Controlling a power generation system using multiple maintenance modes during online maintenance

Abstract

Embodiments of the present disclosure provide a method for controlling a power generation system (100) during online maintenance. The method includes operating the power generation system (100) in a first maintenance mode, which causes a controller (180) of the power generation system (100) to disable an automatic response to at least one operational fault of the power generation system (100); monitoring a risk parameter of the power generation system (100) or at least one sensor (164) within the power generation system (100) while operating the power generation system (100) in the first maintenance mode; and operating the power generation system (100) in a second maintenance mode in response to detecting an override command, an elapsed time exceeding a time limit, or the monitored risk parameter exceeding a safety threshold. The second maintenance mode causes the controller (180) of the power generation system (100) to enable the automatic response to the at least one operational fault of the power generation system (100).

Description

Background Technology

[0001] This disclosure relates generally to the operation of power generation systems. More specifically, embodiments of the invention provide a method for controlling a power generation system during online maintenance operations by providing multiple maintenance modes.

[0002] A power generation system (also known as a power plant) typically comprises a variety of different systems (e.g., turbines, generators, and / or other interconnected components) for generating power output. Such a power plant may include a power source (e.g., a turbine, solar panels, a nuclear reactor, etc.), a prime mover (e.g., a rotatable shaft or similar element) for coupling the power source to the generator, and / or various components of the generator. For example, a power generation system may include a gas turbine assembly having a compressor coupled to the gas turbine. The gas turbine may then be coupled to and drive a generator mounted on the same shaft. The generator produces power output.

[0003] Power generation systems are designed and constructed to operate for several years. During this time, aging and continued use will require maintenance of the system and its components, such as repairs, replacements, upgrades, and / or other types of repairs. Given the continuous demand for electricity from customers of the power infrastructure, a complete shutdown for "offline" maintenance is not advisable unless absolutely necessary. Many power generation systems allow operation in a "maintenance setting" (i.e., a setting where the system continues to generate electricity at a modified output). Operations in this maintenance setting are possible during periods of lower demand. When the system operates in this setting, repairs (e.g., mechanical repairs or decontamination), replacements, upgrades of target components or parts, etc., are performed. Maintenance of the power generation system in this state is referred to as "online maintenance."

[0004] Online maintenance setups, characterized by several power generation systems, may face technical challenges that limit their effectiveness. For example, many systems used to monitor variables (such as the concentration of hazardous fluids) or other variables (such as shaft speed, fluid pressure, vibration amplitude, etc.) may trigger online maintenance in response to minor anomalies. When such anomalies do not indicate significant system problems, switching to and / or switching out of online maintenance consumes substantial time and costs, in the form of lost power output, repair time, purchasing spare parts, and / or repairing equipment. Increasing the threshold for each monitored variable to reduce false alarms can lead to system problems going undetected. In extreme cases, managing reduced system failures may require shutting down the power generation system for offline maintenance. Summary of the Invention

[0005] This disclosure provides a method for controlling a power generation system during online maintenance, the method comprising: operating the power generation system in a first maintenance mode, wherein operating the power generation system in the first maintenance mode causes the controller of the power generation system to disable automatic response to at least one operational fault of the power generation system; while operating the power generation system in the first maintenance mode, monitoring a risk parameter of the power generation system or at least one sensor within the power generation system; and, in response to detecting an overwrite command, an elapsed time exceeding a time limit in the first maintenance mode, or a monitored risk parameter exceeding a safety threshold, operating the power generation system in a second maintenance mode, wherein operating the power generation system in the second maintenance mode causes the controller of the power generation system to enable automatic response to at least one operational fault of the power generation system.

[0006] Another aspect of this disclosure provides a program product stored on a computer-readable storage medium for controlling a power generation system during online maintenance, the computer-readable storage medium including program code for causing a computer system to perform actions including: operating the power generation system in a first maintenance mode, wherein operating the power generation system in the first maintenance mode causes the controller of the power generation system to disable automatic response to at least one operational failure of the power generation system; monitoring risk parameters of the power generation system or at least one sensor within the power generation system while operating the power generation system in the first maintenance mode; and operating the power generation system in a second maintenance mode in response to detecting an overwrite command, an elapsed time exceeding a time limit in the first maintenance mode, or a monitored risk parameter exceeding a safety threshold, wherein operating the power generation system in the second maintenance mode causes the controller of the power generation system to enable automatic response to at least one operational failure of the power generation system.

[0007] Additional aspects of this disclosure provide a system comprising: a power generation system configured to operate in an online maintenance setting; a system controller communicating with the power generation system and configured to perform actions during operation of the power generation system in the online maintenance setting, the actions comprising: operating the power generation system in a first maintenance mode, wherein operating the power generation system in the first maintenance mode causes the controller of the power generation system to disable automatic response to at least one operational failure of the power generation system; monitoring a risk parameter of the power generation system or at least one sensor within the power generation system while operating the power generation system in the first maintenance mode; and operating the power generation system in a second maintenance mode in response to detecting an overwrite command, an elapsed time exceeding a time limit in the first maintenance mode, or a monitored risk parameter exceeding a safety threshold, wherein operating the power generation system in the second maintenance mode causes the controller of the power generation system to enable automatic response to at least one operational failure of the power generation system.

[0008] Exemplary aspects of this disclosure are designed to address the problems described herein and / or other problems not discussed herein. Attached Figure Description

[0009] These and other features of the present disclosure will be more readily understood from the following detailed description of various aspects of the present disclosure in conjunction with the accompanying drawings depicting various embodiments thereof, wherein:

[0010] Figure 1 This is a schematic diagram of a controller, power generation system and other components configured for use in a method according to an embodiment of this disclosure.

[0011] Figure 2 This is a block diagram illustrating the interaction between the controller and the power generation system in a method according to an embodiment of this disclosure.

[0012] Figure 3 A schematic diagram of a power generation system, controller and other components configured for use according to an embodiment of the present disclosure is shown.

[0013] Figure 4 An exemplary flowchart of a method for controlling a power generation system during online maintenance, according to an embodiment of this disclosure, is provided.

[0014] It should be noted that the accompanying drawings of this disclosure are not drawn to scale. The drawings are intended to depict only typical aspects of this disclosure and therefore should not be considered as limiting the scope of this disclosure. In the drawings, similar numbers denote similar elements between the figures. Detailed Implementation

[0015] First, in order to clearly describe the present art, it will be necessary to select certain terms when referring to and describing related machine parts within the various systems, components, and other embodiments of this disclosure. To the extent possible, common industry terms will be used and adopted in a manner consistent with the accepted meaning of the terms. Unless otherwise stated, such terms should be given a broad interpretation consistent with the context of this application and the scope of the appended claims. Those skilled in the art will understand that several different or overlapping terms may generally be used to refer to a particular part. An object that can be described herein as a single part may include multiple parts and is referred to in another context as being composed of multiple parts. Alternatively, an object that can be described herein as comprising multiple parts may elsewhere be referred to as a single part.

[0016] In addition, several descriptive terms may be used regularly in this document, 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 a single component.

[0017] The terminology used herein is for the purpose of describing particular embodiments only and is not intended to limit this disclosure. As used herein, the singular forms “a,” “an,” and “the” are intended to include the plural forms as well, unless the context clearly indicates otherwise. It will be further understood that, when used in the specification, the terms “comprising” and / or “including” specify the presence of stated features, integers, steps, operations, elements, and / or components, but do not exclude the presence or addition of one or more other features, integers, steps, operations, elements, components, and / or groups thereof. “Optional” or “optionally” means that an event or condition subsequently described may or may not occur, and the description includes instances where the event occurs and instances where the event does not occur.

[0018] When an element or layer is referred to as “on,” “joined to,” “connected to,” or “linked to” another element or layer, it may be directly on, joined to, connected to, or linked to another element or layer, or an intermediary element or layer may be present. In contrast, when an element is referred to as “directly on another element or layer,” “directly joined to another element or layer,” “directly connected to another element or layer,” or “directly linked to another element or layer,” an intermediary element or layer may not be present. Other terms used to describe relationships between elements should be interpreted in a similar manner (e.g., “between” vs. “directly between,” “adjacent” vs. “directly adjacent,” etc.). As used herein, the term “and / or” includes any and all combinations of one or more of the associated listed items.

[0019] This disclosure provides methods, procedures, and systems for operating a power generation system in a maintenance setup. The method according to this disclosure uses multiple maintenance modes to allow the power generation system to operate in a first maintenance mode without requiring at least one automatic response to operational failures of the power generation system (i.e., automatic shutdown, changes in ignition rate, temperature, pressure, etc.). When operating in the first maintenance mode, one or more sensors of the power generation system can monitor various risk parameters, such as chemical parameters like gas concentration, mechanical parameters like shaft speed, and / or electrical parameters like power output. In this state, any of several conditions can cause the power generation system to switch from operating in the first maintenance mode to operating in a second maintenance mode. For example, detecting an overwrite command, operating in the first maintenance mode for an extended period beyond a time limit, and / or one of the monitored risk parameters exceeding a safety threshold can cause the power generation system to operate in the second maintenance mode. In the second maintenance mode, the controller of the power generation system re-enables automatic responses to operational failures, thereby making the power generation system more sensitive to various maintenance scenarios. Therefore, the method according to this disclosure allows for limited operation with more relaxed monitoring while ensuring safety through automatic recovery of preventative responses to operational risks.

[0020] Figure 1 A schematic diagram of a power generation system 100 configured for implementing various embodiments of the present disclosure is shown. According to one example, the power generation system 100 may include a turbine 102 (e.g., a gas turbine assembly), but other types of power sources and / or components may also be used in embodiments of the present disclosure. The turbine 102 itself may be one of two, five, ten, one hundred, or more turbines in a power plant, and is only for illustrative purposes. Figure 1 The diagram shows only one turbine assembly. In a non-limiting example, turbine 102 may include a gas turbine, which may include compressor 122. As an inlet fluid flow (e.g., air) from inlet 124 flows through compressor 122, compressor 122 compresses the inlet fluid flow. Compressor 122 may include a multi-stage stator vanes (not shown) and rotating blades (not shown) positioned within compressor 122. The stator vanes and rotating blades positioned within compressor 122 may be configured to facilitate the movement and / or delivery of fluid through compressor 122. Compressor 122 may include a set of inlet guide vanes (IGVs) 126. IGV 126 is an adjustable compressor nozzle specifically configured to guide the inlet working fluid flow onto the rotating blades of compressor 122. IGV 126 is adjustable between several positions to affect the flow rate, angle of incidence, and / or other characteristics of the fluid entering compressor 122. IGV 126 is thus able to affect the temperature of compressor 122, power output from power generation system 100, and / or other characteristics.

[0021] Compressor 122 delivers a compressed fluid stream (e.g., compressed air) to combustor 138. Combustor 138 mixes the compressed fluid stream with a pressurized fuel stream supplied by fuel source 140 and ignites the mixture to produce a combustion gas stream. The combustion gas stream is then delivered to turbine component 142, which typically includes multi-stage stator vanes (not shown) and turbine blades (not shown), similar to compressor 122. Exhaust gases from combustion within combustor 138 may flow to exhaust component 144. Exhaust component 144 may include various filtration instruments to remove harmful substances from the exhaust gas before they reach interconnecting components (e.g., heat recovery steam generator). The combustion gas stream drives turbine component 142 to generate mechanical work. The mechanical work generated in turbine component 142 drives compressor 122 via shaft 150 and can be used to drive generator 152 (e.g., an external component) configured to generate electricity. Generator 152 may be electrically coupled to electrical infrastructure for supplying electricity to customers, such as various transmission lines (not shown), via power substations, distribution lines, etc.

[0022] Various parts of the power generation system 100 may also include or be in fluid communication with a cooling fluid source 154 for directing one or more cooling fluids (e.g., air, various refrigerants, etc.) to the various components of the power generation system 100. In many cases, the cooling fluid source 154 may be a fluid coupled to the fluid within the compressor 122 for siphoning to other components of the power generation system 100. In other types of power generation systems, the cooling fluid source 154 may be a dedicated cooling fluid source. The cooling fluid source 154 may be a dedicated fluid source and / or may be connected to ambient air or water. One or more cooling passages, air circuits, etc., may control the flow of cooling fluid from the cooling fluid reservoir throughout the power generation system 100 to cool the compressor 122, turbine assembly 142, generator 152, and / or other components. One or more valves 162 may be used to control the flow of fluid to, from, or within the power generation system 100. Such fluids may include, for example, fuel from fuel source 140, cooling fluid from cooling fluid source 154, and / or other fluid sources directed to, from, or within the power generation system 100. Each valve 162 may take the form of any currently known or later developed component for controlling the flow of fluid through a pipeline used to transport the fluid. Regardless of how valve 162 is implemented, one or more variables of the operable fluid within turbine component 142, such as quantity, temperature, flow rate, etc., can be affected by adjusting the position of control valve 162, as described herein. Valve 162 may control the quantity or fraction of fuel, operable fluid, cooling fluid, etc., circulating to, from, or within the power generation system 100. Some valves 162 may take the form of three-way valves coupled to one or more bypass lines, for example, configured to allow fluid to bypass one or more components of the power generation system 100 and / or discharge from one or more components of the power generation system.

[0023] The power generation system 100 and its connected components (e.g., fuel source 140 and / or cooling fluid source 154) may include one or more sensors 164 for monitoring parameters such as mechanical, electrical, and / or chemical parameters. In one example, sensor 164 may be in the form of a temperature sensor, gas sensor, flow sensor, pressure sensor, and / or other means for assessing the properties of the power generation system 100 and / or materials therein at a particular location. Sensor 164 may include fluid concentration sensors, such as those for detecting the concentration of hazardous and / or explosive fluids (e.g., methane) and / or other materials harmful to the power generation system 100 (e.g., corrosive acids and / or gases). In this case, sensor 164 may be located in exhaust component 144 and / or other parts of the power generation system 100 where such gases may be present. Sensor 164 for detecting hazardous fluids may include suction sensors, direct point sensors, light-based sensors, catalytic bead sensors, electrochemical sensors, and / or ultrasonic sensors.

[0024] Sensor 164 in the form of a temperature sensor may include a thermometer, a thermocouple (i.e., a voltage device that indicates a change in temperature relative to a change in voltage), a resistive temperature sensing device (i.e., a device for assessing temperature based on a change in resistance), an infrared sensor, an expansion-based sensor (i.e., a sensor for deriving a temperature change based on the expansion or contraction of a material such as a metal), and / or a state change sensor. Sensor 164 in the form of a pressure sensor may include a barometer, a pressure gauge, a tactile pressure sensor, an optical pressure sensor, an ionization pressure sensor, etc. To calculate the flow rate and / or other dynamic characteristics of the operable fluid, sensor 164 may include, for example, an air flow meter, a mass flow sensor, a gas velocity meter, etc. Sensor 164 may also derive one or more parameters from other measured quantities, such as temperature, pressure, flow rate, etc. These measured quantities may then be measured at multiple locations in turbine component 142 and / or power generation system 100 and applied to a mathematical model of the fluid flowing through a particular component (e.g., via controller 180 as described herein). In this context, sensor 164 may include components for measuring temperature-related variables and processing components (e.g., computer software) for predicting and / or calculating temperature values ​​or other measures based on the relevant variables. Generally, in the context of sensor 164, the term "monitoring" refers to a direct measurement and / or process of mathematically calculating a specific value through direct measurement, predictive modeling, deriving from relevant quantities, and / or other mathematical techniques for measuring and / or finding a specific quantity. In any case, the conditions measured by each sensor 164 can be indexed, tabulated, etc., according to the corresponding measurement time, or, in the case of a movable sensor 164, indexed, tabulated, etc., at the corresponding location. In some cases, controller 180 may act as a "pseudo-sensor" for calculating (e.g., by estimation or derivation) one or more operating conditions within the power generation system 100 at locations not including sensor 164.

[0025] One or more sensors 164 may include energy sensors for measuring, for example, energy output from power generation system 100 and / or generator 152. Such sensors 164 may be embodied as any currently known or later-developed apparatus for measuring the energy generated by power generation system 100 and / or generator 152, including but not limited to current sensors, voltage detectors, magnetometers, speed sensors configured to measure the rotational speed of shaft 150 (including, for example, optical-based sensors, position sensors, capacitance sensors, tachometers, etc.), and / or other types of sensors for calculating the amount of energy generated by power generation system 100 and / or generator 152. Regardless of the implementation used, sensors 164 may be communicatively connected (e.g., electrical and / or wireless) to controller 180 to calculate the energy output of power generation system 100 and / or generator 152. Furthermore, the energy output detected using sensors 164 may be time-tabulated or otherwise indexed, such that the calculated energy output can be cross-referenced in controller 180 to other parameters monitored using other sensors 164. The controller 180 can calculate the energy output from the power generation system 100 and / or the generator 152, which corresponds to a set of input conditions, output conditions, etc., monitored by the sensor 164.

[0026] The power generation system 100 may include a controller 180 configured to monitor and / or control the operation of the power generation system 100. The controller 180 may be structurally integrated into the power generation system 100 or may be implemented as a separate controller communicating with the power generation system 100. The controller 180 may operatively communicate with the power generation system 100 via any suitable electronic and / or mechanical communication components or technologies. The controller 180 and its various components discussed herein may each be a single, independent system, either as part of or separate from another power plant control system (e.g., a computing device) (not shown), which may control and / or regulate the operation and / or functions of the power generation system 100. The controller 180 may be operatively coupled to a sensor 164, for example via one or more electrical couplings, wireless data couplings, etc., to receive information from it. Thus, various characteristics measured by the sensor 164 may be measured and / or converted into electrical signals or inputs relayed to the controller 180. In some cases, the controller 180 may operatively communicate with a valve 162 or other elements of the power generation system 100 to regulate its operation in real time. The controller 180 may use the sensor 164 to monitor and control the operation of the power generation system 100 in maintenance mode, for example, to enable or disable various automatic responses to one or more risk parameters as described herein.

[0027] To achieve the various control features of this disclosure, controller 180 may be operatively coupled to one or more valves 162, such that controller 180 controls the position of valve 162 during operation of power generation system 100. More specifically, controller 180 may adjust the position of valve 162 based on measurements collected by and / or derived from sensor 164. In an exemplary embodiment, controller 180 may adjust the position of valve 162 based on a calibrated performance model using measurements of operating conditions, energy output, etc., generated from sensor 164. In addition to directly controlling variables such as temperature, pressure, and fluid flow rate through various parts of power generation system 100, valve 162 may also affect other characteristics of the path of combustion of fuel and / or cooling fluid through power generation system 100 (e.g., volume increase due to thermal expansion, thermal stress, etc.). Furthermore, controller 180 remains operable to regulate additional properties of power generation system 100, for example, by controlling the amount of combustion in burner 138 and / or the amount of cooling fluid drawn from cooling fluid source 154. To this end, controller 180 may include program code that includes a model for operating power generation system 100 in maintenance mode. Such a model may include one or more automatic responses to various operational failures (e.g., pressure, temperature, hazardous fluid concentration, etc.) exceeding corresponding thresholds.

[0028] Figure 2 Various operational interactions between a power generation system 100 and a controller 180 according to an exemplary embodiment are illustrated in schematic form. As noted herein, the power generation system 100 may be communicatively coupled to the controller 180, such that various components of the power generation system 100 provide data to the controller 180. The controller 180 may operate and / or interpret the provided data to influence the operation of the power generation system 100. The controller 180 may implement one or more operating methods to interact with and / or control the power generation system 100. Embodiments of the present invention may provide a separate process for controlling the power generation system 100 by the controller 180. In some embodiments, the controller 180 may interact with and / or override existing methods for controlling the operation of the power generation system 100. Such existing methods may operate on the same data as embodiments of this disclosure or on other data received from the power generation system 100 and / or other sources. Figure 2As shown in the example, controller 180 may receive monitored data from power generation system 100 (e.g., hazardous fluid concentration, shaft speed, airflow rate, power output level, etc.) via one or more sensors 164. In addition or alternatively, controller 180 may receive various forms of sensor quality data 164, indicating, for example, the fidelity of various types of data collected by sensors 164. Sensor quality data provided to controller 180 may include parameters such as airflow rate through sensors 164 (e.g., in the case of a suction sensor), total deployment time of various sensors 164, estimation errors (e.g., comparing measurements from several similar sensors 164 to each other and / or comparing expected measurements with actual measurements), and / or other variables indicating sensor quality.

[0029] As discussed herein, maintenance control procedure 212 may use various types of data from power generation system 100 and / or sensor 164 to determine whether it is possible to operate power generation system 100 in a “first maintenance mode.” A first maintenance mode refers to any type of online maintenance mode that disables at least one automatic response of controller 180 to operational faults. For example, a first maintenance mode may disable automatic shutdown of power generation system 100, which would otherwise occur if monitored hazardous fluid concentrations, shaft speeds, efficiency losses, and / or other parameters exceed certain thresholds. Therefore, a first maintenance mode may allow continued operation of power generation system 100 with a modified (e.g., relaxed) response to detected faults, but with different safeguards to distinguish between false alarms and actual faults in power generation system 100. In some cases, maintenance control procedure 212 may also determine whether controller 180 must operate power generation system 100 in a “second maintenance mode” (i.e., an operating state where automatic responses to operational faults are re-enabled). As noted herein, the power generation system 100 may operate in a second maintenance mode once the controller 180 detects that a risk parameter exceeds a safety threshold, an overwrite command is issued by a user or other component, and / or operation in the first maintenance mode exceeds the permissible time limit. In any case, the controller 180 may generate control functions (e.g., various diagnostic and protective actions) that directly affect the operation of the power generation system 100. In some cases, one or more intermediary components (e.g., converters (not shown)) may receive control functions output from the controller 180 to modify the operation of the power generation system 100.

[0030] See Figure 3 A schematic diagram is shown of the controller 180 and its sub-components as part of the power generation system 100. Figure 3 The diagram shows only one power generation system 100 in detail, and for clarity, Figure 3 The controller 180 is only schematically shown in the diagram. Figure 1The controller 180 is operatively coupled between various components of the power generation system 100. As shown, the controller 180 may include a computing device 200, which may include a memory 202 and a control system 204 operating thereon. The control system 204 may be a software system integrated with a portion of the actuator 170, or otherwise operatively communicate with it. The control system 204 may include, for example, a maintenance control program 212. The maintenance control program 212 may enable the controller 180 to act on the power generation system 100 and / or modify the power generation system, and / or may modify the existing operating methods of the controller 180 for operating the power generation system 100. Figure 3 The controller 180 shown represents a type of hardware for interacting with and / or controlling the power generation system 100. As discussed herein, the controller 180 can respond to various risk parameters and / or other monitored attributes of the power generation system 100 to ensure the safe and reliable operation of the power generation system 100 in maintenance mode. Within the controller 180, a maintenance control program 212 can monitor, and / or interact with, other operations performed by the controller 180 to control the power generation system 100 during operation in maintenance settings (e.g., regulation of valve 162, modification of fuel and / or cooling fluid consumption, etc.) and / or override such other operations in some cases.

[0031] According to one example, controller 180 can control power generation system 100 during operation in a maintenance setting and continuously evaluate whether to operate power generation system 100 using a first maintenance mode or a second maintenance mode, each with a different response to various operational faults. Maintenance control procedure 212 enables controller 180 to operate power generation system 100 in either the first or second maintenance mode based on multiple criteria, including monitored safety risks, operating time in one or both modes, and / or user overwrite commands. Embodiments of this disclosure can be configured or operated in part by a technician, computing device 200, and / or a combination of a technician and computing device 200. It should be understood that... Figure 3 Some of the various components shown may be implemented, combined, and / or stored in memory independently for one or more separate computing devices included in computing device 200. Furthermore, it should be understood that some components and / or functions may not be implemented, or alternative schemes and / or functions may be included as part of control system 204.

[0032] The computing device 200 may include a processor unit (PU) 228, an input / output (I / O) interface 230, a memory 202, and a bus 234. Furthermore, the computing device 200 is shown communicating with an external I / O device 236 and a storage system 238. The control system 204 may provide a maintenance control program 212, which can then be operated using various modules 242 (e.g., calculators, determinants, comparators, etc.) to implement various functions and / or logical steps. The various modules 242 may use algorithm-based calculations, lookup tables, and similar tools stored in the memory 202 to process, analyze, and manipulate data to perform their respective functions. Generally, the PU 228 may execute computer program code to run software, such as the control system 204, which may be stored in the memory 202 and / or the storage system 238. When executing the computer program code, the PU 228 may read and / or write data to or from the memory 202, the storage system 238, and / or the I / O interface 236. Bus 234 may provide a communication link between each component in computing device 200. I / O device 230 may include any means that enable a user to interact with computing device 200 or any means that enable computing device 200 to communicate with the equipment and / or other computing devices described herein. I / O device 230 (including, but not limited to, keyboard, display, pointing device, etc.) may be coupled to controller 180 directly or through an intermediate I / O controller (not shown).

[0033] The memory 202 may also include various forms of data 250 relating to various components of the power generation system 100, such as various forms of data and / or predetermined data that the controller 180 may use as a reference to modify the operation of the power generation system 100. The maintenance control program 212 may store and interact with the data 250, which is subdivided into various fields. For example, the risk parameter field 252 may store any and all types of data collected by the sensor 164 (e.g., hazardous fluid concentration, shaft speed, ignition temperature, inlet temperature, exhaust temperature, power output, operating efficiency, etc.), which can be used to assess the risk of continuing to operate the power generation system 100 in a first maintenance mode. Where applicable, the risk parameter field 252 may be divided into various subfields corresponding to specific types of data. In addition or alternatively, the data 250 may include a sensor risk field 254 for storing risk parameters of any sensor 164 (e.g., measurement accuracy compared to other sensors 164 in the power generation system 100 or other systems 100, total deployment time, expected remaining service life, airflow through the sensing lines of the power generation system 100 or sensor 164, etc.).

[0034] The controller 180 can be used to operate the power generation system 100 for online maintenance, and various maintenance modes can be stored in the maintenance mode field 256. Such maintenance modes may include a range of acceptable power outputs, shaft speeds, combustion rates, etc., for selected components of the power generation system 100. More specifically, maintenance modes may include operating settings specific only to the compressor 122, burner 138, turbine assembly 142, generator 152, etc., and such settings may be selected to allow online maintenance of specific components within the power generation system 100. Furthermore, each maintenance mode in the maintenance mode field 256 may include one or more automatic responses to at least one operational fault of the power generation system 100. An "operational fault" refers to any detected attribute of the power generation system 100 that violates a specific threshold, rule, and / or other requirement. In various examples, an operational fault may include a hazardous fluid concentration exceeding an acceptable maximum value, a shaft speed greater than or less than a desired level range, an ignition temperature greater than or less than a desired or safe operating range, etc. Automatic responses to operational faults in each maintenance mode may include, for example, reducing the ignition rate or ignition temperature in the burner, reducing the generator shaft speed and / or power output, purging gas from selected lines, partially or completely shutting down the power generation system 100, etc. The maintenance mode field 256 may include a first maintenance mode that disables at least one automatic response to operational faults, and a second maintenance mode that enables automatic responses to operational faults.

[0035] Data 250 may include one or more risk thresholds for various parameters measured by sensor 164 during operation of the power generation system 100 in any of its various maintenance modes. The thresholds may indicate whether it is safe to continue operation of the power generation system 100 in a first maintenance mode (i.e., disabling one or more automatic responses) under specific conditions. One or more of the thresholds may be stored in the threshold field 258 of data 200. In various examples, such thresholds may include the maximum concentration of a hazardous fluid (e.g., any hazardous fluid with a concentration greater than approximately 1000 ppm), shaft speeds above a specific maximum value (e.g., approximately 25,000 rpm), and / or other values ​​indicating that the operation of the power generation system 100 may be approaching an unsafe condition.

[0036] The computing device 200 may include any general-purpose computing artifact (e.g., personal computer, server, handheld device, etc.) installed by the user for executing computer program code. However, it should be understood that the computing device 200 represents only various possible equivalent computing devices and / or skilled workers capable of performing the various process steps of this disclosure. Furthermore, the computing device 200 may be part of a larger system architecture operable to model and / or control various aspects and elements of the power generation system 100.

[0037] In this regard, in other embodiments, computing device 200 may include any dedicated computing article having hardware and / or computer program code for performing specific functions, or any computing article including a combination of dedicated and general-purpose hardware / software, etc. In each case, the program code and hardware may be created using standard programming and engineering techniques, respectively. In one embodiment, computing device 200 may include a program product stored on a computer-readable storage device, which is operable to automatically control other elements of power generation system 100 upon execution. Computing device 200 may also take the form of, for example, a remote monitoring system that is part of a central monitoring system that in turn monitors several power generation systems 100. In this case, computing device 200 may represent a part or sub-component of a central control system.

[0038] See Figure 3 and Figure 4 Embodiments of this disclosure provide a method for controlling a power generation system 100 during operation in an online maintenance setup. The power generation system 100 may include, for example, a power source such as a turbine 102 for mechanically driving a shaft 150 to drive power output from a generator 152. Figure 4 A flowchart for operating the power generation system 100 during online maintenance is provided, and references are made. Figure 3 Examples have been described, but embodiments of this disclosure are equally applicable to other types of power generation systems 100. Embodiments of the methods described herein may be implemented, for example, using various modules and / or sub-components of a controller 180 and / or a computing device 200. The methods according to this disclosure may also rely on other components, such as a controller 180 communicatively coupled to the computing device 200, to operate the power generation system 100 using various control settings as discussed herein. The power generation system 100 may analyze various characteristics of the power generation system during operation, and specifically, the power generation system 100 may switch between a first maintenance mode and a second maintenance mode. Different maintenance modes may affect whether the power generation system 100 experiences one or more automatic responses upon detection of an operational fault. Figure 4 The exemplary flowcharts shown herein have several processes organized in an exemplary process, but it should be understood that one or more processes may be implemented simultaneously and / or sequentially and / or executed in any alternative order, while retaining the various technical features described in the examples herein.

[0039] In an exemplary embodiment, the method according to this disclosure may include a process P1 for operating the power generation system 100 in a first maintenance mode. Process P1 may precede other operations described herein (e.g., authorizing the first maintenance mode and / or determining whether the power generation system 100 meets the preconditions in decision D0), and details of these processes are discussed elsewhere herein. Process P1 may include using controller 180 to switch the operation of the power generation system 100 from a non-maintenance mode (or a second maintenance mode, when the method is implemented in a loop) to the first maintenance mode. This switching may include regulating valve 162 and / or other characteristics of the power generation system 100 to affect the power output, combustion temperature, shaft rotation speed, cooling fluid flow rate, and / or other characteristics of the power generation system 100, thereby allowing maintenance (e.g., repair, replacement, maintenance, etc. of components) while the power generation system 100 continues to operate. In the first maintenance mode, maintenance control program 212 of controller 180 may disable one or more automatic responses to corresponding operational faults within the power generation system 100. The disabled responses may be specified via module 242 and / or may be shown within the maintenance mode field 256 of data 250. According to an exemplary embodiment, in the first maintenance mode, the power generation system 100 may disable an automatic response to temporarily shut down the power generation system 100 in response to the detection of a hazardous fluid exceeding 1500 ppm. When the maintenance control procedure 212 performs other procedures of this disclosure, the power generation system 100 may continue to operate in the first maintenance mode, unless the controller 180 changes the maintenance mode, as described herein.

[0040] In some cases, the operator or administrator of the power generation system 100 may limit the amount of time that the power generation system 100 can operate in a first maintenance mode. To provide this feature, embodiments of this disclosure may include setting and implementing a total time limit in which the power generation system 100 can operate in the first maintenance mode. The time limit for operation in the first maintenance mode may be stored, for example, in a maintenance mode field 256 of data 250. In this case, the power generation system 100 may be allowed to operate in the first maintenance mode for the duration of the time limit, and then automatically switch to operating in a second maintenance mode without analyzing risk parameters and / or other operational characteristics.

[0041] In various specific implementations, the same time limit can be applied to the total elapsed time of multiple instances of the power generation system 100 operating in the first maintenance mode. Therefore, past operating periods in the first maintenance mode will be included in the time limit. The elapsed time can be reset only on a specified date, for example, after two weeks, one month, three months, six months, one year, etc. In one example, the time limit for the first maintenance mode could be five hundred hours of total operating time in the first maintenance mode. In such an example, the elapsed time can be reset to zero only once a year. Thus, the time limit can be reached after fifty instances of the power generation system 100 operating for ten hours in the first maintenance mode, or after a single instance of the power generation system 100 operating for five hundred hours in the first maintenance mode. After the specified time period has elapsed, or after the administrator of the power generation system 100 otherwise permits the elapsed time to be reset, embodiments of this disclosure may optionally include a process P1.1 (shown in dashed lines) for resetting the elapsed time of operation in the first maintenance mode. Resetting the elapsed time may include, for example, module 242 of maintenance control program 212 archiving and / or replacing the current value of the “elapsed time” variable in data 250 with zero. If the specified time period has not passed and / or the administrator of power generation system 100 has not authorized the reset of the actual elapsed time, process P1.1 shall be omitted or skipped.

[0042] While the power generation system 100 continues to operate in the first maintenance mode, the methods of this disclosure may include a process P2 for monitoring various risk parameters of the power generation system 100 and / or sensor 164. Monitoring of risk parameters in process P2 may be achieved, for example, using analysis of sensor 164 and / or other characteristics of the power generation system 100 (e.g., power output, operating time, etc.) without the assistance of sensor 164. As used herein, the term "risk parameter" may refer to any conceivable characteristic and / or group of characteristics (including, for example, mechanical data, electrical data, and / or chemical data) that indicates whether the power generation system 100 is approaching unsafe operation. Exemplary risk parameters of the power generation system 100 to be analyzed may include, but are not limited to, shaft speed, one or more temperatures, internal vibration, fluid purity, purge fluid flow rate, fluid pressure, power output, flame detection parameters, fluid velocity, etc. Similarly, exemplary risk parameters of sensor 164 may include, for example, the sensor quality of a gas sensor in fluid communication with a sensing line. In this context, sensor quality may refer to the differences between one sensor 164 and other sensors 164, the total deployment time and / or expected lifespan of sensors 164, the availability of sensors 164 during the operation of the power generation system 100, etc. Risk parameters may be direct measurements by sensors 164, and / or may be based on current data, historical operating data, a model of the power generation system 100, anticipated operating settings, and / or parameters of the power generation system 100, etc. In another specific implementation, the maintenance control program 212 of the controller 180 may simulate these and other monitored risk parameters of the power generation system 100 based on monitoring via sensors 164. In further processing, the maintenance control program 212 of the controller 180 may use the monitored risk parameters to assess whether to continue operating the power generation system 100 in a first maintenance mode or to switch the power generation system 100 to a second maintenance mode.

[0043] As the power generation system 100 continues to operate in the first maintenance mode, while continuing to monitor risk parameters of system 100 and / or sensor 164, the method of this disclosure includes determining whether to continue operation in the first maintenance mode. To maintain the safe and reliable operation of the power generation system 100, further actions in the first maintenance mode (i.e., disabling one or more automatic responses to operational failures) depend on compliance with various technical and / or user-defined requirements. Examples of such requirements are shown in an exemplary flowchart as decision nodes D1, D2, and D3.

[0044] At decision D1, module 242 can determine whether the operator or administrator of the power generation system 100 has issued a write-over command. The write-over command can be any input to controller 180 (e.g., provided via I / O device 236) instructing maintenance control program 212 to stop operating in the first maintenance mode and begin operating in the second maintenance mode. In some cases, the write-over command can be issued automatically by maintenance control program 212 itself, for example, by referring to an external control program and / or device communicating with controller 180. If a write-over command is detected (i.e., "yes" at decision D1), the method can immediately proceed to process P3, operating the power generation system 100 in the second maintenance mode, and / or implement additional optional processes (e.g., disabling the first maintenance mode in process P4). If no write-over command is detected (i.e., "no" at decision D1), the method can continue with further analysis to determine whether to maintain operation in the first maintenance mode.

[0045] At decision D2, module 242 can determine whether the actual operating time (e.g., the total operating time of the current instance of the first maintenance mode plus past instances using the first maintenance mode) exceeds the time limit for operating the power generation system 100 under the first maintenance mode. As noted elsewhere herein, the time limit may be, for example, approximately five hundred hours of total operation under the first maintenance mode. In this case, if the power generation system 100 has previously used the first maintenance mode without initializing the time limit (e.g., in process P1.1), the actual time of less than five hundred hours for a single instance using the first maintenance mode may exceed the time limit. If the time limit for the first maintenance mode has been reached (i.e., "yes" at decision D2), the method may continue with process P3 and / or process P4 or other operations as described herein. If the time limit for the first maintenance mode has not been reached (i.e., "no" at decision D2), the method may continue analyzing the risk parameters monitored in process P2.

[0046] At decision D3, module 242 of maintenance control procedure 212 may assess whether any risk parameter of power generation system 100 or a sensor exceeds its corresponding risk threshold. The relevant threshold for each monitored risk parameter may be stored and organized in threshold field 258 of data 250, as described elsewhere herein. The corresponding risk threshold may not indicate that power generation system 100 has violated safety limits or otherwise failed, but may simply indicate that its operation is beginning to approach a level requiring enhanced review. According to one example, module 242 of maintenance control procedure 212 may assess whether the concentration of a hazardous fluid in one or more sections of turbine 102 exceeds a specified safety level (e.g., 1000 ppm). Decision D3 may, in some cases, include determining whether a predetermined number and / or percentage of selected risk parameters exceeds their corresponding threshold. If a risk parameter exceeds its corresponding risk threshold (i.e., "yes" at decision D3), the method may proceed to further operations to operate power generation system 100 in a second maintenance mode. If the risk parameter does not exceed the corresponding risk threshold (i.e., "No" at decision D3), the controller 180 will maintain its operation of the power generation system 100 in the first maintenance mode. Therefore, automatic response to one or more operational failures will remain disabled only if each of decisions D1, D2, and D3 outputs "No".

[0047] If any of the decision nodes D1, D2, and D3 outputs "No", the method according to this disclosure may include process P3 for operating the power generation system 100 in a second maintenance mode instead of the first maintenance mode described above. Process P3 may include, for example, using controller 180 to switch the operation of the power generation system 100 from the first maintenance mode to the second maintenance mode. This switching may keep the power output, combustion temperature, shaft rotation speed, and / or other characteristics of the power generation system 100 substantially the same to allow maintenance (e.g., repair, replacement, maintenance, etc. of components) to be performed while the power generation system 100 continues to operate. However, in the second maintenance mode, the maintenance control program 212 of controller 180 may enable or re-enable one or more automatic responses to corresponding operational faults within the power generation system 100. As noted herein, such responses may be specified via module 242 and / or may be shown in the maintenance mode field 256 of data 250. According to an exemplary embodiment, operating the power generation system 100 in the first maintenance mode may disable the automatic response to temporarily shut down the power generation system 100 in response to the detection of a hazardous fluid at 1500 ppm. While maintenance control procedure 212 implements other procedures of this disclosure, power generation system 100 may continue to operate in the second maintenance mode, except that controller 180 changes the maintenance mode, as described herein. This method may end (“complete”) when power generation system 100 begins operation in the second maintenance mode, or may return to other procedures (e.g., procedure P1 discussed below or optional procedure P0) to potentially restart operation in the first maintenance mode.

[0048] In some cases, the operator or administrator of the power generation system 100 may wish to prevent further operation in the first maintenance mode, for example, when a time limit has been reached and / or when any other circumstances require enhanced review during maintenance (e.g., exceeding operator preferences and / or specific risk thresholds). To accommodate these situations, the method of this disclosure optionally includes disabling further use of the first maintenance mode in process P4. Disabling may include, for example, module 242 automatically overwriting a further request to enable the first maintenance mode in decision D1, or otherwise preventing further operation in the first maintenance mode without reinitializing controller 180 or overwriting instructions from users, operators, etc. After disabling the first maintenance mode, the method may proceed to process P3, which operates the power generation system 100 in the second maintenance mode, as described elsewhere herein.

[0049] In some cases, the method according to this disclosure may include an optional process P0 that authorizes the first maintenance mode before other actions (e.g., processes P1, P2, decisions D1, D2, D3) can be performed. Process P0 may occur, for example, before any other process of this disclosure is performed, or only after the power generation system 100 begins operation in the second maintenance mode. Process P0 may include, for example, preventing the maintenance control program 212 from performing any process according to this disclosure until the first maintenance mode is authorized. Authorization may be manual (e.g., input by the operator of the power generation system 100 to the controller 180) or may be automatic (e.g., based on signals from interconnected control devices and / or automatic authorization by the maintenance control program 212).

[0050] Following process P0, the method may proceed to decision D0, where module 242 determines whether one or more preconditions for operation in the first maintenance mode have been met. Preprocessing may include the risk thresholds analyzed in decision D3 or the same risk thresholds analyzed in that decision. Alternatively or additionally, the one or more preconditions to be analyzed in decision D0 may differ from the risk thresholds in decision D3. In an example of hazardous fluid monitoring, decision D0 may include determining whether the concentration of a hazardous fluid within a portion of turbine 102 is less than 750 ppm (i.e., half of the exemplary risk threshold). Preconditions may, alternatively or additionally, include other requirements, such as that the elapsed time in the first operating mode has not exceeded a time limit prior to allowing a reset of the elapsed time. If the preconditions are not met (i.e., “No” at decision D0), the method may immediately proceed to process P3 for operating the power generation system 100 in the second maintenance mode, and / or restart such operation where applicable. If the preconditions are met, the method may proceed to process P1 and the subsequent operations discussed herein.

[0051] The technical advantages of the embodiments described herein include adapting to multiple levels of review of the operation of the power generation system during online maintenance. Specifically, the method of this disclosure enables the power generation system 100 to operate with reduced review via a first operating mode during maintenance. The first operating mode prevents shutdown or other responses to operational failures when such failures are unlikely to be caused by system problems. This disclosure automatically increases review when the operator overrides the first maintenance mode, allows for reduced review within a specified time, or when risk parameters exceed corresponding thresholds. Therefore, embodiments of this disclosure provide multiple forms of operation during online maintenance to automatically adapt to higher and lower review requirements under different conditions.

[0052] As used throughout the specification and claims, approximate language can be used to modify any quantitative expression that allows for variation without causing a change in its underlying function. Therefore, values ​​modified by one or more terms (such as “about,” “approximately,” and “substantially”) are not limited to specified exact values. In at least some cases, approximate language may correspond to the precision of the instrument used to measure the value. Range limitations may be combined and / or interchanged herein and throughout the specification and claims. Unless otherwise specified by context or language, these ranges are identified and include all subranges contained therein. The term “about” applied to a specific value within a range applies to both terminating values ​​and may indicate + / - 10% of said value unless otherwise dependent on the precision of the instrument used to measure the value.

[0053] All means or steps plus functional elements in the following claims are intended to include any structure, material, action, and equivalent for performing a function in conjunction with other claimed elements of a particular claim. This disclosure has been described for purposes of illustration and description, but it is not intended to be exhaustive or to limit the disclosure to the forms disclosed. Many modifications and variations will be apparent to those skilled in the art without departing from the scope and spirit of this disclosure. Embodiments have been selected and described to best explain the principles and practical application of this disclosure and to enable others skilled in the art to understand various embodiments of this disclosure with various modifications suitable for the intended particular use.

Claims

1. A method for controlling a power generation system (100) during online maintenance, the method comprising: The power generation system (100) is modeled under the first maintenance mode and the second maintenance mode; The power generation system (100) is operated in the first maintenance mode, wherein operating the power generation system (100) in the first maintenance mode causes the controller (180) of the power generation system (100) to be programmed to disable automatic response to at least one operational failure of the power generation system (100); The automatic response to the at least one operational failure of the power generation system (100) is determined by modeling the power generation system (100). Calculate the actual time consumed when operating the power generation system (100) in the first maintenance mode, wherein the calculation of the actual time includes the accumulated time from previous instances operated in the first maintenance mode; while operating the power generation system (100) in the first maintenance mode, monitor the risk parameters of the power generation system (100) or at least one sensor (164) within the power generation system (100); as well as In response to detecting that the actual time consumed in the first maintenance mode exceeds the time limit or the monitored risk parameter exceeds the safety threshold, the power generation system (100) is operated in the second maintenance mode. Operating the power generation system (100) in the second maintenance mode causes the controller (180) of the power generation system (100) to programmatically enable the automatic response to the at least one operational failure of the power generation system (100).

2. The method of claim 1, wherein the monitored risk parameters include each of the concentration of hazardous fluid in the sensing line of the power generation system (100), the air flow rate in the sensing line, and the mass of the sensor (164) of the gas sensor (164) in fluid communication with the sensing line of the power generation system (100).

3. The method of claim 1, further comprising maintaining the operation of the power generation system (100) in the first maintenance mode in response to the absence of detection that the actual time consumed in the first maintenance mode does not exceed the time limit and the monitored risk parameter does not exceed the safety threshold.

4. The method according to claim 1, further comprising operating the power generation system (100) in the second maintenance mode: In response to detecting authorization to operate the power generation system (100) in the first maintenance mode, it is determined whether the power generation system (100) meets a set of preconditions for the first maintenance mode; In response to the power generation system (100) meeting the set of preconditions, the power generation system (100) is operated in the first maintenance mode; and In response to the fact that the power generation system (100) does not meet the set of preconditions, the operation of the power generation system (100) is maintained in the second maintenance mode.

5. The method according to claim 1, wherein the monitored risk parameters include a plurality of risk parameters, each risk parameter having a corresponding safety threshold.

6. The method of claim 1, wherein the actual time consumed includes the total cumulative time of past instances of operating the power generation system (100) in the first maintenance mode.

7. The method of claim 1, further comprising disabling further operation of the power generation system (100) in the first maintenance mode in response to detecting that the actual time consumed in the first maintenance mode exceeds the time limit.

8. A program product stored on a computer-readable storage medium for controlling a power generation system (100) during online maintenance, the computer-readable storage medium comprising program code for causing the computer system (100) to perform actions, said actions including: The power generation system (100) is modeled under the first maintenance mode and the second maintenance mode; The power generation system (100) is operated in the first maintenance mode, wherein operating the power generation system (100) in the first maintenance mode causes the controller (180) of the power generation system (100) to be programmed to disable automatic response to at least one operational failure of the power generation system (100); The automatic response to the at least one operational failure of the power generation system (100) is determined by modeling the power generation system (100). Calculate the actual time consumed when operating the power generation system (100) in the first maintenance mode, wherein the calculation of the actual time includes the accumulated time from previous instances operating in the first maintenance mode; When operating the power generation system (100) in the first maintenance mode, monitor the risk parameters of the power generation system (100) or at least one sensor (164) within the power generation system (100); as well as In response to detecting that the actual time consumed in the first maintenance mode exceeds the time limit or the monitored risk parameter exceeds the safety threshold, the power generation system (100) is operated in the second maintenance mode, wherein operating the power generation system (100) in the second maintenance mode causes the controller (180) of the power generation system (100) to programmatically enable the automatic response to the at least one operational failure of the power generation system (100).

9. The procedure product of claim 8, wherein the monitored risk parameters include each of the concentration of hazardous fluid in the sensing line of the power generation system (100), or the air flow rate in the sensing line and the mass of the sensor (164) of the gas sensor (164) in fluid communication with the sensing line of the power generation system (100).

10. The program product of claim 8, further comprising program code for maintaining the operation of the power generation system (100) in the first maintenance mode in response to the absence of detection that the actual time consumed in the first maintenance mode does not exceed the time limit and the monitored risk parameter does not exceed the safety threshold.

11. The program product according to claim 8, further comprising program code for actions, the actions including, when operating the power generation system (100) in the second maintenance mode: In response to detecting authorization to operate the power generation system (100) in the first maintenance mode, it is determined whether the power generation system (100) meets a set of preconditions for the first maintenance mode; In response to the power generation system (100) meeting the set of preconditions, the power generation system (100) is operated in the first maintenance mode; and In response to the fact that the power generation system (100) does not meet the set of preconditions, the operation of the power generation system (100) is maintained in the second maintenance mode.

12. The program product according to claim 8, wherein the monitored risk parameters include a plurality of risk parameters, each risk parameter having a corresponding safety threshold.

13. The program product of claim 8, wherein the actual time consumed includes the total cumulative time of past instances of operating the power generation system (100) in the first maintenance mode.

14. The program product of claim 8, further comprising program code for disabling further operation of the power generation system (100) in the first maintenance mode in response to detecting that the actual time consumed in the first maintenance mode exceeds the time limit.

15. A system for controlling a power generation system (100) during online maintenance, comprising: The power generation system (100) is configured to operate in an online maintenance setting; A system controller (180) communicating with the power generation system (100), the system controller (180) being configured to perform actions during operation of the power generation system (100) in the online maintenance settings, the actions including: The power generation system (100) is modeled under the first maintenance mode and the second maintenance mode; The power generation system (100) is operated in a first maintenance mode, wherein operating the power generation system (100) in the first maintenance mode causes the controller (180) of the power generation system (100) to be programmed to disable automatic response to at least one operational failure of the power generation system (100); The automatic response to the at least one operational failure of the power generation system (100) is determined by modeling the power generation system (100). Calculate the actual time consumed when operating the power generation system (100) in the first maintenance mode, wherein the calculation of the actual time includes the accumulated time from previous instances operating in the first maintenance mode; When operating the power generation system (100) in the first maintenance mode, monitor the risk parameters of the power generation system (100) or at least one sensor (164) within the power generation system (100); and In response to detecting that the actual time consumed in the first maintenance mode exceeds the time limit or the monitored risk parameter exceeds the safety threshold, the power generation system (100) is operated in the second maintenance mode, wherein operating the power generation system (100) in the second maintenance mode causes the controller (180) of the power generation system (100) to programmatically enable the automatic response to the at least one operational failure of the power generation system (100).

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