Abstract: An objective of the present invention is to provide a control device, control system, control method, and computer-readable storage medium, for enabling verification of the reliability of operation machine control. Provided is a control device comprising: a control part comprising a controller for outputting output data with regard to input data, said control part serving to control an operation machine using the controller; an acquisition part for acquiring attribute information including statistics of previously obtained input data and output data; and an evaluation part for, on the basis of a comparison of the attribute information with new input data being newly inputted into the controller and/or new output data being newly outputted from the controller with regard to the new input data, evaluating to what extent the new input data and/or the new output data deviate from the statistics.

Abstract: A steam turbine pipe 1 of an embodiment includes: an upper half side main steam pipe 11 that leads steam to a steam turbine; an upper half side main steam control valve 30 that intervenes in the upper half side main steam pipe 11; and a post-valve drain pipe 31 that is connected to the upper half side main steam control valve 30 and leads drain to an outside. The steam turbine pipe 1 further includes: a shut-off valve 32 that intervenes in the post-valve drain pipe 31; and a branching pipe 60 that makes the post-valve drain pipe 31 on the side closer to the upper half side main steam control valve 30 than is the shut-off valve 32 communicate with the upper half side main steam pipe 11 between the upper half side main steam control valve 30 and a high-pressure turbine 200.

Abstract: In a method for actuating a shim coil arrangement of a magnetic resonance data acquisition scanner that has a shim controller that operates said shim coil arrangement, and a gradient coil arrangement operated by a gradient controller, the gradient controller determine a gradient pulse shape, in accordance with specifications of a magnetic resonance data acquisition sequence, that is activated by the gradient coil arrangement, when the sequence is executed in said scanner. A modifies the gradient pulse shape and provides the modified gradient pulse shape to the shim controller and the shim controller generates shim settings dependent on the modified gradient pulse shape, and actuates said shim coil arrangement according to the shim settings during activation of the gradient pulse shape by the gradient coil arrangement during execution of the sequence in said scanner.

Abstract: Embodiments of the invention provide systems, methods, and apparatus for receiving input information including at least one of generator parameters, energy output requirements, fuel cost, fuel availability, and a maintenance schedule; creating a resource model based on the input information wherein creating the resource model includes linearizing a quadratic objective function and linearizing a quadratic gas constraints function; generating an optimized operating schedule, fuel mix, and allocation plan from the resource model based on the input information; and controlling the generator resources to optimally meet energy output requirements using the operating schedule fuel mix, and allocation plan. Numerous other aspects are provided.

Abstract: A blade vibration monitor backpressure limiting system (BVMBLS), that in addition to direct blade vibration and condenser backpressure monitoring utilizes other plural types of other parallel, real time monitored power plant operation state (OS) information that influences blade vibration. The system references previously stored information in an information storage device that associates respective types of monitored OS information with blade vibration. The BVMBLS determines in real time a likelihood of whether any of the monitored operation states, alone or in combination with other types of monitored operation states, is indicative of a turbine blade vibration safe operation (SO). The BVMBLS determination is utilized to increase or reduce power generation load incrementally so that power efficiency and maximum load is enhanced while turbine blade vibration is maintained in a safe operation state. The previously stored information is updated to new association information.

Abstract: Certain embodiments of the disclosure may include systems and methods for boundary control during steam turbine acceleration. According to an example embodiment, the method can include receiving an indication the turbine is in an initial acceleration phase; receiving speed control parameter data from a plurality of sensors; receiving boundary control parameter data from a plurality of sensors; providing a control valve configured for controlling steam flow entering the turbine; determining the control valve position based on received speed control parameter data; determining the control valve position based on received boundary control parameter data; adjusting at least one boundary control parameter to the at least one boundary control parameter limit during turbine startup, wherein the value of a speed control parameter is simultaneously adjusted based on the adjusted at least one boundary control parameter; and adjusting the control valve position based at least on determined parameter data.

Abstract: Operation of a hydropower generation facility may be optimized by consideration and analysis of multiple factors influencing function of the facility. Aspects of the facility and surrounding hydraulic system are represented in a model that may include efficiency curves for hydropower turbines. Efficiency curves for one or more turbines are approximated by piecewise linear functions. The use of piecewise linear representations allows for calculation of recommended operational settings as well as predicted outputs in real time. An optimization system may consider input data such as weather and market prices for electricity. The input data may also include desired operational outputs of the hydropower generation facility. A user interface may present recommendations for specific operational settings to achieve the desired operational outputs.

Abstract: A method for noise-reduced operation a wind is provided. The method includes determining a wind speed during normal operation of the wind turbine and determining a weighted rotor speed setpoint for a rotor of the wind turbine so that a noise emission of the wind turbine for the wind speed is reduced compared to nominal noise emission of the wind turbine at the wind speed. Using the weighted rotor speed setpoint, a torque setpoint for a power conversion assembly connected to the rotor is determined. The torque setpoint is applied to the power conversion assembly to control the wind turbine.

Abstract: Systems, methods, and apparatus embodiments for electric power grid and network registration and management of active grid elements. Grid elements are transformed into active grid elements following initial registration of each grid element with the system, preferably through network-based communication between the grid elements and a coordinator, either in coordination with or outside of an IP-based communications network router. A multiplicity of active grid elements function in the grid for supply capacity, supply and/or load curtailment as supply or capacity. Also preferably, messaging is managed through a network by a Coordinator using IP messaging for communication with the grid elements, with the energy management system (EMS), and with the utilities, market participants, and/or grid operators.

Abstract: A system is provided for mitigating an electric unbalance of a three-phase current at a Point of Common Coupling being located between a wind farm having a plurality of wind turbines and a power grid. The system includes a measurement device and a central wind farm controller. The measurement device measures the electric unbalance at the Point of Common Coupling and provides a measurement signal being indicative for the measured electric unbalance. The central wind farm controller is coupled to the measurement device and controls the operation of the plurality of wind turbines. In response to the measurement signal the central wind farm provides a control signal for mitigating the electric unbalance at the Point of Common Coupling. Also provided is a corresponding method for mitigating an electric unbalance of a three-phase current and a computer program for controlling and/or for carrying out the mentioned method.

Abstract: A system includes a metering module that receives fluid through a fluid inlet. The metering module includes a rotating component driven by the fluid, an electric machine, and a controller. The fluid is received from the fluid inlet at an inlet flow rate, and the rotating component provides the fluid to an outlet of the rotating component at an outlet pressure. The electric machine is configured to generate electrical power in response to rotation of the rotating component. The controller is powered by the electrical power generated by the electric machine, and controls a rotational speed of the rotating component to control the outlet pressure.

Abstract: A controller for a building management system includes a system of rules for detecting faults in the building management system. The rules include content conditions and trigger conditions. The content conditions are not checked until one or more of the trigger conditions are met. A rule-based fault detection engine may be implemented by a low level building equipment controller. One or more thresholds for a rule may be automatically or manually adjusted.

Abstract: A present invention relates to a novel hybrid intelligent control system and method for power generating apparatuses, in which the control system comprises: a fuzzy sliding mode speed controller, embedded with a fuzzy inference mechanism so as to be used for controlling the speed of a power generating apparatus; and a radial basis function network (RBFN) pitch controller, being embedded with an on-line training RBFN so as to be used for controlling the pitch angle of a turbine coupled to the power generating apparatus. In a variable-speed energy conversion system using the aforesaid control system, the turbine can be driven to operate at its maximum efficiency by adjusting its blade pitch angle in response to the variation of the input flowing into the turbine, while allowing the shaft speed of the power generating apparatus to be controlled by a fuzzy interference mechanism so as to achieve its maximum power output.

Abstract: A method of decreasing a transition time through a speed range that is unsafe for an integrity of a first expander, by automatically biasing a speed of a second expander that receives a fluid flow output from the first expander is provided, when the current speed of the first expander is within a bias application range. The method includes setting the speed of the second expander to be larger than a current speed of the first expander when the current speed of the first expander increases and is smaller than a first speed value, or decreases and is smaller than a second speed value, and setting the speed of the second expander to be smaller than the current speed of the first expander, when the current speed of the first expander increases and is larger than the first speed value or decreases and is larger than the second speed value.

Abstract: A method of controlling a transition time through a speed range that is unsafe for an integrity of a second expander that receives a fluid flow from a first expander, by automatically biasing a speed of the second expander is provided. The method includes setting the speed of the second expander to be smaller than a current speed of the first expander. The method also includes setting the speed of the second expander to be larger than the current speed of the first expander, when the current speed of the first expander is within the bias application range, and the current speed of the second expander increases and is larger than the first speed value, or decreases and is larger than the second speed value.

Abstract: A method for controlling operation of a wind turbine and a method for controlling operation of a plurality of wind turbines positioned in a wind farm are disclosed. According to the method, a pitch and rotational speed curve, e.g. a ? versus ? curve, is selected from a group of pitch and rotational speed curve, and the wind turbine is operated in accordance with the selected curve for a short period, while monitoring at least one target parameter, e.g. power production or loads on one or more components. This is repeated for each of the curves of the group of pitch and rotational speed curves. This is also repeated a predetermined number of times, i.e. each curve is selected in turn a predetermined number of times. Based on the monitored target parameters an optimum curve is determined from the group of pitch and rotational speed curve, and the wind turbine is operated in accordance with this optimum curve.

Abstract: A wind energy plant and method for operating it, the plant having a doubly-fed asynchronous machine, a grid-sided converter and a generator-sided converter both being controlled by a control means. In case of a grid fault the converters are controlled by at least one control module which (i) controls the torque and/or the active power and (ii) controls the reactive current and/or the reactive power.

Abstract: Provided is a gas turbine operation control device and operation control method that are capable of suppressing turbine inlet temperature and of satisfying the demand response for shaft output. An IGV emergency fully-open flag is activated when the output of a generator is in a high load band at or above a predetermined value, and the like. When the IGV emergency fully-open flag is activated, the degree of opening of an inlet guide vane is set to a predetermined degree of opening, a temperature adjustment setting is set by switching in accordance with the degree of opening of the inlet guide vane, and an exhaust gas temperature setting value or a blade path temperature setting value of a turbine, for controlling the fuel supply amount for a combustor, is generated based on the temperature adjustment setting.

Abstract: A rotor blade is used in combination with a submersible electrical generator for generating electricity to be put into the grid, where the pitch of the rotor blade is controlled by a microprocessor. The microprocessor controls a radio frequency transmitter which emits signals to a receiver which controls a hydraulic value. The hydraulic valve controls a push-pull arrangement which through a right angle gear and pitch adjustment axial adjust the rotor pitch according to pre-programmed conditions stored in the microprocessor.

Abstract: Methods for setting a basal rate profile for an insulin pump with an input unit and a calculation unit are disclosed. A number of interpolation nodes for the basal rate profile are defined by means of the input unit of the insulin pump. A continuous function with respect to the interpolation nodes, which images the interpolation nodes and any previously stored basal rates, is formed using the calculation unit of the insulin pump, and a temporal sequence of basal rates to be released by the insulin pump during specific time intervals is generated from the continuous function using the calculation unit of the insulin pump.

Abstract: Systems and methods for specifying one or more operational parameters for a pumping system are disclosed. A first suction pressure loss profile for a first pump in a pumping system is determined. A second suction pressure loss profile for a second pump in the pumping system is determined. The first suction pressure loss profile is compared with the second suction pressure loss profile. One or more operational parameters are specified based, at least in part, on the comparison.

Abstract: A method of controlling at least one wind turbine is provided. The method comprises predicting at least one future state related to the at least one wind turbine. The method further comprises evaluating a fitness of solutions associated with a plurality of individuals of a population for a current operating environment of the at least one wind turbine. Each individual comprising a dominant genotype and a recessive genotype. Each genotype represents a solution for controlling the at least one wind turbine. A fitness function is applied to the dominant genotype of each individual. The fitness function is based on the at least one predicted future state. The method further comprises storing previously encountered genotypes in the recessive genotypes of the individuals. The method further comprises selecting a solution for controlling operation of the at least one wind turbine based on the fitness evaluation.

Abstract: A method for simulating a compressor of a gas turbine may generally include determining a predicted pressure ratio and a predicted mass flow of the compressor based on a model of the gas turbine, monitoring an actual pressure ratio and an actual mass flow of the compressor, determining difference values between at least one of the predicted pressure ratio and the actual pressure ratio and the predicted mass flow and the actual mass flow, modifying the difference values using an error correction system to generate a compressor flow modifier and using the compressor flow modifier to adjust the predicted pressure ratio and the predicted mass flow.

Abstract: A system for tuning the operation of a gas turbine is provided based on measuring operational parameters of the turbine and directing adjustment of operational controls for various operational elements of the turbine. A controller is provided for communicating with sensors and controls within the system. The controller receiving operational data from the sensors and comparing the data to stored operational standards to determining if turbine operation conforms to the standards. The controller then communicates selected adjustment in an operational parameter of the turbine. The controller then receives additional operational data from the sensors to determine if an additional adjustment is desired or is adjustment is desired of a further selected operational parameter.

Abstract: A system for managing and synchronizing the operation of an electric power generation and delivery system that includes a number of generators configured to provide distributed electric power generation is disclosed. In the disclosed system, a number of intelligent electronic devices coupled with at distributed generators may be utilized to synchronize the operation of the generators with the system when the generators become isolated from the system. In some embodiments, the disclosed intelligent electronic devices may control the speed of isolated generators based on synchronization information received from at least one other intelligent electronic device and a common time signal.

Abstract: A method for assembling a gas turbine engine to prevent rotor over-speeding is described. The method includes serially coupling a first fuel system interface to a second fuel system interface, such that at least one of the first fuel system interface and the second fuel system interface is coupled to the gas turbine engine. The method also includes coupling a control system to the first fuel system interface and to the second fuel system interface. The control system is configured to identify an occurrence of an over-speed condition. The method also includes programming the control system to discontinue fuel flow to the engine when both the first fuel system interface and the second fuel system interface indicate an over-speed condition has occurred.

Abstract: An overspeed protection system for a gas turbine engine comprises: a plurality of engine speed sensors that generate engine speed signals; and a plurality of engine overspeed detection channels, each channel comprising an overspeed detector that receives and generates an overspeed signal when it detects the engine speed signal exceeding a selected value of overspeed.

Abstract: An engine having at least one stage of propeller rotor blades, and a load, the at least one stage being associated with electrical generation means to generate electricity for the load. The load is switchable into a high load state in the event of an overspeed signal from the rotor blades. Also a method of controlling rotor overspeed of an engine, characterized by the steps of: i. detecting an overspeed signal from the at least one stage, and ii. switching the load into a high load state to apply torque to the at least one stage to counteract the overspeed.

Abstract: A method and apparatus for controlling an air motor. Speed information is received for an operation using an apparatus comprising the air motor having an inlet and an exhaust, and a valve comprising a body with a first port, a second port, and a third port. The first port is connected to the air motor, the second port is configured for connection to an air supply, and the third port is configured to vent air out of the body. A first flow of air is controlled in the body between the first port and the second port and a second flow of air is controlled out of the body through the third port to control a speed of the operation.

Abstract: An auxiliary power unit has a speed sensor for sensing a speed of operation of the auxiliary power unit. The speed sensor sends a signal to an electronic control box. The electronic control box is operable to control the auxiliary power unit. A branch line is for communicating the speed signal to a health monitoring system. The branch passes through an electronic component that will isolate the speed signal as it passes beyond the component and to the downstream use, such that corruption at a downstream use will not pass back upstream to corrupt the signals used in the electronic control box.

Abstract: An embodiment of the present invention may incorporate an adaptive model based control (MBC) for determining a physical parameter including: generator output, head, generator speed, or the like. The adaptive MBC may reduce the need for pre-defined control curves. The adaptive MBC may receive a plurality of data on the hydroelectric plant, and then builds a new operating model, based on that data, which controls the operation of a hydroelectric plant. This model may then be used to forecast and/or control an output variable including the generator output of the hydroelectric plant. The MBC of an embodiment of the present invention may be configured to automatically and/or continuously monitor the hydroelectric plant to determine whether the output parameter is within a desired range.

Abstract: An apparatus for determining a resonant frequency of a wind turbine tower is provided. The apparatus includes a processing unit configured to receive an acceleration measurement value, the acceleration measurement value representative of the acceleration of the wind turbine tower in the direction parallel to a rotor rotational axis of the wind turbine and/or in the direction perpendicular to both the rotor rotational axis and the tower axis of the wind turbine. The apparatus includes a memory configured to store a series of acceleration measurement values, and the processing unit includes a Fourier transform module configured to calculate a spectral vector based on calculating a convolution-based fast Fourier transform of the series of acceleration measurement values, and includes a resonant frequency calculation module configured to calculate the tower resonant frequency based on the calculated spectral vector.

Abstract: An optimization and control system for a utility plant that uses fan based air cooled condensers controls the operation of the power generation system at the plant in conjunction with the operation of the air cooled condensers so as to run the power plant at an optimum operating point associated with minimizing or reducing the cost of each kilowatt-hour of energy or other useful energy produced by the plant. The optimization and control system includes an optimizer having a numerical solver that determines values for a set of control variables associated with an optimal operating point of the plant and an expert system that oversees and modifies the control variable settings prior to providing these settings to a plant controller. The numerical solver uses an objective function and one or more models of plant equipment to determine the operating point of the plant that minimizes the cost per unit of useful energy generated by the plant.

Abstract: A controller for use in managing an operational lifetime of at least one wind turbine is communicatively coupled to at least one wind turbine and a server sub-system. The controller is configured to receive operational data from the wind turbine, transmit the operational data to the server sub-system, and transmit a request for historical data corresponding to the wind turbine to the server sub-system. The controller is further configured to receive a response from the server sub-system, wherein the response includes historical data corresponding to the wind turbine, and to determine an estimate of a time failure of the wind turbine based on at least one of the operational data and the historical data.

Abstract: A method of controlling a power generating unit or other process equipment with a slow reaction time includes creating a feedforward control signal to selectively include a fast response rate component or a slow response rate component based on the average rate at which a load demand set point signal has changed during a particular previous period of time. The method then uses the developed feedforward control signal to control the power generating equipment or other slowly reacting process equipment. In particular, a control method switches between introducing a fast or a slow response component within a feedforward control signal based on whether the change in the load demand set point over a particular period of time in the past (e.g., an average rate of change of the load demand set point signal) is greater than or less than a predetermined threshold. This method is capable of providing a relatively fast control action even if the expected load demand set point change is in a small range.

Abstract: A method for starting up a wind energy plant after an operation stoppage, wherein the wind energy plant has a gearbox in the drive train and an operation management which can control at least one operational variable significant for the strain of the gearbox B of the wind energy plant to a desired value BSoll, wherein after the operation stoppage, the desired value BSoll is limited by a maximum value BMax, which is preset depending on a measured temperature of a gearbox component and/or of a lubricant for the gearbox.

Abstract: Provided is a gas turbine operation control device and operation control method that are capable of suppressing turbine inlet temperature and of satisfying the demand response for shaft output. An IGV emergency fully-open flag is activated when the output of a generator is in a high load band at or above a predetermined value, and the like. When the IGV emergency fully-open flag is activated, the degree of opening of an inlet guide vane is set to a predetermined degree of opening, a temperature adjustment setting is set by switching in accordance with the degree of opening of the inlet guide vane, and an exhaust gas temperature setting value or a blade path temperature setting value of a turbine, for controlling the fuel supply amount for a combustor, is generated based on the temperature adjustment setting.

Abstract: In a process for protection of a gas turbine (1) from damage caused by pressure pulsations (P), pressure pulsations (P) occurring during the operation of the gas turbine (1) are measured, from the measured pressure pulsations (P), a pulsation-time signal (PZS) is generated, the pulsation-time signal (PZS) is transformed into a pulsation-frequency signal (PFS), from the pulsation-frequency signal (PFS), a pulsation level (PL) is determined for at least one specified monitoring frequency band (12), the pulsation level (PL) is monitored for the occurrence of at least one specified trigger condition, and, when the at least one trigger condition occurs, a specified protective action (16) is carried out.

Abstract: A method of coupling a mechanical power source through an electrical power generator to an electrical load is disclosed. A characteristic of an electrical output is measured from the electrical power generator produced during a power generation cycle during which there is a coupling of the mechanical power source through the electrical power generator to the electrical load. The coupling of the mechanical power source is adjusted through the electrical power generator to the electrical load during a subsequent power generation cycle based at least in part on the measured characteristic of the electrical output.

Abstract: A method for simulating a gas turbine including the steps of: sensing values of a plurality of first operating parameters of an actual gas turbine; applying the sensed values of the first operating parameters to a model of the gas turbine, wherein the model generates a plurality of predicted second operating parameters; determining difference values between the predicted second operating parameters and corresponding sensed second operating parameters of the actual gas turbine; modifying the difference values based on tuning factors generated by a Kalman filter gain matrix during operation of the gas turbine, and using the adjusted difference values to adjust the model of the gas turbine. The method may further comprise generating the tuning factors by applying to the model the sensed values of the plurality of first operating parameters and perturbated values of the adjusted different values to determine optimal tuning factors.

Abstract: An embodiment of the present invention may incorporate an adaptive model based control (MBC) for determining a physical parameter, such as, but not limiting of, generator output, head, generator speed, or the like. The adaptive MBC may reduce the need for pre-defined control curves. The adaptive MBC may receive a plurality of data on the hydroelectric plant and then build an operating model. This model may then be used to forecast and/or control an output variable, such as, but not limiting of, a generator output of the hydroelectric plant. The control system of an embodiment of the present invention may be configured to automatically and/or continuously monitor the hydroelectric plant to determine whether a physical parameter is within a desired range. Alternatively, the control system may be configured to require a user action to the initiate operation. An embodiment of the control system of the present invention may function as a stand-alone system.

Abstract: An intelligent auxiliary power supply system for supplying power to a load such as a furnace or air handler using a rechargeable power source. An intelligent controller determines appropriate periods for switching to auxiliary power, thus allowing the user to realize increased energy related cost savings. A plurality of sensors including a current transducer, an indoor and outdoor temperature sensor, and a clock transmit information to the intelligent controller. Implementing user configured algorithms, the intelligent controller continuously compares information transmitted from said sensors and said load, to information inputted by the user via an electronic device to determine the appropriate power configuration. A remote electronic device may also be connected to the system, allowing the user to control the system while not in close proximity to said system and also allowing the user's energy provider to send requests to switch to auxiliary power.

Abstract: A microsource is provided, which includes a generator, a prime mover, and a controller. The prime mover includes a shaft connected to drive the generator to generate power at a frequency controlled by a rotation rate of the shaft. The controller calculates an operating frequency for the generator based on a comparison between a power set point and a measured power flow. A requested shaft speed for the prime mover is calculated by combining a maximum frequency change, a minimum frequency change, and the calculated operating frequency. A shaft speed adjustment is calculated for the prime mover based on a comparison between the requested shaft speed and a measured shaft speed of the prime mover. A fuel command for the prime mover is calculated based on the shaft speed adjustment. A rotation rate of the shaft of the prime mover is adjusted based on the calculated fuel command to control the frequency.

Abstract: A system and method for controlling the speed of a turbine engine, the turbine engine being operative to provide power to a primary load. When a decrease in the power requirement of the primary load is detected, at least a portion of the power generated by the turbine engine is redirected to a secondary load, thereby maintaining the speed of the turbine engine below a rated maximum speed. In the example of a turbine-powered train in which the turbine engine provides power to electric traction motors driving the wheels of the train, when a wheel spin is detected, at least a portion of the power generated by the turbine engine is diverted from the respective electric traction motor to rheostats for conversion to heat.

Abstract: This invention relates to a speed monitor apparatus for monitoring speed and acceleration of rotating turbine equipment (turbomachinery) and for operating an overspeed trip to shut down the equipment in the event that the speed or acceleration exceed predetermined thresholds. The invention provides a speed monitor module wherein the speed monitor module may be may be plugged in to the same chassis as a module which is controlling the speed of the turbine, and wherein the turbine speed monitor is arranged to receive configuration parameters relating to the overspeed threshold and the overacceleration threshold only when the turbine is operating at a speed lower than a predetermined threshold.

Abstract: A system and method is provided for fault detection in a turbine engine. The fault detection system and method uses discrete event system modeling to provide improved fault diagnosis and prognosis. The fault detection system and method receives sensor taken at multiple dynamic events occurring in different time windows. An event determination mechanism evaluates the received sensor data to determine if specified events have occurred. Indications of the occurrence of specified events are then passed to a discrete event system model. The discrete event system model analyzes the timing and sequencing of the event occurrences to determine if a fault has occurred. This method does not require a detailed modeling of the system, and thus can be applied to complex systems such as turbine engines.

Abstract: A method for a functional test of a wind turbine generator plant which comprises the following procedural steps: a control unit for the wind turbine generator plant reads in actual values from at least one structural part of the wind turbine generator plant and generates control signals for actuators of the wind turbine generator plant, a simulation unit has at least one input and at least one output as well as one or more mathematical models which depict the behaviour of one or more structural parts of the wind turbine generator plant, the control signals are applied to the input of the simulation unit and the modeled actual values of the models on the structural parts are applied to the output of the simulation unit, wherein the actual values of the simulation unit are applied to the input of the control unit and the control signals of the control unit are applied to the input of the simulation unit; the simulation unit models the actual values of the structural parts resulting for the control signals appli

Abstract: Disclosed herein are methods and systems for controlling fan speed by approximating a nonlinear temperature control function activated within a given temperature control range. The temperature control range is divided into numerous linear segments each of which is associated with a sub-range of temperatures and may approximate a segment of the control function. Control coefficients may be determined for each of the linear segments. The controlled temperature is measured and used for determining a corresponding sub-range, and a linear segment. A control signal may be calculated according to the control coefficients of the segment determined by the measured temperature. The control signal is used for the activation of one or more fans, and is continuously determined for new measured temperatures.

Abstract: Example embodiments of the present invention relate to a method for collecting data from a wind turbine plant, where data are collected regularly. The collected data made can be stored, where corrections are performed on the stored data. The method also maintains or stores the originally collected data, so that reports may be generated to represent selected data in a plurality of different types of reports. Accordingly, a wind turbine plant may be controlled in relation to originally collected data and in relation to possible correction made to the data.

Abstract: In a turbine apparatus comprising a runner rotatable to be rotationally driven by a water, a gain of a derivative calculation element generating a derivative component of a control signal for controlling a flow rate of the water which derivative component is to be applied to the derivative calculation element and the integration calculation element by performing differentiation on a difference between an actual rotational speed and a desired rotational speed of the runner with respect to a time proceeding has a value sufficiently increased to converge a value of the control signal toward a desired value in accordance with the time proceeding in S-characteristic portion.