Gas capture system and method using gas from steam turbine steam powered by auxiliary boiler support

Abstract

A system includes a heat recovery steam generator (HRSG) configured to generate a first steam using heat from an exhaust gas. The system also 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 also includes a gas capture system configured to capture an undesirable gas from the exhaust gas. The gas capture system is configured to receive the second steam from the auxiliary boiler, receive a third steam from the steam turbine system when the steam turbine system receives the second steam from the auxiliary boiler, or a combination thereof.

Description

Background Technology

[0001] This application relates in its entirety to a system and method for supporting a gas capture system utilizing steam, which takes into account variations in steam supply under full-load and partial-load operating conditions.

[0002] Industrial power plants (such as combustion-driven power plants) may produce a variety of gases, including exhaust gases from combustion systems. Combustion systems may include gas turbine engines, reciprocating piston-cylinder engines, furnaces, boilers, or other industrial equipment. These exhaust gases may include one or more undesirable gases, such as acid gases and / or greenhouse gases. For example, undesirable gases may include carbon oxides (CO). x Such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NO) x Such as nitrogen dioxide (NO2) and / or sulfur oxides (SO4) x Examples of undesirable gases include sulfur dioxide (SO2). CO2 is both an acid gas and a greenhouse gas. Unfortunately, atmospheric CO2 levels have generally increased over thousands of years and currently exceed approximately 420 parts per million (ppmv) by volume or 643 parts per million (ppmw) by weight. With the emergence of environmental concerns and regulations regarding global warming, there is a desire to reduce the emission of undesirable gases (e.g., CO2) into the atmosphere, particularly for equipment that consumes hydrocarbon fuels, such as combustion systems. Carbon capture plants can reduce atmospheric CO2. Therefore, improving the efficiency of such plants can have significant commercial and environmental implications. Summary of the Invention

[0003] The following outlines some embodiments that are comparable to the scope of the originally claimed subject matter. These embodiments are not intended to limit the scope of the claimed embodiments, but rather are intended only to provide a brief overview of the possible forms of the subject matter. In practice, the currently claimed embodiments may include a variety of forms that may be similar to or different from those set forth below.

[0004] In some embodiments, a system includes a heat recovery steam generator (HRSG) configured to use heat from exhaust gas to generate first steam. The system also includes: an auxiliary boiler configured to generate 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 unwanted gases from the exhaust gas. The gas capture system is configured to receive the second steam from the auxiliary boiler, and, when the steam turbine system receives the second steam from the auxiliary boiler, to receive a third steam, or a combination thereof.

[0005] In some embodiments, a system includes a controller having a processor, memory, and instructions stored in the memory and executable by the processor to control the supply of first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from exhaust gas to generate the first steam. The controller is further configured to control the supply of 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 unwanted gases from the exhaust gas. The controller is further configured to control the supply of third steam from the steam turbine system to the gas capture system when the steam turbine system receives the second steam from the auxiliary boiler.

[0006] In some embodiments, a method includes supplying first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from exhaust gas to generate the first steam. The method further includes supplying 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 unwanted gases from the exhaust gas. The method also includes supplying a third steam from the steam turbine system to the gas capture system when the steam turbine system receives the second steam from the auxiliary boiler. Attached Figure Description

[0007] These and other features, aspects, and advantages of the currently disclosed technology will be better understood when the following detailed description is read with reference to the accompanying drawings, in which the same characters denote the same parts, wherein:

[0008] Figure 1 It is a block diagram of an implementation scheme of a combined cycle system having a gas turbine system, a steam turbine system, a heat recovery steam generator (HRSG), a gas handling system having one or more gas capture systems, and an auxiliary boiler (i.e., an auxiliary boiler) configured to supply steam to the steam turbine system, the gas handling system, or both.

[0009] Figure 2 yes Figure 1 A schematic diagram of an implementation scheme for a gas capture system of a gas handling system, illustrating an adsorbent-based gas capture system having an adsorption mode and a desorption mode, and an auxiliary boiler configured to supply steam to a steam turbine system, a gas handling system, or both.

[0010] Figure 3 yes Figure 1 A schematic diagram illustrating an implementation scheme of a gas capture system for a gas handling system, the schematic diagram illustrating a solvent-based gas capture system with an absorber and a stripper, and an auxiliary boiler configured to supply steam to a steam turbine system, a gas handling system, or both.

[0011] Figure 4 This is a schematic diagram of an implementation scheme for an auxiliary boiler as part of a gas handling system, wherein the auxiliary boiler is configured to supply steam to a steam turbine system, a gas handling system, or both. Detailed Implementation

[0012] The following describes one or more specific embodiments of the systems and methods disclosed herein. To provide a concise description of these embodiments, not all features of the actual implementation may be described in the specification. It should be understood that, as in any engineering or design project, numerous implementation-specific decisions must be made in the development of any such implementation to achieve the developer's specific objectives, such as complying with system-related and business-related constraints, which may vary from implementation to implementation. Furthermore, it should be understood that such development work may be complex and time-consuming, but remains a routine task of design, fabrication, and manufacturing for those skilled in the art who benefit from this disclosure.

[0013] When describing elements of various embodiments of the currently disclosed implementations, the articles “a,” “an,” “the,” and “the” are intended to mean that one or more of the elements are present. The terms “comprising,” “including,” and “having” are intended to be inclusive and mean that additional elements may be present in addition to those listed.

[0014] The disclosed embodiments include systems and methods for reducing the carbon footprint of combustion systems, such as combustion-driven power plants and / or combined cycle power plants, using gas treatment systems with one or more gas capture systems. As discussed below, 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 supplying variable steam to the steam turbine system, wherein the steam is provided by the steam turbine system and / or the auxiliary boiler as a heat source (e.g., steam) for the gas capture system. The gas capture system is configured to remove unwanted gases (e.g., CO2) from the intake air and / or exhaust gas of the combustion system. The gas capture system may include adsorbent-based gas capture systems, solvent-based gas capture systems, cryogenic gas capture systems, membrane-based gas capture systems, or combinations thereof. For example, a gas capture system (e.g., an adsorbent-based gas capture system) may include one or more temperature-switching adsorption (TSA) units or absorbers that rely on temperature fluctuations to adsorb unwanted gases at a first temperature (e.g., a low temperature) and desorb unwanted gases at a second temperature (e.g., a high temperature).

[0015] Gas capture systems typically use a heat source (e.g., steam) to support the gas capture process. For example, an adsorbent-based gas capture system is configured to adsorb unwanted gases into an adsorbent material, and then subsequently desorb the unwanted gases from the adsorbent material using a heat source (e.g., steam from an HRSG, steam from a steam turbine system at least partially supported by an HRSG and an auxiliary boiler, steam from an auxiliary boiler, or other steam sources). The adsorption process is exothermic, while the desorption process is endothermic. By further example, a solvent-based gas capture system may include an absorber configured to absorb unwanted gases into a solvent and a stripper configured to strip the unwanted gases from the solvent using steam (e.g., steam from an HRSG, steam from a steam turbine system at least partially supported by an HRSG and an auxiliary boiler, steam from an auxiliary boiler, or other steam sources). Although solvent-based gas capture systems are discussed as using a solvent as the absorbent fluid, the disclosed embodiments may use any suitable absorbent fluid to capture unwanted gases. Therefore, a solvent-based gas capture system may also be described as a fluid-based absorbent gas capture system.

[0016] Gas capture systems can use steam at certain pressure levels and temperatures to capture gases such as carbon capture (e.g., CO2 capture). Therefore, in the embodiments described in detail below, steam can be extracted from a steam turbine system, an auxiliary boiler, or both, which are at least partially supported by an HRSG and an auxiliary boiler. This disclosure describes the concept of integrating an auxiliary boiler with a steam turbine system, wherein the steam turbine system receives a primary supply of steam from the HRSG while receiving additional steam from the auxiliary boiler, allowing steam to be extracted from the steam turbine system for use in the gas capture system, regardless of the operating mode (e.g., partial load or full load operating conditions). Specifically, during full load operation, integrating auxiliary boiler steam with the steam turbine can increase the steam turbine system output by 2.5% to 5% and improve efficiency by 0.2%, allowing steam to be extracted from the steam turbine system for use in the gas capture system. During partial load operation, the steam turbine system may face operational challenges leading to lower efficiency output. However, an auxiliary boiler integrated with the steam turbine system helps increase the output and efficiency of the steam turbine system during partial load operation, allowing steam to be extracted from the steam turbine system for use in the gas capture system. In partial load operation, auxiliary boilers can change the pressure of steam supplied to the steam turbine system and / or change the location of steam supply to the steam turbine system, for example, by supplying steam to multiple steam turbine stages (e.g., high-pressure and medium-pressure steam turbine stages) of the steam turbine system.

[0017] As discussed below, auxiliary boilers integrated with steam turbine systems can be used in a variety of configurations in conjunction with gas capture systems. Although specific examples are provided below, auxiliary boilers integrated with steam turbine systems can be used in any suitable manner to support a variety of gas capture systems, including but not limited to adsorbent-based gas capture systems, solvent-based gas capture systems, and cryogenic gas capture systems.

[0018] In view of the above, Figure 1 This 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 handling system 18 having one or more gas capture systems 20, a waste heat recovery (WHR) system 22, and an auxiliary boiler 24. In some embodiments, the WHR 22 is excluded from the combined cycle system 10. The auxiliary boiler 24 may be completely separated from the HRSG 16, such that the auxiliary boiler 24 and the HRSG 16 operate separately or independently. The gas turbine system 12 is driven by high-temperature combustion gases and outputs exhaust gas 152. The HRSG 16 recovers heat from the exhaust gas 152 to generate steam, which then drives the steam turbine system 14. In some embodiments, such as Figure 1 As depicted, auxiliary boiler 24 can be integrated into combined cycle system 10 as an additional steam source to support steam turbine system 14 and / or otherwise meet the steam demand of combined cycle system 10. In some embodiments, auxiliary boiler 24 is integrated with steam turbine system 14, wherein steam turbine system 14 receives a main steam supply from HRSG 16 while receiving additional steam from auxiliary boiler 24, such that steam can be extracted from steam turbine system 14 for use in gas handling system 18 (e.g., one or more gas capture systems 20), regardless of the operating mode (e.g., partial or full load operating conditions of combined cycle system 10). The integration of auxiliary boiler 24 with steam turbine system 14 is discussed in more detail below. Combined cycle system 10 may also include or may not include WHR system 22, which recovers heat from exhaust gas 184 to obtain heated fluid 26 used in gas handling system 18. One or more gas capture systems 20 of gas handling system 18 are configured to capture undesired gases (e.g., CO2) from gases such as exhaust gas 152 and / or air. The gas capture system 20 may include an adsorbent-based gas capture system, a solvent-based gas capture system, a cryogenic gas capture system, or any combination thereof.

[0019] Before discussing the details of the gas handling system 18, various aspects of the combined cycle system 10 will be discussed in further detail. For the purposes of orientation in the figures, reference may be made to the axial direction or axis 30, the radial direction or axis 32 extending radially away from the axial direction or axis 30, and the circumferential direction or axis 34 extending circumferentially around the axial direction or axis 30. For example, directions or axes 30, 32, and 34 may be referenced to the axis of rotation 36 of the gas turbine system 12.

[0020] 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. In some embodiments, the exhaust section 48 includes an exhaust chimney and / or exhaust duct coupled to the HRSG 16. The compressor section 42 may include at least one shaft 50 disposed along a rotation axis 36, a housing 52 (e.g., an annular housing) 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 guide vanes 56 extending radially inward from the housing 52 toward the at least one shaft 50. In an illustrated embodiment, the compressor section 42 may include a plurality of compressor stages 58, each compressor stage having a plurality of compressor guide vanes 56 circumferentially spaced apart in an axial position about the at least one shaft 50 and a plurality of compressor blades 54 circumferentially spaced apart in different axial positions about the at least one shaft 50 (i.e., the compressor guide vanes 56 and compressor blades 58 are axially spaced apart). Therefore, compressor section 42 is configured to receive the intake gas 60 flow from intake section 40 and progressively compress the intake gas 60 through multiple compressor stages 58. As discussed in more detail below, the intake gas 60 may include intake air, exhaust gas recirculation (EGR) flow or recirculated exhaust gas, or a combination thereof.

[0021] Combustor section 44 may include one or more burners 62, such as a single annular burner circumferentially arranged about an axis of rotation 36 or a plurality of burners 62 circumferentially spaced about an axis of rotation 36. In an illustrated embodiment, each burner 62 includes a head end portion 64 coupled to a combustion section 66. The combustion section 66 includes a combustion chamber 68, a burner liner 70 circumferentially arranged around the combustion chamber 68, a flow sleeve 72 circumferentially arranged around the burner liner 70, and a channel 74 extending between the burner liner 70 and the flow sleeve 72. The channel 74 is configured to deliver a compressed gas flow toward a head end chamber 78 disposed in the head end portion 64 in an upstream direction 76. The head end chamber 78 of the burner 62 and the combustion chamber 68 are separated or partitioned from each other by an intermediate plate 80. In the head end chamber 78, a plurality of fuel nozzles 82 are coupled to the intermediate plate 80 and the end plate 84 of the head end portion 64. During operation, each burner 62 receives compressed gas 86 (e.g., air, EGR, etc.) from the compressor section 42, delivers the compressed gas 86 along the passage 74 toward the head chamber 78 as indicated by arrow 76, and delivers the compressed gas into the combustion chamber 68 through the fuel nozzle 82.

[0022] In some embodiments, each burner 62 may receive one or more fuel flows from a fuel system 88 coupled to a fuel nozzle 82, wherein the fuel system 88 includes a fuel supply system 90 coupled to one or more fuel circuits 92. For example, the fuel circuits 92 may include fuel circuits 94, 96, and 98 coupled to different sets of fuel nozzles 82. Fuel circuits 92 (e.g., 94, 96, and 98) may include fuel conduits, fuel manifolds, fuel valves, pressure regulators, and other flow control elements. The fuel system 88 is configured to supply one or more fuels, such as liquid fuels and / or gaseous fuels, to each of the fuel nozzles 82 for injection into the combustion chamber 68. Fuels may include natural gas, syngas generated by a gasifier, methane, hydrogen, biofuels, fuel oil, or any combination thereof. The fuel supply system 90 may include multiple components for controlling the flow rate of various fluids to the burner 62. For example, the fuel supply system 90 may include one or more components 100. In some embodiments, component 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.

[0023] Fuel nozzle 82 is configured to inject one or more fuels from fuel system 88 and compressed gas 86 from compressor section 42. In some embodiments, fuel nozzle 82 is configured to inject compressed air 104 from compressor system 106 having air compressor 108 coupled to drive unit 110, such as an electric motor, internal combustion engine, shaft coupled to gas turbine system 12, or another suitable drive unit. Compressor system 106 may be configured to receive air from the environment and / or from intake section 40. Additionally, compressor system 106 may be configured to enable multiple operating modes, such as EGR mode or non-EGR mode. For example, in some embodiments of gas turbine system 12 with exhaust gas recirculation (EGR), compressor section 42 supplies compressed gas 86 (e.g., compressed exhaust gas) to each burner 62, while compressor system 106 supplies compressed air 104 to each burner 62.

[0024] For example, in some embodiments of the gas turbine system 12 without exhaust gas recirculation (EGR), the compressor section 42 supplies compressed gas 86 (e.g., compressed air) to each combustor 62 without an additional air supply. Therefore, the compressor system 106 may optionally supply compressed air 104 to each combustor 62. During operation, fuel can be burned with air in the combustion chamber 68 of each combustor 62 to generate hot combustion gases 112, which are then delivered from the combustion chamber 68 to the turbine section 46.

[0025] The turbine section 46 includes at least one shaft 114 disposed along a rotation axis 36, a housing 116 (e.g., an annular housing) circumferentially disposed about the at least one shaft 114, a plurality of rotating turbine blades 118 extending radially outward from the at least one shaft 114, and a plurality of fixed turbine guide vanes 120 extending radially inward from the housing 116 toward the at least one shaft 114. The turbine section 46 may include a plurality of turbine stages 122, each turbine stage having a plurality of turbine guide vanes 120 circumferentially spaced about the at least one shaft 114 in an axial position and a plurality of turbine blades 118 circumferentially spaced about the at least one shaft 114 in different axial positions (i.e., the turbine guide vanes 120 and turbine blades 118 are axially spaced). The at least one shaft 114 may also be coupled to 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. In some embodiments, the load 126 may include a generator, a machine, a vehicle propulsion system, or any other suitable load. In the illustrated embodiment, load 126 may be a generator, making combined cycle system 10 a combined cycle power plant. During operation, combustion gas 112 flows from combustor 62 to turbine section 46, where it progressively expands and drives turbine blades 118 in each turbine stage of turbine stage 122, which are coupled to at least one shaft 114, to rotate. Thus, combustion gas 112 drives turbine section 46, which in turn drives compressor section 42 and load 126 via interconnected shafts 50, 124, 114, and 128.

[0026] In some embodiments, the gas turbine system 12 may be configured to have shafts 50, 114, 124, and 128 and connected compressor blades 54 and turbine blades 118 in a common direction of rotation. Shafts 50, 114, 124, and 128 may be removably coupled together using shaft connectors such as flange joints. In some embodiments, some of these shafts may be combined to reduce the number of shafts. For example, all illustrated shafts 50, 114, and 124 may represent a common shaft rotating in a common direction of rotation, such as clockwise or counterclockwise.

[0027] The gas turbine system 12 may be configured to have or not have a compressor system 106 and an exhaust gas recirculation (EGR) system 150. The EGR system 150 is configured (e.g., via intake section 40) to recirculate the exhaust gas 152 output from the turbine section 46 back to the compressor section 42 for compression and delivery to the combustor section 44. However, the gas turbine system 12 may not include the EGR system 150, and may simply introduce airflow into the intake section 40 for compression by the compressor section 42.

[0028] In some embodiments of the gas turbine system 12 with EGR system 150, recirculated exhaust gas 152 flows through each compressor stage 58 of the compressor stage 40 and compressor stage 42, thereby compressing the recirculated exhaust gas into compressed gas 86 for delivery to the combustor stage 44. Additionally, the combustor stage 44 receives compressed air 104 from the air compressor 108 of the compressor system 106 via fuel nozzle 82. The combustor stage 44 also receives fuel from the fuel system 88, such as via fuel nozzle 82. The fuel from the fuel system 88 is then burned together with the air from the compressor system 106 to produce combustion gases 112, which then flow through the turbine stage 46 to drive the rotation of turbine blades 118 in each turbine stage 122. The recirculated exhaust gas helps reduce temperature and certain emissions associated with combustion in the combustor stage 44 (e.g., nitrogen oxides (NOx)). x The formation of ).

[0029] In some embodiments of the gas turbine system 12 that do not have an EGR system 150, the compressor section 42 receives an airflow from the intake section 40, progressively compresses the airflow via compressor stage 58, and delivers the compressed airflow as compressed gas 86 to the combustor section 44. The compressed airflow then promotes combustion of fuel from the fuel system 88, generating hot combustion gases 112 for delivery to the turbine section 46. In such embodiments, the compressor system 106 may be omitted or included to provide additional compressed air 104 to the combustor section 44. Regardless of the configuration, the combustion gases 112 drive the rotation of turbine blades 118 in the turbine stage 122, thereby rotating at least one shaft 114 coupled to at least one shaft 50 of the compressor section 42 and the shaft 128 driving the load 126.

[0030] In some embodiments, the exhaust gas 152 output from turbine section 46 can then pass through HRSG 16 to transfer heat from the exhaust gas to the water to generate steam for steam turbine system 14. For example, HRSG 16 may include a first pressure section 160 (e.g., a high-pressure (HP) section), a second pressure section 162 (e.g., an intermediate-pressure (IP) section), and a third pressure section 164 (e.g., a low-pressure (LP) section) arranged in series to generate high-pressure steam 166, intermediate-pressure steam 168, and low-pressure steam 170. The heat recovery steam generator 16 can deliver high-pressure steam 166 to the high-pressure steam turbine 172 of steam turbine system 14, intermediate-pressure steam 168 to the intermediate-pressure steam turbine 174 of the steam turbine system, and low-pressure steam 170 to the low-pressure steam turbine 176 of the steam turbine system. Furthermore, an auxiliary boiler 24 may be integrated with steam turbine system 14 to provide supplemental steam at variable steam pressures based on energy and load requirements. For example, auxiliary boiler 24 may include multiple steam injection or supply points for steam injection to high-pressure steam turbine 172, medium-pressure steam turbine 174, or both, such as Figure 1 As depicted in the diagram. Additionally, the auxiliary boiler 24 may be configured to have a steam outlet directly to the gas handling system 18. That is, supplemental steam directly from the auxiliary boiler 24 and / or excess steam from the steam turbine system 14 may be directed to the gas handling system 14 to help support gas capture within the gas handling system 14. In this way, excess or waste steam can be used to support one or more gas capture systems 20 of the gas handling system 18. Steam drives the rotation of blades within each of the steam turbines 172, 174, 176, thereby driving a shaft 178 coupled to a load 180 such as a generator. The low-pressure steam turbine 176 may also return condensate 182 to the low-pressure section 164 of the HRSG 16 via a return line 181 through a pump 183. Additionally, the low-pressure steam turbine 176 may return condensate 182 to the auxiliary boiler 24. The HRSG 16 may then output exhaust gas 152 as partially cooled exhaust gas 184. In some embodiments, exhaust gas 184 may be partially or completely directed through an exhaust stack, gas treatment system 18, EGR system 150, or a combination thereof. In some embodiments, combined cycle system 10 may include an exhaust stack downstream of gas turbine system 12, HRSG 16, gas treatment system 18, or any combination thereof. However, in some embodiments, combined cycle system 10 does not include HRSG 16 and / or steam turbine system 14.

[0031] In the illustrated embodiment, exhaust gas 152 from turbine section 46 and / or exhaust gas 184 from HRSG 16 can pass through WHR system 22 to transfer heat from the exhaust gas to gas treatment system 18. As discussed above, gas treatment system 18 includes one or more gas capture systems 20. For example, gas capture systems 20 may include any or any combination of gas capture systems 190, 192, and 194, each having multiple components (e.g., components 196, 198, 200, and 202). Gas capture systems 20 (e.g., 190, 192, and 194) are configured to obtain captured gas 204 from intake gas 60 and / or exhaust gas 152, 184. In the illustrated embodiment, gas capture systems 20 (e.g., 190, 192, and 194) may capture carbon dioxide (CO2) and output it as captured gas 204, which may be further directed to compression system 206. For example, 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 a storage device and / or pipeline 208.

[0032] Gas capture system 190 is located at, in, or upstream of intake section 40 to capture unwanted gases from the intake air. Gas capture systems 192 and 194 are located downstream of gas turbine system 12 and / or HRSG 16 to capture unwanted gases from exhaust gases 152 and 184. Gas capture systems 20 (e.g., 190, 192, and 194) may include adsorbent-based gas capture systems, solvent-based gas capture systems, cryogenic gas capture systems, or any combination thereof configured to remove and capture unwanted gases. In some embodiments, gas capture systems 20 (e.g., 190, 192, and 194) may be configured to remove and capture unwanted gases such as carbon oxides (CO). x (e.g., carbon dioxide (CO2) and carbon monoxide (CO)), and therefore gas capture system 20 can be described as a carbon capture system. In some embodiments, gas capture system 20 (e.g., 190, 192, and 194) can be configured to remove and capture undesirable gases such as nitrogen oxides (NOx). x (e.g., nitrogen dioxide (NO2)), and therefore the gas capture system 20 can be described as NO x Gas capture system. In some embodiments, gas capture system 20 (e.g., 190, 192, and 194) may be configured to remove and capture undesirable gases such as sulfur oxides (SO₄). x (e.g., sulfur dioxide (SO2)), and therefore the gas capture system 20 can be described as SO xCapture System. In the following discussion, gas capture systems 20 (e.g., 190, 192, and 194) may be described as adsorbent-based carbon capture systems, for example, using adsorbent materials, and / or solvent-based carbon capture systems, for example, using liquid absorbents (e.g., solvents). Alternatively or additionally, the carbon capture system may include membrane-based carbon capture systems, cryogenic carbon capture systems, or any combination thereof. However, embodiments disclosed herein may use gas capture systems 20 (e.g., 190, 192, and 194) of any type or configuration as indicated above.

[0033] Each gas capture system in gas capture system 20 (e.g., 190, 192, and 194) 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 of gas capture systems 192 and 194. For adsorbent-based gas capture systems 20 (e.g., 190, 192, and 194), components 196, 198, 200, and 202 may include adsorbent material disposed on or in a conduit (e.g., adsorption conduit, desorption conduit, and cooling conduit), contactor, cylinder, moving bed, rotating wheel, or any combination thereof along the flow path of inlet gas 60 and / or exhaust gas 152, 184. The adsorbent-based gas capture system 20 is configured to adsorb unwanted gases (e.g., CO2) into the adsorbent material in adsorption mode and desorb unwanted gases from the adsorbent material in desorption mode. Components 196, 198, 200, and 202 may include a cooling system for helping to control the temperature of the adsorbent material (e.g., maintaining the adsorbent temperature within an upper and lower temperature threshold range) to improve the efficiency of the adsorption mode. This cooling system may include heat exchangers (e.g., finned and tubular heat exchangers), heat pipes, and other thermal control systems coupled to the adsorbent material to help control its temperature. Components 196, 198, 200, and 202 may also include a heating system, such as a heating fluid system (e.g., a steam system, an electric heater, a waste heat system, etc.), configured to apply heat to the adsorbent material during desorption mode to desorb unwanted gases from the adsorbent material. For example, auxiliary boiler 24 is configured to provide supplemental steam to steam turbine system 14, gas handling system 18, or both. Components 196, 198, 200, and 202 may also include a cooling system, such as a cooling fluid system (e.g., a gas cooling system, a liquid cooling system, etc.), configured to apply cooling fluid to the adsorbent material during cooling mode. The adsorbent-based gas capture system 20 may also include other suitable components 196, 198, 200, and 202 that support the adsorbent material.

[0034] For a solvent-based gas capture system 20 (e.g., 190, 192, and 194), components 196, 198, 200, and 202 may include one or more absorbers, one or more strippers, and a solvent loop through the absorbers and strippers. The absorber is configured to absorb an undesired gas (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., a CO2-rich solvent). The stripper is configured to strip the undesired gas from the gas-rich solvent in a desorption mode, thereby outputting a gas-lean solvent (e.g., a CO2-lean solvent) back to the absorber and outputting captured gas 204. Components 196, 198, 200, and 202 may include a cooling system coupled to the absorber, wherein the cooling system is configured to extract heat generated by the absorption mode to help control the solvent temperature (e.g., maintain the solvent temperature within an upper and lower temperature threshold range) to improve the efficiency of the absorption mode. The cooling system may include heat exchangers (e.g., finned and tubular heat exchangers), heat pipes, and other thermal control systems coupled to the absorber to help control the solvent temperature. Components 196, 198, 200, and 202 may also include heating systems coupled to the stripper, such as heated fluid systems (e.g., steam systems, electric heaters, waste heat systems, etc.), wherein the heating systems are configured to apply heat to the rich gas solvent during desorption mode to desorb unwanted gases from the rich gas solvent. For example, auxiliary boiler 24 may provide heat directly to gas processing system 18 in the form of steam, indirectly to gas processing system 18 in the form of steam via steam turbine system 14, or a combination thereof, including providing heat to the rich gas solvent in the form of steam during desorption mode. WHR 22 may also be configured to provide excess heat to the rich gas solvent as heated fluid 26 during desorption mode. Components 196, 198, 200, and 202 may also include a reboiler coupled to the stripper, pumps and valves for controlling the flow rate of solvent through the solvent loop between the absorber and the stripper, and heat exchangers for cooling the lean solvent supplied to the absorber and heating the rich solvent supplied to the stripper. The solvent-based gas capture system 20 may also include other suitable components 196, 198, 200, and 202 supporting the absorber and the stripper.

[0035] In some embodiments, components 196, 198, 200, and 202 of the gas capture system 20 and / or components 210 upstream of gas capture systems 192 and 194 (e.g., WHR system 22 and components 212, 214, and 216) may include a dryer or dehydration system (e.g., a water-gas separator), a particulate removal system (e.g., a filter and / or a solid-gas separator), one or more booster fans configured to enhance the flow of the treated gas, one or more coolers, one or more valves controlling the flow of gas to the gas capture system 20, a bypass system configured to bypass the gas capture system 20, or one or more of these combinations. 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 by injecting a cooling fluid (e.g., cooling water) directly into the exhaust gas 184. Therefore, the cooler is configured to cool the exhaust gas 184 before it is treated in the gas treatment system 18. The separator may include a gravity separator, a centrifugal separator, or a combination thereof. In some embodiments, the gas capture systems 20 (e.g., 190, 192, and 194) may be described as multiple gas capture stages. However, in some embodiments, the gas treatment system 18 may include only a single stage and / or the gas capture system 20. For example, the gas capture system 20 may include only one, two, or all three of the gas capture systems 190, 192, and / or 194.

[0036] In some embodiments, exhaust gas 184 may partially or completely bypass gas treatment system 18 and flow to EGR system 150, and / or exhaust gas 184 may partially or completely flow through gas treatment system 18 before flowing to EGR system 150. EGR system 150 may include one or more ducts, valves, flow controls, coolers, blowers, or any combination thereof configured to provide at least a portion of exhaust gas 152, 184 (e.g., EGR flow) to intake section 40 for recirculation through compressor section 42. Coolers may be configured to cool exhaust gas 152, 184 to a lower temperature (e.g., approximately ambient temperature) before recirculation to compressor section 42. Blowers may be configured to increase the pressure and flow rate of exhaust gas 152, 184 to help overcome pressure losses in EGR system 150.

[0037] In the illustrated embodiment, the combined cycle system 10 also includes a controller 220 coupled to the gas turbine system 12, steam turbine system 14, HRSG 16, gas handling system 18, fuel system 88, EGR system 150, and compression system 106, and various sensors 222 distributed throughout the combined cycle system 10. In the illustrated embodiment, the controller 220 includes one or more processors 224, a memory 226, instructions 228 stored in 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. For example, the controller 220 is configured to control fuel delivery and distribution from the fuel system 88 to the fuel nozzles 82 in the combustor section 44. In some embodiments, controller 220 is configured to control the operation of gas capture system 20 (e.g., 190, 192, and 194), such as by controlling operating modes (e.g., adsorption mode, desorption mode, cooling mode), controlling WHR system 22, steam turbine system 14, and (integrated with steam turbine system 14) auxiliary boiler 24 to control the flow rate and temperature of excess heat or steam supplied to gas capture system 20, controlling the flow rate of various fluids through gas capture system 20, or any combination thereof.

[0038] Sensor 222 (labeled "S") is configured to monitor various operating parameters of the combined cycle system 10. In some embodiments, sensor 222 includes a temperature sensor, a pressure sensor, a flow rate sensor, a fluid composition sensor (e.g., a gas composition sensor), a vibration sensor, a gap sensor, a velocity sensor, a humidity and / or moisture sensor, or any combination thereof. Sensor 222 may monitor parameters (e.g., temperature, pressure, flow rate, and fluid composition) at one or more locations of the compressor section 42, burner section 44, turbine section 46, gas handling system 18, WHR system 22, auxiliary boiler 24, steam turbine system 14, heated fluid 26, or any combination thereof.

[0039] For example, sensor 222 can monitor compressor parameters (e.g., the pressure ratio between the inlet and outlet of compressor section 42), combustion gas parameters (e.g., ignition temperature and combustion dynamics), turbine parameters (e.g., temperature and pressure at each turbine stage, turbine inlet, and turbine exhaust manifold), and exhaust emissions. As a further example, exhaust emissions monitored by sensor 222 may include carbon oxides (CO). x Such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NO) x Such as nitrogen dioxide (NO2) and sulfur oxides (SO4). xSuch as sulfur dioxide (SO2), unburned hydrocarbons, particulate matter, and other undesirable exhaust emissions. By further example, sensor 222 can monitor the temperature, pressure, and flow rate of the heated fluid 26 supplied to gas capture system 20, the temperature, pressure, and flow rate of steam supplied to gas capture system 20 via steam turbine system 14 and / or auxiliary boiler 24, the temperature of the adsorbent material in an adsorbent-based gas capture system, the temperature of the solvent in a solvent-based gas capture system, or any combination thereof. In response to feedback from sensor 222, controller 220 can adjust the operating mode, fluid flow rate, heating, cooling, or any combination thereof in gas capture system 20.

[0040] Additionally, in response to feedback from sensor 222 and the operating mode of combined cycle system 10 (e.g., full-load or partial-load operating mode), controller 220 may adjust the supply of steam from auxiliary boiler 24 to steam turbine system 14 and the supply of steam from auxiliary boiler 24 and / or steam turbine system 14 to gas capture system 20. For example, in full-load operating mode, controller 220 may control auxiliary boiler 24 to supply steam to high-pressure steam turbine 172 and change steam parameters (e.g., temperature, pressure, and flow rate) to adapt to full-load operating mode. By further example, in partial-load operating mode, controller 220 may control auxiliary boiler 24 to supply steam to high-pressure steam turbine 172, medium-pressure steam turbine 174, or a combination thereof and change steam parameters (e.g., temperature, pressure, and flow rate) to adapt to partial-load operating mode. In both operating modes, controller 220 can control auxiliary boiler 24 to supply steam only to steam turbine system 14 for indirect supply to gas capture system 20, to gas capture system 20 only directly, or a combination of supplying steam to both steam turbine system 14 and gas capture system 20. Additionally, in both operating modes, controller 220 can (e.g., via valve control) control the extraction of steam from steam turbine system 14 to gas capture system 20. For example, controller 220 can control the extraction of steam from one or more extraction points in steam turbine system 14 (such as from intermediate-pressure steam turbine 174, low-pressure steam turbine 176, or from between steam turbines 174 and 176) via one or more valves along the steam extraction duct.

[0041] The controller 220 can control the auxiliary boiler 24 to adjust (e.g., increase or decrease) the steam temperature, pressure, and flow rate based on the operating mode of the combined cycle system 10, conditions in the steam turbine system 14, the main steam supply from the HRSG 16, the demands of the gas capture system 20, and the steam injection positions from the auxiliary boiler 24 to the steam turbine system 14 and the gas capture system 20. In some embodiments, the auxiliary boiler 24 includes a variable pressure boiler to adapt to different pressure demands during different operating modes of the combined cycle system 10. However, in some embodiments, one or more constant pressure boilers 24 may be coupled to the steam turbine system 14. In some embodiments, the auxiliary boiler 24 may supply steam only to the steam turbine system 14 for indirect supply to the gas capture system 20 from the steam turbine system 14. However, in some embodiments, the auxiliary boiler 24 may also supply steam directly to the gas capture system 20. In view of the above, Figure 2 and Figure 3 Implementation schemes of an adsorbent-based gas capture system and a solvent-based gas capture system using steam from an integrated steam turbine system 14 and an auxiliary boiler 24 are presented.

[0042] Figure 2 yes Figure 1 A schematic diagram of an embodiment of the gas capture system 20 of the gas handling system 18 illustrates an adsorbent-based gas capture system 250 using steam from an integrated steam turbine system 14 and an auxiliary boiler 24. In the illustrated embodiment, the adsorbent-based gas capture system 250 includes multiple adsorbent-based gas capture components or units 252 (e.g., adsorbers or adsorption units) associated with multiple corresponding conduits 254 such as conduits 256, 258, and 260 (e.g., adsorbent-containing conduits). The adsorbent-based gas capture unit 252 may include a temperature-switching adsorption (TSA) unit or adsorber, wherein temperature fluctuations or variations are used to alternate between an adsorption mode at a first temperature and a desorption mode at a second temperature. The first temperature is lower than the second temperature. The lower first temperature enables the adsorbent-based gas capture unit 252 to adsorb unwanted gases, where the lower temperature generally increases the capacity for adsorbing unwanted gases. The higher second temperature enables the adsorbent-based gas capture unit 252 to desorb unwanted gases, which can then be captured and used in other downstream processes.

[0043] In the illustrated embodiment, the adsorbent-based gas capture unit 252 includes adsorbent-based gas capture units 252A, 252B, and 252C associated with conduits 256, 258, and 260. Conduits 254 (e.g., 256, 258, and 260) may be lined with adsorbent along their inner surfaces, filled with adsorbent within their internal volumes, or typically filled with at least 10%, 20%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, or more percent of adsorbent material by volume. However, the adsorbent-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, configured in parallel and / or in series. Each of the conduits 254 (e.g., 256, 258, and 260) includes an outer conduit wall 262 circumferentially disposed around a flow path 264 (e.g., a fluid channel or orifice) along a central axis 266 from an inlet 268 to an outlet 270, wherein adsorbent material 272 is disposed along the inner surface 274 of the outer conduit wall 262 and / or along the outer surface 276 of a plurality of contactors 280 (e.g., contactor plates, panels, or fins). In the illustrated embodiment, the contactors 280 are arranged parallel to each other 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 contactors 280 (e.g., 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, or more contactors 280).

[0044] Each contactor in contactor 280 has a body 284 having an outer surface 276 disposed around an inner portion 286. In some embodiments, an adsorbent material 272 is disposed along the outer surface 276, while the inner portion 286 comprises a material 282 different from the adsorbent material 272. In some embodiments, the body 284 may be a solid body extending through the inner portion 286, wherein the body 284 extending through the inner portion 286 to the outer surface 276 is at least substantially or entirely made of the adsorbent material 272. In some embodiments, the body 284 may be a hollow body of the inner portion 286 (e.g., an inner chamber or cavity), wherein the body 284 has an outer wall 288 disposed around the inner portion 286. For example, the inner portion 286 may include a heat exchange loop or flow path extending through the body 284 between a fluid inlet and a fluid outlet, the heat exchange loop or flow path being coupled to a heat exchange loop for cooling and / or heating. In some embodiments, the internal portion 286 may be configured to circulate cooling fluid during the adsorption mode of the adsorbent-based gas capture system 250, circulate heating fluid (e.g., steam from WHR 22, steam from steam turbine system 14, and / or steam from auxiliary boiler 24) during the desorption mode, and circulate cooling fluid during the cooling mode.

[0045] As discussed in detail below, the gas capture system 20 is configured to operate cyclically and repeatedly for each of the adsorbent-based gas capture units 252A, 252B, and 252C in the following sequence: (1) adsorption mode, (2) desorption mode, and (3) cooling mode. During the adsorption mode, the temperature of the adsorbent material 272 directly affects the adsorption efficiency of the adsorbent material 272. The adsorbent material 272 may have an optimal temperature or temperature range for the effective adsorption of unwanted gases. Unfortunately, the adsorption of unwanted gases into the adsorbent material 272 is an exothermic process that generates heat, which typically increases the temperature of the adsorbent material 272 and reduces its adsorption efficiency without any cooling. Therefore, the disclosed embodiments can control the cooling of the adsorbent material 272 during the adsorption mode to improve the adsorption efficiency. Similarly, the temperature of the adsorbent material 272 directly affects the desorption efficiency of the adsorbent material 272 during the desorption mode. The adsorbent material 272 may have an optimal temperature or temperature range for effectively adsorbing unwanted gases. Therefore, the disclosed embodiments allow for controlled heating of the adsorbent material 272 during desorption mode to improve desorption efficiency. As discussed in detail below, 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 adsorbent-based gas capture units 252A, 252B, and 252C individually or in combination with other heated fluids during desorption mode.

[0046] The temperatures in the adsorption, desorption, and cooling modes can vary depending on the specific application. In some embodiments of carbon capture (e.g., CO2 capture), the adsorption mode can be configured to adsorb unwanted gases from gas 340 into adsorbent material 272 at a first temperature, the desorption mode can be configured to desorb unwanted gases from adsorbent material 272 using a heat source (e.g., steam from steam turbine system 14 and / or auxiliary boiler 24) at a second temperature, and the cooling mode can be configured to cool adsorbent 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 less than the first and second temperatures. For example, 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, and the third temperature may be less than or equal to approximately 0, 5, 10, 15, 20, 25, or 30 degrees Celsius.

[0047] In the illustrated embodiment, the gas capture system 20 includes a thermal control system 290 having a fluid circulation system 292, one or more fluid circulation loops 294 (e.g., fluid conduits, manifolds, valves, etc.), and one or more heat exchangers 296 coupled to each contactor assembly 278 in the adsorbent-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 may also 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 multiple components, such as components 300, 302, and 304, such as heat exchangers, pumps, valves, coolant supply devices, or any combination thereof. The thermal control system 290 circulates a hot fluid (e.g., a liquid or gaseous hot fluid) from the fluid circulation system 292 through the fluid circulation loop 294 and the heat exchanger 296 to exchange heat between the hot fluid and the contactor 280 and the adsorbent material 272 during any or all operating modes (e.g., adsorption mode, desorption mode, and / or cooling mode). In some embodiments, the fluid circulation loop 294 may include an independent fluid circulation loop for each contactor assembly in the contactor assembly 278, such that the thermal control system 290 can independently control the temperature of each contactor assembly in the contactor assembly 278 according to the operating modes (e.g., adsorption mode, desorption mode, and / or cooling mode) of the adsorbent-based gas capture units 252A, 252B, and 252C. For example, the thermal control system 290 is configured to circulate the hot fluid (e.g., circulate a coolant or cooling fluid at a relatively low temperature) during adsorption and cooling modes, thereby cooling the contactor 280 and the adsorbent material 272. For example, the thermal control system 290 is configured to circulate a hot fluid (e.g., circulate a heated fluid or heating fluid at a relatively high temperature) during desorption mode, thereby heating the contactor 280 and the adsorbent material 272 to facilitate desorption. As noted above, for example, during desorption mode, the hot fluid may include steam from the steam turbine system 14 and / or steam from the auxiliary boiler 24.

[0048] Adsorbent material 272 (e.g., a solid adsorbent) may cover, coat, or substantially line at least 50%, 60%, 70%, 80%, 90%, 95%, or 100% of the inner surface 274 of the outer conduit wall 262, the outer surface 276 of the contactor 280, and / or other structures within the conduit 254. In some embodiments, the contactor 280 may include a rectangular plate, an airfoil-shaped panel, parallel-arranged tubes, mesh-arranged tubes, multiple cylinders, radial protrusions, baffles, fins, honeycomb structures, bundled supported multiple contactor elements, or any combination thereof. The multiple contactor elements may include multiple particles, beads, strips, bundles, meshes, or other distributed structures that leave voids for fluid flow. Additionally or alternatively, adsorbent material 272 may at least partially fill or plug the internal volume of the central hole or inner surface 274, such that voids are retained to facilitate fluid flow (e.g., a porosity of less than or equal to 10%, 20%, 30%, 40%, or 50%). Furthermore, in some embodiments, the central axis 266 extending from the inlet 268 to the outlet 270 can define the flow path 264 as a linear flow path, a tortuous flow path, a winding or serpentine flow path, a spiral or helical flow path, a meandering flow path, an expanding and contracting flow path, a flow path with splitting and / or merging, or any combination thereof. For example, the flow path 264 can be defined as a tortuous flow path and include any number or configuration of the aforementioned flow paths.

[0049] Adsorbent material 272 may include one or more adsorbent materials configured to adsorb undesirable gases, such as those designed or suitable for adsorbing carbon oxides (CO). x Such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NO) x ), sulfur oxides (SO x Adsorbent materials such as sulfur dioxide (SO2), methane (CH4), or any other undesirable gases or greenhouse gases restricted and / or considered by regulations as described herein. For example, adsorbent material 272 may comprise porous solid-phase materials, including mesoporous silica, zeolites (e.g., aluminosilicates), and metal-organic frameworks (MOFs) and covalent organic frameworks (COFs). The aforementioned adsorbent material 272 may be particularly suitable for CO2 adsorption in adsorbent-based gas capture units 252. However, any suitable adsorbent material 272 may be used, depending on the desired objective of capturing the undesirable gas. In some embodiments, multiple adsorbent-based gas capture systems 250 may be used in series, wherein each of the adsorbent-based gas capture systems 250 uses the same or different adsorbent material 272 to stage the removal and capture of the same or different undesirable gases.

[0050] The adsorbent-based gas capture system 250 can be configured to use a controller 220 and a sensor 222 to alternate between an adsorption mode (e.g., adsorbing unwanted gas into the adsorbent material 272), a desorption mode (e.g., desorbing unwanted gas from the adsorbent material 272), and a cooling mode (e.g., cooling the adsorbent material 272) for each of the adsorbent-based gas capture units 252A, 252B, and 252C associated with conduits 256, 258, and 260. The controller 220 is configured to control the adsorbent-based gas capture system 250 to perform interleaved operating cycles of the adsorbent-based gas capture units 252A, 252B, and 252C between different operating modes (e.g., adsorption mode, desorption mode, and cooling mode). For example, for a first duration, controller 220 may operate adsorbent-based gas capture unit 252A in adsorption mode, adsorbent-based gas capture unit 252B in desorption mode, and adsorbent-based gas capture unit 252C in cooling mode. As a further example, for a second duration, controller 220 may operate adsorbent-based gas capture unit 252A in desorption mode, adsorbent-based gas capture unit 252B in cooling mode, and adsorbent-based gas capture unit 252C in adsorption mode. As a further example, for a third duration, controller 220 may operate adsorbent-based gas capture unit 252A in cooling mode, adsorbent-based gas capture unit 252B in adsorption mode, and adsorbent-based gas capture unit 252C in desorption mode. The adsorbent-based gas capture system 250 can also be configured to simultaneously operate multiple units (e.g., two, three, four, or more) of the adsorbent-based gas capture unit 252 in each operating mode, such as multiple units 252 in adsorption mode, multiple units 252 in desorption mode, and multiple units 252 in cooling mode. The multiple units 252 can be arranged in series, in parallel, or in a combination thereof. The controller 220 is configured to alternate between adsorption mode, desorption mode, and cooling mode via multiple support systems.

[0051] The support system may include a 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 a gas inlet system), a heating fluid supply system 316 (e.g., a heated gas and / or heated liquid supply system), and a cooling fluid supply system 318, while the downstream flow distribution system 312 includes an adsorption post-treatment system 320 (e.g., after adsorption mode), a desorption post-treatment system 322 (e.g., a fluid processing system after desorption mode), and a cooling post-treatment system 324 (e.g., after cooling mode).

[0052] The gas supply system 314 of the upstream flow distribution system 310 is configured to supply gas 340 (e.g., intake gas 60 or exhaust gas 152, 184) to achieve adsorption mode when each of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) is selectively operated in adsorption mode via controller 220. The gas supply system 314 includes a gas pretreatment system 330 having one or more gas pretreatment components 332, 334, and 336, which can be configured to process, adjust, and / or control the characteristics of the gas 340 upstream of the conduits 254 (e.g., 256, 258, and 260) of the adsorbent-based gas capture units 252 (e.g., units 252A, 252B, and 252C). For example, gas pretreatment component 332 may include thermal control components (e.g., gas temperature control components), such as heat exchangers, heaters, coolers, or any combination thereof, configured to regulate (e.g., increase or decrease) the temperature of gas 340. The heat exchanger may exchange heat with steam, water, exhaust gas, compressor vents, waste heat, or some other hot fluid. In some embodiments, a waste heat recovery system may be used for heat transfer in the heat exchanger. Gas pretreatment component 334 may include pressure control components, such as pressure regulators, expanders or expansion chambers, contractors or contraction chambers, energy-increasing fans or pumps, energy-extracting turbines, or other suitable pressure controllers. Gas pretreatment component 336 may include one or more contaminant removal units, such as particulate filters, moisture removal units or dryers, chemical removal units, and / or other removal units configured to clean gas 340. For example, gas pretreatment component 336 may include a humidity controller configured to maintain a desired relative humidity of gas 340 received in the adsorbent-based gas capture system 250.

[0053] The gas supply system 314 may also include one or more valves 342 configured to control the distribution of gas 340 to multiple conduits 254 (e.g., 256, 258, and 260) of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 344, 346, and 348. For example, valves 342 may include one or more multi-way valves and / or distribution manifolds to independently distribute gas 340 to the respective adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 344, 346, and / or 348 when operating in adsorption mode in response to a control signal from controller 220.

[0054] The heating fluid supply system 316 of the upstream flow distribution system 310 is configured to supply heating fluid to enable desorption mode when each of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) is selectively operated in desorption mode via controller 220. As discussed further in detail below, the heating fluid supply system 316 may also cooperate with the vacuum system of the desorption post-processor 442. The heating fluid supply system 316 includes one or more heating fluid supply devices 350, such as one or more steam supply devices, hot water supply devices, heated gas supply devices, and / or waste heat supply devices. The heating fluid may also be described as a purge fluid, such as purge gas or purge steam. For example, the heating fluid supply device 350 may include a steam turbine system 14, an HRSG 16, a waste heat recovery system 22 (e.g., recovering heat from a compressor, pump, generator, reactor, or other power plant equipment), an auxiliary boiler 24 (e.g., directly or indirectly via the steam turbine system 14), or any combination thereof. In some embodiments, WHR 22 utilizes waste heat recovered from exhaust gases 152, 184 and provides a heated fluid 26 for use as a heating fluid 354. The heated fluid 26 (e.g., a waste heat recovery fluid) can also be described as excess heat or waste heat recovered for use in the heating fluid supply system 316 of the adsorbent-based gas capture unit 252. The heating fluid supply device 350 can be configured to supply heating fluid 352 (e.g., steam and / or heated water) and / or heating fluid 354 (e.g., a waste heat recovery fluid such as heated fluid 26) to the heating fluid control 356 of the heating fluid supply system 316. In some embodiments, the heating fluid 352 (e.g., heated fluid 26) may include heated liquids and / or heated gases, such as heated CO2, air, an inert gas such as nitrogen, water, oil, or any combination thereof.

[0055] Heating fluid control unit 356 includes one or more heating fluid control components 358, 360, and 362, which can be configured to process, adjust, and / or control the characteristics of heating fluid 352 and / or heating fluid 354 upstream of conduits 254 (e.g., 256, 258, and 260) of adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C). For example, heating fluid control component 358 may include thermal control components (e.g., temperature control components), such as heat exchangers, heaters, coolers, or any combination thereof, configured to regulate (e.g., increase or decrease) the temperature of heating fluid 352 and / or heating fluid 354. Heat exchangers can exchange heat with steam, water, lubricants, coolants, refrigerants, or some other hot fluid. In some embodiments, a waste heat recovery system can be used for heat transfer in the heat exchanger. The heating fluid control unit 360 may include pressure control components, such as a pressure regulator, expander or expansion chamber, contractor or contraction chamber, energy-increasing fan or pump, energy-extracting turbine, or other suitable pressure controller. The heating fluid control unit 362 may include pretreatment components, such as particulate filters, cold water discharge devices, and / or other pretreatment components configured to alter the properties of heating fluids 352 and / or 354 or remove contaminants.

[0056] The heating fluid supply system 316 may also include one or more valves 364 configured to control the distribution of heating fluid 352 (e.g., steam and / or heated water) and / or heating fluid 354 (e.g., waste heat recovery fluid) to multiple conduits 254 (e.g., 256, 258, and 260) of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 366, 368, and 370. For example, valve 364 may include one or more multi-way valves and / or distribution manifolds to independently distribute heating fluid 352 and / or heating fluid 354 to the respective adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 366, 368, and 370 when operating in desorption mode in response to a control signal from controller 220.

[0057] The cooling fluid supply system 318 of the upstream flow distribution system 310 is configured to supply cooling fluid to achieve a cooling mode when each of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) is selectively operated in a cooling mode via a controller 220. The cooling fluid supply system 318 includes one or more cooling fluid supply devices 372, such as one or more water supply devices, cooled air supply devices, cooled inert gas (e.g., nitrogen) supply devices, cooled CO2 supply devices, or any combination thereof. The cooling fluid supply devices 372 may be configured to supply coolant or cooling fluid 374 (e.g., liquid or gaseous coolant) to the cooling fluid control element 376 of the cooling fluid supply system 318.

[0058] Cooling fluid control component 376 includes one or more cooling fluid control components 378, 380, and 382, ​​which can be configured to process, adjust, and / or control the characteristics of cooling fluid 374 upstream of conduits 254 (e.g., 256, 258, and 260) of adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C). For example, cooling fluid control component 378 may include thermal control components (e.g., temperature control components), such as heat exchangers, heaters, coolers, or any combination thereof, configured to regulate (e.g., increase or decrease) the temperature of cooling fluid 374. Heat exchangers may exchange heat with steam, water, lubricants, coolants, refrigerants, or some other hot fluid. Cooling fluid control component 380 may include pressure control components, such as pressure regulators, expanders or expansion chambers, contractors or contraction chambers, energy-increasing fans or pumps, energy-extracting turbines, or other suitable pressure controllers. The cooling fluid control unit 382 may include pretreatment components, such as particulate filters and / or other pretreatment components configured to change the properties of the cooling fluid 374 or remove contaminants.

[0059] The cooling fluid supply system 318 may also include one or more valves 384 configured to control the distribution of cooling fluid 374 (e.g., liquid or gaseous coolant) to multiple conduits 254 (e.g., 256, 258, and 260) of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 386, 388, and 390. For example, valve 384 may include one or more multi-way valves and / or distribution manifolds to independently distribute cooling fluid 374 to the respective adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) via distribution conduits 386, 388, and 390 when operating in cooling mode in response to a control signal from controller 220.

[0060] In the illustrated embodiment, controller 220 is configured to control upstream flow distribution system 310 to alternately distribute the flow rates of gas 340 during adsorption mode, heating fluid 352 and / or heating fluid 354 during desorption mode, and cooling fluid 374 during cooling mode to different adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) having adsorbent material 272. In adsorption mode, gas 340 (e.g., intake gas 60 or exhaust gas 152, 184) flows through the conduit 254 of the selected adsorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) and contacts the adsorbent material 272 disposed on the inner surface 274 of the outer conduit wall 262 and / or the outer surface 276 of the contactor 280, such that the adsorbent material 272 adsorbs unwanted gases (e.g., CO2) from gas 340. In some embodiments, the thermal control system 290 may circulate coolant through the heat exchanger 296 to provide cooling to the contactor 280 and the adsorbent material 272 during adsorption mode. The thermal control system 290 may also facilitate heat transfer to the coolant via multiple heat pipes 298 of the heat exchanger 296. The adsorbent-based gas capture unit 252 then discharges the treated gas 400 (e.g., lean or substantially free of unwanted gases) to the adsorption post-treatment system 320.

[0061] In desorption mode, heating fluid 352 and / or heating fluid 354 flow through conduit 254 of a selected adsorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) and contact adsorbent material 272 disposed on the inner surface 274 of the outer conduit wall 262 and / or the outer surface 276 of the contactor 280, thereby heating the adsorbent material 272 to facilitate the desorption of unwanted gases (e.g., CO2) from the adsorbent material 272. In some embodiments, the desorption mode may be configured to indirectly heat the adsorbent material 272 via a heating circuit (e.g., a heating conduit) extending through the adsorbent-based gas capture unit 252. For example, thermal control system 290 may circulate heating fluid (e.g., heating fluid 352 and / or heating fluid 354) through heat exchanger 296 to provide heating of contactor 280 and adsorbent material 272. As noted above, heating fluid 354 may include heated fluid 26 from WHR 22, and heating fluid 352 may include steam from steam turbine system 14 and / or (e.g., auxiliary boiler 24 supporting steam turbine system 14). Thermal control system 290 may also facilitate heat transfer from the heating fluid across contactor 280 via multiple heat pipes 298 of heat exchanger 296. Adsorbent-based gas capture unit 252 then discharges a fluid stream 402 comprising unwanted gas, heating fluid 352, and / or heating fluid 354 for further processing by desorption post-treatment system 322.

[0062] In cooling mode, cooling fluid 374 flows through conduit 254 of a selected adsorbent-based gas trapping unit 252 (e.g., 252A, 252B, or 252C) and contacts adsorbent material 272 disposed on the inner surface 274 of the outer conduit wall 262 and / or the outer surface 276 of the contactor 280, thereby cooling the adsorbent material 272 and the contactor 280. In some embodiments, the cooling mode may be configured to indirectly cool the adsorbent material 272 and the contactor 280 via a cooling circuit (e.g., a cooling conduit) extending through the adsorbent-based gas trapping unit 252. For example, thermal control system 290 may circulate cooling fluid through heat exchanger 296 to provide cooling to the contactor 280 and the adsorbent material 272. Thermal control system 290 may also facilitate the transfer of heat from the contactor 280 and the adsorbent material 272 via a plurality of heat pipes 298 of heat exchanger 296. The cooling mode is configured to cool and regenerate the adsorbent material 272 prior to the subsequent adsorption mode. The adsorbent-based gas capture unit 252 then discharges a fluid stream 404 (e.g., cooling fluid 374) for processing by the cooled system 324.

[0063] In some embodiments, the adsorbent-based gas capture system 250 includes a movable adsorbent system configured to continuously or periodically move adsorbent material 272 between adsorption, desorption, and cooling modes. For example, the adsorbent-based gas capture system 250 may include a rotary contactor assembly or wheel (e.g., a rotary contactor having adsorbent material 272) configured to rotate from adsorption, desorption, and cooling, thereby providing a continuous flow of captured undesirable gas. For example, the wheel (e.g., a rotary contactor having adsorbent material 272) may extend into each of a plurality of conduits 254 and rotate continuously through the conduits 254. During wheel rotation, one or more conduits in conduit 254 flow the gas 340 to be treated to remove unwanted gases, while simultaneously flowing heating fluid 352 and / or heating fluid 354 to remove and capture unwanted gases (e.g., CO2), thereby generating captured gas 204. Simultaneously, one or more conduits in conduit 254 also flow cooling fluid 374 to regenerate adsorbent material 272. For desorption, heating fluid 352 and / or heating fluid 354 may be delivered or generally configured to provide direct and / or indirect heat transfer to adsorbent material 272, thereby aiding in the separation and capture of unwanted gases.

[0064] In an illustrated embodiment, controller 220 is configured to control downstream flow distribution system 312 to alternately distribute flows from each adsorbent-based gas capture unit 252 (e.g., 252A, 252B, and 252C), thereby delivering treated gas 400 to adsorption post-treatment system 320 during adsorption mode, delivering fluid flow 402 (e.g., unwanted gas, heating fluid 352, and / or heating fluid 354) to desorption post-treatment system 322 during desorption mode, and delivering fluid flow 404 (e.g., cooling fluid 374) to cooling post-treatment system 324 during cooling mode. In some embodiments, downstream flow distribution system 312 includes one or more valves 410 fluidly coupled to adsorbent-based gas capture unit 252A, one or more valves 412 fluidly coupled to adsorbent-based gas capture unit 252B, and one or more valves 414 fluidly coupled to adsorbent-based gas capture unit 252C. Valve 410 may include one or more multi-way valves and / or distribution manifolds connected to distribution conduits 416, 418, and 420, which are respectively connected to the adsorption post-treatment system 320, the desorption post-treatment system 322, and the cooling post-treatment system 324. Valve 412 may include one or more multi-way valves and / or distribution manifolds connected to distribution conduits 422, 424, and 426, which are respectively connected to the adsorption post-treatment system 320, the desorption post-treatment system 322, and the cooling post-treatment system 324. Valve 414 may include one or more multi-way valves and / or distribution manifolds connected to distribution conduits 428, 430, and 432, which are respectively connected to the adsorption post-treatment system 320, the desorption post-treatment system 322, and the cooling post-treatment system 324. In operation, controller 220 is configured to control valves 410, 412 and 414 to independently control the flow rates from the adsorbent-based gas capture unit 252 (e.g. 252A, 252B and 252C) to the adsorption post-treatment system 320 in adsorption mode, to the desorption post-treatment system 322 in desorption mode and to the cooling post-treatment system 324 in cooling mode.

[0065] The adsorption post-treatment system 320 includes a treated gas treatment system 440, which may include an exhaust chimney, an auxiliary gas treatment system, or any other suitable post-treatment equipment. In some embodiments, the adsorption post-treatment system 320 may recycle all or part of the treated gas 400 to the EGR system 150, as referenced above. Figure 1 The subject of discussion.

[0066] The desorption post-treatment system 322 may include a desorption post-processor 442 having one or more desorption post-treatment components 444, 446, and 448. In some embodiments, the fluid flow 402 directed to the desorption post-processor 442 is a result of a desorption mode in which heated fluid 352 (e.g., steam and / or heated water) and / or heated fluid 354 (e.g., waste heat recovery fluid such as heated fluid 26) are directed through conduits 254 of the adsorbent-based gas capture unit 252 (e.g., 252A, 252B, or 252C) to desorb unwanted gases (e.g., CO2) from the adsorbent material 272. Therefore, one or more desorption post-treatment components 444, 446, and 448 (e.g., steam, heated water, and / or other fluid processing components) may be configured to process, adjust, and / or control the characteristics of fluid flow 402 (e.g., steam, heated water, and / or other fluid flow) from conduits 254 (e.g., 256, 258, and 260) of the adsorbent-based gas capture unit 252 (e.g., 252A, 252B, and 252C). For example, desorption post-treatment component 444 may include a captured gas / heated fluid separator configured to separate heated fluid 352 (e.g., steam and / or heated water) and / or heated fluid 354 from the captured gas, thereby outputting fluid 450 (e.g., water condensate or other separated fluid) and captured gas 204. Examples of captured gas / heated fluid separators include thermal control components, pressure control components, chemical separation components, or combinations thereof. For example, the captured gas / heated fluid separator may be configured to use a condenser to condense or cool the heated fluid 352 (e.g., steam). The desorption post-treatment component 446 may include one or more removal units configured to remove contaminants from the fluid 450 and / or captured gas 204. For the fluid 450, the removal unit may include a particulate filter and / or a water treatment unit. For the captured gas 204, the removal unit may include a particulate filter, a water removal unit, a dryer, or an additional gas treatment unit. The desorption post-treatment 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 desorption post-treatment component 448 may also include a vacuum system with one or more vacuum pumps configured to draw the captured gas / heated fluid stream from the adsorbent-based gas capture unit 252. In other words, the vacuum pumps are configured to create a low-pressure environment to aid in drawing the captured gas / heated fluid stream from the adsorbent-based gas capture unit 252.

[0067] The cooling system 324 may include a cooling fluid recirculation system 452 configured to recirculate fluid flow 404 back to the cooling fluid supply system 318 as 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, cooling system, and flow control valve. The cooling system may include a heat exchanger configured to transfer heat from fluid flow 404, thereby cooling the fluid flow for reuse as cooling fluid 374. In some embodiments, heat obtainable from fluid flow 404 may be recovered in one or more heat exchangers to heat heating fluid 352 and / or heating fluid 354 of heating fluid supply system 316, thereby reducing total heating energy requirements. Excess low-level heat from fluid flow 404 may then be discharged into the environment.

[0068] Controller 220 is configured to receive feedback from sensor 222 to adjust various operating parameters and change the operating mode (e.g., adsorption mode, desorption mode, and cooling mode) of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C). For example, controller 220 may be configured to alternate the flow (e.g., gas 340, heating fluid 352, and / or heating fluid 354 and cooling fluid 374) through multiple conduits 254 (e.g., 256, 258, and 260), such that the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C) can alternate between adsorption mode, desorption mode, and cooling mode. In adsorption mode, conduit 254 receives the flow of gas 340, adsorbs unwanted gases (e.g., CO2) from gas 340 into adsorbent material 272, and outputs treated gas 400 with reduced content or concentration level of unwanted gases. The adsorption of unwanted gases into the adsorbent material 272 is an exothermic process that generates heat. A thermal control system 290, including a heat exchanger 296 and a heat pipe 298, helps regulate the temperature of the adsorbent material 272 during adsorption mode, thereby maintaining or improving the adsorption efficiency of the adsorbent material 272. In desorption mode, the conduit 254 receives a flow of heated fluid 352 (e.g., steam and / or heated water) and / or heated fluid 354, desorbing unwanted gases (e.g., CO2) from the adsorbent material 272 into the heated fluid 352 and / or heated fluid 354, and outputs a fluid flow 402 containing the desorbed unwanted gases (e.g., heated fluid 352 and / or heated fluid 354 rich in unwanted gases such as CO2). The desorption of unwanted gases from the adsorbent material 272 is an endothermic process, and the heated fluid 352 and / or heated fluid 354 provides sufficient heat (e.g., directly or indirectly) to drive the desorption of unwanted gases (e.g., CO2) from the adsorbent material 272. In cooling mode, conduit 254 receives a flow of cooling fluid 374 (e.g., gaseous or liquid coolant), thereby cooling adsorbent material 272 and contactor 280.

[0069] Controller 220 is configured to monitor sensors 222, such as sensors 222 located at or upstream of inlet 268 and sensors 222 located at or downstream of outlet 270, to assess the rates of adsorption, desorption, and cooling, the concentration levels of unwanted gases, and other characteristics affecting the operating modes of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C). If sensors 222 indicate a need to alternate the operating modes (e.g., adsorption, desorption, and cooling modes) of the adsorbent-based gas capture units 252 (e.g., 252A, 252B, and 252C), controller 220 may be configured to control valves 342, 364, 384, 410, 412, and 414 to change the flow rate through conduit 254 to support the desired operating mode. Sensor 222 can also monitor the temperature of adsorbent material 272 and adjust thermal control system 290 according to the operating mode to provide heating or cooling (e.g., cooling during adsorption and cooling mode and heating during desorption mode).

[0070] For gas 340 treated in one of the conduits 254 in adsorption mode, controller 220 may be configured to control gas pretreatment system 330 to control the characteristics of gas 340 (e.g., temperature, pressure, flow rate, etc.). Similarly, controller 220 is configured to control treated gas treatment system 440 to control the treatment of treated gas 400 discharged from one or more conduits in conduits 254. For heated fluid 352 (e.g., steam and / or heated water) and / or heated fluid 354 (e.g., waste heat recovery fluid such as heated fluid 26) supporting desorption mode in one of the conduits 254, controller 220 may be configured to control HRSG 16, steam turbine system 14, WHR system 22, auxiliary boiler 24, heated fluid control element 356, or any combination thereof to control the characteristics of heated fluid 352 and / or heated fluid 354 (e.g., temperature, pressure, flow rate, steam content, water content, etc.). Similarly, controller 220 is configured to control desorption post-processor 442 to control the treatment of fluid flow 402 (including undesirable gases desorbed during desorption mode) exiting from one or more conduits in conduit 254. For cooling fluid 374 supporting a cooling mode in one of conduits 254, controller 220 may be configured to control cooling fluid control element 376 and / or cooling fluid recirculation system 452 to control the characteristics of cooling fluid 374 (e.g., temperature, pressure, flow rate, etc.). Similarly, controller 220 is configured to control cooling fluid recirculation system 452 to control the treatment of fluid flow 404 (e.g., cooling fluid 374) exiting from one or more conduits in conduit 254.

[0071] Figure 3 yes Figure 1A schematic diagram of an embodiment of a combined cycle system 10 illustrates an embodiment of a gas capture system 20 having a gas handling system 18 with a solvent-based gas capture system 500 using steam from an integrated steam turbine system 14 and an auxiliary boiler 24. The solvent-based gas capture system 500 may use one or more solvents to capture undesirable gases. Example solvents include monoethanolamine (MEA), diethylene glycolamine (DGA), higher amine solvents, amino acid salts, carbonate solvents, ammonia, immiscible liquids, and ionic liquids. As discussed below, the solvent-based gas capture system 500 uses one or more heated fluids 502 from the steam turbine system 14, HRSG 16, WHR 22, and / or (e.g., the auxiliary boiler 24 supporting the steam turbine system 14). For example, the heated fluid 502 may include steam and / or heated water from the steam turbine system 14, HRSG 16, and / or (e.g., the auxiliary boiler 24 supporting the steam turbine system 14). By further example, the heated fluid 502 may include heated gas and / or heated liquid from WHR 22.

[0072] The gas turbine system 12, steam turbine system 14, HRSG 16, and auxiliary boiler 24 are substantially the same as those discussed in detail above. Specifically, the illustrated HRSG 16 includes a first pressure section 160 (e.g., a high-pressure (HP) section), a second pressure section 162 (e.g., an intermediate-pressure (IP) section), and a third pressure section 164 (e.g., a low-pressure (LP) section), wherein each of sections 160, 162, and 164 includes one or more heat exchangers and / or heat exchange components. In some embodiments, the gas capture system 20 (e.g., a solvent-based gas capture system 500) may be configured to deliver a 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., the solvent-based gas capture system 500), wherein the steam may be high-pressure steam, medium-pressure steam, and / or low-pressure steam extracted from one or more sections of the HRSG 16 (e.g., 160, 162, 164), one of the steam turbines 172, 174, and / or 176 of the steam turbine system 14 supported by the auxiliary boiler 24, and / or high-pressure steam, medium-pressure steam, and / or low-pressure steam extracted by the auxiliary boiler 24. However, in some embodiments, the gas capture system 20 (e.g., the 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 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, where steam is supplied solely to the steam turbine system 14 by the auxiliary boiler 24. Thus, the auxiliary boiler 24 may be configured to serve as steam support for the steam turbine system 14 in various operating modes (e.g., full-load and partial-load operating modes), such that the steam turbine system 14 can then supply steam to the gas capture system 20 (e.g., solvent-based gas capture system 500).

[0073] The solvent-based gas capture system 500 includes an absorber 504 (e.g., an absorber tower), a stripper 506 (e.g., a stripper column), a gas circuit 508 (e.g., a gas treatment circuit), a solvent circuit 510 (e.g., a fluid absorbent circuit), and one or more heated fluid circuits 512. Each of the gas circuit 508, solvent circuit 510, and heated fluid circuit 512 includes one or more fluid conduits or lines, fluid manifolds, fluid separators, fluid combiners, fluid mixing chambers, fluid valves, internal fluid paths through components, or any combination thereof. In operation, the gas circuit 508 is configured to deliver exhaust gases 152, 184 (or any other gas flow with undesired gases) through the absorber 504, while the solvent circuit 556 is configured to deliver solvent flows through the absorber 504 and the stripper 506. Gas circuit 508 includes a gas path 514 extending toward absorber 504 between absorber 504 and WHR system 22 and / or HRSG16, a gas path 516 extending upward through absorber 504, and a gas path 518 extending away from absorber 504. Solvent circuit 510 extends in a loop through absorber 504 and stripper 506, including a solvent path 520 extending downward through absorber 504, a solvent path 522 extending from absorber 504 to stripper 506, a solvent path 524 extending downward through stripper 506, and a solvent path 526 extending from stripper 506 to absorber 504. Heated fluid circuit 512 extends between stripper 506 and one or more heated fluid sources 528 to support operation of stripper 506 using heated fluid 502. The heated fluid loop 512 may be configured to extract the heated fluid 502 at pressures and temperatures suitable for transferring heat to the stripper 506, thereby reducing or eliminating the need for a separate heat source for the stripper 506. In some embodiments, the heated fluid loop 512 may be configured to supply high-pressure steam, medium-pressure steam, and / or low-pressure steam as a heated fluid source 528 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. In an illustrated embodiment, the heated fluid source 528 may also include a WHR 22 as a source and / or waste heat source for the heated fluid 502 to support steam generation in the auxiliary boiler 24. However, in some embodiments, the heated fluid 502 may be supplied solely by the steam turbine system 14, which receives steam from and / or directly from the auxiliary boiler 24.

[0074] The heated fluid loop 512 may include any number and configuration 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 loop 512 may be fluidly and mechanically coupled to the heated fluid source 528 at one or more heated fluid extraction locations 530 (e.g., extraction ports or connections) at the auxiliary boiler 24, WHR system 22, steam turbine system 14, and HRSG 16. In some embodiments, 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 HRSG 16, such as at sections (e.g., 160, 162, 164) and steam turbines 172, 174, and 176, upstream, downstream, and / or at locations 530 between these sections and the steam turbines. Additionally, the heated fluid circuit 512 may be fluidly and mechanically coupled to the stripper 506 at one or more heated fluid injection locations 532 (e.g., injection ports or connections). In the illustrated embodiments, the heated fluid injection locations 532 may be located 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 heated fluid circuits in the heated fluid circuit 512 with any combination of heated fluid extraction locations 530 and heated fluid injection locations 532. The heated fluid circuit 512 may be a separate circuit (e.g., a separate heated fluid path or conduit) or an interconnected circuit (e.g., a fluidly coupled heated fluid path or conduit) with one or more common conduits, wherein the heated fluid circuit 512 may include one or more valves 534 coupled to the controller 220 for selectively controlling the flow of heated fluid to the stripper 506.

[0075] In the illustrated embodiment, the heated fluid circuit 512 includes one or more heated fluid circuits 512 between the heated fluid source 528 and the stripper 506. The one or more heated fluid circuits 512 are fluidly and mechanically coupled to the heated fluid source 528 at one or more heated fluid extraction locations 530, and fluidly and mechanically coupled to the stripper 506 at one or more heated fluid injection locations 532 (e.g., 540, 542, 544, and 546). In some embodiments, the heated fluid circuit 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 with valves 535 between the auxiliary boiler 24 and the high-pressure steam turbine 172 and the medium-pressure steam turbine 174. Additionally, in some embodiments, the heated fluid circuit 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 with valves 537 between the stripper 506 and the intermediate-pressure steam turbine 174, the low-pressure turbine 176, or between turbines 174 and 176. Circuit 538 may extend to a manifold 539, which is then coupled to valve 534 for controlled distribution to the stripper 506. Additionally, in some embodiments, the heated fluid circuit 512 may include one or more heated water and / or steam circuits extending between the stripper 506 and one or more sections of the HRSG 16 (e.g., 160, 162, 164), one or more heated water and / or steam circuits extending between the stripper 506 and the auxiliary boiler 24, or any combination thereof. In some embodiments, the heated fluid extraction location 530 may include multiple different locations, and the heated fluid injection locations 532 (e.g., 540, 542, 544, and 546) may include multiple different locations. However, the heated fluid loop 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. In some embodiments, each heated fluid loop in the heated fluid loop 512 may be selectively coupled 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 control elements. The heated fluid circuit 512 is configured to supply heated fluid 502 to the stripper 506 at temperature, pressure, and flow rate controlled at least in part by valves 534, 535, and 537 (e.g., via controller 220 and feedback control from sensor 222). Additional details regarding the heated fluid circuit 512 and the supply of heated fluid to the stripper 506 will be discussed below.

[0076] Absorber 504 includes multiple absorber sections 560 disposed within a container or housing 562, wherein housing 562 includes a gas inlet 564, a gas outlet 566, a solvent inlet 568, and a solvent outlet 570. Housing 562 has a top portion 572, a bottom portion 574, and an intermediate portion 576 axially disposed between the top portion 572 and the bottom portion 574 relative to a central axis 578 of housing 562. Top portion 572 includes a top plate or cover 580 having a gas outlet 566 coaxial with the central axis 578. However, gas outlet 566 may be disposed off-center from the central axis 578 or at other locations along top portion 572. Intermediate portion 576 includes sidewalls 582 extending about the central axis 578. For example, sidewall 582 may be an annular sidewall, square sidewall, rectangular sidewall, or any other suitable shape extending about the central axis 578. In some embodiments, gas outlet 566 may be disposed in sidewall 582 along top portion 572. Additionally, a solvent inlet 568 may be disposed in the top portion 572 along a top plate or cover 580 or a sidewall 582. A bottom portion 574 may include a substrate 584 located below the gas inlet 564 and the solvent outlet 570. In an illustrated embodiment, the gas inlet 564 and the solvent outlet 570 are disposed along the bottom portion 574 in the sidewall 582. However, in some embodiments, the gas inlet 564 and / or the solvent outlet 570 may be disposed in the substrate 584 within the bottom portion 574. In some embodiments, the gas inlet 564 may include multiple gas inlets and / or the solvent outlet 570 may include multiple solvent outlets.

[0077] The plurality of absorber sections 560 within the internal volume 586 of the housing 562 may include any number and type of absorber sections 560, such as absorber sections 588, 590, 592, 594, 596, and 598. These absorber sections may include packing material, support trays or screens, wire mesh, solvent dispensers, or any combination thereof in any configuration. For example, each packing material may include a plurality of beads, balls, or mixture-inducing structures configured to facilitate mixing between the gas flow and the solvent flow in absorber 504. Each support tray or screen may include wire mesh, a plate with multiple openings, or another suitable structure that holds the packing material in place while allowing fluid flows of gas and solvent to pass through the support tray or screen in opposite directions through absorber 504. Each solvent dispenser may include a plurality of solvent nozzles configured to dispense solvent across internal volume 586. In some embodiments, absorber sections 588, 592, 596, and 598 include wire mesh, while absorber sections 590 and 594 include packing material, support trays or screens, and solvent dispensers. However, absorber sections 560 (e.g., 588, 590, 592, 594, 596, and 598) are not limited to the illustrated configurations.

[0078] In operation, absorber 504 is configured to create cross-flow or counter-flow of gas 600 (e.g., exhaust gases 152, 184) along gas path 516 and lean solvent 602 along solvent path 520 within internal volume 586, thereby promoting the absorption of certain undesirable gases (e.g., CO2) from gas 600 into lean solvent 602. As shown, at bottom portion 574, gas 600 enters absorber 504 through gas inlet 564 and flows upward through internal volume 586 of absorber 504. Gas 600 entering absorber 504 through gas inlet 564 can form gas bubbles that rise upward through lean solvent 602 within internal volume 586. Gas 600 then passes through each subsequent absorber section 560 (e.g., 588, 590, 592, 594, 596, and 598).

[0079] At the intermediate section 576 (or top section 572), the solvent-based gas capture system 500 supplies lean gas solvent 602 into the internal volume 586 using one or more solvent dispensers (such as solvent distribution manifolds, solvent nozzles, or solvent injector grids). The solvent-based gas capture system 500 may supply lean gas solvent 602 directly at, above, and / or below absorber section 560 via the illustrated solvent inlet 568 or any number or arrangement of solvent inlets 568. The lean gas solvent 602 then flows downward through the internal volume 586 through each subsequent absorber section 560. As the lean gas solvent 602 passes through each absorber section 560, various mixing structures (e.g., packing, wire mesh, support trays, etc.) are configured to aid in mixing the lean gas solvent 602 with the gas 600, thereby facilitating the absorption of various undesirable gases from the gas 600 into the lean gas solvent 602. For example, the lean gas solvent 602 can be configured to absorb carbon dioxide (CO2) or other undesirable gases, as discussed in detail above. When the absorption process occurs, heat is generated within the absorber 504, thereby raising the temperature of the solvent within the absorber 504.

[0080] In some embodiments, a thermal control system 604 may be coupled to the absorber 504 to control the temperature and improve the efficiency of the absorption process. For example, 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., a cooler) and a pump 610. The pump 610 is configured to circulate the 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.

[0081] In some embodiments, absorber 504 further includes a water washing system 612 having a heat exchanger 614 (e.g., a cooler) and a pump 616 disposed along a water washing loop 618. In some embodiments, absorber sections 594, 596, and / or 598 may be configured to assist the water washing process of the water washing system 612, while absorber sections 588, 590, and 592 help enhance the mixing between gas 600 and lean gas solvent 602 to increase the absorption of unwanted gases. For example, absorber sections 594, 596, and / or 598 may be configured to help distribute water across absorber 504 in top portion 572 for removing any soluble solvents from gas 600 flowing upward through absorber 504. In some embodiments, the water washing system 612 may be eliminated or moved downstream of absorber 504.

[0082] Finally, absorber 504 discharges the gas-rich solvent 620 at the bottom portion 574 through solvent outlet 570, and the treated gas 622 at the top portion 572 through gas outlet 566. The treated gas 622 may be substantially free of or vaporize one or more undesirable gases (e.g., CO2). In contrast, the gas-rich solvent 620 may have absorbed one or more undesirable gases (e.g., CO2). Therefore, 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 specific gas absorption occurring in absorber 504). Similarly, gas 600 may be described as containing or being rich in CO2 (or containing or being rich in other gases, depending on the undesirable gas), while the treated gas 622 may be described as a CO2-reduced, lean, or non-containing gas (or other reduced, lean, or non-containing gas, depending on the undesirable gas and the specific gas absorption occurring in absorber 504). The gas absorption discussed herein is intended to cover any one or more undesirable gases or any other regulated gases or greenhouse gases described herein.

[0083] In some embodiments, gas circuit 508 may include one or more components upstream of absorber 504. For example, gas circuit 508 may include a gas cooler or gas cooling system, such as a direct contact cooler (DCC) 624, disposed upstream of absorber 504 along gas path 514. In some embodiments, WHR system 22 may be configured to generate heated fluid 502 while cooling exhaust gases 152, 184, such that the DCC 624 can be scaled down or eliminated in solvent-based gas capture system 500. If included in gas circuit 508, DCC 624 may include a cooling housing 626 housing wire mesh 628 and cooling fluid distributor 630, wherein cooling fluid distributor 630 includes a plurality of fluid nozzles 632. The DCC 624 may also include a cooling fluid circuit 634 having a pump 636 and a heat exchanger 638 (e.g., a cooler), wherein the cooling fluid circuit 634 is coupled above the wire mesh 628 to the cooling fluid distributor 630 and below the wire mesh 628 to the bottom portion of the housing 626. The pump 636 is configured to circulate 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 it to another working fluid. Multiple fluid nozzles 632 distribute the cooling fluid across the internal volume of the housing 626 (e.g., a cooling fluid dispersion), while the DCC 624 delivers a gas flow from a gas inlet 640 to a gas outlet 642, as indicated by arrow 644. Thus, the cooling fluid dispersion directly contacts and cools the gas flow (e.g., exhaust gases 152, 184). In some embodiments, the gas circuit 508 also includes one or more fans 646 configured to increase the pressure and / or flow rate of the gas stream (e.g., exhaust gases 152, 184) supplied to the absorber 504. However, as noted above, when combined with the WHR system 22, the DCC 624 can be eliminated or its scaled down, since the WHR system 22 serves a dual purpose as an exhaust gas cooler and heat source for the solvent-based gas capture system 500.

[0084] The solvent-based gas capture system 500 may further include multiple components of a solvent circuit 510 along the absorber 504 and stripper 506. In an illustrated embodiment, the solvent circuit 510 includes a pump 648, a heat exchanger 650, and a heat exchanger 704 along a solvent path 522 from the absorber 504 to the stripper 506, and the solvent circuit 510 includes a pump 652, a heat exchanger 650, a heat exchanger 654, and a filter 656 along a solvent path 526 from the stripper 506 to the absorber 504. The pump 648 is configured to pump a rich gas solvent 620 along the solvent path 522 through the heat exchangers 650 and 704 to the stripper 506, while the pump 652 is configured to pump a lean gas solvent 602 along the solvent path 526 through the heat exchanger 296 and the filter 656 to the absorber 504. Heat exchanger 650 is configured to transfer heat away from lean solvent 602 in solvent path 526 to rich solvent 620 in solvent path 522, thereby cooling lean solvent 602 and heating rich solvent 620. As discussed in further detail below, heat exchanger 704 is configured to transfer heat from heated fluid 502 in heated fluid circuit 702 to rich solvent 620 in solvent path 522, thereby heating rich solvent 620. Heat exchanger 654 is configured to cool lean solvent 602 by transferring heat away from lean solvent 602 to a coolant stream (e.g., water or other liquid coolant), thereby providing cooled lean solvent 602 for supply to absorber 504. Filter 656 is configured to filter and / or clean lean solvent 602 used in absorber 504. In some embodiments, solvent circuit 510 may include additional components (e.g., heat exchangers, filters, valves, etc.) and / or exclude one or more of the illustrated components. Stripper 506 is used to process gas-rich solvent 620, as discussed below.

[0085] Stripper 506 includes multiple stripper sections 658 disposed within a container or housing 660, wherein housing 660 includes a solvent inlet 662, a solvent outlet 664, and a gas outlet 666. Housing 660 has a top portion 668, a bottom portion 670, and an intermediate portion 672 axially disposed between the top portion 668 and the bottom portion 670 relative to a central axis 674 of housing 660. Top portion 668 includes a top plate or cover 676 having a gas outlet 666 coaxial with central axis 674. However, gas outlet 666 may be disposed off-center from central axis 674 or at other locations along top portion 668. Intermediate portion 672 includes sidewalls 678 extending about central axis 674. For example, sidewall 678 may be an annular sidewall, square sidewall, rectangular sidewall, or any other suitable shape extending about central axis 674. In some embodiments, gas outlet 666 may be disposed in sidewall 678 along top portion 668. Additionally, the solvent inlet 662 may be disposed along the top portion 668 or the middle portion 672. The bottom portion 670 may include a substrate 680 below the solvent outlet 664. In the illustrated embodiment, the solvent outlet 664 is disposed in the sidewall 678 along the bottom portion 670. However, in some embodiments, the solvent outlet 664 may be disposed in the substrate 680 within the bottom portion 670.

[0086] The plurality of stripper sections 658 within the internal volume 682 of the housing 660 may include any number and type of stripper sections 658, such as stripper sections 684, 686, 688, 690, and 692. These stripper sections may include packing, support trays or screens, wire mesh, solvent dispensers with nozzles, vapor dispensers with nozzles, or any combination thereof, in any configuration. For example, each packing may include a plurality of beads, balls, or mixture-inducing structures configured to facilitate mixing between a flow of solvent (e.g., rich gas solvent 620) and a flow of vapor 694 in the stripper 506. Each support tray or screen may include wire mesh, a plate with multiple openings, or another suitable structure that holds the packing in place while allowing fluid flow of solvent (e.g., rich gas solvent 620) and vapor 694 through the support tray or screen. Each solvent dispenser may include a plurality of solvent nozzles configured to dispense solvent across the internal volume 682. Each steam distributor may include multiple fluid nozzles configured to distribute steam 694 across an internal volume 682. In some embodiments, stripper sections 686, 688, and 692 include wire mesh, stripper section 684 includes packing and a support tray or screen, and stripper section 690 includes a baffle or partition plate with one or more openings. However, stripper sections 658 (e.g., 684, 686, 688, 690, and 692) are not limited to the illustrated configurations.

[0087] As discussed above, stripper 506 is configured to strip unwanted gases from gas-rich solvent 620 using heated fluid 502 supplied via heated fluid loop 512 from one or more of the following: WHR system 22, steam turbine system 14, HRSG 16, auxiliary boiler 24, another waste heat recovery system of combined cycle system 10, or combinations thereof. In the illustrated embodiment, heated fluid loop 512 is coupled to various heated fluid extraction locations 530 and heated fluid injection locations 532 (e.g., 540, 542, 544, and 546) to provide heat in the form of heated fluid 502 to support stripper 506. Each of these heated fluid loops 512 may be configured to transfer heat to the solvent in stripper 506 via direct heat transfer (e.g., direct injection into the solvent), indirect heat transfer (e.g., via a heat exchanger), or any combination thereof. Controller 220 is configured to selectively control (e.g., open and close) valve 534 to control the corresponding flow of heated fluid 502 through heated fluid circuit 512 to stripper 506. In an illustrated embodiment, heated fluid circuit 512 includes heated fluid circuits (or circuit portions) 696, 698, 700, and 702 coupled to corresponding heated fluid injection positions 532 (e.g., 540, 542, 544, and 546). For example, heated fluid circuits 512 (e.g., 698 and 700) are coupled to the intermediate portion 672 of housing 660 at corresponding heated fluid injection positions 532 (e.g., 542 and 544) located between stripper sections 686 and 688. However, heated fluid circuits 698 and 700 may be coupled to stripper 506 at any suitable heated fluid injection position 532, which may be the same or different between heated fluid circuits 698 and 700. For example, heated fluid injection locations 532 (e.g., 542 and 544) may be located directly above, below, or within one or more stripper sections of stripper section 658. Additionally, heated fluid injection locations 532 (e.g., 542 and 544) may include a fluid distributor having a plurality of fluid nozzles configured to distribute heated fluid 502 across the internal volume 682 of stripper 506.

[0088] In the illustrated embodiments, stripper 506 may be coupled to or include one or more additional components, such as thermal control system 706 and moisture removal system 708. Thermal control system 706 may be coupled to any part of stripper 506, such as at bottom portion 670. Thermal control system 706 may include solvent recirculation loop 710 with reboiler 712 configured to heat and boil solvent for recirculation into stripper 506. In the illustrated embodiments, reboiler 712 is coupled to at least one heated fluid loop (e.g., 696) in heated fluid loop 512 as a heat source for heating and boiling solvent, rather than relying on a separate or independent heat source. However, in some embodiments, reboiler 712 may include one or more additional heat sources for heating solvent, such as electric heaters, burners or furnaces, steam generators, or other heat sources. Additional heat sources may be used when steam is unavailable and / or insufficient to provide the desired heating in reboiler 712.

[0089] However, in the illustrated embodiment, the heated fluid loop 512 may be the primary heat source supporting the reboiler 712. For example, at least one heated fluid loop (e.g., 696) in the heated fluid loop 512 supplies heated fluid 502 to the reboiler 712 at an inlet 714 (e.g., 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 from the reboiler 712 to the heated fluid source 528 (e.g., steam turbine system 14, auxiliary boiler 24, and / or WHR system 22) via a return loop 718, wherein the return loop 718 may include a fluid handling unit (FTU) 720 configured to treat the heated fluid 502 before returning to the heated fluid source 528. For example, the FTU 720 may include a condenser, particulate filter, descaling unit, ultraviolet (UV) treatment unit, or any combination thereof configured to condense steam and / or other liquid vapors into condensate. In the illustrated embodiment, return loop 718 is coupled to pump 722, which is configured to pump heated fluid 502 back to heated fluid source 528. Although heated fluid loop 512 (e.g., 696) is coupled to reboiler 712, any one or more heated fluid loops in heated fluid loop 512 (e.g., 696, 698, 700, and 702) may be coupled to reboiler 712 to provide heated fluid 502 as a heat source for heating and boiling the solvent in stripper 506.

[0090] In some embodiments, at least one heated fluid loop (e.g., 702) in the heated fluid loop 512 supplies heated fluid 502 to a heated fluid injection position 544 at a heat exchanger 704 disposed along the solvent loop 510, thereby heating the rich gaseous solvent 620 between the absorber 504 and the stripper 506. For example, the heat exchanger 704 may be disposed between the heat exchanger 650 and the solvent inlet 662 leading into the stripper 506. In some embodiments, the heated fluid 502 may be injected directly into the rich gaseous solvent 620, such that the heated fluid 502 mixes with the rich gaseous solvent 602 and heat is directly transferred to the rich gaseous solvent. However, in some embodiments, the heat exchanger 704 provides indirect heat transfer between the heated fluid 502 and the rich gaseous solvent 602, and thus the heated fluid 502 may be recirculated back to the heated fluid source 528 along a return loop (e.g., return loop 718).

[0091] The moisture removal system 708 may include a condenser loop 724 having a condenser 726, wherein the condenser loop 724 is coupled to a gas outlet 666 and a return inlet 728. The condenser 726 is configured to cool and condense any vapors and solvent vapors present in the captured gas 204 discharged from the stripper 506, thereby outputting water or condensate 730, captured gas 204 substantially free of water content and solvent vapors, and solvent vapors for return to the stripper 506 via the return inlet 728. In some embodiments, the condenser 726 includes a heat exchanger (e.g., a 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 housing 660. However, the moisture removal system 708 may be located at any suitable location to condense any vapors and solvent vapors present in the captured gas 204. The captured gas 204 may also be compressed in a compression system 206 and delivered to a storage device and / or line 208 as discussed above.

[0092] In operation, controller 220 is configured to monitor sensor 222 and control the operation of solvent-based gas capture system 500 to support stripper 506 using heated fluid 502 supplied via heated fluid loop 512. For example, controller 220 may selectively control valve 534 to supply heated fluid 502 via one or more of the heated fluid loops 512 according to: the conditions of heated fluid 502, the temperature of the solvent in stripper 506, the temperature of the solvent in reboiler 712, the operating conditions of combined cycle system 10 (e.g., start-up mode, steady-state mode, shutdown mode, full-load mode, and / or partial-load mode), the percentage of unwanted gas in exhaust gases 152, 184, the flow rate of lean solvent 602, the flow rate of rich solvent 620, the flow rate of gas 600, or any combination thereof. During start-up, shutdown, and / or partial load modes, if the heated fluid 502 is unavailable or limited, controller 220 may be configured to control one or more additional heat sources (e.g., electric heaters, furnaces, etc.) to provide heat to support stripper 506. During steady-state mode, if the heated fluid 502 is available, controller 220 may be configured to control WHR system 22, auxiliary boiler 24, steam turbine system 14, HRSG 16, valve 534, or any combination thereof to supply heated fluid 502 to stripper 506. In some embodiments, controller 220 may be configured to control WHR system 22 and / or HRSG 16 (e.g., 160, 162, 164) to provide adequate cooling of exhaust gases 152, 184 to eliminate DCC 624 while providing heated fluid 502 to support stripper 506. In some embodiments, controller 220 may be configured to control the mixing of heated fluids 502 from various heated fluid extraction sites 530, thereby providing heated fluids 502 at desired temperatures and pressures to support stripper 506. However, solvent-based gas capture system 500 may be configured to selectively use heated fluids 502 from auxiliary boiler 24, WHR system 22, steam turbine system 14, HRSG 16, or any combination thereof in any manner. Depending on the heated fluid source 528 and the type of heat transfer (e.g., direct or indirect heat transfer), heated fluids 502 may include heated water, steam, solvents (e.g., the same solvents used in solvent-based gas capture system 500), or any combination thereof.

[0093] Figure 4 yes Figure 1 A block diagram of an embodiment of the combined cycle system 10 is provided, which further illustrates the integration of the auxiliary boiler 24 with the steam turbine system 14 and the gas handling system 18. The combined cycle system 10 is substantially the same as described above. Figure 1 The same as discussed in detail above. Furthermore, the gas handling system 18 may include, as referenced above. Figures 1 to 3 The gas capture system 20 is discussed in detail. Furthermore, the gas turbine system 12, steam turbine system 14, and heat recovery steam generator (HRSG) are essentially the same as those discussed above. Therefore, unless otherwise stated, references... Figures 1 to 3 The various components, functionalities, sensor feedback, control of controller 220, and various aspects of auxiliary boiler 24 (e.g., connections, functions, etc.) described in Figure 4 The implementation methods are the same.

[0094] In the illustrated embodiment, auxiliary boiler 24 is integrated as an additional steam source into combined cycle system 10 to support steam turbine system 14 under various operating modes of combined cycle system 10 (e.g., partial load and full load operating modes). As shown, auxiliary boiler 24 is configured to supply steam to steam turbine system 14 via steam circuit 750 and / or to gas processing system 18 (e.g., one or more gas capture systems 20) via steam supply circuit 752. Additionally, auxiliary boiler 24 is configured to deliver exhaust gas to gas processing system 18 (e.g., one or more gas capture systems 20) via exhaust gas circuit 754, which may be configured to connect exhaust gas circuit 756 between HRSG 16 and gas processing system 18. Thus, exhaust gases 152, 184 from gas turbine system 12 (i.e., through HRSG 16) and exhaust gases from auxiliary boiler 24 can be processed in gas processing system 18. Steam turbine system 14 is configured to supply steam to gas processing system 18 (e.g., one or more gas capture systems 20) via steam circuit 758, wherein steam circuits 752 and 758 may be coupled together and / or operated individually to and from gas processing system 18. Each of steam circuits 750, 752, and 758 includes one or more fluid conduits, valves, manifolds, flow separators, flow combiners, pressure regulators, flow meters, sensor 222, or any combination thereof. Additionally, exhaust gas 184 may be directed wholly or partially to auxiliary boiler 24, thereby partially or completely replacing the auxiliary boiler combustion air. In this way, CO2 concentration may increase and O2 concentration may decrease in exhaust gas circuit 756. Notably, due to the lower O2 concentration in the exhaust gas, this process can improve the performance of gas capture system 20 and reduce operating costs. Additional details of steam circuits 750, 752, and 758 are discussed in detail below.

[0095] The auxiliary boiler 24 includes a vessel 760 having a combustion section or burner 762 and a steam section or steam generator 764, wherein the burner 762 is configured to burn fuel with air to generate combustion gases, and the combustion gases transfer heat to water in the steam generator 764 to generate steam. In some embodiments, the auxiliary boiler 24 has a combustion heating source, an electric heating source, or a combination thereof. In some embodiments, the auxiliary boiler 24 is a variable pressure boiler configured to generate steam at different pressures, or the auxiliary boiler 24 is a constant pressure boiler configured to generate steam at a constant pressure. Therefore, in some embodiments, a controller 220 is coupled to the auxiliary boiler 24 and configured to control the burner 762 and the steam generator 764 to change the pressure, temperature, and other characteristics of the steam used in the steam turbine system 14 and the gas handling system 18 (e.g., one or more gas capture systems 20). For example, depending on the operating mode of the combined cycle system 10 (e.g., partial load or full load operating mode), the controller 220 may change (e.g., increase or decrease) the pressure, temperature, and other characteristics of the steam. In some embodiments, the steam generator 764 includes multiple different steam pressure sections, such as a low-pressure section, a medium-pressure section, and a high-pressure section for steam generation. Thus, in the case of multiple steam pressure sections, the steam generator 764 can be configured to supply steam with different steam pressures to different sections (e.g., 172, 174, and / or 176) of the steam turbine system 14.

[0096] In an illustrated embodiment, the steam circuit 750 between the auxiliary boiler 24 and the steam turbine system 14 may include a conduit 766 branching into conduits 768 and 770, wherein conduit 768 is connected to the high-pressure steam turbine 172 and conduit 770 is connected to the intermediate-pressure steam turbine 174. In some embodiments, the steam circuit 750 may further extend to the low-pressure steam turbine 176. For example, the steam circuit 750 may include a conduit 766 branching into three conduits: conduit 768, conduit 770, and an additional conduit connected to the low-pressure steam turbine 176. The steam circuit 750 may include one or more valves configured to control and separate the flow of steam to different steam turbine sections. In an illustrated embodiment, conduit 766 includes valve 772, and conduit 768 includes valve 774. Controller 220 is coupled to and configured to control valves 772 and 774, such that valve 772 is configured to control the overall flow of steam from auxiliary boiler 24 to steam turbine system 14, and valve 774 is configured to control the separation or ratio of steam flows to high-pressure steam turbine 172 and intermediate-pressure steam turbine 174. In some embodiments, each of ducts 766, 768, 770 and additional ducts includes a valve to facilitate steam flow to each of steam turbines 172, 174, and 176.

[0097] In some embodiments, controller 220 is configured to control auxiliary boiler 24 and valves 772 and 774 based on the operating mode of combined cycle system 10 (e.g., partial load or full load operating mode) and other parameters (e.g., steam demand of steam turbine system 14, steam demand of gas handling system 18, electrical power demand, etc.). For example, in some embodiments, controller 220 is configured to control auxiliary boiler 24 and valves 772 and 774 to supply steam only to high-pressure steam turbine 172, only to intermediate-pressure steam turbine 174, or to mix or separate the flow to both high-pressure steam turbine 172 and intermediate-pressure steam turbine 174. In some embodiments, controller 220 is configured to control auxiliary boiler 24 and valves 772 and 774 to supply steam to intermediate-pressure steam turbine 174 during full-load operating mode of combined cycle system 10, and to supply steam to both high-pressure steam turbine 172 and intermediate-pressure steam turbine 174 during partial-load operating mode of combined cycle system 10. For example, during full-load operation, auxiliary boiler 24 may supply steam to intermediate-pressure steam turbine 174 to increase steam turbine output by at least 2.5% to 5% and improve efficiency by at least 0.2%. Additionally, during partial-load operation, controller 220 may be configured to control auxiliary boiler 24 to change steam characteristics (e.g., pressure, temperature, etc.), and control valves 772 and 774 to control (e.g., increase or decrease) the overall steam supply and steam separation between high-pressure steam turbine 172 and intermediate-pressure steam turbine 174. In some embodiments, during partial-load operation, controller 220 may continuously or incrementally change (e.g., increase or decrease) the overall steam supply based on steam demand, and / or maintain the overall steam supply within a range (e.g., upper and lower thresholds) from auxiliary boiler 24 to high-pressure steam turbine 172 and intermediate-pressure steam turbine 174. Additionally, in some embodiments, during partial load operation, the controller 220 may continuously or incrementally change (e.g., increase or decrease) the separation based on steam demand, and / or maintain the separation within a range from the auxiliary boiler 24 to the high-pressure steam turbine 172 and the medium-pressure steam turbine 174 (e.g., upper and lower thresholds for separation).

[0098] Steam turbine system 14 is configured to supply steam to gas handling system 18 via steam circuit 758, which may include conduit 776 connected to intermediate-pressure steam turbine 174, conduit 778 connected to conduit 779 extending between intermediate-pressure steam turbine 174 and low-pressure steam turbine 176, and conduit 780 connected to low-pressure steam turbine 176. Conduits 776, 778, and 780 may also include corresponding valves 782, 784, and 786 connected to and controlled by controller 220. Conduits 776, 778, and 780 may extend individually to gas handling system 18, and / or conduits 776, 778, and 780 may be combined to form conduit 788 extending to gas handling system 18. Steam circuit 758 may also include conduit 790 as a return (e.g., condensate return) from gas handling system 18 to steam turbine system 14, such as a return line 181 connected from low-pressure steam turbine 176 to HRSG 16.

[0099] In some embodiments, controller 220 is configured to control auxiliary boiler 24, steam turbine system 14, and valves 782, 784, and 786 based on the operating mode of combined cycle system 10 (e.g., partial load or full load operating mode) and other parameters (e.g., steam demand of steam turbine system 14, steam demand of gas handling system 18, electrical power demand, etc.). For example, in some embodiments, controller 220 is configured to control conduits 776, 778, and 780 to extract steam (e.g., medium-pressure steam) only from medium-pressure steam turbine 174 via conduit 776 for supply to gas handling system 18, to extract steam only from conduit 779 between steam turbines 174 and 176 via conduit 778 for supply to gas handling system 18, to extract steam only from low-pressure steam turbine 176 via conduit 780 for supply to gas handling system 18, or any combination thereof. For example, in some embodiments, controller 220 is configured to control the ratio of steam flow (e.g., steam at different pressures) from one or more of the conduits 776, 778, and 780 through steam circuit 758 to gas processing system 18 via conduits 776, 778, 780, and 788. In some embodiments, controller 220 is configured to control conduits 776, 778, and 780 based on sensor feedback (e.g., temperature, pressure, etc.) from sensors 222 along conduits 776, 778, 779, 780, and / or 788, such that steam within a desired range of properties (e.g., temperature range, pressure range, etc.) can be supplied to gas processing system 18 for use in one or more gas capture systems 18.

[0100] In some embodiments, the auxiliary boiler 24 may be configured to supply steam to the gas handling system 18 independently and / or in combination with steam supplied by the steam turbine system 14. In an exemplary embodiment, steam circuits 752 and 758 are coupled together such that conduit 792 of steam circuit 752 is coupled to and supplies steam to conduit 788 of steam circuit 758, and conduit 794 of steam circuit 752 is coupled to and receives condensate from conduit 790 of steam circuit 758. For example, the combined steam supply may be provided to the gas handling system 18 via conduit 792 coupled to the auxiliary boiler 24 and conduit 788 coupled to the steam turbine system 14. By further example, condensate from the gas handling system 18 may be returned to the HRSG 16 via conduit 790, returned to the auxiliary boiler 24 via conduits 790 and 794, or a combination thereof. In some embodiments, valve 796 may be provided along conduit 792 to control the separation of steam supply from auxiliary boiler 24 to gas handling system 18 and / or from auxiliary boiler 24 and steam turbine system 14 to gas handling system 18. Similarly, in some embodiments, valve 798 may be provided along conduit 794 to control condensate return from gas handling system 18 to auxiliary boiler 24 and / or from gas handling system 18 to auxiliary boiler 24 and HRSG 16.

[0101] In some embodiments, HRSG 16 may be configured to supply steam to the gas processing system 18 independently and / or in combination with steam supplied to the gas processing system 18 by the steam turbine system 14 and / or in combination with steam supplied to the gas processing system 18 by the auxiliary boiler 24. For example, HRSG 16 may be configured to supply low-pressure steam, medium-pressure steam, and / or high-pressure steam to the gas processing system 18, as illustrated by steam circuits 800, 802, and 804, respectively. For example, steam circuits 800, 802, and 804 may be coupled to, for example,... Figure 1 The HRSG 16 example includes HP segment 160, IP segment 162, and LP segment 164.

[0102] The efficiency, output, and / or energy requirements of HRSG 16, steam turbine system 14, and / or gas handling system 18 can determine where and how much steam to extract. Additionally or alternatively, such as Figure 4 As shown, excess water and / or condensate from the steam turbine system 14 and / or gas handling system 18 can be returned to the auxiliary boiler 24. Furthermore, as previously mentioned, the controller 220 can be configured to control the HRSG 16, steam turbine system 14, WHR system 22, auxiliary boiler 24, or any combination thereof to control the characteristics of the steam supplied to the gas handling system 18 (e.g., temperature, pressure, flow rate, steam content, water content, etc.).

[0103] Additionally or alternatively, the auxiliary boiler 24 may be configured for integration with the EGR system 150. In this embodiment, exhaust gas 184 from the HRSG 16 may be sent to the EGR system 150, the auxiliary boiler 24, or both as a diluent for combustion in the burner 762 of the auxiliary boiler 24. In this way, unfavorable gases such as CO2 sent to the gas capture system 20 may have increased concentrations, thereby improving the efficiency of the gas capture system 20. Furthermore, the integration of the auxiliary boiler 24 with the EGR system 150 may reduce the concentration of fuel gases such as O2 sent to the gas handling system 18 and / or the gas capture system 20, thereby improving the efficiency of the EGR system 150. Additionally, in this embodiment, the auxiliary boiler 24 may be designed to generate a steam flow that can be easily integrated into the steam turbine system 14 in terms of temperature and pressure levels, thereby avoiding the need for supplemental steam using the HRSG. It should be noted that supplemental ignition of the HRSG may require increased air and / or limit the exhaust gas recirculation percentage during operation due to oxygen consumption. Therefore, auxiliary boilers are particularly useful for retrofitting power plants with supplemental ignition via HRSG, in conjunction with EGR system 150.

[0104] The disclosed embodiments provide a flexible steam supply to the gas handling system 18, which uses steam as a heat source to facilitate gas capture processes (e.g., desorption from adsorbent materials, stripping from solvents, etc.) performed by one or more gas capture systems 20. This flexible steam supply integrates an auxiliary boiler 24 with the steam turbine system 14, wherein the auxiliary boiler 24 supplies steam directly to the gas handling system 18 and / or supplies steam to the gas handling system 18 when supporting the steam turbine system 14. In some embodiments, the steam turbine system 14 may receive a primary steam supply from the HRSG 16 and a secondary steam supply from the auxiliary boiler 24 during normal operating conditions (e.g., full-load operating mode). During partial-load operating modes, the auxiliary boiler 24 helps support the steam turbine system 14 when the steam from the HRSG 16 may not meet the steam demand of the steam turbine system 14 and / or the gas handling system 18. The auxiliary boiler 24 can alter steam properties (e.g., pressure, temperature, etc.) and steam delivery to one or more steam sections (e.g., high-pressure steam turbine 172, medium-pressure steam turbine 174, and / or low-pressure steam turbine 176) to support the steam turbine system 14. Additionally, the steam turbine system 14 can alter steam properties (e.g., pressure, temperature, etc.) and steam delivery to the gas handling system 18 by changing the extraction points from the steam turbine system 18 (e.g., via conduits 779 connecting to the medium-pressure steam turbine 174, between the medium-pressure steam turbine 174 and the low-pressure steam turbine 176, and conduits 776, 778, and 780 of the low-pressure steam turbine 176). For at least these reasons, 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 handling system 14.

[0105] As illustrated below, the subject matter described in the detailed description above may be defined by one or more clauses.

[0106] A system includes a heat recovery steam generator (HRSG) configured to use heat from exhaust gas to generate a first steam. 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 also includes a gas capture system configured to capture unwanted gases from the exhaust gas. The gas capture system is configured to receive the second steam from the auxiliary boiler, and, when the steam turbine system receives the second steam from the auxiliary boiler, to receive a third steam, or a combination thereof.

[0107] According to the system described in the foregoing clauses, the steam turbine system is configured to receive the first steam from the HRSG and the second steam from the auxiliary boiler.

[0108] According to any of the foregoing provisions, the gas capture system is configured to receive the third steam from the steam turbine system when the steam turbine system receives the second steam from the auxiliary boiler.

[0109] According to any of the foregoing provisions, the gas capture system is configured to receive the second steam from the auxiliary boiler.

[0110] According to any of the foregoing provisions, the steam turbine system is configured to receive the second steam from the auxiliary boiler at a high-pressure steam turbine, a medium-pressure steam turbine, a low-pressure steam turbine, or a combination thereof.

[0111] According to any of the foregoing provisions, the steam turbine system is configured to receive the second steam from the auxiliary boiler at the intermediate-pressure steam turbine during a full-load operation mode of the combined cycle system having the gas turbine system, the HRSG, and the steam turbine system, wherein the steam turbine system is configured to receive the second steam from the auxiliary boiler at both the high-pressure steam turbine and the intermediate-pressure steam turbine during a partial-load operation mode of the combined cycle system.

[0112] According to any of the foregoing provisions, the gas capture system is configured to receive the third steam from the steam turbine system at a medium-pressure steam turbine, a low-pressure steam turbine, or a duct extending between the medium-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

[0113] According to any of the foregoing provisions, the gas capture system is configured to receive the second steam from the auxiliary boiler via a first steam circuit, receive the third steam from the steam turbine system via a second steam circuit, and the first steam circuit and the second steam circuit are connected to each other.

[0114] In any of the foregoing provisions, the auxiliary boiler in the system includes a variable pressure auxiliary boiler.

[0115] According to any of the foregoing clauses, the auxiliary boiler includes a combustion section and a steam generation section having multiple different steam pressure sections.

[0116] According to any of the foregoing provisions, the auxiliary boiler and the HRSG each supply exhaust gas to the gas capture system.

[0117] The system according to any of the foregoing clauses, wherein the gas capture system includes a carbon capture system, and the undesired gas includes carbon dioxide (CO2).

[0118] The system according to any of the foregoing clauses, wherein the gas capture system includes an adsorbent-based gas capture system, a solvent-based gas capture system, or any combination thereof.

[0119] According to any of the foregoing provisions, 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 supply the second steam to the steam turbine system, the gas capture system, or a combination thereof at one or more steam pressures, and the steam turbine system is configured to supply the third steam to the gas capture system at one or more steam pressures.

[0120] The system according to any of the foregoing provisions further includes a controller having a processor, a memory, and instructions stored in the memory and executable by the processor to control the steam supply to the steam turbine system and the steam supply to the gas capture system.

[0121] A system includes a controller having a processor, a memory, and instructions stored in the memory and executable by the processor to control the supply of first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from exhaust gas to generate the first steam. The controller is further configured to control the supply of 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 unwanted gases from the exhaust gas. The controller is further configured to control the supply of a third steam from the steam turbine system to the gas capture system when the steam turbine system receives the second steam from the auxiliary boiler.

[0122] The system according to the foregoing clauses further includes the gas capture system, wherein the gas capture system includes a carbon capture system, and the undesired gas includes carbon dioxide (CO2).

[0123] According to any of the foregoing provisions of the system, wherein the 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. The controller is further configured to control the supply of the third steam from the intermediate-pressure steam turbine, a low-pressure steam turbine, or a duct extending between the intermediate-pressure steam turbine and the low-pressure steam turbine, or a combination thereof, from the steam turbine system to the gas capture system.

[0124] A method includes supplying first steam from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from exhaust gas to generate the first steam. The method further includes supplying 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 unwanted gases from the exhaust gas. The method further includes supplying a third steam from the steam turbine system to the gas capture system when the steam turbine system receives the second steam from the auxiliary boiler.

[0125] The method according to the foregoing provisions further includes: 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 also 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 a duct extending between the intermediate-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

[0126] The method described in accordance with the foregoing clauses includes supplying the exhaust gas from the heat recovery steam generator (HRSG) to the auxiliary boiler.

[0127] According to the method described in the foregoing clauses, the auxiliary boiler provides supplemental steam in place of the HRSG as needed by the steam turbine system.

[0128] This written description uses examples to disclose the invention, including the best mode, and also enables any person skilled in the art to practice the invention, including making and using any device or system and performing any combined methods. The patentable scope of the invention is defined by the claims and may include other examples that will occur to those skilled in the art. Such other examples are contemplated within the scope of the claims if they have structural elements that are not different from the literal language of the claims, or if they include equivalent structural elements that are not substantially different from the literal language of the claims.

Claims

1. A system comprising: A heat recovery steam generator (HRSG) is configured to use heat from exhaust gas to generate first steam; An auxiliary boiler, configured to generate a second steam; A steam turbine system configured to receive the first steam, the second steam, or a combination thereof; A gas capture system configured to capture unwanted gases from exhaust gas, wherein the gas capture system is configured to receive second steam from the auxiliary boiler, receive third steam from the steam turbine system when the steam turbine system receives the second steam from the auxiliary boiler, or a combination thereof.

2. The system of claim 1, wherein the steam turbine system is configured to receive the first steam from the HRSG and the second steam from the auxiliary boiler.

3. The system of claim 2, wherein the gas capture system is configured to receive the third steam from the steam turbine system when the steam turbine system receives the second steam from the auxiliary boiler.

4. The system of claim 3, wherein the gas capture system is configured to receive the second steam from the auxiliary boiler.

5. The system of claim 1, wherein the steam turbine system is configured to receive the second steam from the auxiliary boiler at a high-pressure steam turbine, a medium-pressure steam turbine, a low-pressure steam turbine, or a combination thereof.

6. The system of claim 5, wherein the steam turbine system is configured to receive the second steam from the auxiliary boiler at the intermediate-pressure steam turbine during a full-load operation mode of the combined cycle system having the gas turbine system, the HRSG, and the steam turbine system, wherein the steam turbine system is configured to receive the second steam from the auxiliary boiler at both the high-pressure steam turbine and the intermediate-pressure steam turbine during a partial-load operation mode of the combined cycle system.

7. The system of claim 1, wherein the gas capture system is configured to receive the third steam from the steam turbine system at a medium-pressure steam turbine, a low-pressure steam turbine, or a duct extending between the medium-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

8. The system of claim 1, wherein the gas capture system is configured to receive the second steam from the auxiliary boiler via a first steam circuit, receive the third steam from the steam turbine system via a second steam circuit, and the first steam circuit and the second steam circuit are connected to each other.

9. The system according to claim 1, wherein the auxiliary boiler comprises a variable pressure auxiliary boiler.

10. The system according to claim 1, wherein the auxiliary boiler includes a combustion section and a steam generation section having multiple different steam pressure sections.

11. The system of claim 1, wherein the auxiliary boiler and the HRSG each supply exhaust gas to the gas capture system.

12. The system of claim 1, wherein the gas capture system comprises a carbon capture system, and the undesirable gas comprises carbon dioxide (CO2).

13. The system of claim 1, wherein the gas capture system comprises an adsorbent-based gas capture system, a solvent-based gas capture system, or any combination thereof.

14. The system of claim 1, wherein 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, wherein the auxiliary boiler is configured to supply the second steam to the steam turbine system, the gas capture system, or a combination thereof at one or more steam pressures, wherein the steam turbine system is configured to supply the third steam to the gas capture system at one or more steam pressures.

15. The system of claim 1, the system comprising a controller having a processor, a memory, and instructions, the instructions being stored in the memory and executable by the processor to control the steam supply to the steam turbine system and the steam supply to the gas capture system.

16. A system comprising: The controller has a processor, memory, and instructions, the instructions being stored in the memory and executable by the processor to control: The first steam is supplied from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from the exhaust gas to generate the first steam; A second steam supply from the auxiliary boiler to the steam turbine system and / or gas capture system, wherein the gas capture system is configured to capture unwanted gases from the exhaust gas; and When the steam turbine system receives the second steam from the auxiliary boiler, a third steam is supplied from the steam turbine system to the gas capture system.

17. The system of claim 16, wherein the system includes the gas capture system, wherein the gas capture system includes a carbon capture system, and the undesirable gas includes carbon dioxide (CO2).

18. The system of claim 16, wherein the controller is further configured to control: The second steam is supplied from the auxiliary boiler to the steam turbine system at a high-pressure steam turbine, a medium-pressure steam turbine, or a combination thereof; and The third steam is supplied from the steam turbine system to the gas capture system from the intermediate-pressure steam turbine, the low-pressure steam turbine, or a duct extending between the intermediate-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

19. A method comprising: The first steam is supplied from a heat recovery steam generator (HRSG) to a steam turbine system, wherein the HRSG uses heat from the exhaust gas to generate the first steam; A second steam source is supplied from the auxiliary boiler to the steam turbine system and / or the gas capture system, wherein the gas capture system is configured to capture unwanted gases from the exhaust gas; and When the steam turbine system receives the second steam from the auxiliary boiler, a third steam is supplied from the steam turbine system to the gas capture system.

20. The method of claim 19, wherein the method comprises: The second steam is supplied from the auxiliary boiler to the steam turbine system at a high-pressure steam turbine, a medium-pressure steam turbine, or a combination thereof; as well as The third steam is supplied from the steam turbine system to the gas capture system from the intermediate-pressure steam turbine, the low-pressure steam turbine, or a duct extending between the intermediate-pressure steam turbine and the low-pressure steam turbine, or a combination thereof.

21. The method of claim 19, wherein the method comprises: The exhaust gas is supplied from the heat recovery steam generator (HRSG) to the auxiliary boiler.

22. The method of claim 19, wherein the auxiliary boiler provides supplemental steam in place of the HRSG as needed by the steam turbine system.

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