Systems and methods for multistage carbon capture

Abstract

A system includes a gas treatment system having first and second gas capture systems and a steam supply loop. The first gas capture system is configured to capture a first portion of the bad gas from the combined cycle power plant. The second gas capture system is configured to capture a second portion of the bad gas from the combined cycle power plant, where the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant. The steam supply circuit includes a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply circuit is configured to be coupled to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of a combined cycle power plant.

Description

Background Art

[0001] The present application generally relates to systems and methods for treating gases, such as exhaust gases.

[0002] Industrial plants, such as power plants, may produce a variety of gases, such as 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 such as carbon dioxide (CO 2 ) and carbon monoxide (CO), nitrogen oxides such as nitrogen dioxide (NO 2 ), and / or sulfur oxides such as sulfur dioxide (SO 2 ). 2 It is both an acid gas and a greenhouse gas. Unfortunately, for thousands of years, CO 2 Levels have generally increased and currently exceed about 420 parts per million by volume (ppmv) or about 643 parts per million by weight (ppmw) in the atmosphere. With the advent of environmental concerns and various regulations regarding global warming, it is desirable to reduce the release of undesirable gases (e.g., CO 2 ) into the atmosphere, particularly for equipment that consumes hydrocarbon fuels (such as combustion systems). Summary of the invention

[0003] Certain embodiments comparable in scope to the originally claimed subject matter are summarized below. These embodiments are not intended to limit the scope of the claimed embodiments, but rather, these embodiments are intended only to provide a brief overview of possible forms of the subject matter. In fact, the presently claimed embodiments may include various forms that may be similar or different from the embodiments set forth below.

[0004] In certain embodiments, a system includes a gas processing system having first and second gas capture systems and a steam supply loop. The first gas capture system is configured to capture a first portion of bad gases from a combined cycle power plant. The second gas capture system is configured to capture a second portion of bad gases from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant. The steam supply loop includes a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

[0005] In certain embodiments, a system includes a controller configured to control a first gas capture system of a gas processing system to capture a first portion of bad gas from a combined cycle power plant. The controller is configured to control a second gas capture system of the gas processing system to capture a second portion of bad gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant. The controller is configured to control the supply of steam to the first and second gas capture systems via a steam supply loop having a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

[0006] In certain embodiments, a method includes controlling a first gas capture system of a gas processing system to capture a first portion of bad gas from a combined cycle power plant. The method also includes controlling a second gas capture system of the gas processing system to capture a second portion of bad gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series relative to a fluid flow path through the combined cycle power plant. The method also includes controlling the supply of steam to the first and second gas capture systems via a steam supply loop, the steam supply loop having a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant. BRIEF DESCRIPTION OF THE DRAWINGS

[0007] These and other features, aspects and advantages of the presently disclosed technology will be better understood when the following detailed description is read with reference to the accompanying drawings, in which like characters refer to like parts throughout the several views, and in which:

[0008] Figure 1 is a schematic diagram of an embodiment of a combined cycle power plant having a gas turbine system, a heat recovery steam generator (HRSG), a steam turbine system, and a multi-stage gas processing system having a plurality of gas treatment systems configured to capture undesirable gases (e.g., CO 2 )'s multiple gas capture systems.

[0009] Figure 2 yes Figure 1 A schematic diagram of an embodiment of a gas capture system of a multi-stage gas processing system is shown, illustrating a sorbent-based gas capture system.

[0010] Figure 3 yes Figure 1Schematic diagram of an embodiment of a gas capture system of a multi-stage gas processing system, showing a solvent based gas capture system. DETAILED DESCRIPTION

[0011] One or more specific embodiments of the presently disclosed system are described below. In order to provide a concise description of these embodiments, not all features of an actual implementation may be described in the specification. It should be understood that in the development of any such actual implementation, as in any engineering or design project, many implementation-specific decisions must be made to achieve the developer's specific goals, such as complying with system-related and business-related constraints, which may vary from implementation to implementation. In addition, it should be understood that such development work may be complex and time-consuming, but it is still a routine task of design, fabrication, and manufacturing for ordinary technicians who benefit from this disclosure.

[0012] When introducing elements of various embodiments of the presently disclosed embodiments, the articles "a," "an," "the," and "said" are intended to mean that there are one or more of the elements. The terms "comprising," "including," and "having" are intended to be inclusive and mean that there may be additional elements other than the listed elements.

[0013] The disclosed embodiments include gas processing systems and methods for reducing the carbon footprint of a combustion system, such as a combined cycle power plant, such that the carbon footprint is at least carbon neutral or carbon negative. Carbon neutrality is net zero CO 2 Emission status, among which CO in exhaust gas 2 The amount is equal to the CO in the process inlet air 2 Carbon negativity is a net negative CO 2 Emission status, among which CO in exhaust gas 2 The amount is less than the CO emitted into the atmosphere through the process 2 Although the CO 2 Although the disclosed embodiments are illustrated and described in the context of removing undesirable gases, the disclosed embodiments may be used to remove any undesirable gases, including but not limited to carbon oxides (e.g., CO 2 , CO), nitrogen oxides (e.g., NO 2 ), sulfur oxides (e.g., SO 2 ) and various other acid gases and / or greenhouse gases. As described below, the combustion system may be associated with a combined cycle power plant, a simple cycle gas turbine engine, a reciprocating piston-cylinder engine, a furnace, a boiler, or other industrial equipment. A combined cycle power plant may include a gas turbine engine that drives a generator, a heat recovery steam generator (HRSG) that uses heat from the exhaust of the gas turbine engine to generate steam, and a steam turbine that is driven by the steam to drive the generator.

[0014] In view of the foregoing, the disclosed embodiments include a plurality of gas processing stages configured to remove undesirable gases (e.g., CO 2 ) to help achieve net neutral emissions or net negative emissions. The multiple gas processing stages may include one or more gas processing systems disposed upstream of the compressor and / or combustor, one or more gas processing systems disposed downstream of the gas turbine and / or HRSG, or a combination thereof. The gas processing system may include an adsorbent-based gas processing system, a solvent-based gas processing system, or a combination thereof. For example, an adsorbent-based gas processing system is configured to adsorb undesirable gases into an adsorbent material and then subsequently desorb the undesirable gases from the adsorbent material using a heat source (e.g., steam from the HRSG). The adsorption process is exothermic, while the desorption process is endothermic. By further example, a solvent-based gas processing system may include: an absorber configured to absorb the undesirable gases into a solvent; and a regenerator configured to strip the undesirable gases from the solvent using steam (e.g., steam from the HRSG). Thus, in both types of gas processing systems, steam from the HRSG may be used to promote the desorption of undesirable gases (e.g., CO 2 Additionally or alternatively, in one or both types of gas processing systems, one or more types of waste heat recovery can be used to remove and capture undesirable gases (e.g., CO 2 ) heat source. For example, the gas processing system can use waste heat recovered from cooling one or more generators, waste heat recovered from cooling (or intercooling) compressed gas from one or more compressors, waste heat recovered from cooling other equipment in the combined cycle power plant, or a combination thereof. Various aspects and embodiments of the gas processing system are discussed in further detail below.

[0015] Figure 1 1 is a schematic diagram of an embodiment of a combined cycle power plant 10 having a gas turbine system 12, a heat recovery steam generator (HRSG) 14, a steam turbine system 16, and a multi-stage gas treatment system (GTS) 18. As discussed in further detail below, the multi-stage gas treatment system 18 is configured to treat one or more intake gases and / or exhaust gases in the combined cycle power plant 10. Various features and various stages of the gas treatment system 18 are discussed in further detail below, and the various features and various stages may be used in any suitable combination with each other. However, before turning to the gas treatment system 18, the combined cycle power plant 10 will be described as one possible scenario for using the gas treatment system 18.

[0016] The gas turbine system 12 cycle is often referred to as a "topping cycle," while the steam turbine system 16 cycle is often referred to as a "bottoming cycle." Figure 1As shown, by combining the two cycles, the combined cycle power plant 10 can produce higher efficiencies in both cycles. In particular, waste heat from the topping cycle can be captured and used to generate steam in the HRSG 14 for use in the bottoming cycle. However, the HRSG 14 can be configured to generate and supply steam for other uses in the combined cycle power plant 10 (including the gas processing system 18). For example, the gas processing system 18 can be configured to use the steam generated in the HRSG 14 to facilitate the separation and capture of undesirable gases, such as carbon capture (e.g., CO 2 ) in an adsorbent-based gas processing system and / or a solvent-based gas processing system. 2 capture).

[0017] As shown, the gas turbine system 12 includes an air intake section 20, a compressor section 22, a combustor section 24, a turbine section 26, and a load 28 (such as a generator). The air intake section 20 may include one or more air filters, an anti-icing system, a fluid injection system (e.g., a temperature control fluid), a muffler baffle, or any combination thereof. The compressor section 22 includes a plurality of compressor stages 30, each of which has a plurality of rotating compressor blades 32 coupled to a compressor shaft 38 and a plurality of fixed compressor guide vanes 34 coupled to a compressor housing 36. The combustor section 24 includes one or more combustors 40. The shaft 42 extends between the compressor section 22 and the turbine section 26. Each combustor 40 includes one or more fuel nozzles 44 coupled to one or more fuel suppliers 46, which may supply fuel through a primary fuel circuit and a secondary fuel circuit. The fuel supplier 46 may supply any combination of natural gas, syngas, biofuel, fuel oil, or liquid fuel and gas fuel. Turbine section 26 includes a plurality of turbine stages 56 each having a plurality of rotating turbine blades 48 coupled to a turbine shaft 54 ​​and a plurality of stationary turbine vanes 50 coupled to a turbine casing 52. Turbine shaft 54 ​​is also connected to load 28 via shaft 58.

[0018] In operation, the gas turbine system 12 passes an air intake flow 60 from the air intake section 20 into the compressor section 22. The compressor section 22 progressively compresses the air intake flow 60 in the stage 30 and delivers the compressed air flow 62 to one or more combustors 40. The one or more combustors 40 receive fuel from the fuel supply 46, pass the fuel through the fuel nozzles 44, and combust the fuel with the compressed air flow 62 to generate hot combustion gases in a combustion chamber 64 within the combustor 40. The one or more combustors 40 then pass the hot combustion gas flow 66 into the turbine section 26. The turbine section 26 progressively expands the hot combustion gas flow 66 and drives the turbine blades 48 in the stage 56 to rotate before discharging the exhaust gas flow 68. As the hot combustion gas flow 66 drives the turbine blades 48 to rotate, the turbine blades 48 drive the turbine shaft 54, the shafts 42 and 58, and the compressor shaft 38 to rotate. Thus, the turbine section 26 drives the compressor section 22 and the load 28 to rotate. The exhaust gas flow 68 may be partially or completely directed to flow through the HRSG 14 to achieve heat recovery and steam generation. In certain embodiments, one or more additional gas turbine engines 12 may be included as part of the combined cycle power plant 10, wherein the additional gas turbine engines 12 may discharge the exhaust gas flow 68 to the HRSG 14. Thus, the collective exhaust gas flow 68 from the gas turbine engines 14 (e.g., 1, 2, 3, 4, or more) may pass through the HRSG 14 to generate steam for the steam turbine system 16, and the exhaust gas flow 68 is then processed by the gas processing system 18.

[0019] The HRSG 14 may include a plurality of heat exchangers and / or heat exchange components 70 disposed in different sections, such as a high pressure (HP) section 72, an intermediate pressure (IP) section 74, and a low pressure (LP) section 76. The components 70 may include economizers, evaporators, superheaters, or any combination thereof in each of the HP section 72, the IP section 74, and the LP section 76. The components 70 may be coupled together via various conduits and headers, and the HRSG 14 may transmit one or more steam (e.g., low pressure steam, intermediate pressure steam, and high pressure steam) streams to the steam turbine system 16. In the illustrated embodiment, the components 70 of the HRSG 14 include a final high pressure superheater 78, a secondary reheater 80, a primary reheater 82, a primary high pressure superheater 84, an interstage attemperator 86, an interstage attemperator 88, a high pressure evaporator 90 (HP EVAP), a high pressure economizer 92 (HP ECON), an intermediate pressure evaporator 94 (IP EVAP), an intermediate pressure economizer 96 (IP ECON), a low pressure evaporator 98 (LP EVAP), and a low pressure economizer 100 (LP ECON). The HRSG 14 also includes a housing or duct 102 that houses the various components 70. The functionality of the components 70 is discussed in further detail below.

[0020] The steam turbine system 16 includes a steam turbine 104 having a high pressure steam turbine (HP ST) 106, an intermediate pressure steam turbine (IP ST) 108, and a low pressure steam turbine (LP ST) 110 coupled together via shafts 112 and 114. In addition, the steam turbine 104 may be coupled to a load 116 via a shaft 118. Similar to the load 28, the load 116 may include an electrical generator. The HRSG 14 may be configured to generate high pressure steam for the high pressure steam turbine 106, intermediate pressure steam for the intermediate pressure steam turbine 108, and low pressure steam for the low pressure steam turbine 110. In certain embodiments, exhaust gas from the high pressure steam turbine 106 may be transmitted to the intermediate pressure steam turbine 108 via the primary reheater 82, the interstage attemperator 88, and the secondary reheater 80 within the HRSG 14, and exhaust gas from the intermediate pressure steam turbine 108 may be transmitted to the low pressure steam turbine 110. The steam turbine 104 may discharge the condensate 120 (or the steam may be condensed in a condenser 122 downstream of the steam turbine 104 ) such that the condensate 120 may be pumped back into the HRSG 14 via one or more pumps 124 .

[0021] In operation, the exhaust gas flow 68 passes through the HRSG 14 and transfers heat to the components 70 to generate steam for driving the steam turbine 104. Exhaust steam from the low-pressure steam turbine 110 may be directed to a condenser 122 to form a condensate 120. The condensate 120 from the condenser 122 may then be directed to the low-pressure section 76 of the HRSG 14 with the assistance of a pump 124. The condensate 120 may then flow through a low-pressure economizer 100, which is configured to heat a feedwater 126 (including the condensate 120) with the exhaust gas flow 68. The feedwater 126 may flow from the low-pressure economizer 100 into the low-pressure evaporator 98. The feedwater 126 from the low-pressure economizer 100 may be directed toward the intermediate-pressure economizer 96 and the high-pressure economizer 92 with the assistance of a pump 125. Steam from the low-pressure evaporator 98 may be directed to the low-pressure steam turbine 110. Likewise, the feed water 126 may be routed from the intermediate pressure economizer 96 into the intermediate pressure evaporator 94 and / or toward the high pressure economizer 92. Additionally, steam from the intermediate pressure economizer 96 may be routed to the fuel gas heater 95, where the steam may be used to heat the fuel gas used in the combustor 64 of the gas turbine system 12. Steam from the intermediate pressure evaporator 94 may be routed to the intermediate steam turbine 108.

[0022] Feedwater 126 from the high pressure economizer 92 may be delivered to the high pressure evaporator 90. Steam from the high pressure evaporator 90 may be delivered to the primary high pressure superheater 84 and the final high pressure superheater 78, where the steam is superheated and ultimately delivered to the high pressure steam turbine 106. An interstage attemperator 86 may be located between the primary high pressure superheater 84 and the final high pressure superheater 78. The interstage attemperator 86 may enable more robust control of the exhaust temperature of the steam from the final high pressure superheater 78. Specifically, the interstage attemperator 86 may be configured to control the temperature of the steam leaving the final high pressure superheater 78 by injecting a cooler feedwater spray into the superheated steam upstream of the final high pressure superheater 78 whenever the exhaust temperature of the steam leaving the final high pressure superheater 78 exceeds a predetermined value.

[0023] In addition, the exhaust gas from the high pressure steam turbine 106 may be directed to the primary reheater 82 and the secondary reheater 80, where the exhaust gas may be heated again before being directed to the intermediate pressure steam turbine 108. The primary reheater 82 and the secondary reheater 80 may also be associated with an interstage attemperator 88, which is configured to control the exhaust steam temperature from the reheaters. Specifically, the interstage attemperator 88 may be configured to control the temperature of the steam leaving the secondary reheater 80 by injecting a cooler feedwater spray into the superheated steam upstream of the secondary reheater 80 whenever the exhaust temperature of the steam leaving the secondary reheater 80 exceeds a predetermined value. The arrangement of the components 70 of the HRSG 14 is merely one possible example for use with the combined cycle power plant 10 and the gas processing system 18, and the components 70 may be arranged in different ways within the scope of the present disclosure.

[0024] The combined cycle power plant 10 further includes a fluid connection system 130 located between the stages of the HRSG 14 and the stages of the steam turbine system 16. For example, the fluid connection system 130 includes a high pressure steam supply conduit or line 132 coupled to the final high pressure superheater 78 and the inlet into the high pressure steam turbine 106 and a discharge or return line 134 coupled to the outlet of the high pressure steam turbine 106 and the primary reheater 82. The fluid connection system 130 also includes an intermediate pressure steam supply conduit or line 136 and a discharge or return line 138. The intermediate pressure steam supply line 136 is fluidly coupled to the outlet of the secondary reheater 80 and the intermediate pressure evaporator 94 and the inlet into the intermediate pressure steam turbine 108. The discharge or return line 138 is fluidly coupled to the outlet of the intermediate pressure steam turbine 108 and the inlet into the low pressure steam turbine 110. The fluid connection system 130 also includes a low pressure steam supply conduit or line 140 and a discharge or return line 142. The low pressure steam supply line 140 is fluidly coupled to the discharge or return line 138 from the intermediate pressure steam turbine 108 and the outlet of the low pressure evaporator 98, and is fluidly coupled to the inlet into the low pressure steam turbine 110. The discharge or return line 142 is fluidly coupled to the outlet of the low pressure steam turbine 110 and the inlet into the low pressure economizer 100. As discussed above, the return line 142 includes the condenser 122 and the pump 124.

[0025] The combined cycle power plant 10 may include a control system 144 communicatively coupled to a monitoring system 146, wherein the control system 144 and the monitoring system 146 are communicatively coupled to various components of the gas turbine system 12, the HRSG 14, the steam turbine system 16, and the gas processing system 18. The monitoring system 146 is configured to monitor a plurality of sensors 148, designated “S,” distributed throughout the combined cycle power plant 10. The control system 144 includes a controller 150, wherein the controller 150 includes one or more processors 152, a memory 154, and instructions 156 stored on the memory 154 and executable by the processor 152 to perform various control functions for operating the gas turbine system 12, the HRSG 14, the steam turbine system 16, and the gas processing system 18. In certain embodiments, the control system 144 may communicate information (e.g., sensor feedback, alerts, alarms, etc.) to a user interface, cloud storage, a remote computer system, or any combination thereof.

[0026] The sensor 148 may be communicatively coupled to the control system 144 via a communication line or wireless communication circuit. The sensor 148 may be disposed at one or more locations in the air intake section 20, the compressor section 22, the combustor section 24, the turbine section 26, the HRSG 14, the steam turbine system 16, and the gas processing system 18. For example, the sensor 148 may be disposed at one or more locations in each of the high pressure steam turbine 106, the intermediate pressure steam turbine 108, and the low pressure steam turbine 110, thereby enabling monitoring of steam characteristics (e.g., temperature, pressure, etc.) at various locations. The sensor 148 may also be disposed along each of the pipelines 132, 134, 136, 138, 140, and 142 of the fluid connection system 130, thereby facilitating monitoring of various fluid parameters between the HRSG 14, the steam turbines 106, 108, and 110, and the gas processing system 18. Additionally, sensors 148 may be coupled to the gas treatment system 18 and / or distributed throughout the gas treatment system to enable monitoring and control of gas processing (e.g., gas capture) from various intake and / or exhaust flows. In certain embodiments, the sensors 148 may include flow sensors, pressure sensors, temperature sensors, fluid composition sensors, flame sensors, vibration sensors, clearance sensors, travel sensors, or any combination thereof. The fluid composition sensors may monitor the composition levels of various undesirable gases, such as carbon oxides (e.g., CO 2 , CO), nitrogen oxides (such as NO 2 ), sulfur oxides (such as SO 2 ) and various other acid gases and / or greenhouse gases as well as the component levels of oxygen, hydrogen, and unreacted fuel gas content. Thus, sensor feedback from sensor 148 can be used to adjust various aspects of the gas processing system 18 to reduce the carbon footprint of the combined cycle power plant 10, such as by substantially removing undesirable gases (e.g., CO 2 ), so that the carbon footprint is at least carbon neutral or carbon negative. Additional details of monitoring and control of the gas processing system 18 are discussed further below.

[0027] As discussed in further detail below, the gas treatment system 18 is configured to remove and / or capture one or more undesirable gases (e.g., waste exhaust gases, acid gases, greenhouse gases, etc.) from the air intake flow 60 and / or the exhaust flow 68 (e.g., upstream of the turbine section 26 and / or the HRSG 14) entering the gas turbine engine 12 (e.g., upstream of the compressor section 22 and / or the combustor section 24). Undesirable gases are intended to encompass any gas that may be undesirable in the air intake flow 60 and / or the exhaust flow 68. For example, the undesirable gases may include acid gases and / or greenhouse gases. For another example, the undesirable gases may include any gas that is typically regulated, including, but not limited to, carbon oxides (CO X) For example, carbon dioxide (CO 2 ) and carbon monoxide (CO), nitrogen oxides (NO X ), sulfur oxides (SO X ) For example, sulfur dioxide (SO 2 ), methane (CH 4 ) or any combination thereof. The disclosed embodiments are particularly suitable for adsorbing gases or absorbing CO from the air intake stream 60 and / or the exhaust stream 68. 2 . However, the following discussion is intended to cover each of these examples when it comes to bad gases.

[0028] The gas processing system 18 may include a plurality of gas capture systems 160 (e.g., gas capture systems 162, 164, and 166) disposed throughout the combined cycle power plant 10 to process gas streams (e.g., intake air streams, fuel streams, exhaust streams, etc.). Each of the gas capture systems 160 (e.g., 162, 164, and 166) may be configured to facilitate gas capture using one or more heat sources, wherein the gas capture systems 160 may include adsorbent-based gas capture systems, solvent-based gas capture systems, or combinations thereof. As described below, the heat sources may include a heating fluid 168 (e.g., steam and / or heating water) extracted from the HRSG 14 and / or the steam turbine system 16 and supplied to the gas capture system 160 via a steam supply system 170 (e.g., a steam supply loop), waste heat recovered by a waste heat recovery (WHR) system 172 of the combined cycle power plant 10, or a combination thereof. The steam supply system 170 may include steam supply conduits or lines 174 and 176 coupled to the HRSG 14 and / or the steam turbine system 16 at one or more locations. In the illustrated embodiment, the steam supply lines 174 and 176 may be coupled to the HRSG 14 and / or the steam turbine system 16 at or between the low pressure and intermediate pressure sections (e.g., between the low pressure steam turbine 110 and the intermediate pressure steam turbine 108 and / or between the LP section 76 and the IP section 74 of the HRSG 14). However, in certain embodiments, the steam supply system 170 may be selectively coupled to any one, more, or all components of the HRSG 14 (e.g., one or more components or locations in each of the HP section 72, the IP section 74, and the LP section 76) and / or any one, more, or all stages of the steam turbine system 16 (e.g., the HP steam turbine 106, the IP steam turbine 108, and the LP steam turbine 110) such that a heating fluid 168 (e.g., steam and / or heating water) may be extracted at one or more pressures, temperatures, or conditions for use in the gas capture system 160. For example, the control system 144 may be configured to control various valves coupled to the steam lines to control the flow of steam from the various components of the HRSG 14 and the stages of the steam turbine system 16. Additionally, in certain embodiments, the heating fluid 168 (e.g., steam and / or heating water) may be extracted from other sources, such as a waste heat steam generator that generates steam using waste heat from the waste heat recovery system 172. The gas processing system 18 is also configured to combine steam 18 from various steam sources (e.g., HRSG 14, steam turbine system 16, waste heat recovery system 172, waste heat steam generator, etc.) to provide a mixed steam having desired steam characteristics (e.g., steam temperature and associated pressure between upper and lower temperature thresholds) via control of the control system 144. In addition, the quality of the steam (saturated or superheated) can be monitored to meet the specific heating requirements of the gas processing system 18.

[0029] The control system 144 and monitoring system 146 are communicatively coupled to the gas processing system 18, including the various gas capture systems 160, to provide control of the gas processing and capture processes, including control of the heating fluid 168 (e.g., steam and / or heated water) used by the gas capture system 160. The steam may be used as indirect heating or to load the CO 2 through a heat exchanger process. 2 Direct heating of the adsorbent or solvent is applied to the gas treatment system 18. If the monitoring system 146 (e.g., sensor 148) indicates that the temperature of the extracted heating fluid 168 (e.g., steam and / or heating water) is above the upper temperature threshold, the control system 144 can be configured to control the gas treatment system 18 to adjust or cool the heating fluid 168 (e.g., via a thermostat, cooler, or heat exchanger) to reduce the steam temperature to within the upper temperature threshold and the lower temperature threshold. If the monitoring system 146 (e.g., sensor 148) indicates that the temperature of the extracted heating fluid 168 (e.g., steam and / or heating water) is below the lower temperature threshold, the control system 144 can be configured to control the gas treatment system 18 to heat the heating fluid 168 (e.g., via a heater or heat exchanger) to increase the steam temperature to within the upper temperature threshold and the lower temperature threshold. In certain embodiments, for a gas capture system 160 using an adsorbent material (e.g., an adsorbent-based gas capture system), the upper temperature threshold and the lower temperature threshold may be approximately 80 to 120 degrees Celsius. For temperature regulation, the steam supply lines 174 and 176 may include respective heat exchangers 178 and 180 configured to regulate the heating fluid 168 (e.g., steam and / or heating water) supplied to the gas capture system 160. The heat exchangers 178 and 180 may heat or cool the steam using another fluid. For example, the waste heat recovery system 172 may be configured to exchange heat with the heat exchangers 178 and 180 (e.g., via a heat exchange fluid) to heat or cool the heating fluid 168 (e.g., steam and / or heating water) to within the upper temperature threshold and the lower temperature threshold. The control system 144 may be coupled to various valves, pressure regulators, and sensors 148 to help control the respective flows through the heat exchangers 178 and 180, thereby controlling the heat exchange and the final temperature of the heating fluid 168 (e.g., steam and / or heating water). Additionally or alternatively, as described above, the waste heat recovery system 172 may be configured to transfer heat between waste heat and the heating fluid 168 (e.g., steam and / or heating water), such as in a waste heat steam generator, to regulate the temperature of the heating fluid 168. The waste heat recovery system 172 may also be used to improve the efficiency of the combined cycle power plant 10 in other ways, such as by providing heat to other equipment throughout the combined cycle power plant 10.

[0030] The waste heat recovery system 172 may include a plurality of distributed waste heat recovery systems 182, 184, and 186. The waste heat recovery system 182 is coupled to the load 28 (e.g., a generator) of the gas turbine engine 12, the waste heat recovery system 184 is coupled to the load 116 (e.g., a generator) of the steam turbine system 16, and the waste heat recovery system 186 is coupled to the compression system 188 of the gas processing system 18. The waste heat recovery systems 182, 184, and 186 may include one or more heat exchangers configured to transfer heat between the corresponding heat generating components (e.g., 28, 116, and 188) and one or more fluids. For example, each waste heat recovery system 182, 184, and 186 may transfer heat between a first fluid (e.g., a coolant and / or lubricant in the heat generating components 28, 116, and 188) and a second fluid via a first heat exchanger. The second fluid can be water used directly to generate steam in the waste heat steam generator or a working fluid used indirectly to transfer heat to water (e.g., via a second heat exchanger) to generate steam. In some embodiments, the waste heat recovery system 172 may include one or more distributed waste heat recovery systems that are connected to other machines and equipment in the combined cycle power plant, including but not limited to electric motors, pumps, compressors, chemical reactors, air separation units (ASUS), or any combination thereof. In some embodiments, the waste heat recovery system 172 can be configured to transport a heating fluid (e.g., water, coolant, lubricant, etc.) to provide heat to the gas capture system 160, wherein the heating fluid can be used alone or in combination with a heating fluid 168 (e.g., steam and / or heated water) as a heat source for the gas capture system 160.

[0031] In certain embodiments, the gas capture systems 160 (e.g., 162, 164, and 166) may be arranged in series (e.g., multiple stages), in parallel, or a combination thereof relative to the direction of flow through the combined cycle power plant 10. However, the illustrated embodiment includes at least two gas capture systems 160 arranged in series, such that the multiple stages of gas capture facilitate sequentially reducing the content of undesirable gases to a net neutral or net negative capture state. For example, the gas processing system 18 may include only a plurality of gas capture systems 162, only a plurality of gas capture systems 164, only a plurality of gas capture systems 166, a combination of gas capture systems 162 and 164, a combination of gas capture systems 162 and 166, a combination of gas capture systems 164 and 166, all gas capture systems 162, 164, and 166, or any suitable multi-stage arrangement of 2, 3, 4, 5, 6, 7, 8, 9, 10, or more gas capture systems 160. In addition, the multi-stage gas treatment system 18 may include the same or different gas capture systems 160 at different locations, such as different sizes or flow capacities, different internal surface areas along the flow paths, different flow rates along the flow paths, different numbers of flow paths, different geometries or tortuosity configurations of the flow paths, different residence times along the flow paths, different gas capture technologies (e.g., adsorbent-based gas capture and / or solvent-based gas capture), specifications for handling high or low concentrations of undesirable gases, or any combination thereof. For example, the gas capture systems 162 and 166 may be designed to handle low concentrations of undesirable gases, while the gas capture system 164 may be designed to handle high concentrations of undesirable gases. In some embodiments, the concentration of undesirable gases in the gas capture systems 162 and 166 may be more than 100 times lower than that in the gas capture system 164.

[0032] The gas capture systems 162, 164, and 166 may differ in design and gas processing capabilities due, at least in part, to their placement in the combined cycle power plant 10. In the illustrated embodiment, the gas capture system 162 is coupled to the combined cycle power plant 10 along the air intake flow 60 (e.g., at the air intake section 20), while the gas capture systems 164 and 166 are coupled to the combined cycle power plant 10 along the exhaust flow 68 (e.g., downstream of the turbine section 26). The gas capture system 162 is configured to capture undesirable gases (e.g., CO 2 ) from the air flow (air stream) 190 prior to entering and / or being combusted in the gas turbine engine 12. 2 ), wherein the gas capture system 162 uses a heating fluid 168 (e.g., steam and / or heated water) as a heat source. As discussed in further detail below, the gas capture system 162 may include an adsorbent-based gas capture system, a solvent-based gas capture system, or a combination thereof. Figure 2 and Figure 3 An example is given. The steam supply line 174 is coupled to the gas capture system 162 and provides a heating fluid 168 (e.g., steam and / or heated water) as a steam flow and / or a water flow, as indicated by arrow 192. As described above, the steam supply system 170 may include one or more steam supply lines (e.g., line 174) coupled to the HRSG 14 and / or the steam turbine system 16 at one or more locations so that the heating fluid 168 (e.g., steam and / or heated water) can be supplied to the gas capture system 162 under various conditions (e.g., pressure, temperature, steam content, water content, etc.). Although shown at the air intake section 20, the gas capture system 162 can be configured to process the air flow 190 at any location throughout the combined cycle power plant 10, including the air flow upstream of the compressor section 22, between the compressor stages 30 of the compressor section 22, downstream of the compressor section 22 and upstream of the combustor section 24, other locations including the air flow, or a combination thereof. In certain embodiments, the gas capture system 162 may be configured to process recirculated exhaust gas (EGR), such as the exhaust gas 68 that is recirculated into the compressor section 22, and thus the gas capture system 162 may be sized to process a greater concentration of undesirable gases that are recirculated as part of the EGR process. The gas capture system 162 generally processes the air flow 190 (or EGR flow) directed into the gas turbine engine 12 so that the concentration of undesirable gases is low, while also transmitting the captured gas 194 to the compression system 188 via an exhaust conduit or line 196. The exhaust line 196 may also include post-processing equipment, such as a dryer 198 configured to remove moisture content from the captured gas 194.

[0033] as Figure 1As further shown in FIG. 1 , gas capture systems 164 and 166 are coupled to the combined cycle power plant 10 downstream of the HRSG 14 and the gas turbine section 26 along the exhaust stream 68. In the illustrated position, the gas capture systems 164 and 166 are configured to remove undesirable gases from the exhaust stream 68 discharged from the gas turbine engine 12 and the HRSG 14. In certain embodiments, the gas capture systems 164 and 166 may be configured to process the exhaust stream at any location throughout the combined cycle power plant 10, including the exhaust stream upstream of the HRSG 14, between the various sections of the HRSG 14 (e.g., the HP section 72, the IP section 74, and the LP section 76), the exhaust stream downstream of the HRSG 14, an independent exhaust stream relative to the exhaust stream 68, or any combination thereof. For example, the independent exhaust stream may originate from other combustion systems, such as a furnace, a boiler, a reciprocating piston-cylinder engine, or any combination thereof. In the illustrated embodiment, gas capture system 164 is disposed upstream of gas capture system 166 such that gas capture systems 164 and 166 may represent first and second gas capture stages along exhaust flow 68 .

[0034] Along the exhaust gas stream 68, the gas treatment system 18 may include one or more dryers 200, one or more fans 202, and one or more valves 204 located upstream of the gas capture systems 164 and 166 along the exhaust gas flow path (e.g., exhaust duct) 206. The one or more dryers 200 are configured to remove moisture (e.g., water content or steam) and dry the exhaust gas stream 68. The one or more fans 202 (e.g., electric motor driven fans) are configured to increase the pressure and / or flow rate of the exhaust gas stream 68. The one or more valves 204 are configured to adjust the pressure, flow rate, and / or distribution of the exhaust gas stream 68 entering the gas capture systems 164 and 166. In certain embodiments, the illustrated dryers 200, fans 202, and valves 204 are partially or completely shared by the gas capture systems 164 and 166. However, in some embodiments, the one or more dryers 200, fans 202, and valves 204 may be independently disposed upstream of each of the gas capture systems 164 and 166. The exhaust gas stream 68 flows through each of the gas capture systems 164 and 166 connected in series for staged removal of undesirable gases to achieve a desired capture amount.

[0035] The gas capture system 164 removes a portion of the undesirable gases from the exhaust stream 68, discharges a treated exhaust stream (e.g., upstream or first stage treated exhaust) to the gas capture system 166, and discharges a captured gas portion of the captured gas 194 as shown by a discharge conduit or line 208. As discussed in further detail below, the gas capture system 164 may include an adsorbent-based gas capture system, a solvent-based gas capture system, or a combination thereof. Figure 2 and Figure 3An example is given. The steam supply line 176 is coupled to the gas capture system 164 and provides the heating fluid 168 (e.g., steam and / or heated water) as a steam flow and / or a heated water flow into the gas capture system 164. As described above, the steam supply system 170 may include one or more steam supply lines (e.g., line 176) coupled to the HRSG 14 and / or the steam turbine system 16 at one or more locations so that the heating fluid 168 (e.g., steam and / or heated water) can be supplied to the gas capture system 164 under various conditions (e.g., pressure, temperature, steam content, water content, etc.). The exhaust line 208 may include a variety of post-processing equipment, such as a dryer 210, which is configured to remove moisture (e.g., water content or steam) and dry the captured gas 194 to generate a dry captured gas, as shown by the exhaust conduit or line 212. The captured gas 194 then flows to the compression system 188, as discussed below.

[0036] Similarly, the gas capture system 166 removes a portion of the undesirable gases from the exhaust stream 68, discharges a treated exhaust stream (e.g., downstream or second stage treated exhaust) to a subsequent gas capture system or exhaust stack 214, and discharges a captured gas portion of the captured gas 194 as shown by an exhaust conduit or line 216. As discussed in further detail below, the gas capture system 166 may include an adsorbent-based gas capture system, a solvent-based gas capture system, or a combination thereof. Figure 2 and Figure 3 An example is given. The steam supply line 176 is coupled to the gas capture system 166 and provides the heating fluid 168 (e.g., steam and / or heated water) as a steam flow and / or a heated water flow into the gas capture system 166. As described above, the steam supply system 170 may include one or more steam supply lines (e.g., line 176) coupled to the HRSG 14 and / or the steam turbine system 16 at one or more locations so that the heating fluid 168 (e.g., steam and / or heated water) can be supplied to the gas capture system 166 under various conditions (e.g., pressure, temperature, steam content, water content, etc.). The exhaust line 216 may include a variety of post-processing equipment, such as a dryer 218, which is configured to remove moisture (e.g., water content or steam) and dry the captured gas 194 to generate a dry captured gas, as shown by the exhaust conduit or line 220. The captured gas 194 then flows to the compression system 188, as discussed below.

[0037] The compression system 188 may include a single-stage or multi-stage compression system. In the illustrated embodiment, the compression system 188 includes one or more first or upstream compressors 222 configured to compress the captured gas 194 in one or more upstream stages, one or more second or downstream compressors 224 configured to compress the captured gas 194 after it is compressed by the compressor 222, and one or more intercoolers 226 configured to cool the captured gas 194 between the compressors 222 and 224. The intercooler 226 may include a heat exchanger, a gas dryer, and / or other equipment to facilitate gas compression. The compression system 188 outputs the compressed captured gas 194 to a storage unit and / or pipeline 228 at a specified pressure and gas purity, as shown by a discharge conduit or pipeline 230. As described above, the waste heat recovery system 186 can be coupled to the compression system 188 to extract waste heat for use as a heat source for the gas processing system 18 (e.g., the gas capture system 160), to improve plant efficiency, or other purposes. Waste heat recovery system 186 may be coupled to one or more of compressor 222 , compressor 224 , and / or intercooler 226 .

[0038] As described above, gas capture systems 162, 164, and 166 may differ due to their placement within combined cycle power plant 10. For example, gas capture system 162 may be designed to process low concentrations of undesirable gases, such as CO at or near typical atmospheric concentration levels. 2 concentration, thereby ensuring that the gas capture system 162 is configured to convert CO 2 concentrations to levels below typical atmospheric levels (e.g., below about 420 ppmv CO 2 ). For example, the gas capture system 162 can be configured to convert CO 2 The concentration of the gas treatment system 18 may be reduced by at least 50%, 60%, 70%, 80%, or 90% of the concentration level in a typical atmosphere. In certain embodiments, to achieve such concentration levels, the gas capture system 162 may be sized to be substantially larger than the gas capture systems 164 and 166 to allow the gas (e.g., air being processed within the gas capture system 162) to have sufficient residence time. In certain embodiments, the gas capture system 162 may be excluded from the gas treatment system 18.

[0039] In contrast, gas capture system 164 may be designed to process high concentrations of undesirable gases relative to gas capture systems 162 and / or 166, while gas capture system 166 may be designed to process low or medium concentrations of undesirable gases relative to gas capture systems 162 and / or 164. For example, gas capture system 164 may be designed to process at least 10, 20, 30, 40, 50, 60, 70, 80, 90, 100, 110, 120, 130, 140, 150, or more times greater CO than gas capture system 162. 2 concentration, and gas capture system 162 can be designed to handle at least 2, 3, 4, 5, 6, 7, 8, 9, 10, or more times greater CO concentration than gas capture system 166. 2 By further example, gas capture system 164 may be designed to process at least 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21, 22, 23, 24, 25, or more times greater CO concentration than gas capture system 166. 2 By way of further example, the gas capture system 166 may be designed to process CO relative to that processed by the gas capture system 162. 2 A concentration of at least 1%, 2%, 3%, 4%, 5%, 6%, 7%, 8%, 9%, 10% or more of CO 2 In one embodiment, gas capture systems 164 and 166 can capture CO in exhaust gas stream 68, respectively. 2 95% and 4.5% of the total concentration of CO, leaving the remaining 0.5% for discharge to the exhaust stack 214. In another embodiment, the gas capture systems 164 and 166 can capture CO in the exhaust stream 68, respectively. 2 Approximately 90% and 9.5% of the total concentration, leaving the remaining 0.5% for discharge to the exhaust stack 214.

[0040] In certain embodiments, the gas capture system 164 may be designed to process approximately 60,000 ppmw of inlet CO 2 concentration (e.g., capturing at least 70%, 75%, 80%, 85%, 90%, 95% or more of the CO 2 ), and the gas capture system 162 can be designed to handle about 643 ppmw of inlet CO 2 concentration (e.g., capturing at least 50%, 60%, 70%, 80% or more of the CO 2 ), and the gas capture system 166 can be designed to handle about 3000 ppmw of inlet CO 2concentration (e.g., capturing at least 50%, 60%, 70%, 80%, 90% or more of the CO 2 In certain embodiments, the gas capture system 164 may be designed to capture approximately 25,000 to 100,000 ppmw of CO. 2 , and the gas capture system 162 can be designed to capture approximately 100 to 300 ppmv of CO 2 , and the gas capture system 166 can be designed to capture about 1,000 to 10,000 ppmw of CO 2 In some embodiments, the gas capture system 164 may be designed to capture the total CO in the exhaust gas stream 68 2 concentration of at least 70%, 75%, 80%, 85%, 90%, 95% or more, while the gas capture system 162 and / or 166 may be designed to capture the remaining CO that is otherwise present in the exhaust stream 68. 2 Substantially all or part of (e.g., the remaining CO 2 Carbon capture by gas capture system 162 (which removes undesirable gases (e.g., CO 2 )) indirectly reduces the presence of undesirable gases in the exhaust flow 68.

[0041] In one particular embodiment, the gas capture system 164 may be designed to capture the total CO 2 About 95% of the concentration (e.g., 95% of 60,000 ppmw, resulting in 57,000 ppmw of CO 2 Gas capture), and gas capture system 162 and / or 166 can be designed to capture the total CO in exhaust gas stream 68 2 Substantially all or part of the remaining 5% of the concentration (e.g., 2.5%, 3%, 3.5%, 4%, 4.5%, or 5% of 60,000 ppmw, resulting in an additional 3,000 ppmw of CO 2 For example, gas capture systems 162 and / or 166 may capture the total CO 2 90% of the remaining 5% (or effectively 4.5%) of the concentration (e.g., 3000 ppmw CO 2 90% of CO), resulting in only 300 ppmw of CO in the treated exhaust stream 68 delivered to the exhaust stack 214 2 This particular embodiment will result in a net negative carbon footprint for the combined cycle power plant 10 . However, the present disclosure contemplates a variety of configurations of the gas capture systems 160 (eg, 162 , 164 , and 166 ) in order to achieve a net neutral or net negative carbon footprint for the combined cycle power plant 10 .

[0042] In some embodiments, each of the gas capture systems 162, 164, and 166 may include a plurality of modular gas capture units, wherein each of the modular gas capture units has a common capacity and is configured based on the concentration level (e.g., CO 2 The number of modular gas capture units can be selected based on the number of levels (i.e., the number of modular gas capture units). The modular gas capture units can also include modular adsorbent-based gas capture units, modular solvent-based gas capture units, or a combination thereof. In this way, using the same or different types of gas capture technology, gas capture systems 162, 164, and 166 can be assembled and scaled to the needs of a particular location and application.

[0043] As described above, the control system 144 and the monitoring system 146 may be communicatively coupled to the gas capture system 160 and the various sensors 148 to provide information on the undesirable gases (e.g., CO 2 ) of gas capture. For example, the sensors 148 may include a gas composition sensor configured to provide undesirable gases (e.g., CO ) upstream, within, and / or downstream of each of the gas capture systems 160. 2 ) and other gas (e.g., oxygen, hydrogen) concentration levels. Sensors 148 may also include temperature sensors, pressure sensors, and flow rate sensors configured to provide associated feedback about the flow of gas (e.g., air, exhaust) processed by gas capture system 160 and the flow of steam or other fluids used to support gas capture system 160. The control system 144 may use sensor feedback to adjust the operation of the gas capture system 160, such as by adjusting the characteristics of the steam or other fluids in the gas capture system 160 (e.g., temperature, pressure, flow rate, and / or flow path), adjusting the residence time in the gas capture system 160, activating or deactivating one or more of the gas capture system 160, adjusting the dryers (e.g., 200, 210, and 218), adjusting the fans 202, adjusting the valves 204, adjusting the extraction of the HRSG 14 and / or the heating fluid 168 (e.g., steam and / or water content and conditions, extraction points, etc.), adjusting the gas turbine engine 12 (e.g., adjusting the fuel / air ratio, combustion characteristics, fuel type, fuel additives, etc.), or any combination thereof, depending on the concentration level of the undesirable gas. By adjusting various aspects of the gas processing system 18 (e.g., the multi-stage gas capture system 160) in coordination with the gas turbine engine 12 and the HRSG 14, the combined cycle power plant 10 may be configured to provide a net neutral or net negative carbon footprint.

[0044] The gas capture system 160 (eg, 162, 164, and 166) may be configured based on the specific requirements of the combined cycle power plant 10 and the CO2 The concentration levels are configured in a variety of ways. Table 1 presents various scenarios for the gas capture systems 162, 164, and 166 in the combined cycle power plant 10. The following scenarios indicate each of the gas capture systems 162, 164, and 166 as n / a (e.g., absent or active), adsorbent-based (e.g., active or not), or adsorbent-based (e.g., active or not). Figure 2 described), or solvent-based (such as those described below Figure 3 ). The adsorbent-based and solvent-based gas capture systems can each use a heating fluid 168 (e.g., steam and / or heated water) from the HRSG 14 and / or waste heat from a waste heat recovery system 172 (e.g., 182, 184, and / or 186) as a heat source for the gas capture process. In addition, for each of the following scenarios, the adsorbent-based systems can be the same or different in type, configuration, capacity, residence time, and / or any other characteristics. Similarly, for each of the following scenarios, the solvent-based systems can be the same or different in type, configuration, capacity, residence time, and / or any other characteristics. Finally, for each of the following scenarios, each of the gas capture systems 162, 164, and 166 can include one or more stages and / or parallel flows of gas capture.

[0045]

[0046] Table 1: Gas capture system scenarios

[0047] As described above, the disclosed embodiments include at least 20 scenarios for gas capture systems 162, 164, and 166. Additional scenarios using other gas capture technologies and / or variations in sorbent-based and solvent-based gas capture systems are also contemplated. In view of the foregoing, Figure 2 and Figure 3 Examples of sorbent-based and solvent-based gas capture systems are presented.

[0048] Figure 2 yes Figure 11 is a schematic diagram of an embodiment of a gas capture system 160 for a multi-stage gas processing system 18 of the present invention, showing an adsorbent-based gas capture system 250. In the illustrated embodiment, the adsorbent-based gas capture system 250 includes an adsorbent-based gas capture assembly or unit 252 (e.g., an adsorber or adsorption unit) having a plurality of adsorbent-containing conduits 254, such as adsorbent-containing conduits 256 and 258. The adsorbent-containing conduits 254 (e.g., 256 and 258) can be lined with adsorbent along an interior surface, packed with adsorbent within an interior volume, or generally filled with at least 10%, 20%, 30%, 40%, 50%, 60%, 70%, 80%, 90%, or more percentages of adsorbent material by volume. However, the adsorbent-based gas capture unit 252 may include any number of adsorbent-containing 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 adsorbent-containing conduits 254 (e.g., 256 and 258) includes an outer conduit wall 260 disposed circumferentially around a flow path 262 along a central axis 264 from an inlet 266 to an outlet 268, wherein an adsorbent material 270 is disposed along and / or within a central hole or inner surface 272 of the outer conduit wall 260.

[0049] The adsorbent material 270 (e.g., a solid sorbent) may cover, coat, or substantially line at least 50%, 60%, 70%, 80%, 90%, 95%, or 100% of the inner surface 272 of the outer conduit wall 260. Additionally or alternatively, the adsorbent material 270 may at least partially fill or plug the inner volume of the inner surface 272 or the central bore such that voids remain to facilitate fluid flow (e.g., less than or equal to 10%, 20%, 30%, 40%, or 50% void fraction). For example, the adsorbent material 270 may include a plurality of particles, beads, strips, bundles, meshes, or other distributed structures that leave voids for fluid flow. In certain embodiments, the adsorbent material 270 may be coupled to one or more internal structures within the adsorbent-containing conduit 254, such as one or more of a wire grid or mesh, radial protrusions, baffles, fins, a honeycomb structure, or any combination thereof. Furthermore, in some embodiments, the central axis 264 extending from the inlet 266 to the outlet 268 may define the flow path 262 as a linear flow path, a tortuous flow path, a serpentine or serpentine flow path, a spiral or helical flow path, a tortuous flow path, an expanding and contracting flow path, a flow path with diverging and / or converging flows, or any combination thereof. For example, the flow path 262 may be defined as a tortuous flow path and include any number or configuration of the foregoing flow paths. The adsorbent material 270 may include one or more adsorbent materials configured to adsorb undesirable gases, such as designed or adapted to adsorb carbon oxides (COX ) For example, carbon dioxide (CO 2 ) and carbon monoxide (CO), nitrogen oxides (NO X ), sulfur oxides (SO X ) For example, sulfur dioxide (SO 2 ), methane (CH 4 ) or any other undesirable gas or greenhouse gas subject to regulatory restrictions and / or considerations as described herein. For example, the adsorbent material 270 may include porous solid phase materials, including mesoporous silica, zeolites (e.g., aluminosilicates), and metal organic frameworks (MOFs) and covalent organic frameworks (COFs). The foregoing adsorbent materials 270 may be particularly suitable for CO in the adsorbent-based gas capture unit 252. 2 Adsorption. However, any suitable adsorbent material 270 may be used, depending on the desired goal for gas capture of undesirable gases. In certain 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 270 to stagedly remove and capture the same or different undesirable gases.

[0050] The adsorbent-based gas capture system 250 may be configured to alternate the various adsorbent-based gas capture units 252 between an adsorption mode (e.g., adsorbing undesirable gases into the adsorbent material 270) and a desorption mode (e.g., desorbing undesirable gases from the adsorbent material 270) using the controller 150 of the control system 144 and the sensors 148 of the monitoring system 146. For example, using the controller 150, the adsorbent-based gas capture system 250 may operate the adsorbent-based gas capture unit 256 in the adsorption mode while operating the adsorbent-based gas capture unit 258 in the desorption mode, and vice versa. The adsorbent-based gas capture system 250 may also be configured to operate multiple units (e.g., 2, 3, 4, or more) of the adsorbent-based gas capture unit 252 in the adsorption mode while operating multiple units (e.g., 2, 3, 4, or more) of the adsorbent-based gas capture unit 252 in the desorption mode, wherein the multiple units may be arranged in series, in parallel, or a combination thereof. The controller 150 is configured to alternate the adsorbent-based gas capture unit 252 between an adsorption mode and a desorption mode via a plurality of upstream and downstream systems, such as an upstream flow distribution system 274 and a downstream flow distribution system 276. The upstream flow distribution system 274 includes a heating fluid supply system 278 (e.g., a steam and / or heated water supply system) and a gas supply system 280, while the downstream flow distribution system 276 includes a post-desorption processing system 282 (e.g., a gas, steam, and / or heated water processing system) and a treated gas processing system 284.

[0051] For the desorption mode, the adsorbent-based gas capture unit 252 can be configured to pass the heating fluid 168 through the adsorbent-containing conduit 254 in direct contact with the adsorbent material 270 (e.g., direct heat transfer), through or around the adsorbent-containing conduit 254 via one or more heat exchange conduits without contacting the adsorbent material 270 (e.g., indirect heat transfer), or a combination thereof. Thus, in certain embodiments of the desorption mode described below, the adsorbent-based gas capture unit 252 can pass the heating fluid 168 directly through the adsorbent material 270 in the adsorbent-containing conduit 254 to remove the undesirable gas (e.g., CO 2 ) to produce a gas stream / heated fluid stream for further processing, or the adsorbent-based gas capture unit 252 may use the heated fluid 168 to indirectly transfer heat to the adsorbent material 270 to desorb the undesirable gas while using another flow induction system (e.g., a vacuum system) to direct the undesirable gas downstream for further processing. For example, the vacuum system may include one or more fans, blowers, or pumps to draw the flow and / or create a vacuum to induce flow out of the adsorbent-containing conduit 254 into downstream processing components. Additionally, in some embodiments, the heated fluid 168 may use steam to heat water to produce heated water, which is then passed through the adsorbent-based gas capture unit 252 to directly contact the adsorbent material 270 and desorb the undesirable gas from the adsorbent material 270. Thus, the disclosed embodiments may use a variety of heating fluids 168 (eg, steam, heated water, a fluid heated by steam, or combinations thereof) as heat sources that may directly or indirectly apply heat to the adsorbent material 270 to facilitate the desorption process.

[0052] In certain embodiments, a continuous process may be performed to provide a continuous flow of captured undesirable gases in which the wheel of adsorbent material 270 rotates from adsorption, desorption, and cooling. For example, the wheel of adsorbent material 270 may extend into each of a plurality of conduits 254 and continuously rotate through the conduits 254. During the rotation of the wheel, one or more of the conduits 254 flows the treated gas 286 to remove the undesirable gases, while one or more of the conduits 254 simultaneously flows the heating fluid 168 (e.g., steam and / or heated water) to remove and capture the undesirable gases (e.g., CO 2 ) to generate captured gas 194. For desorption, a heating fluid 168 (e.g., steam and / or heated water) may be delivered or generally configured to provide direct heat transfer and / or indirect heat transfer to the adsorbent material 270 to aid in the separation and capture of the undesirable gases.

[0053] In the illustrated embodiment, the upstream flow distribution system 274 is configured to distribute the flow and alternating flow (e.g., when changing between adsorption mode and desorption mode) of the heating fluid 168 (e.g., steam and / or heating water) and gas 286 (e.g., intake air flow 60 and / or exhaust flow 68) to the plurality of adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252. The heating fluid supply system 278 includes one or more steam supplies, heating water supplies, and / or waste heat supplies configured to generate the heating fluid 168 (e.g., steam and / or heating water), such as the HRSG 14 and the waste heat recovery system 172 (e.g., 182, 184, and / or 186). The heating fluid supply system 278 also includes a heating fluid control 288 (e.g., steam and / or heating fluid control) having one or more heating fluid control components 290, 292, and 294, which can be configured to process, regulate, and / or control the characteristics of the heating fluid 168 upstream of the adsorbent-containing conduits 254 (e.g., 256 and 258) from the adsorbent-based gas capture unit 252. For example, the heating fluid control component 290 may include a thermal control component (e.g., a steam / hot water temperature control component) such as a heat exchanger, a heater, a cooler, or any combination thereof, which is configured to regulate (e.g., increase or decrease) the temperature of the heating fluid 168. The heat exchanger may exchange heat with water, a lubricant, a coolant, a refrigerant, or some other hot fluid. In some embodiments, the waste heat recovery system 172 may be used for heat transfer in the heat exchanger. The heating fluid control component 292 may include a pressure control component such as a pressure regulator, an expander or expansion chamber, a contractor or contraction chamber, a fan or pump to add energy, a turbine to extract energy, or other suitable pressure controller. The heating fluid control components 294 may include pre-treatment components, such as particulate filters, cold water drains, and / or other pre-treatment components configured to modify the characteristics of the heating fluid 168 (e.g., steam and / or heated water) or remove contaminants. The heating fluid supply system 278 may also include one or more valves 296 configured to control the distribution of the heating fluid 168 (e.g., steam and / or heated water) to the plurality of adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252, as shown by distribution conduits or lines 298 and 300. For example, the valves 296 may include one or more two-way valves, three-way valves, or distribution manifolds to distribute the heating fluid 168 (e.g., steam and / or heated water) in response to a control signal from the controller 150.

[0054] For distribution of the gas 286, the gas supply system 280 of the upstream flow distribution system 274 includes a gas pre-treatment 302 having one or more gas pre-treatment components 304, 306, and 308, which can be configured to process, condition, and / or control the characteristics of the gas 286 (e.g., the intake air flow 60 or the exhaust flow 68) upstream of the adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252. For example, the gas pre-treatment component 304 can include a thermal control component (e.g., a gas temperature control component) such as a heat exchanger, a heater, a cooler, or any combination thereof, which is configured to adjust (e.g., increase or decrease) the temperature of the gas 286. The heat exchanger can exchange heat with water, exhaust gas, a compressor bleed stream, waste heat, or some other hot fluid. In some embodiments, the waste heat recovery system 172 can be used for heat transfer in the heat exchanger. The gas pre-treatment component 306 may include a pressure control component, such as a pressure regulator, an expander or expansion chamber, a contractor or contraction chamber, a fan or pump to add energy, a turbine to extract energy, or other suitable pressure controller. The gas pre-treatment component 308 may include one or more pollutant removal units, such as a particulate filter, a moisture removal unit or dryer, a chemical removal unit, and / or other removal units configured to clean the gas 286. The gas supply system 280 may also include one or more valves 310 configured to control the distribution of the gas 286 to multiple adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252, as shown by distribution conduits or pipelines 312 and 314. For example, the valve 310 may include one or more two-way valves, three-way valves or distribution manifolds, perforated plates, and / or flow distribution packings to distribute the gas 286 in response to a control signal from the controller 150.

[0055] The downstream flow distribution system 276 is configured to distribute flows and alternating flows (e.g., when changing between adsorption mode and desorption mode) from the plurality of adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252 to the post-desorption processing system 282 and the treated gas processing system 284. The post-desorption processing system 282 may include one or more valves 316 configured to control the distribution of captured gas / heating fluid flows (e.g., gas, steam, and / or heating water) from the plurality of adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252, as shown by distribution conduits or lines 318 and 320. For example, the valve 316 may include one or more two-way valves, three-way valves, or manifolds to collect the captured gas / heating fluid flows in response to control signals from the controller 150. In certain embodiments, the captured gas / heating fluid flow is the result of a desorption mode, wherein a heating fluid 168 (e.g., steam and / or heated water) is directed through the adsorbent-containing conduits 254 to desorb undesirable gases (e.g., CO 2 ) from the adsorbent material 270 in the respective adsorbent-containing conduits 254 . 2). Thus, the post-desorption processing system 282 may also include a post-desorption processor 322 having one or more post-desorption processing components 324, 326, and 328 (e.g., gas, steam, and / or heated water processing components), which may be configured to process, regulate, and / or control the characteristics of the captured gas / heating fluid flow (e.g., gas, steam, and / or heated water flow) from the adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252. For example, the post-desorption processing component 324 may include a captured gas / heating fluid separator configured to separate the heating fluid 168 (e.g., steam and / or heated water) from the captured gas, thereby outputting water 330 (e.g., condensate) and the captured gas 194. Examples of captured gas / heating fluid separators include thermal control components, pressure control components, chemical separation components, or combinations thereof. For example, the captured gas / heating fluid separator may be configured to condense or cool the heating fluid 168 using a condenser. The post-desorption processing components 326 may include one or more removal units configured to remove contaminants from the water 330 and / or the captured gas 194. For the water 330, the removal unit may include a particulate filter and / or a water treatment unit. For the captured gas 194, the removal unit may include a particulate filter, a water removal unit or dryer, or an additional gas treatment unit. The post-desorption processing components 328 may include one or more pressure control components and / or flow control components, such as one or more pumps for the water 330 and one or more compressors for the captured gas 194. The post-desorption processing components 328 may also include one or more vacuum pumps configured to draw the captured gas / heating fluid flow from the adsorbent-based gas capture unit 252.

[0056] For distribution of the gas 286, the treated gas processing system 284 of the downstream flow distribution system 276 may include one or more valves 332 configured to control the distribution of the treated gas flow from the plurality of adsorbent-containing conduits 254 (e.g., 256 and 258) of the adsorbent-based gas capture unit 252, as shown by distribution conduits or pipelines 334 and 336. For example, the valve 332 may include one or more two-way valves, three-way valves, or manifolds to collect the treated gas flow in response to a control signal from the controller 150 to output the treated gas 338. The treated gas is the result of the adsorption mode, in which the gas 286 (e.g., the intake air flow 60 or the exhaust flow 68) is directed through the adsorbent-containing conduits 254 to remove undesirable gases (e.g., CO 2 ) are adsorbed into the adsorbent material 270 in the corresponding adsorbent-containing conduit 254, thereby reducing the content or concentration level of the undesirable gas in the remaining treated gas flow.

[0057] The control system 144 (e.g., controller 150) is configured to receive feedback from the sensor 148 to facilitate adjustment of various operating parameters of the sorbent-based gas capture unit 252. For example, the control system 144 can be configured to alternate the flow (e.g., heating fluid 168 and gas 286) through the plurality of sorbent-containing conduits 254 (e.g., 256 and 258) so that the sorbent-containing conduits 254 can alternate between an adsorption mode and a desorption mode. In the adsorption mode, the sorbent-containing conduits 254 (e.g., 256 or 258) receive the flow of gas 286, remove the undesirable gas (e.g., CO 286) from the gas 286, and remove the undesirable gas (e.g., CO 286) from the gas 286. 2 ) is adsorbed into the adsorbent material 270, and the gas 286 having a reduced content or concentration level of the undesirable gas is output as the treated gas 338. The adsorption mode is an exothermic process that generates heat that is carried away with the treated gas 338. In the desorption mode, the adsorbent-containing conduit 254 (e.g., 256 or 258) receives a flow of a heating fluid 168 (e.g., steam and / or heated water) to remove the undesirable gas (e.g., CO) from the adsorbent material 270. 2 ) is desorbed into the heated fluid 168, and the undesirable gas (e.g., rich in undesirable gas such as CO) having desorbed 2 ) is output as a captured gas / heating fluid stream. The desorption mode is an endothermic process, and the heating fluid 168 provides sufficient heat (e.g., directly or indirectly) to drive the undesirable gas (e.g., CO 2) is desorbed from the adsorbent material 270. The control system 144 is configured to monitor sensors 148, such as sensors 148 located at or upstream of the inlet 266 and sensors 148 located at or downstream of the outlet 268, to assess the rates of adsorption and desorption, the concentration levels of the undesirable gases, and other characteristics that affect the adsorption and desorption modes in the corresponding adsorbent-containing conduits 254 (e.g., 256 and 258). If the sensors 148 indicate that it is necessary to alternate the modes (e.g., adsorption mode and desorption mode) of the adsorbent-containing conduits 254 (e.g., 256 and 258), the control system 144 can be configured to control valves 296, 310, 316, and 332 to change from the flow of the heating fluid 168 to the flow of the gas 286 in one of the adsorbent-containing conduits 254, and from the flow of the gas 286 to the flow of the heating fluid 168 in another of the adsorbent-containing conduits 254. For the heating fluid 168 (e.g., steam and / or heating water) used in one of the adsorbent-containing conduits 254, the control system 144 may be configured to control the HRSG 14, the waste heat recovery system 172, the heating fluid control 288, or any combination thereof, to control characteristics of the heating fluid 168 (e.g., temperature, pressure, flow rate, steam content, water content, etc.). For the gas 286 used in one of the adsorbent-containing conduits 254, the control system 144 may be configured to control the gas pre-treatment 302 to control characteristics of the gas 286 (e.g., temperature, pressure, flow rate, etc.). Similarly, the control system 144 is configured to control the desorption post-processor 322 to control the processing of the captured gas / heating fluid discharged from one or more of the adsorbent-containing conduits 254. For a multi-stage gas processing system 18, the control system 144 also coordinates control between multiple gas capture systems 160 to provide undesirable gas (e.g., CO 2 ) to achieve a net neutral or net negative carbon footprint. Additionally, after desorption is complete and prior to adsorption, a flow of cold water or other coolant may be applied through the adsorbent-based gas capture unit 252 to cool the adsorbent-containing conduit 254 to a desired temperature prior to the next adsorption step.

[0058] Figure 3 yes Figure 1A schematic diagram of an embodiment of a gas capture system 160 of a multi-stage gas processing system 18 is shown, showing a solvent-based gas capture system 350. The solvent-based gas capture system 350 includes an absorber 352, a solvent supply system 354, and a solvent exhaust system 356. The solvent-based gas capture system 350 can use one or more solvents to capture undesirable gases. Example solvents include monoethanolamine (MEA), diglycolamine (DGA), advanced amine solvents, amino acid salts, carbonate solvents, ammonia, immiscible liquids, and ionic liquids. As described below, the solvent-based gas capture system 350 uses a heating fluid 168 (e.g., from the HRSG 14) and / or waste heat (e.g., from the waste heat recovery system 172) to facilitate gas capture of undesirable gases.

[0059] As discussed in further detail below, the solvent supply system 354 is configured to supply a gas-lean solvent 358 into the absorber 352 via a conduit 360 coupled to a solvent distributor 362 having a plurality of nozzles 364. The nozzles 364 are configured to output a solvent dispersion 366 into an interior volume 368 of the absorber 352. The solvent dispersion 366 helps to more evenly distribute the gas-lean solvent 358 throughout the interior volume 368 so that the solvent has a more even temperature distribution as it flows downward through the absorber 352 toward the solvent exhaust system 356. The conduit 360 is coupled to a solvent inlet 370 of the absorber 352, while the solvent exhaust system 356 is coupled to a solvent outlet 372 of the absorber 352.

[0060] The solvent exhaust system 356 is configured to receive the gas-rich solvent 374 from the solvent outlet 372 and to deliver the gas-rich solvent 374 to the solvent regeneration system 376. The solvent exhaust system 356 also includes a gas compressor 378 downstream of the solvent regeneration system 376, a gas dryer 380 downstream of the gas compressor 378, and an outlet for the captured gas 194 downstream of the gas dryer 380. The solvent exhaust system 356 also provides a return conduit 382 from the solvent regeneration system 376 back to the solvent supply system 354 so that the regenerated solvent can be returned to the solvent supply system 354 as the gas-lean solvent 358.

[0061] The absorber 352 also includes a gas inlet 384 configured to receive the gas 286 (e.g., the intake air flow 60 or the exhaust flow 68) into the absorber 352 and a gas outlet 386 configured to discharge the treated gas 338 out of the absorber 352. In the illustrated embodiment, the absorber 352 includes a container or shell 388 having a top portion 390, a bottom portion 392, and an intermediate portion 394 axially disposed between the top portion 390 and the bottom portion 392 relative to a central axis 396 of the shell 388. In the following discussion, reference may be made to an axial direction or axis 398 disposed along the central axis 396, a radial direction or axis 400 intersecting or perpendicular to the central axis 396, and a circumferential direction or axis 402 extending circumferentially around the central axis 396. The top portion 390 includes a top plate or cover 404 having the gas outlet 386 coaxial with the central axis 396. However, the gas outlet 386 may be disposed offset from the central axis 396 or at other locations along the top portion 390 .

[0062] The middle portion 394 includes a sidewall 406 extending in a circumferential direction 402 about the central axis 396. For example, the sidewall 406 can be an annular sidewall, a square sidewall, a rectangular sidewall, or any other suitable shape extending about the central axis 396. In certain embodiments, the gas outlet 386 can be disposed in the sidewall 406 along the top portion 390. Additionally, the solvent inlet 370 can be disposed in the top portion 390 along the top plate or cover 404 or the sidewall 406.

[0063] The bottom portion 392 may include a substrate 408 located below the gas inlet 384 and the solvent outlet 372. In the illustrated embodiment, the gas inlet 384 and the solvent outlet 372 are disposed in the sidewall 406 along the bottom portion 392. However, in certain embodiments, the gas inlet 384 and / or the solvent outlet 372 may be disposed in the substrate 408 in the bottom portion 392. In some embodiments, the gas inlet 384 may include multiple gas inlets and / or the solvent outlet 372 may include multiple solvent outlets.

[0064] Within the interior volume 368 of the absorber 352, the absorber 352 may further include one or more sets of packing 410, a support tray or screen 412, and a solvent distributor 414 having a plurality of nozzles 416. For example, in the illustrated embodiment, the absorber 352 includes four sets of components (e.g., packing 410, support tray or screen 412, and solvent distributor 414) disposed between the solvent distributor 362 and the bottom portion 392 having the gas inlet 384 and the solvent outlet 372. The packing 410 may include a plurality of beads, balls, or mixing inducing structures configured to promote mixing between the gas 286 and the gas-lean solvent 358 supplied into the interior volume 368 of the absorber 352. The support tray or screen 412 may include a wire mesh, a plate having a plurality of openings, or other suitable structure that holds the packing 410 in place while permitting fluid flow of the gas and solvent through the support tray or screen 412 in opposite directions through the absorber 352. The solvent distributor 414 may be similar to the solvent distributor 362, and thus the nozzles 416 may be distributed throughout the interior volume 368 in a uniform manner to output a solvent dispersion 418 to better distribute the solvent through the packing 410 and the support tray or screen 412. The set of packing 410, support tray or screen 412, and solvent distributor 414 are spaced apart from one another along the central axis 396. However, in certain embodiments of the absorber 352, the spacing may be increased or decreased or even eliminated.

[0065] In operation, absorber 352 is configured to create a cross flow or counter flow of lean solvent 358 and gas 286 within interior volume 368, thereby facilitating the removal of certain undesirable gases (e.g., CO 2 ) from the gas 286 to the gas absorption in the gas-lean solvent 358. As shown, at the bottom portion 392, the gas 286 enters the absorber 352 through the gas inlet 384, and the gas 286 flows upward through the interior volume 368 of the absorber 352, as shown by arrows 420. The gas 286 entering the absorber 352 as shown by arrows 420 can form bubbles of gas 286 that rise upward through the gas-lean solvent 358 within the interior volume 368. The gas 286 then passes through each subsequent stage or group of packing 410, support trays or screens 412, and solvent distributors 414.

[0066] At the top portion 390, the solvent supply system 354 feeds the gas-lean solvent 358 into the interior volume 368 through the solvent inlet 370, the conduit 360, the solvent distributor 362, and the plurality of nozzles 364. Likewise, the nozzles 364 may be distributed at various locations across the interior volume 368 to help distribute the gas-lean solvent 358 more evenly throughout the interior volume 368, as shown by the solvent dispersion 366. The gas-lean solvent 358 then flows downward through the interior volume 368, passing through each subsequent set or stage of packing 410, support trays or screens 412, and solvent distributors 412 having nozzles 416. As the gas-lean solvent 358 passes through each packing 410, the various beads, balls, or mixing structures in the packing 410 are configured to help mix the gas-lean solvent 358 with the gas 286, thereby helping to absorb various undesirable gases from the gas 286 into the gas-lean solvent 358. For example, the gas-lean solvent 358 may be configured to absorb carbon dioxide (CO 2 ) or other undesirable gases, as discussed in detail above. When the absorption process occurs, heat is generated in the absorber 352, thereby raising the temperature of the solvent in the absorber 352. In certain embodiments, a thermal control system (e.g., a heat exchanger, a cooler, etc.) may be coupled to the absorber 352 to control the temperature and improve the efficiency of the absorption process. The absorption process continues in each group or level of the filler 410, the support tray or screen 412, and the solvent distributor 414. Between each level or group, the solvent distributor 414 helps to better distribute the solvent, as shown in the solvent dispersion 418. The solvent dispersion 418 can help to evenly mix the solvent with the gas 286, and prove that the temperature distribution is more uniform. The absorption process is then repeated in the next group or level of the filler 410, the support tray or screen 412, and the solvent distributor 414.

[0067] Finally, the absorber 352 discharges the rich solvent 374 at the bottom portion 392 through the solvent outlet 372, and the absorber 352 discharges the treated gas 338 at the top portion 390 through the gas outlet 386. The treated gas 338 may be substantially free of or stripped of one or more undesirable gases (e.g., CO 2 In contrast, the gas-rich solvent 374 may have absorbed one or more undesirable gases (e.g., CO 2 ). Therefore, the gas-rich solvent 374 can be described as being rich in CO 2 solvent (or other rich solvent, depending on the undesirable gas), while the lean solvent 358 can be described as being CO-poor 2 The specific gas absorption occurs in the solvent (or other lean solvent, depending on the undesirable gas) and absorber 352. Similarly, gas 352 can be described as containing CO 2 or CO-rich 2gas (or containing or enriched with other gases, depending on the undesirable gas), and the treated gas 338 can be described as CO 2 Reduced, lean or free gas (or other reduced, lean or free gas, depending on the undesirable gas) and specific gas absorption occurring in absorber 352. Gas absorption discussed herein is intended to encompass any one or more of the undesirable gases described herein or any other regulated gas or greenhouse gas.

[0068] The rich gas solvent 374 output from the absorber 352 flows into a solvent regeneration system 376, which can be configured to capture undesirable gases (e.g., CO 2 ) and regenerate the solvent (e.g., remove undesirable gases (e.g., CO 2 ) to reuse the solvent as the lean gas solvent 358). In the illustrated embodiment, the solvent-based gas capture system 350 includes a steam supply system 422 that is coupled to the solvent regeneration system 376 to facilitate solvent regeneration and capture of the captured gas 194. In particular, the steam supply system 422 includes one or more sources of a heating fluid 168 (e.g., steam and / or heated water), such as the HRSG 14 and / or the waste heat recovery system 172 (e.g., 182, 184, and 186). The steam supply system 422 may inject the heating fluid 168 (e.g., steam and / or heated water) directly into the solvent regeneration system 376 for solvent regeneration and capture of the captured gas 194. In some embodiments, the steam supply system 422 may further process and / or control characteristics of the heating fluid 168 (e.g., steam and / or heated water), such as temperature control and / or pressure control, prior to injection into the solvent regeneration system 376. In some embodiments, the steam supply system 422 can use the heating fluid 168 (e.g., steam and / or heated water) and / or waste heat from the waste heat recovery system 172 as an indirect heat source for the absorber 352 and / or generate steam in a boiler. In each of these embodiments, the heating fluid 168 (e.g., steam and / or heated water) and the waste heat from the waste heat recovery system 172 can be as described above with reference to Figure 1 and Figure 2 are acquired and / or processed as discussed in detail.

[0069] Therefore, undesirable gases (e.g., CO 2) may be output from the solvent regeneration system 376 to the gas compressor 378, as indicated by arrow 424, such that the gas compressor 378 is configured to compress the undesirable gas before it is dried by the gas dryer 380. The gas dryer 380 then removes any moisture content in the compressed undesirable gas from the gas compressor 378, and then outputs the compressed and dried undesirable gas as the captured gas 194. Additionally, the solvent regeneration system 376 outputs the regenerated solvent as a gas-lean solvent 358 that is returned to the solvent supply system 354 via a return conduit 382. The regenerated solvent is essentially a gas-rich solvent 374 with the undesirable gas removed in the solvent regeneration system 376.

[0070] In the solvent supply system 354, the lean gas solvent 358 (whether the original supply of the lean gas solvent 358 or the regenerated solvent from the solvent regeneration system 376) is supplied to the absorber 352 through one or more components 426, 428, 430, and 432. The components 426, 428, 430, and 432 may include one or more solvent pumps, solvent filters or treatment systems, one or more heat exchangers configured to cool the lean gas solvent 358, one or more solvent tanks, one or more solvent pressure regulators, one or more solvent flow meters, or any combination thereof.

[0071] Technical effects of the disclosed embodiments include a multi-stage gas processing system having a plurality of gas capture systems 160 (e.g., 162, 164, and 166), which may include sorbent-based gas capture systems (e.g., Figure 2 250) and / or solvent-based gas capture systems (e.g., Figure 3 350), wherein the heating fluid 168 (e.g., steam and / or heated water) and / or waste heat from the waste heat recovery system 172 (e.g., 182, 184, and 186) is used as a heat source for the gas capture process. The disclosed embodiments substantially convert the undesirable gas (e.g., CO 2 ) concentration levels to levels equal to or below input levels, thereby helping to achieve a net neutral or net negative carbon footprint for the combined cycle power plant 10.

[0072] As set forth below, the subject matter described above in detail may be defined by one or more clauses.

[0073] A system includes a gas processing system having first and second gas capture systems and a steam supply loop. The first gas capture system is configured to capture a first portion of bad gas from a combined cycle power plant. The second gas capture system is configured to capture a second portion of bad gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant. The steam supply loop includes a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

[0074] A system according to any of the preceding clauses, comprising: a controller connected to the gas handling system; and one or more sensors configured to obtain feedback indicative of a concentration level of the undesirable gas, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas based on one or more threshold concentration levels.

[0075] The system of any preceding clause, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas to be net neutral or net negative for the combined cycle power plant.

[0076] A system as described in any preceding clause, wherein the undesirable gas includes carbon dioxide (CO2).

[0077] The system of any preceding clause, comprising a combined cycle power plant having a gas turbine system, a HRSG configured to receive exhaust gas from the gas turbine system, and a steam turbine system configured to receive steam from the HRSG.

[0078] The system of any preceding clause, wherein at least one of the first gas capture system or the second gas capture system comprises a sorbent-based gas capture system.

[0079] The system of any preceding clause, wherein at least one of the first gas capture system or the second gas capture system comprises a solvent-based gas capture system.

[0080] The system of any preceding clause, wherein each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system.

[0081] A system as in any preceding clause, wherein at least one of the first gas capture system or the second gas capture system is configured to be positioned along an air flow path upstream of a combustor of a gas turbine system of the combined cycle power plant.

[0082] The system of any preceding clause, wherein at least one of the first gas capture system or the second gas capture system is configured to be positioned along an exhaust flow path of exhaust gas from a gas turbine system of the combined cycle power plant.

[0083] The system of any preceding clause, wherein each of the first gas capture system and the second gas capture system is configured to be positioned along an exhaust flow path of exhaust gas from a gas turbine system of the combined cycle power plant.

[0084] The system of any preceding clause, wherein each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system.

[0085] The system of any preceding clause, wherein each of the first gas capture system and the second gas capture system is configured to be positioned downstream of the HRSG along the exhaust flow path.

[0086] A system as described in any preceding clause, wherein the adsorbent-based gas capture system includes a wheel having an adsorbent material, and the wheel is configured to rotate the adsorbent material between a first flow path for adsorbing the undesirable gas and a second flow path for desorbing the undesirable gas.

[0087] A system as described in any preceding clause, wherein the adsorbent-based gas capture system includes a first conduit having a first adsorbent material and a second conduit having a second adsorbent material, wherein the gas treatment system is configured to alternate the flow of the gas to be treated and the steam between the first and second conduits to alternate between corresponding desorption and absorption modes.

[0088] A system includes a controller configured to control a first gas capture system of a gas processing system to capture a first portion of bad gas from a combined cycle power plant. The controller is configured to control a second gas capture system of the gas processing system to capture a second portion of bad gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant. The controller is configured to control steam supply to the first and second gas capture systems via a steam supply loop having a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

[0089] A system according to the preceding clause, wherein the controller is configured to obtain feedback indicative of a concentration level of the undesirable gas via one or more sensors, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas based on one or more threshold concentration levels.

[0090] A system according to any preceding clause, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas to be net neutral or net negative for the combined cycle power plant, wherein each of the first gas capture system and the second gas capture system is configured to be positioned along an exhaust flow path of exhaust from a gas turbine system of the combined cycle power plant, wherein each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system, and wherein the undesirable gas comprises carbon dioxide (CO2).

[0091]

[00136] The system of any preceding clause, further comprising at least one of the first gas capture system, the second gas capture system, the HRSG, the steam turbine system, the gas turbine system, or any combination thereof.

[0092] The system of any preceding clause, wherein the sorbent-based gas capture unit is configured to convey the heating fluid through or around the sorbent-containing conduit via one or more heat exchange conduits without contacting the sorbent material in an indirect heat transfer manner.

[0093] A method includes controlling a first gas capture system of a gas processing system to capture a first portion of bad gas from a combined cycle power plant. The method also includes controlling a second gas capture system of the gas processing system to capture a second portion of bad gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series relative to a fluid flow path through the combined cycle power plant. The method also includes controlling a steam supply to the first and second gas capture systems via a steam supply loop having a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system. The steam supply loop is configured to couple to and receive steam from a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant.

[0094] This written description uses examples to describe the present embodiments, including the best mode, and also enables any person skilled in the art to practice the presently disclosed embodiments, including making and using any device or system and performing any combined methods. The patentable scope of the presently disclosed embodiments is defined by the claims, and may include other examples that occur to those skilled in the art. Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ 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 gas processing system, the gas processing system comprising: a first gas capture system configured to capture a first portion of undesirable gases from a combined cycle power plant; a second gas capture system configured to capture a second portion of the undesirable gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant; and A steam supply loop comprising a first steam supply line coupled to the first gas capture system and a second steam supply line coupled to the second gas capture system, wherein the steam supply loop is configured to be coupled to a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant and receive steam from the heat recovery steam generator and / or the steam turbine system.

2. The system according to claim 1, comprising: a controller coupled to the gas processing system; and one or more sensors configured to obtain feedback indicative of a concentration level of the undesirable gas, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas based on one or more threshold concentration levels.

3. The system according to claim 2, wherein: The controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas to be net neutral or net negative for the combined cycle power plant.

4. The system according to claim 3, wherein: The undesirable gas includes carbon dioxide (CO2).

5. The system of claim 4, comprising a combined cycle power plant having a gas turbine system, a HRSG configured to receive exhaust gas from the gas turbine system, and a steam turbine system configured to receive steam from the HRSG.

6. The system according to claim 1, wherein: At least one of the first gas capture system or the second gas capture system comprises a sorbent based gas capture system.

7. The system according to claim 6, wherein: At least one of the first gas capture system or the second gas capture system comprises a solvent based gas capture system.

8. The system according to claim 1, wherein: Each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system.

9. The system according to claim 1, wherein: At least one of the first gas capture system or the second gas capture system is configured to be positioned along an air flow path upstream of a combustor of a gas turbine system of the combined cycle power plant.

10. The system according to claim 9, wherein: At least one of the first gas capture system or the second gas capture system is configured to be positioned along an exhaust flow path of exhaust gas from a gas turbine system of the combined cycle power plant.

11. The system according to claim 1, wherein: Each of the first gas capture system and the second gas capture system is configured to be positioned along an exhaust flow path of exhaust gas from a gas turbine system of the combined cycle power plant.

12. The system according to claim 11, wherein: Each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system.

13. The system according to claim 12, wherein: Each of the first gas capture system and the second gas capture system is configured to be positioned downstream of the HRSG along the exhaust flow path.

14. The system according to claim 12, wherein: The sorbent-based gas capture system includes a wheel having a sorbent material, and the wheel is configured to rotate the sorbent material between a first flow path for adsorbing the undesirable gas and a second flow path for desorbing the undesirable gas.

15. The system of claim 12, wherein: The adsorbent-based gas capture system comprises a first conduit having a first adsorbent material and a second conduit having a second adsorbent material, wherein the gas treatment system is configured to alternate the flow of the vapor and gas to be treated between the first and second conduits to alternate between respective desorption and absorption modes.

16. A system comprising: A controller configured to: controlling a first gas capture system of the gas processing system to capture a first portion of undesirable gas from the combined cycle power plant; controlling a second gas capture system of the gas processing system to capture a second portion of undesirable gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant; and Steam supply to the first and second gas capture systems is controlled via a steam supply loop, the steam supply loop comprising a first steam supply line connected to the first gas capture system and a second steam supply line connected to the second gas capture system, wherein the steam supply loop is configured to be connected to a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant and receive steam from the heat recovery steam generator and / or the steam turbine system.

17. The system according to claim 16, wherein: The controller is configured to obtain feedback indicative of a concentration level of the undesirable gas via one or more sensors, wherein the controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas based on one or more threshold concentration levels.

18. The system of claim 16, wherein: The controller is configured to control the first and second gas capture systems to control the concentration level of the undesirable gas to be net neutral or net negative for the combined cycle power plant, wherein each of the first gas capture system and the second gas capture system is configured to be positioned along an exhaust flow path of exhaust from a gas turbine system of the combined cycle power plant, wherein each of the first gas capture system and the second gas capture system comprises a sorbent-based gas capture system, wherein the undesirable gas comprises carbon dioxide (CO2).

19. The system of claim 16, further comprising at least one of the first gas capture system, the second gas capture system, the HRSG, the steam turbine system, the gas turbine system, or any combination thereof.

20. A method comprising: controlling a first gas capture system of the gas processing system to capture a first portion of undesirable gas from the combined cycle power plant; controlling a second gas capture system of the gas processing system to capture a second portion of undesirable gas from the combined cycle power plant, wherein the first and second gas capture systems are arranged in series with respect to a fluid flow path through the combined cycle power plant; and Steam supply to the first and second gas capture systems is controlled via a steam supply loop, the steam supply loop comprising a first steam supply line connected to the first gas capture system and a second steam supply line connected to the second gas capture system, wherein the steam supply loop is configured to be connected to a heat recovery steam generator (HRSG) and / or a steam turbine system of the combined cycle power plant and receive steam from the heat recovery steam generator and / or the steam turbine system.

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