Patent Description:
A power generation system may include one or more machines including several interconnected components, and various properties of the power generation system can be derived from conditions of these individual components. Examples of power generation systems may include, e.g., combustion based or non-combustion based power plants including a fleet of gas turbines and/or other machines therein. In the example of a combustion based power plant, gas turbine assemblies therein can generate mechanical energy by combusting a source of fuel intermixed with compressed air. These combustion reactions create mechanical power for driving a load component attached to the combustion-based power source (e.g., by a rotatable shaft).

The effectiveness of power generation systems may depend on their implementation, environment, and/or other factors such as manufacturing quality and state of operation (e.g., transient state or steady state). In addition, several user-driven and environmental factors can affect the performance of components in a power generation system, including the magnitude of intended energy output, efficiency or condition of individual components, and estimates of part and/or system lifespan.

Monitoring of a power generation system is a critically important process to determine the properties of various components within the power generation system. Such properties may include, e.g., the operating status of a component, the estimating time remaining before the component should be serviced, a recommended adjustment to one or more operating settings of the power generation system, etc. It is possible to monitor some components or attributes of a system via automation. However, various other components of a power generation system rely on an operator or servicer to visually monitor and report their characteristics. Such characteristics, e.g., the appearance of one or more machines, may not be discernable without visually inspecting the machine. Monitoring a power generation system by visual inspection carries various limitations, most particularly the time and costs associated with repeated inspections.

<CIT> and <CIT> disclose systems and methods for on-line monitoring of hot gas path components of a gas turbine. The system may include a camera operable to monitor one or more hot gas path components of the gas turbine and a processor communicatively coupled to the camera.

According to the invention, there is provided a method according to claim <NUM>, a system according to claim <NUM> and a computer program according to claim <NUM>.

A first aspect of the disclosure provides a method for controlling a power generation system, the method including: detecting a gauge measurement of an operating parameter while visually monitoring a gauge of the power generation system during operation of the power generation system; calculating an expected value of the operating parameter based on a library of modeling data for the power generation system; calculating whether a difference between the gauge measurement of the operating parameter and the calculated expected value of the operating parameter exceeds a predetermined threshold; and adjusting the power generation system in response to the difference exceeding the thermal threshold, wherein the adjusting includes one of calibrating the gauge or modifying an operating setting of the power generation system.

A second aspect of the disclosure provides a program product stored on a computer readable storage medium for controlling a power generation system, the computer readable storage medium comprising program code for causing a computer system to perform actions including: detecting a gauge measurement of an operating parameter while visually monitoring a gauge of the power generation system during operation of the power generation system; calculating an expected value of the operating parameter based on a library of modeling data for the power generation system; calculating whether a difference between the gauge measurement of the operating parameter and the calculated expected value of the operating parameter exceeds a predetermined threshold; and adjusting the power generation system in response to the difference exceeding the thermal threshold, wherein the adjusting includes one of calibrating the gauge or modifying an operating setting of the power generation system.

A third aspect of the disclosure provides a system for controlling a power generation system, the system including: a camera operable to visually monitor a gauge of the power generation system; a system controller in communication with the camera and operable to, during operation of the power generation system, perform actions including: detecting a gauge measurement of an operating parameter while visually monitoring the gauge of the power generation system via the camera; calculating an expected value of the operating parameter based on a library of modeling data for the power generation system; calculating whether a difference between the gauge measurement of the operating parameter and the calculated expected value of the operating parameter exceeds a predetermined threshold; and adjusting the power generation system in response to the difference exceeding the thermal threshold, wherein the adjusting includes one of calibrating the gauge or modifying an operating setting of the power generation system.

These and other features of the disclosed system will be more readily understood from the following detailed description of the various aspects of the system taken in conjunction with the accompanying drawings that depict various embodiments, in which:.

The drawings are intended to depict only typical aspects of the disclosure, and therefore should not be considered as limiting its scope.

In the following description, reference is made to the accompanying drawings that form a part thereof, and in which is shown by way of illustration specific exemplary embodiments in which the present teachings may be practiced. These embodiments are described in sufficient detail to enable those skilled in the art to practice the present teachings and it is to be understood that other embodiments may be used and that changes may be made without departing from the scope of the present teachings. The following description is, therefore, merely illustrative.

In addition, several descriptive terms may be used regularly herein, and it should prove helpful to define these terms at the onset of this section. These terms and their definitions, unless stated otherwise, are as follows. As used herein, "downstream" and "upstream" are terms that indicate a direction relative to the flow of a fluid, such as the working fluid through the turbine engine or, for example, the flow of air through the combustor or coolant through one of the turbine's component systems. The term "downstream" corresponds to the direction of flow of the fluid, and the term "upstream" refers to the direction opposite to the flow. The terms "forward" and "aft," without any further specificity, refer to directions, with "forward" referring to the front or compressor end of the engine, and "aft" referring to the rearward or turbine end of the engine. It is often required to describe parts that are at differing radial positions with regard to a center axis. The term "radial" refers to movement or position perpendicular to an axis. In cases such as this, if a first component resides closer to the axis than a second component, it will be stated herein that the first component is "radially inward" or "inboard" of the second component. If, on the other hand, the first component resides further from the axis than the second component, it may be stated herein that the first component is "radially outward" or "outboard" of the second component. The term "axial" refers to movement or position parallel to an axis. Finally, the term "circumferential" refers to movement or position around an axis. It will be appreciated that such terms may be applied in relation to the center axis of the turbine.

Embodiments of the present disclosure provide systems, program products, and methods for controlling a power generation system. In an example embodiment, a system according to the present disclosure can include a system controller or similar device in communication with one or more cameras and/or other devices configured to audio-visually monitor a particular area of the power generation system. The monitored area of the power generation system may include, e.g., one or more gauges for reporting operational parameters of the system, one or more components susceptible to thermal variability, one or more sensitive components where people or animals are prohibited during operation, one or more valve banks for controlling a fluid flow into or out of a component, etc..

In embodiments of the present disclosure, multiple cameras may be capable of visually monitoring one power generation system at multiple locations, and may also detect related inputs such as sound, infrared light, etc. A system controller in the form of, e.g., a computing device and/or other control system, may be communicatively connected to one or more cameras to monitor various operational parameters of the power generation system. The system controller may process images and/or other data collected by visual monitoring of the power generation system and adjust the power generation system based on the processed data. In alternative embodiments, the computing device of the system can be wholly or partially located at a geographic location remote from the power generation system, and may use a library of data pertaining to multiple power generation systems to adjust the operation of each power generation system. Providing a network of cameras in communication with a system controller can provide greater accessibility and functionality to managers of a power generation system, e.g., by permitting a user to access an application, web-portal, etc., immediately after the cameras have been installed to analyze various portions of the power generation system, and undertake corrective actions, without personally visiting and viewing different portions of the power generation system.

<FIG> shows a turbomachine <NUM>, which may be included within a power generation system as discussed elsewhere herein. Turbomachine <NUM> can include, e.g., a compressor <NUM> operatively coupled to a turbine component <NUM> through a shared compressor/turbine shaft <NUM>. Turbomachine <NUM> is depicted as being in the form of a gas turbine in <FIG>, but it is understood that other types of machines (e.g., steam turbines, etc.) can be substituted for, or used with, gas turbines and/or deployed in the same power generation system in embodiments of the present disclosure. More generally, any machine which includes an embodiment of turbine component <NUM> can be used, modified, and/or controlled to yield embodiments of the present disclosure as discussed herein. Compressor <NUM> can be in fluid communication with turbine component <NUM>, e.g., through a combustor assembly <NUM>. Each combustor assembly <NUM> can include one or more combustors <NUM>. Combustors <NUM> may be mounted to turbomachine <NUM> in a wide range of configurations including, but not limited to, being arranged in a can-annular array. Compressor <NUM> includes a plurality of compressor rotor wheels <NUM>. Compressor rotor wheels <NUM> include a first stage compressor rotor wheel <NUM> having a plurality of first stage compressor rotor blades <NUM> each having an associated airfoil portion <NUM>. Similarly, turbine component <NUM> includes a plurality of turbine wheel components <NUM> including one or more rotor wheels <NUM> having a set of corresponding turbine rotor blades <NUM>.

During operation, an operative fluid such as a combusted hot gas can flow from combustor(s) <NUM> into turbine component <NUM>. The operative fluid in turbine component <NUM> can pass over multiple rotor blades <NUM> mounted on turbine wheel <NUM> and arranged in a group of successive stages. The first set of turbine blades <NUM> coupled to wheel <NUM> and shaft <NUM> can be identified as a "first stage" of turbomachine <NUM>, with the next set of turbine blades <NUM> being identified as a "second stage" of turbomachine <NUM>, etc., up to the last set of turbine blades <NUM> in a final stage of turbomachine <NUM>. The final stage of turbomachine <NUM> can include the largest size and/or highest radius turbine blades <NUM> in turbomachine <NUM>. A plurality of respective nozzles (not shown) can be positioned between each stage of turbomachine <NUM> to further define a flow path through turbomachine <NUM>. The operative fluid flowing over each turbine blade <NUM> can rotate shaft <NUM> by imparting thermal and mechanical energy thereto, thereby rotating shaft <NUM> of turbomachine <NUM>.

Turbomachine <NUM> may also include one or more auxiliary components such as internal valves <NUM>, e.g., to modulate the operative fluid flow out of and into the direct flow path for various purposes, e.g., to be used in one or more pump/motor sets <NUM> also included within turbomachine <NUM>. Rotating shaft <NUM> can generate power by being mechanically coupled to a generator component <NUM> which converts mechanical energy of shaft <NUM> into electrical energy for powering devices connected to generator <NUM>. The amount of electrical energy produced by generator <NUM> can be measured, e.g., in Joules (J) and/or Watts (W) as an amount of work and/or power produced by turbomachine <NUM>. In addition, at least one air source <NUM> (e.g., a dedicated supply, an ambient air source, etc.) may be in fluid communication with compressor <NUM>. At least one fuel source <NUM> (e.g., a reserve, supply nozzle, etc.) may be in fluid communication with combustor <NUM> to provide one or more combustible fuels thereto. Air source(s) <NUM> and/or fuel source(s) <NUM> may be in fluid communication with compressor <NUM> through one or more valves <NUM> for controlling the amount of fuel, air, and/or other fluids supplied to turbomachine <NUM> to drive combustion reactions therein. Any one or more of the various components of turbomachine <NUM> may produce an acoustic output <NUM>, which may be detectable and/or measurable as an acoustic signal produced from a respective component, as discussed herein.

Turning to <FIG>, a system <NUM> for monitoring a power generation system according to embodiments of the present disclosure is shown. System <NUM> may be configured to monitor, or may otherwise include, a power generation system <NUM>, which as noted elsewhere herein can include, e.g., combustion based power plants including a fleet of gas turbines and/or other machines therein, or non-combustion based power plants such as a water turbine, steam turbine, solar or wind based power generation system.

Power generation system <NUM> in some cases may be located at a particular geographic location, with other power generation systems <NUM> being located at other geographic positions. Regardless of where power generation systems <NUM> may be located, each power generation system <NUM> of system <NUM> is in communication with one system controller as described herein.

System <NUM> and power generation system <NUM> are described herein with power generation system <NUM> being in the form of a power plant including one or more assemblies therein, such as turbomachine(s) <NUM> and components thereof (e.g., compressor <NUM>, turbine component <NUM>, combustor <NUM>, valves <NUM>, pump/motor sets <NUM>, etc., hereinafter "component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>"). Although gauges <NUM> and valves <NUM> may not be identified collectively with component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> for the sake of emphasizing gauges <NUM> and valves <NUM>, it is understood that gauges <NUM> and valves <NUM> may also be considered to be components of power generation system <NUM>. Additionally, although component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and valves <NUM> are discussed throughout the present disclosure as an example, it is understood that system <NUM> can be configured to monitor any number of predetermined components within turbomachine <NUM> and/or other machines within power generation system <NUM>. Each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of turbomachine <NUM> within power generation system <NUM> can be housed in a respective area <NUM>, <NUM>, <NUM> and/or other areas or sub-areas of power generation system <NUM> not explicitly identified or described.

Turbomachine <NUM> is shown by example to include compressor component <NUM>, gauge <NUM>, and valves <NUM> in first area <NUM>, combustor <NUM> and valve <NUM> in second area <NUM>, turbine component <NUM> and gauge <NUM> in third area <NUM> and pump/motor set <NUM> in a fourth unenclosed or unidentified area. Each area <NUM>, <NUM>, <NUM> can be separated by architectural features such as partitions, floors, signage, etc., and/or can refer to areas within a shared room, space, building, etc. In some cases, component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of one turbomachine <NUM> may be in close proximity with each other, but may be separated from similar component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> in other turbomachines. Thus, component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> shown in <FIG> may be part of a single turbomachine <NUM> or alternatively may each be portions of respective separate turbomachines <NUM>. It is also understood that areas <NUM>, <NUM>, <NUM> can be defined solely by whether they are illuminated with one or more corresponding cameras <NUM>, e.g., where all components <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of power generation system <NUM> are housed in a single room. Areas <NUM>, <NUM>, <NUM> can include multiple components <NUM>, <NUM>, <NUM>, <NUM>, <NUM> therein in alternative embodiments.

A group of cameras <NUM> may be installed in power generation system <NUM> at positions capable of monitoring one or more components <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and/or valves <NUM> of power generation system <NUM>. Each camera <NUM> may be positioned within, or at a location suitable to visually monitor, respective areas <NUM>, <NUM>, <NUM> of power generation system <NUM>. As discussed elsewhere herein, each camera <NUM> can be provided in the form of any currently-known visual or audio-visual capturing system and as examples may include fixed or portable devices including conventional cameras, infrared cameras, light filed cameras, acoustic cameras, magnetic resonance imaging (MRI) cameras, and/or other type of image detection instruments. More particularly, each camera <NUM> can be configured to operate at a position suitable to visually monitor power generation system <NUM>, e.g., through a corresponding electrical and/or mechanical coupling.

Cameras <NUM> in some cases may be operable to detect the acoustic output of component(s) <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and/or valves <NUM> of power generation system <NUM>. In this case, camera(s) <NUM> may include a microphone or other acoustic sensing device. Cameras <NUM> may also include a communications mechanism, for example ethernet over power, WIFI or cellular, to transmit measured data outside of camera <NUM>, or more generally outside power generation system <NUM>. Camera(s) <NUM> can be configured to detect acoustic outputs <NUM> by converting them into an acoustic signature. As described herein, an "acoustic output," or alternatively an "acoustic signature," refers to a one or more sound waves detected with camera(s) <NUM> generated by one or more respective components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM>, including ultrasonic emissions (i.e., those having a frequency of at least approximately twenty kilohertz (kHz) and above). Acoustic outputs <NUM> can be represented analytically as a singular or composite sound wave having varied frequencies, amplitudes, and/or other properties based on the underlying source(s) of acoustic output <NUM>. Each acoustic output <NUM> can originate from one or more sources in power generation system <NUM> during operation, such that several acoustic outputs <NUM> detected within power generation system <NUM> each have a set of frequencies, wavelengths, amplitudes, phases, etc., when plotted as a sound wave.

System <NUM> may include a system controller <NUM> (alternatively, "computing device" or simply "controller") communicatively coupled to one or more cameras <NUM> to perform various functions, including the monitoring of components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and/or valves <NUM> of power generation system <NUM> as described herein. System controller <NUM> can generally include any type of computing device capable of performing operations by way of a processing component (e.g., a microprocessor) and as examples can include a computer, computer processor, electric and/or digital circuit, and/or a similar component used for computing and processing electrical inputs. Example components and operative functions of system controller <NUM> are discussed in detail elsewhere herein. One or more cameras <NUM> may also include an integrated circuit to communicate with and/or wirelessly transmit signals to system controller <NUM>.

One or more sensors <NUM> may be in communication with system controller <NUM> and can be positioned, e.g., within corresponding areas of turbine component <NUM> where operating fluids can be measured or examined including without limitation: components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and/or valves <NUM>. Each sensor <NUM> can be configured to determine (e.g., by direct measurement and/or calculation from related variables) various quantities such as the input conditions, output conditions, fluid path conditions (e.g., the temperature, pressure, and/or flow rate of operative fluids within a portion of power generation system <NUM>), etc., to model and affect the performance of power generation system <NUM>.

A variety of sensors can be used in embodiments of the present disclosure. Sensor(s) <NUM> can be in the form of temperature sensor(s), flow sensor(s), pressure sensor(s), and/or other devices for evaluating the properties of a component or sub-component, operative fluid(s) within a component or sub-component, etc., at a particular location. Sensor(s) <NUM> in the form of a temperature sensor can include thermometers, thermocouples (i.e., voltage devices indicating changes in temperature from changes in voltage), resistive temperature-sensing devices (i.e., devices for evaluating temperature from changes in electrical resistance), infrared sensors, expansion-based sensors (i.e., sensors for deriving changes in temperature from the expansion or contraction of a material such as a metal), and/or state-change sensors. Where one or more sensors <NUM> include temperature sensors, the temperature of fluid(s) passing through the location of sensor(s) <NUM> can be measured and/or converted into an electrical signal or input relayed to system controller <NUM>. Sensor(s) <NUM> in the form of pressure sensors can include barometers, manometers, tactile pressure sensors, optical pressure sensors, ionizing pressure sensors, etc. For calculating flow rate and/or other kinetic properties of the operative fluid, sensor(s) <NUM> can include, e.g., air flow meters, mass flow sensors, anemometers, etc..

Sensor(s) <NUM> may also derive one or more parameters from other measured quantities, e.g., temperature, pressure, flow rate, etc. These measured quantities, in turn, can be measured at multiple positions of power generation system <NUM> and applied to mathematical models of fluid flow through a particular component, e.g., via system controller <NUM>. In this case, sensor(s) <NUM> can include components for measuring variables related to temperature and processing components (e.g., computer software) for prediction and/or calculating values of temperature or other metrics based on the related variables. In general, the term "calculating" in the context of sensor(s) <NUM> refers to the process of mathematically computing a particular value by direct measurement, predictive modeling, derivation from related quantities, and/or other mathematical techniques for measuring and/or finding a particular quantity. In any event, the conditions measured by each sensor(s) <NUM> can be indexed, tabulated, etc., according to a corresponding time of measurement. As is discussed elsewhere herein, system controller <NUM> can act as a "pseudo-sensor" for calculating (e.g., by estimation or derivation) one or more operating conditions at positions within power generation system <NUM> which do not include sensor(s) <NUM>.

In some cases, sensor(s) <NUM> may take the form of an energy sensor for measuring, e.g., an energy output from various components of power generation system <NUM>. In this case, sensor(s) <NUM> can generally be embodied as any currently-known instrument for measuring the energy produced by power generation system <NUM> and/or generator <NUM> including without limitation, a current sensor, a voltage detector, a magnetometer, a velocity sensors configured to measure a rotation of shaft <NUM> (including, e.g., optical-based sensors, positional sensors, capacitive sensors, tachometers, etc.), and/or other types of sensors for calculating an amount of produced energy. Regardless of the embodiment(s) used, sensor(s) <NUM> can be communicatively connected (e.g., electrically and/or wirelessly) to system controller <NUM> to calculate an energy output from various portions of power generation system <NUM>. In addition, the energy output detected with sensor(s) <NUM> can be tabulated or otherwise indexed by time of measurement, such that the calculated energy output(s) can be cross-referenced in system controller <NUM> to conditions calculated with sensor(s) <NUM>. System controller <NUM> additionally may calculate actual or projected energy outputs from power generation system <NUM> which correspond to a given set of input conditions, output conditions, etc., calculated with sensor(s) <NUM>.

To further illustrate the operational features and details of system <NUM>, an illustrative embodiment of system controller <NUM> is discussed herein. Referring to <FIG> and <FIG> together, an example embodiment of system <NUM> and system controller <NUM> and sub-components thereof is illustrated with a simplified depiction of one power generation system <NUM>. In particular, system <NUM> can include system controller <NUM>, which in turn can include a monitoring system <NUM>. The configuration shown in <FIG> is one embodiment of a system for monitoring power generation system(s) <NUM> by visually monitoring a component <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge <NUM>, and/or valve <NUM>. System <NUM> in some cases may be capable of interacting with multiple distinct power generation systems <NUM>.

System controller <NUM> may be implemented as a cloud computing environment, an on-premises ("on-prem") computing environment, or a hybrid computing environment. Cloud computing environments typically employ a network of remote, hosted servers to manage, store and/or process data, instead of personal computers or local servers as in an on-prem computing environment. A cloud computing environment includes a network of interconnected nodes, and provides a number of services, for example by hosting deployment of customer-provided software, hosting deployment of provider-supported software, and/or providing infrastructure. In general, cloud computing environments are typically owned and operated by a third-party organization providing cloud services (e.g., Amazon Web Services, Microsoft Azure, etc.), while on-prem computing environments are typically owned and operated by the organization that is using the computing environment. Cloud computing environments may have a variety of deployment types. For example, a cloud computing environment may be a public cloud where the cloud infrastructure is made available to the general public or particular sub-group. Alternatively, a cloud computing environment may be a private cloud where the cloud infrastructure is operated solely for a single customer or organization or for a limited community of organizations having shared concerns (e.g., security and/or compliance limitations, policy, and/or mission). A cloud computing environment may also be implemented as a combination of two or more cloud environments, at least one being a private cloud environment and at least one being a public cloud environment. Further, the various cloud computing environment deployment types may be combined with one or more on-prem computing environments in a hybrid configuration.

In still further examples, each power generation system <NUM> may be positioned at a distinct geographic location. For example, one power generation system <NUM> is shown to be located at "Location A," while two other power generation systems <NUM> are shown to be in communication with system controller <NUM> but located at "Location B" and "Location C," respectively. Location A may represent, e.g., a location in North America, while Location B and Location C may represent locations at any other part of the world (including, e.g., other continents such as Africa and Australia). In this manner, one system controller <NUM> or combination of system controllers <NUM> may together or separately manage a worldwide network of power generation systems <NUM>. In some cases, system controller(s) <NUM> being in communication with power generation systems <NUM> at multiple locations may allow system <NUM> to include machine learning features, e.g., using data obtained from power generation systems(s) <NUM> at Location B and Location C to control power generation system <NUM> at Location A.

As discussed herein, system controller <NUM> can extract data obtained from cameras <NUM> visually monitoring components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauges <NUM>, and/or valves <NUM> to monitor power generation system <NUM>. For ease of illustration, several connections between component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM> are omitted in <FIG> (but shown in <FIG>) solely for clarity of illustration. Furthermore, embodiments of the present disclosure can perform these functions automatically and/or responsive to user input by way of an application accessible to a user or other computing device. Such an application may, e.g., exclusively provide the functionality discussed herein and/or can combine embodiments of the present disclosure with a system, application, etc., for remotely controlling camera(s) <NUM>. Embodiments of the present disclosure may be configured or operated in part by a technician, system controller <NUM>, and/or a combination of a technician and system controller <NUM>. It is understood that some of the various components shown in <FIG> can be implemented independently, combined, and/or stored in memory for one or more separate computing devices that are included in system controller <NUM>. Further, it is understood that some of the components and/or functionality may not be implemented, or additional schemas and/or functionality may be included as part of monitoring system <NUM>.

System controller <NUM> can include a processor unit (PU) <NUM>, an input/output (I/O) interface <NUM>, a memory <NUM>, and a bus <NUM>. Further, system controller <NUM> is shown in communication with an external I/O device <NUM> and a storage system <NUM>. Monitoring system <NUM> can execute an analysis program <NUM>, which in turn can include various software modules <NUM> configured to perform different actions, e.g., a calculator, a determinator, a comparator, an image processing algorithm, etc.. The various modules <NUM> of monitoring system <NUM> can use algorithm-based calculations, look up tables, and similar tools stored in memory <NUM> for processing, analyzing, and operating on data to perform their respective functions.

In general, PU <NUM> can execute computer program code to run software, such as control system <NUM>, which can be stored in memory <NUM> and/or storage system <NUM>. While executing computer program code, PU <NUM> can read and/or write data to or from memory <NUM>, storage system <NUM>, and/or I/O interface <NUM>. Bus <NUM> can provide a communications link between each of the components in system controller <NUM>. I/O device <NUM> can comprise any device that enables a user to interact with system controller <NUM> or any device that enables system controller <NUM> to communicate with the equipment described herein and/or other computing devices. I/O device <NUM> (including but not limited to keyboards, displays, pointing devices, etc.) can be coupled to system controller <NUM> either directly or through intervening I/O controllers (not shown).

Memory <NUM> can also include various forms of data stored in a library <NUM> for quantifying one or more operational parameters of power generation system <NUM>, which may pertain to and/or components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauges(s) <NUM>, and/or valves <NUM>. As discussed elsewhere herein, system controller <NUM> can monitor power generation <NUM> via camera(s) <NUM> through operating steps which in turn can rely upon various forms of data in library <NUM>. To exchange data between computer system <NUM> and cameras <NUM>, computer system <NUM> can be in communication with camera(s) <NUM> through any currently known or later developed type of communications network. For example, computer system <NUM> can be embedded at least partially within camera <NUM> as a component thereof, or can be embodied as a remotely located device such as a tablet, PC, smartphone, etc., in communication with camera(s) <NUM> through any combination of wireless and/or wired communication protocols. To monitor power generation system <NUM>, analysis program <NUM> of monitoring system <NUM> can store and interact with library <NUM> according to processes of the present disclosure.

Library <NUM> can be organized into a group of fields. For example, library <NUM> can also include a gauge measurement field <NUM> for storing measurements detected from gauge(s) <NUM> via camera(s) <NUM>. Gauge measurement field <NUM> can include relative and/or absolute values for one or more operational parameters of power generation system <NUM>, e.g., fluid pressure, fluid temperature, fluid flow rate, blade speed, blade temperature, and/or any conceivable parameter capable of being measured and reported via gauge(s) <NUM> mounted on portions of power generation system <NUM>.

Other forms of library <NUM> may include, e.g., a heat distribution field <NUM> for recording the thermal properties of various components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM> of power generation system <NUM>. The data included in heat distribution field <NUM> may be recorded via camera(s) <NUM> in embodiments where camera(s) <NUM> are capable of thermal imaging (e.g., by including components for detecting infrared light). In one example, data in heat distribution field <NUM> may take the form of a plot of temperatures on a particular component relative to locations on the component. In a further example, data recorded in heat distribution field <NUM> may take the form of a two-dimensional temperature map in which each coordinate in a two-dimensional map of one component is correlated to its temperature at a particular time. In a more simplified example, heat distribution field <NUM> may include a time-indexed table for a group (i.e., two or more) sample locations of a component correlated to the temperature of the component at the group of sample locations.

Library <NUM> in addition may include a valve position field <NUM> for recording the position of one or more valve(s) <NUM>, <NUM> of power generation system <NUM>. Detected valve positions stored in valve position field <NUM> may be detectable, e.g., using camera(s) <NUM> at locations with a view of one or more valve(s) <NUM>, <NUM> for controlling fluid flow in part of power generation system <NUM>. Valve position field <NUM> may be organized to include a flow rate through a portion of power generation system <NUM> caused by valve(s) <NUM>, <NUM> being in the position(s) detected by camera(s) <NUM>.

Library <NUM> may also include, e.g., an acoustic profile field <NUM> for recording a set of acoustic outputs originating from or otherwise associated with component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM>, <NUM>. As noted herein, acoustic outputs <NUM> from various with component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM>, <NUM> may be detectable via camera(s) <NUM>. The detected acoustic output(s) <NUM> in some cases may be converted into acoustic signatures and/or other representations capable of being stored in library <NUM>. The acoustic profile(s) stored in acoustic profile field <NUM> may be used in some embodiments to detect an acoustic disturbance in power generation system <NUM>.

A threshold field <NUM> can include one or more tolerance windows for determining whether any detected operating conditions (indicated, e.g., by gauge measurements, heat distributions, valve positions, acoustic profiles, etc.) in library <NUM> require adjusting of power generation system <NUM>. More specifically, threshold field <NUM> may include operating data pertaining to past operation of power generation system <NUM>, and/or other relevant operating data pertaining to the operation of other power generation systems <NUM> (e.g., those located at Location B and/or Location C). In still further embodiments, threshold field <NUM> may additionally or alternatively include projected operating data for power generation system <NUM> or projected operating data for other power generation systems <NUM> (e.g., those located at Location B and/or Location C). In the case of projected operating data, modules <NUM> may use various forms of input data (e.g., past operation, selected operating settings, measurements from present operation, etc.) to predict future values of one or more operating parameters (e.g., pressures, temperatures, flow rate, power generated, etc.) of power generation system <NUM>. Threshold field <NUM> may be expressed as one or more sets of boundary values for operating parameters such as temperature, pressure, flow rate, acoustic frequencies and wavelengths, for automatic monitoring of power generation system <NUM>. As discussed herein, system controller <NUM> may initiate various adjustments to power generation system <NUM> and its operation upon any operating parameter, or combination of operating parameters, exceeding corresponding thresholds in threshold field <NUM>. Each entry of fields <NUM>, <NUM>, <NUM>, <NUM>, <NUM> can be indexed relative to time such that a user can cross-reference information of each field <NUM>, <NUM>, <NUM>, <NUM>, <NUM> in library <NUM>. It is also understood that library <NUM> can include other data fields and/or other types of data therein for evaluating the condition of components <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, gauge(s) <NUM>, and/or valve(s) <NUM>, <NUM> of power generation system <NUM>.

Library <NUM> can also be subject to preliminary processing by modules <NUM> of analysis program <NUM> before being recorded in one or more of fields <NUM>, <NUM>, <NUM>, <NUM>, <NUM>. For example, one or more modules <NUM> can apply a set of rules to remove false readings from field(s) <NUM>, <NUM>, <NUM>, filter inconsequential noise from acoustic signature(s) <NUM> in field <NUM>, etc. Such rules and/or other criteria may be generated from the manufacturer's manufacturing specification of these components and/or data pertaining to other power generation system(s) <NUM>. For example, compressor <NUM> may generate thermal energy and acoustic outputs related to the number of rotating blades of various stages. In the case of combustor <NUM>, the possible resonant frequencies, as related to the type and geometry of combustor <NUM>, operating conditions, type(s) of fuels combusted, etc., may be specified at the time of manufacture. Such analyses can determine criteria such as the amplitude limits associated with data field <NUM>, <NUM>, <NUM>, <NUM> being analyzed with respect to threshold field <NUM>.

System controller <NUM> can comprise any general purpose computing article of manufacture for executing computer program code installed by a user (e.g., a personal computer, server, handheld device, etc.).

In addition, system controller <NUM> can be part of a larger system architecture operable to evaluate one or more power generation systems <NUM>.

To this extent, in other embodiments, system controller <NUM> can comprise any specific purpose computing article of manufacture comprising hardware and/or computer program code for performing specific functions, any computing article of manufacture that comprises a combination of specific purpose and general purpose hardware/software, or the like. In each case, the program code and hardware can be created using standard programming and engineering techniques, respectively. In one embodiment, system controller <NUM> may include a program product stored on a computer readable storage device, which can be operative to automatically monitor power generation system <NUM> when executed.

Turning to <FIG>, an expanded schematic view of system controller <NUM> and camera <NUM> for monitoring gauge <NUM> is shown. Camera(s) <NUM> may have a field of vision Fvis sized for visual monitoring of or more component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>. At least one component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> visually monitored with camera <NUM> may include a gauge <NUM> for measuring at least one operational parameter. In the example of <FIG>, gauge <NUM> is a temperature gauge for measuring an internal temperature of the component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis. Gauge <NUM> may display a gauge measurement MGauge via one or more measuring devices. Gauge <NUM> may include an indicator <NUM>, e.g., a needle in simplistic implementations, a screen in digital implementations, and/or any instrument for communicating parameter(s) measured with gauge <NUM> in various other embodiments. In the example of <FIG>, indicator <NUM> is shown as an arrow on gauge <NUM> indicating the temperature within component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis. During operation, various events may cause gauge <NUM> and/or indicator <NUM> to display an inaccurate measurement, e.g., miscalibration of gauge <NUM>, wear or damage to intervening components which measure the operational parameter(s) displayed by gauge <NUM>, indicator <NUM> being stuck or exhibit a slight jitter indicating that the gauge is operating normally or exhibit extreme jitter indicating that the gauge is malfunctioning. As discussed herein, system controller <NUM> may use sensor(s) <NUM> to derive an expected value Mexpected of the operational parameter(s) measured with gauge(s) <NUM>, and implement various processes to detect and correct differences between gauge measurement MGauge and expected value MExpected.

Referring to <FIG> together, embodiments of the disclosure provide a method to control power generation system(s) <NUM> based on visual monitoring of gauge(s) <NUM> via camera(s) <NUM>. Processes PX1-PX6 are shown by example in <FIG> as being implemented separately from other processes according to the disclosure. The example processes shown in <FIG> (illustrating process PY1-PY8) and <FIG> (illustrating process PZ1-PZ6), and discussed elsewhere herein, may be implemented sequentially and/or simultaneously with those shown in <FIG>. It is understood that any or all of the various processes discussed herein optionally may be combined and implemented together substantially as a set of combined processes or sub-processes wherever possible. The example process flows shown in <FIG>, <FIG>, and <FIG> and described herein thus provide an illustrative set of examples for implementing embodiments of the present disclosure. In addition, the process flows illustrated in <FIG>, <FIG>, and <FIG> may be implemented, e.g., by way of system controller(s) <NUM> including computing device(s) <NUM> communicatively connected to cameras <NUM> configured to monitor various portions of power generation system <NUM>. It is understood that the various processes described herein can be implemented in real time during operation of turbomachine <NUM> and/or can be implemented as part of a historical analysis of turbomachine <NUM> (e.g., a post-failure or post-servicing analysis).

An initial process PX1 may include installing one or more camera(s) <NUM> within power generation system <NUM>. Camera(s) <NUM> can be installed by a party implementing the various process steps described herein and/or another party before processes of the present disclosure are implemented. As such, process PX1 is shown in phantom to indicate that process PX1 may be a preliminary step which occurs before other processes according to the present disclosure. The installing of cameras in process PX1 may include, e.g. electrically and mechanically coupling each camera <NUM> to a mounting component or fixture provided within power generation system <NUM>. A location for each camera <NUM> may be selected such that at least one camera <NUM> may visually monitor gauge(s) <NUM> and gauge measurement(s) MGauge (<FIG>) displayed thereon. The installation process may include, e.g., operating camera(s) <NUM> in a test mode to adjust field of vision Fvis (<FIG>) to determine whether the desired gauge(s) <NUM> will be visually monitored. A user may operate camera(s) <NUM> manually to determine whether each gauge <NUM> to be monitored appears in the field view of the installed camera(s) <NUM>. The subsequent visual monitoring of gauge(s) <NUM> may be implemented automatically by system controller <NUM>, and without user intervention, as described herein.

At process PX2, each camera <NUM> may operate independently of power generation system <NUM> to detect gauge measurement(s) being displayed by gauge(s) <NUM>. Process PX2 thus may include, e.g., recording or otherwise obtaining photographic or video footage of gauge(s) <NUM> at a particular time, with the measurement(s) of each gauge <NUM> being visible. In some cases, process PX2 may include continuous video monitoring of power generation system <NUM>. In other cases, process PX2 may include burst photographic capturing of gauge(s) <NUM> at particular intervals, e.g., capturing one image per predetermined interval (e.g., five-minute span) of operation. The detecting of gauge measurements in process PX2 may yield a photographic or video record of temperatures, pressures, generated energy, flow rates, etc., for a particular component <NUM>, <NUM>, <NUM>, <NUM> in power generation system <NUM>. In conventional settings, a user or inspector would manually examine each gauge <NUM> to record various operating parameters. In embodiments of the disclosure, system controller <NUM> detects the measurement displayed on each gauge <NUM> automatically via camera(s) <NUM>. The conversion from records provided by camera(s) <NUM> to gauge measurements storable, e.g., in gauge measurement field <NUM> of library <NUM> may be implemented via any currently known or later developed method for converting portions of an image to data.

Turning to process PX3, depicted in phantom to indicate an optional procedure, the method may include implementing pattern recognition on images or video captured by camera(s) <NUM> to isolate or extract gauge measurement(s) included therein. According to an example, modules <NUM> of computing device <NUM> may include one or more algorithms, look-up tables, mathematical formulas, etc., capable of automatically identifying one or more portions of an image, or video, as illustrating a gauge measurement. In a more specific example, at least one gauge <NUM> in the form of a temperature gauge may include indicator <NUM> (e.g., an arrow as shown in <FIG>), or other visually identifiable component, e.g., a contrasting-colored measuring indicator <NUM> such as a red needle against a white surface for distinguishing gauge(s) <NUM> from remaining portions of the same image or video of camera <NUM>. Camera <NUM> and/or system controller <NUM> additionally may include physical image filters and/or similar tools for isolating irrelevant sections of an image or video feed to better identify measurements displayed on gauge(s) <NUM>. Gauge measurements detected in PX2, and PX3 where applicable, may be stored in gauge measurement field <NUM> of library <NUM>.

Methods according to the disclosure optionally may include an additional process PX3. <NUM> of using visual pattern recognition to identify whether indicator <NUM> of gauge <NUM> is stuck or jittering. Indicator <NUM> being "stuck" refers to a situation where indicator <NUM> is at least partially non-responsive to changes in one or more parameters being measured via gauge(s) <NUM>. In some cases, indicator <NUM> being stuck may refer to a situation where indicator <NUM> is in a fixed position where a minor amount of movement or jitter would be expected. Indicator <NUM> undergoing "jittering" refers to a situation where indicator <NUM> fluctuates over a range of possible measurements in a manner that is inconsistent with actual fluctuations in the parameter being measured. Indicators <NUM> which jitter are thus another possible source of inaccuracy in the monitoring of parameter(s) with gauge(s) <NUM>. To account for such possibilities, the pattern recognition algorithm may identify visually distinct shapes, colors, and/or other properties in an image of gauge <NUM> to detect whether indicator <NUM> is stuck (i.e., not moving enough) or jittering (i.e., moving too much) based on other data, e.g., data obtained from sensor(s) <NUM>, or historical data of where indicator <NUM> has been position over a given time period. In the event that a stuck or jittering indicator <NUM> is detected (i.e., "Yes" at process PX3. <NUM>), the method may proceed to process PX6 of adjusting power generation system <NUM> as discussed elsewhere herein. Where indicator <NUM> does not appear to be jittering or stuck based on the pattern recognition algorithm (i.e., "No" at process PX3. <NUM>), the method may proceed to process PX4 as discussed below.

The method may continue by implementing process PX4 of calculating one or more expected values for operational parameters measured by gauge <NUM>. Embodiments of the disclosure, in some cases, may detect an error in one or more gauges <NUM>. For example, embodiments of the disclosure are operable to detect, e.g., whether one or more gauges <NUM> are measuring inaccurately, whether one or more gauges <NUM> have ceased functioning, whether one or more mechanical components of any gauge <NUM> are malfunctioning, etc. Process PX4 includes using other data, e.g., detected by sensor(s) <NUM> or included in library <NUM>, to calculate an expected value of the operational parameter being measured with gauge(s) <NUM>. The calculating in process PX4 may implemented, e.g., using modules <NUM> of analysis program <NUM>, or by direct reference to one or more sets of data included in library <NUM>. In an example, sensor(s) <NUM> may detect a temperature of e.g., approximately <NUM> degrees Celsius (° C) within turbine component <NUM> and an associated energy output of approximately fifty megawatts (MW). Modules <NUM> of analysis program <NUM> may then derive other operational parameters, e.g., an inlet temperature of <NUM>° C in turbine component <NUM>, an outlet temperature of <NUM>° C in turbine component <NUM>, by application of predetermined correlations, material properties of turbomachine <NUM>, etc. The expected value calculated in process PX4 may thus indicate one or more measurements that would be displayed on an ideal (i.e., properly operating) gauge <NUM>.

Continuing to process PX5, methods according to the disclosure include analyzing the difference between the gauge measurement(s) for an operating parameter, as detected in processes PX2, PX3, and the expected value(s) of the same parameter as calculated in process PX4. Embodiments of the disclosure can thus determine whether the measurement(s) displayed on gauge(s) <NUM> are consistent the expected value(s) for the same parameters. Process PX5 may include determining whether a difference between the gauge measurement(s), e.g., as expressed in gauge measurement field <NUM>, differ from the operating parameter's expected values by at least a predetermined threshold. The predetermined threshold may be stored in library <NUM> within threshold field <NUM>, as discussed elsewhere herein. In an illustrative example, the expected value of a parameter as calculated in process PX5 may be an outlet temperature of approximately <NUM>° C within turbine component <NUM>. However, the gauge measurement displayed on gauge <NUM> at the same moment of time may be, e.g., approximately <NUM>° C. Threshold field <NUM> may specify a threshold value of <NUM>° C difference between measured and expected values for this parameter, e.g., indicating that each gauge cannot misrepresent its respective operating temperature by more than a <NUM>° C difference. In cases where the difference between the gauge measurement of an operating parameter, and its expected value, exceeds the predetermined threshold (i.e., "Yes" at process PX5), the method may proceed to process PX6 of adjusting power generation system <NUM>, e.g., by recalibrating the gauge or shutting down power generation system <NUM> for servicing. In cases where the difference between the gauge measurement and its expected value is within the predetermined threshold (e.g., gauge <NUM> displays an inlet temperature between approximately <NUM>° C and approximately <NUM>° C; "No" at process PX5), the method may conclude ("Done"). Where continuous monitoring of power generation system <NUM> is desired, the flow may return to process PX2 of detecting another gauge measurement from the same gauge <NUM> or a different gauge <NUM>.

In cases where process PX6 of adjusting power generation system <NUM> is implemented, the method may include any one or more sub-processes (e.g., processes PX6-<NUM>, PX6-<NUM> shown in <FIG>). The adjusting of power generation system <NUM> in process PX6 may be undertaken automatically via system controller <NUM>, or in some cases may be undertaken with the aid of one or more operators, servicers, etc., of power generation system <NUM>. In still further examples, system controller <NUM> may implement the adjusting in process PX6 substantially automatically, with an operator or servicer of power generation system <NUM> serving only to verify the results of the adjusting after it concludes. In an example sub-process PX6-<NUM>, embodiments of the disclosure may include calibrating or re-calibrating (simply "calibrating" hereafter) gauge(s) <NUM> to display the correct measurement of a given operating parameter. The calibrating in process PX6-<NUM> may include, e.g., updating software on gauge(s) <NUM>, mechanically adjusting one or more sub-components of gauge(s) <NUM> (e.g., by adjusting a transducer, tare settings, component dimensions, etc.) to improve the accuracy of gauge(s) <NUM>.

In another example, gauge(s) <NUM> may incorrectly measure one or more operating parameters as a result of, e.g., being improperly installed, in the wrong location, having one or more defective parts, and/or being at the end of its useful life. In such cases, component(s) <NUM>, <NUM>, <NUM>, <NUM> and/or gauge(s) <NUM> may require servicing. To initiate servicing of <NUM>, <NUM>, <NUM>, <NUM> and/or gauge(s) <NUM>, embodiments of the disclosure may include initiating a shutdown of power generation system <NUM> in process PX6-<NUM>, e.g., via system controller <NUM>. To initiate a shutdown, system controller <NUM> may directly command one or more component(s) <NUM>, <NUM>, <NUM>, <NUM> to transition into a shutdown mode, cease operating altogether, etc. In further examples, system controller <NUM> may sound an alarm, alert, or other indicator to initiate a shutdown of power generation system <NUM>, or command another controller (not shown) to cease further operation of power generation system <NUM>. It is understood that process PX6 may include various other additional or alternative sub-processes for adjusting power generation system <NUM> to correct the measurement(s) displayed on gauge(s) <NUM>.

Referring now to <FIG>, an expanded schematic view of system controller <NUM> and camera <NUM> for visually monitoring the thermal characteristics of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> is shown. The example process flow shown in <FIG> may also be implemented to monitor acoustic characteristics, as discussed elsewhere herein. Camera(s) <NUM> may have a field of vision Fvis sized for visual monitoring of at least a portion of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> susceptible to thermal variability and/or acoustic disruptions. In an example, camera(s) <NUM> may include an infrared camera capable of detecting heat in the form of infrared light emitted from component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> within field of vision Fvis. In the example of <FIG>, system controller <NUM> may be operable to generate a heat distribution HDist for visualizing thermal properties of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis. In the example of <FIG>, heat distribution HDist may take the form of a two-dimensional coordinate map for identifying locations which exceed a threshold temperature. Within heat distribution HDist, locations which exceed a threshold temperature may be separately identified as violating regions HVio, and the presence of heat violating regions HVio may require, e.g., shutting down power generation system <NUM> (<FIG>) and/or servicing component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>. In some cases, system controller <NUM> may use sensor(s) <NUM> in combination with camera(s) <NUM> to generate heat distribution HDist for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis.

Referring now to <FIG>, <FIG>, and <FIG>, additional methods according to the disclosure may include controlling power generation system <NUM> based on the thermal properties of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, which may be expressed and stored in library <NUM> in heat distribution field <NUM>. Various embodiments of the disclosure may implement a dual analysis of thermal output and acoustic output of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, to adjust power generation system <NUM> based on a wider variety of circumstances, possible threats, etc. Methods according to the disclosure may include one or more of processes PY1-PY8 described herein. As noted elsewhere, the example methodologies illustrated in <FIG> and described herein may be combined with one or more other methods described herein, e.g., simultaneously or sequentially, where desired.

An initial process PY1 may include installing one or more camera(s) <NUM> within power generation system <NUM>. Process PY1 may be substantially the same as process PX1 (<FIG>) described elsewhere herein, apart from possible differences to the camera hardware being installed, the location where cameras are installed and the detectability of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, etc. Camera(s) <NUM> can be installed by a party implementing the various process steps described herein and/or another party before processes of the present disclosure are implemented. As such, process PY1 is shown in phantom to indicate that process PY1 may be a preliminary step which occurs before other processes according to the present disclosure. Camera(s) <NUM> installed in process PY1 may include, e.g., one or more infrared cameras capable of visually detecting the heat output from component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> within the field of view of camera(s) <NUM>. The installing of camera(s) <NUM> in process PY1 may include, e.g. electrically and mechanically coupling each camera <NUM> to a mounting component or fixture provided within power generation system <NUM>. A location for each camera <NUM> may be selected such that field of vision Fvis (<FIG>) for at least one camera <NUM> will visually monitor component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> and detect the heat output therefrom. The installation process may include, e.g., operating camera(s) <NUM> in a test mode to determine whether the desired component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> will be visually monitored. A user may operate camera(s) <NUM> manually to determine whether each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> to be monitored appears in the field view of the installed camera(s) <NUM>. The subsequent visual monitoring of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, may be implemented automatically by system controller <NUM>, and without user intervention, as described herein.

Continuing to process PY2, each camera <NUM> may operate independently of power generation system <NUM> to detect the heat distribution across each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> being monitored. As noted elsewhere herein, the heat distribution for each component may include, e.g., a two dimensional map of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, indicating locations which violate a respective temperature threshold. In various other embodiments, the heat distribution may include, e.g., any tabulation of detected temperatures and/or thermal properties accumulated at respective positions on one component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> being monitored. In a further example, the heat distribution may be, e.g., a temperature of a tank at its foundation, and a temperature of the same tank at its fluid outlet, each indexed with respect to the time when these temperatures are recorded. In a more sophisticated example, the detected heat distribution may constitute a two-dimensional or three-dimensional coordinate map of the monitored component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> at a time of measurement, with each coordinate being associated with a corresponding temperature or thermal energy output. Process PY2 thus may include, e.g., recording or otherwise obtaining photographic or video footage of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> at a particular time to detect the heat distribution. In some cases, process PY2 may include continuous video monitoring of component(s) in component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of power generation system <NUM>. In other cases, process PY2 may include burst-capture photography of component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> at particular intervals, e.g., capturing one image per predetermined interval (e.g., five-minute span) of operation.

The detecting of heat distributions for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> being monitored in process PY2 may yield a photographic or video record of temperatures, pressures, generated energy, flow rates, etc., for a particular component <NUM>, <NUM>, <NUM>, <NUM> in power generation system <NUM>. In conventional settings, a user or inspector would manually examine each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> for temperature-related anomalies. In embodiments of the disclosure, system controller <NUM> automatically detects the heat distribution of each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis via camera(s) <NUM>. In the case of an infrared camera, the detected images may be stored directly in heat distribution field <NUM> of library <NUM>. In other cases, the detected images may be cross-referenced with measured temperatures, times, coordinates, component IDs, etc., and stored in heat distribution field <NUM>, e.g., in the form of a table. In this case, the conversion from records provided by camera(s) <NUM> to heat distributions storable, e.g., in heat distribution field <NUM> of library <NUM> may be implemented via modules <NUM> via any currently known or later developed method for converting portions of an image to data.

After detecting the heat distribution for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> the method may proceed to process PY3 of calculating one or more projected heat distribution(s) for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>. Embodiments of the disclosure, in some cases, may detect a different accumulation of heat in one or more component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> than is otherwise acceptable. For example, embodiments of the disclosure are operable to detect, e.g., via camera(s) <NUM> and based on infrared imaging where applicable, whether one or more component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> have unacceptable thermal stress, have malfunctioned, are at risk of rupturing, etc. Process PY3 includes using other data, e.g., detected by sensor(s) <NUM> or included in library <NUM>, to calculate an expected heat distribution for each component <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis. The calculating in process PY3 may implemented, e.g., using modules <NUM> of analysis program <NUM>, or by direct reference to one or more sets of data included in library <NUM>.

In an example, sensor(s) <NUM> and current operating settings of power generation system <NUM> may indicate that combustor should have a firing temperature of e.g., approximately <NUM>° C when generating an energy output of approximately fifty megawatts (MW). However, camera(s) <NUM> positioned to visually monitor combustor(s) <NUM> may detect a firing temperature that is too high (e.g., <NUM>° C) or too low (e.g., <NUM>° C) for a particular setting. In a similar fashion, expected values for the temperature of various other components (e.g., inlet and outlet lines, the temperature of various protective casings, etc.) may be calculable for any component being visually monitored with camera(s) <NUM>. The calculated heat distribution may be specific as to the expected temperature and location for a given component. For instance, an inlet line to turbine component <NUM> may have an expected temperature distribution that is higher at a junction with combustor <NUM> than at a junction with the entrance to turbine component <NUM>. The expected value calculated in process PY3 may thus indicate the heat distribution for an idealized operation under the given operating settings of power generation system <NUM>.

Continuing to process PY4, methods according to the disclosure analyze the difference between the detected heat distribution(s) for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> under analysis, as detected in process PY2 and the projected value(s) of the heat distribution for the same component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> as calculated in process PY3. Embodiments of the disclosure can thus determine whether the detected heat distribution(s) for each component are with an acceptable range of the projected heat distribution(s) for the same operating settings or circumstances. Process PY4 includes determining whether a difference between the detected heat distribution(s) for component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>, e.g., as expressed in heat distribution field <NUM>, differ from the projected values of process PY3 by at least a predetermined threshold. The predetermined threshold may be stored in library <NUM> within threshold field <NUM>, as discussed elsewhere herein.

In an illustrative example, the projected heat distribution calculated in process PY3 may be an outlet temperature of approximately <NUM>° C at the outlet portion of combustor <NUM>. However, the detected heat distribution may include an outlet temperature of, e.g., approximately <NUM>° C. Threshold field <NUM> may specify a threshold value of <NUM>° C difference between measured and expected temperatures at the outlet of combustor <NUM>. Thus, the difference indicates that combustor <NUM> is operating at an abnormally high temperature (e.g., by having more than a <NUM>° C temperature difference). In cases where the difference between the detected heat distribution, and its projected value, exceeds the predetermined threshold (i.e., "Yes" at process PY4), the method may proceed to process PY5 of adjusting power generation system <NUM>, e.g., by servicing one or more components or shutting down power generation system <NUM> to prevent or mitigate damage to its components. In cases where the difference between the heat distribution and its projected value is within the predetermined threshold (i.e., "No" at process PY4), the method may conclude ("Done"). Where continuous monitoring of power generation system <NUM> is desired, the flow may return to process PY2 of detecting another heat distribution from the same component(s) or a different set of component(s).

In cases where process PY5 of adjusting power generation system <NUM> is implemented, the method may include any one or more sub-processes (e.g., processes PY5-<NUM>, PY5-<NUM> shown in <FIG>). The adjusting of power generation system <NUM> in process PY5 may be undertaken automatically via system controller <NUM>, or in some cases may be undertaken with the aid of one or more operators, servicers, etc., of power generation system <NUM>. In still further examples, system controller <NUM> may implement the adjusting in process PY5 substantially automatically, with an operator or servicer of power generation system <NUM> serving only to verify the results of the adjusting after it concludes. In an example sub-process PY5-<NUM>, embodiments of the disclosure may include repairing or otherwise servicing (simply "servicing" hereafter) component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> to resolve underlying heat dissipation problems with component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM>. The servicing in process PY5-<NUM> may include, e.g., repairing or replacing any component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> even as power generation system <NUM> continues operating. In such cases, the servicing may include treating or reinforcing sensitive portions of affected component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> to improve their heat distribution(s).

In another examples, component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> may have non-compliant heat distributions as a result of, e.g., being improperly installed, having one or more defective parts, and/or being at the end of its useful life. In such cases, component(s) <NUM>, <NUM>, <NUM>, <NUM> and/or gauge(s) <NUM> may require repair or replacement. Embodiments of the disclosure may include initiating a shutdown of power generation system <NUM> in process PY5-<NUM>, e.g., via system controller <NUM>. To initiate a shutdown, system controller <NUM> may directly command one or more component(s) <NUM>, <NUM>, <NUM>, <NUM> to transition into a shutdown mode, cease operating altogether, etc. In further examples, system controller <NUM> may sound an alarm, alert, or other indicator to initiate a shutdown of power generation system <NUM>, or command another controller (not shown) to cease further operation of power generation system <NUM>. It is understood that process PY5 may include various other additional or alternative sub-processes for adjusting, repairing, and/or replacing component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of power generation system <NUM>.

Embodiments of the disclosure may include additional processes for monitoring power generation system <NUM> based on acoustic outputs <NUM> detected via cameras <NUM> or other acoustic monitoring components in communication with system controller <NUM>. Processes PY6-PY8 shown in <FIG> may be implemented together with processes PY1-PY5 described herein, or may be implemented separately or in combination with other processes described herein. According to an example, embodiments of the disclosure may include process PY6 of installing camera(s) <NUM> or other sensing components to enable acoustic monitoring of system <NUM>. It is understood that PY6 may be the same process as PY1 (e.g., when cameras <NUM> include a microphone), or may be a separate process when distinct camera(s) <NUM> and/or other components for acoustic monitoring are installed. In any case, the method may proceed to process PY7 of detecting one or more acoustic disturbances within power generation system <NUM> as it operates. As used herein, an acoustic disturbance refers to one or more acoustic outputs <NUM> that are not expected to occur during operation of power generation system <NUM> according to its specifications and/or under its specified settings. To distinguish between acoustic outputs <NUM> that are expected, and acoustic disturbances to be monitored, camera(s) <NUM> and/or system controller <NUM> may include various noise filters and/or other criteria for identifying acoustic outputs <NUM> which constitute a disturbance.

Where camera(s) <NUM> or other acoustic monitoring devices detect acoustic output(s) <NUM> originating from multiple sources, and/or where noise (i.e., external acoustic signatures generated by sources other than component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> of power generation system <NUM>) contaminates acoustic output(s) <NUM>, process PY7 optionally may include processing acoustic output(s) <NUM> detected in process PY7 with system controller <NUM>. The processing of acoustic signatures <NUM> may include using modules <NUM> of analysis program <NUM> (e.g., waveform processing modules) to perform actions including, e.g., splitting each detected acoustic output <NUM> into distinct waveforms to be stored in memory <NUM> (e.g., in acoustic profile field <NUM> of library <NUM>), filtering acoustic waves with particular frequencies, amplitudes, etc., for removal, converting or simplifying acoustic signature(s) <NUM> into various waveform representations, etc..

Acoustic disturbances detected in process PY7 in some cases may originate from one or more operational violations including, e.g., component(s) <NUM>, <NUM>, <NUM>, <NUM>, <NUM> being in need of service, malfunctioning, being defective, and/or other similar problems. Acoustic disturbances detected in process P7 may also originate from operational violations caused by sources external to power generation system <NUM>, e.g., a human or animal trespassing in a sensitive area of power generation system <NUM>. To detect a broad range of operational violations, embodiments of the disclosure include determining in process PY8 whether the detected disturbance corresponds to one or more of the pre-determined operational violations. A set of acoustic profiles and/or other points of comparison may be included in library <NUM>, e.g., as part of threshold field <NUM>. Where the detected acoustic disturbance(s) corresponds to an operational violation (i.e., "Yes" at process PY8) the methodology may proceed to process PY5 to adjust power generation system as described elsewhere herein. Where the detected acoustic disturbance(s) do not correspond to an operational violation (i.e., "No" at process PY8), the method may conclude ("Done"), and/or optionally may return to process PY7 of detecting acoustic disturbance(s).

Turning to <FIG>, an expanded schematic view of system controller <NUM> and camera <NUM> for monitoring valve(s) <NUM> is shown. Camera(s) <NUM> may have a field of vision Fvis sized for visual monitoring of or more component(s) <NUM>, <NUM>, <NUM>, <NUM> with a fluid flow controllable via valve(s) <NUM>, <NUM>. The position of valve(s) <NUM>, <NUM> thus may control and define the fluid flow rate through component(s) <NUM>, <NUM>, <NUM>, <NUM> to which it operatively connects. In the example of <FIG>, component(s) <NUM>, <NUM>, <NUM>, <NUM> may include visual markings <NUM> to determine a valve position VPos by comparing the location and/or orientation of valve(s) <NUM>, <NUM> with respect to visual markings <NUM>. During operation, camera(s) <NUM> may visually monitor valve(s) <NUM>, <NUM> to detect the degree of valve <NUM>, <NUM> openness or closure based on visual markings <NUM>. System controller <NUM> may be further operable to evaluate fluid flow rate(s) through component(s) <NUM>, <NUM>, <NUM>, <NUM> via sensor(s) <NUM> in combination with camera(s) <NUM>. System <NUM> in some cases may include an adjustment device <NUM> in communication with system controller <NUM>, e.g., an electrical-mechanical converter, a robot, an actuator, etc., for physically adjusting the position of valve(s) <NUM>, <NUM> based on signals issued by system controller(s) <NUM>. As discussed herein, system controller <NUM> may implement various processes to detect and correct differences between the current valve position VPos and a target valve position for creating a desired fluid flow rate.

Referring to <FIG>, <FIG>, and <FIG> together, embodiments of the disclosure provide a method to control power generation system(s) <NUM> based on visual monitoring of valve(s) <NUM>, <NUM> via camera(s) <NUM>. Processes PZ1-PZ6 are shown by example in <FIG> as being implemented separately from other processes discussed elsewhere herein, but it is understood that each example flow diagram and set of processes discussed in embodiments of the disclosure may be implemented sequentially and/or simultaneously. It is understood that any or all of the various processes discussed herein optionally may be combined and implemented together substantially as a set of combined processes or sub-processes wherever possible.

An initial process PZ1 may include installing one or more camera(s) <NUM> within power generation system <NUM>. Camera(s) <NUM> can be installed by a party implementing the various process steps described herein and/or another party before processes of the present disclosure are implemented. As such, process PZ1 is shown in phantom to indicate that process PZ1 may be a preliminary step which occurs before other processes according to the present disclosure. The installing of cameras in process PZ1 may include, e.g. electrically and mechanically coupling each camera <NUM> to a mounting component or fixture provided within power generation system <NUM>. A location for each camera <NUM> may be selected such that at least one camera <NUM> may visually monitor valve(s) <NUM>, <NUM>, including the position of valve(s) <NUM>, <NUM> within its adjustable range. The visible position of valve(s) <NUM>, <NUM> may indicate the rate of fluid flow within a corresponding fluid flow section of power generation system <NUM>. The installation process may include, e.g., operating camera(s) <NUM> in a test mode to determine whether valve(s) <NUM>, <NUM> selected for analysis will be visually monitored. A user may operate camera(s) <NUM> manually to determine whether each valve <NUM>, <NUM> to be monitored appears in the field view of the installed camera(s) <NUM>. The subsequent visual monitoring of valve(s) <NUM>, <NUM> may be implemented automatically by system controller <NUM>, and without user intervention, as described herein.

At process PZ2, each camera <NUM> may operate independently of power generation system <NUM> to detect the position of valve(s) <NUM>, <NUM> to identify the corresponding flow rate of fluids within a portion of power generation system <NUM>. Process PZ2 thus may include, e.g., recording or otherwise obtaining photographic or video footage of valve(s) <NUM>, <NUM> at a particular time, with the position(s) of each valve <NUM>, <NUM> being visible. In some cases, process PZ2 may include continuous video monitoring of power generation system <NUM>. In other cases, process PZ2 may include burst-capture photography of valve(s) <NUM>, <NUM> at particular intervals, e.g., capturing one image per predetermined interval (e.g., five-minute span) of operation. The detecting of valve(s) <NUM>, <NUM> in process PZ2 may yield a photographic or video record of the fluid flow rate through a corresponding portion of power generation system <NUM>. In conventional settings, a user or inspector would manually examine each valve <NUM>, <NUM> to identify its position. In embodiments of the disclosure, system controller <NUM> detects the position of valve(s) <NUM>, <NUM> automatically via camera(s) <NUM>. The conversion from images or video provided by camera(s) <NUM> to valve position measurements storable, e.g., in valve position field <NUM> of library <NUM> may be implemented via any currently known or later developed method for converting portions of an image to data.

Turning to process PZ3, depicted in phantom to indicate an optional procedure, the method may include implementing pattern recognition on images or video captured by camera(s) <NUM> to isolate or extract the valve <NUM>, <NUM> positions visible therein. According to an example, modules <NUM> of computing device <NUM> may include one or more algorithms, look-up tables, mathematical formulas, etc., capable of automatically identifying one or more portions of an image, or video, as illustrating a gauge measurement. In a more specific example, at least one valve <NUM>, <NUM> may include visual identifiers <NUM> (<FIG>) in the form of a contrasting-colored measuring instrument (e.g., red marker on a rotatably adjustable valve) to for identify the degree to which valve(s) <NUM>, <NUM> are open or closed. Camera <NUM> and/or system controller <NUM> additionally may include physical image filters and/or similar tools for isolating irrelevant sections of an image or video feed to better identify the position of valve(s) <NUM>, <NUM>. Gauge measurements detected in PZ2, and PZ3 where applicable, may be stored in valve position field <NUM> of library <NUM>.

The method may continue by implementing process PZ4 of calculating one or more target flow rates to be controlled by valve(s) <NUM>, <NUM> during a given state of operation (e.g., startup, transient, steady state, downturn, etc.). Embodiments of the disclosure, in some cases, may detect a position of valve(s) <NUM>, <NUM> that is inconsistent with the target position for creating desired fluid flow rate. For example, embodiments of the disclosure are operable to detect, e.g., whether one or more valve(s) <NUM>, <NUM> are too far open, or too far closed, relative to their desired position for a particular type of operation. Process PZ4 includes using other data, e.g., detected by sensor(s) <NUM> or included in library <NUM>, and/or direct commands to system controller <NUM>, to calculate a target flow rate of fluid(s) controlled by valve(s) <NUM>, <NUM>. The calculating in process PZ4 may implemented, e.g., using modules <NUM> of analysis program <NUM>, or by direct reference to one or more sets of data included in library <NUM>. In an example, sensor(s) <NUM> may detect, during steady state operation, a valve position of <NUM>% open to produce a fluid flow of <NUM> kilograms per hour through turbine component <NUM>. Where transient operation has initiated, a user may desire to partially close valve(s) <NUM>, <NUM> to control the fluid flow through turbine component <NUM>. In this case, modules <NUM> of analysis program <NUM> may calculate a valve position suitable to produce a reduced fluid flow (e.g., approximately <NUM> kilograms per hour) for transient operation, e.g., by application of predetermined correlations, material properties of turbomachine <NUM>, etc. According to the same example, modules <NUM> may calculate a target flow rate of <NUM> kilograms per hour, which may be associated with valve(s) <NUM>, <NUM> being in a <NUM>% open position. The target flow rate calculated in process PZ4 may thus indicate the desired fluid flow for a present or upcoming operating mode of power generation system <NUM>.

Continuing to process PZ5, methods according to the disclosure analyze the difference between the current valve <NUM>, <NUM> position, as detected in processes PZ2, PZ3, and the target valve <NUM>, <NUM> position as calculated in process PZ4. Embodiments of the disclosure can determine whether the valve <NUM>, <NUM> position(s) are consistent their target values for various circumstances. Process PZ5 may include determining whether a difference between the flow rate for the current valve <NUM>, <NUM> position(s), e.g., as expressed in valve position field <NUM>, differ from the target flow rate(s) by at least a predetermined threshold. The predetermined threshold may be stored in library <NUM> within threshold field <NUM>, as discussed elsewhere herein. In an illustrative example, the target fluid flow rate through turbine component <NUM> may be, e.g., <NUM> kilograms per second, which may arise from valve(s) <NUM>, <NUM> being in a <NUM>% open position. However, valve(s) <NUM>, <NUM> may be in a <NUM>% open position, e.g., due to previous steady-state operation. Threshold field <NUM> may specify a threshold value of <NUM>% valve <NUM>, <NUM> openness difference between detected and target values for valve openness, e.g., indicating that valve <NUM>, <NUM> cannot differ from its target position by more than approximately <NUM>% openness. In cases where the difference between the flow rate for a given valve <NUM>, <NUM> position, differs from its target value by the predetermined threshold (i.e., "Yes" at process PZ5), the method may proceed to process PZ6 of adjusting power generation system <NUM>, e.g., by modifying the position(s) of valve(s) <NUM>, <NUM> or shutting down power generation system <NUM> for servicing and/or further adjustment. In cases where the difference between the flow rate for the current valve <NUM>, <NUM> position(s) and the target flow rate is within the predetermined threshold (i.e., "No" at process ZX5), the method may conclude ("Done"). Where continuous monitoring of power generation system <NUM> is desired, the flow may return to process PZ2 of again detecting the position(s) of valve(s) <NUM>, <NUM> or different valve(s) <NUM>, <NUM>.

In cases where process PZ6 of adjusting power generation system <NUM> is implemented, the method may include various sub-processes (e.g., processes PZ6-<NUM>, PZ6-<NUM> shown in <FIG>). The adjusting of power generation system <NUM> in process PZ6 may be undertaken automatically via system controller <NUM>, or in some cases may be undertaken with the aid of one or more operators, servicers, etc., of power generation system <NUM>. In still further examples, system controller <NUM> may implement the adjusting in process PZ6 substantially automatically, with an operator or servicer of power generation system <NUM> serving only to verify the results of the adjusting after it concludes. In an example sub-process PZ6-<NUM>, embodiments of the disclosure may include modifying the position of valve(s) <NUM>, <NUM> to achieve the target flow rate(s) therethrough. The adjusting in process PX6-<NUM> may include, e.g., causing a user adjustment device <NUM> (<FIG>) (e.g., an adjustment mechanism of power generation system <NUM> and/or other device external to power generation system <NUM> and in communication with system controller <NUM>, such as a robot) to mechanically adjust valve(s) <NUM>, <NUM>. In alternative examples where valve(s) <NUM>, <NUM> are at least partially automated, system controller <NUM> may directly adjust valve(s) <NUM>, <NUM> until the target flow rate is reached.

In another example, valve(s) <NUM>, <NUM> may be in an undesired position, e.g., due to being improperly modified, adjusted, having one or more defective parts, and/or being at the end of its useful life. In such cases, valve(s) <NUM>, <NUM> may require servicing. To initiate servicing of valve(s) <NUM>, <NUM>, embodiments of the disclosure may include initiating a shutdown of power generation system <NUM> in process PZ6-<NUM>, e.g., via system controller <NUM>. To initiate a shutdown, system controller <NUM> may directly command one or more component(s) <NUM>, <NUM>, <NUM>, <NUM> to transition into a shutdown mode, cease operating altogether, etc. In further examples, system controller <NUM> may sound an alarm, alert, or other indicator to initiate a shutdown of power generation system <NUM>, or command another controller (not shown) to cease further operation of power generation system <NUM>. It is understood that process PZ6 may include various other additional or alternative sub-processes for adjusting power generation system <NUM> to modify valve(s) <NUM>, <NUM>, or more generally to modify various aspects of power generation system <NUM>.

Technical effects of the invention are to automatically monitor and adjust operating parameters of power generation system <NUM> based on various criteria. In one example, technical effects of the invention are to automatically adjust the measurements displayed on gauge(s) <NUM> based on expected operating parameters, or automatically shutting down power generation system <NUM> in the event that one or more gauge(s) <NUM> fail. In another example, technical effects of the invention are to automatically adjust, or automatically initiate servicing of, various component(s) <NUM>, <NUM>, <NUM>, <NUM> upon detecting a non-conforming heat distribution, and/or to automatically shut down further operation of power generation system <NUM> upon detecting a non-conforming heat distribution. In yet another example, technical effects of the invention are to recognize when the fluid flow through valve(s) <NUM>, <NUM> does not meet a target amount of fluid flow, and thereafter automatically adjust the position of valve(s) <NUM>, <NUM> to meet the target fluid flow, or otherwise cease operation of power generation system <NUM>. In each example, the determination may be based at least partially on images and/or video collected by visually monitoring power generation system(s) <NUM> with camera(s) <NUM>. Advantages of the present disclosure include, e.g., reducing or eliminating the need for people to visually inspect and record various attributes of power generation system(s) <NUM> on-site. Additional advantages of the present disclosure include the ability for one or more system controllers <NUM> to automatically control, via visual monitoring, various properties of multiple power generation systems <NUM> via the internet as part of a network of remote power generation system(s) <NUM>.

Claim 1:
A method for controlling a power generation system (<NUM>), the method comprising:
visually monitoring, with a camera, a thermal output of a component (<NUM>, <NUM>, <NUM>) of the power generation system (<NUM>);
detecting a heat distribution across the component (<NUM>, <NUM>, <NUM>) of the power generation system (<NUM>) from the visually monitored thermal output of the component (<NUM>, <NUM>, <NUM>), during operation of the power generation system (<NUM>);
calculating a projected heat distribution across the component (<NUM>, <NUM>, <NUM>) based on a library (<NUM>) of modeling data for the power generation system (<NUM>);
calculating whether a difference between the heat distribution and the projected heat distribution exceeds a thermal threshold;
adjusting, by a system controller (<NUM>) in communication with the camera and the power generation system (<NUM>), the power generation system (<NUM>) in response to the difference exceeding the thermal threshold, wherein the adjusting includes modifying an operating setting of the power generation system (<NUM>);
wherein the power generation system (<NUM>) is positioned at a first geographic location, the system controller (<NUM>) is positioned at least partially at a second geographic location different from the first geographic location, and wherein the power generation system (<NUM>) is one of a plurality of power generation systems, each of the plurality of power generation systems being positioned at a different respective geographic location; and
wherein the system controller (<NUM>) is further configured to control one or more power generation systems of the plurality of power generation systems other than the power generation system (<NUM>).