Thermal integration systems and methods for gas capture systems

Abstract

This invention provides a system and method for thermal integration for gas capture systems. [Solution] The system includes a fuel heating system having a first heat exchanger. The first heat exchanger is fluidly coupled to a steam turbine system, a gas turbine system, a carbon capture system, and a heat recovery steam generator (HRSG). The first heat exchanger is configured to receive steam from the HRSG, the steam turbine system, or a combination thereof. The first heat exchanger is also configured to receive fuel. The first heat exchanger is also configured to put steam with the fuel into a first heat exchange relationship to produce a first heating fuel and a first cooling steam. The first heat exchanger is also configured to send the first cooling steam to the carbon capture system. The first heat exchanger is also configured to send the first heating fuel to a gas turbine system, a duct burner, or a combination thereof.

Description

Technical Field

[0001] The subject matter disclosed herein generally relates to systems and methods for improving the efficiency of industrial plants having combustion systems and gas treatment systems.

Background Art

[0002] Various undesirable gases pollute the atmosphere. For example, undesirable gases include carbon oxides (CO X ), such as carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NO X ), such as nitrogen dioxide (NO2), and / or sulfur oxides (SO X ), such as sulfur dioxide (SO2). Due to various regulations and environmental concerns regarding global warming, it is desirable to reduce undesirable gases (e.g., CO2) in the atmosphere. An industrial plant can include a combined cycle system having a gas turbine system that generates exhaust gas from the combustion of fuel, a heat recovery steam generator configured to generate steam from the heat of the exhaust gas, and a steam turbine system driven by the steam. The combined cycle system can include a gas treatment system for reducing undesirable gases. However, the gas treatment system can add cost and potentially reduce the efficiency of the plant. Therefore, it is necessary to improve the efficiency of the gas treatment system used in the combined cycle system and remove undesirable gases from the exhaust gas discharged from and / or into the atmosphere while maintaining the efficiency of the remaining subsystems used in the combined cycle system.

Summary of the Invention

[0003] Specific embodiments corresponding to the scope of the subject matter originally claimed are summarized below. These embodiments are not intended to limit the scope of the claimed embodiments, but rather to provide an overview of possible forms of the subject matter. In fact, the embodiments claimed herein may encompass a variety of forms that may be similar to or different from the embodiments described below.

[0004] In certain embodiments, the system includes a fuel heating system having a first heat exchanger. The first heat exchanger is fluidly coupled to a steam turbine system, a gas turbine system, a carbon capture system, and a heat recovery steam generator (HRSG). The first heat exchanger is configured to receive steam from the HRSG, the steam turbine system, or a combination thereof. The first heat exchanger is also configured to receive fuel. The first heat exchanger is also configured to place steam with the fuel in a first heat exchange relationship to produce a first heating fuel and a first cooling steam. The first heat exchanger is also configured to deliver the first cooling steam to the carbon capture system. The first heat exchanger is also configured to deliver the first heating fuel to one or more fuel injection locations in the gas turbine system, a duct burner in the HRSG, or a combination thereof.

[0005] In certain embodiments, the system includes a gas turbine system, a heat recovery steam generator (HRSG), a steam turbine system, a carbon capture system, and a fuel heating system. The fuel heating system includes a first heat exchanger. The first heat exchanger is configured to receive steam from the HRSG, the steam turbine system, or a combination thereof. The first heat exchanger is also configured to receive fuel. The first heat exchanger is also configured to transfer heat from the steam to the fuel to produce a first heated fuel and a first cooling steam. The first heat exchanger is also configured to deliver the first cooling steam to the carbon capture system. The first heat exchanger is also configured to deliver the first heated fuel to one or more fuel injection locations in the gas turbine system, a duct burner in the HRSG, or a combination thereof.

[0006] In certain embodiments, the method includes receiving steam from a heat recovery steam generator (HRSG), a steam turbine system, or a combination thereof to at least one heat exchanger in a fuel heating system. The method also includes receiving fuel to at least one heat exchanger. The method also includes transferring heat from the steam to the fuel in at least one heat exchanger to produce heated fuel and cooling steam. The method also includes sending the cooling steam to a carbon capture system. The method also includes sending the heated fuel to one or more fuel injection locations in a gas turbine system, a duct burner in an HRSG, or a combination thereof.

[0007] These and other features, aspects and advantages of the techniques disclosed herein will be better understood by reading the following descriptions of embodiments for carrying out the invention with reference to the accompanying drawings, in which similar reference numerals throughout the drawings represent similar parts. [Brief explanation of the drawing]

[0008] [Figure 1] This is a block diagram of one embodiment of a combined cycle system having a fuel heating system according to the embodiments described herein. [Figure 2] This is a block diagram of one embodiment of a composite cycle system having a fuel heating system having a heat exchanger, according to embodiments described herein. [Figure 3] This is a block diagram of one embodiment of a composite cycle system having a fuel heating system having two heat exchangers in series, according to embodiments described herein. [Figure 4] This is a block diagram of one embodiment of a composite cycle system having a fuel heating system having two heat exchangers configured in parallel, according to embodiments described herein. [Figure 5] This is a block diagram of one embodiment of a steam turbine having multiple tap-off positions for transferring steam to a fuel heating system, according to embodiments described herein. [Figure 6]This figure shows one embodiment of the process for operating a fuel heating system according to the embodiments described herein. [Modes for carrying out the invention]

[0009] One or more specific embodiments of the systems and methods disclosed herein are described below. Not all features of the actual embodiments are described herein in order to provide a concise description of these embodiments. It should be understood that, as with any engineering or design project, the development of such actual embodiments requires numerous decisions specific to the embodiment, such as compliance with system-related and business-related constraints, in order to achieve the developer's specific goals, although these constraints may differ from embodiment to embodiment. Furthermore, it should be understood that such development efforts, while complex and time-consuming, are still routine design, fabrication, and manufacturing tasks for those skilled in the art who are interested in this disclosure.

[0010] When introducing elements of various embodiments of the embodiments disclosed herein, the articles “a,” “an,” “the,” and “said” mean that there are one or more elements. The terms “comprising,” “including,” and “having” are intended to be comprehensive and mean that there may be additional elements other than those listed.

[0011] This disclosure generally relates to a fuel heating system for an industrial plant having a combined cycle system. The fuel heating system receives steam from a heat recovery steam generator (HRSG), a steam turbine system, or a combination thereof. The fuel heating system also receives fuel (e.g., natural gas, hydrogen, methane, gasoline, diesel, etc.) from a fuel source. The fuel heating system places the steam in a heat exchange relationship with the fuel, transferring heat from the steam to the fuel, thereby producing heated fuel and cooling steam. The fuel heating system delivers the heated fuel to a gas turbine system, duct burner, or a combination thereof in the combined cycle system. The fuel heating system delivers the cooling steam to a carbon capture system in the combined cycle system. As disclosed herein, the fuel heating system may include one or more heat exchangers. In embodiments of a fuel heating system having two or more heat exchangers, the heat exchangers may be arranged in series or parallel with respect to the fuel and steam flows, as described herein. The fuel heating system can eliminate the need for a superheat reducer, which is otherwise used to superheat and reduce the steam for use in a carbon capture system. Thus, the fuel heating system serves the dual purpose of both heating the fuel and superheating and reducing the steam for a carbon capture system.

[0012] With the above in mind, Figure 1 is a block diagram of one embodiment of an industrial plant 10 having a gas turbine system 12, an energy recovery system 14, a fuel heating system 16, a gas treatment system 18 having one or more gas capture systems 20, and controllers 22 coupled to each of systems 12, 14, 16, and 18. As described below, one or more gas capture systems 20 of the gas treatment system 18 are configured to capture undesirable gases (e.g., CO2) from exhaust gases and / or air (e.g., direct air capture). The gas capture system 20 of the industrial plant 10 includes a carbon capture system 100 for use in capturing undesirable gases (e.g., CO2) from exhaust gases of the combustion system, air from the atmosphere, or a combination thereof. It should be noted that the gas capture system 20 (e.g., the carbon capture system 100) does not necessarily have to be coupled to the gas treatment system 18. In certain embodiments, the carbon capture system 100 may be independent or separate from the industrial plant 10, such as a standalone carbon capture system 100 used for direct air capture. Furthermore, the carbon capture system 100 also includes a heating source and a cooling source. Before describing the details of the gas processing system 18, various embodiments of the industrial plant 10 will be described in more detail. For the purpose of directions in the drawings, the axial direction or axis 40, the radial direction or axis 42 extending radially away from the axial direction or axis 40, and the circumferential direction or axis 44 extending circumferentially around the axial direction or axis 40 may be referenced, for example, to the rotation axis 36 of the gas turbine system 12.

[0013] The gas turbine system 12 includes an intake port 50, a compressor 52 having one or more compressor stages, one or more combustors 54, a turbine 56 having one or more turbine stages, and a load 58 (e.g., a generator) driven by the turbine 56. In certain embodiments, the gas turbine system 12 further includes an exhaust gas recirculation (EGR) system 60 configured to recirculate exhaust gas 62 to the intake port 50. The recirculated exhaust gas 62 contains certain emissions associated with combustion in the combustors 54 (e.g., nitrogen oxides (NOx)). X This helps reduce the temperature and formation of the exhaust gases. During operation, the compressor 52 receives air (and exhaust gases 62 if the EGR system 60 is operating) from the intake port 50 and compresses the air and / or exhaust gases 62 in one or more compressor stages (e.g., stages of rotary compressor blades). The combustor 54 then burns the fuel from the fuel supply system with the compressed air and / or exhaust gases to produce hot combustion gases. The hot combustion gases expand to drive one or more turbine stages (e.g., stages of rotary turbine blades) in the turbine 56, thereby driving the rotation of the compressor 52 and load 58 via the shaft. The turbine 56 then outputs the hot combustion gases as exhaust gases 62. The gas turbine system 12 may include various piping to support the flow of intake, compressed air (e.g., extraction), one or more fuels (e.g., liquid fuel, gaseous fuel, etc.), combustion additives, exhaust gases (e.g., exhaust gas recirculation), or other fluids.

[0014] The energy recovery system 14 includes a steam turbine system 64 and a heat recovery steam generator (HRSG) 66. The HRSG 66 recovers waste heat from exhaust gas 62 and generates steam to drive the steam turbine system 64. The HRSG 66 includes an HP steam section 70, an IP steam section 72, and an LP steam section 74 configured to generate high-pressure (HP) steam 76, medium-pressure (IP) steam 78, and low-pressure (LP) steam 80. As shown in the figure, the HP steam section 70 includes an HP drum 71 and an HP economizer 73, the IP steam section 72 includes an IP drum 75 and an IP economizer 77, and the LP steam section 74 includes an LP drum 79 and an LP economizer 81. As shown in the figure, the HRSG 66 includes a duct burner 83 configured to heat the exhaust gas 62 entering the HRSG 66. The duct burner 83 burns fuel with an oxidizer (e.g., oxygen, air, etc.) in the exhaust gas 62, thereby heating the exhaust gas 62 prior to heat recovery from the exhaust gas 62 in the HRSG 66. As shown in the figure, the pump 85 receives feedwater 87 from the LP drum 79. The pump 85 pumps the feedwater 87 to the HP economizer 73 via the first line 89. The pump 85 also pumps the feedwater 87 to the IP economizer 77 via the second line 91.

[0015] As shown in the figure, the steam turbine system 64 may include an HP steam turbine 82 driven by HP steam 76, an IP steam turbine 84 driven by IP steam 78, and an LP steam turbine 86 driven by LP steam 80. In addition to the steam provided by the HRSG 66, the HP steam turbine 82 provides IP steam to the IP steam turbine 84, and the IP steam turbine 84 provides LP steam to the LP steam turbine 86. During operation, the steam turbine system 64 drives a load 94 (e.g., a generator) via a shaft. In certain embodiments, the steam turbine system 64 and / or the HRSG 66 may provide heated water and / or steam (e.g., HP steam 76, IP steam 78, and / or LP steam 80) to a gas processing system 18 to support the attachment and detachment modes of one or more gas capture systems 20. For example, the gas capture system 20 can receive heated water and / or steam in temperature ranges of 100-150 degrees Celsius, 110-150 degrees Celsius, 120-150 degrees Celsius, or 130-150 degrees Celsius. The steam turbine system 64 and HRSG 66 may include various piping to support the flow of exhaust gas, steam, water, or other fluids, thereby facilitating waste heat recovery, steam generation, and steam power.

[0016] After HRSG66, the exhaust gas 62 can flow into the EGR system 60 and / or the gas treatment system 18. In the illustrated embodiment, the exhaust gas 62 flows through one or more gas capture systems 20 configured to capture undesirable gases. In some embodiments, the gas capture systems 20 can receive air 96 from an additional source (e.g., environment, fan, etc.). For example, if the gas capture system 20 is configured as a direct air capture (DAC) system, the air 96 may be atmospheric air. Undesirable gases from the exhaust gas 62 and / or air 96 include carbon oxides (CO2). X (For example, carbon dioxide (CO2) and carbon monoxide (CO), nitrogen oxides (NO) X (For example, nitrogen dioxide (NO2), sulfur oxides (SO2)) XExamples include carbon dioxide (e.g., sulfur dioxide (SO2)) or any combination thereof. In the following description, CO2 may be used as an example of an undesirable gas, but the gas capture system 20 may be designed to capture any of the aforementioned undesirable gases. For example, the gas capture system 20 includes one or more carbon capture systems 100 (e.g., CO2 capture systems).

[0017] In some embodiments, the gas capture system 20 (e.g., carbon capture system 100) may include an adsorbent-based gas capture system, a solvent-based gas capture system, a cryogenic gas capture system, or any combination thereof, configured to remove and capture undesirable gases. The carbon capture system 100 may include components 102, 104, 106, and 108 configured to enable gas capture of undesirable gases (e.g., CO2) from the exhaust gas 62, thereby outputting the treatment gas 110 and the captured gas 112 (e.g., CO2).

[0018] In the illustrated embodiment, the fuel heating system 16 receives fuel 114 (for example, from a fuel source 115). The fuel 114 may include natural gas, liquid natural gas, a hydrogen blend, synthesis gas, methane, or a combination thereof. The fuel heating system 16 also receives steam 116 from an energy recovery system 14. The steam 116 may be received (for example, extracted, drained, or taken out) from a steam turbine system 64 and / or HRSG 66. As will be described in more detail herein, the fuel heating system 16 places the fuel 114 in a heat exchange relationship with the steam 116 to produce heated fuel 118 and cooling steam 119. The heat exchange relationship may include one or more heat exchangers (e.g., indirect heat exchangers, shell-and-tube heat exchangers, printed circuit heat exchangers, etc.) for indirect heat transfer between the fuel 114 and the steam 116. In certain embodiments, a heat exchange relationship (e.g., a heat exchanger) can eliminate a superheat reducer used to cool the steam 116, which removes heat from the steam 116 but does not use that heat for other purposes (e.g., waste heat). As shown, the fuel heating system 16 delivers heated fuel 118 to the gas turbine system 12 (e.g., combustor 54) and / or duct burner 83. The fuel heating system 16 also delivers cooling steam 119 to the carbon capture system 100. Thus, in the illustrated embodiment, the heat exchange relationship (e.g., a heat exchanger) advantageously provides thermal integration (e.g., heat transfer) between the fuel heating system 16, the energy recovery system 14, and the gas capture system 20 (e.g., the carbon capture system 100), thereby utilizing the heat that would otherwise be wasted by integrating systems 116, 14, and 20.

[0019] In the illustrated embodiment, the controller 22 is configured to control all aspects of the industrial plant 10. The controller 22 includes one or more processors 120, a memory 122, instructions 124 stored in the memory 122 and executable by the processors 120, and a communication circuit 126 configured to communicate with sensors and various devices of the industrial plant 10. For example, the controller 22 receives sensor feedback from one or more sensors 128 coupled to the gas turbine system 12, the steam turbine system 64, the HRSG 66, and the gas treatment system 18 (e.g., the gas capture system 20), and / or additional components of the industrial plant 10, and is configured to control the same devices based on the sensor feedback, operating mode, user input, computer model, or any combination thereof. The sensors 128 can include temperature sensors, pressure sensors, flow sensors, gas composition sensors, or any combination thereof.

[0020] In the illustrated embodiment, the gas capture system 20 can include one or more sensors 128 communicatively coupled to the controller 22. The one or more sensors 128 can be configured to measure one or more parameters associated with the cooling steam 119 entering the carbon capture system 100 from the fuel heating system 16. In certain embodiments, the one or more sensors 128 can measure the pressure, temperature, flow rate, or a combination thereof associated with the cooling steam 119. In certain embodiments, the controller 22 can control parameters associated with the fuel 114 and / or the steam 116 sent to the fuel heating system 16 in response to changes in one or more estimated parameters of the cooling steam 119 based on signals received by the controller 22 from the one or more sensors 128.

[0021] Additionally or alternatively, the steam turbine system 64 may include one or more sensors 130 communicably coupled to the controller 22. One or more sensors 130 may be configured to measure one or more parameters of the cooling steam 119 entering the gas processing system 18. For example, one or more sensors 130 may measure the pressure, temperature, flow rate, steam saturation, or any combination thereof of the cooling steam 119. Additionally or alternatively, the HRSG 66 may include one or more sensors 132 communicably coupled to the controller 22. One or more sensors 132 may be configured to measure one or more parameters of the steam 116 supplied to the fuel heating system 16. For example, one or more sensors 132 may measure the pressure, temperature, flow rate, steam saturation, or any combination thereof of the steam 116.

[0022] In certain embodiments, the controller 22 controls heat exchange within the fuel heating system 16, such as by controlling the sensed parameters of the steam 116 supplied to the fuel heating system 16 for heat transfer with the fuel 114, to control the temperature of the heated fuel 118 within temperature thresholds (e.g., upper and lower temperature thresholds) and to control the temperature of the cooled steam 119 within temperature thresholds (e.g., upper and lower temperature thresholds). For example, the controller 22 can selectively control one or more valves of the steam extraction conduit to control the steam extraction position from the steam turbine system 64 and / or the HRSG 66, thereby selectively controlling the characteristics (e.g., temperature, pressure, flow rate, steam saturation, etc.) of the steam 116 supplied to the fuel heating system 16. For example, the controller 22 can selectively open a valve to allow the flow of LP steam from the steam turbine system 64 and / or the HRSG 66 if a low level of heating of the fuel 114 is required, the controller 22 can selectively open a valve to allow the flow of IP steam from the steam turbine system 64 and / or the HRSG 66 if a medium level of heating of the fuel 114 is required, and / or the controller 22 can selectively open a valve to allow the flow of HP steam from the steam turbine system 64 and / or the HRSG 66 if a high level of heating of the fuel 114 is required. The fuel heating system 16 can provide heat transfer between the fuel 114 and the steam 116 via one or more heat exchangers, as will be described in more detail below.

[0023] Figure 2 is a block diagram of one embodiment of an industrial plant 10 having a fuel heating system 16 including a heat exchanger 150 (e.g., a first heat exchanger 152). In the illustrated embodiment, the first heat exchanger 152 is fluidly coupled to a gas turbine system 12, a steam turbine system 64, an HRSG 66, a carbon capture system 100, and a fuel source 115. In certain embodiments, the first heat exchanger 152 includes indirect heat exchangers such as a shell-and-tube heat exchanger, a coil heat exchanger, or a printed circuit heat exchanger. The controller 22 is configured to control the heat exchange in the first heat exchanger 152 by controlling the flow rate and residence time, temperature, pressure, and other characteristics of the fuel 114 and steam 116 to be heat exchanged, thereby controlling the temperatures of the heated fuel 118 and cooling steam 119 within temperature thresholds (e.g., upper and lower temperature thresholds).

[0024] As shown in the illustration, the first heat exchanger 152 receives fuel 114 (for example, from a fuel source 115). The fuel 114 may include natural gas, liquid natural gas, hydrogen blend, synthesis gas, methane, or a combination thereof. The first heat exchanger 152 also receives steam 116 from the energy recovery system 14. The steam 116 can be received (e.g., extracted, drained, or taken out) from one or more extraction locations of the steam turbine system 64 and / or HRSG 66. In the illustrated embodiment, the steam 116 is received from extraction locations along a cross line 154 that is fluidly coupled to the LP steam turbine 86 and the IP steam turbine 84. Additionally or alternatively, the steam 116 can be received from one or more additional extraction locations of the HRSG 66 and / or the steam turbine system 64 as a whole. For example, an extraction location may include one or more of the HP steam section 70, IP steam section 72, LP steam section 74, any connections between sections 70, 72, and 74, or any combination thereof of the HRSG66. In a further example, an extraction location may include one or more of the HP steam turbine 82, IP steam turbine 84, LP steam turbine 86, any connections between steam turbines 82, 84, and 86, or any combination thereof of the steam turbine system 64. Thus, the illustrated extraction locations are for illustrative purposes only and are not intended to limit the extraction locations of the disclosed embodiments. Any description of extraction locations is intended to include one, more, or all of the extraction locations of the HRSG66 and the steam turbine system 64. As understood, each extraction location may include a fluid conduit (e.g., a line, pipe, or duct) having one or more valves coupled to a controller 22 that controls the valves for controlling the flow of steam from various extraction locations.

[0025] The first heat exchanger 152 places the fuel 114 in a heat exchange relationship with steam 116 to produce heated fuel 118 and cooling steam 119. As shown in the figure, the first heat exchanger 152 delivers the heated fuel 118 to the gas turbine system 12 (e.g., combustor 54) and / or duct burner 83. In certain embodiments, the heated fuel 118 can be delivered to one or more injection locations in the combustor 54 and / or gas turbine system 12 (e.g., to reheat the combustion gases). The first heat exchanger 152 also delivers the cooling steam 119 to the carbon capture system 100. In certain embodiments, the first heat exchanger 152 can heat the fuel 114 to a temperature of at least 290, 295, 300, 305, or 310 degrees Celsius or higher. Furthermore, the first heat exchanger 152 can cool the steam 116 to a temperature suitable for the desorption mode in the carbon capture system 100, for example, 100-150 degrees Celsius, 110-150 degrees Celsius, 120-150 degrees Celsius, or 130-150 degrees Celsius. However, the specific temperature range may vary depending on the gas turbine system 12, the duct burner 82, and the carbon capture system 100. Here again, as described above, the first heat exchanger 152 heats the fuel 114 and cools the steam 116 simultaneously, rather than using a separate system to heat the fuel 114 and cool the steam 116. In other words, the first heat exchanger 152 can eliminate a separate fuel heater for heating the fuel 114 and a separate superheat reducer for cooling the steam 116, thereby reducing the number of components, reducing the amount of waste heat, and increasing the efficiency of the industrial plant 10.

[0026] Figure 3 is a block diagram of an industrial plant 10 having a fuel heating system 16 having a series flow arrangement of multiple heat exchangers 150 (e.g., a first heat exchanger 152, a second heat exchanger 170). Although Figure 3 shows two heat exchangers 150, a particular embodiment of the fuel heating system 16 may include two, three, four, five, or more heat exchangers 150 in a series flow arrangement. In the illustrated embodiment, the first heat exchanger 152 is fluid-coupled to a steam turbine system 64, a fuel source 115, and a second heat exchanger 170, and the second heat exchanger 170 is fluid-coupled to the first heat exchanger 152, an HRSG 66, a carbon capture system 100, and a gas turbine system 12 (e.g., a combustor 54, one or more injection positions). In certain embodiments, the first heat exchanger 152, the second heat exchanger 170, or a combination thereof, includes indirect heat exchangers such as shell-and-tube heat exchangers and coil heat exchangers. The controller 22 is configured to control the heat exchange between the first heat exchanger 152 and the second heat exchanger 170 by controlling the flow rate and residence time, temperature, pressure, and other characteristics of the fuel 114 and steam 116 to be heat exchanged, thereby controlling the temperatures of the heated fuel and cooling steam within temperature thresholds (e.g., upper and lower temperature thresholds).

[0027] As shown in the illustration, the first heat exchanger 152 receives fuel 114 (for example, from a fuel source). The fuel 114 may include natural gas, liquid natural gas, hydrogen blend, synthesis gas, methane, or a combination thereof. The first heat exchanger 152 also receives steam 116 from the energy recovery system 14. The steam 116 can be received (e.g., extracted, withdrawn, or taken out) from one or more extraction locations of the steam turbine system 64 and / or HRSG 66. In the illustrated embodiment, the steam 116 is received from extraction locations along the cross line 154 which is fluidly coupled to the LP steam turbine 86 and the IP steam turbine 84. Additionally or alternatively, the steam 116 can be received from one or more additional locations of the HRSG 66 and / or the steam turbine system 64 as a whole. For example, the extraction location may include one or more of the HP steam section 70, IP steam section 72, LP steam section 74, any connections between sections 70, 72, and 74, or any combination thereof of HRSG66. In a further example, the extraction location may include one or more of the HP steam turbine 82, IP steam turbine 84, LP steam turbine 86, any connections between steam turbines 82, 84, and 86, or any combination thereof of steam turbine system 64.

[0028] In the illustrated embodiment, the first heat exchanger 152 places fuel 114 in a first heat exchange relationship with steam 116 to produce first-stage heating fuel 172 (e.g., first heating fuel) and first-stage cooling steam 174 (e.g., first cooling steam). As shown in the figure, the first heat exchanger 152 sends the first-stage heating fuel 172 to the second heat exchanger 170. The first heat exchanger 152 also sends the first-stage cooling steam 174 to the second heat exchanger 170.

[0029] In the illustrated embodiment, the second heat exchanger 170 receives first-stage heating fuel 172 from the first heat exchanger 152. The second heat exchanger 170 also receives first-stage cooling steam 174 from the first heat exchanger 152. That is, the first heat exchanger 152 and the second heat exchanger 170 are arranged in series flow configuration with respect to the first-stage heating fuel 172 and the first-stage cooling steam 174. The second heat exchanger 170 puts the first-stage heating fuel 172 into a second heat exchange relationship with the first-stage cooling steam 174 to produce second-stage heating fuel 176 (e.g., second heating fuel) and second-stage cooling steam 178 (e.g., second cooling steam). As shown in the illustration, the second heat exchanger 170 delivers the second-stage heating fuel 176 to the gas turbine system 12 (e.g., combustor 54, one or more injection positions) and / or duct burner 83. In certain embodiments, the heated fuel 176 can be delivered to one or more injection locations in the combustor 54 and / or gas turbine system 12 (for example, to reheat the combustion gases). The second heat exchanger 170 also delivers second-stage cooling steam 174 to the carbon capture system 100. In certain embodiments, the first heat exchanger 152 and the second heat exchanger 170 can heat the fuel 114 to temperatures of 290, 295, 300, 305, or 310 degrees Celsius or higher. Furthermore, the first heat exchanger 152 and the second heat exchanger 170 can gradually cool the steam 116 to temperatures suitable for the desorption mode in the carbon capture system 100, for example, 100-150 degrees Celsius, 110-150 degrees Celsius, 120-150 degrees Celsius, or 130-150 degrees Celsius. Here again, the illustrated embodiment integrates heating and cooling in the first heat exchanger 152 and the second heat exchanger 170 of the fuel heating system 16, thereby eliminating the need for a separate fuel heater and a separate steam superheat reducer.

[0030] Figure 4 is a block diagram of an industrial plant 10 having a fuel heating system 16 including a plurality of heat exchangers 150 (e.g., a first heat exchanger 152, a second heat exchanger 170) in a parallel flow arrangement. Although Figure 4 shows two heat exchangers 150, a particular embodiment of the fuel heating system 16 may include two, three, four, five, or more heat exchangers 150 in a parallel flow arrangement. In some embodiments, the fuel heating system 16 may include a combination of the series flow arrangement of Figure 3 and the parallel flow arrangement of Figure 4, and therefore the fuel heating systems 16 of Figures 3 and 4 are not mutually exclusive in a particular embodiment of the fuel heating system 16. In the illustrated embodiment, the first heat exchanger 152 is fluidly coupled to a steam turbine system 64, HRSG 66, a second heat exchanger 170, and a carbon capture system 100. The second heat exchanger 170 is fluid-coupled to the fuel source 115, the first heat exchanger 152, the HRSG 66, and the gas turbine system 12 (e.g., the combustor 54). In certain embodiments, the first heat exchanger 152, the second heat exchanger 170, or a combination thereof, includes indirect heat exchangers such as shell-and-tube heat exchangers, printed circuit heat exchangers, and coil heat exchangers. The controller 22 is configured to control the heat exchange between the first heat exchanger 152 and the second heat exchanger 170 by controlling the flow rate and residence time, temperature, pressure, and other characteristics of the fuel 114 and steam 116 to be heat-exchanged, thereby controlling the temperatures of the heated fuel and cooling steam within temperature thresholds (e.g., upper and lower temperature thresholds).

[0031] As shown in the illustration, the first heat exchanger 152 receives steam 116 from the energy recovery system 14. The steam 116 can be received (e.g., extracted, drained, or taken out) from one or more extraction locations of the steam turbine system 64 and / or HRSG 66. In the illustrated embodiment, the steam 116 is received from an extraction location along a cross line 154 that is fluidly coupled to the LP steam turbine 86 and the IP steam turbine 84. Additionally or alternatively, the steam 116 can be received from one or more additional locations of the HRSG 66 and / or the entire steam turbine system 64, as described in detail above with reference to Figures 2 and 3. The first heat exchanger 152 also receives a portion of feedwater 87 from a first line 89 configured to transfer feedwater 87 from a pump 85 to an HP economizer 73. In certain embodiments, the first heat exchanger 152 may be configured to receive a portion of the feedwater 87 from one or more extraction locations of the HRSG 66 and / or the entire steam turbine system 64, and therefore the illustrated extraction locations are not intended to be limiting.

[0032] In the illustrated embodiment, the first heat exchanger 152 places feedwater 87 in a first heat exchange relationship with steam 116 to generate first-stage heated feedwater 200 (e.g., first heated feedwater) and cooling steam 119. That is, heat is transferred from steam 116 to feedwater 87. As shown in the figure, the first heat exchanger 152 sends the first-stage heated feedwater 200 to the second heat exchanger 170. The first heat exchanger 152 also sends the cooling steam 119 to the carbon capture system 100.

[0033] In the illustrated embodiment, the second heat exchanger 170 receives first-stage heated feedwater 200 from the first heat exchanger 152. The second heat exchanger 170 also receives fuel 114 from a fuel source 115. The fuel 114 may include natural gas, liquid natural gas, hydrogen blend, synthesis gas, methane, or a combination thereof. The first-stage heated feedwater 200 will be recognized as transferring heat from the first heat exchanger 152 to the second heat exchanger 170.

[0034] The second heat exchanger 170 places the first-stage heated feedwater 200 in a second heat exchange relationship with the fuel 114 to produce heated fuel 118 and cooling feedwater 202. As shown in the figure, the second heat exchanger 170 delivers the heated fuel 118 to the gas turbine system 12 (e.g., combustor 54) and / or duct burner 83. In certain embodiments, the heated fuel 118 can be delivered to one or more injection positions in the combustor 54 and / or gas turbine system 12 (e.g., to reheat the combustion gases). The second heat exchanger 170 also delivers the cooling feedwater 202 to the LP drum 79. The flow rate of the cooling feedwater 202 to the LP drum 79 can be controlled by a valve 204. In certain embodiments, the second heat exchanger 170 can heat the fuel 114 to a temperature of 290, 295, 300, 305, or 310 degrees Celsius or higher. Furthermore, the first heat exchanger 152 can cool the steam 116 to a temperature suitable for the desorption mode in the carbon capture system 100, for example, 100-150 degrees Celsius, 110-150 degrees Celsius, 120-150 degrees Celsius, or 130-150 degrees Celsius.

[0035] It will be understood that any combination of the configurations shown in Figures 1 to 4 can be used in the fuel heating system 16. For example, the fuel heating system 16 may include a first part having a single heat exchanger 150 as shown in Figure 2, and a second part having a double heat exchanger 150 as shown in Figures 3 and 4. Furthermore, although the illustrated embodiments show a fuel heating system 16 having one or two heat exchangers, it will be recognized that the fuel system may include three or more heat exchangers. For example, the fuel heating system may include three, four, five, six, seven, or more heat exchangers.

[0036] Figure 5 is a block diagram of one embodiment of a steam turbine system 64 having a plurality of tap-off valves 220 (e.g., tap-off valves 222, 224, 226, 228, 230, and 231) for delivering steam to a fuel heating system 16. In the illustrated embodiment, the steam turbine system 64 includes an HP steam turbine 82, an IP steam turbine 84, and an LP steam turbine 86. As shown, the steam turbine system 64 includes a cross line 154 fluid-coupled to the LP steam turbine 86 and the IP steam turbine 84. In the illustrated embodiment, IP steam 78 flows from the IP steam turbine 84 to the LP steam turbine 86 through the cross line 154. As shown, the cross line 154 includes a flow line 232 (e.g., a fluid conduit) having a butterfly valve 234, and a bypass line 236 (e.g., a fluid conduit) parallel to the flow line 232.

[0037] In the illustrated embodiment, the steam turbine system 64 also includes lines 237 (e.g., fluid conduits) for transporting steam 116 to and from the steam turbine system 64. Lines 237 include an HP inlet line 238 fluid-coupled to the HP inlet portion 240 of the HP steam turbine 82 and an HP outlet line 242 fluid-coupled to the HP outlet portion 244 of the HP steam turbine 82. As shown in the illustration, lines 237 also include an IP inlet line 246 fluid-coupled to the IP inlet portion 248 of the IP steam turbine 84 and an IP outlet line 250 fluid-coupled to the IP outlet portion 252 of the IP steam turbine 84. The IP inlet line 246 includes a reheater 254, and the IP outlet line 250 includes a first flow control valve 256 and a second flow control valve 258. In certain embodiments, the HP outlet line 242 may be fluid-coupled to the reheater 254 located in the IP inlet line 246.

[0038] As shown in the figure, the tap-off valve 230 is located in line 237. The first tap-off valve 222 is located upstream of the first flow control valve 256 and the second flow control valve 258 (for example, upstream of the steam 116 flowing into the IP steam turbine 84). The second tap-off valve 224 is located downstream of the first flow control valve 256 and the second flow control valve 258 (for example, downstream of the steam 116 flowing into the IP steam turbine 84). The third tap-off valve 226 is located downstream of the reheater 254 (for example, downstream of the steam 116 flowing into the IP steam turbine 84). The fourth tap-off valve 228 is located in the HP inlet line 238, and the fifth tap-off valve 230 is located in the HP outlet line 242. The sixth tap-off valve 231 is fluid-coupled to the cross line 154.

[0039] In certain embodiments, the controller 22 can selectively control the tap-off valves 230 based on the operating conditions of the operating parameters of the gas turbine system 12. For example, in response to the gas turbine system 12 operating at full load, the controller 22 can extract steam 116 from the cross line 154. Additionally or alternatively, in response to the gas turbine system 12 operating at partial load, the controller 22 can extract steam 116 from any combination of the tap-off valves 230. In certain embodiments, the controller 22 can control the butterfly valve 234 and / or the tap-off valves 230 to control the pressure of the steam 116. It will be understood that the steam 116 can be transferred to the fuel heating system 16 using any combination of the tap-off valves 230. Furthermore, it will be recognized that the tap-off valves 230 described herein can be used in combination with any of the configurations of the fuel heating system 16 shown in Figures 1 to 4. In certain embodiments, the controller 22 may be configured to control one or more valves to extract steam at an appropriate steam pressure (e.g., IP, LP, and / or HP steam) from any of the steam sections 70, 72, and 74 of the HRSG 66 and any of the steam turbines 82, 84, and 86 of the steam turbine system 64 and deliver it to the fuel heating system 16, depending on the operating conditions of the gas turbine system 12 (e.g., starting, full load, partial load, stop, etc.), the fuel temperature threshold, the steam temperature threshold supplied to the carbon capture system 100, or any combination thereof.

[0040] Figure 6 is a flowchart of one embodiment of the process 260 for operating the fuel heating system 16. Process 260 may be carried out by the computing devices or controllers disclosed above with reference to Figures 1 to 4, or any other suitable computing devices or controllers. Furthermore, the blocks of process 260 may be carried out in the order disclosed herein, or in any other suitable order. For example, certain blocks of process 260 may be carried out simultaneously. In addition, in certain embodiments, at least one block of process 260 may be omitted.

[0041] In block 262 of process 260, the fuel heating system 16 can receive steam from the HRSG 66, the steam turbine system 64, or a combination thereof. As described herein, the steam can be received from the cross line between the LP steam turbine and the IP steam turbine, from one or more locations of one or more tap-off valves, and / or from the HRSG 66.

[0042] In block 264 of process 260, the fuel heating system 16 can receive fuel. In certain embodiments, the fuel can be received from a fuel source (e.g., a tank, a pipeline, etc.). As described herein, the fuel may include natural gas, liquid natural gas, a hydrogen blend, synthesis gas, methane, or a combination thereof.

[0043] In block 266 of process 260, the fuel heating system 16 can transfer heat from steam to fuel to produce heated fuel and cooling steam. In certain embodiments, the fuel heating system 16 can transfer heat from steam to fuel using one or more heat exchangers. In certain embodiments, two or more heat exchangers may be arranged in series with respect to the fuel and steam flows, or in parallel. In certain embodiments, a buffer fluid (e.g., feedwater) may be used to transfer heat between two or more heat exchangers arranged in parallel.

[0044] In block 268 of process 260, the fuel heating system 16 sends cooling steam to the carbon capture system 100. In certain embodiments, the cooling steam can be used to scavenge one or more containers containing adsorbent material in the carbon capture system 100. In certain embodiments, one or more sensors can monitor the pressure, temperature, and / or flow rate of the cooling steam entering the carbon capture system 100 and transmit signals indicating the monitored pressure, temperature, and / or flow rate to the controller 22.

[0045] In block 270 of process 260, the fuel heating system 16 delivers heated fuel to the gas turbine system 12, the duct burner 83, or a combination thereof. In certain embodiments, the fuel is delivered to the combustor of the gas turbine system 12. In certain embodiments, the fuel heating system 16 can heat the fuel to a temperature of 290, 295, 300, 305, or 310 degrees Celsius or higher.

[0046] The technical effect of the disclosed embodiment is to utilize steam from a steam turbine system, HRSG, or a combination thereof to heat the fuel used in a gas turbine system and simultaneously scavenge a carbon capture system. Thus, the disclosed embodiment provides thermal integration (e.g., heat transfer) between the fuel heating system and the carbon capture system via steam, where the steam acts as a heat source in the carbon capture system, and the fuel heating system transfers heat from the steam for both heating the fuel and cooling the steam to suit the carbon capture system. In this way, the fuel heating system can eliminate steam superheat reducers that would otherwise have been used to reduce the superheating of the steam prior to the carbon capture system, such as by releasing heat into the environment (e.g., waste heat). Instead, the fuel heating system uses the heat that would otherwise be wasted to heat the fuel for the gas turbine system and / or duct burners while cooling the steam for the carbon capture system. In this way, the disclosed embodiment eliminates components and costs (e.g., steam superheat reducers) and increases the efficiency of the industrial plant. Additionally or alternatively, the efficiency of the carbon capture system can be increased by at least 0.1% during base load operation. Furthermore, the disclosed embodiments may be implemented in new combined cycle power plants and / or retrofitted to existing combined cycle power plants.

[0047] The subject matter described in detail above may be defined by one or more of the following clauses.

[0048] According to a first embodiment, the system includes a fuel heating system having a first heat exchanger. The first heat exchanger is fluidly coupled to a steam turbine system, a gas turbine system, a carbon capture system, and a heat recovery steam generator (HRSG). The first heat exchanger is configured to receive steam from the HRSG, the steam turbine system, or a combination thereof. The first heat exchanger is also configured to receive fuel. The first heat exchanger is also configured to generate a first heating fuel and a first cooling steam by placing steam with the fuel in a first heat exchange relationship. The first heat exchanger is also configured to send the first cooling steam to the carbon capture system. The first heat exchanger is also configured to send the first heating fuel to one or more fuel injection locations of the gas turbine system, a duct burner of the HRSG, or a combination thereof. The system described in the preceding clause, wherein the first heat exchanger is configured to receive steam from a cross line between the intermediate-pressure steam turbine of the steam turbine system and the low-pressure steam turbine of the steam turbine system.

[0049] A fuel heating system as described in any of the preceding clauses, comprising a second heat exchanger fluidly coupled to a first heat exchanger, a gas turbine system, a duct burner, an HRSG, or a combination thereof.

[0050] The system as described in any of the preceding clauses, wherein the second heat exchanger is configured to receive a first cooling steam from the first heat exchanger; to receive a first heating fuel from the first heat exchanger; to generate a second heating fuel and a second cooling steam in a second heat exchange relationship with the first heating fuel; to send the second cooling steam to a carbon capture system; and to send the second heating fuel to a gas turbine system, a duct burner, or a combination thereof.

[0051] The system as described in any of the preceding clauses, wherein the first heat exchanger is configured to receive feedwater from the low-pressure drum of the HRSG; to receive steam from the HRSG, a steam turbine system, or a combination thereof; to produce first heated feedwater and second cooling steam in a second heat exchange relationship with the feedwater; to send the first heated feedwater to the second heat exchanger; and to send the second cooling steam to a carbon capture system.

[0052] The system as described in any of the preceding clauses, wherein the second heat exchanger is configured to receive first heated feedwater from the first heat exchanger; to receive fuel; to produce second heated feedwater and second heated fuel in a third heat exchange relationship with the fuel; to send the second heated feedwater to a low-pressure drum; and to send the second heated fuel to a gas turbine system, a duct burner, or a combination thereof.

[0053] The system described in any of the preceding clauses, including a pump configured to transfer feedwater from a low-pressure drum to a high-pressure economizer of the HRSG via a first line, and to transfer feedwater from a low-pressure drum to a medium-pressure economizer of the HRSG via a second line.

[0054] The system described in any of the preceding clauses, wherein the first heat exchanger is configured to receive feedwater from the first line.

[0055] A system as described in any of the preceding clauses, comprising a controller having memory and a processor, wherein the controller is configured to control one or more actuators in response to the gas turbine operating at full load to cause steam to flow from a cross line to a first heat exchanger; or in response to the gas turbine operating at partial load to cause steam to flow from one or more lines coupled to a high-pressure steam turbine, an intermediate-pressure steam turbine, or a combination thereof of the steam turbine; or a combination thereof.

[0056] The system described in any of the preceding clauses, wherein one or more lines include a first inlet line connected to the inlet portion of a high-pressure steam turbine, a first outlet line connected to the outlet portion of a high-pressure steam turbine, a second inlet line connected to the inlet portion of an intermediate-pressure steam turbine, a second outlet line connected to the outlet portion of an intermediate-pressure steam turbine, or a combination thereof.

[0057] The system described in any of the preceding clauses, wherein the first outlet line is configured to transfer steam from a high-pressure steam turbine to a reheater, and the second inlet line is configured to transfer steam from the reheater to a medium-pressure steam turbine.

[0058] The system described in any of the preceding clauses, comprising one or more valves configured to regulate the flow of steam to a first heat exchanger, wherein a controller is configured to selectively actuate one or more valves.

[0059] The system described in any of the preceding clauses, wherein the first heat exchanger is configured to selectively receive steam from a plurality of extraction positions via a plurality of valves controlled by a controller, the plurality of extraction positions including at least three of the low-pressure section of the HRSG, the intermediate-pressure section of the HRSG, the high-pressure section of the HRSG, the low-pressure steam turbine, the intermediate-pressure steam turbine, the high-pressure steam turbine, the crossing lines between steam turbines in a steam turbine system, or any combination thereof.

[0060] According to a second embodiment, the system includes a gas turbine system, a heat recovery steam generator (HRSG), a steam turbine system, a carbon capture system, and a fuel heating system. The fuel heating system includes a first heat exchanger. The first heat exchanger is configured to receive steam from the HRSG, the steam turbine system, or a combination thereof. The first heat exchanger is also configured to receive fuel. The first heat exchanger is also configured to transfer heat from the steam to the fuel to produce a first heated fuel and a first cooling steam. The first heat exchanger is also configured to send the first cooling steam to the carbon capture system. The first heat exchanger is also configured to send the first heated fuel to one or more fuel injection locations of the gas turbine system, a duct burner of the HRSG, or a combination thereof.

[0061] The system described in the preceding clause, wherein the first heat exchanger is configured to receive steam from the intersection line between the intermediate-pressure steam turbine and the low-pressure steam turbine of the steam turbine system.

[0062] A fuel heating system as described in any of the preceding clauses, comprising a second heat exchanger fluidly coupled to a first heat exchanger, a gas turbine system, a duct burner, or a combination thereof.

[0063] The system as described in any of the preceding clauses, wherein the second heat exchanger is configured to receive a first cooling steam from the first heat exchanger; to receive a first heating fuel from the first heat exchanger; to generate a second heating fuel and a second cooling steam in a second heat exchange relationship with the first heating fuel; to send the second cooling steam to a carbon capture system; and to send the second heating fuel to a gas turbine system, a duct burner, or a combination thereof.

[0064] The system as described in any of the preceding clauses, wherein the first heat exchanger is configured to receive feedwater from the low-pressure drum of the HRSG; to receive steam from the cross line between the intermediate-pressure steam turbine of the steam turbine system and the low-pressure steam turbine of the steam turbine system; to produce first heated feedwater and second cooling steam in a second heat exchange relationship with the feedwater; to send the first heated feedwater to the second heat exchanger; and to send the second cooling steam to the carbon capture system.

[0065] According to a third aspect, the method includes receiving steam from a heat recovery steam generator (HRSG), a steam turbine system, or a combination thereof to at least one heat exchanger of a fuel heating system. The method also includes receiving fuel to at least one heat exchanger. The method also includes transferring heat from the steam to the fuel in at least one heat exchanger to produce heated fuel and cooling steam. The method also includes sending the cooling steam to a carbon capture system. The method also includes sending the heated fuel to one or more fuel injection locations of a gas turbine system, a duct burner of an HRSG, or a combination thereof.

[0066] The method described in the preceding clause, which includes capturing carbon dioxide (CO2) from air and / or exhaust gases from a gas turbine system, wherein the capture includes using cooling steam during the desorption mode of the carbon capture system.

[0067] This specification uses examples to disclose the invention in its best mode and to enable any person skilled in the art to practice the invention, including the fabrication and use of any device or system and the implementation of any method incorporating it. The patentable scope of the invention is defined by the claims and may include other examples that a person skilled in the art may conceive. Such other examples are intended to be within the claims if they have structural elements that are no different from the language of the claims, or if they include equivalent structural elements that are no substantially different from the language of the claims. [Explanation of symbols]

[0068] 10 Industrial Plants 12 Gas Turbine Systems 14 Energy Recovery Systems 16 Fuel heating system 18 Gas Processing System 20 Gas Capture Systems 22 controllers 36 Rotation axis 40 Axis or axis 42 Radial or axial 44 Circumferential direction or axis 50 Intake port 52 Compressor 54 Combustor 56 Turbine 58 load 60 Exhaust Gas Recirculation (EGR) System 62 Exhaust gas 64 Steam Turbine System 66 Heat Recovery Steam Generator, HRSG 70 HP steam section 71 HP Drum 72 IP Steam Section 73 HP Economizer 74 LP steam section 75 IP Drum 76 High-pressure (HP) steam 77 IP Economizer 78 Medium-pressure (IP) steam 79 LP Drums 80 Low-pressure (LP) steam 81 LP Economizer 82 HP steam turbine 83 Duct Burner 84 IP Steam Turbine 85 pumps 86 LP Steam Turbine 87 Water supply 89 First line 91 Second line 94 load 96 Air 100 Carbon Capture Systems 102 Components 104 Components 106 Components 108 components 110 Processed gas 112 Captured Gas 114 Fuel 115 Fuel source 116 Steam 118 Heating fuel 119 Cooling steam 120 processors 122 memory 124 Command 126 Communication Circuit 128 sensors 130 sensors 132 sensors 150 Heat exchanger 152 First heat exchanger 154 Intersecting Lines 170 Second heat exchanger 172 First-stage heating fuel 174 First-stage cooling steam 176 Second-stage heating fuel 178 Second stage cooling steam 200 First stage heated water supply 202 Cooling water supply 204 Valve 220 Tap-off valve 222 First tap-off valve 224 Second tap-off valve 226 Third tap-off valve 228 Fourth tap-off valve 230 Fifth tap-off valve 231 Sixth Tap-Off Valve 232 Flowline 234 Butterfly Valve Route 236 Bypass Line Line 237 238 HP Entrance Line 240 HP entrance part 242 HP Exit Line 244 HP exit part 246 IP Inlet Line 248 IP entrance part 250 IP exit line 252 IP exit part 254 Reheater 256 First flow control valve 258 Second flow control valve 260 processes 262 blocks 264 blocks 266 blocks 268 blocks 270 blocks

Claims

1. A fuel heating system (16) comprising a first heat exchanger (152), wherein the first heat exchanger (152) is fluidly coupled to a steam turbine system (64), a gas turbine system (12), a carbon capture system (100), and a heat recovery steam generator (HRSG) (66), and the first heat exchanger (152) The system is configured to receive steam (116) from the HRSG (66), the steam turbine system (64), or a combination thereof. It is configured to receive fuel (114), The steam (116) is configured to generate a first heating fuel and a first cooling steam in a first heat exchange relationship with the fuel (114), The first cooling steam is configured to be sent to the carbon capture system (100), The first heated fuel is configured to be delivered to one or more fuel injection positions of the gas turbine system (12), the duct burner (83) of the HRSG (66), or a combination thereof. Fuel heating system (16) A system that includes these features.

2. The system according to claim 1, wherein the first heat exchanger (152) is configured to receive steam (116) from the intersection line (154) between the intermediate-pressure steam turbine (84) and the low-pressure steam turbine (86) of the steam turbine system (64).

3. The system according to claim 1, wherein the fuel heating system (16) comprises a second heat exchanger (170) fluidly coupled to the first heat exchanger (152), the gas turbine system (12), the duct burner (83), the HRSG (66), or a combination thereof.

4. The second heat exchanger (170) It is configured to receive the first cooling steam from the first heat exchanger (152), It is configured to receive the first heating fuel from the first heat exchanger (152), The first cooling steam is configured to generate a second heating fuel and a second cooling steam in a second heat exchange relationship with the first heating fuel. The second cooling steam is configured to be sent to the carbon capture system (100), The second heating fuel is configured to be supplied to the gas turbine system (12), the duct burner (83), or a combination thereof. The system according to claim 3.

5. The first heat exchanger (152) It is configured to receive water (87) from the low-pressure drum (79) of the HRSG (66), The system is configured to receive the steam (116) from the HRSG (66), the steam turbine system (64), or a combination thereof. The steam (116) is configured to generate a first heated feedwater and a second cooling steam in a second heat exchange relationship with the feedwater (87). The first heated water supply is configured to be sent to the second heat exchanger (170), The second cooling steam is configured to be sent to the carbon capture system (100), The system according to claim 3.

6. The second heat exchanger (170) It is configured to receive the first heated feedwater from the first heat exchanger (152), It is configured to receive the aforementioned fuel (114), The first heated feedwater is configured to generate a second heated feedwater and a second heated fuel in a third heat exchange relationship with the fuel (114), The second heated water supply is configured to be sent to the low-pressure drum (79), The second heating fuel is configured to be supplied to the gas turbine system (12), the duct burner (83), or a combination thereof. The system according to claim 5.

7. The water supply (87) is transferred from the low-pressure drum (79) to the high-pressure economizer (73) of the HRSG (66) via the first line (89). The water supply (87) is configured to be transferred from the low-pressure drum (79) to the medium-pressure economizer (77) of the HRSG (66) via a second line (91). The system according to claim 5, further comprising a pump (85).

8. The system according to claim 7, wherein the first heat exchanger (152) is configured to receive the water supply (87) from the first line (89).

9. The steam turbine comprises one or more lines (237) coupled to a high-pressure steam turbine (82), an intermediate-pressure steam turbine (84), or a combination thereof, wherein the one or more lines (237) A first inlet line connected to the inlet portion (240) of the high-pressure steam turbine (82), A first outlet line connected to the outlet portion (244) of the high-pressure steam turbine (82), A second inlet line connected to the inlet portion (248) of the aforementioned intermediate-pressure steam turbine (84), A second outlet line connected to the outlet portion (252) of the aforementioned intermediate-pressure steam turbine (84), or a combination of those The system according to claim 2, comprising:

10. The system according to claim 9, wherein the first outlet line is configured to transfer the steam (116) from the high-pressure steam turbine (82) to the reheater (254), and the second inlet line is configured to transfer the steam (116) from the reheater (254) to the intermediate-pressure steam turbine (84).

11. The system according to claim 9, comprising a controller (22) having memory (122) and a processor (120), and one or more valves (204) configured such that the first inlet line, the first outlet line, the second inlet line, the second outlet line, or a combination thereof regulates the flow of steam (116) to the first heat exchanger (152), the controller (22) is configured to selectively actuate the one or more valves (204).

12. The system according to claim 1, wherein the first heat exchanger (152) is configured to selectively receive steam (116) from a plurality of extraction positions via a plurality of valves (204) controlled by a controller (22), the plurality of extraction positions include at least three of the low-pressure section (74) of the HRSG (66), the intermediate-pressure section (72) of the HRSG (66), the high-pressure section (70) of the HRSG (66), the low-pressure steam turbine (86), the intermediate-pressure steam turbine (84), the high-pressure steam turbine (82), the crossing line (154) between the steam turbines (82, 84, 86) of the steam turbine system (64), or any combination thereof.

13. Receiving steam (116) from a heat recovery steam generator (HRSG) (66), a steam turbine system (64), or a combination thereof to at least one heat exchanger (150) of the fuel heating system (16) (262), Receiving fuel (114) to at least one heat exchanger (150) (264), (266) Transferring heat from the steam (116) to the fuel (114) in the at least one heat exchanger (150) to generate heated fuel (118) and cooling steam (119), Sending the cooling steam (119) to the carbon capture system (100) (268), The heated fuel (118) is to be delivered (270) to one or more fuel injection positions of the gas turbine system (12), the duct burner (83) of the HRSG (66), or a combination thereof. Methods that include...

14. Carbon dioxide (CO2) from air (96) and / or exhaust gas (62) from the gas turbine system (12) ２ The method according to claim 13, comprising capturing ) and comprising using the cooling steam (119) during the desorption mode of the carbon capture system (100).

15. The controller (22) In response to the gas turbine operating at full load, one or more valves (204) are controlled to direct the steam (116) from the cross line (154) to the first heat exchanger (152), In response to the gas turbine operating at partial load, the system is configured to control one or more valves (204) to allow the steam (116) to flow from one or more lines (237), Or configured to perform a combination thereof, The system according to claim 11.

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