g., 252A, 252B, and 252C) to route the treated gas 400 to the post-adsorption processing system 320 during the adsorption mode, the fluid flow 402 (e.g., the undesirable gas, the heating fluid 352, and/or the heating fluid 354) to the post-desorption processing system 322 in the desorption mode, and the fluid flow 404 (e.g., cooling fluid 374) to the post-cooling system 324 in the cooling mode.
  • each sorbent-based gas capture unit 252 e.g., 252A, 252B, and 252C
  • the fluid flow 402 e.g., the undesirable gas, the heating fluid 352, and/or the heating fluid 354
  • the fluid flow 404 e.g., cooling fluid 374
  • the downstream flow distribution system 312 includes one or more valves 410 fluidly coupled with the sorbent-based gas capture unit 252 A, one or more valves 412 fluidly coupled with the sorbent-based gas capture unit 252B, and one or more valves 414 fluidly coupled with the sorbent-based gas capture unit 252C.
  • the valves 410 may include one or more multi-way valves and/or distribution manifolds coupled to distribution conduits 416, 418, and 420, which are coupled to the postadsorption processing system 320, the post-desorption processing system 322, and the post-cooling system 324, respectively.
  • the valves 412 may include one or more multiway valves and/or distribution manifolds coupled to distribution conduits 422, 424, and 426, which are coupled to the post-adsorption processing system 320, the postdesorption processing system 322, and the post-cooling system 324, respectively.
  • the valves 414 may include one or more multi-way valves and/or distribution manifolds coupled to distribution conduits 428, 430, and 432, which are coupled to the postadsorption processing system 320, the post-desorption processing system 322, and the post-cooling system 324, respectively.
  • the controller 220 is configured to control the valves 410, 412, and 414 to independently control the flows from the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) to the post- adsorption processing system 320 in the adsorption mode, to the post-desorption processing system 322 in the desorption mode, and to the post-cooling system 324 in the cooling mode.
  • the sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the post-adsorption processing system 320 includes a treated gas processing system 440, which may include an exhaust stack, an additional gas treatment system, or any other suitable post processing equipment.
  • the post-adsorption processing system 320 may recirculate all or part of the treated gas 400 to the EGR system 150 as discussed above with reference to FIG. 1.
  • the post-desorption processing system 322 may include a post-desorption processor 442 having one or more post-desorption processing components 444, 446, and 448.
  • the fluid flow 402 directed to the post-desorption processor 442 is a result of the desorption mode, wherein the heating fluid 352 (e.g., steam and/or heated water) and/or heating fluid 354 (e.g., waste heat recover fluid, such as heated fluid 26) is directed through the conduit 254 of the sorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) to desorb the undesirable gases (e.g., CO2) from the sorbent material 272.
  • the heating fluid 352 e.g., steam and/or heated water
  • heating fluid 354 e.g., waste heat recover fluid, such as heated fluid 26
  • the one or more post-desorption processing components 444, 446, and 448 may be configured to process, adjust, and/or control characteristics of the fluid flow 402 (e.g., steam, heated water, and/or other fluid flow) from the conduits 254 (e.g., 256, 258, and 260) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C).
  • the fluid flow 402 e.g., steam, heated water, and/or other fluid flow
  • the conduits 254 e.g., 256, 258, and 260
  • the sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C
  • the post-desorption processing component 444 may include a captured gas/heated fluid separator configured to separate the heating fluid 352 (e.g., steam and/or heated water) and/or the heating fluid 354 from the captured gas, thereby outputting a fluid 450 (e.g., water condensate or other separated fluid) and the captured gas 204.
  • a captured gas/heated fluid separator include thermal control components, pressure control components, chemical separation components, or a combination thereof.
  • the captured gas/heated fluid separator may be configured to condense or cool the heating fluid 352 (e.g., steam) using a condenser.
  • the post-desorption processing component 446 may include one or more removal units configured to remove contaminants from the fluid 450 and/or the captured gas 204.
  • the removal units may include particulate filters and/or water treatment units.
  • the removal units may include particulate filters, water removal units or dryers, or further gas treatment units.
  • the post-desorption processing component 448 may include one or more pressure control components and/or flow control components, such as one or more pumps for the fluid 450 and one or more compressors for the captured gas 204.
  • the post-desorption processing components 448 also may include a vacuum system having one or more vacuum pumps configured to suction the captured gas/heated fluid flow from the sorbent-based gas capture units 252. In other words, the vacuum pumps are configured to create a low-pressure environment to help draw the captured gas/heated fluid flow from the sorbent-based gas capture units 252.
  • the post-cooling system 324 may include a cooling fluid recirculation system 452, which is configured to recirculate the fluid flow 404 back to the cooling fluid supply system 318 as the cooling fluid 374.
  • the cooling fluid recirculation system 452 may include components 454, 456, and 458, such as a recirculation pump, compressor, or booster fan, a cooling system, and flow control valves.
  • the cooling system may include a heat exchanger configured to transfer heat away from the fluid flow 404, thereby cooling the fluid flow for additional use as the cooling fluid 374.
  • the heat available from the fluid flow 404 may be recovered in one or more heat exchangers to heat the heating fluid 352 and/or heating fluid 354 of the heating fluid supply system 316, thereby reducing the total heating energy demand. The remaining low-grade heat from the fluid flow 404 may then be rejected to ambient.
  • the controller 220 is configured to receive feedback from the sensors 222 to facilitate adjustments of various operating parameters and change operating modes (e.g., adsorption mode, desorption mode, and cooling mode) of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C).
  • various operating parameters and change operating modes e.g., adsorption mode, desorption mode, and cooling mode
  • the sorbent-based gas capture units 252 e.g., 252A, 252B, and 252C.
  • the controller 220 may be configured to alternate flows (e.g., gas 340, heating fluid 352 and/or heating fluid 354, and cooling fluid 374) through the plurality of conduits 254 (e.g., 256, 258, and 260), such that the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) can alternate between the adsorption mode, the desorption mode, and the cooling mode.
  • the conduit 254 receives a flow of the gas 340, adsorbs the undesirable gases (e.g., CO2) from the gas 340 into the sorbent material 272, and outputs a treated gas 400 with a reduced content or concentration level of the undesirable gases.
  • the undesirable gases e.g., CO2
  • the adsorption of undesirable gases into the sorbent material 272 is an exothermic process, which generates heat.
  • the thermal control system 290 including the heat exchangers 296 and the heat pipes 298, help to regulate the temperature of the sorbent material 272 during the adsorption mode, thereby maintaining or increasing the adsorption efficiency of the sorbent material 272.
  • the conduit 254 receives a flow of the heating fluid 352 (e.g., steam and/or heated water) and/or heating fluid 354, desorbs the undesirable gases (e.g., CO2) from the sorbent material 272 into the heating fluid 352 and/or heating fluid 354, and outputs the fluid flow 402 with the desorbed undesirable gases (e.g., heating fluid 352 and/or heating fluid 354 rich in the undesirable gases such as CO2).
  • the desorption of undesirable gases from the sorbent material 272 is an endothermic process, and the heating fluid 352 and/or heating fluid 354 provides sufficient heat (e.g., directly or indirectly) to drive the desorption of the undesirable gases (e.g., CO2) from the sorbent material 272.
  • the conduit 254 receives a flow of the cooling fluid 374 (e.g., gas or liquid coolant), thereby cooling the sorbent material 272 and the contactors 280.
  • the controller 220 is configured to monitor the sensors 222, such as sensors 222 at or upstream from the inlets 268 and sensors 222 at or downstream from the outlets 270, to evaluate rates of adsorption, desorption, and cooling, concentration levels of the undesirable gases, and other characteristics impacting the operating modes of the sorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C).
  • the controller 220 may be configured to control the valves 342, 364, 384, 410, 412, and 414 to change the flows through the conduits 254 to support the desired operating modes.
  • the sensors 222 also may monitor the temperature of the sorbent material 272 and adjust the thermal control system 290 to provide heating or cooling depending on the operating mode (e.g., cooling during the adsorption and cooling modes and heating during the desorption mode).
  • the controller 220 may be configured to control the gas pre-treatment system 330 to control characteristics of the gas 340 (e.g., temperature, pressure, flow rate, etc.). Similarly, the controller 220 is configured to control the treated gas processing system 440 to control the processing of the treated gas 400 discharged from one or more of the conduits 254.
  • the controller 220 may be configured to control the HRSG 16, the steam turbine system 14, the WHR system 22, the auxiliary boiler 24, the heating fluid control 356, or any combination thereof, to control characteristics of the heating fluid 352 and/or the heating fluid 354 (e.g., temperature, pressure, flow rate, steam content, water content, etc.).
  • the controller 220 is configured to control the post-desorption processor 442 to control the processing of the fluid flow 402 (including the undesirable gas desorbed during the desorption mode) discharged from one or more of the conduits 254.
  • the controller 220 may be configured to control the cooling fluid control 376 and/or the cooling fluid recirculation system 452 to control characteristics of the cooling fluid 374 (e.g., temperature, pressure, flow rate, etc.). Similarly, the controller 220 is configured to control the cooling fluid recirculation system 452 to control the processing of the fluid flow 404 (e.g., cooling fluid 374) discharged from one or more of the conduits 254.
  • the fluid flow 404 e.g., cooling fluid 374
  • FIG. 3 is a schematic of an embodiment of the combined cycle system 10 of FIG. 1, illustrating an embodiment of the gas capture system 20 of the gas treatment system 18 having a solvent-based gas capture system 500 using steam from the integrated steam turbine system 14 and auxiliary boiler 24.
  • the solvent-based gas capture system 500 may use one or more solvents for capturing the undesirable gases.
  • Example solvents include monoethanolamine (MEA), diglycolamine (DGA), advanced amine solvents, amino acid salts, carbonate solvents, aqueous ammonia, immiscible liquids, and ionic liquids.
  • the solvent-based gas capture system 500 uses one or more heated fluids 502 from the steam turbine system 14, the HRSG 16, the WHR 22, and/or the auxiliary boiler 24 (e.g., supporting the steam turbine system 14).
  • the heated fluids 502 may include steam and/or heated water from the steam turbine system 14, the HRSG 16, and/or the auxiliary boiler 24 (e.g., supporting the steam turbine system 14).
  • the heated fluids 502 may include heated gas and/or heated liquid from the WHR 22.
  • the gas turbine system 12, the steam turbine system 14, the HRSG 16, and the auxiliary boiler 24 are substantially the same as discussed in detail above.
  • the illustrated HRSG 16 includes the first pressure section 160 (e.g., the high- pressure (HP) section), the second pressure section 162 (e.g., the intermediate-pressure (IP) section), and the third pressure section 164 (e.g., the low-pressure (LP) section), wherein each of the sections 160, 162, and 164 includes one or more heat exchangers and/or heat exchange components.
  • the gas capture system 20 may be configured to route the heated fluid 502 (e.g., steam and/or heated water) from the steam turbine system 14, the auxiliary boiler 24, and/or the HRSG 16 to the gas capture system 20 (e.g., solvent-based gas capture system 500), wherein the steam may be high-pressure steam, intermediatepressure steam, and/or low-pressure steam extracted from one or more of the sections (e.g., 160, 162, 164) of the HRSG 16, one or more of the steam turbines 172, 174, and/or 176 of the steam turbine system 14 supported by the auxiliary boiler 24, and/or the auxiliary boiler 24.
  • the heated fluid 502 e.g., steam and/or heated water
  • the gas capture system 20 e.g., solvent-based gas capture system 500
  • the steam may be high-pressure steam, intermediatepressure steam, and/or low-pressure steam extracted from one or more of the sections (e.g., 160, 162, 164) of the HRSG 16, one or more of the steam turbines 172, 174,
  • the gas capture system 20 may not receive any steam from the HRSG 16, but instead receive steam only from the steam turbine system 14 and/or the auxiliary boiler 24 (e.g., directly from the auxiliary boiler 24 and/or indirectly through the steam turbine system 14). Furthermore, in some embodiments, the gas capture system 20 (e.g., solvent-based gas capture system 500) may not receive any steam from the HRSG 16, but instead receive steam only from the steam turbine system 14 with steam being provided by the auxiliary boiler 24 only to the steam turbine system 14.
  • the auxiliary boiler 24 may be configured to function as steam support for the steam turbine system 14 in various operating modes (e.g., full load and part load operating modes), such that the steam turbine system 14 can in turn provide the steam to the gas capture system 20 (e.g., solvent-based gas capture system 500).
  • various operating modes e.g., full load and part load operating modes
  • the steam turbine system 14 can in turn provide the steam to the gas capture system 20 (e.g., solvent-based gas capture system 500).
  • the solvent-based gas capture system 500 includes an absorber 504 (e.g., absorber column), a stripper 506 (e.g., stripper column), a gas circuit 508 (e.g., gas treatment circuit), a solvent circuit 510 (e.g., fluid absorbent circuit), and one or more heated fluid circuits 512.
  • Each of the gas circuit 508, the solvent circuit 510, and the heated fluid circuits 512 includes one or more fluid conduits or lines, fluid manifolds, fluid splitters, fluid combiners, fluid mixing chambers, fluid valves, internal fluid paths through components, or any combination thereof.
  • the gas circuit 508 is configured to route the exhaust gas 152, 184 (or any other gas flow having undesirable gases) through the absorber 504, while the solvent circuit 456 is configured to route a solvent flow through the absorber 504 and the stripper 506.
  • the gas circuit 508 includes a gas path 514 extending toward the absorber 504 between the absorber 504 and the WHR system 22 and/or the HRSG 16, a gas path 516 extending upwardly through the absorber 504, and a gas path 518 extending away from the absorber 504.
  • the solvent circuit 510 extends through the absorber 504 and the stripper 506 in a loop, including a solvent path 520 extending downwardly through the absorber 504, a solvent path 522 extending from the absorber 504 to the stripper 506, a solvent path 524 extending downwardly through the stripper 506, and a solvent path 526 extending from the stripper 506 to the absorber 504.
  • the heated fluid circuits 512 extend between the stripper 506 and one or more heated fluid sources 528 to support operation of the stripper 506 using the heated fluid 502.
  • the heated fluid circuits 512 may be configured to extract the heated fluid 502 at a pressure and a temperature suitable for transferring heat to the stripper 506 to reduce or eliminate a need for separate heat sources for the stripper 506.
  • the heated fluid circuits 512 may be configured to provide a high-pressure steam, an intermediate-pressure steam, and/or a low-pressure steam to the stripper 506 from the steam turbine system 14 supported by the auxiliary boiler 24, the auxiliary boiler 24, and/or the HRSG 16 as the heated fluid sources 528.
  • the heated fluid sources 528 also may include the WHR 22 as a source of the heated fluid 502 and/or a source of waste heat to support steam generation in the auxiliary boiler 24.
  • the heated fluid 502 may only be provided by the steam turbine system 14 that receives steam from the auxiliary boiler 24 and/or directly from the auxiliary boiler 24.
  • the heated fluid circuits 512 may include any number and configurations of heated fluid flow paths (e.g., conduits), connection locations, and control features to provide suitable heated fluid 502 to the stripper 506.
  • the heated fluid circuits 512 may fluidly and mechanically couple to the heated fluid sources 528 at one or more heated fluid extraction locations 530 (e.g., extraction ports or connections) at the auxiliary boiler 24, the WHR system 22, the steam turbine system 14, and the HRSG 16.
  • the heated fluid extraction locations 530 may include one or more heated water and/or steam extraction locations at the steam turbine system 14 and/or the HRSG 16, such as locations 530 at, upstream of, downstream of, and/or between: the sections (e.g., 160, 162, 164) of the HRSG 16 and the steam turbines 172, 174, and 176.
  • the heated fluid circuits 512 may fluidly and mechanically couple to the stripper 506 at one or more heated fluid injection locations 532 (e.g., injection ports or connections).
  • the heated fluid injection locations 532 may be disposed at, upstream of, downstream of, and/or between components of the stripper 506.
  • the solvent-based gas capture system 500 may have one or more of the heated fluid circuits 512 with any combination of the heated fluid extraction locations 530 and the heated fluid injection locations 532.
  • the heated fluid circuits 512 may be independent circuits (e.g., separate heated fluid paths or conduits) or interconnected circuits (e.g., fluidly coupled heated fluid paths or conduits) having one or more common conduits, wherein the heated fluid circuits 512 may include one or more valves 534 coupled to the controller 220 for selective control of the heated fluid flows to the stripper 506.
  • the heated fluid circuits 512 include one or more heated fluid circuits 512 between the heated fluid sources 528 and the stripper 506.
  • the one or more heated fluid circuits 512 are fluidly and mechanically coupled to the heated fluid sources 528 at one or more heated fluid extraction locations 530, and the one or more heated fluid circuits 512 are fluidly and mechanically coupled to the stripper 506 at one or more heated fluid injection locations 532 (e.g., 540, 542, 544, and 546).
  • the heated fluid circuits 512 may include one or more heated water and/or steam circuits 536 extending between the auxiliary boiler 24 and the steam turbine system 14, such as conduits having valves 535 between the auxiliary boiler 24 and the high-pressure steam turbine 172 and the intermediate -pressure steam turbine 174. Additionally, in certain embodiments, the heated fluid circuits 512 may include one or more heated water and/or steam circuits 538 extending between the steam turbine system 14 and the stripper 506, such as conduits having valves 537 between the stripper 506 and the intermediate-pressure steam turbine 174, the low- pressure turbine 176, or between the turbines 174 and 176.
  • the circuits 538 may extend to a manifold 539, which then couples to valves 534 for a controlled distribution to the stripper 506.
  • the heated fluid circuits 512 may include one or more heated water and/or steam circuits extending between the stripper 506 and one or more of the sections (e.g., 160, 162, 164) of the HRSG 16, one or more heated water and/or steam circuits extending between the stripper 506 and the auxiliary boiler 24, or any combination thereof.
  • the heated fluid extraction locations 530 may include a plurality of different locations
  • the heated fluid injection locations 532 e.g., 540, 542, 544, and 546) may include a plurality of different locations.
  • the heated fluid circuits 512 may include one or more common heated fluid extraction locations 530, one or more common heated fluid injection locations 532 (e.g., 540, 542, 544, and 546), or any combination thereof.
  • each of the heated fluid circuits 512 may selectively couple to the stripper 506 at any one or more of the heated fluid injection locations 532 (e.g., 540, 542, 544, and 546) using conduits, valves 534, manifolds 539, and other flow controls.
  • the heated fluid circuits 512 are configured to provide the heated fluid 502 to the stripper 506 at a temperature, a pressure, and a flow rate at least partially controlled by the valves 534, 535, and 537 (e.g., controlled via the controller 220 and feedback from sensors 222) along the respective heated fluid circuits 512. Additional details of the heated fluid circuits 512 and the heated fluid supply to the stripper 506 will be discussed below.
  • the absorber 504 includes a plurality of absorber sections 560 disposed inside of a vessel or enclosure 562, wherein the enclosure 562 includes a gas inlet 564, a gas outlet 566, a solvent inlet 568, and a solvent outlet 570.
  • the enclosure 562 has a top portion 572, a bottom portion 574, and an intermediate portion 576 disposed axially between the top and bottom portions 572 and 574 relative to a central axis 578 of the enclosure 562.
  • the top portion 572 includes a top plate or cover 580 having the gas outlet 566 coaxial with the central axis 578. However, the gas outlet 566 may be disposed offset from the central axis 578 or at other locations along the top portions 572.
  • the intermediate portion 576 includes a sidewall 582 extending about the central axis 578.
  • the sidewall 582 may be an annular sidewall, a square shaped sidewall, a rectangular sidewall, or any other suitable shape that extends around the central axis 578.
  • the gas outlet 566 may be disposed in the sidewall 582 along the top portion 572.
  • the solvent inlet 568 may be disposed along the top plate or cover 580 or the sidewall 582 in the top portion 572.
  • the bottom portion 574 may include a base plate 584 below the gas inlet 564 and the solvent outlet 570. In the illustrated embodiment, the gas inlet 564 and the solvent outlet 570 are disposed in the sidewall 582 along the bottom portion 574.
  • the gas inlet 564 and/or the solvent outlet 570 may be disposed in the base plate 584 in the bottom portion 574.
  • the gas inlet 564 may include a plurality of gas inlets and/or the solvent outlet 570 may include a plurality of solvent outlets.
  • the plurality of absorber sections 560 within an interior volume 586 of the enclosure 562 may include any number and type of absorber sections 560, such as absorber sections 588, 590, 592, 594, 596, and 598, which may include any configuration of packings, support trays or screens, wire meshes, solvent distributors, or any combination thereof.
  • each packing may include a plurality of beads, balls, or mixture inducing structures, which are configured to facilitate mixing between a gas flow and a solvent flow in the absorber 504.
  • Each support tray or screen may include a wire mesh, a plate having a plurality of openings, or another suitable structure that holds the packing in position while permitting fluid flow of gas and solvent through the support tray or screen in opposite directions through the absorber 504.
  • Each solvent distributor may include a plurality of solvent nozzles configured to distribute solvent across the interior volume 586.
  • the absorber sections 588, 592, 596, and 598 include wire meshes, while the absorber sections 590 and 594 include packings, support trays or screens, and solvent distributors.
  • the absorber sections 560 e.g., 588, 590, 592, 594, 596, and 598) are not limited to the illustrated configuration.
  • the absorber 504 is configured to create a crossflow or opposing flows of a gas 600 (e.g., exhaust gas 152, 184) along the gas path 516 and a gas lean solvent 602 along the solvent path 520 within the interior volume 586, thereby facilitating gas absorption of certain undesirable gases (e.g., CO2) from the gas 600 into the gas lean solvent 602.
  • a gas 600 e.g., exhaust gas 152, 184
  • gas lean solvent 602 along the solvent path 520 within the interior volume 586
  • certain undesirable gases e.g., CO2
  • the gas 600 enters the absorber 504 through the gas inlet 564, and the gas 600 flows upwardly through the interior volume 586 of the absorber 504.
  • the gas 600 entering the absorber 504 through the gas inlet 564 may form bubbles of the gas 600 that rise upwardly through the gas lean solvent 602 within the interior volume 586.
  • the gas 600 then passes through each subsequent absorber section 560 (e.g., 588,
  • the solvent-based gas capture system 500 supplies the gas lean solvent 602 into the interior volume 586 using one or more solvent distributors, such as a solvent distribution manifold, solvent nozzles, or a grid of solvent injectors.
  • the solvent-based gas capture system 500 may supply the gas lean solvent 602 through the illustrated solvent inlet 568, or any number or arrangement of solvent inlets 568, at positions directly at, above, and/or below the absorber sections 560.
  • the gas lean solvent 602 then flows downwardly through the interior volume 586 through each subsequent absorber section 560.
  • various mixing structures e.g., packings, wire meshes, support trays, etc.
  • the gas lean solvent 602 may be configured to absorb carbon dioxide (CO2) or other undesirable gases as discussed in detail above.
  • CO2 carbon dioxide
  • heat is generated within the absorber 504, thereby raising the temperature of the solvent within the absorber 504.
  • a thermal control system 604 may be coupled to the absorber 504 to control the temperatures and improve the efficiency of the absorption process.
  • the thermal control system 604 may include a cooling circuit 606 coupled to the absorber 504, wherein the cooling circuit 606 includes a heat exchanger 608 (e.g., cooler) and a pump 610.
  • the pump 610 is configured to circulate solvent through the heat exchanger 608 to cool the solvent by transferring heat away from the solvent to a cooling fluid, such as water or another coolant. Any number or configuration of thermal control systems 604 may be implemented in the absorber 504.
  • the absorber 504 also includes a water wash system 612 having a heat exchanger 614 (e.g., cooler) and a pump 616 disposed along a water wash circuit 618.
  • the absorber section 594, 596, and/or 598 may be configured to assist with the water wash process of the water wash system 612, while the absorber sections 588, 590, and 592 help to enhance mixing between the gas 600 and the gas lean solvent 602 to increase absorption of the undesirable gases.
  • the absorber section 594, 596, and/or 598 may be configured to help distribute water across the absorber 504 in the top portion 572 for removing any dissolved solvent in the gas 600 flowing upwardly through the absorber 504.
  • the water wash system 612 may be eliminated or moved downstream from the absorber 504.
  • the absorber 504 discharges a gas rich solvent 620 at the bottom portion 574 through the solvent outlet 570, and the absorber 504 discharges the treated gas 622 at the top portion 572 through the gas outlet 566.
  • the treated gas 622 may be substantially free or stripped of one or more undesirable gases (e.g., CO2).
  • the gas rich solvent 620 may have absorbed the one or more undesirable gases (e.g., CO2).
  • the gas rich solvent 620 may be described as a CO2 rich solvent (or other gas rich solvent depending on the undesirable gas), while the gas lean solvent 602 may be described as a CO2 lean solvent (or other gas lean solvent depending on the undesirable gas and the particular gas absorption occurring in the absorber 504).
  • the gas 600 may be described as a CO2 containing or rich gas (or other containing or rich gas depending on the undesirable gas), while the treated gas 622 may be described as a CO2 reduced, lean, or free gas (or other reduced, lean, or free gas depending on the undesirable gas and the particular gas absorption occurring in the absorber 504).
  • the gas absorption discussed herein is intended to cover any one or more of the undesirable gases described herein, or any other regulated or greenhouse gases.
  • the gas circuit 508 may include one or more components upstream from the absorber 504.
  • the gas circuit 508 may include a gas cooler or gas cooling system, such as a direct contact cooler (DCC) 624, disposed along the gas path 514 upstream from the absorber 504.
  • the WHR system 22 may be configured to generate the heated fluid 502 while cooling the exhaust gas 152, 184, such that the DCC 624 may be downsized or eliminated in the solvent-based gas capture system 500.
  • the DCC 624 may include a cooling enclosure 626 that houses a wire mesh 628 and a cooling fluid distributor 630, wherein the cooling fluid distributor 630 includes a plurality of fluid nozzles 632.
  • the DCC 624 also may include a cooling fluid circuit 634 having a pump 636 and a heat exchanger 638 (e.g., cooler), wherein the cooling fluid circuit 634 is coupled to the cooling fluid distributor 630 above the wire mesh 628 and a bottom portion of the enclosure 626 below the wire mesh 628.
  • the pump 636 is configured to circulate a cooling fluid (e.g., water or other liquid) through the DCC 624, while the heat exchanger 638 is configured to cool the cooling fluid by transferring heat away from the cooling fluid to another working fluid.
  • a cooling fluid e.g., water or other liquid
  • the plurality of fluid nozzles 632 distribute the cooling fluid across an interior volume of the enclosure 626 (e.g., cooling fluid dispersion), while the DCC 624 routes a gas flow from a gas inlet 640 to a gas outlet 642 as indicated by arrow 644.
  • the cooling fluid dispersion directly contacts and cools the gas flow (e.g., exhaust gas 152, 184).
  • the gas circuit 508 also includes one or more fans 646 configured to boost a pressure and/or flow rate of the gas flow (e.g., exhaust gas 152, 184) supplied to the absorber 504.
  • the DCC 624 may be eliminated or downsized when incorporating the WHR system 22, because the WHR system 22 serves dual purposes of an exhaust gas cooler and a heat source for the solvent-based gas capture system 500.
  • the solvent-based gas capture system 500 also may include a plurality of components along the solvent circuit 510 between the absorber 504 and the stripper 506.
  • the solvent circuit 510 includes a pump 648, a heat exchanger 650, and a heat exchanger 704 along the solvent path 522 from the absorber 504 to the stripper 506, and the solvent circuit 510 includes a pump 652, the heat exchanger 650, a heat exchanger 654, and a filter 656 along the solvent path 526 from the stripper 506 to the absorber 504.
  • the pump 648 is configured to pump the gas rich solvent 620 along the solvent path 522 through the heat exchanger 650 and the heat exchanger 704 to the stripper 506, while the pump 652 is configured to pump the gas lean solvent 602 along the solvent path 526 through the heat exchangers 296 and the filter 656 to the absorber 504.
  • the heat exchanger 650 is configured to transfer heat away from the gas lean solvent 602 in the solvent path 526 to the gas rich solvent 620 in the solvent path 522, thereby cooling the gas lean solvent 602 and heating the gas rich solvent 620.
  • the heat exchanger 704 is configured to transfer heat from the heated fluid 502 in a heated fluid circuit 702 to the gas rich solvent 620 in the solvent path 522, thereby heating the gas rich solvent 620.
  • the heat exchanger 654 is configured to cool the gas lean solvent 602 by transferring heat away from the gas lean solvent 602 to a coolant flow (e.g., water or other liquid coolant), thereby providing a cooled gas lean solvent 602 for supply to the absorber 504.
  • the filter 656 is configured to filter and/or clean the gas lean solvent 602 for use in the absorber 504.
  • the solvent circuit 510 may include additional components (e.g., heat exchangers, filters, valves, etc.) and/or exclude one or more of the illustrated components.
  • the stripper 506 processes the gas rich solvent 620 as discussed below. [0085]
  • the stripper 506 includes a plurality of stripper sections 658 disposed inside of a vessel or enclosure 660, wherein the enclosure 660 includes a solvent inlet 662, a solvent outlet 664, and a gas outlet 666.
  • the enclosure 660 has a top portion 668, a bottom portion 670, and an intermediate portion 672 disposed axially between the top and bottom portions 668 and 670 relative to a central axis 674 of the enclosure 660.
  • the top portion 668 includes a top plate or cover 676 having the gas outlet 666 coaxial with the central axis 674. However, the gas outlet 666 may be disposed offset from the central axis 674 or at other locations along the top portion 668.
  • the intermediate portion 672 includes a sidewall 678 extending about the central axis 674.
  • the sidewall 678 may be an annular sidewall, a square shaped sidewall, a rectangular sidewall, or any other suitable shape that extends around the central axis 674.
  • the gas outlet 666 may be disposed in the sidewall 678 along the top portion 668.
  • the solvent inlet 662 may be disposed along the top portion 668 or the intermediate portion 672.
  • the bottom portion 670 may include a base plate 680 below the solvent outlet 664.
  • the solvent outlet 664 is disposed in the sidewall 678 along the bottom portion 670.
  • the solvent outlet 664 may be disposed in the base plate 680 in the bottom portion 670.
  • the plurality of stripper sections 658 within an interior volume 682 of the enclosure 660 may include any number and type of stripper sections 658, such as stripper sections 684, 686, 688, 690, and 692, which may include any configuration of packings, support trays or screens, wire meshes, solvent distributors having nozzles, steam distributors having nozzles, or any combination thereof.
  • each packing may include a plurality of beads, balls, or mixture inducing structures, which are configured to facilitate mixing between flows of a solvent flow (e.g., gas rich solvent 620) and a steam 694 in the stripper 506.
  • Each support tray or screen may include a wire mesh, a plate having a plurality of openings, or another suitable structure that holds the packing in position while permitting fluid flow of the solvent (e.g., gas rich solvent 620) and the steam 694 through the support tray or screen.
  • Each solvent distributor may include a plurality of solvent nozzles configured to distribute solvent across the interior volume 682.
  • Each steam distributor may include a plurality of fluid nozzles configured to distribute steam 694 across the interior volume 682.
  • the stripper sections 686, 688, and 692 include wire meshes
  • the stripper section 684 includes a packing and a support tray or screen
  • the stripper section 690 includes a barrier plate or divider plate having one or more openings.
  • the stripper sections 658 e.g., 684, 686, 688, 690, and 692 are not limited to the illustrated configuration.
  • the stripper 506 is configured to strip the undesirable gases from the gas rich solvent 620 using the heated fluid 502 supplied by the heated fluid circuits 512 from one or more of the WHR system 22, the steam turbine system 14, the HRSG 16, the auxiliary boiler 24, another waste heat recovery system of the combined cycle system 10, or a combination thereof.
  • the heated fluid circuits 512 are coupled to various heated fluid extraction location 530 and heated fluid injection locations 532 (e.g., 540, 542, 544, and 546) to provide heat in the form of the heated fluid 502 for supporting the stripper 506.
  • Each of these heated fluid circuits 512 may be configured to transfer heat to the solvent in the stripper 506 by direct heat transfer (e.g., direct injection into the solvent), indirect heat transfer (e.g., via a heat exchanger), or any combination thereof.
  • the controller 220 is configured to selectively control (e.g., open and close) the valves 534 to control the respective flows of heated fluid 502 through the heated fluid circuits 512 to the stripper 506.
  • the heated fluid circuits 512 include heated fluid circuits (or circuit portions) 696, 698, 700, and 702 coupled to the respective heated fluid injection locations 532 (e.g., 540, 542, 544, and 546).
  • the heated fluid circuits 512 are coupled to the intermediate portion 672 of the enclosure 660 at the respective heated fluid injection locations 532 (e.g., 542 and 544), which are located between the stripper sections 686 and 688.
  • the heated fluid circuits 698 and 700 may be coupled to the stripper 506 at any suitable heated fluid injection locations 532, which may be the same or different between the heated fluid circuits 698 and 700.
  • the heated fluid injection locations 532 e.g., 542 and 544 may be disposed directly at, above, and/or below one or more of the stripper sections 658.
  • the heated fluid injection locations 532 may include fluid distributors having a plurality of fluid nozzles configured to distribute the heated fluid 502 across the interior volume 682 of the stripper 506.
  • the stripper 506 may be coupled to or include one or more additional components, such as a thermal control system 706 and a moisture removal system 708.
  • the thermal control system 706 may be coupled to any portion of the stripper 506, such as at the bottom portion 670.
  • the thermal control system 706 may include a solvent recirculation circuit 710 having a reboiler 712 configured to heat and boil the solvent for recirculation into the stripper 506.
  • the reboiler 712 is coupled to at least one of the heated fluid circuits 512 (e.g., 696) as a heat source for heating and boiling the solvent, rather than relying on an independent or separate heat source.
  • the reboiler 712 may include one or more additional heat sources, such as an electric heater, a combustor or furnace, a steam generator, or other heat sources, for heating the solvent.
  • the additional heat sources may be used when steam is unavailable and/or insufficient to provide the desired heating in the reboiler 712.
  • the heated fluid circuits 512 may be the primary source of heat to support the reboiler 712.
  • at least one of the heated fluid circuits 512 e.g., 696 supplies the heated fluid 502 into the reboiler 712 at an inlet 714 (e.g., the heated fluid injection location 540), while the reboiler 712 discharges water and/or steam at an outlet 716.
  • the discharged water and/or steam flows through a return circuit 718 from the reboiler 712 to the heated fluid source 528 (e.g., steam turbine system 14, auxiliary boiler 24, and/or WHR system 22), wherein the return circuit 718 may include a fluid treatment unit (FTU) 720 configured to treat the heated fluid 502 prior to return to the heated fluid source 528.
  • the FTU 720 may include a condenser configured to condense steam and/or other liquid vapor into a condensate, a particulate filter, a descaling unit, an ultraviolet (UV) treatment unit, or any combination thereof.
  • the return circuit 718 is coupled to a pump 722, which is configured to pump the heated fluid 502 back to the heated fluid source 528.
  • the heated fluid circuit 512 e.g., 696
  • any one or more of the heated fluid circuits 512 may be coupled to the reboiler 712 to provide the heated fluid 502 as a source of heat for heating and boiling the solvent in the stripper 506.
  • At least one of the heated fluid circuits 512 supplies the heated fluid 502 into the heated fluid injection location 544 at the heat exchanger 704 disposed along the solvent circuit 510, thereby heating the gas rich solvent 620 between the absorber 504 and the stripper 506.
  • the heat exchanger 704 may be disposed between the heat exchanger 650 and the solvent inlet 662 into the stripper 506.
  • the heated fluid 502 may be directly injected into the gas rich solvent 620, such that the heated fluid 502 mixes with and directly transfers heat to the gas rich solvent 602.
  • the heat exchanger 704 provides indirect heat transfer between the heated fluid 502 and the gas rich solvent 602, and thus the heated fluid 502 may be recirculated back to the heated fluid source 528 along a return circuit (e.g., return circuit 718).
  • a return circuit e.g., return circuit 718
  • the moisture removal system 708 may include a condenser circuit 724 having a condenser 726, wherein the condenser circuit 724 is coupled to the gas outlet 666 and a return inlet 728.
  • the condenser 726 is configured to cool and condense any steam and solvent vapor present in the captured gas 204 discharged from the stripper 506, thereby outputting water or condensate 730, the captured gas 204 substantially free of water content and solvent vapor, and solvent vapor for return to the stripper 506 via the return inlet 728.
  • the condenser 726 includes a heat exchanger (e.g., cooler) configured to transfer heat away from the captured gas 204.
  • the moisture removal system 708 is coupled to the top portion 668 of the enclosure 660. However, the moisture removal system 708 may be disposed at any suitable location to condense any steam and solvent vapor present in the captured gas 204.
  • the captured gas 204 also may be compressed in the compression system 206 and routed to a storage and/or pipeline 208 as discussed above.
  • the controller 220 is configured to monitor the sensors 222 and control operation of the solvent-based gas capture system 500, using the heated fluid 502 supplied through the heated fluid circuits 512 to support the stripper 506.
  • the controller 220 may selectively control the valves 534 to supply the heated fluid 502 through one or more of the heated fluid circuits 512 depending on the conditions of the heated fluid 502, the temperature of solvent in the stripper 506, the temperature of solvent in the reboiler 712, the operating conditions of the combined cycle system 10 (e.g., startup mode, steady state mode, shutdown mode, full load mode, and/or part load mode), the percentage of undesirable gases in the exhaust gas 152, 184, the flow rate of the gas lean solvent 602, the flow rate of the gas rich solvent 620, the flow rate of the gas 600, or any combination thereof.
  • the controller 220 may selectively control the valves 534 to supply the heated fluid 502 through one or more of the heated fluid circuits 512 depending on the conditions of the heated fluid 502, the temperature of solvent in the stripper
  • the controller 220 may be configured to control the one or more additional heat sources (e.g. , electric heaters, furnaces, etc.) to provide heat to support the stripper 506.
  • the controller 220 may be configured to control the WHR system 22, the auxiliary boiler 24, the steam turbine system 14, the HRSG 16, the valves 534, or any combination thereof, to provide the heated fluid 502 to the stripper 506.
  • the controller 220 may be configured to control the WHR system 22 and/or the HRSG 16 (e.g., 160, 162, 164) to provide sufficient cooling of the exhaust gas 152, 184 to eliminate the DCC 624 while providing the heated fluid 502 to support the stripper 506.
  • the controller 220 may be configured to control mixing of the heated fluid 502 from the various heated fluid extraction location 530, thereby providing a desired temperature and pressure of heated fluid 502 to support the stripper 506.
  • the solventbased gas capture system 500 may be configured to selectively use the heated fluid 502 in any manner from the auxiliary boiler 24, the WHR system 22, the steam turbine system 14, the HRSG 16, or any combination thereof.
  • the heated fluid 502 may include a heated water, steam, a solvent (e.g., same solvent used in the solvent-based gas capture system 500), or any combination thereof.
  • FIG. 4 is a block diagram of an embodiment of the combined cycle system 10 of FIG. 1, further illustrating integration of the auxiliary boiler 24 with the steam turbine system 14 and the gas treatment system 18.
  • the combined cycle system 10 is substantially the same as discussed in detail above with reference to FIG. 1.
  • the gas treatment system 18 may include the gas capture systems 20 as discussed in detail above with reference to FIGS. 1-3.
  • the gas turbine system 12, the steam turbine system 14, and the heat recovery steam generator (HRSG) are substantially the same as discussed above. Accordingly, unless stated otherwise, the various components, functionalities, sensor feedback, controls by the controller 220, and aspects of the auxiliary boiler 24 (e.g., connections, functions, etc.) as described with reference to FIGS. 1-3 are the same in the embodiment of FIG. 4.
  • the auxiliary boiler 24 is integrated into the combined cycle system 10 as an additional source of steam to support the steam turbine system 14 in various operating modes (e.g., part load and full load operating modes) of the combined cycle system 10.
  • the auxiliary boiler 24 is configured to supply steam to the steam turbine system 14 via a steam circuit 750 and/or to the gas treatment system 18 (e.g., one or more gas capture systems 20) via a steam supply circuit 752.
  • the auxiliary boiler 24 is configured to route exhaust gas to the gas treatment system 18 (e.g., one or more gas capture systems 20) via an exhaust gas circuit 754, which may be configured to couple to an exhaust gas circuit 756 between the HRSG 16 and the gas treatment system 18.
  • the exhaust gas 152, 184 from the gas turbine system 12 i.e., passing through the HRSG 16
  • the exhaust gas from the auxiliary boiler 24 may be treated in the gas treatment system 18.
  • the steam turbine system 14 is configured to supply steam to the gas treatment system 18 (e.g., one or more gas capture systems 20) via a steam circuit 758, wherein the steam circuits 752 and 758 may couple together and/or run separately to and from the gas treatment system 18.
  • Each of the steam circuits 750, 752, and 758 includes one or more fluid conduits, valves, manifolds, flow splitters, flow combiners, pressure regulators, flow meters, sensors 222, or any combination thereof.
  • the exhaust gas 184 may be directed fully or partially to the auxiliary boiler 24, thereby substituting the auxiliary boiler combustion air partially or fully.
  • the CO2 concentration may increase and the 02 concentration may decrease in the exhaust gas circuit 756.
  • this process may improve the performance of the gas capture system 20 and reduce operating expenditures due to the lower 02 concentration in the exhaust gas. Additional details of the steam circuits 750, 752, and 758 are discussed in detail below.
  • the auxiliary boiler 24 includes a vessel 760 having a combustion section or combustor 762 and a steam section or steam generator 764, wherein the combustor 762 is configured to combust a fuel with air to generate combustion gases, and the combustion gas transfer heat to water in the steam generator 764 to generate steam.
  • the steam circuit 750 between the auxiliary boiler 24 and the steam turbine system 14 may include a conduit 766 that splits into a conduit 768 and a conduit 770, wherein the conduit 768 is coupled to the high-pressure steam turbine 172 and the conduit 770 is coupled to the intermediate-pressure steam turbine 174.
  • the steam circuit 750 may further extend to the low-pressure steam turbine 176.
  • the steam circuit 750 may include the conduit 766 splitting three ways into the conduit 768, the conduit 770, and an additional conduit coupled to the low-pressure steam turbine 176.
  • the steam circuit 750 may include one or more valves configured to control the flow and split of steam to the different steam turbine sections.
  • the conduit 766 includes a valve 772 and the conduit 768 includes a valve 774.
  • the controller 220 is coupled to and configured to control the valves 772 and 774, such that the valve 772 is configured to control the overall flow of steam from the auxiliary boiler 24 to the steam turbine system 14 and the valve 774 is configured to control a split or ratio of steam flows to the high-pressure steam turbine 172 and the intermediate-pressure steam turbine 174.
  • each of the conduits 766, 768, 770, and the additional conduit includes a valve to facilitate steam flow to each of the steam turbines 172, 174, and 176.
  • the controller 220 is configured to control the auxiliary boiler 24 and the valves 772 and 774 based on the operating mode (e.g., part load or full load operating mode) of the combined cycle system 10 and other parameters (e.g., steam demand by the steam turbine system 14, steam demand by the gas treatment system 18, electrical power demand, etc.).
  • the controller 220 is configured to control the auxiliary boiler 24 and the valves 772 and 774 to provide steam only to the high-pressure steam turbine 172, only to the intermediate-pressure steam turbine 174, or a mix or split of flows to both the high- pressure steam turbine 172 and the intermediate-pressure steam turbine 174.
  • the controller 220 is configured to control the auxiliary boiler 24 and the valves 772 and 774 to provide steam to the intermediate-pressure steam turbine 174 during a full load operating mode of the combined cycle system 10, and to provide steam to both the high-pressure steam turbine 172 and the intermediate-pressure steam turbine 174 during a part load operating mode of the combined cycle system 10.
  • the auxiliary boiler 24 may provide steam to the intermediate-pressure steam turbine 174 to improve steam turbine output by at least 2.5%-5% and to improve the efficiency by at least 0.2%.
  • the controller 220 may be configured to control the auxiliary boiler 24 to vary the steam characteristics (e.g., pressure, temperature, etc.) and the valves 772 and 774 to control (e.g., increase or decrease) the overall steam supply and the split of steam between the high-pressure steam turbine 172 and the intermediatepressure steam turbine 174.
  • the controller 220 may continuously or incrementally vary (e.g., increase or decrease) the overall steam supply based on the steam demand and/or maintain the overall steam supply within a range (e.g., upper and lower thresholds) from the auxiliary boiler 24 to the high-pressure steam turbine 172 and the intermediate-pressure steam turbine 174.
  • the controller 220 may continuously or incrementally vary (e.g., increase or decrease) the split based on the steam demand and/or maintain the split within a range (e.g., upper and lower thresholds for the split) from the auxiliary boiler 24 to the high- pressure steam turbine 172 and the intermediate-pressure steam turbine 174.
  • a range e.g., upper and lower thresholds for the split
  • the steam turbine system 14 is configured to provide steam to the gas treatment system 18 via the steam circuit 758, which may include a conduit 776 coupled to the intermediate-pressure steam turbine 174, a conduit 778 coupled to a conduit 779 extending between the intermediate-pressure steam turbine 174 and the low-pressure steam turbine 176, and a conduit 780 coupled to the low-pressure steam turbine 176.
  • the conduits 776, 778, and 780 may further include respective valves 782, 784, and 786 coupled to and controlled by the controller 220.
  • the conduits 776, 778, and 780 may extend separately to the gas treatment system 18 and/or the conduits 776, 778, and 780 may combine into a conduit 788 extending to the gas treatment system 18.
  • the steam circuit 758 may further include a conduit 790 as a return (e.g., condensate return) from the gas treatment system 18 to the steam turbine system 14, such as connected to the return line 181 from the low-pressure steam turbine 176 to the HRSG 16.
  • a conduit 790 as a return (e.g., condensate return) from the gas treatment system 18 to the steam turbine system 14, such as connected to the return line 181 from the low-pressure steam turbine 176 to the HRSG 16.
  • the controller 220 is configured to control the auxiliary boiler 24, the steam turbine system 14, and the valves 782, 784, and 786 based on the operating mode (e.g., part load or full load operating mode) of the combined cycle system 10 and other parameters (e.g., steam demand by the steam turbine system 14, steam demand by the gas treatment system 18, electrical power demand, etc.).
  • the operating mode e.g., part load or full load operating mode
  • other parameters e.g., steam demand by the steam turbine system 14, steam demand by the gas treatment system 18, electrical power demand, etc.
  • the controller 220 is configured to control the conduits 776, 778, and 780 to extract steam (e.g., intermediate-pressure steam) only from the intermediate-pressure steam turbine 174 through the conduit 776 for supply to the gas treatment system 18, to extract steam only from the conduit 779 between the steam turbines 174 and 176 through the conduit 778 for supply to the gas treatment system 18, to extract steam (e.g., low-pressure steam) only from the low-pressure steam turbine 176 through the conduit 780 for supply to the gas treatment system 18, or any combination thereof.
  • steam e.g., intermediate-pressure steam
  • the controller 220 is configured to control the conduits 776, 778, and 780 to extract steam (e.g., intermediate-pressure steam) only from the intermediate-pressure steam turbine 174 through the conduit 776 for supply to the gas treatment system 18, to extract steam only from the conduit 779 between the steam turbines 174 and 176 through the conduit 778 for supply to the gas treatment system 18, to extract steam (e.g., low-pressure steam) only from the low-
  • the controller 220 is configured to control the conduits 776, 778, and 780 to provide a ratio of steam flows (e.g., steam at different pressures) through one or more of the conduits 776, 778, 780, and 788 of the steam circuit 758 to the gas treatment system 18.
  • a ratio of steam flows e.g., steam at different pressures
  • the controller 220 is configured to control the conduits 776, 778, and 780 based on sensor feedback (e.g., temperature, pressure, etc.) from sensors 222 along the conduits 776, 778, 779, 780, and/or 788, such that steam within a desired property range (e.g., temperature range, pressure range, etc.) can be supplied to the gas treatment system 18 for use in the one or more gas capture systems 18.
  • sensor feedback e.g., temperature, pressure, etc.
  • a desired property range e.g., temperature range, pressure range, etc.
  • the auxiliary boiler 24 may be configured to provide steam to the gas treatment system 18 independently and/or in combination with the steam provided by the steam turbine system 14 to the gas treatment system 18.
  • the steam circuits 752 and 758 are coupled together, such that a conduit 792 of the steam circuit 752 couples to and supplies steam to the conduit 788 of the steam circuit 758, and a conduit 794 of the steam circuit 752 couples to and receives condensate from the conduit 790 of the steam circuit 758.
  • a combined steam supply may be provided to the gas treatment system 18 via the conduit 792 coupled to the auxiliary boiler 24 and the conduit 788 coupled to the steam turbine system 14.
  • the condensate from the gas treatment system 18 may be returned to the HRSG 16 via the conduit 790, to the auxiliary boiler 24 via the conduits 790 and 794, or a combination thereof.
  • a valve 796 may be disposed along the conduit 792 to control the steam supply from the auxiliary boiler 24 to the gas treatment system 18 and/or a split of steam supplies from the auxiliary boiler 24 and the steam turbine system 14 to the gas treatment system 18.
  • a valve 798 may be disposed along the conduit 794 to control the condensate return to the auxiliary boiler 24 from the gas treatment system 18 and/or a split of condensate returns to the auxiliary boiler 24 and the HRSG 16 from the gas treatment system 18.
  • the HRSG 16 may be configured to provide steam to the gas treatment system 18 independently and/or in combination with the steam provided by the steam turbine system 14 to the gas treatment system 18 and/or in combination with the steam provided by the auxiliary boiler 24 to the gas treatment system 18.
  • the HRSG 16 may be configured to provide low-pressure steam, intermediate-pressure steam, and/or high-pressure steam to the gas treatment system 18 as illustrated by steam circuits 800, 802, and 804, respectively.
  • the steam circuits 800, 802, and 804 may be coupled to the HP section 160, the IP section 162, and the LP section 164 of the HRSG 16 as illustrated in FIG. 1.
  • Efficiency, output, and/or energy demands of the HRSG 16, the steam turbine system 14, and/or the gas treatment system 18 may determine where steam is extracted as well as how much steam is extracted. Additionally or alternatively, as shown in FIG. 4, excess water and/or condensation from the steam turbine system 14 and/or the gas treatment system 18 may be returned to the auxiliary boiler 24. Further, as mentioned previously, the controller 220 may be configured to control the HRSG 16, the steam turbine system 14, the WHR system 22, the auxiliary boiler 24, or any combination thereof, to control characteristics of the steam (e.g., temperature, pressure, flow rate, steam content, water content, etc.) supplied to the gas treatment system 18.
  • characteristics of the steam e.g., temperature, pressure, flow rate, steam content, water content, etc.
  • the auxiliary boiler 24 may be configured for integration with the EGR system 150.
  • exhaust gas 184 from the HRSG 16 may be sent to the EGR system 150, to the auxiliary boiler 24 as a diluent for combustion in the combustor 762 of the auxiliary boiler 24, or both.
  • unfavorable gases, such as CO2 sent to the gas capture systems 20 may increase in concentration, thereby increase the efficiency of the gas capture system 20.
  • integration of the auxiliary boiler 24 with the EGR system 150 may decrease the concentration of gases used for fuel, such as 02, sent to the gas treatment system 18 and/or the gas capture systems 20, thereby increasing the efficiency of the EGR system 150.
  • the auxiliary boiler 24 may be designed to produce steam flows in terms of temperature and pressure levels that can be easily integrated in the steam turbine system 14, thereby avoiding the need for using the HRSG to provide supplementary steam. It should be noted that supplementary firings of the HRSG may require augmenting air and/or would limit the exhaust gas recirculation percentage when in operation due to the consumption of oxygen. As such, the auxiliary boiler may be particularly useful to implement with the EGR system 150 as a retrofit in a power plant that has supplementary firing of the HRSG.
  • a flexible steam supply to the gas treatment system 18, which uses the steam as a heat source to facilitate the gas capture process (e.g., desorption from sorbent material, stripping from solvents, etc.) by the one or more gas capture systems 20.
  • the flexible steam supply integrates the auxiliary boiler 24 with the steam turbine system 14, wherein the auxiliary boiler 24 provides steam directly to the gas treatment system 18 and/or indirectly to the gas treatment system 18 while supporting the steam turbine system 14.
  • the steam turbine system 14 may receive a main steam supply from the HRSG 16 during normal operating conditions (e.g., full load operating mode) and a secondary steam supply from the auxiliary boiler 24.
  • the auxiliary boiler 24 helps to support the steam turbine system 14 when steam from the HRSG 16 may not meet the steam demands of the steam turbine system 14 and/or the steam demands of the gas treatment system 18.
  • the auxiliary boiler 24 may vary the steam properties (e.g., pressure, temperature, etc.) and vary the steam delivery to one or more steam sections (e.g., high-pressure steam turbine 172, intermediatepressure steam turbine 174, and/or low-pressure steam turbine 176) to support the steam turbine system 14.
  • the steam turbine system 14 may vary the steam properties (e.g., pressure, temperature, etc.) and vary the steam delivery to the gas treatment system 18 by varying the extraction points from the steam turbine system 18, such as via conduits 776, 778, and 780 coupled to the intermediate-pressure steam turbine 174, the conduit 779 between the intermediate-pressure steam turbine 174 and the low-pressure steam turbine 176, and the low-pressure steam turbine 176.
  • the auxiliary boiler 24 integrated with the steam turbine system 14 provides flexibility in simultaneously supporting both the steam turbine system 14 and the gas treatment system 14.
  • a system includes a heat recovery steam generator (HRSG) configured to generate a first steam using heat from an exhaust gas.
  • the system further includes an auxiliary boiler configured to generate a second steam and a steam turbine system configured to receive the first steam, the second steam, or a combination thereof.
  • the system further includes a gas capture system configured to capture an undesirable gas from an exhaust gas.
  • the gas capture system is configured to receive the second steam from the auxiliary boiler, a third steam from the steam turbine system while the steam turbine system receives the second steam from the auxiliary boiler, or a combination thereof.
  • the steam turbine system is configured to receive the second steam from the auxiliary boiler at a high-pressure steam turbine, an intermediate pressure steam turbine, a low-pressure steam turbine, or a combination thereof.
  • auxiliary boiler includes a variable pressure auxiliary boiler.
  • the gas capture system includes a sorbent-based gas capture system, a solvent-based gas capture system, or any combination thereof.
  • the HRSG is configured to supply the first steam to the steam turbine system, the gas capture system, or a combination thereof, at one or more steam pressures
  • the auxiliary boiler is configured to provide the second steam to the steam turbine system, the gas capture system, or a combination thereof, at one or more steam pressures
  • the steam turbine system is configured to provide the third steam to the gas capture system at one or more steam pressures.
  • a controller having a processor, a memory, and instructions stored on the memory and executable by the processor to control steam supply to the steam turbine system and steam supply to the gas capture system.
  • a system includes a controller having a processor, a memory, and instructions stored on the memory and executable by the processor to control a supply of a first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG generates the first steam using heat from an exhaust gas.
  • the controller is further configured to control a supply of a second steam from an auxiliary boiler to the steam turbine system and/or a gas capture system, wherein the gas capture system is configured to capture an undesirable gas from the exhaust gas.
  • the controller is further configured to control a supply of a third steam from the steam turbine system to the gas capture system while the steam turbine system receives the second steam from the auxiliary boiler.
  • controller is further configured to control: the supply of the second steam from the auxiliary boiler to the steam turbine system at a high-pressure steam turbine, an intermediate pressure steam turbine, or a combination thereof.
  • controller is further configured to control: the supply of the third steam from the steam turbine system to the gas capture system from an intermediate-pressure steam turbine, a low-pressure steam turbine, or at a conduit extending between the intermediate-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.
  • a method includes supplying a first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG generates the first steam using heat from an exhaust gas.
  • the method further includes supplying a second steam from an auxiliary boiler to the steam turbine system and/or a gas capture system, wherein the gas capture system is configured to capture an undesirable gas from the exhaust gas.
  • the method further includes supplying a third steam from the steam turbine system to the gas capture system while the steam turbine system receives the second steam from the auxiliary boiler.
  • the method of the preceding clause further including supplying the second steam from the auxiliary boiler to the steam turbine system at a high-pressure steam turbine, an intermediate pressure steam turbine, or a combination thereof.
  • the method further includes supplying the third steam from the steam turbine system to the gas capture system from an intermediate-pressure steam turbine, a low-pressure steam turbine, or at a conduit extending between the intermediate -pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

Un système comprend un générateur de vapeur à récupération de chaleur (HRSG) conçu pour générer une première vapeur à l'aide de la chaleur provenant d'un gaz d'échappement. Le système comprend en outre une chaudière auxiliaire conçue pour générer une seconde vapeur et un système de turbine à vapeur conçu pour recevoir la première vapeur, la seconde vapeur ou une combinaison de celles-ci. Le système comprend en outre un système de capture de gaz conçu pour capturer un gaz indésirable provenant d'un gaz d'échappement. Le système de capture de gaz est conçu pour recevoir la seconde vapeur provenant de la chaudière auxiliaire, une troisième vapeur provenant du système de turbine à vapeur pendant que le système de turbine à vapeur reçoit la seconde vapeur provenant de la chaudière auxiliaire, ou une combinaison de celles-ci.
PCT/US2023/084097 2023-12-14 2023-12-14 Système et procédé de capture de gaz à l'aide de la vapeur provenant d'une turbine à vapeur supportée par une chaudière auxiliaire Pending WO2025128110A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
PCT/US2023/084097 WO2025128110A1 (fr) 2023-12-14 2023-12-14 Système et procédé de capture de gaz à l'aide de la vapeur provenant d'une turbine à vapeur supportée par une chaudière auxiliaire

Applications Claiming Priority (1)

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PCT/US2023/084097 WO2025128110A1 (fr) 2023-12-14 2023-12-14 Système et procédé de capture de gaz à l'aide de la vapeur provenant d'une turbine à vapeur supportée par une chaudière auxiliaire

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WO2025128110A1 true WO2025128110A1 (fr) 2025-06-19

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Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2108888A1 (fr) * 2008-04-07 2009-10-14 Siemens Aktiengesellschaft Installation de capture de carbone et système de centrale électrique
US20110120130A1 (en) * 2009-11-25 2011-05-26 Hitachi, Ltd. Fossil Fuel Combustion Thermal Power System Including Carbon Dioxide Separation and Capture Unit
US20120031101A1 (en) * 2009-01-23 2012-02-09 Alstom Technology Ltd Gas turbine with flow separation and recirculation
US20150000249A1 (en) * 2012-03-21 2015-01-01 Alstom Technology Ltd Combined cycle power plant
US20210079823A1 (en) * 2018-04-24 2021-03-18 Mitsubishi Heavy Industries Engineering, Ltd. Plant and air pollution control method

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP2108888A1 (fr) * 2008-04-07 2009-10-14 Siemens Aktiengesellschaft Installation de capture de carbone et système de centrale électrique
US20120031101A1 (en) * 2009-01-23 2012-02-09 Alstom Technology Ltd Gas turbine with flow separation and recirculation
US20110120130A1 (en) * 2009-11-25 2011-05-26 Hitachi, Ltd. Fossil Fuel Combustion Thermal Power System Including Carbon Dioxide Separation and Capture Unit
US20150000249A1 (en) * 2012-03-21 2015-01-01 Alstom Technology Ltd Combined cycle power plant
US20210079823A1 (en) * 2018-04-24 2021-03-18 Mitsubishi Heavy Industries Engineering, Ltd. Plant and air pollution control method

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