Combined cycle power plant with exhaust gas recirculation injectors

Abstract

A combined cycle power plant includes a gas turbine engine including a compressor and a turbine. The turbine discharges a first exhaust gas stream therefrom. A heat recovery steam generator receives the first exhaust stream, extracts heat from the first exhaust stream, and discharges a second exhaust stream therefrom. A cooler cools the second exhaust gas stream to form a cooled exhaust gas stream and discharges the cooled exhaust gas stream. An exhaust gas recirculation line directs a first portion of the cooled exhaust gas stream toward the injector. The ejector receives the compressor extraction stream and the first portion of the cooled exhaust stream, compresses the first portion of the cooled exhaust stream using the compressor extraction stream, and discharges a recovered gas stream to the turbine.

Description

Background Art

[0001] The present disclosure relates generally to power generation systems, and more particularly to systems that use ejectors and recirculated exhaust gas to enhance power plant output.

[0002] Gas turbine systems are used to generate electricity and typically include a compressor, a combustor, and a turbine. Operation of a gas turbine system at higher operating temperatures typically improves performance, efficiency, and power output. However, during operation, various gas path components in the system may be subjected to high temperature flows. Over time, continued exposure to high temperature flows may excessively affect the components and / or reduce the service life of the components. Therefore, at least some known gas turbine components that are subjected to high temperature flows are cooled so that the gas turbine system can continue to operate at elevated temperatures. For example, some components may be provided with compressor bleed air, etc., for cooling purposes. However, any air that has been compressed in the compressor and is not used to produce combustion gases typically reduces the overall efficiency and output of the gas turbine system. Summary of the invention

[0003] In one aspect, a combined cycle power plant is provided that includes a gas turbine engine that includes a compressor and a turbine. The turbine discharges a first exhaust gas stream therefrom. A heat recovery steam generator receives the first exhaust gas stream therein, extracts heat from the first exhaust gas stream, and discharges a second exhaust gas stream therefrom. A cooler cools the second exhaust gas stream to form a cooled exhaust gas stream, and discharges the cooled exhaust gas stream. An exhaust gas recirculation line directs a first portion of the cooled exhaust gas stream toward an ejector. The ejector receives the compressor extract stream from the compressor, receives the first portion of the cooled exhaust gas stream, compresses the first portion of the cooled exhaust gas stream using the compressor extract stream, and discharges the recovered gas stream to the turbine.

[0004] On the other hand, a combined cycle power plant is provided that includes a gas turbine engine that includes a compressor and a turbine. The turbine discharges a first exhaust gas stream therefrom. A heat recovery steam generator receives the first exhaust gas stream therein, extracts heat from the first exhaust gas stream, and discharges a second exhaust gas stream therefrom. A cooler cools the second exhaust gas stream to form a cooled exhaust gas stream, and discharges the cooled exhaust gas stream. An exhaust gas recirculation line directs a first portion of the cooled exhaust gas stream toward an ejector. The ejector receives the compressor extraction stream from the compressor, receives the first portion of the cooled exhaust gas stream, compresses the first portion of the cooled exhaust gas stream using the compressor extraction stream, and discharges the recovered gas stream to the turbine. A steam turbine receives a steam stream therein and discharges a steam extraction stream. A carbon capture system receives the steam extraction stream and a second portion of the cooled exhaust gas stream. BRIEF DESCRIPTION OF THE DRAWINGS

[0005] Figure 1is a schematic diagram of an exemplary combined cycle power plant.

[0006] Figure 2 is a schematic diagram of an exemplary combined cycle power plant including an exhaust gas recirculation ejector.

[0007] Figure 3 yes Figure 2 Illustration of an exhaust gas recirculation injector shown in .

[0008] Figure 4 is a schematic diagram of an alternative combined cycle power plant system including an exhaust gas recirculation ejector, a second exhaust gas recirculation line, and an exhaust gas recirculation blower. DETAILED DESCRIPTION

[0009] Embodiments described herein relate to power generation systems that use ejectors and recirculated exhaust gas to enhance power plant output and / or efficiency.

[0010] Unless otherwise indicated, approximate language as used herein, such as "substantially", "substantially" and "about" indicate that as will be recognized by those of ordinary skill in the art, the terms so modified may apply only to approximate degrees, rather than absolute or perfect degrees. Therefore, the values ​​modified by one or more terms (such as "about", "approximately" and "substantially") are not limited to the specified precise values. In at least some cases, approximate language may correspond to the precision of the instrument used to measure the value. In addition, unless otherwise indicated, the terms "first", "second", etc. are used only as tags in this article, and are not intended to impose order, position or hierarchical requirements on the items to which these terms are related. In addition, for example, a reference to a "second" item does not require or exclude the existence of, for example, a "first" or lower numbered item or a "third" or higher numbered item.

[0011] Figure 1 1 is a schematic diagram of an exemplary combined cycle power plant 100. In the exemplary embodiment, the power plant 100 includes a gas turbine assembly 102 and a steam turbine 104. The gas turbine assembly 102 includes a compressor 106, a combustor 108, and a turbine 110 coupled together in a series flow relationship. In operation, the combustor 108 receives air from the compressor 106 and receives fuel from the fuel supply, and mixes the fuel and air to form a fuel-air mixture, which is combusted to generate combustion gases. The combustion gases are directed through the turbine 110 and discharged from the turbine 110 as a first exhaust gas stream 112. In the exemplary embodiment, the power plant 100 also includes a steam cycle arrangement, which includes a heat recovery steam generator (HRSG) 114 and the steam turbine 104. In some embodiments, the steam cycle arrangement may also include other components, including a condenser 116 and at least one condensate pump 117.

[0012] In an exemplary embodiment, the HRSG 114 includes an inlet 118 that receives a first exhaust gas stream 112 from the gas turbine assembly 102. Heat is extracted from the first exhaust gas stream 112, and a second exhaust gas stream 120 is discharged from a first outlet 122. The temperature of the second exhaust gas stream 120 is lower than the temperature of the first exhaust gas stream 112 entering the inlet 118. The HRSG 114 also includes a second outlet 124 that discharges a first steam stream 126. The steam turbine 104 receives the first steam stream 126 and then discharges an interstage steam extraction stream 128 therefrom. Any steam that is not extracted with the stream 128 continues to expand until it condenses in the condenser 116. In some embodiments, the steam turbine 104 may include an additional steam intake from the HRSG 114. In an exemplary embodiment, both the gas turbine assembly 102 and the steam turbine 104 are coupled to a generator 132 that generates electricity using a working fluid flowing through each. Alternatively, the turbine assembly 102 and the steam turbine 104 may be on separate shafts, each of which is coupled to a separate generator.

[0013] In an exemplary embodiment, the power plant 100 also includes a carbon capture system 134. During operation, the carbon capture system 134 produces a carbon dioxide stream 138. The carbon capture system 134 may include one or more separators, which are used alone or in combination with other separation processes (such as carbon dioxide selective membrane technology, absorption processes, diaphragms, etc.). An exhaust gas stream or carbon-depleted exhaust gas stream 140 can be discharged from the carbon capture system 134 into the surrounding environment. The exhaust gas stream 140 can also be further processed before being discharged to the environment or elsewhere. For example, at least a portion of the carbon dioxide stream 138 can be increased to a supercritical pressure for transportation and / or storage.

[0014] The carbon capture system 134 generally includes an absorber 142, a stripper 144, and a stripper reboiler 146. In operation, the second exhaust gas stream 120 discharged from the HRSG 114 is directed toward the absorber 142. The exhaust gas may be pre-treated to remove particulates and impurities, such as SOx and NOx, before entering the absorber 142. In addition, in the exemplary embodiment, a first cooler 148 is coupled between the HRSG 114 and the carbon capture system 134. Alternatively, the carbon capture system 134 may include at least one boost blower (not shown) to pressurize the flow directed toward the carbon capture system 134. The first cooler 148 may be, but is not limited to, a quench tower. The first cooler 148 cools a portion of the second exhaust gas stream 120 that will be directed toward the carbon capture system 134.

[0015] The solvent 152 rich in carbon dioxide is discharged from the absorber 142 and then directed to the stripper 144 via a pump 154. The solvent 156 lean in carbon dioxide is discharged from the stripper 144 and directed back to the upper part of the absorber 142 via a reboiler 146, a pump 166 and a heat exchanger 158. The absorber 142 can be any typical configuration for providing gas-liquid contact and absorption. For example, the absorber 142 and the stripper 144 can include a variety of internal components, such as trays, packing and / or supports. In one embodiment, the absorber 142 absorbs carbon dioxide via a countercurrent from the exhaust gas entering the absorber 142. The stripper 144 removes carbon dioxide from the solvent 152. The absorber 142 and the stripper 144 can be variably sized based on the amount of carbon dioxide to be removed, and can be variably sized according to various engineering design formulas. In addition, a single stripper 144 can be used for and connected to multiple absorbers 142.

[0016] In an exemplary embodiment, the solvent 152 is preheated with the solvent 156 in a countercurrent heat exchanger 158 and is then directed to the stripper 144. The stripper 144 is a pressurized unit in which carbon dioxide is recovered from the solvent 152. The stripper 144 typically includes a reboiler 146 that receives a portion of the solvent 156 exiting the stripper 144. The reboiler 146 vaporizes the solvent 156 and directs solvent vapor 160 back to the stripper 144 to facilitate enhanced carbon dioxide separation. A single stripper 144 may be coupled to more than one reboiler 146. The reboiler 146 receives steam, such as from the steam turbine 104, via stream 128 to provide a heating function in the reboiler 146.

[0017] The vapor 162 exiting the stripping column 144 is partially condensed in the condenser 136. The condensed portion of the vapor 162 is returned to the stripping column 144 as a reflux stream 164. The reflux stream 164 may be passed through an accumulator (not shown) and a pump (not shown) before entering the stripping column 144. A carbon dioxide stream 138 is removed from the condenser 136 for transport and / or storage after compression.

[0018] In the exemplary embodiment, the compressor 106 includes a compressor inlet 168, a compressor outlet 170, and a compressor extraction outlet 174. The turbine 110 includes a turbine inlet 169, a turbine outlet 171, and a turbine coolant inlet 173. The power plant 100 includes an extraction line 178 coupled between the compressor 106 and the turbine 110. Specifically, the extraction line 178 is coupled between the compressor extraction outlet 174 and the turbine coolant inlet 173. The compressor 106 discharges a compressor extraction flow 180 of pressurized air toward the turbine 110 through the extraction line 178 to cool the turbine 110.

[0019] Figure 2is a schematic diagram of an exemplary combined cycle power plant 200 . Figure 2 The embodiment illustrated in Figure 1 The embodiments illustrated in the examples are as follows, with the differences being noted herein below, therefore, Figure 2 The reference numerals used in Figure 1 The same reference numerals are used in Figure 2 In the exemplary embodiment, the power plant 200 utilizes exhaust gas recirculation with a post-combustion carbon capture system 134. The exhaust gas recirculation flow 202 is drawn downstream from the first cooler 148 and directed toward the ejector 204 (hereinafter referred to as Figure 3 178 . The first cooler 148 may be, but is not limited to, a quench tower. The ejector 204 is located between the compressor 106 and the turbine 110 along the extraction line 178 . Specifically, the ejector 204 is coupled between the compressor extraction outlet 174 and the turbine coolant inlet 173 along the extraction line 178 .

[0020] like Figure 2 and Figure 3 As shown, the ejector 204 includes a first ejector inlet 206, a second ejector inlet 208, and an ejector outlet 210. The first ejector inlet 206 receives the compressor extraction flow 180 discharged from the compressor 106 through the extraction line 178, and the second ejector inlet 208 receives the exhaust gas recirculation flow 202. The ejector 204 compresses the exhaust gas recirculation flow 202 using the pressure of the compressor extraction flow 180, wherein the pressure of the compressor extraction flow 180 is higher than the operating pressure of the exhaust gas recirculation flow 202. The ejector 204 discharges a recovered gas flow 212 from the ejector outlet 210 through the extraction line 178 to facilitate cooling the turbine 110, wherein the pressure of the recovered gas flow 212 is higher than the pressure of the exhaust gas recirculation flow 202 and lower than the pressure of the compressor extraction flow 180.

[0021] like Figure 1 As illustrated, using pressurized air from compressor 106 to cool turbine 110 via extraction line 178 may reduce the output of gas turbine 102, thereby resulting in a reduction in the output of power plant 100. Figure 2As illustrated, providing the exhaust gas recirculation flow 202 to the ejector 204 facilitates increasing the output of the gas turbine 110 by reducing the amount of pressurized air from the compressor 106 required to cool the turbine 102. The exemplary power plant 200 may include a controller 214 for dynamically adjusting the operation of the power plant 200. For example, the controller 214 may determine the power consumption generated by the compressor 106 discharging the compressor extraction flow 180 toward the turbine 110 through the extraction line 178. Therefore, in one embodiment, the flow of the exhaust gas recirculation flow 202 is adjusted by the controller 214 to facilitate increasing the output of the power plant 200. That is, as described herein, the controller 214 may selectively adjust the flow of the exhaust gas recirculation flow 202 drawn downstream from the first cooler 148 to facilitate increasing the output of the power plant 200. The controller 214 facilitates extending the service life of various components within the power plant 200. Therefore, the flow adjustment provides options for the operator of the power plant 200 to use when determining how to optimize the performance and life consumption of the gas turbine 102.

[0022] Ejector 204 may facilitate improved combustion stability of power plant 200. Directing exhaust gas recirculation flow 202 to ejector 204 may facilitate increasing the oxygen concentration and reducing the carbon dioxide concentration of air received by combustor 108 from compressor 106, compared to exhaust gas recirculation flow 202 received by compressor 106 (not shown). That is, combustion stability of combustor 108 may be improved by bypassing combustor 108 and directing exhaust gas recirculation flow 202 toward turbine 110 through extraction line 178.

[0023] Figure 4 is a schematic diagram of an alternative combined cycle power plant 200 . Figure 4 The alternative embodiment illustrated in Figure 2 The embodiments illustrated in the examples are as follows, with the differences noted below, therefore, Figure 4 The reference numerals used in Figure 2 The same reference numerals are used in Figure 4, the power plant 200 utilizes an exhaust gas recirculation 202 with a post-combustion carbon capture system 134. The exhaust gas recirculation flow 202 is drawn downstream from the first cooler 148, and a first portion 402 of the exhaust gas recirculation flow 202 is directed toward the ejector 204. A second portion 404 of the exhaust gas recirculation flow 202 is directed toward the compressor 106. A boost blower 406 is coupled between the cooler 148 and the compressor 106. The boost blower 406 receives the second portion 404 of the exhaust gas recirculation flow 202 and discharges a pressurized cooling flow 408 toward the compressor 106. The compressor 106 receives the cooling flow 408 at the compressor inlet 168. Both the cooling flow 408 and the first portion 402 of the exhaust gas recirculation flow 202 improve the performance of the power plant 200 by increasing the CO2 concentration in the second exhaust gas flow 120. Stream 128 is extracted via interstage steam to carbon capture system 134, which reduces both size, cost, and reboiler steam requirements.

[0024] The above description is intended to be exemplary only, and those skilled in the art will recognize that changes may be made to the described embodiments without departing from the scope of the disclosed invention. Modifications falling within the scope of the invention will be apparent to those skilled in the art in view of a review of the present disclosure, and such modifications are intended to fall within the appended claims. The systems and methods described herein are not limited to the specific embodiments described herein, but rather the components of the various systems may be utilized independently and separately from other systems and components described herein. For example, an exhaust gas recirculation injector may be implemented and utilized in conjunction with any application where enhanced output is desired.

[0025] Although specific features of various embodiments of the present invention may be shown in some drawings and not in others, this is for convenience only. In addition, reference to "one embodiment" in the above description is not intended to be interpreted as excluding the existence of additional embodiments that also include the described features. In accordance with the principles of the present invention, any feature of a drawing may be referenced and / or claimed in conjunction with any feature of any other drawing.

[0026] Further aspects of the invention are provided by the subject matter of the following clauses:

[0027] 1. A combined cycle power plant, comprising: a gas turbine engine, the gas turbine engine comprising: a compressor; a turbine, the turbine being configured to discharge a first exhaust gas stream therefrom; a heat recovery steam generator, the heat recovery steam generator being configured to: receive the first exhaust gas stream therein; extract heat from the first exhaust gas stream; and

[0028] a second exhaust gas stream discharged therefrom; a cooler configured to cool the second exhaust gas stream to form a cooled exhaust gas stream, wherein the cooler discharges the cooled exhaust gas stream; and an exhaust gas recirculation line configured to direct a first portion of the cooled exhaust gas stream toward an ejector, wherein the ejector is configured to: receive a compressor extract flow from the compressor; receive the first portion of the cooled exhaust gas stream; compress the first portion of the cooled exhaust gas stream using the compressor extract flow; and discharge a recovered gas stream to the turbine.

[0029] 2. The combined cycle power plant according to claim 1 further comprises: a heat recovery steam generator configured to discharge a steam flow; a steam turbine configured to: receive the steam flow therein; and discharge a steam extraction flow; a carbon capture system configured to receive the steam extraction flow; and a controller configured to adjust the flow of the cooled exhaust gas flow recirculated toward the ejector to facilitate increasing the output of the combined cycle power plant.

[0030] 3. A combined cycle power plant according to claim 2, wherein the controller is further configured to: determine the power consumption generated by discharging the compressor extraction flow from the compressor; and adjust the flow rate of the cooling exhaust gas flow recirculated toward the ejector to facilitate increasing the output of the combined cycle power plant.

[0031] 4. The combined cycle power plant of claim 2, wherein the controller is further configured to: monitor the temperature of the turbine; and adjust the flow rate of the cooling exhaust gas flow recirculated toward the ejector to facilitate component life consumption management of the gas turbine engine.

[0032] 5. The combined cycle power plant of claim 1 , wherein the compressor extraction flow has a first pressure measurement, the cooling exhaust gas flow has a second pressure measurement, and the recovered gas flow has a third pressure measurement, wherein the second pressure measurement is lower than the first pressure measurement, and the third pressure measurement is lower than the first pressure measurement and higher than the second pressure measurement.

[0033] 6. The combined cycle power plant of claim 2, further comprising the carbon capture system configured to receive the second portion of the cooling exhaust gas flow.

[0034] 7 . The combined cycle power plant of claim 1 , further comprising a second exhaust gas recirculation line configured to direct a third portion of the cooled exhaust gas flow toward the compressor.

[0035] 8. The combined cycle power plant of claim 7, further comprising an exhaust boost blower configured to direct the third portion of the cooling exhaust gas flow toward the compressor.

[0036] 9. A combined cycle power plant, comprising: a gas turbine engine, the gas turbine engine comprising: a compressor; a turbine, the turbine being configured to discharge a first exhaust gas stream therefrom; a heat recovery steam generator, the heat recovery steam generator being configured to: receive the first exhaust gas stream therein; extract heat from the first exhaust gas stream; and

[0037] a second exhaust gas stream and a steam stream discharged therefrom; a cooler configured to cool the second exhaust gas stream to form a cooled exhaust gas stream, wherein the cooler discharges the cooled exhaust gas stream; an exhaust gas recirculation line configured to direct a first portion of the cooled exhaust gas stream toward an ejector, wherein the ejector is configured to: receive a compressor extract stream from the compressor; receive the first portion of the cooled exhaust gas stream; compress the first portion of the cooled exhaust gas stream using the compressor extract stream; and discharge a recovered gas stream to the turbine; a steam turbine configured to: receive the steam stream therein; and

[0038] a discharge steam extraction stream; and a carbon capture system configured to receive the steam extraction stream.

[0039] 10. The combined cycle power plant of claim 9, further comprising a controller configured to: determine power consumption resulting from discharging the compressor extract flow from the compressor; and regulate the flow of the cooled exhaust gas flow recirculated toward the ejector to facilitate increasing the output of the combined cycle power plant.

[0040] 11. The combined cycle power plant of claim 10, wherein the controller is further configured to: monitor a temperature of the turbine; and adjust the flow of the cooling exhaust gas stream recirculated toward the ejector to facilitate component life consumption management of the gas turbine engine.

[0041] 12. The combined cycle power plant of claim 9, further comprising the carbon capture system configured to receive the second portion of the cooling exhaust gas flow.

[0042] 13. A combined cycle power plant according to claim 9, wherein the compressor extraction flow has a first pressure measurement value, the cooling exhaust gas flow has a second pressure measurement value, and the recovered gas flow has a third pressure measurement value, wherein the second pressure measurement value is lower than the first pressure measurement value, and the third pressure measurement value is lower than the first pressure measurement value and higher than the second pressure measurement value.

[0043] 14. The combined cycle power plant of claim 9, further comprising a second exhaust gas recirculation line configured to direct a third portion of the cooled exhaust gas flow toward the compressor.

[0044] 15. The combined cycle power plant of claim 14, further comprising an exhaust boost blower configured to direct the third portion of the cooling exhaust gas flow toward the compressor.

[0045] While the invention has been described in terms of various specific embodiments, those skilled in the art will recognize that the invention can be practiced with modification within the spirit and scope of the claims.

Claims

1. A combined cycle power plant, comprising: A gas turbine engine, the gas turbine engine comprising: compressor; a turbine configured to discharge a first exhaust gas stream therefrom; A heat recovery steam generator, the heat recovery steam generator being configured to: receiving said first exhaust gas stream therein; extracting heat from said first exhaust gas stream; and discharging a second exhaust gas stream therefrom; a cooler configured to cool the second exhaust gas stream to form a cooled exhaust gas stream, wherein the cooler discharges the cooled exhaust gas stream; and an exhaust gas recirculation line configured to direct a first portion of the cooled exhaust gas flow toward an ejector, wherein the ejector is configured to: receiving a compressor extract stream from the compressor; receiving said first portion of said cooled exhaust gas stream; compressing the first portion of the cooled exhaust gas stream using the compressor extract stream; and The recovered air flow is discharged to the turbine.

2. The combined cycle power plant according to claim 1, further comprising: the heat recovery steam generator, the heat recovery steam generator being configured to discharge a steam flow; A steam turbine, the steam turbine being configured to: receiving the steam flow therein; and exhausting a steam extraction stream; a carbon capture system configured to receive the steam extraction stream; and A controller is configured to adjust the flow of the cooled exhaust gas stream recirculated toward the ejector to facilitate increasing the output of the combined cycle power plant.

3. The combined cycle power plant of claim 2, wherein the controller is further configured to: determining power consumption resulting from discharging the compressor extract stream from the compressor; and The flow of the cooled exhaust gas stream recirculated toward the ejector is adjusted to facilitate increasing the output of the combined cycle power plant.

4. The combined cycle power plant of claim 2, wherein the controller is further configured to: monitoring a temperature of the turbine; and The flow rate of the cooling exhaust gas stream recirculated toward the ejector is adjusted to facilitate component life consumption management of the gas turbine engine.

5. The combined cycle power plant of claim 1 , wherein the compressor extraction flow has a first pressure measurement, the cooling exhaust gas flow has a second pressure measurement, and the recovered gas flow has a third pressure measurement, wherein the second pressure measurement is lower than the first pressure measurement, and the third pressure measurement is lower than the first pressure measurement and higher than the second pressure measurement.

6. The combined cycle power plant of claim 2, further comprising the carbon capture system configured to receive the second portion of the cooling exhaust gas flow. 7 . The combined cycle power plant of claim 1 , further comprising a second exhaust gas recirculation line configured to direct a third portion of the cooled exhaust gas flow toward the compressor.

8. The combined cycle power plant of claim 7, further comprising an exhaust boost blower configured to direct the third portion of the cooling exhaust gas flow toward the compressor.

9. A combined cycle power plant, comprising: A gas turbine engine, the gas turbine engine comprising: compressor; a turbine configured to discharge a first exhaust gas stream therefrom; A heat recovery steam generator, the heat recovery steam generator being configured to: receiving said first exhaust gas stream therein; extracting heat from said first exhaust gas stream; and discharging a second waste gas stream and a steam stream therefrom; a cooler configured to cool the second exhaust gas stream to form a cooled exhaust gas stream, wherein the cooler discharges the cooled exhaust gas stream; an exhaust gas recirculation line configured to direct a first portion of the cooled exhaust gas flow toward an ejector, wherein the ejector is configured to: receiving a compressor extract stream from the compressor; receiving said first portion of said cooled exhaust gas stream; compressing the first portion of the cooled exhaust gas stream using the compressor extract stream; and discharging the recovered airflow to the turbine; A steam turbine, the steam turbine being configured to: receiving the steam flow therein; and exhausting a steam extraction stream; and A carbon capture system is configured to receive the steam extraction stream.

10. The combined cycle power plant according to claim 9, further comprising a controller, wherein the controller is configured to: determining power consumption resulting from discharging the compressor extract stream from the compressor; and The flow of the cooled exhaust gas stream recirculated toward the ejector is adjusted to facilitate increasing the output of the combined cycle power plant.

11. The combined cycle power plant of claim 10, wherein the controller is further configured to: monitoring a temperature of the turbine; and The flow rate of the cooling exhaust gas stream recirculated toward the ejector is adjusted to facilitate component life consumption management of the gas turbine engine.

12. The combined cycle power plant of claim 9, further comprising the carbon capture system configured to receive the second portion of the cooling exhaust gas flow.

13. A combined cycle power plant according to claim 9, wherein the compressor extraction flow has a first pressure measurement value, the cooling exhaust gas flow has a second pressure measurement value, and the recovered gas flow has a third pressure measurement value, wherein the second pressure measurement value is lower than the first pressure measurement value, and the third pressure measurement value is lower than the first pressure measurement value and higher than the second pressure measurement value.

14. The combined cycle power plant of claim 9, further comprising a second exhaust gas recirculation line configured to direct a third portion of the cooled exhaust gas flow toward the compressor.

15. The combined cycle power plant of claim 14, further comprising an exhaust boost blower configured to direct the third portion of the cooling exhaust gas flow toward the compressor.

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