System and method having flame stabilizer for isothermal expansion in a turbine stage of a gas turbine engine

Abstract

The system includes a gas turbine having a turbine shaft disposed along a rotational axis, a turbine casing disposed circumferentially about the turbine shaft, a combustion gas path disposed between the turbine shaft and the turbine casing, and a turbine stage disposed in the combustion gas path. The turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The gas turbine includes an isothermal expansion system coupled to the turbine stages, the isothermal expansion system including a plurality of flame stabilizers configured to vary an axial position of combustion within the turbine stage expansion of the turbine stages to reduce temperature variations across the expansion of the turbine stages. The flame stabilizers are disposed at different axial positions along an axial length between the leading edge and the trailing edge of the turbine blades, at least one flame stabilizer being coupled to each of the turbine blades.

Description

[Technical Field]

[0001] The subject matter disclosed herein relates to gas turbine engines, and more particularly to systems and methods for improving efficiency through isothermal expansion of turbine stages. [Background technology]

[0002] A gas turbine engine may include a compressor, a combustor, and a turbine driven by combustion gases from the combustor. The turbine may include one or more turbine stages, each having a plurality of turbine blades. The combustion gas flow expands through the turbine and drives the rotation of the turbine blades in each of the one or more turbine stages. Unfortunately, unlike the Carnot cycle, the combustion gas flow generally changes temperature during expansion through each of the one or more turbine stages. Therefore, there is a need for isothermal expansion through each of the one or more stages. [Prior art documents] [Patent documents]

[0003] [Patent Document 1] U.S. Patent Application Publication No. 2006-0026962 Summary of the Invention

[0004] Certain embodiments commensurate in scope with the initially claimed subject matter are summarized below. These embodiments are not intended to limit the scope of the claimed embodiments; rather, these embodiments are intended only to provide a brief summary of possible forms of the present subject matter. Indeed, the embodiments claimed herein may include a variety of forms that may be similar to or different from the embodiments set forth below.

[0005] The system includes a gas turbine having a turbine shaft disposed along a rotational axis, a turbine casing disposed circumferentially about the turbine shaft, a combustion gas path disposed between the turbine shaft and the turbine casing, and a turbine stage disposed in the combustion gas path. The turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The gas turbine includes an isothermal expansion system coupled to the turbine stage, the isothermal expansion system further including a plurality of flame stabilizers configured to vary an axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature variations across the expansion of the turbine stage. The plurality of flame stabilizers are disposed at different axial positions along an axial length between leading edges and trailing edges of the plurality of turbine blades, and at least one of the plurality of flame stabilizers is coupled to each of the turbine blades.

[0006] The method includes routing combustion gases through turbine stages along a combustion gas path disposed between a turbine shaft and a turbine casing of a gas turbine. The turbine shaft is disposed along a rotational axis, the turbine casing is disposed circumferentially about the turbine shaft, and the turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The method includes varying an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature fluctuations across the expansion of the turbine stage via a plurality of flame stabilizers of an isothermal expansion system coupled to the turbine stage. The plurality of flame stabilizers are disposed at different axial positions across an axial length between leading edges and trailing edges of the plurality of turbine blades, and at least one of the plurality of flame stabilizers is coupled to each of the turbine blades.

[0007] The system includes a controller having a processor, a memory, and instructions stored in the memory and executable by the processor, the controller controlling combustion in a combustor to generate a combustion gas flow through a turbine stage along a combustion gas path disposed between a turbine shaft and a turbine casing of a gas turbine. The turbine shaft is disposed along a rotational axis, the turbine casing is disposed circumferentially about the turbine shaft, and the turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The controller is further configured to control an isothermal expansion system coupled to the turbine stage to vary an axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature fluctuations across the turbine stage expansion. The isothermal expansion system includes a plurality of flame stabilizers disposed at different axial positions along an axial length between leading edges and trailing edges of the plurality of turbine blades, at least one of the plurality of flame stabilizers coupled to each of the turbine blades.

[0008] These and other features, aspects, and advantages of the presently disclosed technology will be better understood from the following detailed description when taken in conjunction with the accompanying drawings, in which like reference numerals represent like parts throughout the drawings. [Brief explanation of the drawings]

[0009] [Figure 1] 1 is a block diagram of an embodiment of a combined cycle system having a gas turbine system, a steam turbine system, a heat recovery steam generation (HRSG) system, and an isothermal expansion system in the turbine stages. [Figure 2] 2 is a schematic diagram of an embodiment of a portion of the turbine section of the gas turbine system of FIG. 1 further illustrating details of an isothermal expansion system having a variable injection system with fluid injectors and a variable stabilizer system with flame stabilizers. [Figure 3]2 is a schematic diagram of an embodiment of a portion of the turbine section of the gas turbine system of FIG. 1, further illustrating details of the isothermal expansion system. [Figure 4] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at a trailing edge portion of the vane at an axial distance from the leading edge of the vane. [Figure 5] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at an axial distance from the leading edge of the vane at an intermediate portion of the vane. [Figure 6] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at a leading edge portion of the vane at an axial distance from the leading edge of the vane. [Figure 7] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at a trailing edge portion of the vane at a variable axial distance from the leading edge of the vane. [Figure 8] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at a mid-portion of the vane at a variable axial distance from the leading edge of the vane. [Figure 9] FIG. 4 is a perspective view of one embodiment of a vane of the turbine section of FIGS. 1-3, further illustrating a fluid injector at a leading edge portion of the vane at a variable axial distance from the leading edge of the vane. [Figure 10] 4 is a perspective view of a vane of the turbine section of FIGS. 1-3, the fluid injectors having different cross-sectional areas. FIG. [Figure 11] 4 is a perspective view of a vane of the turbine section of FIGS. 1-3, the fluid injectors having different cross-sectional areas. FIG. [Figure 12] 4 is a perspective view of a vane of the turbine section of FIGS. 1-3, the fluid injectors having different cross-sectional areas. FIG. [Figure 13] FIG. 13 is a schematic diagram of an embodiment of the isothermal expansion system of FIGS. 1-12, further illustrating an embodiment of the fluid injector as a multi-fluid injector. [Figure 14] FIG. 14 is a cross-sectional view of the multi-fluid injector of FIG. 13 taken along line 14-14, further illustrating the flow passages and wall configuration of the multi-fluid injector. [Figure 15] FIG. 13 is a cross-sectional view of an embodiment of one of the fluid injectors of FIGS. 1-12, further illustrating a fluid passage having a converging-diverging passage geometry. [Figure 16] FIG. 13 is a cross-sectional view of an embodiment of one of the fluid injectors of FIGS. 1-12, further illustrating a fluid passage having a converging passage shape. [Figure 17] FIG. 15 is a cross-sectional view of the multi-fluid injector of FIGS. 13 and 14, further illustrating the converging passage geometry of the fluid passages. [Figure 18] FIG. 18 is a cross-sectional view of one embodiment of the fluid injector of FIGS. 1-17, further illustrating that the fluid injection axis or direction angle is approximately 90 degrees. [Figure 19] FIG. 18 is a cross-sectional view of one embodiment of the fluid injector of FIGS. 1-17, further illustrating the acute angle of the fluid injection axis or direction. [Figure 20] 19 is a cross-sectional view of one embodiment of the fluid injector of FIGS. 1-17, further illustrating that the angle of the fluid injection axis or direction is an acute angle less than the acute angle of FIG. [Figure 21] FIG. 4 is a perspective view of one embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at a leading edge portion of the blade at an axial distance from the leading edge of the blade. [Figure 22] FIG. 4 is a perspective view of one embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at an axial distance from the leading edge of the blade at an intermediate portion of the blade. [Figure 23] FIG. 4 is a perspective view of an embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at a trailing edge portion of the blade at an axial distance from the leading edge of the blade. [Figure 24] FIG. 4 is a perspective view of an embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at a leading edge portion of the blade at a variable axial distance from the leading edge of the blade. [Figure 25] FIG. 4 is a perspective view of an embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at a variable axial distance from the leading edge of the blade at an intermediate portion of the blade. [Figure 26] FIG. 4 is a perspective view of an embodiment of a blade of the turbine section of FIGS. 1-3, further illustrating a flame stabilizer at a trailing edge portion of the blade at a variable axial distance from the leading edge of the blade. [Figure 27] FIG. 27 is a top view of one embodiment of the flame stabilizer of FIGS. 1-3 and 21-26, further illustrating details of a protrusion disposed within the recess, the protrusion having a curved or C-shaped geometry. [Figure 28] 28 is a cross-sectional view of one embodiment of the flame stabilizer of FIG. 27, further illustrating details of the protrusions and recesses, including variable height of the protrusions. [Figure 29] FIG. 27 is a top view of one embodiment of the flame stabilizer of FIGS. 1-3 and 21-26, further illustrating details of a protrusion disposed within the recess, the protrusion having curved or arcuate walls. [Figure 30] 30 is a cross-sectional view of one embodiment of the flame stabilizer of FIG. 29, further illustrating details of the protrusions and recesses, including variable height of the protrusions. [Figure 31] FIG. 27 is a top view of one embodiment of the flame stabilizer of FIGS. 1-3 and 21-26, further illustrating details of a protrusion disposed within the recess, the protrusion having a rectangular shape. [Figure 32] 32 is a cross-sectional view of one embodiment of the flame stabilizer of FIG. 31, further illustrating details of the protrusions and recesses, including variable height of the protrusions. [Figure 33] 33 is a flow chart of one embodiment of a process for operating a gas turbine system using the variable injection system of the isothermal expansion system 18 of FIGS. [Figure 34] 34 is a flow chart of one embodiment of a process for operating a gas turbine system using the variable injection system of the isothermal expansion system 18 of FIGS. DETAILED DESCRIPTION OF THE INVENTION

[0010] The following describes one or more specific embodiments of the systems and methods of the present disclosure. While an effort is made to provide a concise description of these embodiments, not all features of an actual implementation may be described herein. It is understood that in developing an actual implementation, such as an engineering or design project, many implementation-specific decisions must be made to achieve the developer's particular objectives, including, for example, adherence to system-related and business-related constraints, and that these constraints may vary from implementation to implementation. It is further understood that such a development effort may be complex and time-consuming, but would nevertheless be a routine undertaking of design, fabrication, and manufacture for those skilled in the art having the benefit of this disclosure.

[0011] When introducing elements of various embodiments of the presently disclosed embodiments, the words "a," "an," "the," and "said" are intended to mean that there are one or more of the elements. The terms "comprising," "including," and "having" are intended to be inclusive and mean that there may be additional elements other than the listed elements.

[0012] The disclosed embodiments are configured to provide isothermal expansion (e.g., expansion at a constant temperature) for turbine stages of a gas turbine system by controlling (e.g., varying and / or distributing) the heat release of combustion across the rotating blades in the turbine stage expansion of the turbine stage. While isothermal expansion contemplates expanding combustion gases at a constant temperature, the disclosed embodiments may also allow for some temperature fluctuations with substantially isothermal expansion. The heat release of combustion is controlled by at least a variable injection system having fluid injectors on stationary vanes upstream of the rotating blades, a variable stabilizer system having flame stabilizers on the rotating blades, or a combination thereof. The fluid injectors and flame stabilizers are configured to distribute the heat release of combustion (e.g., via axial positioning of the flame) along the rotating blades over an axial range between the leading and trailing edges of the rotating blades in the turbine stage expansion, where the axial range can vary between the entire axial distance and a partial axial distance between the leading and trailing edges. The fluid injectors may be fuel injectors or multi-fluid injectors that deliver fuel, oxidant, and another fluid as a barrier gas.

[0013] The variable injection system may passively and / or actively control the axial location of the heat release of combustion through the fluid injectors on the stationary vanes and across the rotating blades in the turbine stage expansion. For example, the variable injection system may passively control the axial location of the heat release of combustion through the fluid injectors on the stationary vanes and across the rotating blades in the turbine stage expansion by using different mounting locations (e.g., axial and radial locations) of the fluid injectors, different geometries of the fluid ports, different cross-sectional areas of the fluid ports, different angles of fluid injection, or other characteristics that are not controlled during operation.

[0014] As a further example, a variable injection system can actively control the axial location of the heat release of combustion across the rotating blades in a turbine stage expansion via fluid injectors on stationary vanes by using control of fluid flow (e.g., fuel flow, oxidant flow, and / or barrier fluid flow) through the fluid injectors. The variable injection system can include multiple fluid circuits (e.g., fuel circuits, oxidant circuits, and / or barrier fluid circuits) independently coupled to multiple different fluid injectors on the same or different stationary vanes. Thus, the variable injection system can vary fluid pressure, flow rate, or other fluid characteristics to vary the downstream axial distance the fuel travels to mix and combust along the rotating blades. In certain embodiments, the variable injection system can combine active and passive control to vary the downstream axial distance the fuel travels to mix and combust along the rotating blades in a turbine stage expansion.

[0015] The variable injection system may also be actively controlled using, for example, multiple fluid circuits and flow control valves to adjust the axial location of the heat of combustion within the turbine stage expansion depending on the operating conditions of the gas turbine system (e.g., full load vs. part load conditions). In response to a decrease in load, the variable injection system may selectively move the axial location of the heat of combustion further upstream from the trailing edge of the rotating blades and / or, via control of fluid flow through the fluid injectors, may move the axial location of the heat of combustion further downstream toward the trailing edge of the rotating blades. For example, the variable injection system may selectively vary the flow of fluid through different fluid circuits (e.g., fuel circuits) coupled to different fluid injectors at different axial locations along the stationary vanes.

[0016] As load decreases, the variable injection system may selectively decrease or stop fluid flow (e.g., fuel flow) through the fluid circuit to the fluid injector located downstream along the stationary vane, while maintaining fluid flow (e.g., fuel flow) through the fluid circuit to the fluid injector located upstream along the stationary vane. As load increases, the variable injection system may selectively increase or start fluid flow (e.g., fuel flow) through the fluid circuit to the fluid injector located downstream along the stationary vane, while maintaining fluid flow (e.g., fuel flow) through the fluid circuit to the fluid injector located upstream along the stationary vane. Thus, the ability to vary the axial location of the heat release of combustion along the rotating blades within the turbine stage expansion enables isothermal expansion of the turbine stage at various operating conditions of the gas turbine system, including both full load and part load conditions.

[0017] A variable stabilizer system having flame stabilizers on rotating blades can passively control the axial location of the heat release of combustion across the rotating blades within a turbine stage expansion through differences in the flame stabilizers, such as different mounting locations (e.g., axial and radial locations) of the turbine stages, different geometries, different cross-sectional areas, and / or different dimensions, from one flame stabilizer to another in the turbine stages, and / or from one rotating blade to another. For example, flame stabilizers can be mounted on multiple rotating blades at axial locations that vary in multiple incremental axial increments from the leading edge to the trailing edge. The flame stabilizers may be fixed or stationary relative to the rotating blades.

[0018] The following description generally presents various embodiments of an isothermal expansion system for a turbine stage to help improve the efficiency of a gas turbine system. The isothermal expansion system may include any and all combinations of the disclosed features, including variations of variable injection systems and variable stabilizer systems. While reference is made to an isothermal expansion system, the disclosed embodiments are intended to include substantially isothermal expansion through a turbine stage within a turbine stage expansion.

[0019] 1 is a block diagram of an embodiment of a combined cycle system 10 having a gas turbine system 12, a steam turbine system 14, and a heat recovery steam generator (HRSG) 16. As described in further detail below, the combined cycle system 10 includes an isothermal expansion system 18 coupled to the gas turbine system 12 to facilitate isothermal expansion within the turbine stages. Before discussing the details of the isothermal expansion system 18, various aspects of the combined cycle system 10 will be discussed in more detail. For purposes of orientation in the drawings, reference may be made to an axial direction or axis 30, a radial direction or axis 32 extending radially away from the axial direction or axis 30, and a circumferential direction or axis 34 extending circumferentially around the axial direction or axis 30. The directions or axes 30, 32, and 34 may be referenced, for example, to an axis of rotation 36 of the gas turbine system 12.

[0020] The gas turbine system 12 may include an intake section 40, a compressor or compressor section 42, a combustor section 44, a gas turbine or turbine section 46, and an exhaust section 48. The compressor section 42 may include at least one shaft 50 disposed along the rotational axis 36, a casing 52 (e.g., an annular casing) disposed circumferentially about the at least one shaft 50, a plurality of rotating compressor blades 54 extending radially outward from the at least one shaft 50, and a plurality of stationary compressor vanes 56 extending radially inward from the casing 52 toward the at least one shaft 50. In the illustrated embodiment, the compressor section 42 may include multiple compressor stages 58, each having a plurality of compressor vanes 56 spaced circumferentially about the at least one shaft 50 at an axial location and a plurality of compressor blades 54 spaced circumferentially about the at least one shaft 50 at different axial locations (i.e., the compressor vanes 56 and compressor blades 54 are axially spaced apart). Thus, the compressor section 42 is configured to intake a gas flow from the intake section 40 and progressively compress the gas flow through the multiple compressor stages 58. As discussed in more detail below, the gas flow may include an intake air flow, an exhaust gas recirculation (EGR) flow, or a combination thereof.

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

[0022] In certain embodiments, each combustor 62 may receive one or more fluid streams from a fluid system 88, which may include a fuel supply system 90, an oxidizer supply system 92, and a fluid supply system 94. The fluid system 88 may include one or more fluid circuits 96 (e.g., fluid conduits, manifolds, valves, etc.) extending to the multiple fuel nozzles 82 and / or other locations along the combustor 62. For example, the fuel supply system 90 is configured to supply one or more fuels, such as liquid and / or gaseous fuels, to each of the fuel nozzles 82 for injection into the combustion chamber 68. The fuel may include natural gas, syngas produced from a gasifier, methane, hydrogen, biofuel, fuel oil, or any combination thereof. The oxidizer supply system 92 is configured to supply one or more oxidizers, such as air, oxygen, oxygen-rich air, or oxygen-lean air, to each fuel nozzle 82 for injection into the combustion chamber 68. Fluid supply system 94 is configured to inject one or more fluids, such as exhaust gases, carbon dioxide, an inert gas such as nitrogen, or any combination thereof, into fuel nozzles 82 for injection into combustion chamber 68. In certain embodiments, fluid system 88 may exclude oxidant supply system 92 and / or fluid supply system 94.

[0023] Fluid system 88 may include multiple components for controlling the flow of various fluids to combustor 62. For example, fuel supply system 90 may include one or more components 98, oxidant supply system 92 may include one or more components 100, and fluid supply system 94 may include one or more components 102. In certain embodiments, components 98, 100, and 102 may include one or more valves, pressure regulators, flow regulators, filters, water removal units, particulate removal units, manifolds, flow controllers, or any combination thereof.

[0024] The fuel nozzles 82 are configured to inject one or more fuels from a fuel supply system 90, an oxidizer from an oxidizer supply system 92, a fluid from a fluid supply system 94, and compressed gas 86 from the compressor section 42. In a particular embodiment, the fuel nozzles 82 are configured to inject compressed air 104 from a compressor system 106 having an air compressor 108 coupled to a drive device 110, such as an electric motor, a combustion engine, a shaft coupled to the gas turbine system 12, or another suitable drive device. For example, in a particular embodiment of a gas turbine system 12 with exhaust gas recirculation (EGR), the compressor section 42 supplies the compressed gas 86 (e.g., compressed exhaust gas) to each combustor 62, the compressor system 106 supplies the compressed air 104 to each combustor 62, and / or the oxidizer supply system 92 supplies the oxidizer to each combustor 62.

[0025] As a further example, in certain embodiments of the gas turbine system 12 without exhaust gas recirculation (EGR), the compressor section 42 supplies compressed gas 86 (e.g., compressed air) to each combustor 62 without requiring an additional air and / or oxidant supply. Accordingly, the compressor system 106 may optionally supply compressed air 104 to each combustor 62, and / or the oxidant supply system 92 may optionally supply oxidant to each combustor 62. During operation, fuel may be combusted with air and / or oxidant in the combustion chamber 68 of each combustor 62, thereby generating hot combustion gases 112 for delivery from the combustion chamber 68 to the turbine section 46.

[0026] The turbine section 46 may include at least one shaft 114 disposed along the rotational axis 36, a casing 116 (e.g., an annular casing) disposed circumferentially about the at least one shaft 114, a plurality of rotating turbine blades 118 extending radially outward from the at least one shaft 114, and a plurality of stationary turbine vanes 120 extending radially inward from the casing 116 toward the at least one shaft 114. In the illustrated embodiment, the turbine section 46 may include a plurality of turbine stages 122, each of which may include a plurality of turbine vanes 120 spaced circumferentially about the at least one shaft 114 at an axial location and a plurality of turbine blades 118 spaced circumferentially about the at least one shaft 114 at different axial locations (i.e., the turbine vanes 120 and turbine blades 118 are axially spaced apart). The at least one shaft 114 may also be coupled to at least one shaft 50 of the compressor section 42 via at least one intermediate shaft 124. Additionally, the at least one shaft 114 may be coupled to a load 126 via a shaft 128. In certain embodiments, the load 126 may include an electrical generator, a machine, a vehicle propulsion system, or any other suitable load. In the illustrated embodiment, the load 126 may be an electrical generator, such that the combined cycle system 10 is a combined cycle power plant. During operation, the combustion gases 112 flow from the combustor 62 to the turbine section 46, where the combustion gases 112 gradually expand and drive the rotation of turbine blades 118 coupled to the at least one shaft 114 in each of the turbine stages 122. Thus, the combustion gases 112 drive the turbine section 46, which in turn drives the compressor section 42 and the load 126 via the interconnected shafts 50, 124, 114, 128.

[0027] In certain embodiments, the gas turbine system 12 may be configured with shafts 50, 114, 124, and 128 and a common rotational direction with the connected compressor blades 54 and turbine blades 118. The shafts 50, 114, 124, and 128 may be removably coupled with shaft connections, such as flange joints. In some embodiments, some of the shafts may be combined to reduce the number of shafts. For example, all of the illustrated shafts 50, 114, and 124 may represent a common shaft that rotates in a common rotational direction, such as a clockwise or counterclockwise rotational direction.

[0028] Alternatively, in some embodiments, the gas turbine system 12 may be configured for counter-rotation of the compressor blades 54 in the compressor section 42 and / or counter-rotation of the turbine blades 118 in the turbine section 46. In such embodiments, at least one shaft 50 in the compressor section 42 may include a concentric arrangement of an inner shaft 50A surrounded by an outer shaft 50B along at least a portion of the compressor section 42. Similarly, at least one shaft 114 in the turbine section 46 may include a concentric arrangement of an inner shaft 114A surrounded by an outer shaft 114B along at least a portion of the turbine section 46. For example, in the compressor section 42, the inner shaft 50A may be coupled to the compressor blades 54 in a subset 130 of the compressor stages 58, and the outer shaft 50B is coupled to a subset 132 of the compressor stages 58. Similarly, in turbine section 46, inner shaft 114A may be coupled to turbine blades 118 of subset 134 of turbine stages 122, and outer shaft 114B may be coupled to turbine blades 118 of subset 136 of turbine stages 122. For example, the counter-rotating blades in turbine section 46 may include turbine blade set 140 (or turbine stage portion) followed by turbine blade set 142 (or turbine stage portion), with turbine blade sets 140 and 142 coupled to respective outer shaft 114B and inner shaft 114A, respectively.

[0029] The outer shaft 114B of the turbine section 46 is coupled to the outer shaft 50B of the compressor section 42 via the outer shaft 124B of the intermediate shaft 124. Similarly, the inner shaft 114A of the turbine section 46 is coupled to the inner shaft 50A of the compressor section 42 via the inner shaft 124A of the intermediate shaft 124. During operation, the inner shaft 50A and associated compressor blades 54, the inner shaft 124A, and the inner shaft 114A and associated turbine blades 118 (i.e., turbine blade set 142) rotate in a first direction about the axis of rotation 36. The outer shaft 50B and associated compressor blades 54, the outer shaft 124B, and the outer shaft 114B and associated turbine blades 118 (i.e., turbine blade set 140) rotate in a second rotational direction about the axis of rotation 36. The first rotational direction and the second rotational direction are opposite or counter to each other. Although gas turbine system 12 may be configured with counter-rotating compressor and turbine blades 54 and 118, embodiments of gas turbine system 12 may include a single rotational direction of the shaft and associated blades. In embodiments with a single rotational direction of the shaft, turbine blade set 140 may be the only blade set used in the first turbine stage, and turbine blade set 142 may be omitted from the first turbine stage. Counter-rotating blade sets 140, 142 are useful in turbines where the pressure drop across the first turbine stage is high enough to cause excessive loads on a single set of turbine blades. Therefore, the use of two blade sets configured to counter-rotate relative to each other manages the pressure drop.

[0030] The gas turbine system 12 may be configured with or without a compressor system 106 and an exhaust gas recirculation (EGR) system 150. The EGR system 150 is configured to recirculate exhaust gases 152 output by the turbine section 46 to the compressor section 42 (e.g., via the intake section 40) for compression and delivery to the combustor section 44. However, the gas turbine system 12 may eliminate the EGR system 150 and only intake airflow into the intake section 40 for compression by the compressor section 42.

[0031] In certain embodiments of the gas turbine system 12 having the EGR system 150, the recirculated exhaust gas 152 flows through the intake section 40 and each compressor stage 58 of the compressor section 42, thereby compressing the recirculated exhaust gas 152 as compressed gas 86 for delivery to the combustor section 44. Additionally, the combustor section 44 may receive compressed air 104 from an air compressor 108 of the compressor system 106, an oxidizer from an oxidizer supply system 92, or a combination thereof, via fuel nozzles 82. The combustor section 44 also receives fuel from a fuel supply system 90, such as via the fuel nozzles 82. The fuel from the fuel supply system 90 is then combusted with the air from the compressor system 106 and / or the oxidizer from the oxidizer supply system 92 to generate combustion gases 112, which then flow through the turbine section 46 and drive the rotation of the turbine blades 118 of each turbine stage 122. The recirculated exhaust gases may also be used to reduce certain emissions associated with combustion in the combustor section 44, such as nitrogen oxides (NO X )) helps to reduce the temperature and formation of

[0032] In certain embodiments of the gas turbine system 12 without the EGR system 150, the compressor section 42 receives the airflow from the intake section 40, progressively compresses the airflow through the compressor stages 58, and delivers the compressed airflow as compressed gas 86 to the combustor section 44. The compressed airflow then promotes combustion of fuel from the fuel supply system 90, thereby generating hot combustion gases 112 for delivery to the turbine section 46. In such embodiments, the compressor system 106 may be excluded or included to supply additional compressed air 104 to the combustor section 44. Additionally, the oxidizer supply system 92 may be excluded or included to supply an additional oxidizer flow to the combustor section 44. Regardless of the configuration, the combustion gases 112 drive the rotation of turbine blades 118 in the turbine stages 122, thereby rotating at least one shaft 114 coupled to the at least one shaft 50 of the compressor section 42 and a shaft 128 that drives a load 126.

[0033] The exhaust gas 152 output by the turbine section 46 may then pass through the HRSG 16 to transfer heat from the exhaust gas to water to generate steam for the steam turbine system 14. For example, the HRSG 16 may include a high-pressure section 160, an intermediate-pressure section 162, and a low-pressure section 164 in a serial arrangement, thereby generating high-pressure steam 166, intermediate-pressure steam 168, and low-pressure steam 170. The heat recovery steam generator 16 may deliver the high-pressure steam 166 to a high-pressure steam turbine 172, the intermediate-pressure steam 168 to an intermediate-pressure steam turbine 174, and the low-pressure steam 170 to a low-pressure steam turbine 176 of the steam turbine system 14. The steam drives the rotation of blades in each of the steam turbines 172, 174, 176, thereby driving a shaft 178 coupled to a load 180, such as an electrical generator. The low-pressure steam turbine 176 may also return condensate 182 to the low-pressure section 164 of the HRSG 16. The HRSG 16 may then output the exhaust gases 152 as partially cooled exhaust gases 184 , after which the exhaust gases may pass through a gas treatment system 190 .

[0034] Gas processing system 190 may include a carbon capture system 192 and multiple gas processing components, such as components 194, 196, 198, 200, and 202. Gas processing system 190 is configured to remove one or more undesirable substances from exhaust gas 184. In one particular embodiment, carbon capture system 192 removes carbon dioxide (CO), such as carbon dioxide (CO). X ) and / or carbon monoxide (CO). Components 194, 196, 198, 200, and 202 may be part of and / or separate from carbon capture system 192. Components 194, 196, 198, 200, and 202 may include one or more of a gas removal system, a water removal system (e.g., a water-gas separator), a particulate removal system (e.g., a filter and / or a solid-gas separator), one or more heat exchangers, or any combination thereof. The separator may include a gravity separator, a centrifuge, or a combination thereof. The gas removal system may be part of carbon capture system 192 and may include a solvent-based gas absorption system, a sorbent-based gas adsorption system, or a combination thereof. The gas removal system may include an acid gas removal (AGR) system, a sulfur recovery unit, or a combination thereof. In the illustrated embodiment, carbon capture system 192 can capture and output carbon dioxide (CO2) 204, which can be further directed to fluid supply system 94 and / or compression system 206. For example, compression system 206 can include one or more compressors configured to compress the carbon dioxide and deliver the carbon dioxide to storage and / or a pipeline 208.

[0035] In certain embodiments, the exhaust gases 184 may flow to the EGR system 150, partially or completely bypassing the gas treatment system 190, and / or the exhaust gases 184 may flow partially or completely through the gas treatment system 190 before flowing to the EGR system 150. The EGR system 150 may include various conduits, valves, and flow controls configured to provide at least a portion of the exhaust gases 152, 184 (e.g., an EGR stream) to the intake section 40 for recirculation through the compressor section 42. The exhaust gases 152, 184 may be extracted at various locations and used as one of the fluids in the fluid supply system 94, which may provide the exhaust gases 152, 184 for use in the isothermal expansion system 18 as a barrier gas stream, as described in further detail below.

[0036] In certain embodiments, gas turbine system 12 includes an air separation unit (ASU) 210 configured to receive an inlet air stream and separate the air into constituent gases, such as oxygen 212 for supply to oxidant supply system 92 and nitrogen 214 for supply to fluid supply system 94. Oxygen 212 and nitrogen 214 may also be used for other purposes throughout combined cycle system 10. However, in some embodiments, ASU 210 may be excluded from combined cycle system 10.

[0037] In the illustrated embodiment, the combined cycle system 10 also includes a controller 220 coupled to the gas turbine system 12, the steam turbine system 14, the HRSG 16, the isothermal expansion system 18, the gas processing system 190, the fluid system 88, the EGR system 150, the compression system 106, the ASU 210, and various sensors 220 distributed throughout the combined cycle system 10. In the illustrated embodiment, the controller 220 includes one or more processors 224, a memory 226, instructions 228 stored in the memory 226 and executable by the processor 224, and communication circuitry 230 configured to communicate with the sensors 222 and various devices throughout the combined cycle system 10. For example, the controller 222 is configured to control the fluid supply (e.g., fuel, oxidant, and fluid) from the fluid system 88 to the combustor section 44 and the isothermal expansion system 18. In one particular embodiment, the controller 222 is configured to control the fuel supply system, the oxidant supply system, and the fluid supply systems 90, 92, and 94 to control the flow of fuel, oxidant, and fluid (e.g., barrier fluid) to the isothermal expansion system 18 to help provide an isothermal expansion of the combustion gases 112 through the turbine blade sets 140 and / or 142.

[0038] The controller 220 may store one or more control modes (e.g., an isothermal control mode, a part load control mode, a full load control mode, or a combination thereof) on the memory 226 for execution by the processor 224. The isothermal control mode is configured to control the isothermal expansion system 18, including the fluid injectors 246, to provide a variable axial position of combustion to help reduce temperature fluctuations and facilitate isothermal expansion through the turbine blade sets 140 and / or 142. As used herein, the fluid injectors 246 are intended to include fuel injectors and multi-fluid injectors that inject fuel, oxidant, and barrier gas. Thus, references to fluids associated with the fluid injectors 246 are intended to include fuel or a suitable fluid mixture to facilitate combustion. The isothermal control mode may also include and / or be coordinated with a part load control mode and a full load control mode, where the isothermal expansion system 18 is adjusted to account for changes in operating parameters (e.g., changes in pressure ratio across the compressor section 42) due to changes in the load on the gas turbine system 12. As described in more detail below, the isothermal control mode (e.g., via the part load control mode and the full load control mode) may enable the axial extent of the variable axial position of combustion across the turbine blade sets 140 and / or 142 to change in response to changes in the load of the gas turbine system 12.

[0039] For example, the isothermal control mode (e.g., via the part load control mode and the full load control mode) may enable changes in the axial range of the variable axial location of combustion by at least changing the axial distance between the upstream end and the downstream end of the axial range, changing the upstream axial position of the upstream end of the axial range, changing the downstream axial position of the downstream end of the axial range, or a combination thereof. These changes in axial range may be achieved by varying fluid flow (e.g., fuel flow, oxidizer flow, and / or barrier gas flow) to (A) move the axial location of combustion further upstream from the trailing edge of the turbine blades 118 in response to a decrease in load on the gas turbine system 12, or (B) move the axial location of combustion downstream toward the trailing edge of the turbine blades 118 in response to an increase in load on the gas turbine system 12.

[0040] Sensors 222 (designated "S") are configured to monitor various operating parameters of combined cycle system 10. In a particular embodiment, sensors 222 include temperature sensors, pressure sensors, flow sensors, fluid composition sensors (e.g., gas composition sensors), vibration sensors, clearance sensors, speed sensors, humidity and / or moisture sensors, or any combination thereof. Sensors 222 may monitor parameters (e.g., temperature, pressure, flow, and fluid composition) at one or more locations in compressor section 42, combustor section 44, turbine section 46, isothermal expansion system 18, or any combination thereof.

[0041] For example, sensors 222 may monitor compressor parameters (e.g., pressure ratio between the inlet and outlet of compressor section 42), combustion gas parameters (e.g., flame temperature and combustion dynamics), turbine parameters (e.g., temperature and pressure of each turbine stage, turbine inlet, and turbine exhaust), and exhaust gas emissions. In the illustrated embodiment, sensors 222 may monitor the expansion of combustion gases 112 within turbine section 46, such as turbine blade sets 140 and 142, to enable controller 220 to monitor and control additional combustion and temperature distribution within turbine blade sets 140 and 142 to enable isothermal expansion. By way of further example, exhaust gas emissions monitored by sensors 222 may include carbon oxides (CO), such as carbon dioxide (CO) and carbon monoxide (CO). X ), nitrogen oxides such as nitrogen dioxide (NO2) X ), sulfur dioxide (SO2) and other sulfur oxides (SO X ), unburned hydrocarbons, particulate matter, and other undesirable exhaust emissions.

[0042] In the illustrated embodiment, isothermal expansion system 18 is configured to provide isothermal expansion across at least one or more turbine stages 122 of turbine section 46, such as turbine blade set 140 and / or turbine blade set 142. Isothermal expansion system 18 may provide isothermal expansion across turbine blade sets 140 and 142, for example, in a counter-rotating configuration of turbine blades 118. Isothermal expansion system 18 may include a distribution system 240 coupled to fluid system 88 and a fluid manifold 242. Distribution system 240 may include multiple distribution components 244, such as valves, pressure regulators, fluid manifolds, flow controllers, sensors, one or more fluid circuits, or any combination thereof. Isothermal expansion system 18 includes multiple fluid circuits 254, each including one or more valves 256 to enable flow control by controller 220. The fluid circuit 254 may be included with and / or extend between the fluid system 88 , the distribution system 240 , and the fluid manifold 242 .

[0043] The number of fluid circuits 254 can correspond to several different axial locations of the heat release of combustion and can include at least 2 to 1000, 5 to 500, 10 to 100, a number equal to the number of turbine vanes 120, or a number equal to the axial length of the turbine vanes 120 divided by the desired axial spacing of the fluid injectors 246 (e.g., 1 mm, 2 mm, 3 mm, 4 mm, 5 mm, 6 mm, 7 mm, 8 mm, 9 mm, 10 mm, 15 mm, 20 mm, 25 mm, 30 mm, 40 mm, or 50 mm). The fluid circuits 254 can include a fuel circuit, an oxidizer circuit, a barrier fluid circuit, a mixed fluid circuit, or any combination thereof. For example, the fluid circuits 254 can include multiple fuel circuits coupled to the fuel supply system 90, multiple oxidizer circuits coupled to the oxidizer supply system 92, and multiple fluid circuits (e.g., barrier fluid circuits) coupled to the fluid supply system 94. In certain embodiments, distribution component 244 may include a single or fluid mixer or mixing chamber configured to mix fluids from fluid system 88 before the fluids are delivered to fluid manifold 242 coupled to turbine section 46. Thus, distribution system 240 may be configured to individually or collectively deliver fuel, oxidant, and / or fluid (e.g., barrier fluid) to fluid manifold 242 along turbine blade set 140 and / or turbine blade set 142.

[0044] The isothermal expansion system 18 includes multiple combustion control mechanisms in the turbine vanes 120 and the turbine blades 118. The isothermal expansion system 18 may include multiple fluid injectors 246 disposed in the turbine vanes 120 of a turbine vane set 248 upstream of the turbine blade set 140 and / or the turbine blade set 142. In certain embodiments, the isothermal expansion system 18 may also include one or more flame stabilizers 250 disposed along each of the turbine blades 118 of the turbine blade set 140 and / or the turbine blade set 142. In the illustrated embodiment, the fluid injectors 246 of the turbine vane set 248 and the flame stabilizers 250 of the turbine blade set 140, and 142, if present, are all part of a common turbine stage 252. For example, the common turbine stage 252 may be an inlet or first turbine stage of the turbine section 46. In some embodiments, the isothermal expansion system 18 may be disposed in one or more turbine stages 122 downstream of the inlet turbine stage. Furthermore, when used with multiple turbine stages 122 , the isothermal expansion system 18 may have the same or different configurations for each of the turbine stages 122 .

[0045] As described below, the fluid injectors 246 are configured to provide a combustible mixture to generate combustion within the turbine blade sets 140 and 142. Each fluid injector 246 may include one or more fluid injection ports, such as a fuel injection port, an oxidizer injection port, and / or a fluid injection port (e.g., a barrier fluid injection port). The fluid injectors 246 may be configured to inject a fuel-oxidizer mixture (e.g., premixed upstream in a mixing chamber) and / or to inject separate fuel, oxidizer, and fluid streams (e.g., along the turbine blades 118 of the turbine blade sets 140 and / or 142) for subsequent mixing downstream. In certain embodiments, the fluid injectors 246 are coupled to multiple fluid circuits 254 having valves 256 that enable variable control of the fluid injection. The isothermal expansion system 18 may also include one or more flame stabilizers 250 disposed along each of the turbine blades 118 of the turbine blade sets 140 and 142. Flame stabilizer 250 may include structural features configured to help retain and / or stabilize a flame at specific locations (e.g., axial and radial locations) along turbine blade 118. Fluid injectors 246 on turbine vane 120 and / or flame stabilizer 250 on turbine blade 118 are configured to control the distribution of the flame (and associated heat release) at multiple locations (e.g., axial and radial locations) between the leading and trailing edges of turbine blade 118, thereby providing a substantially uniform temperature while expanding combustion gases 112 through turbine blade sets 140 and 142 (e.g., isothermal expansion). As will be appreciated, isothermal expansion improves the efficiency and performance of gas turbine system 12.

[0046] 2 is a schematic diagram of one embodiment of a portion of turbine section 46 of FIG. 1 , further illustrating details of isothermal expansion system 18 having a variable injection system 270 with fluid circuit 254 coupled to fluid injectors 246 and a variable stabilizer system 272 having flame stabilizers 250. As described below, variable injection system 270 has fluid injectors 246 disposed at various axial locations within the expansion of the turbine stage to help vary the axial location of heat release from combustion along turbine blades 118. Additionally, variable stabilizer system 272 has flame stabilizers 250 disposed at various axial locations within the expansion of the turbine stage to help vary the axial location of heat release from combustion along turbine blades 118 within the turbine stage. In certain embodiments, flame stabilizers 250 can be eliminated, and the various axial locations of heat release are controlled by fluid injectors 246. The fluid injectors 246 may also incorporate other controls to facilitate various axial locations of heat release, such as by controlling the flow rate of fuel, oxidant, and / or fluid (e.g., barrier fluid) from one fluid injector 246 to another. Details of the isothermal expansion system 18 are described in more detail below after describing the arrangement of the turbine vanes 120 and turbine blades 118.

[0047] As shown, the portion of the turbine section 46 (e.g., turbine stage 252) having the isothermal expansion system 18 includes a turbine vane set 248 having a circumferential arrangement 274 of vanes 120 at an axial position 276 along the rotational axis 36, a turbine blade set 140 having a circumferential arrangement 278 of turbine blades 118 at an axial position 280 along the rotational axis 36, and a turbine blade set 142 having a circumferential arrangement 282 of blades 118 at an axial position 284 along the rotational axis 36. The axial position 276 of the circumferential arrangement 274 of the vanes 120 (i.e., turbine vane set 248) is disposed upstream of the axial positions 280 and 284 of the circumferential arrangements 278 and 282 of the blades 118 (i.e., turbine blade sets 140 and 142). Axial location 280 of circumferential arrangement 278 of blades 118 (ie, turbine blade set 140 ) is disposed upstream of axial location 284 of circumferential arrangement 282 of blades 118 (ie, turbine blade set 142 ).

[0048] In turbine vane set 248, circumferential arrangement 274 has vanes 120 that are generally aligned with one another at axial positions 276 such that the vanes 120 axially overlap one another along the axis of rotation 36. Similarly, in turbine blade set 140, circumferential arrangement 278 has blades 118 that are generally aligned with one another at axial positions 280 such that the blades 118 axially overlap one another along the axis of rotation 36. Finally, in turbine blade set 142, circumferential arrangement 282 has blades 118 that are generally aligned with one another at axial positions 284 such that the blades 118 axially overlap one another along the axis of rotation 36. In the illustrated embodiment, the vanes 120 are disposed in a stationary position, the blades 118 of circumferential arrangement 278 of turbine blade set 140 rotate in a rotational direction 286 about the axis of rotation 36, and the blades 118 of circumferential arrangement 282 of turbine blade set 142 rotate in a rotational direction 288 about the axis of rotation 36. As shown, rotational directions 286 and 288 are opposite or counter to one another such that blades 118 of turbine blade sets 140 and 142 counter-rotate relative to one another (ie, counter-rotating turbine blades 118).

[0049] For reference purposes, dashed vertical line 290 represents 0 degrees about the axis of rotation 36, dashed vertical line 292 represents 180 degrees about the axis of rotation 36, and dashed vertical line 294 represents 360 degrees about the axis of rotation 36. Accordingly, the depicted vanes 120 and blades 118 are shown at various angular or circumferential positions throughout 360 degrees about the axis of rotation 36. As described in more detail below, the isothermal expansion system 18 includes a variable injection system 270 and a variable stabilizer system 272 configured to vary the heat release of combustion occurring in the depicted portion of the turbine section 46 (i.e., within the turbine stage expansion of turbine stage 252).

[0050] In the illustrated embodiment, the variable injection system 270 includes fluid injectors 246 disposed on the vanes 120 at variable injection locations 296 (e.g., spatially distributed injection locations), as indicated by dashed lines 298. The dashed lines 298 vary in axial position from 0 degrees to 180 degrees, as indicated by dashed lines 290 and 292, and from 180 degrees to 360 degrees, as indicated by dashed lines 292 and 294. Each vane 120 has a leading edge 300, a trailing edge 302, a pressure side or surface 304 extending from the leading edge 300 to the trailing edge 302, and a suction side or surface 306 extending from the leading edge 300 to the trailing edge 302. The variable injection locations 296 of the fluid injectors 246 may vary in position (e.g., axial position, radial position) from the leading edge 300 to the trailing edge 302 of each respective vane 120.

[0051] For example, the variable injection locations 296 may include from 2 to 1000 or more axial and radial locations, such as at least 2, 3, 4, 5, 6, 7, 8, 9, 10, 20, 30, 40, 50, 100, 200, or more axial and radial locations. For example, the vanes 120 near 0 and 360 degrees may have the fluid injectors 246 disposed at or near the leading edges 300, the vanes 120 disposed near the 180 degree locations may have the fluid injectors 246 disposed near the trailing edges 302, and the vanes 120 disposed between 0 and 180 degrees and between 180 and 360 degrees may have the fluid injectors 246 disposed partway or at an intermediate location between the leading edges 300 and the trailing edges 302. Thus, the variable injection position 296 of the fluid injector 246 may vary with respect to the axial distance from the leading edge 300 to the fluid injector 246 and the overall axial length 310 of the turbine blade 120 from the leading edge 300 to the trailing edge 302 along the axis of rotation 36. The variable injection position 296 of the fluid injector 246 may vary periodically from 0 degrees to 360 degrees, such as by crossing dashed line 298 through lines 290, 292, and 294. The dashed line 298 may represent a sinusoidal, cosine, or sawtooth periodic variation having one period of variation about the axis of rotation 36, with the axial position 276 varying from near the leading edge 300 to near the trailing edge 302 throughout the period. Other embodiments may include multiple periodic variations about the axis of rotation 36. For example, but not limited to, an embodiment may include a sinusoidal or sawtooth variation having multiple periods. Additionally, the variable injection location 296 may have a variable radial position along the radial direction or axis 32 .

[0052] The fluid injector 246 may also have an injection axis or injection direction 312 disposed at an angle 314 relative to a tangent 316 of the fluid injector 246. In certain embodiments, the angle 314 may be constant across the vanes 120 of the turbine vane set 248. Alternatively, the angle 314 may vary from one fluid injector 246 to another fluid injector 246 across the vanes 120 of the turbine vane set 248. For example, the angle 314 may be constant or variable for multiple fluid injectors 246 on each individual vane 120 and / or between fluid injectors 246 on different vanes 120. The fluid injectors 246 may also be constant or variable in other ways, including the cross-sectional area of ​​the fluid injection ports, the shape of the fluid injection ports (e.g., circular, oval, rectangular, etc.), the flow rate, or any combination thereof, from one fluid injector 246 to another and / or from one vane 120 to another. For example, the fluid injectors 246 may have a total cross-sectional flow area of ​​the fluid injection ports that is constant or variable from one fluid injector 246 to another and / or from one vane 120 to another. Furthermore, in certain embodiments, each fluid injector 246 includes multiple fluid injection ports, such as a fuel injection port, an oxidizer injection port, and a barrier fluid injection port, and the cross-sectional area (or ratio of cross-sectional areas) of the fluid injection ports may be constant or variable from one fluid injector 246 to another and / or from one vane 120 to another vane 120. Similarly, in embodiments having multiple fluid injection ports per fluid injector 246, the ratio of flow rates (e.g., fuel, oxidizer, and fluid) from one fluid injector 246 to another fluid injector 246 and / or from one vane 120 to another vane 120 may be constant or variable.

[0053] Each of the vanes 120 is fluidly coupled to one or more fluid circuits 254 having valves 256 coupled to the controller 220. The fluid circuits 254 may be part of, extend through, and / or fluidly couple the fluid system 88, the distribution system 240, and the fluid manifold 242, as described above with reference to FIG. 1. Using the fluid circuits 254 and the valves 256, the distribution system 240 is configured to supply one or more of the fluids (e.g., fuel, oxidizer, and fluid) from the fluid system 88 (e.g., supply systems 90, 92, and 94) to the fluid manifold 242, which then routes the fluid to each of the fluid injectors 246 in the vanes 120. For example, the distribution system 240 may route fuel from the fuel supply system 90 through the fluid manifold 242 via one or more fuel circuits of the fluid circuit 254 to the various fluid injectors 246 in the vanes 120. The distribution system 240 can deliver oxidizer from the oxidizer supply system 92 through the fluid manifold 242 to the various fluid injectors 246 in the vanes 120 via one or more oxidizer circuits of the fluid circuit 254. The distribution system 240 can deliver fluid (e.g., barrier fluid) from the fluid supply system 94 through the fluid manifold 242 to the various fluid injectors 246 in the vanes 120 via one or more fluid circuits (e.g., barrier fluid circuits) of the fluid circuit 254.

[0054] In certain embodiments, the fuel circuit, oxidizer circuit, and fluid circuit are separate from one another (i.e., separate fluid circuits 254 and fluid manifolds 242) such that fluid injectors 246 separately inject fuel, oxidizer, and fluid flows into turbine section 46. For example, distribution system 240 may use separate fluid circuits 254 to route fuel, oxidizer, and fluid from supply systems 90, 92, and 94 through fluid manifold 242 to multiple fluid ports of each of fluid injectors 246, as described in further detail below. However, in some embodiments, distribution system 240 mixes one or more fluids (e.g., fuel, oxidizer, and / or fluid) from supply systems 90, 92, and 94, thereby generating a fluid mixture (e.g., a fuel-oxidizer mixture) for distribution to fluid injectors 246 via the mixed fluid manifolds and circuits of fluid circuit 254. The controller 220 may also control the flow rates of various fluids to the fluid injectors 246 to help vary the heat release downstream of the turbine blade sets 140 and 142 .

[0055] In the illustrated embodiment, the variable injection system 270 includes a plurality of fluid circuits 254 (e.g., 254A, 254B, 254C, 254D, 254E, 254F, 254G, 254H, 254I, 254J, and 254K) and associated valves 256 (e.g., 256A, 256B, 256C, 256D, 256E, 256F, 256G, 256H, 256I, 256J, and 256K) coupled to fluid injectors 246 on a plurality of turbine vanes 120. Each of the illustrated fluid circuits 254 may represent a single fluid circuit (e.g., a single fuel, oxidant, or barrier gas circuit) or multiple fluid circuits (e.g., multiple fuel, oxidant, and / or barrier gas circuits). For example, each of the turbine vanes 120 may be coupled to a single fluid circuit 254 or multiple fluid circuits 254, each of the fluid circuits 254 may be coupled to a single turbine vane 120 or multiple turbine vanes 120, and each of the fluid circuits 254 may be coupled to a single fluid injector 246 or multiple fluid injectors 246. In the illustrated embodiment, each of the turbine vanes 120 has one or more fluid injectors 246 (e.g., 1, 2, 3, 4, 5, 6, 7, 8, 9, 10 or more) disposed at different locations of the variable injection location 296, and each of the turbine vanes 120 is coupled to a different one or more of the fluid circuits 254 to provide a fluid stream (e.g., a fuel stream) or multiple fluid streams (e.g., fuel, oxidant, and barrier gas streams) to the fluid injectors 246. For each turbine vane 120, the fluid injectors 246 may be disposed at a common axial location, as described below with reference to Figures 4-6 and 10-12, or at a variable axial location, as described below with reference to Figures 7-9. In certain embodiments, the variable injection locations 296 are at least partially or completely different for each turbine vane 120.

[0056] Variable injection system 270 and variable stabilizer system 272 are configured to enable and control variable heat release or combustion location 320 (e.g., spatially distributed heat release) along turbine blade sets 140 and 142 within the turbine stage expansion. Thus, isothermal expansion system 18 can enable and control variable heat release or combustion location 320 between circumferential arrangement 278 of blades 118 of turbine blade set 140 and / or circumferential arrangement 282 of blades 118 of turbine blade set 142. As shown, variable heat release or combustion location 320 is indicated by stars along dashed line 322 of turbine blade set 140 and dashed line 324 of turbine blade set 142, respectively. Dashed lines 322 and 324 generally vary in axial position between 0 degrees and 180 degrees, as indicated by dashed lines 290 and 292, and between 180 degrees and 360 degrees, as indicated by dashed lines 292 and 294. Dashed lines 322 and 324 represent one possible embodiment of variation (e.g., spatial variation) in variable heat release or combustion location 320. However, dashed lines 322 and 324 may vary in other ways, such as slanted lines, curved lines, wavy lines, or zigzag lines, randomly or irregularly varying lines, or any combination thereof. For example, dashed lines 322 and 324 may vary periodically from 0 degrees to 360 degrees, e.g., a transverse direction of dashed lines 322 and 324 passing through lines 290, 292, and 294. Dashed line 298 may represent a sinusoidal, cosine, or sawtooth periodic variation having one period of variation about axis of rotation 36, with axial positions 280 and 284 varying from near leading edge 326 to trailing edge 328 throughout the period. Other embodiments may include multiple periodic variations about axis of rotation 36. For example, embodiments may include, but are not limited to, a sinusoidal or sawtooth variation having multiple periods.

[0057] 2 , each of the blades 118 in circumferential arrangements 278 and 282 includes a leading edge 326, a trailing edge 328, a pressure side or surface 330 extending from the leading edge 326 to the trailing edge 328, and a suction side or surface 332 extending from the leading edge 326 to the trailing edge 328. A variable heat release or combustion location 320 of combustion occurring in the turbine section 46 downstream of the fluid injectors 246 varies axially between the leading edge 326 and the trailing edge 328 of the blades 118 in the circumferential arrangements 278 and / or the circumferential arrangements 282 of the blades 118. For example, the variable heat release or combustion location 320 may be defined with reference to a reference location such as the leading edge 326. Additionally, an axial distance 334 may be defined from a reference position (e.g., leading edge 326) to each of the variable heat release or combustion locations 320, where the axial distance 334 is a portion of the overall axial length 336 of the blade 118 from the leading edge 326 to the trailing edge 328.

[0058] In certain embodiments, one or more of the variable heat release or combustion locations 320 may be disposed directly at or adjacent the leading edge 326 as shown by the blade 118 at 0 degrees and 360 degrees (e.g., an axial distance 334 of zero), at or adjacent the trailing edge 328 as shown by a location close to 180 degrees (e.g., an axial distance 334 equal to the entire axial length 336), or at an axial distance 334 intermediate between the leading edge 326 and the trailing edge 328 of the blade 118. Thus, the variable heat release or combustion locations 320 may include an axial distance 334 that varies by 360 degrees for each blade 118 about the axis of rotation 336 in each of the circumferential arrangements 278 and 282. The variable heat release or combustion locations 320 may be axially spaced apart from one another at equal intervals, unequal intervals, or a combination thereof. For example, equal spacing may be defined by the overall axial length 336 divided by N, where N may be any number from 2 to 1000, 2 to 500, 2 to 100, or 2 to 50. For example, N may be at least 2, 3, 4, 5, 6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, or more.

[0059] In certain embodiments, the variable heat release or combustion location 320 may be achieved at least in part or in whole by a variable injection system 270 having a variable injection location 296. For example, varying axial distance 308 of the fluid injectors 246 may vary the axial distance 334 of the variable heat release or combustion location 320 along the blades 118 downstream of the vanes 120. Additionally, the variable injection system 270 may vary the fluid injectors 246 by a cross-sectional area, geometry, flow rate, or other operating parameter configured to adjust the distance to which heat release or combustion occurs at the turbine blade sets 140 and 142, as indicated by the variable heat release or combustion location 320.

[0060] The variable injection system 270 of the isothermal expansion system 18 may be controlled by the controller 220 in one or more of a plurality of control modes 360, such as an isothermal control mode 362, a load control mode 364, a fuel control mode 366, and / or a multi-fluid control mode 368. The isothermal control mode 362 is configured to control the variable injection system 270 to control the flow of fluid to the plurality of fluid injectors 246 to vary the axial position of combustion (e.g., variable heat release or combustion location 320) and reduce temperature variations across the turbine blades 118 within the turbine stage expansion, thereby providing an isothermal expansion for the turbine stage 252. In conjunction with and / or as part of the isothermal control mode 362, the load control mode 364 is configured to control the variable injection system 270 to control the flow of fluid to the plurality of fluid injectors 246 to vary the axial extent of the variable axial position of the combustion section 320 in response to changes in the load of the gas turbine system 12 (e.g., an increase or decrease in load). The load may be a generator load, and thus, the change in load may include a change in the generator load. Load control mode 364 is described in further detail below. A fuel control mode 366, which is coupled with and / or part of isothermal control mode 362, is configured to control variable injection system 270 to control fuel flow to multiple fluid injectors 246 (e.g., fuel-only injectors) to vary the axial location of combustion section 320 within the turbine stage expansion. A multi-fluid control mode 368, which is coupled with and / or part of isothermal control mode 362, is configured to control variable injection system 270 to control multiple fluid flows (e.g., fuel, oxidant, and barrier gas flows) to multiple fluid injectors 246 (e.g., multi-fluid injectors) to vary the axial location of combustion section 320 within the turbine stage expansion, as described in further detail below with reference to FIGS. 13, 14, and 17.

[0061] The controller 220 is configured to control the variable injection system 270 using a plurality of control modes 360, independently or in any combination with each other, to vary the axial location of the combustion (e.g., variable heat release or combustion location 320) and / or vary the axial range of different axial locations of the combustion 320 within the turbine stage expansion. For example, in load control mode 364, the controller 220 is configured to control the variable injection system 270 to vary the axial range of different axial locations of the combustion by varying the axial distance between the upstream end and downstream end of the axial range, varying the upstream axial position of the upstream end of the axial range, varying the downstream axial position of the downstream end of the axial range, or any combination thereof. In the illustrated embodiment, the controller 220 is configured to control the variable injection system 270 to vary the axial range of different axial locations of the combustion between the leading edge 326 and the trailing edge 328 of the plurality of turbine blades 118 of the turbine stage 252.

[0062] For example, the controller 220 is configured to control the variable injection system 270 to vary the axial range of different axial positions of combustion by varying at least the downstream axial position of the downstream end of the axial range (e.g., relative to the trailing edge 328), including (A) moving the downstream axial position of the downstream end of the axial range upstream in response to a change in load, including a decrease in the load of the gas turbine system 12, or (B) moving the downstream axial position of the downstream end of the axial range downstream in response to a change in load, including an increase in the load of the gas turbine system 12.

[0063] In a further example, the controller 220 is configured to control the variable injection system 270 to vary the axial range of different axial positions of combustion by varying at least the upstream axial position of the upstream end of the axial range (e.g., relative to the leading edge 326), including (A) moving the upstream axial position of the upstream end of the axial range upstream in response to a change in load, including a decrease in the load of the gas turbine system 12, or (B) moving the upstream axial position of the upstream end of the axial range downstream in response to a change in load, including an increase in the load of the gas turbine system 12.

[0064] In a further example, the controller 220 is configured to control the variable injection system 270 to vary the axial extent of the different axial locations of combustion by at least (A) decreasing the axial extent of the different axial locations of combustion in response to a change in load, including a decrease in the load of the gas turbine system 12, or (B) increasing the axial extent of the different axial locations of combustion in response to a change in load, including an increase in the load of the gas turbine system 12. The variable control of the axial extent of the different axial locations of combustion may be achieved by the controller 220 controlling (e.g., increasing, decreasing, starting, or stopping) the flow of fluid through the multiple fluid circuits 254 to the multiple fluid injectors 246 on the multiple turbine vanes 120.

[0065] 2 , the controller 220 is configured to control the variable injection system 270 to control fluid flow to the multiple fluid injectors 246 via the multiple fluid circuits 254 and associated valves 256, thereby selectively varying (e.g., starting, increasing, decreasing, or stopping) fluid flow at the variable injection locations 296 to achieve a corresponding change in the variable heat release or combustion location 320. The variable heat release or combustion location 320 along the turbine blade 118 may be a function of the variable injection locations 296, such that the upstream variable injection locations 296 correspond to the upstream combustion location 320, the downstream variable injection locations 296 correspond to the downstream combustion location 320, and the intermediate variable injection locations 296 correspond to the intermediate combustion location 320. Thus, the variable heat release or combustion location 320, and the axial extent of such location 320, is controlled by selectively varying the flow of fluid to the fluid injectors 246 at the variable injection locations 296.

[0066] In one particular embodiment, the load control mode 364 of the controller 220 may respond to a decrease in the load of the gas turbine engine 12 by controlling the valves 256 along the fluid circuit 254 to gradually reduce and / or stop the flow of fluid to the fluid injectors 246 in a sequence based on the variable injection positions 296 (e.g., in an upstream direction moving from the downstream fluid injector 246 toward the upstream fluid injector 246). For example, the controller 220 may gradually close the valves 256 along the fluid circuit 254 in the following sequence: (1) valve 256F along the fluid circuit 254F, (2) valve 256G along the fluid circuit 254G, (3) valve 256E along the fluid circuit 254E, (4) valve 256H along the fluid circuit 254H, (5) valve 256D along the fluid circuit 254D, (6) valve 256I along the fluid circuit 254I, (7) valve 256C along the fluid circuit 254C, (8) valve 256J along the fluid circuit 254J, (9) valve 256B along the fluid circuit 254B, (10) valve 256K along the fluid circuit 254K, and (11) valve 256A along the fluid circuit 254A. The foregoing sequence gradually moves the variable heat release or combustion location 320 upstream along the turbine blade 118 from the trailing edge 328 towards the leading edge 326 of the turbine blade 118 , thereby also reducing the axial extent of the combustion location 320 .

[0067] In one particular embodiment, the load control mode 364 of the controller 220 may respond to an increase in the load of the gas turbine engine 12 by controlling the valves 256 along the fluid circuit 254 to gradually initiate or increase the flow of fluid to the fluid injectors 246 in a sequence based on the variable injection position 296 (e.g., in a downstream direction starting from the upstream fluid injector 246 and moving toward the downstream fluid injector 246). For example, the controller 220 can gradually open the valves 256 along the fluid circuit 254 in the following sequence: (1) valve 256A along the fluid circuit 254A, (2) valve 256K along the fluid circuit 254K, (3) valve 256B along the fluid circuit 254B, (4) valve 256J along the fluid circuit 254J, (5) valve 256C along the fluid circuit 254C, (6) valve 256I along the fluid circuit 254I, (7) valve 256D along the fluid circuit 254D, (8) valve 256H along the fluid circuit 254H, (9) valve 256E along the fluid circuit 254E, (10) valve 256G along the fluid circuit 254G, and (11) valve 256F along the fluid circuit 254F. The foregoing sequence gradually moves the variable heat release or combustion location 320 along the turbine blade 118 downstream from the leading edge 326 towards the trailing edge 328 of the turbine blade 118 , thereby also increasing the axial extent of the combustion location 320 .

[0068] Further, in embodiments of the variable injection system 270 having the variable injection location 296 of FIG. 2 or the fixed injection location 350 of FIG. 3 , the load control mode 364 of the controller 220 may respond to changing loads on the gas turbine engine 12 by controlling the valves 256 along the fluid circuit 254 to vary the range of flow to the different fluid injectors 246, thereby varying the axial extent of the combustion location 320 along the turbine blade 118 within the turbine stage expansion. For example, for each of the fluid injectors 246, the controller 220 may gradually close the valves 256 along the fluid circuit 254 to reduce the flow to the fluid injector 246, thereby gradually moving the corresponding combustion location 320 upstream from the trailing edge 328 toward the leading edge 326 of the turbine blade 118. As a further example, for each fluid injector 246, controller 220 may gradually open valves 256 along fluid circuit 254 to increase flow to fluid injector 246, thereby gradually moving the corresponding combustion location 320 downstream from leading edge 326 toward trailing edge 328 of turbine blade 118. Using this increase or decrease in flow to fluid injector 246, controller 220 is configured to control variable injection system 270 to vary the number of different combustion locations 320, vary the axial distance 334 to the different combustion locations 320, vary the axial range of the different combustion locations 320, vary the downstream end of the axial range, vary the upstream end of the axial range, or any combination thereof.

[0069] In certain embodiments, variable heat release or combustion location 320 may be controlled at least in part or in whole by flame stabilizer 250 of variable stabilizer system 272. For example, flame stabilizer 250 may be disposed on each of blades 118 in circumferential arrangement 278 and / or circumferential arrangement 282 at various locations (e.g., axial and radial locations) along blade 118. For example, the various locations of flame stabilizer 250 may include from 2 to 1000 or more axial and radial locations, such as at least 2, 3, 4, 5, 6, 7, 8, 9, 10, 20, 30, 40, 50, 100, 200 or more axial and radial locations. In a further example, flame stabilizer 250 may be disposed at variable heat release or combustion location 320 an axial distance 334, as indicated by dashed lines 322 and 324, to help distribute the heat release of combustion occurring at turbine blade sets 140 and 142.

[0070] In certain embodiments, flame stabilizers 250 may be stationary or fixed in position relative to each of turbine blades 118. As described in more detail below, flame stabilizers 250 include structural features on the surface of blades 118 that facilitate turbulence or low-velocity zones along blades 118 to facilitate flame retention or stabilization along blades 118 at different axial locations or distances 334, as indicated by variable heat release or combustion locations 320. Flame stabilizers 250 may be identical structures disposed at different axial distances 334, different geometries or shapes at different or common axial distances 334, or any combination thereof. For example, as described in more detail below, flame stabilizers 250 may include one or more recesses, one or more protrusions, or any combination thereof. Thus, different flame stabilizers 250 may be used for each blade 118 in circumferential arrangements 278 and / or circumferential arrangements 282 to provide variable heat release or combustion locations 320.

[0071] Variable heat release or combustion location 320 achieved by variable injection system 270 with variable injection location 296 and / or variable stabilizer system 272 with flame stabilizer 250 is configured to distribute heat release across turbine blades 118 to provide a more uniform temperature and isothermal expansion of the hot gas flow through turbine blade sets 140 and 142. Again, variable heat release location or variable combustion location 320 may be achieved at least partially or wholly via variable injection system 270, which may vary axial distance 308 to fluid injectors 246, vary cross-sectional flow area, geometric drop shape, angle 314, or any combination thereof. Additionally or alternatively, variable heat release location or variable combustion location 320 may be achieved at least partially or wholly via variable stabilizer system 272, which may vary axial distance 334 to flame stabilizer 250, vary the geometry of flame stabilizer 250, or any combination thereof. Therefore, the variable injection system 270 and / or the variable stabilizer system 272 are configured to evenly distribute or average the combustion temperature across the turbine blade sets 140 and 142 to help provide an isothermal expansion in the turbine section 46.

[0072] FIG. 3 is a schematic diagram of an embodiment of a portion of the turbine section 46 of FIG. 1 , further illustrating details of the isothermal expansion system 18 having a variable injection system 270 and a variable stabilizer system 272. The illustrated embodiment has a variable stabilizer system 272 having substantially the same features as described in detail above with reference to FIG. 2. However, the variable injection system 270 of FIG. 3 differs from the embodiment of FIG. 2 because the variable injection system 270 has fluid injectors 246 positioned at constant injection locations 350 between the vanes 120, as indicated by dashed lines 352. In particular, each vane 120 of a circumferential arrangement 274 of vanes 120 of a turbine vane set 248 may have a fluid injector 246 disposed the same axial distance 308 from the leading edge 300 of the vane 120.

[0073] However, the variable injection system 270 may vary other aspects of the fluid injectors 246 from vane 120 to vane 120 in the circumferential arrangement 274 of the vanes 120 within the turbine vane set 248. For example, as described above with reference to FIG. 2 , the fluid injectors 246 may vary in cross-sectional flow area, flow rate, angle 314 of injection axis or direction 312, or any combination thereof, from vane 120 to vane 120. For example, if each fluid injector 246 includes a fuel injection port, the cross-sectional flow area of ​​the fuel injection port may vary from vane 120 to vane 120. Similarly, if each fluid injector 246 includes multiple fluid injection ports, such as a fuel injection port, a barrier fluid injection port, and an oxidizer injection port, the relative cross-sectional areas of the different ports of each fluid injector 246 may vary from vane 120 to vane 120 in the circumferential arrangement 274. Thus, even though the variable injection system 270 of FIG. 3 has a constant injection position 350 at axial distance 308, the variable injection system 270 has other modifications to the fluid injectors 246 to provide variable heat release or combustion positions 320 on the blades 118 of the turbine blade sets 140 and 142, as described above with reference to FIG. 2.

[0074] Additionally, variable stabilizer system 272 may include flame stabilizers 250 disposed at various axial distances 334 and described above with reference to Figure 2. In the illustrated embodiment, variable injection system 270 and variable stabilizer system 272, used alone or in combination with each other, are configured to distribute heat more evenly throughout turbine blade sets 140 and 142, thereby providing substantially isothermal expansion through turbine blade sets 140 and 142.

[0075] In the illustrated embodiment, the load control mode 364 of the controller 220 may respond to changing loads on the gas turbine engine 12 by controlling the valves 256 along the fluid circuit 254 to vary the range of flow rates to the different fluid injectors 246, thereby varying the axial extent of the combustion location 320 along the turbine blade 118. For example, for each of the fluid injectors 246, the controller 220 may gradually close the valve 256 along the fluid circuit 254 to decrease the flow rate to the fluid injector 246, thereby gradually moving the corresponding combustion location 320 upstream from the trailing edge 328 toward the leading edge 326 of the turbine blade 118. As a further example, for each of the fluid injectors 246, the controller 220 may gradually open the valve 256 along the fluid circuit 254 to increase the flow rate to the fluid injector 246, thereby gradually moving the corresponding combustion location 320 downstream from the leading edge 326 toward the trailing edge 328 of the turbine blade 118. Using the above-described increase or decrease in flow rate to the fluid injectors 246, the controller 220 is configured to control the variable injection system 270 to vary the number of different combustion locations 320, vary the axial distance 334 to the different combustion locations 320, vary the axial range of the different combustion locations 320, vary the downstream end of the axial range, vary the upstream end of the axial range, or any combination thereof.

[0076] 4-12 are perspective views of embodiments of the vane 120 of the isothermal expansion system 18 of FIGS. 1-3, further illustrating embodiments of fluid injectors 246 that may be used alone or in combination with one another in the variable injection location 296 of FIG. 2 and / or the constant injection location 350 of FIG. 3. In each illustrated embodiment, the vane 120 has a vane body 370 that extends in the radial direction 32 from a vane base 372 to a vane tip 374. The vane 120 may have a total radial length 376 from the base 372 to the tip 374, and the fluid injectors 246 may be disposed at multiple radial distances 378 measured in the radial direction 32 from the base 372 toward the tip 374.

[0077] In certain embodiments, the vane 120 may include a single fluid injector 246 disposed at a particular radial distance 378. However, in the illustrated embodiment, the vane 120 includes multiple fluid injectors 246 disposed at different radial distances 378 between the base 372 and the tip 374. For example, the radial distance 378 may vary anywhere from the very base 372 to the very tip 374 and at various positions in between. For example, the radial distance 378 may range from 0 to 100%, 10 to 90%, 20 to 80%, 30 to 70%, or 40 to 60% of the radial length 376 (sometimes referred to as the "span"). The fluid injectors 246 may be uniformly spaced radially, or the fluid injectors 246 may be non-uniformly spaced (e.g., using a greater number of fluid injectors 246 at a particular radial span).

[0078] The vane body 370 may have an airfoil-shaped geometry defined by a leading edge 300, a trailing edge 302, a pressure side 304, and a suction side 306. In certain embodiments, the vane body 370 may have a cross-sectional area or shape 380 (e.g., an airfoil-shaped cross-section) that varies or is constant in the radial direction 32 from the base 372 to the tip 374. The number of fluid injectors 246 may include at least one, two, three, four, five, six, seven, eight, nine, ten, or more fluid injectors 246 disposed on the suction side 306 of the vane body 370. As described in more detail below, for each embodiment of the vane 120, the axial distance 308 from the leading edge 300 to the fluid injector 246 may vary or remain constant, the cross-sectional area 382 of the fluid injector 246 may vary or remain constant, the angle 314 of the injection axis or direction 312 may vary or remain constant, the geometric shape or geometry may vary or remain constant, the flow rate may vary or remain constant, or any combination thereof, may be between the fluid injectors 246 on each vane 120.

[0079] FIG. 4 is a perspective view of one embodiment of the vane 120 of FIGS. 1-3 , in which multiple fluid injectors 246 are disposed at a constant axial distance 308 from the leading edge 300, as indicated by dashed line 384. In particular, the dashed line 384 may be disposed directly along, adjacent to, and / or parallel to the trailing edge 302, such that the dashed line 384 extends in the radial direction 32 at the constant axial distance 308 relative to the leading edge 300. In the illustrated embodiment, the axial distance 308 may be at least 70%, 80%, 90%, or 100% of the axial length 310. The vane 120 of FIG. 4 may be used for one or more of the vanes 120 of FIG. 2 , with other vanes 120 disposed at multiple different axial distances 308. Furthermore, in certain embodiments, the vane 120 of FIG. 4 may be used for each of the vanes 120 at the constant injection location 350 of FIG. 3 . 4 may vary or remain the same relative to one another along dashed line 384. For example, fluid injectors 246 may be the same or different from one another with respect to cross-sectional area 382, ​​angle 314 of injection axis or direction 312, geometric shape or geometry, flow rate, type of fluid injected, or any combination thereof.

[0080] FIG. 5 is a perspective view of one embodiment of the vane 120 of FIGS. 1-3, in which the plurality of fluid injectors 246 are disposed at a fixed axial distance 308 from the leading edge 300, as indicated by dashed line 390. The vane 120 of FIG. 5 is similar to the embodiment of FIG. 4. However, the fixed axial distance 308 in FIG. 5 is smaller than the fixed axial distance 308 in FIG. 4. In particular, the fixed axial distance 308 (e.g., dashed line 390) to the plurality of fluid injectors 246 in FIG. 5 is approximately midway between the leading edge 300 and the trailing edge 302 of the vane 120. For example, the fixed axial distance 308 may be approximately 30 to 70%, 40 to 60%, or 50% of the axial length 310 from the leading edge 300 to the trailing edge 302. A vane 120 having a fluid injector 246 disposed along dashed line 390 in Figure 5 may be used with one or more of the vanes 120 having variable injection locations 296, as shown in Figure 2, or with each of the vanes 120 having fixed injection locations 350 in Figure 3. In certain embodiments, the fluid injectors 246 in Figure 5 may vary relative to one another along dashed line 390 or may remain the same. For example, the fluid injectors 246 may be the same or different from one another with respect to cross-sectional area 382, ​​angle 314 of injection axis or direction 312, geometric shape or geometry, flow rate, type of fluid injected, or any combination thereof.

[0081] FIG. 6 is a perspective view of one embodiment of the vane 120 of FIGS. 1-3 in which multiple fluid injectors 246 are disposed a fixed axial distance 308 from the leading edge 300, as indicated by dashed line 400. The vane 120 of FIG. 6 is similar to the embodiment of FIGS. 4 and 5. However, the fixed axial distance 308 in FIG. 6 is smaller than the fixed axial distance 308 in FIGS. 4 and 5. In particular, the fixed axial distance 308 (e.g., dashed line 400) to the multiple fluid injectors 246 in FIG. 6 is directly along, adjacent to, and / or parallel to the leading edge 300 of the vane 120. For example, in the illustrated embodiment, the fixed axial distance 308 may be between 0% and 50%, 0% and 40%, 0% and 30%, 0% and 20%, or 0% and 10% of the axial length 310 from the leading edge 300 to the trailing edge 302. A vane 120 having fluid injectors 246 disposed along dashed line 400 in Figure 6 may be used with one or more of the vanes 120 having variable injection locations 296 in Figure 2 or each of the vanes 120 having fixed injection locations 350 in Figure 3. In certain embodiments, the fluid injectors 246 in Figure 6 may vary relative to one another along dashed line 400 or may remain the same. For example, the fluid injectors 246 may be the same or different from one another with respect to cross-sectional area 382, ​​angle 314 of injection axis or direction 312, geometric shape or geometry, flow rate, type of fluid injected, or any combination thereof.

[0082] 7 is a perspective view of one embodiment of the vane 120 of FIGS. 1-3 , in which multiple fluid injectors 246 are disposed at a variable axial distance 308 from the leading edge 300 along a variable dashed line 410. For example, the variable dashed line 410 may include one or more of a curved line, a zigzag or wavy line, a slanted line, or any combination thereof, where the variable dashed line 410 indicates (or follows) a change in the axial distance 308 relative to the leading edge 300. For example, the variable dashed line 410 may alternately curve back and forth (e.g., curved) in opposite axial directions, uniformly (e.g., sinusoidal) or non-uniformly (e.g., irregular) to define the variable axial distance 308 to the fuel injectors 246.

[0083] Thus, the fluid injectors 246 are not disposed at a common axial distance 308 from the leading edge 300; rather, the axial distance 308 of the fluid injectors 246 may vary over an axial range 412 relative to the axial length 310 of the vane 120 from the leading edge 300 to the trailing edge 302. The axial range 412 may be 10% or more, 20% or more, 30% or more, 40% or more, 50% or more, 60% or more, 70% or more, 80% or more, 90% or more, or 100% or more of the axial length 310 between the leading edge 300 and the trailing edge 302. In the illustrated embodiment, the axial range 412 of the fluid injectors 246 is disposed at a trailing edge portion 414 of the vane 120 and may include a region of the vane 120 between the trailing edge 302 and approximately 10%, 20%, or 30% of the axial length 310 of the vane 120. During operation, variation of the axial distance 308 of the fluid injector 246 over the axial range 412 can provide axial variation to facilitate variable heat release location or combustion location 320, as described above with reference to Figures 2 and 3.

[0084] 7 may be used for one or more of the vanes 120 having variable injection locations 296 as shown in FIG. 2. In some embodiments, the vanes 120 having fluid injectors 246 disposed along the variable dashed line 410 in FIG. 7 may be used for all of the vanes 120 in FIG. 3, with each vane 120 having variations, but the vanes 120 being the same throughout the circumferential configuration 274. In certain embodiments, the fluid injectors 246 in FIG. 7 may vary relative to one another along the variable dashed line 410 or may remain the same. For example, the fluid injectors 246 may be the same or different from one another with respect to cross-sectional area 382, ​​angle 314 of injection axis or direction 312, geometric shape or geometry, flow rate, type of fluid injected, or any combination thereof.

[0085] 8 is a perspective view of one embodiment of the vane 120 of FIGS. 1-3 , in which multiple fluid injectors 246 are disposed at a variable axial distance 308 from the leading edge 300 along a variable dashed line 420. The variable dashed line 420 in FIG. 8 may vary in the same or similar manner as the variable dashed line 410 in FIG. 7 , except that the variable dashed line 420 is disposed upstream of the variable dashed line 410 in FIG. 7 . For example, the variable dashed line 420 may alternately curve back and forth (e.g., curved) in opposite axial directions in a uniform (e.g., sinusoidal) or non-uniform (e.g., irregular) manner to define the variable axial distance 308 to the fuel injectors 246. In the illustrated embodiment, variable dashed line 420 extends over an axial range 422 between leading edge 300 and trailing edge 302, which may be 10% or more, 20% or more, 30% or more, 40% or more, 50% or more, 60% or more, 70% or more, 80% or more, 90% or more, or 100% or more of axial length 310 between leading edge 300 and trailing edge 302. For example, axial range 422 may be the same as axial range 412 in FIG. 7 and variable dashed line 420 may be the same shape as variable dashed line 410 in FIG. 7. However, axial range 422 and variable dashed line 420 may differ from the embodiment of FIG. 7.

[0086] As discussed above with reference to Figure 7, the vanes 120 of Figure 8 may be used for one or more of the vanes 120 having variable injection locations 296 of Figure 2, or the vanes 120 of Figure 8 may be used for all of the vanes 120 in the circumferential arrangement 274 of Figure 3. In certain embodiments, the fluid injectors 246 of Figure 8 may vary relative to one another along the variable dashed lines 420 or may remain the same. For example, the fluid injectors 246 may be the same or different from one another with respect to cross-sectional area 382, ​​angle 314 of injection axis or direction 312, geometric shape or geometry, flow rate, type of fluid injected, or any combination thereof.

[0087] Figure 9 is a perspective view of one embodiment of the vane 120 of Figures 1-3, in which multiple fluid injectors 246 are disposed at a variable axial distance 308 from the leading edge 300 along a variable dashed line 430. The variable dashed line 430 in Figure 9 may vary in the same or similar manner as the variable dashed line 410 in Figure 7 and / or the variable dashed line 420 in Figure 8, except that the variable dashed line 430 is disposed upstream of the variable dashed lines 410, 420 in Figures 7 and 8. For example, the variable dashed line 430 may alternately curve back and forth (e.g., curved) in opposite axial directions in a uniform (e.g., sinusoidal) or non-uniform (e.g., irregular) manner to define the variable axial distance 308 to the fuel injectors 246. The plurality of fluid injectors 246 are disposed along a variable dashed line 430 over an axial extent 432 that may be 10% or more, 20% or more, 30% or more, 40% or more, 50% or more, 60% or more, 70% or more, 80% or more, 90% or more, or 100% or more of the axial length 310 between the leading edge 300 and the trailing edge 302. In the illustrated embodiment, the axial extent 432 of the plurality of fluid injectors 246 is disposed at a leading edge portion 434 of the vane 120, which may extend between the leading edge 300 and approximately 10%, 20%, or 30% of the axial length 310.

[0088] 2, the vanes 120 may be used for one or more of the vanes 120 of the variable injection location 296, or the vanes 120 of FIG. 9 may be used for all of the vanes 120 of the circumferential arrangement 274. In certain embodiments, the fluid injectors 246 of FIG. 9 may vary relative to one another along the variable dashed line 430 or may remain the same. For example, the fluid injectors 246 may be the same or different from one another with respect to the cross-sectional area 382, ​​the angle 314 of the injection axis or direction 312, the geometric shape or geometry, the flow rate, the type of fluid injected, or any combination thereof.

[0089] 1-3, the fluid injectors 246 have different cross-sectional areas 382. For example, the cross-sectional area 382 of the fluid injector 246 of FIG. 10 is larger than the cross-sectional area 382 of the fluid injector 246 of FIG. 11 and FIG. 12, which in turn is larger than the cross-sectional area 382 of the fluid injector 246 of FIG. 11. As shown in FIG. 10, the fluid injectors 246 are disposed an axial distance 308 from the leading edge 300, as indicated by dashed line 440, which may be constant or variable, as described in detail above with reference to FIGS. 4-9. Similarly, fluid injector 246 in Figure 11 is disposed at an axial distance 308 from leading edge 300 as indicated by dashed line 450, where axial distance 308 may be constant or variable as described in detail above with reference to Figures 4-9. Finally, fluid injector 246 in Figure 12 is disposed at an axial distance 308 from leading edge 300 as indicated by dashed line 460, where axial distance 308 may be constant or variable as described in detail above with reference to Figures 4-9.

[0090] In each of the vanes 120 of Figures 10, 11, and 12, the fluid injectors 246 may have common or varying geometric shapes or geometries, such as circular geometries, elliptical geometries, square geometries, polygonal geometries, triangular geometries, or any combination thereof. Additionally, the fluid injectors 246 of Figures 10, 11, and 12 may have common or variable angles 314 of fluid injection axis or direction 312, constant or variable flow rates, constant or variable types of fluid injected, or any combination thereof. The vanes 120 of Figures 10, 11, and 12 may be used alone or in combination with each other in the variable injection system 270 of Figures 2 and 3.

[0091] 4-12 may be used independently for the vanes 120 of the turbine vane set 248 or in combination with one another. Additionally, the fuel injector 246 may include any number and types of variations in the axial 30, radial 32, and circumferential 34 directions to vary the heat release or combustion of the turbine blades 118 of the turbine blade sets 140 and 142 within a turbine stage expansion to help provide an isothermal expansion for the turbine stage 122 (e.g., common turbine stage 252). For example, the number of variations may be 2, 3, 4, 5, 6, 7, 8, 9, 10, 15, 20, 25, 30, 40, 50, 75, 100, or more. The types of variations may include the axial distance 308, the cross-sectional area 382, ​​the angle 314 of the injection axis or direction 312, the geometric shape or geometry, the flow rate, the type of fluid injected, or any combination thereof. Further details of the fluid injectors 246 may be used in combination with the vanes 120 described in detail above with reference to Figures 1-12. For example, as described in detail below, each of the fluid injectors 246 may include one or more fluid injection ports in various arrangements, one or more angles 314 of the fluid injection axis or direction 312, one or more internal geometries for accelerating or directing the flow from the fluid injector 246, or any combination thereof.

[0092] 1-12, further illustrating one embodiment of fluid injector 246 as a multi-fluid injector 470. In the illustrated embodiment, multi-fluid injector 470 has a body 472 which may be part of vane body 370 of vane 120 as described above, or body 472 may be located in a receptacle of vane 120. Body 472 includes a fluid passageway 474 disposed longitudinally along a central axis 476, a wall 478 disposed circumferentially about fluid passageway 474 and central axis 476 and defining fluid passageway 474, a fluid passageway 480 disposed circumferentially about wall 478, a wall 482 disposed circumferentially about fluid passageway 480 and defining the fluid passageway, a fluid passageway 484 disposed circumferentially about wall 482, and a wall 486 disposed circumferentially about fluid passageway 484 and defining the fluid passageway. Walls 478, 482, 486 may be concentric annular walls disposed about central axis 476, with fluid passageway 474 being a cylindrical passageway centered along central axis 476, fluid passageway 480 being an annular passageway concentric with fluid passageway 474, and fluid passageway 484 being an annular passageway concentric with fluid passageways 480 and 474. In certain embodiments, fluid passageway 480 can include multiple passageways spaced circumferentially about central axis 476, fluid passageway 484 can include multiple passageways spaced circumferentially about central axis 476, or a combination thereof. Generally, fluid passageway 480 is disposed between fluid passageways 474 and 484, thus separating the fluid flows.

[0093] The multi-fluid injector 470 is configured to inject the oxidizer from the oxidizer supply system 92, the barrier fluid from the fluid supply system 94, and the fuel from the fuel supply system 90. In certain embodiments, the isothermal expansion system 18 delivers the oxidizer, barrier fluid, and fuel to the respective fluid passages 484, 480, 484 of the multi-fluid injector 470 via distribution through the distribution system 240 and the fluid manifold 242, as described above. For example, the controller 220 may be configured to control the oxidizer supply system 92, the fluid supply system 94, the fuel supply system 90, the distribution system 240, and the fluid manifold 242, as well as various flow control components, to adjust the fluid flow rate, pressure, fluid flow direction, fluid composition, or any combination thereof, to and through the multi-fluid injector 470 at one or more positions within each of the vanes 120.

[0094] In certain embodiments, the isothermal expansion system 18 may be configured to selectively reroute the oxidant flow, the barrier fluid flow, and the fuel flow to different passages 474, 480, 484 of the multi-fluid injector 470. For example, in some embodiments, the controller 220 may control the distribution system 240, the fluid manifold 242, and various flow control components (e.g., valves) to route the fuel flow through fluid passage 474, the barrier fluid flow through fluid passage 480, and the oxidant flow through fluid passage 484 such that the barrier fluid flow is disposed between the fuel and oxidant flows. Similarly, the controller 220 may control the distribution system 240, the fluid manifold 242, and various flow control components to route the oxidant flow through fluid passage 474, the barrier fluid flow through fluid passage 480, and the fuel flow through fluid passage 484 such that the oxidant flow is disposed between the oxidant flow and the fuel flow.

[0095] In either case, a barrier fluid flow is output by the multi-fluid injector 470 between the fuel and oxidant flows, thereby delaying mixing of the oxidant and fuel flows up to an axial distance downstream of the multi-fluid injector 470. In certain embodiments, the isothermal expansion system 18 is configured to control the flow rates of the oxidant, barrier fluid, and fuel, and as described in detail above with reference to FIGS. 2 and 3 , the barrier fluid helps delay mixing between the oxidant and fuel flows up to a variable axial distance downstream of the multi-fluid injector 470 to facilitate variable heat release or combustion locations 320. Thus, the isothermal expansion system 18 can differentially control the flow of fluids (e.g., oxidant, barrier fluid, and fuel) through different multi-fluid injectors 470 on the same or different vanes 120, thereby varying the axial distance to heat release or combustion along the turbine blades 118 within the turbine stage expansion to help provide an isothermal expansion through the turbine stage 122 (e.g., common turbine stage 252).

[0096] Figure 14 is a cross-sectional view of the multi-fluid injector 470 of Figure 13 taken along line 14-14, further illustrating the configuration of fluid passages 474, 480, 484 and walls 478, 482, 486. As shown in Figure 14, walls 478, 482, 486 are annular walls disposed concentrically about central axis 476. Similarly, fluid passages 474, 480, and 484 are disposed in a concentric arrangement about central axis 476, with fluid passage 474 being a cylindrical passage, fluid passage 480 being an annular passage disposed between annular walls 478 and 482, and fluid passage 484 being an annular passage disposed between annular walls 482 and 486.

[0097] In the illustrated embodiment, fluid passage 474 may be configured to inject fuel from fuel supply system 90, fluid passage 480 may be configured to inject barrier fluid from fluid supply system 94, and fluid passage 484 may be configured to inject oxidizer from oxidizer supply system 92. However, in other embodiments, fluids may be rerouted through fluid passages 474, 480, 484. For example, fluid passage 474 may be configured to inject oxidizer from oxidizer supply system 92, fluid passage 480 may be configured to inject barrier fluid from fluid supply system 94, and fluid passage 484 may be configured to inject fuel from fuel supply system 90. The oxidizer may include oxygen, air, oxygen-reduced air, oxygen-enriched air, or any combination thereof. The barrier fluid may include an inert gas such as nitrogen, exhaust gas (e.g., exhaust gas from stoichiometric combustion), oxygen-reduced air (e.g., exhaust gas from non-stoichiometric combustion), carbon dioxide or other capture gas from a carbon capture system 192, or another suitable fluid to prevent mixing of the fuel and oxidizer and retard combustion.

[0098] 13 and 14 , the walls 478, 482, 486 terminate at a common axial location or plane 488 along the central axis 476. However, in certain embodiments, the walls 478, 482, and 486 may be axially staggered relative to one another along the central axis 476 to control the injection location and delay the mixing of the oxidizer and fuel streams from the multi-fluid injector 470. Again, the multi-fluid injector 470 may be used in each of the fluid injectors 246 in the vane 120 to help control the variable heat release of the combustion location 320 in the turbine blade sets 140 and 142 of the circumferential arrangements 278 and 282 of the blades 118.

[0099] FIG. 15 is a cross-sectional view of an embodiment of one of the fluid injectors 246 of FIGS. 1-12 , further illustrating a fluid passage 500 having a converging-diverging passage geometry 502. The fluid passage 530 may be a fuel passage, an oxidant passage, or a barrier fluid passage. As shown, the fluid passage 500 is disposed within a body 504, which may be part of the vane body 370 of the vane 120, as described above. However, the body 504 may be fixedly or removably attached to a receptacle within the vane 120. The fluid passage 500 extends through the body 504 in a flow direction 510 along an axis 512 from an inlet 506 to an outlet 508. In the illustrated embodiment, the converging-diverging passage geometry 502 of the fluid passage 500 includes a converging passage 514 disposed at the inlet 506, a diverging passage 516 disposed at the outlet 508, and a throat 518 between the converging and diverging passages 514 and 516. Converging-diverging channel shape 502 may be symmetrical about axis 512. For example, converging channel 514 may include an annular converging channel that converges toward axis 512 along a straight or curved contour 518, and diverging channel 516 may be an annular diverging channel that diverges away from axis 512 along a straight or curved contour 520 (e.g., an inner annular surface profile). For example, profiles 518 and 520 may be defined by conical and / or curved annular surfaces. Throat 518 may be a circular or cylindrical throat that defines the smallest cross-sectional area along converging-diverging channel shape 502.

[0100] In certain embodiments, the convergent passages 514 are configured to accelerate the fluid flow along the flow direction 510 toward the outlets 508 of the fluid injectors 246. As described above with reference to Figures 2 and 3, the specific geometries of the convergent passages 514, divergent passages 516, and throats 518 can be used to control the acceleration of the fluid flow in the downstream direction to facilitate variable heat release or combustion locations 320. For example, the cross-sectional areas of the fluid passages 500 (e.g., the inlets 506, outlets 508, and throats 518), ratios of the cross-sectional areas, and other characteristics of the fluid passages 500 may be varied from fluid injector 246 to help vary the heat release or combustion locations 320 within the turbine stage expansion, thereby helping to provide an isothermal expansion across the blades 118 of the turbine stages 122 (e.g., the common turbine stage 252).

[0101] FIG. 16 is a cross-sectional view of an embodiment of one of the fluid injectors 246 of FIGS. 1-12 , further illustrating a fluid passage 530 having a converging passage shape 532. The fluid passage 530 may be a fuel passage, an oxidant passage, a barrier fluid passage, or a fluid mixture passage (e.g., a fuel-air mixing channel). As shown, the fluid passage 530 has a converging passage shape 532 extending from an inlet 534 to an outlet 536 in a flow direction 538 along an axis 540. The converging passage shape 532 may include an annular converging passage shape, which gradually converges toward the axis 540 in a linear or curved manner, as indicated by a profile 542 (e.g., an inner annular surface profile). In certain embodiments, the linear profile 542 may include one or more angles relative to the axis 540, thereby gradually converging the fluid flow in the flow direction 510 toward the outlet 536. 15 , the converging passage geometry 532 can be configured to accelerate the fluid flow in a flow direction 538 toward the turbine blades 118 to provide variable heat release or combustion locations 320, as described in detail above with reference to FIGS. 2 and 3 . For example, the cross-sectional areas of the fluid passages 530 (e.g., at the inlet 534, outlet 536, and intermediate locations), ratios of the cross-sectional areas, and other characteristics of the fluid passages 530 may be varied from fluid injector 246 to help vary the heat release or combustion locations 320 within the turbine stage expansion, thereby helping to provide an isothermal expansion across the blades 118 of a turbine stage 122 (e.g., common turbine stage 252).

[0102] 17 is a cross-sectional view of the multi-fluid injector 470 of FIGS. 13 and 14 , further illustrating converging passage shapes 550, 552, and 554 within fluid passages 474, 480, and 484, respectively. In particular, fluid passage 474 has a converging passage shape 550 configured to converge in flow direction 556 toward central axis 476, passage 480 has a converging passage shape 552 to converge the passage in flow direction 556, and passage 484 has a converging passage shape 554 configured to converge the passage in flow direction 556. Thus, passage 474 may be a converging conical flow path from inlet 558 to outlet 560, passage 480 may be a converging annular flow path extending from inlet 562 to outlet 564, and passage 484 may be a converging annular flow path extending from inlet 566 to outlet 568. 13 and 14 , the outlets 560, 564, and 568 may be disposed along a common axial location or plane 488, or the outlets 560, 564, 568 may be axially staggered relative to one another by the axial staggering of the walls 478, 482, and 486. The illustrated multi-fluid injector 470 may be used for one or more of the fluid injectors 246 on the vane 120, alone or in combination with the multi-fluid injector 470 of FIGS. 13 and 14 , the converging-diverging passage shape 502 of FIG. 15 , the converging passage shape 532 of FIG. 16 , or additional passage shapes described in more detail below, to help provide variable heat release or isothermal expansion across the combustion location 320 and the blades 118 of the turbine stage 122 (e.g., common turbine stage 252).

[0103] FIG. 18 is a cross-sectional view of one embodiment of the fluid injector 246 of FIGS. 1-17 , further illustrating the angle 314 of the fluid injection axis or direction 312, which is approximately 90 degrees relative to the surface 580 of the outlet 582 of the fluid passage 584 through the body 586. The body 586 may be part of the vane body 370 of the vane 120, as described in detail above. However, in certain embodiments, the body 586 may be fixedly or removably coupled to the vane 120 via a receptacle in the vane body 370. The fluid passage 584 extends through the body 586 from the inlet 588 to the outlet 582. The fluid passage 584 is generally aligned or coaxial with an axis 590 extending through the body 586, with the axis 590 and the fluid injection axis or direction 312 disposed at the angle 314 relative to the surface 580, which may correspond to a surface along the vane 120. As explained in detail above, the angle 314 may be the same or vary between different fluid injectors 246 on each vane 120, or between different vanes 120 within a circumferential arrangement 274 of vanes 120 within a turbine vane set 248. Thus, while the angle 314 in FIG. 18 is approximately 90 degrees, the angle 314 may vary for other fluid injectors 246. The variable angle 314 between the fluid injector 246 and the vane 120 may be configured to help vary the heat release or combustion location 320 within a turbine stage expansion, thereby helping to provide an isothermal expansion across the blades 118 of a turbine stage 122 (e.g., common turbine stage 252).

[0104] 1-17 , further illustrating the angle 314 of the fluid injection axis or direction 312 as an acute angle relative to the surface 598 of the body 600. In the illustrated embodiment, the fluid injector 246 has a fluid passageway 602 extending through the body 600 from an inlet 604 at the surface 580 to an outlet 606, which may be part of the vane body 370 or may be attached to a receptacle in the vane body 370 as described above. The fluid passageway 602 may include a passageway 608 followed by a passageway 610, with the passageway 608 extending from the inlet 604 to the passageway 610, which in turn extends to the outlet 606. While the passageway 608 may be approximately perpendicular to the surface 580, the passageway 610 may be oriented at an angle 314 when the fluid injection axis or direction 312 extends at an angle relative to the surface 580 (e.g., relative to a line tangent to the surface 580 at the outlet 606). For example, the angle 314 may be between 0 and 90 degrees, between 10 and 80 degrees, between 20 and 70 degrees, between 30 and 60 degrees, or between 40 and 60 degrees. In the illustrated embodiment, the angle 314 is an acute angle. A fluid injector 246 having an angle 314 for the passageway 610 leading to the outlet 606 may be used for one or more of the fluid injectors 246 on one or more of the vanes 120, as described in detail above.

[0105] 20 is a cross-sectional view of one embodiment of the fluid injector 246 of FIGS. 1-17 , further illustrating the angle 314 of the fluid injection axis or direction 312 as an acute angle relative to the surface 620 of the body 622. The fluid injector 246 includes a fluid passage 624 that extends through the body 622 along the surface 620 from an inlet 626 to an outlet 628, the fluid passage 624 including a passage 630 followed by passages 632 and 634. The passage 630 extends from the inlet 626 to the passage 632, the passage 632 extends from the passage 630 to the passage 634, and the passage 634 extends from the passage 632 to the outlet 628. Each of the passages 630, 632, 634 may have a constant or variable cross-sectional area along the axis 590. For example, one or more of passages 630, 632, or 634 may include converging or diverging passages, as described above with reference to Figures 15-17. In the illustrated embodiment, passage 634 includes a converging passage (e.g., a conical passage) that converges in the flow direction to outlet 628.

[0106] The passages 630, 632, 634 may gradually change angle until they reach the surface 620, thereby defining an angle 314 of the fluid injection axis or direction 312. In the illustrated embodiment, the angle 314 may be 5, 10, 15, 20, 25, or 30 degrees or less relative to the surface 620 (e.g., relative to a line tangent to the surface 620 at the outlet 628). Furthermore, the angle 314 of the fluid injector 246 in FIG. 20 is less than the angle 314 of the fluid injector 246 in FIGS. 18 and 19, which in turn is less than the angle 314 of the fluid injector 246 in FIG. 18. Thus, in the circumferential arrangement 274 of the vanes 120 within the turbine vane set 248, various angles 314 may be used for the fluid injectors 246 on each of the vanes 120 and / or from one vane 120 to another. 18-20 (including any number of different angles 314), may be used in combination with the various fluid injector 246 features described herein. As described above, the variable angle 314 of the fluid injector 246 may be configured to help control or vary the heat release or combustion location 320 along the blades 118 of the turbine blade sets 140 and 142 within the turbine stage expansion, thereby helping to provide an isothermal expansion across the blades 118 of the turbine stage 122 (e.g., common turbine stage 252).

[0107] 21-26 are perspective views of an embodiment of the blade 118 of FIGS. 1-3 , further illustrating details of the flame stabilizer 250 of the variable stabilizer system 272. The flame stabilizer 250 includes structural features configured to help retain and / or stabilize the flame (resulting in heat release from combustion) at specific locations (e.g., axial and radial locations) along the turbine blade 118. Before addressing each embodiment of FIGS. 21-26 , various aspects of the blade 118 will now be described. As shown, the blade 118 includes a blade body 650 extending from a base 652 in the radial direction 32 to a tip 654. The blade body 650 has a cross-sectional area 656 that may be constant or variable in the radial direction 32 from the base 652 to the tip 654. For example, in certain embodiments, the cross-sectional area 656 gradually decreases in the radial direction 32 from the base 652 to the tip 654. Blade body 650 is further defined by leading edge 326, trailing edge 328, pressure side 330, and suction side 332. A cross-sectional area 656 is bounded by pressure side 330 and suction side 332 and may define an airfoil-shaped geometry. As described above, blade 118 has an axial length 336 that extends from leading edge 326 to trailing edge 328. Axial length 336 may vary from base 652 to tip 654 depending on whether cross-sectional area 656 is constant or variable from base 652 to tip 654.

[0108] Variable stabilizer system 272 includes flame stabilizers 250 disposed at one or more locations along blade 118, such as disposed radially 32 and axially 30 along pressure side 330 between leading edge 326 and trailing edge 328. Each flame stabilizer 250 may include one or more protrusions 660 and / or recesses 662 disposed in separate or overlapping locations relative to one another. For example, in the illustrated embodiment, each flame stabilizer 250 may include a protrusion 660 disposed in a recess 662 along a surface 664 of blade body 650, such as pressure side 330. Protrusions 660 and recesses 662 may have various shapes and dimensions in axially 30, radially 32, and circumferentially 34 directions. In the illustrated embodiment, recesses 662 have an elongated oval shape 666, and protrusions 660 have a curved or C-shaped shape 668. However, as will be explained in more detail below, the geometry of the protrusions 660 and recesses 662 may vary between the flame stabilizers 250 on each blade 118 and between different blades 118. Additionally, the variable stabilizer system 272 has the flame stabilizers 250 disposed at various locations along the blades 118 as shown in Figures 21-26 to facilitate variable heat release or combustion location 320 and isothermal expansion, as discussed above with reference to Figures 2 and 3. The differences between the embodiments of Figures 21-26 will now be explained in more detail below.

[0109] 21 is a perspective view of one embodiment of the blade 118 of FIGS. 1-3 , further illustrating details of a variable stabilizer system 272 having flame stabilizers 250 disposed at a constant axial distance 334 from the leading edge 326, as indicated by dashed line 670. Dashed line 670 generally extends in a radial direction 32 parallel to the leading edge 326 such that each of the flame stabilizers 250 is disposed at the same axial distance 334 from the leading edge 326. The flame stabilizers 250 may have the same or different geometries of the protrusions 660 and recesses 662 in various embodiments. In the illustrated embodiment, the variable stabilizer system 272 includes multiple flame stabilizers 250 at different radial distances 672 from the base 652 in the radial direction 32. For example, the radial distance 672 may be in the ranges of 0% to 100%, 10% to 90%, 20% to 80%, 30% to 70%, and 40% to 60%, or any other suitable range or percentage of the total radial length 674 of the blade 118 from the base 652 to the tip 654.

[0110] Flame stabilizers 250 may be evenly or unevenly spaced from one another in radial direction 32. In the embodiment of FIG. 21 , axial distance 334 may be measured between leading edge 326 and the center of flame stabilizer 250, as shown by dashed line 670. Thus, axial distance 334 may be 0% to 50%, 0% to 40%, 0% to 30%, 0% to 20%, and 0% to 10% of axial length 336 between leading edge 326 and trailing edge 328. For example, flame stabilizer 250 along dashed line 670 may be disposed at leading edge portion 676 of blade 118, which may correspond to a portion of blade 118 between leading edge 326 and approximately 10%, 20%, or 30% of axial length 336.

[0111] FIG. 22 is a perspective view of one embodiment of the blade 118 of FIGS. 1-3 , further illustrating details of the variable stabilizer system 272 having flame stabilizers 250 disposed at a common axial distance 334 from the leading edge 326, as indicated by dashed line 690. In the illustrated embodiment, the flame stabilizers 250 may have substantially the same characteristics as described above with reference to FIG. 21 . However, the axial distance 334 along dashed line 690 is further downstream from the leading edge 326 compared to FIG. 21 . In the illustrated embodiment, the axial distance 334 along dashed line 690 may be 20% to 80%, 30% to 70%, 40% to 60%, or approximately 50% of the axial length 336 between the leading edge 326 and the trailing edge 328. Again, the flame stabilizers 250 may have the same or different geometries for the protrusions 660 and recesses 662. Flame stabilizers 250 may be disposed at similar radial distances 672 in radial direction 32 as described above with reference to Figure 21. However, in certain embodiments, the radial distances 672 of flame stabilizers 250 may differ from the radial distances of flame stabilizers 250 in Figure 21.

[0112] FIG. 23 is a perspective view of one embodiment of the blade 118 of FIGS. 1-3 , further illustrating details of the variable stabilizer system 272 having the flame stabilizer 250 disposed a fixed axial distance 334 from the leading edge 326, as indicated by dashed line 700. In the illustrated embodiment, the flame stabilizer 250 may have substantially the same characteristics as described above with reference to FIG. 21 . However, the axial distance 334 along dashed line 700 is further downstream from the leading edge 326 compared to FIGS. 21 and 22 . For example, in the embodiment of FIG. 23 , the flame stabilizer 250 along dashed line 700 may be disposed along a trailing edge portion 702 of the blade 118, which may be disposed between the trailing edge 328 and approximately 10%, 20%, or 30% of the axial length 336 from the trailing edge 328. In certain embodiments, axial distance 334 may be approximately 50% to 100%, 60% to 100%, 70% to 100%, 80% to 100%, or 90% to 100% of axial length 336 of blade 118. As with the embodiment of Figures 21 and 22, dashed line 700 extends in radial direction 332, and flame stabilizers 250 may be disposed at different radial distances 672 along radial length 674 of blade 118. Radial distance 672 may be the same as or different from radial distance 672 of flame stabilizer 250, as shown in Figures 21 and 22.

[0113] Flame stabilizers 250 having constant axial distances 334 along dashed lines 670, 690, and 700 in Figures 21, 22, and 23 may be used individually or in combination with one another on blades 118 in circumferential arrangements 278 and 282 in Figures 2 and 3. Flame stabilizers 250 may also be arranged in other arrangements in combination with those shown in Figures 21, 22, and 23. Furthermore, flame stabilizers 250 may be coupled to blades 118 at any number of axial and radial positions, such as at least 2, 3, 4, 5, 6, 7, 8, 9, 10, 20, 30, 40, 50, 100, 200, or more axial and radial positions. The different positions of the flame stabilizers 250 help vary the heat release or combustion location 320 along the blades 118 of the turbine blade sets 140 and 142 within the turbine stage expansion, thereby helping to provide an isothermal expansion across the blades 118 of the turbine stage 122 (e.g., common turbine stage 252).

[0114] 24, 25, and 26 are perspective views of embodiments of blade 118 having a variable axial distance 334 from the leading edge 326 to the flame stabilizer 250, with each successive embodiment showing the flame stabilizer 250 further offset from the leading edge 326. For example, FIG. 24 is a perspective view of the blade 118 of FIGS. 1-3, illustrating a variable stabilizer system 272 having flame stabilizers 250 disposed at variable axial distances 334, as indicated by variable dashed lines 710. Variable dashed lines 710 generally extend in the radial direction 32 while varying in the axial direction 30. Thus, the axial distance 334 from the leading edge 326 to the flame stabilizer 250 varies along variable dashed lines 710 for each flame stabilizer 250. In the illustrated embodiment, the flame stabilizers 250 having the variable axial distances 334 are generally disposed at the leading edge portion 676 of the blade 118. For example, the flame stabilizer 250 may be positioned (e.g., centered) along the variable dashed line 710 over an axial range 712 of approximately 5% to 100%, 10% to 90%, 20% to 80%, 30% to 70%, or 40% to 60% of the axial length 336 between the leading edge 326 and the trailing edge 328.

[0115] Variable dashed line 710 may include one or more of a curved line, a zigzag or wavy line, a slanted line, or any combination thereof, where variable dashed line 710 indicates (or follows) the change in axial distance 334 relative to leading edge 326. For example, variable dashed line 710 may alternately rotate back and forth (e.g., curvilinear) in opposite axial directions, uniformly (e.g., sinusoidally) or non-uniformly (e.g., irregularly), to define variable axial distance 334 to flame stabilizer 250. Thus, variable axial distance 334 of flame stabilizer 250 may be disposed anywhere between leading edge 326 and trailing edge 328. However, in the illustrated embodiment, flame stabilizer 250 along variable dashed line 710 is generally disposed at leading edge portion 676.

[0116] Figure 25 is a perspective view of one embodiment of blade 118 of Figures 1-3, further illustrating details of variable stabilizer system 272 having flame stabilizer 250 disposed at variable axial distance 334 as indicated by variable dashed line 720. Variable dashed line 720 in Figure 25 may vary in the same or similar manner as variable dashed line 710 in Figure 24, except that variable dashed line 720 is disposed downstream from variable dashed line 710 in Figure 24. For example, variable dashed line 720 may rotate back and forth alternately (e.g., curvilinearly) in opposite axial directions in a uniform (e.g., sinusoidal) or non-uniform (e.g., irregular) manner to define variable axial distance 334 to flame stabilizer 250. Furthermore, flame stabilizer 250 may be positioned (e.g., centrally positioned) along variable dashed line 720 over an axial range 722 that may be at least approximately 5% to 100%, 10% to 90%, 20% to 80%, 30% to 70%, or 40% to 60% of axial length 336 between leading edge 326 and trailing edge 328. In the illustrated embodiment, flame stabilizer 250 is disposed along variable dashed line 720 in an intermediate region approximately halfway between leading edge 326 and trailing edge 328.

[0117] Figure 26 is a perspective view of one embodiment of blade 118 of Figures 1-3, further illustrating details of variable stabilizer system 272 having flame stabilizer 250 disposed at variable axial distance 334 as indicated by variable dashed line 730. Variable dashed line 730 in Figure 26 may vary in the same or similar manner as variable dashed lines 710 and 720 in Figures 24 and 25, except that variable dashed line 730 is disposed downstream from variable dashed lines 710 and 720 in Figures 24 and 25. For example, variable dashed line 730 may rotate back and forth alternately (e.g., curvilinearly) in opposite axial directions in a uniform (e.g., sinusoidal) or non-uniform (e.g., irregular) manner to define variable axial distance 334 to flame stabilizer 250. Flame stabilizer 250 may be positioned (e.g., centrally positioned) along variable dashed line 730 over an axial range 732 that may be at least approximately 5% to 100%, 10% to 90%, 20% to 80%, 30% to 70%, or 40% to 60% of axial length 336 between leading edge 326 and trailing edge 328. In the illustrated embodiment, flame stabilizer 250 along dashed line 730 is generally disposed at trailing edge portion 702 of blade 118, and flame stabilizer 250 may be between trailing edge 328 and approximately 10%, 20%, or 30% of axial length 336.

[0118] As shown in Figures 24, 25, and 26, the flame stabilizers 250 may have the same geometry and configuration at each and every blade 118. However, in certain embodiments, the flame stabilizers 250 may be constant or variable in terms of geometry, angle, spacing, or any combination thereof from one flame stabilizer 250 to another and from one blade 118 to another. The variable stabilizer system 272 may have the flame stabilizers 250 in any of the arrangements shown in Figures 21-26 used alone or in combination with each other on the blades 118 in the circumferential arrangements 278 and 282 of Figures 2 and 3. The arrangement and variation in arrangement of the flame stabilizers 250 is configured to help provide a variable heat release or combustion location 320, which in turn helps provide an isothermal expansion across the blades 118 of the turbine stage 122 (e.g., common turbine stage 252). In embodiments having two turbine blade sets 140 , 142 , the flame stabilizer of the first blade set 140 may be the same as or different from the flame stabilizer of the second blade set 142 .

[0119] As described above, flame stabilizer 250 may be used alone or in combination with various aspects of variable injection system 270, which may include variable injection location 296 of FIG. 2 , fixed injection location 350 of FIG. 3 , varying geometry, flow rate, angle 314, multi-fluid injector 470, or any combination thereof. Each of the features of variable injection system 270 and variable stabilizer system 272 are configured to help provide isothermal expansion across blades 118 in turbine stage 122 (e.g., common turbine stage 252). FIGS. 27-32 illustrate embodiments of flame stabilizer 250 that may be used in any combination with variable injection system 270 and variable stabilizer system 272, as described above.

[0120] FIG. 27 is a top view of one embodiment of the flame stabilizer 250 of FIGS. 1-3 and 21-26 , further illustrating details of the protrusion 660 disposed in a recess 662 in a surface 664 of the blade 118. As shown, the recess 662 has an elongated or elliptical geometry 666, while the protrusion 660 has a curved or C-shaped geometry 668. The protrusion 660 may be disposed at any position within the recess 662, thereby helping to maintain a low protrusion profile along the surface 664 of the blade 118. The blade 118 has the flame stabilizer 250 oriented along a flow direction 750, such that the fluid flow in the flow direction 750 extends partially across the recess 662 before reaching the protrusion 660. During operation, the fluid flow in flow direction 750 enters recess 662 and impinges on protrusion 660, which creates a low velocity zone to help stabilize or maintain the flame at a position along blade 118, and thus control the positioning (e.g., axial and radial position) of the heat release from combustion along blade 118.

[0121] The recess 662 has an elongated or elliptical geometry 666 that may include an upstream edge 752, a downstream edge 754, and opposing side surfaces 756 and 758 that extend from the upstream edge 752 to the downstream edge 754. The recess 662 may also have a constant or variable depth between the upstream edge 752 and the downstream edge 754 and between the opposing side surfaces 758. The protrusion 660 may be disposed at a variable or constant distance 760 relative to the upstream edge 752. For example, the distance 760 may be any percentage of the axial length 762 of the recess 662 between the upstream edge 752 and the downstream edge 754. For example, distance 760 may range from 0% to 100%, 0% to 80%, 0% to 60%, 0% to 40%, 0% to 20%, 20% to 80%, 30% to 70%, or 40% to 60% of axial length 762, or any other suitable percentage of axial length 762. Distance 760 may be varied to control the flame stabilization provided by flame stabilizer 250.

[0122] The protrusion 660 may have a curved or C-shaped shape 668 and may include a rear wall 764 connected to opposing side walls 766 and 768. The rear wall 764 and side walls 766, 768 are arranged about a space 770, and the protrusion 760 has an opening 772 into the space 770 between the opposing side walls 766 and 768. The opening 772 and space 770 face an upstream direction opposite the flow direction 750 such that fluid flow is directed into the opening 772 and space 770. The rear wall 764 may be a flat wall or a curved wall, while the side walls 766 and 768 may be sloped, straight, or curved about the space 770. The protrusion 660 may also provide or define a low velocity zone 774 behind or downstream of the rear wall 764 in the flow direction 750, thereby facilitating flame stabilization of a flame formed adjacent to the flame stabilizer 250.

[0123] The geometry, dimensions, and positioning of the recesses 662 and protrusions 660 can facilitate or adjust the position of the flame stabilization provided by the flame stabilizer 250. In certain embodiments, the recesses 662 and protrusions 660 of the flame stabilizer 250 of FIG. 27 may have the same geometry and dimensions, while varying their positioning across multiple flame stabilizers 250 on a particular blade 118 or between different blades 118 in the circumferential arrangements 278 and 282 of the turbine blade sets 140 and 142. However, the geometry and / or dimensions may also vary between different flame stabilizers 250 on the same or different blades 118, with or without variations in positioning. In certain embodiments, the geometry, dimensions, and positioning of the recesses 662 and protrusions 660 may vary between different flame stabilizers 250 on a particular blade 118 or between different blades 118.

[0124] FIG. 28 is a cross-sectional view of one embodiment of flame stabilizer 250 of FIG. 27 , further illustrating details of protrusion 660 and recess 662. As shown in FIG. 28 , recess 664 has a base or bottom surface 790 with a variable depth 792 between upstream edge 752 and downstream edge 754. In particular, base or bottom surface 790 may be curved to the variable depth 792 between upstream edge 752 and downstream edge 754. Protrusion 660 is disposed within recess 662 along base or bottom surface 790, and protrusion 760 extends outward to a height 794 relative to base or bottom surface 790. Height 794 may be equal to depth 792 of recess 662 at the location of protrusion 660, or height 794 may be disposed at a lower height 796 or a higher height 798 relative to a line or outline 800 along which surface 664 surrounds recess 662. Thus, in certain embodiments, the flame stabilizers 250 may have a variable depth 792, a variable height 794, a variable distance 760, other variable dimensions and geometries, or any combination thereof, from one flame stabilizer 250 to another, thereby varying the location of flame stabilization by the flame stabilizers 250 to help distribute the heat release of combustion and provide isothermal expansion across the blade 118.

[0125] FIG. 29 is a top view of one embodiment of the flame stabilizer 250 of FIGS. 1-3 and 21-26 , further illustrating details of the protrusion 660 disposed in a recess 662 in a surface 664 of the blade 118. The flame stabilizer 250 is substantially similar to that described above with reference to FIGS. 27 and 28 , with one or more features of the flame stabilizer 250 being variable to help provide isothermal expansion across the blade 118. However, the curved or C-shaped shape 668 of FIG. 29 differs from the embodiment of FIGS. 27 and 28 . The curved or C-shaped shape 668 of the protrusion 660 in the embodiment of FIG. 29 has a curved or arcuate wall 810 that extends at least partially around the space 812. For example, the C-shaped geometry 668 can exclude any flat or straight walls, such that the protrusion 660 is at least substantially or completely defined by the curved or arcuate wall 810. Curved or arcuate wall 810 has an opening 814 to space 812, with opening 814 and space 812 facing upstream, opposite flow direction 750. Downstream of curved or arcuate wall 810, flame stabilizer 250 has a low velocity zone 774 configured to promote flame stabilization and heat release at a desired location for isothermal expansion of turbine blade sets 140 and 142. Other aspects of flame stabilizer 250 are as described in detail above.

[0126] Figure 30 is a cross-sectional view of one embodiment of flame stabilizer 250 of Figure 29, further illustrating curved or arcuate walls 810 of protrusion 660 disposed within recess 662. Recess 662 is substantially similar to that described above with reference to Figures 27 and 28, including a variable depth 792 of base or bottom surface 790 and a variable height 794 of protrusion 660. For example, curved or arcuate walls 810 of protrusion 660 may be disposed at a height 794 that is flush with line or contour 800 of surface 664, or curved or arcuate walls 810 may be disposed at a lower height 796 or higher height 798 relative to line or contour 800. Thus, in certain embodiments, the flame stabilizers 250 may have a variable depth 792, a variable height 794, a variable distance 760, a variable radius of curvature of the curved or arcuate walls 810, other variable dimensions and geometries, or any combination thereof, from one flame stabilizer 250 to another, thereby varying the location of flame stabilization by the flame stabilizer 250 to help distribute the heat release of combustion and provide isothermal expansion across the blade 118.

[0127] FIG. 31 is a top view of one embodiment of the flame stabilizer 250 of FIGS. 1-3 and 21-26 , further illustrating details of a protrusion 660 disposed in a recess 662 in a surface 664 of a blade 118. The flame stabilizer 250 is substantially similar to that described above with reference to FIGS. 27-30 , with one or more features of the flame stabilizer 250 being variable to help provide isothermal expansion across the blade 118. However, the protrusion 660 of the embodiment of FIG. 31 includes a rectangular shape 820, whereas the protrusion 660 of the embodiment of FIGS. 27-30 includes a different curved or C-shaped geometry 668. As shown, the rectangular shape 820 of the protrusion 660 includes an upstream flat wall 822, a downstream flat wall 824, and opposing flat sidewalls 826 and 828. Upstream flat wall 822 faces upstream, opposite flow direction 750, and downstream flat wall 824 faces downstream, toward low velocity zone 774. The ratio of the dimensions of flat walls 822 and 824 to side walls 826 and 828 can vary depending on the dimensions of recess 662 and the desired width of low velocity zone 774. Again, as with the above-described embodiment, distance 760 from upstream edge 752 to rectangular shape 820 of protrusion 660 may vary from flame stabilizer 250 to flame stabilizer 250, on a particular blade 118, or between different blades 118.

[0128] FIG. 32 is a cross-sectional view of one embodiment of the flame stabilizer 250 of FIG. 31 , further illustrating details of the rectangular shape 820 of the protrusion 660 disposed within the recess 662. The recess 662 is substantially similar to that described in detail above with reference to FIGS. 27 and 28 , including a variable depth 792 of the base or bottom surface 790 and a variable height 794 of the protrusion 660. For example, the recess 662 may include a variable depth 792 to the base or bottom surface 790. Furthermore, the protrusion 660 having a rectangular geometry 820 may have a variable height 794 between the base or bottom surface 790 and the line or contour 800, such that the height 794 may be uniform or equal to the line or contour 800, or the protrusion 660 may have a lower height 796 or a higher height 798 relative to the line or contour 800. The distance 760 between the upstream edge 752 and the protrusion 760 may also vary, as described above. Thus, in certain embodiments, the flame stabilizers 250 may have a variable depth 792, a variable height 794, a variable distance 760, a variable width or length / width ratio of the rectangular geometry 820, other variable dimensions and geometries, or any combination thereof, from one flame stabilizer 250 to another, thereby varying the location of flame stabilization by the flame stabilizer 250 to help distribute the heat release of combustion and provide isothermal expansion across the blade 118.

[0129] 27-32 are examples of different flame stabilizers 250 that can be used alone or in combination with each other in a variable stabilizer system 272 on each of the blades 118 and / or from one blade 118 to another. Thus, the flame stabilizers 250 can be coupled to various blades 118 having different geometries, different dimensions, different positioning (e.g., axial and radial positions), or any combination thereof, thereby varying the axial distance to heat release or combustion along the turbine blades 118 within the turbine stage expansion to help provide an isothermal expansion through the turbine stage 122 (e.g., common turbine stage 252). The flame stabilizers 250 of the variable stabilizer system 272 can be used in any combination with the features of the variable injection system 270, as described in detail above.

[0130] FIG. 33 is a flowchart of an embodiment of a process 840 for operating the gas turbine system 12 with the variable injection system 270 of the isothermal expansion system 18 of FIGS. 1-32 , the process 840 including control via the controller 220. In the illustrated embodiment, the process 840 includes combusting fuel in the combustor 62 of the gas turbine system 12 to generate combustion gases 112 (block 842). The process 840 also includes routing the combustion gases 112 through a turbine stage 252 of the turbine section 46 of the gas turbine system 12 (block 844). The process 840 also includes controlling a flow of fluid through a fluid injector 246 coupled to the turbine vanes 120 of the isothermal expansion system 18 to provide combustion across the turbine blades of the turbine stage 252 (block 846). The process 840 also includes varying an axial position of combustion within the turbine stage expansion to reduce temperature variations across the turbine blades 118 of the turbine stage 252 (block 848). Process 840 also includes controlling the axial range of the axial position of the combustion (block 850) in response to changes in load on gas turbine system 12. The variable axial position (block 848) and controlled axial range (block 850) may be achieved by controlling variable injection system 270 using controller 220, as described in detail above with reference to Figures 2 and 3, where fluid injector 246 may be disposed at variable injection location 296 in Figure 2 or fixed injection location 350 in Figure 3.

[0131] As shown below, Table 1 illustrates a control strategy for the isothermal expansion system 18 using the fluid injectors 246 of the variable injection system 270.

[0132] [Table 1]

[0133] As described above, the control scheme may include multiple fluid injectors 246, or groups of multiple fluid injectors 246, as indicated by fluid injectors I1-I10. The fluid injectors 246 may be coupled to the turbine vanes 120 at axial positions, as indicated by axial positions P0-P10. The flow rate of fluid through the fluid injectors 246 may be controlled by the controller 220, such as via valves 256 in the fluid circuit 254, as indicated by flow rates R0-R10. If the fluid injectors 246 inject only fuel, the flow rate may correspond to the fuel flow rate. In the case of a multi-fluid injector 470, the multiple flow rates may be part of a control strategy to account for different flow rates of fuel, oxidant, and barrier gas, as described in detail above.

[0134] The control scheme in Table 1 is configured to use axial position (e.g., P0-P10) and / or flow rate (e.g., R0-R10) to induce variation in axial combustion position (e.g., variable heat release or combustion position 320) along turbine blade 118, as indicated by axial combustion positions CP0-CP10. In certain embodiments, the varying axial positions of combustion (block 848) of process 840 are achieved at least in part or in whole by positioning fluid injectors I0-I10 at a number of different axial positions corresponding to axial positions P0-P10. For example, axial positions P0-P10 may be represented by the ratio of axial distance 308 divided by total axial length 310, as shown in FIGS. 2 and 3 , where the ratio may gradually increase (e.g., 0, 0.1, 0.2, 0.3, 0.4, 0.5, 0.6, 0.7, 0.8, 0.9, and 1.0) from axial position P0 to axial position P10.

[0135] In certain embodiments, the varying axial positions of combustion (block 848) of process 840 are achieved at least in part or in whole by controlling the flow rates through fluid injectors I0-I10 at a plurality of different flow rates (e.g., R0-R10). For example, flow rates R0-R10 may gradually increase from P0 to P10, gradually decrease from P0 to P10, or any combination of increases and decreases from P0 to P10. For example, flow rates R0-R10 may gradually change by at least 5%, 10%, 15%, or 20%. In the embodiment of FIG. 2, the control scheme may use different axial positions P0-P10 with or without different flow rates (e.g., R0-R10). In the embodiment of FIG. 3, the control scheme may use the same axial positions P0-P10 with different flow rates (e.g., R0-R10).

[0136] Additionally, the control scheme in Table 1 is configured to use axial positions (e.g., P0-P10) and / or flow rates (e.g., R0-R10) to control the axial extent of different axial combustion locations (e.g., variable heat release or combustion locations 320) along turbine blade 118, as illustrated by axial combustion locations CP0-CP10. For example, in embodiments with different axial positions (e.g., P0-P10), process 840 can decrease the axial extent, such as by controlling flow rates to shut off upstream and / or downstream fluid injectors 246 to gradually shut off fluid flow in the following order: I10, I9, I8, I7, I6, I5, I4, I3, I2, I1, and I0. The process 840 can increase the axial range by controlling the flow rate to initiate fluid flow through the upstream and / or downstream fluid injectors 246, for example, by gradually initiating fluid flow in the following order: I0, I1, I2, I3, I4, I5, I6, I7, I8, I9, and I10.

[0137] As a further example, in embodiments having the same or different axial positions (e.g., P0-P10), process 840 can control the flow rate to gradually increase the range of flow rates from R0 to R10, such as by gradually increasing the percentage change of flow rate from R0 to R10 to create a larger axial range of combustion locations. Additionally, process 840 can control the flow rate to gradually decrease the range of flow rates from R0 to R10, such as by gradually decreasing the percentage change of flow rate from R0 to R10 to create a smaller axial range of combustion locations. The foregoing aspects of the control scheme can be used independently or in any combination with each other for process 840 of FIG. 33 .

[0138] FIG. 34 is a flowchart of an embodiment of a process 860 for operating the gas turbine system 12 with the variable injection system 270 of the isothermal expansion system 18 of FIGS. 1-33 , where the process 860 includes control via the controller 220. In one particular embodiment, the process 860 provides detailed steps of blocks 848 and 850 of the process 840 of FIG. 33 . As shown, the process 860 includes monitoring a load on the gas turbine system 12 having the isothermal expansion system 18 coupled to the turbine stage 252 (block 862). The load may correspond to a driven machine, such as a generator. The process 860 also monitors a load change, such as an increased or decreased load (block 864). The load change may affect several operating parameters of the gas turbine system 12, which may be monitored to enable load monitoring. For example, the operating parameter may include a compressor pressure ratio across the compressor section 42 of the gas turbine system 12, where a decrease in the compressor pressure ratio indicates a decrease in the load and an increase in the compressor pressure ratio indicates an increase in the load. The operating parameters may also include compressor outlet pressure at the outlet of compressor section 42, exhaust temperature at the outlet of turbine section 46, or any other suitable indicator of load.

[0139] If the process 860 does not observe a load change (block 864), the process 860 continues to monitor the load (block 862). If the process 860 observes a load change (block 864), the process 860 proceeds to initiate a load control mode (e.g., load control mode 364) of a fluid injector 246 of the isothermal expansion system 18, the fluid injector 246 being coupled to a turbine vane 120 upstream of the turbine blade 118 (block 866). Using the load control mode, the process 860 proceeds to reduce fuel flow to a downstream fluid injector of the multiple fluid injectors 246 coupled to the turbine vane 120 in response to a load reduction (block 868). For example, the reduced fuel flow may correspond to a fluid injector 246 near the trailing edge 328 of the turbine blade 118. The process 860 may gradually decrease and / or stop fuel flow to the sequence of fluid injectors 246 at different axial locations along the turbine vane 120, the sequence of decreasing fuel flow gradually moving from one fluid injector 246 in an upstream direction away from the trailing edge 328 to another fluid injector. Similarly, using a load control mode, the process 860 proceeds to increase fuel flow to a downstream fluid injector of the plurality of fluid injectors 246 coupled to the turbine vane 120 in response to an increase in load (block 870). The process 860 may gradually start and / or increase fuel flow to the sequence of fluid injectors 246 at different axial locations along the turbine vane 120, the sequence of increasing fuel flow gradually moving from one fluid injector 246 in a downstream direction toward the trailing edge 328 to another injector.

[0140] Technical effects of the present invention include systems and methods for isothermal expansion in turbine stages of a turbine section of a gas turbine system. The isothermal expansion can be achieved by active and / or passive control mechanisms that vary the axial location and distribution of heat release from combustion occurring in the turbine stages. The isothermal expansion system can include multiple variations of fluid injectors of a variable injection system coupled to stationary vanes of the turbine stages. The fluid injectors may vary in position (e.g., axial and radial location), cross-sectional area, geometry, angle of fluid injection, flow rate, relative flow rate through multiple passages of a multi-fluid injector, or any combination thereof. The isothermal expansion system can also include multiple variations of flame stabilizers of a variable stabilizer system coupled to rotating blades of the turbine stages. The flame stabilizers may vary in position (e.g., axial and radial location), cross-sectional area, geometry, size, or any combination thereof.

[0141] The isothermal expansion system can also provide active control, such as by controlling fluid flow through different fluid circuits of the variable injection system, to accommodate different operating conditions of the gas turbine system (e.g., full load and part load conditions). For example, as described above, when transitioning from a full load condition to a part load condition of the gas turbine system, the isothermal expansion system can adjust the axial location of the heat release of combustion further away from the trailing edges of the rotating blades. The axial location of the heat release of combustion can be controlled by reducing and / or stopping fluid injection from the fluid injectors at a downstream location along the stationary vanes, reducing the flow rate through the fluid injectors to move the heat release further away from the trailing edges of the rotating blades, or a combination thereof.

[0142] The subject matter detailed above may be governed by one or more of the provisions set out below.

[0143] The system includes a gas turbine having a turbine shaft disposed along a rotational axis, a turbine casing disposed circumferentially about the turbine shaft, a combustion gas path disposed between the turbine shaft and the turbine casing, and a turbine stage disposed in the combustion gas path. The turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The gas turbine includes an isothermal expansion system coupled to the turbine stage, the isothermal expansion system further including a plurality of flame stabilizers configured to vary an axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature variations across the expansion of the turbine stage. The plurality of flame stabilizers are disposed at different axial positions along an axial length between leading edges and trailing edges of the plurality of turbine blades, and at least one of the plurality of flame stabilizers is coupled to each of the turbine blades.

[0144] The system of the preceding clause, wherein each of the plurality of flame stabilizers includes a recess, a protrusion, or a combination thereof.

[0145] The system of any preceding clause, wherein each of the plurality of flame stabilizers includes a protrusion disposed within the recess.

[0146] The system of any preceding clause, wherein the recess includes an oval recess.

[0147] The system of any preceding clause, wherein the protrusion comprises a curved wall, a rectangular wall, an angled wall, or a combination thereof.

[0148] The system of any preceding clause, wherein the protrusions and / or recesses vary from one flame stabilizer to another of the plurality of flame stabilizers.

[0149] The system of any preceding clause, wherein each of the plurality of turbine blades includes a plurality of flame stabilizers of the plurality of flame stabilizers.

[0150] 10. The system of any preceding clause, wherein a plurality of flame stabilizers are disposed at only one axial position and at different radial positions on each of the plurality of turbine blades, and the one axial position varies from one turbine blade to another of the plurality of turbine blades.

[0151] 10. The system of any preceding clause, wherein a plurality of flame stabilizers are disposed at at least two axial positions on each of the plurality of turbine blades.

[0152] The system of any preceding clause, wherein the different axial positions span at least 50% of the axial length between the leading edge and the trailing edge.

[0153] The system of any preceding clause, wherein the different axial positions span at least 75% of the axial length between the leading edge and the trailing edge.

[0154] The system of any preceding clause, wherein the different axial positions span about 100% of the axial length between the leading edge and the trailing edge.

[0155] The system of any preceding clause, wherein the turbine stage is a first turbine stage of a gas turbine.

[0156] 10. The system of any preceding clause, wherein the plurality of turbine blades includes a first plurality of turbine blades arranged in a first annular arrangement and a second plurality of turbine blades arranged in a second annular arrangement, the first plurality of turbine blades configured to rotate in a first rotational direction about the rotational axis via a first shaft portion of the turbine shaft, and the second plurality of turbine blades configured to rotate in a second rotational direction about the rotational axis via a second shaft portion of the turbine shaft, the first and second rotational directions being opposite to each other.

[0157] 10. The system of any preceding clause, comprising: a controller having a processor; a memory; and instructions stored in the memory and executable by the processor to vary an axial position of combustion within a turbine stage expansion of a turbine stage to reduce temperature variation across the turbine stage expansion by varying one or more parameters of fluid injection from a plurality of fluid injectors on at least a respective plurality of turbine vanes.

[0158] The method includes routing combustion gases through turbine stages along a combustion gas path disposed between a turbine shaft and a turbine casing of a gas turbine. The turbine shaft is disposed along a rotational axis, the turbine casing is disposed circumferentially about the turbine shaft, and the turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The method includes varying an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature fluctuations across the expansion of the turbine stage via a plurality of flame stabilizers of an isothermal expansion system coupled to the turbine stage. The plurality of flame stabilizers are disposed at different axial positions across an axial length between leading edges and trailing edges of the plurality of turbine blades, and at least one of the plurality of flame stabilizers is coupled to each of the turbine blades.

[0159] The method of the preceding clause, wherein the range of different axial positions spans at least 50% of the axial length between the leading edge and the trailing edge.

[0160] 10. The method of any preceding clause, wherein varying the axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature variation across the turbine stage expansion includes varying one or more parameters of fluid injection from a plurality of fluid injectors on a respective plurality of turbine vanes.

[0161] The system includes a controller having a processor, a memory, and instructions stored in the memory and executable by the processor, the controller controlling combustion in a combustor to generate a combustion gas flow through a turbine stage along a combustion gas path disposed between a turbine shaft and a turbine casing of a gas turbine. The turbine shaft is disposed along a rotational axis, the turbine casing is disposed circumferentially about the turbine shaft, and the turbine stage includes a plurality of turbine vanes disposed upstream of a plurality of turbine blades. The controller is further configured to control an isothermal expansion system coupled to the turbine stage to vary an axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature variations across the turbine stage expansion. The isothermal expansion system includes a plurality of flame stabilizers disposed at different axial positions along an axial length between leading edges and trailing edges of the plurality of turbine blades, at least one of the plurality of flame stabilizers coupled to each of the turbine blades.

[0162] 10. The system of any preceding clause, wherein the controller is configured to vary an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature variation across the expansion of the turbine stage by varying one or more parameters of fluid injection from a plurality of fluid injectors on the respective plurality of turbine vanes.

[0163] Examples are used herein to disclose the invention, including the best mode, and to enable any person skilled in the art to practice the invention, including making and using any devices or systems, and performing any methods incorporated therein. The patentable scope of the invention is defined by the claims, and may include other examples that occur to those skilled in the art. Such other examples are intended to be within the scope of the claims if they have structural elements that do not differ from the literal language of the claims, or if they include equivalent structural elements that do not differ substantially from the literal language of the claims. [Explanation of symbols]

[0164] 10 Combined Cycle Systems 12 Gas Turbine System 14 Steam Turbine System 16 Heat recovery steam generator 18 Isothermal Expansion System 30 axis, axial direction 32 axial, radial 34 Axial and circumferential directions 36 Rotation axis 40 Intake section 42 Compressor Section 44 Combustor Section 46 Turbine Section 48 Exhaust Section 50, 114, 124, 178, 128 shaft 50A, 114A, 124A inner shaft 50B, 114B, 124B outer shaft 52, 116 Casing 54 Compressor blade 56 Compressor vane 58 Compressor Stage 62 Combustor 64 Head end section 66 Combustion part 68 Combustion chamber 70 Combustor liner 72 Flow Sleeve 74, 608, 610, 630, 632, 634 aisles 76 Upstream direction 78 Headend Room 80 Intermediate Plate 82 Fuel nozzle 84 End Plate 86 Compressed Gas 88 Fluid Systems 90 Fuel supply system 92 Oxidant Supply System 94 Fluid Supply System 96, 254, 254A, 254B, 254C, 254D, 254E, 254F, 254G, 254H, 254I, 254J, 254K Fluid circuit 98, 100, 102, 194, 196, 198, 200, 202 Components 104 Compressed Air 106 Compressor System 108 Air Compressor 110 Drive unit 112 Combustion Gas 118 Turbine Blade 120 Turbine vane 122, 252 turbine stages 126, 180 load 130, 132, 134, 136 subsets 140, 142 Turbine Blade Set 150 EGR system 152, 184 Exhaust gas 160 High-Pressure Section 162 Intermediate Pressure Section 164 Low Pressure Section 166 High-Pressure Steam 168 Intermediate Pressure Steam 170 Low-pressure steam 172 High-pressure steam turbine 174 Medium-pressure steam turbine 176 Low-pressure steam turbine 182 Condensate 190 Gas Treatment System 192 Carbon Capture Systems 204 Carbon dioxide (CO2) 206 Compression System 208 Reservoir / Pipeline 210 Air Separation Unit 212 Oxygen 214 Nitrogen 220 Controller 222 Sensor 224 processors 226 memory 228 Command 230 Communication Circuit 240 Distribution System 242 Fluid Manifold 244 Distribution Component 246 Fluid Injector 248 Turbine Vane Set 250 Flame stabilizer 256, 256A, 256B, 256C, 256D, 256E, 256F, 256G, 256H, 256I, 256J, 256K valves 270 variable injection system 272 Variable Ballast System 274, 278, 282 circumferential arrangement 276, 280, 284 axial position 286, 288 Rotation direction 290, 292, 294 vertical dashed lines 296 Variable injection position 298, 322, 324, 352, 384, 390, 400, 440, 450, 460, 670, 690, 700 dashed lines 300, 326 leading edge 302, 328 trailing edge 304 pressure side 306 Negative pressure side 308, 334 Axial distance 310, 336 Overall axial length, axial length 312 Injection direction 314 angle 316 Tangent line 320 Variable Heat Release or Combustion Location 330, 332, 580, 598, 620, 664 surface 350 injection position 360 Control Mode 362 Isothermal Control Mode 364 Load Control Mode 366 Fuel Control Mode 368 Multi-fluid control mode 370 Vane body 372, 652 base 374 Tip 376 Total radial length 378, 672 radial distance 380, 668 shape 382, 656 cross-sectional area 410, 420, 430, 710, 720, 730 Variable dashed lines 412, 422, 432, 712, 722, 732 Axial range 414, 702 Trailing edge part 762 Axial length 434, 676 Leading edge 470 Multi-Fluid Injector 472, 504, 586, 600, 622 main body 474, 480, 484, 500, 530, 584, 602, 624 Fluid passage 476 Central axis 478, 482, 486 Wall 488 plane 502 Converging-diverging passage shape 506, 534, 558, 562, 566, 588, 604, 626 entrance 508, 536, 560, 564, 568, 582, 606, 628 exit 510, 538, 556, 750 Flow direction 512, 540, 590 axes 514 Converging Passage 516 Diffusion Passage 518 Throat 520, 800 contours 532 Converging passage shape 542 Profiles 550, 552, 554 Converging passage shape 650 Blade Body 654 Tip 660 Protrusion 662 recess 666 oval shape 674 Total radial length 752 Upstream edge 754 downstream edge 756, 758 Side 760 distance 764 Back wall 766, 768 side wall 770, 812 space 772, 814 openings 774 Slow Zone 790 bottom 792 depth 794, 796, 798 height 810 Bow-shaped wall 820 rectangular shape 822 Upstream flat wall 824 Downstream flat wall 826, 828 flat side wall 840, 860 process Blocks 842, 844, 846, 848, 850, 862, 864, 866, 868, and 870

Claims

1. A system (10), comprising: A gas turbine (46), a turbine shaft (114) disposed along the rotation axis (36); a turbine casing (116) disposed circumferentially around the turbine shaft (114); a combustion gas path disposed between the turbine shaft (114) and the turbine casing (116); a turbine stage (122) disposed in the combustion gas path, the turbine stage (122) including a plurality of turbine vanes (120) disposed upstream of a plurality of turbine blades (118); an isothermal expansion system coupled to the turbine stage, the isothermal expansion system including a plurality of flame stabilizers configured to vary an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature variations across the expansion of the turbine stage, the plurality of flame stabilizers being disposed at different axial positions across an axial length between a leading edge and a trailing edge of the plurality of turbine blades, at least one of the plurality of flame stabilizers being coupled to each of the plurality of turbine blades; A system (10) comprising:

2. The system (10) of claim 1, wherein each of the plurality of flame stabilizers (250) includes a recess (662), a protrusion (660), or a combination thereof.

3. The system (10) of claim 2, wherein each of the plurality of flame stabilizers (250) comprises the protrusion (660) disposed within the recess (662).

4. The system (10) of claim 3, wherein the recess (662) comprises an oval recess.

5. The system (10) of claim 3, wherein the protrusion (660) comprises a curved wall, a rectangular wall, an angled wall, or a combination thereof.

6. The system (10) of claim 3, wherein the protrusions (660) and / or the recesses (662) vary from one flame stabilizer (250) to another flame stabilizer (250) of the plurality of flame stabilizers (250).

7. The system (10) of any preceding claim, wherein each of the plurality of turbine blades (118) comprises a plurality of flame stabilizers (250) of the plurality of flame stabilizers (250).

8. 8. The system of claim 7, wherein the plurality of flame stabilizers are disposed at only one axial position and at different radial positions on each of the plurality of turbine blades, the one axial position varying from one turbine blade to another of the plurality of turbine blades.

9. The system (10) of claim 7, wherein the plurality of flame stabilizers (250) are disposed at at least two axial positions on each of the plurality of turbine blades (118).

10. The system (10) of claim 1, wherein the different axial positions span at least 50% of the axial length between the leading edge (326) and the trailing edge (328).

11. The system (10) of claim 1, wherein the different axial positions span at least 75% of the axial length between the leading edge (326) and the trailing edge (328).

12. The system of claim 1 , wherein the different axial positions span approximately 100% of the axial length between the leading edge (326) and the trailing edge (328).

13. The system of claim 1 , wherein the turbine stage (122) is a first turbine stage of the gas turbine.

14. 2. The system of claim 1, wherein the plurality of turbine blades includes a first plurality of turbine blades arranged in a first annular arrangement and a second plurality of turbine blades arranged in a second annular arrangement, the first plurality of turbine blades configured to rotate in a first rotational direction about the axis of rotation via a first shaft portion of the turbine shaft, and the second plurality of turbine blades configured to rotate in a second rotational direction about the axis of rotation via a second shaft portion of the turbine shaft, the first and second rotational directions being opposite to one another.

15. 2. The system of claim 1, comprising: a controller having a processor; a memory; and instructions stored in the memory and executable by the processor to vary the axial position of combustion within the turbine stage expansion of the turbine stage to reduce the temperature variation across the turbine stage expansion by varying one or more parameters of fluid injection from a plurality of fluid injectors on at least the respective plurality of turbine vanes.

16. 1. A method comprising: channeling combustion gases (112) along a combustion gas path disposed between a turbine shaft (114) and a turbine casing (116) of a gas turbine (46) through a turbine stage (122), the turbine shaft (114) being disposed along an axis of rotation (36), the turbine casing (116) being circumferentially disposed about the turbine shaft (114), the turbine stage (122) comprising a plurality of turbine vanes (120) disposed upstream of a plurality of turbine blades (118); Varying an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature fluctuations across the expansion of the turbine stage via flame stabilizers of an isothermal expansion system coupled to the turbine stage, the plurality of flame stabilizers being disposed at different axial positions across an axial length between a leading edge and a trailing edge of the plurality of turbine blades, at least one of the plurality of flame stabilizers being coupled to each of the plurality of turbine blades; A method comprising:

17. The method of claim 16, wherein the range of different axial positions spans at least 50% of the axial length between the leading edge (326) and the trailing edge (328).

18. 17. The method of claim 16, wherein varying an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature variation across the expansion of the turbine stage comprises varying one or more parameters of fluid injection from a plurality of fluid injectors on the respective plurality of turbine vanes.

19. A system (10), comprising: A controller (220) having a processor (224), a memory (226), and instructions (228) stored in the memory (226) and executable by the processor (224), the instructions (228) comprising: a combustion gas path disposed between a turbine shaft and a turbine casing of a gas turbine, the turbine shaft disposed along a rotational axis, the turbine casing being circumferentially disposed about the turbine shaft, the turbine stage including a plurality of turbine vanes disposed upstream of a plurality of turbine blades; 10. A system comprising: a controller; wherein the instructions control an isothermal expansion system coupled to the turbine stage to vary an axial position of combustion within the turbine stage expansion of the turbine stage to reduce temperature variations across the expansion of the turbine stage, the isothermal expansion system comprising a plurality of flame stabilizers disposed at different axial positions across an axial length between a leading edge and a trailing edge of the plurality of turbine blades, at least one of the plurality of flame stabilizers being coupled to each of the plurality of turbine blades.

20. 20. The system of claim 19, wherein the controller is configured to vary an axial position of combustion within a turbine stage expansion of the turbine stage to reduce temperature variations across the expansion of the turbine stage by varying one or more parameters of fluid injection from a plurality of fluid injectors on the respective plurality of turbine vanes.

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