Combustor abnormality monitoring using emission feedback

Abstract

This invention provides a system for monitoring combustor abnormalities in a GT system, a GT system including a monitoring system, and related methods. [Solution] The system 110 includes exhaust probes 180 for each combustor element 116 in the GT system 100, and an exhaust analyzer 190 operably coupled to the exhaust probes and periodically measuring the exhaust level of the exhaust flow from each exhaust probe. The combustor anomaly detection system is connected to the exhaust analyzer and determines whether the exhaust level at a selected exhaust probe among the exhaust probes deviates from the expected exhaust level by a predetermined threshold. If the exhaust level deviates in such a way, the system identifies that a combustor element anomaly exists in the combustor element from which the exhaust flow is generated and adjusts the operation of the combustor element having the combustor element anomaly. The system provides accurate identification of combustor anomalies without using a large number of temperature and / or pressure sensors.

Description

Technical Field

[0001] The present disclosure generally relates to gas turbine systems. More specifically, the present disclosure relates to a system for monitoring combustor anomalies in a gas turbine system using an exhaust probe.

Background Art

[0002] A gas turbine system includes a compressor section operably coupled to a turbine section through a combustion section. A flow of compressed air from the compressor section is mixed with fuel in the combustion section to form a combustible mixture. The combustion section includes a plurality of combustor elements (e.g., combustion cans) each including one or more burners. The combustible mixture is directed to the turbine section where it expands along a hot gas path through a number of turbine stages acting on turbine airfoils attached to wheels to produce work, for example, output to power a generator. The hot gas passes from the turbine section through an exhaust section as exhaust gas.

Summary of the Invention

[0003] Hydrogen is an increasingly used fuel in the combustion section because it is a cleaner and more efficient energy source. However, since hydrogen burns at a higher temperature than other fuels, early detection of combustion section anomalies such as flashback or flameholding in the burners within the combustor elements is advantageous in limiting the severity of damage to the hardware. Current approaches use temperature sensors and / or pressure sensors near each burner and / or within the exhaust section to identify anomalies. This arrangement presents manufacturing and cost challenges due to the large number of sensors that need to be provided, for example, potentially hundreds of sensors. Additionally, the time required to maintain a large number of sensors has the drawback of increasing the downtime of the GT system.

[0004] The inventions claimed herein relate to the subject matter set forth in the claims. More specific embodiments are described below. All aspects, examples, and features described below can be combined in any technically possible way.

[0005] One aspect of the present disclosure provides a system for monitoring combustor anomalies in a gas turbine system including an exhaust section downstream of a turbine section and a combustion section including a plurality of combustor elements operably coupled to the turbine section, comprising: an exhaust probe for each of the plurality of combustor elements, the exhaust probe being configured to be positioned circumferentially spaced apart in the exhaust section, each exhaust probe being configured to sample an incoming exhaust flow; at least one exhaust analyzer operably coupled to the exhaust probe and configured to periodically measure the exhaust level of the exhaust flow from each exhaust probe; and a combustor anomaly detection system operably connected to the at least one exhaust analyzer, wherein the combustor anomaly detection system is configured to determine whether the exhaust level at a selected exhaust probe deviates from an expected exhaust level by a predetermined threshold, and in response to the exhaust level at the selected exhaust probe deviating from an expected exhaust level by a predetermined threshold, to identify that a combustor element anomaly exists in the combustor element from which the exhaust flow measured by the selected exhaust probe is generated, and to adjust the operation of the combustor element having the combustor element anomaly.

[0006] Another aspect of the present disclosure includes any of the preceding aspects, wherein at least one emission analyzer comprises a single emission analyzer and further comprises a valve system configured to periodically and operably couple each emission probe to the single emission analyzer under the control of a combustor anomaly detection system.

[0007] Another aspect of the present disclosure includes any of the aforementioned aspects, wherein at least one emission analyzer includes an emission analyzer for each of the emission probes.

[0008] Another aspect of the present disclosure includes any of the preceding aspects, wherein identifying a combustor element anomaly includes determining which combustor element the exhaust flow measured by a selected exhaust probe originates from, based on a swirl chart that maps the exhaust flow paths from each of a plurality of combustor elements through the exhaust section.

[0009] Another aspect of this disclosure includes any of the aforementioned aspects, wherein the combustor malfunction detection system triggers an alarm in response to the identification of a combustor element malfunction.

[0010] Another aspect of the present disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system alters the fuel flow to at least one combustor element in the combustion section and at least one of at least a portion of the combustor elements having the combustor element anomaly, in response to the identification of a combustor element anomaly.

[0011] Another aspect of this disclosure includes any of the preceding aspects, wherein the combustor malfunction detection system shuts down the combustion section in response to the identification of a combustor element malfunction.

[0012] Another aspect of this disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system determines an expected emission level from a baseline emission pattern based on the load of the gas turbine in the gas turbine system.

[0013] Another aspect of the present disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system determines the expected emission level based on a pro rata portion of the overall emission levels of all combustor elements in the exhaust section attributable to a single combustor element among a plurality of combustor elements.

[0014] Another aspect of the present disclosure includes any of the preceding aspects, wherein each combustor element includes a plurality of burners, and the combustor anomaly detection system further includes sequentially turning off each of the plurality of burners of the combustor element having a combustor element anomaly, measuring the decrease in emission levels at a selected emission probe, identifying which of the plurality of burners of the combustor element having a combustor element anomaly has the greatest decrease in emission levels while turned off, determining that a combustor burner anomaly exists in the burner having the greatest decrease in emission levels, and adjusting the operation of the burner having the combustor burner anomaly.

[0015] One aspect of the present disclosure is a gas turbine system comprising: a compressor section; a combustion section operably coupled to the compressor section and including a plurality of combustor elements; a turbine section operably coupled to the combustion section; an exhaust section downstream of the turbine section; and a monitoring system for monitoring combustor abnormalities, the monitoring system comprising discharge probes for each of the plurality of combustor elements, the discharge probes being positioned circumferentially spaced apart in the exhaust section, and each discharge probe being configured to sample the incoming exhaust flow, and a monitoring system comprising discharge probes operably coupled to the discharge probes and configured to periodically measure the discharge level of the exhaust flow from each discharge probe. A gas turbine system includes at least one emission analyzer and a combustor anomaly detection system operably connected to at least one emission analyzer, wherein the combustor anomaly detection system is configured to determine whether the emission level at a selected emission probe among the emission probes deviates from an expected emission level by a predetermined threshold, to identify, in response to the emission level at the selected emission probe deviating from an expected emission level by a predetermined threshold, that a combustor element anomaly exists in the combustor element from which the exhaust flow measured by the selected emission probe is generated, and to adjust the operation of the combustor element having the combustor element anomaly.

[0016] Another aspect of the present disclosure includes any of the preceding aspects, wherein at least one emission analyzer comprises a single emission analyzer and further comprises a valve system configured to periodically and operably couple each emission probe to the single emission analyzer under the control of a combustor anomaly detection system.

[0017] Another aspect of the present disclosure includes any of the aforementioned aspects, wherein at least one emission analyzer includes an emission analyzer for each of the emission probes.

[0018] Another aspect of the present disclosure includes any of the preceding aspects, wherein identifying a combustor element anomaly includes determining which combustor element the exhaust flow measured by a selected exhaust sensor originates from, based on a swirling chart that maps the exhaust flow paths from each of a plurality of combustor elements through the exhaust section.

[0019] Another aspect of this disclosure includes any of the aforementioned aspects, wherein the combustor malfunction detection system triggers an alarm in response to the identification of a combustor element malfunction.

[0020] Another aspect of the present disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system alters the fuel flow to at least one combustor element in the combustion section and at least one of at least a portion of the combustor elements having the combustor element anomaly, in response to the identification of a combustor element anomaly.

[0021] Another aspect of this disclosure includes any of the preceding aspects, wherein the combustor malfunction detection system shuts down the combustion section in response to the identification of a combustor element malfunction.

[0022] Another aspect of this disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system determines an expected emission level from a baseline emission pattern based on the load of the gas turbine in the gas turbine system.

[0023] Another aspect of the present disclosure includes any of the preceding aspects, wherein the combustor anomaly detection system determines the expected emission level based on a pro rata portion of the overall emission levels of all combustor elements in the exhaust section attributable to a single combustor element among a plurality of combustor elements.

[0024] One aspect of the present disclosure is a method for monitoring a combustor anomaly in a gas turbine system including an exhaust section downstream of a turbine section and a combustion section including a plurality of combustor elements operably coupled to the turbine section, the method comprising: measuring the emission level of an exhaust flow from each of a plurality of emission probes positioned circumferentially spaced apart in the exhaust section, using at least one emission analyzer operably coupled to a plurality of emission probes, wherein the plurality of emission probes include an emission probe for each of a plurality of combustor elements; determining whether the emission level at a selected emission probe among the plurality of emission probes deviates from an expected emission level by a predetermined threshold; identifying, in response to the emission level at the selected emission probe deviating from an expected emission level by a predetermined threshold, that a combustor element anomaly exists in the combustor element from which the exhaust flow measured by the selected emission probe is generated; and adjusting the operation of the combustor element having the combustor element anomaly.

[0025] Two or more embodiments described in this disclosure, including those described in this summary section, can be combined to form embodiments not specifically described herein. That is, all embodiments described herein can be combined with one another.

[0026] Details of one or more embodiments are described in the accompanying drawings and the following description. Other features, purposes, and advantages will become apparent from the description and drawings, as well as the claims.

[0027] These and other features of the present disclosure will be more readily understood from the following detailed description of the various aspects of the present disclosure, taken in conjunction with the accompanying drawings that illustrate various embodiments of the present disclosure.

Brief Description of the Drawings

[0028] [Figure 1] FIG. 1 is a schematic block diagram of a gas turbine (GT) system including a monitoring system having a combustor anomaly detection system according to an embodiment of the present disclosure. [Figure 2] FIG. 11 is a cross-sectional side view of an exemplary combustor element in the form of a combustor can type combustor element for a combustion section that can be used in the GT system of FIG. 1. [Figure 3] FIG. 14 is an end view of an exemplary combustor can of FIG. 2. [Figure 4] FIG. 17 is a schematic axial view of an exhaust section of a GT system using a can-annular combustor arrangement according to an embodiment of the present disclosure. [Figure 5] FIG. 20 is a schematic axial view of an exhaust section of a GT system using a can-annular combustor arrangement according to another embodiment of the present disclosure. [Figure 6] FIG. 23 is a schematic axial view of an exhaust section of a GT system using an annular combustor arrangement according to an embodiment of the present disclosure. [Figure 7] FIG. 26 is a flowchart showing a method for detecting a combustor anomaly according to an embodiment of the present disclosure.

[0029] Note that the drawings of the present disclosure are not necessarily to scale. The drawings are intended to illustrate only typical aspects of the present disclosure and should not be considered as limiting the scope of the present disclosure. In the drawings, like reference numerals represent like elements among the drawings.

Modes for Carrying Out the Invention

[0030] As a first issue, in order to clearly describe the subject matter of this technology, it is necessary to select specific technical terms when referring to and describing relevant mechanical components in exemplary applications of gas turbine (GT) systems. Wherever this is done, common industrial terminology will be used and adopted in a manner consistent with its accepted meaning, whenever possible. Unless otherwise stated, such terminology should be given a broad interpretation consistent with the context of this application and the appended claims. Those skilled in the art will understand that, in many cases, certain components may be referred to using several different or overlapping terms. What may be described herein as a single part may comprise multiple components and be referred to in another context as consisting of multiple components. Conversely, what may be described herein as comprising multiple components may be referred elsewhere as a single part.

[0031] In addition, several descriptive terms may be used periodically in this specification, and it will be useful to define these terms at the beginning of this section. These terms and their definitions are as follows, unless otherwise specified: As used herein, “downstream” and “upstream” are terms indicating direction relative to the flow of a working fluid through a GT system, or a fluid such as the flow of air through a combustor, or the coolant through one of the component systems of the GT system. The term “downstream” corresponds to the direction of the fluid flow, and the term “upstream” refers to the direction opposite to the flow. The terms “forward” and “rear” refer to directions unless otherwise specified, “forward” refers to the front of the turbomachinery or the end of the compressor section, and “rear” refers to the rear of the gas turbine system or the turbine end.

[0032] In many cases, it is required to describe parts that are located at different radial positions with respect to a central axis. The term “axial” refers to movement or position parallel to an axis, e.g., the axis of a turbomachine. The term “radial” refers to movement or position perpendicular to an axis, e.g., the axis of a turbomachine. In such cases, if the first component is located closer to the axis than the second component, it is stated herein that the first component is “radially inward” or “inside” the second component. On the other hand, if the first component is located further from the axis than the second component, it may be stated herein that the first component is “radially outward” or “outside” the second component. Finally, the term “circumferential” refers to movement or position around an axis, e.g., the circumferential inner surface of a casing extending around the axis of a turbomachine. As stated above, it will be understood that such terms may be applied with respect to the axis of a turbomachine.

[0033] In addition, several descriptive terms may be used periodically in this specification, as described below. The terms “first,” “second,” and “third” may be used interchangeably to distinguish one component from another and are not intended to indicate the location or importance of any individual component.

[0034] The technical terms used herein are intended solely to describe specific embodiments and are not intended to limit this disclosure. Where used herein, the singular forms “a,” “an,” and “the” are intended to include the plural unless the context otherwise explicitly indicates. The terms “equipped with” and / or “equipped with” when used herein express the presence of the described features, integers, steps, actions, elements, and / or components, but are not intended to exclude the presence or addition of one or more other features, integers, steps, actions, elements, components, and / or groups thereof. “Optional” or “optionally” means that the events described later may or may not occur, or the features described later may or may not exist, and this statement includes both instances in which the events occur or the features exist, and instances in which the events do not occur or the features do not exist.

[0035] When an element or layer is referred to as “on top of,” “engaged,” “connected,” “joined,” or “attached” to another element or layer, it may be directly on top of, engaged, connected, joined, or attached to the other element or layer, or there may be an intervening element or layer. Conversely, when an element is referred to as “directly on top of,” “directly engaged,” “directly connected,” or “directly joined” to another element or layer, there is no intervening element or layer. Other words used to describe the relationship between elements should be interpreted similarly (e.g., “between” vs. “directly between,” “adjacent” vs. “directly adjacent,” etc.). As used herein, the term “and / or” includes any combination of one or more of the related enumerated items. The verb forms “join” and “attach” may be used interchangeably herein.

[0036] Embodiments of the present disclosure include a system for monitoring combustor anomalies in a GT system, a GT system including a monitoring system, and associated methods. The GT system includes an exhaust section downstream of a turbine section and a combustion section including a plurality of combustor elements operably coupled to the turbine section. The monitoring system includes an exhaust probe for each of the plurality of combustor elements, the exhaust probes configured to be positioned circumferentially spaced apart in the exhaust section. Each exhaust probe is configured to sample, for example, the exhaust flow coming from a particular combustor element in the combustion section. The monitoring system also includes at least one exhaust analyzer operably coupled to the exhaust probes and configured to periodically measure the exhaust level of the exhaust flow from each exhaust probe. The combustor anomaly detection system is operably connected to at least one exhaust analyzer and is configured to determine whether the exhaust level at a selected exhaust probe among the exhaust probes deviates from an expected exhaust level by a predetermined threshold. If the exhaust level deviates from an expected exhaust level by a predetermined threshold, the combustor anomaly detection system identifies a combustor element anomaly in the combustor element from which the exhaust flow measured by the selected exhaust probes is generated and adjusts the operation of the combustor element having the combustor element anomaly. The monitoring system provides accurate identification of combustor malfunctions without the need for numerous sensors and without the associated maintenance costs and downtime.

[0037] Figure 1 shows a schematic block diagram of a gas turbine (GT) system 100 including a monitoring system 102. As described herein, the monitoring system 102 includes, among other things, a combustor anomaly detection system 110 according to embodiments of the present disclosure. The GT system 100 includes a compressor section 118, a combustion section 114 operably coupled to the compressor section 118 and including a plurality of combustor elements 116 (one is shown for clarity), and a turbine section 112 (e.g., an expansion turbine) operably coupled to the combustion section 114. The compressor section 118 is fluidly connected to the turbine section 112 through the combustion section 114. The combustion section 114 includes a plurality of combustor elements 116 which can be arranged in a can-annular combustor configuration 115 (see, for example, Figures 4-5) or an annular combustor configuration 117 (see, for example, Figure 6). The compressor section 118 may also be mechanically coupled to the turbine section 112 through a shaft 120.

[0038] The compressor section 118 includes an air inlet 122, and the turbine section 112 includes an exhaust outlet 124. An intake system 126 may be fluidly connected to the air inlet 122. The intake system 126 can regulate the air entering the compressor section 118. For example, the intake system 126 can remove or reduce moisture that may be carried by the air entering the air inlet 122. The exhaust section 130 is fluidly connected to the exhaust outlet 124 downstream of the turbine section 112. The exhaust section 130 can, among other things, regulate the exhaust gases passing from the turbine section 112 before being introduced into the ambient air. The GT system 100 may also include a driven load 132, which can take the form of, for example, a generator, a pump, or a vehicle.

[0039] As used herein, the “combustor element” 116 may include one or more burners 150 and may take on various forms. (The burners 150 may also be referred to as fuel nozzles.) Figure 2 shows a cross-sectional side view of an exemplary combustor element 116 in the form of a combustor can for a combustion section 114 usable in the GT system 100 of Figure 1, and Figure 3 shows an end view of the exemplary combustor can form of the combustor element 116 of Figure 2. In this form, referring to Figures 2 and 3, the combustion section 114 may include a circular array of multiple circumferentially spaced combustor elements 116 in the form of a combustor can. The fuel / air mixture is burned in any number of burners 150 in each combustor can to produce a high-temperature energy combustion gas flow, which flows through a transition piece 136 to the turbine nozzle 138 of the turbine section 112 (Figure 1). For the purposes of this specification, only one combustor can is shown, but it will be understood that all other combustor cans arranged around the combustion section 114 are substantially identical to the combustor can shown in Figure 2. The arrangement of multiple circumferentially spaced combustor cans has become known in the art as a can-annular combustor arrangement (or system).

[0040] Referring here to Figure 2, an exemplary combustor element 116 of the GT system 100 (Figure 1) is shown. The combustor element 116 in the form of a combustor can may include a primary combustion stage 142 and an optional secondary combustion stage 144. As described above, the transition piece 136 directs the hot combustion gas flow to the turbine nozzle 138 and turbine blades (not shown). The primary combustion stage 142 may include a casing 146, an end cover 148, a plurality of burners 150, a cap assembly 152, a flow sleeve 154, and a combustion liner 156 within the flow sleeve 154. An ignition device (not shown) is provided and may include an energized spark plug. Combustion in the primary combustion section 142 occurs within the combustion liner 156. Combustion air is guided through openings (not shown) in the flow sleeve 154 to convectively cool the combustion liner 156, and then guided through the burners 150, and optionally through a plurality of openings formed in the cap assembly 152. Air enters the combustion liner 156 under a pressure difference and mixes with fuel from multiple burners 150 within the combustion liner 156. As a result, a combustion reaction occurs within the combustion liner 156, releasing heat for the purpose of driving the turbine section 112 (Figure 1). High-pressure air for the primary combustion stage 142 can enter the flow sleeve 154 and transition piece impact sleeve 158 from the annular plenum 160 (e.g., compressor discharge plenum). The compressor section 118 (Figure 1), represented by a series of vanes and blades in 162 in Figure 2, as well as the diffuser 164, supplies high-pressure air for this purpose and for other uses to the burners 150.

[0041] As shown in Figure 2, the optional secondary combustion stage 144 may include a plurality of additional burners 166 (e.g., axial fuel injectors) for injecting the secondary fuel mixture laterally into the combustion gas flow products of the primary combustion stage 142. The burners 166 may include any type and number of injection elements for injecting the second fuel mixture. The burners 166 may extend radially into the combustion gas flow path, as shown, or they may be coplanar with the inner surface of the combustion liner 156. It will also be recognized that the secondary combustion stage 144 may be omitted.

[0042] As described above, the combustor element 116 may include a plurality of burners 150, such as the swirling fuel nozzle shown in Figure 3. In the case of a combustor can, each burner 150 may include any currently known or future-developed premixer configuration capable of mixing fuel and air and leading it downstream to the combustion chamber 140. In one non-limiting example, the burner 150 may be operably coupled to an end cover 148. The burner 150 may include any currently known or future-developed configuration for mixing an oxidizer (e.g., air) and fuel (e.g., liquid or gaseous fuel) before introducing them into the burner. For example, the burner 150 may include a plurality of swirling vanes 170 that impart rotation to the incoming air and a plurality of fuel ports (unlabeled) on the swirling vanes 170 that distribute the fuel in the swirling airflow. The fuel and air are then mixed in an annular passage called a burner tube within the burner 150 before reacting in the primary combustion zone 142 of the combustion chamber 140.

[0043] Although burner 150 is shown as a swirl fuel nozzle, it should be understood that other types of fuel nozzles may be used instead of, or in addition to, the swirl fuel nozzle. For example, one or more of the burners 150 may be bundle-tube fuel nozzles (also called "micromixers") in which each burner 150 contains multiple parallel tubes in which fuel and air are premixed upstream of the primary combustion zone 142. Various types of burners 150 can be used, and many variations are well known in the art, so no further details are provided, and the reader can therefore focus on the prominent features of this disclosure.

[0044] Any number of burners 150 may be used in the configuration of each combustor can of the combustor element 116. Figure 2 shows a non-limiting example in which six burners 150 are used, and Figure 3 shows an axial end view of the burners 150 in the combustor element 116 in which a five-around-one burner configuration is used. More or fewer burners 150 may be used in each combustor can.

[0045] Referring to Figure 6, the combustor element 116 may alternatively be provided as part of an annular combustor arrangement 117. In this configuration, the combustor element 116 may include a group or sector of burners 150; see the pie-shaped section in Figure 6. Each burner 150 can take any form typically used in an annular combustor arrangement. In this configuration, one or more circular rows of burners 150 are arranged in an annular shape and used to burn fuel as described with respect to Figure 2. In this configuration, each combustor element 116 may include one or more burners 150 from one or more circular rows. The structure of the burners 150 for this type of arrangement and its variations is well known in the art, so no further details are provided, and the reader can therefore focus on the notable points of this disclosure.

[0046] As described above, burner 150 may experience situations that could cause damage, especially when used with high-energy, high-temperature fuels such as hydrogen. A non-exclusive list of possible damage situations includes flashback, where the combustion reaction is supplied upstream to burner 150 after ignition rather than remaining within combustion chamber 140, and flame retention, where the combustion reaction occurs in burner 150, for example at ignition, but is not pushed or drawn into combustion chamber 140.

[0047] Figure 4 shows a schematic axial view of the exhaust section 130 of a GT system 100 (Figure 1) using a can annular combustor arrangement 115 according to an embodiment of the present disclosure. As shown in Figure 4, the exhaust section 130 includes a housing 174 having an outer surface 176 and an inner surface 178 defining an exhaust gas passage 179. The housing 174 is in fluid communication with the exhaust outlet 124 (Figure 1) of the turbine section 112 (Figure 1) so that exhaust flows through the housing 174. Other structures of the exhaust section 130, such as exhaust filters and / or other handling systems, are omitted as they are not relevant to the operation of the monitoring system 102. The combustor can of the combustion section 114 (labeled as combustor element 116) is shown superimposed in Figure 2 for illustrative purposes, but is not part of the exhaust section 130, i.e., it is located upstream of the turbine section 112. For illustrative purposes, twelve combustor cans (elements 116) are shown, but more or fewer combustor cans can be used in the combustion section 114 (Figure 1).

[0048] The monitoring system 102 includes an exhaust probe 180 for each of the multiple combustor elements 116. As shown in Figure 4, the exhaust probe 180 is configured to be positioned circumferentially spaced apart in the exhaust section 130 and to sample the exhaust flow coming in, i.e., from the turbine section 112 (Figure 1) through the exhaust gas passage 179. The exhaust probe 180 may include any currently known or future-developed structure capable of sampling the exhaust flow, such as an open tube facing upstream of the exhaust flow.

[0049] The monitoring system 102 also includes at least one emission analyzer 190 operably coupled to the emission probes 180 and configured to periodically measure the emission level of the exhaust flow from each emission probe 180. As shown in Figure 4, in certain embodiments, a single emission analyzer 190 may be used. In this case, the monitoring system 102 also includes a valve system 192 configured to periodically and operably couple each emission probe 180 to the single emission analyzer 190 under the control of the detection system 110. As shown in Figure 4, the valve system 192 may include valves 194 for controlling the flow of exhaust flow samples from each emission probe 180 to the single emission analyzer 190 through their respective conduits 196 (not all of which are labeled for clarity). The conduits 196 may include any type of tube or pipe capable of delivering a sample of the exhaust flow to the single emission analyzer 190. In some cases, a portion of the conduits 196 may be shared among the emission probes 180. A single exhaust analyzer 190 may include any currently known or future-developed mechanism, such as a vacuum, fan, or other gas flow generating element, for drawing in the sample exhaust flow and / or cleaning a specific conduit 196 of the exhaust flow sample.

[0050] Figure 5 shows a schematic axial view of the exhaust section 130 of the GT system 100 according to another embodiment of the present disclosure. As shown in Figure 5, in certain embodiments, an exhaust analyzer 190 may be provided for each of the exhaust probes 180. In this case, the monitoring system 102 includes conduits 196 (partially labeled) from the exhaust probes 180 to each exhaust analyzer 190. The conduits 196 may include any type of tube or pipe capable of delivering a sample of the exhaust flow to each exhaust analyzer 190. Each exhaust analyzer 190 may include any currently known or hereafter developed mechanism, such as a vacuum, fan, or other gas flow generating element, for drawing in the sample exhaust flow and / or cleaning the respective conduits 196 of the exhaust flow sample.

[0051] Figure 6 shows a schematic axial view of the exhaust section 130 of a GT system 100 (Figure 1) using an annular combustor arrangement 117 according to an embodiment of the present disclosure. Here, the exhaust section 130 can be configured as described above with respect to Figure 4, for example, using a housing 174 having an outer surface 176 and an inner surface 178 defining an exhaust gas passage 179. The combustor elements 116 in the form of groups or sectors of burners 150 of the combustion section 114 are shown superimposed in Figure 6 for illustrative purposes, but are not part of the exhaust section 130, i.e., are located upstream of the turbine section 112. For illustrative purposes, 24 burners 150 are shown in each circular row, and each combustor element 116 contains four burners 150 (two adjacent burners from each row). However, it is emphasized that other configurations of the annular combustor arrangement 117 are possible, for example, using more or fewer circular rows of burners 150, more or fewer combustor elements 116, or combustor elements 116 each having a different number of burners than four. Figure 6 is shown using the valve system 192 of Figure 4, but it will be recognized that the arrangement of the emission analyzer 190 of Figure 5 may be equally applicable to the annular combustor arrangement 117 of Figure 6.

[0052] In each embodiment, the emission analyzer 190 is communicably coupled to the detection system 110, for example, via wired or wireless communication. The detection system 110 can control when the emission analyzer 190 performs an analysis of exhaust gases from any of the emission probes 180. The period over which each emission analyzer 190 determines the emission level from each emission probe 180 can be defined by the user, for example, daily, weekly, or monthly. The emission analyzer 190 can compare, for example, previously stored emission levels (stored in memory 206 (Figure 1)) or a predetermined threshold, as will be further described herein, with nitrogen oxides (NOx). x Alternatively, the level of any desired form of discharge (such as NO) can be determined.

[0053] In Figures 4–6, the exhaust probes 180 are positioned circumferentially spaced apart, which is shown as coinciding with that in the schematic diagram of the combustor element 116. However, the diagrams are arranged this way for clarity, and it should be emphasized that this coinciding circumferentially aligned arrangement is not necessary in all cases, as two different sets of structures can be offset circumferentially. However, the circumferential arrangement of the combustor element 116 and the exhaust probes 180 is positioned so that the exhaust flow from each combustor element 116 can be measured by the respective exhaust probe 180. More specifically, the path of the exhaust flow from a particular combustor element 116 through the turbine section 112 and partially through the housing 174 of the exhaust section 130 can be identified using empirical data and / or any currently known or future-developed process such as flow modeling. Typically, the flow path data is placed in what is referred to as a “swirling chart,” as swirling is imparted to the combustion gases as they expand through the rotating blades of the turbine section 112. In this way, as will be further explained and as shown in Figure 4, the exhaust level from each specific combustor element 116 can be measured and analyzed by a specific exhaust probe 180 to identify a combustor abnormality for that combustor element 116.

[0054] For example, as shown in Figure 4, exhaust probe 180A can measure the exhaust level for combustor element 116A, exhaust probe 180B can measure the exhaust level for combustor element 116B, exhaust probe 180C can measure the exhaust level for combustor element 116C, and so on. In the illustrated example, each exhaust probe 180 is offset approximately 60° clockwise from the combustion can 116 from which the exhaust to be measured is generated. This situation represents the predicted approximately 60° swirl of the exhaust flow from the combustor element 116 through the turbine section 112 and / or exhaust section 130 to each exhaust probe 180 for a particular GT system 100 under a particular load. It will be recognized that the amount of swirl can vary dramatically within different GT systems 100, for example, under different loads and / or environmental conditions. Therefore, the arrangement of each GT system 100 may have its own specific set of swirl charts that determine the correspondence of the exhaust probes 180 to the combustor element 116 based on different loads and environmental conditions, among other factors. A similar arrangement can be used in the embodiments shown in Figures 5 and 6.

[0055] The monitoring system 102 of the GT system 100 also includes, among other structures controlling the characteristics of the combustion section 114, a combustor anomaly detection system 110 (Figure 1) (hereinafter referred to as "detection system 110" for brevity) operably connected to the exhaust analyzer 190. In Figure 1, the detection system 110 is shown as an entity independent of the GT system 100. It should be understood that the detection system 110 may be located in the same place as other control devices for the GT system 100, or it may be within a central global monitoring and detection system. Thus, the detection system 110 can receive data from multiple GT systems 100 located anywhere in the world from a single monitoring location and monitor combustion simultaneously. In contrast to conventional systems in which combustor anomalies are detected by examining trends in exhaust gas temperature and / or pressure over time, the detection system 110 identifies the presence of combustor anomalies, such as instantaneous high and / or low temperature spots, by evaluating the exhaust flow from each combustor element 116 within the exhaust section 130. As shown in Figure 1, the detection system 110 includes a central processing unit (CPU) 200, a computer-readable storage medium 202 on which a set of program instructions 204 are provided, and a memory 206. As will be described in more detail below, the detection system 110 can optionally be operably connected to an alarm 208 which can provide a visual and / or audible alarm when a combustion element (and / or burner) abnormality is detected.

[0056] Figure 7 shows a flowchart illustrating a method for monitoring combustor anomalies in a GT system 100, which includes an exhaust section 130 downstream of a turbine section 112 and a combustion section 114 including a plurality of combustor elements 116 operably coupled to the turbine section 112. More specifically, Figure 7 illustrates a method for detecting various combustor anomalies according to embodiments of the present disclosure. The method for detecting combustor anomalies can be carried out by a program instruction 204 (Figure 1) of the detection system 110.

[0057] The method is described here with reference to Figures 1 to 7. In the precursor process P1, the combustion section 114 is operated (in the GT system 100), and each emission probe 180 (i.e., emission probe number N) and emission analyzer 190 measures the respective emission levels in the exhaust section 130. As described above, each emission probe 180 measures the emission level from each combustor element 116, identified by a known exhaust flow path from the combustor element 116 through the exhaust section 130, for example, using the aforementioned swirling chart.

[0058] Process P2 describes repeatedly and periodically measuring emission levels using emission probes 180 and emission analyzers 190. Specifically, processes P1-P2 describe measuring the emission levels of the exhaust flow from each of a plurality of emission probes 180 positioned circumferentially spaced apart in the exhaust section 130, using emission analyzers 190 operably coupled to the emission probes 180. As described above, the plurality of emission probes 180 include emission probes for each of a plurality of combustor elements 116. As described above, the duration for which the emission probes 180 are used or accessed can be defined by the user, for example, daily, weekly, monthly, etc. Process P2 describes a detection system 110 that uses emission analyzers 190 to sequentially measure the emission levels from each emission probe 180, i.e., N+1, until all 12 probes 180 in Figure 4 have been measured.

[0059] In process P3, for each emission level measurement, the detection system 110 determines whether the emission level at a selected emission probe 180 from among a plurality of emission probes 180 deviates from the expected emission level by a predetermined threshold. The term “selected” is used to indicate a particular emission probe 180 from among a plurality of emission probes 180 that happens to have an emission level deviation as shown. The “expected emission level” is the predicted or normal emission level for the combustor element 116 in the GT system 100. In certain embodiments, the expected emission level for the combustor element 116 can be defined by the user based on factors such as, but are not limited to, the number, size, and type of combustor elements 116; the number, size, and type of burners 150 in each combustor element 116; the type of fuel (e.g., hydrogen, natural gas, oil, and / or a combination thereof); the fuel flow rate and / or pressure; the fuel splitting within the combustor element 116; the presence or absence of a secondary combustion zone 144 (Figure 2); the type and size of the GT system 100; the environmental conditions at the location of the GT system 100; the load and / or overall emission level of the GT system 100; and / or other operating characteristics of the GT system 100 and its combustion section 114. For example, the expected emission level could be, for example, a value or range of values ​​that a particular combustor element 116 having a particular number and a particular type and size of burners 150 would be expected to produce using a particular fuel.

[0060] In other embodiments, the detection system 110 can determine expected emission levels from a baseline emission pattern based on the load of the turbine section 112 of the GT system 100. In this case, the detection system 110 can refer to empirical data or models (e.g., based on algorithms, neural networks, or artificial intelligence) that show expected emission levels for each combustor element 116 based on the load of the turbine section 112, for example, 5000 ppm NOx for each combustor element 116 with a 50% load on the turbine section 112. The "overall emission level" is the emission level of all exhaust in the exhaust section 130 from all combustor elements 116, which can be measured by another emission probe 210 (Figure 1) at any suitable location in the exhaust section 130, for example, at the outlet of the exhaust section 130 to the periphery. The emission probe 210 can be coupled to any emission analyzer 190 or another dedicated emission analyzer (not shown) capable of measuring emission levels from the probe.

[0061] The “predetermined threshold” can be any user-selected emission level value configured to identify a combustor abnormality in the combustor element 116. The predetermined emission level may vary and may be based, for example, on any of the factors used to create the expected emission level. In one example, the predetermined threshold may be an increase in a set value in the emission level, such as a specific parts per million (ppm) value of NOx, indicating a combustion problem in the combustor element 116. In another example, the predetermined threshold may be a rate of increase in the emission level. In process P3, if the emission level of the selected emission probe 180 does not deviate from the expected emission level by exceeding the predetermined threshold, i.e., the result in process P3 is “no”, the process proceeds to process P2, where the emission level at the emission probe 180 is measured periodically.

[0062] Although the flowchart shows that the emission analysis is performed sequentially after measuring the emission level at each individual emission probe 180, the emission analysis in process P3 may alternatively be performed after the emission levels from all emission probes 180 have been obtained, i.e., before any analysis, by measuring the emission levels at all emission probes and omitting process P2.

[0063] In process P4, in response to the emission level of the selected emission probe 180 deviating from the expected emission level by exceeding a predetermined threshold, the detection system 110 identifies, i.e., indicates, that a "combustion element anomaly" exists in the combustor element 116 from which the exhaust flow measured by the selected emission probe 180 originates. For example, as shown in Figure 4, if the emission level from emission probe 180B determined by the emission analyzer 190 deviates from the expected emission level for combustor element 116B by exceeding a predetermined threshold, the detection system 110 identifies a combustor element anomaly occurring in combustor element 116B. The deviation may be an increase or decrease in the emission level. Indicating also may include determining which combustor element 116 the exhaust flow measured by the selected emission probe 180 originates from, for example, based on a swirling chart that maps the paths of the exhaust flow through the exhaust section 130 from each of a plurality of combustor elements 116.

[0064] In process P5, the detection system 110 adjusts the operation of the combustor element 116 having the detected combustor element anomaly. The adjustment can take various forms. For example, in response to the identification of a combustor element anomaly, the detection system 116 may change the fuel flow to at least one of the combustor elements 116 in the combustion section 114 (i.e., the entire combustor element), and to at least one of the combustor elements 116 having the combustor element anomaly, for example, the fuel flow to one or more of its burners 150. In a particular combustion section 114, several fuel circuits deliver fuel to different burners 150 in each combustor element 116. For example, if the combustor element 116 has the form of a combustor can and includes six burners 150, as shown in Figure 3, they can be grouped for fuel delivery using, for example, one central burner supplied by one fuel circuit (FC1), two outer burners supplied by another fuel circuit (FC2), and the remaining three burners supplied by another fuel circuit (FC3). In this case, the detection system 110 can independently control the fuel ratio to these fuel circuits within the combustor element 116C to address issues such as flashback combustion (i.e., to change the fuel split). In another example, the detection system 110 can change the fuel flow to one or more combustor elements 116 in the combustion section 114 in response to the identification of a combustor element anomaly to address a problem.

[0065] In another (more likely) example, the detection system 110 can shut down the combustion section 114 in response to the identification of a combustor element anomaly. That is, the detection system 110 can turn off all combustor elements 116 and any associated structures of the GT system 100, such as the turbine section 112. Once shut down, an inspection of the combustor elements 116C for damage can be performed. Such an inspection is facilitated by the detection system 110, which has identified a particular combustor element 116 exhibiting abnormal behavior. In an optional embodiment, the detection system 110 can also trigger an alarm 208 in response to the identification of a combustor element anomaly. Other adjustments are also possible.

[0066] If the combustor element 116 is adjusted based on the process described above, the specific burner 150 within the problematic combustor element 116 causing the anomaly may not be known, and the adjustment may be made to all burners 150, or to specific burners 150 that are known to be in a specific location, such as the central burner rather than the radially outer burners. Processes P5-1 to P5-3 are optional processes according to embodiments of the present disclosure. In this embodiment, once a specific combustor element 116 is identified as having a combustor element anomaly, the detection system 110 can also identify a “combustor burner anomaly” from among several burners 150 within the specific combustor element 116 having the combustor element anomaly. That is, the detection system 110 can also identify a specific burner 150 from among several burners 150 for a problematic combustor element 116 that may be causing the combustor element anomaly. Here, the problematic combustor element 116 can be corrected by adjusting one or more specific burners 150 of the problematic combustor element 116 that are known to be causing the problem, rather than blindly adjusting all burners collectively or specific burners. For illustrative purposes, combustor element 116C is referred to as having a combustor element abnormality, and burner 150X (Figure 3) is referred to as having a combustor burner abnormality.

[0067] In process P5-1, as shown in Figure 3, the detection system 110 sequentially turns off each of the multiple burners 150 (six in Figures 2 and 3) of the combustor element 116C having a combustor element abnormality, and measures the decrease in emission levels at the selected emission probe 180A (Figure 4) for the combustor element 116C (Figure 4). The decrease in emission levels occurs after sufficient time for the exhaust flow from the combustor element 116C to reach and / or settle into a consistent pattern at the selected emission probe 180A. Thus, process P5-1 results in the respective emission level decrease measurements for each burner 150 when it is turned off.

[0068] In process P5-2, the detection system 110 identifies the presence of a combustor burner anomaly in burner 150X (Figure 3) of the multiple burners 150 of the combustor element 116C having a combustor element anomaly by identifying the burner (i.e., burner 150X) that has the greatest drop in emission levels while off. That is, in the case of a combustor element 116C having a combustor element anomaly, the specific burner 150X causing the combustor anomaly can typically be identified as the burner that generates a higher emission level and causes the greatest emission drop during the sequence by turning off each burner 150 of the combustor element 116C.

[0069] In process P5-3, the detection system 110 adjusts the operation of the burner 150X having a combustor burner malfunction. The adjustment can take various forms. For example, in response to the identification of a combustor burner malfunction, the detection system 110 may reduce the fuel flow from the combustor element 116C to the burner 150X. In another example, the detection system 110 may shut down the burner 150X having a combustor burner malfunction. In either case, the remaining burners 150 can operate as desired. If one burner 150X is identified as having a combustor burner malfunction and that burner 150X is turned off, processes P5-1 to P5-3 may be repeated for the other burners 150 in the combustor element 116C having a combustor element malfunction.

[0070] Processes P5-1 to P5-3 may be repeated a fixed number of times, for example, two to three times. The number of times the process is repeated may be based on the number of burners 150 in the combustor element 116 in a particular GT system 100, and it is understood that if the number of burners 150 to be adjusted is too large, it may be prudent to perform a more comprehensive shutdown and maintenance on the combustor 116C. In an optional embodiment, the detection system 110 may also trigger an alarm 208 in response to the identification of a combustor burner abnormality. Although the combustion burner abnormality has been described in relation to a single burner 150X, in practice it may include several burners sharing a fuel supply circuit (e.g., FC3), and it will be recognized that the periodic shutdown process may be applied to the fuel circuit rather than to individual burners 150.

[0071] Embodiments of this disclosure offer various technical and commercial advantages, examples of which are discussed herein. The monitoring systems described herein provide accurate identification of combustor abnormalities in combustor elements and / or burners of combustor elements without the use of numerous sensors and without the costs and downtime associated with maintenance.

[0072] The term "operably coupled" can be interpreted, to the understanding of those skilled in the art, as being configured such that each component is fluidly connected to one another and exchanges fluids with one another.

[0073] Throughout this specification and the claims, the approximation language can be applied to modify any quantitative expression that can vary to a reasonable extent without altering the fundamental function of the expression. Thus, values ​​modified by terms such as “approximately,” “about,” and “substantially” are not limited to the exact value specified. In at least some examples, the approximation language can correspond to the precision of the instrument used to measure the value. Herein, and throughout this specification and the claims, limitations on ranges are interchangeable and / or substitutable, and unless the context or wording specifically indicates otherwise, such ranges are identified and include all subranges encompassed therein. “Approximately” or “about” applied to a particular value within a range may indicate + / - 10% of the stated value, unless applied to the values ​​at both ends and particularly dependent on the precision of the instrument used to measure the value.

[0074] All means or step-plus-function elements in the following claims are intended to include any structures, materials, or actions for performing a function in combination with other claimed elements specifically claimed. The descriptions in this disclosure are presented for illustrative and explanatory purposes and are not intended to be exhaustive or to limit the disclosure to the forms disclosed herein. Many modifications and variations will be apparent to those skilled in the art without departing from the scope of this disclosure. The embodiments have been selected and described to best illustrate the principles of this disclosure and the practical applications of the art, and to enable those skilled in the art to understand this disclosure in order to consider various modifications to these embodiments that may be suitable for the particular use under consideration. [Explanation of Symbols]

[0075] 100 Gas Turbine (GT) System 102 Monitoring System 110 Combustor Anomaly Detection System 112 Turbine Section 114 Combustion Section 115-can annular combustor arrangement 116 Combustor elements 116A Combustor element 116B Combustor element 116C Combustor element 117 Annular combustor arrangement 118 Compressor Section 120 shaft 122 Air Inlet 124 Exhaust outlet 126 Intake System 130 Exhaust Section 132 Driven load 136 Transition Pieces 138 Turbine Nozzle 140 Combustion Chamber 142 Primary Combustion Stage / Primary Combustion Section / Primary Combustion Zone 144 Secondary combustion stage / secondary combustion zone 146 Casing 148 End cover 150 burners 150X Burner 152 Cap Assembly 154 Flow Sleeve 156 Combustion Liner 158 Transition Piece Collision Sleeve 160 Ring Plenum 162 Series of vanes and blades 164 Diffuser 166 Burner 170 Swivel vanes 174 Housing 176 Exterior 178 Inner self 179 Exhaust gas passage 180 Discharge probe 180A discharge probe 180B Discharge Probe 180C discharge probe 190 Emission analyzer 192 valve system 194 valves 196 Conduit 200 Central Processing Unit (CPU) 202 Computer-readable storage media 204 Program Instructions 206 memory 208 Alarm 210 Discharge probe FC1 fuel circuit FC2 fuel circuit FC3 fuel circuit P1 Process P2 process P3 process P4 process P5 Process P5-1 Process P5-2 Process P5-3 Process

Claims

1. A method for monitoring a combustor malfunction in a gas turbine system (100) including an exhaust section (130) downstream of a turbine section (112) and a combustion section (114) including a plurality of combustor elements (116) operably coupled to the turbine section (112), (P1) measuring the emission level of the exhaust flow from each of the multiple exhaust probes (180) positioned circumferentially spaced apart in the exhaust section (130) using at least one exhaust analyzer (190) operably coupled to a plurality of exhaust probes (180), wherein the plurality of exhaust probes (180) includes at least one exhaust probe (180) provided on each of the plurality of combustor elements (116), (P2) Determining whether the discharge level at a selected discharge probe (180) among the plurality of discharge probes (180) deviates from the expected discharge level by exceeding a predetermined threshold, In response to the fact that the emission level of the selected emission probe (180) exceeds the predetermined threshold and deviates from the expected emission level, it is determined which combustor element (116) the exhaust flow measured by the selected emission probe (180) originates from, and it is identified that there is a combustor element abnormality in the combustor element (116) from which the exhaust flow measured by the selected emission probe (180) originates (P4), Adjusting the operation of the combustor element (116) having the aforementioned combustor element abnormality (P5) Methods that include...

2. The method according to claim 1, comprising determining which combustor element (116) the exhaust flow measured by the selected exhaust probe (180) originates from, based on a swirling chart that maps the path of the exhaust flow from each of the plurality of combustor elements (116) through the exhaust section (130).

3. The method according to any one of claims 1 to 2, comprising triggering an alarm (208) in response to the identification of the combustion element abnormality.

4. In response to the identification of the aforementioned combustor element abnormality, At least one combustor element (116) in the combustion section (114), or At least a portion of the combustor element (116) having the aforementioned combustor element abnormality The method according to any one of claims 1 to 3, comprising changing the fuel flow to at least one of the following.

5. The method according to any one of claims 1 to 4, comprising stopping the combustion section (114) in response to the identification of the abnormality of the combustor element.

6. The load on the turbine section (112) of the gas turbine system (100), and A proportional distribution portion of the overall emission levels of all of the multiple combustor elements (116) in the exhaust section (130) attributable to a single combustor element among the multiple combustor elements (116). The method according to any one of claims 1 to 5, comprising determining the expected emission level from a baseline emission pattern based on at least one of the following.

7. The process involves sequentially turning off each of the multiple burners (150) of the combustor element (116) having the combustor element abnormality, and measuring the decrease in the emission level at the selected emission probe (180) (P5-1), Identifying that one of the multiple burners (150) of the combustor element (116) having the combustor element abnormality has the greatest decrease in the emission level during the off period, and determining that a combustor burner abnormality exists in the burner (150) having the greatest decrease in the emission level (P5-2), Adjusting the operation of the burner (150) having the combustion burner abnormality (P5-3) The method according to any one of claims 1 to 6.

8. The method according to any one of claims 1 to 7, comprising operating a valve system (192) to periodically and operably couple each of the plurality of discharge probes (180) to a single discharge analyzer (190).

9. A system (102) configured to detect a combustor abnormality in a gas turbine system (100), wherein the gas turbine system (100) includes an exhaust section (130) downstream of a turbine section (112) and a combustion section (114) including a plurality of combustor elements (116) operably coupled to the turbine section (112), and the system (102) A plurality of exhaust probes (180), wherein at least one exhaust probe (180) is provided for each of the plurality of combustor elements (116), and the exhaust probes (180) are configured to be positioned circumferentially spaced apart in the exhaust section (130), and each exhaust probe (180) is configured to sample the incoming exhaust flow. At least one exhaust analyzer (190) is operably coupled to the exhaust probe (180) and configured to periodically measure the exhaust level of the exhaust flow from each exhaust probe (180), A combustor malfunction detection system (110) operably connected to at least one exhaust analyzer (190), wherein the combustor malfunction detection system (110) The process involves determining whether the discharge level at a selected discharge probe (180) among the discharge probes (180) deviates from the expected discharge level by exceeding a predetermined threshold, In response to the fact that the emission level of the selected emission probe (180) exceeds the predetermined threshold and deviates from the expected emission level, it is determined which combustor element (116) the exhaust flow measured by the selected emission probe (180) originates from, and it is identified that there is a combustor element abnormality in the combustor element (116) from which the exhaust flow measured by the selected emission probe (180) originates, To generate an output signal configured to adjust the operation of the combustor element (116) and A combustor abnormality detection system (110) configured to perform the following: A system (102) comprising the above.

10. The system (102) according to claim 9, wherein the output signal configured to adjust the operation of the combustor element (116) is configured to adjust the operation of the combustor element (116) having a combustor element abnormality.

11. The system (102) according to any one of claims 9 or 10, wherein the at least one exhaust analyzer (190) comprises a single exhaust analyzer (190) and further comprises a valve system (192) configured to periodically and operably couple each exhaust probe (180) to the single exhaust analyzer (190) under the control of the combustor malfunction detection system (110).

12. The system (102) according to any one of claims 9 or 10, wherein the at least one discharge analyzer (190) includes a discharge analyzer (190) for each of the discharge probes (180).

13. The combustor abnormality detection system (110) is configured to carry out the method described in any one of claims 1 to 7, the system (102) according to any one of claims 9 to 12.

14. Compressor section (118), A combustion section (114) is operably coupled to the compressor section (118) and includes a plurality of combustor elements (116), A turbine section (112) is operably coupled to the combustion section (114), The exhaust section (130) downstream of the turbine section (112), A system (102) for monitoring a combustor malfunction according to any one of claims 9 to 13, wherein the discharge probe (180) of a plurality of discharge probes (180) is positioned circumferentially spaced apart in the exhaust section (130), and each discharge probe (180) is configured to sample the incoming exhaust flow. A gas turbine system (100) equipped with the following.

15. The gas turbine system (100) according to claim 14, wherein the combustor abnormality detection system (110) is configured to generate an output signal configured to adjust the operation of each of the plurality of combustor elements (116) when an abnormality of each of the combustor elements (116) is detected.

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