Abstract: A gasification unit provided with a gasification furnace 23 to produce fuel gas production is provided. A combined power generation unit 25 which generates power by rotating a gas turbine and a steam turbine using fuel gas produced in the gasification unit is provided. The combined power generation unit 25 is made operable while fuel change over between fuel gas and an auxiliary fuel as the fuel. A control system is provided in which the degree of opening of a control valve 37 for a flare stack 28 provided in a fuel gas feed line is controlled depending upon the pressure of the fuel gas from the gasification unit when fuel change over from the fuel gas to the auxiliary fuel so as to allow the fuel gas supplied to the combined power generation unit 25 to gradually flare from a flare stack 28 until a flared status that total amount of the fuel gas is reached.

Abstract: A gas turbine including a compressor, the gas turbine including a sensor for measuring a clearance of blades in the compressor; and a controller for receiving clearance information and using the information to control the gas turbine for prevention of at least one of a surge and rubbing of the blades.

Abstract: A fuel system for a turbine, including a plurality of fuel control valves connected to the turbine and in parallel with each other, and a controller for opening each of the control valves to pass a lower controllable fuel flow through each valve, and for further opening one of the control valves in response to a control signal for controlling the turbine.

Abstract: A method for transient fuel control for fuel delivery circuits for a plurality of connected gas turbines, the method includes: detecting a transient grid event based on an indication of at least one of a rapid change in a fuel command to the gas turbine or an acceleration of the turbine shaft; upon detection of the transient grid event, commanding a gas turbine controller to transfer the gas turbine to at least one intermediate load; adjusting a fuel split to maintain combustor stability during the transient grid event, and using a predetermined island load demand signal to apportion an island load demand among the connected gas turbine generators.

Abstract: A method, system and software for reducing combustion chamber to chamber variation in a multiple-combustion chamber turbine system comprising sensing dynamic combustion pressure tones emitted from combustion chambers in a multiple combustion chamber turbine and determining a combustion chamber stratification index for the combustion chambers from the dynamic combustion pressure tones emitted for the combustion chambers to record and/or tune combustion chamber performance variations in the multiple-chamber combustion turbine system.

Abstract: A method of operating a gas turbine engine having a rotatable turbine shaft with an electric machine mounted to the shaft. The method includes providing supplemental acceleration and/or deceleration of the turbine shaft of the gas turbine engine through the use of the electric machine operated as an electric motor and/or an electric generator, in order to avoid an undesirable engine speed range during engine operation.

Abstract: A method and system augments shaft output of gas turbine engines that can be used in multiple modes of operation. The system comprises a washing unit capable of injecting atomized water into the gas turbine engine, thereby obtaining a release of fouling material from the at least one compressor blade; and at least one water injection unit capable of injecting atomized water into the air stream of the gas turbine engine's inlet duct or at the gas turbine, under the control of a computational fluid dynamic model, in order to increase a mass flow of said air flow, wherein the power output from said gas turbine engine can be augmented.

Abstract: A method of operating a thermal power plant, such as a gas turbine power plant, in which a rotary unit, such as at least one gas turbine stage, is driven by burning gaseous fuel inside a combustion chamber, with hot gases being formed, the rotary energy of which rotary unit is converted into another form of energy, such as electrical energy. A load set point (L) of the thermal power plant is set by regulating the quantity of gaseous fuel fed to the combustion process. The thermal power plant is operated at a load set point (L), provided the gaseous fuel is fed to the combustion process through a gas line at a gas pressure pgas, with pgas>paction limit(L), where paction limit (L) represents a pressure value which depends on a system internal pressure psystem requirement (L) set in the region of the combustion chamber by the load set point (L) of the thermal power plant, with paction limit(L)>psystem requirement(L).

Abstract: A turbine overspeed control system for use with a gas turbine engine of a gas turbine electrical powerplant. The overspeed control system preferably comprises a first and second overspeed control subsystem. When an overspeed condition of the gas turbine engine is detected, the first overspeed control subsystem acts to remove air from a combustion section of the engine, while the second overspeed control subsystem operates to alter the angle at which an incoming flow of air is supplied to a compressor turbine located therein. The result of operating the first and/or second overspeed control subsystem is a reduction in the speed of the gas turbine engine that is much more rapid than can be accomplished by simply shutting off a fuel supply thereto.

Abstract: A combustion turbine power generation system (10) includes a combustion turbine assembly (11) including a main compressor (12) constructed and arranged to receive ambient inlet air, a main expansion turbine (14) operatively associated with the main compressor, combustors (16) constructed and arranged to receive compressed air from the main compressor and to feed the main expansion turbine, and an electric generator (15) associated with the main expansion turbine for generating electric power. A compressed air storage (18) stores compressed air. A heat exchanger (24) is constructed and arranged to receive a source of heat and to receive compressed air from the storage so as to heat compressed air received from the storage. An air expander (28) is associated with the heat exchanger and is constructed and arranged to expand the heated compressed air for producing additional electric power.

Abstract: Embodiments of the invention can provide systems and methods for initializing dynamic model states using a Kalman or similar type filter. In one embodiment, an adaptable model-based control system for controlling a gas turbine engine is provided. The system can include at least one sensor adapted to obtain dynamic-type information about a current state of the engine. Furthermore, the system can include an engine model adapted to receive information from the sensor, and further adapted to reflect the current state of the engine. In addition, the system can include a model filter adapted to initialize the model with at least a portion of the dynamic-type information, wherein at least one value based at least in part on the dynamic-type information is input to the engine model. Moreover, the model can be further adapted to determine an output from the engine model based at least in part on the at least one value.

Abstract: Method and arrangement for providing and controlling a gas turbine (1) at least one turbine (11, 20, 20?), at least one compressor (2, 5) driven by the turbine and a combustion chamber (16) arranged between the compressor and the turbine in the airflow path. The gas turbine includes devices (8) for direct measurement of the air mass flow at a position upstream of the combustion chamber in the airflow path, with the aim of regulating the quantity of fuel that is delivered to the combustion chamber (16) on the basis of the measured air mass flow.

Abstract: A modular method of modeling a power plant includes selecting a major component module model from a library of component module models for each major component of the power plant, with each major component module representing a power plant major component of a unique configuration. The method also includes inputting initial model information into a database for the selected modules, with the initial model information including at least convergence criteria and a maximum number of passes. The method further includes running the modular model by running each selected module and enabling data exchange between the selected modules.

Abstract: An adjustment method and system for an auxiliary power unit (APU) allows the APU speed to vary based on the inlet air temperature to the APU compressor. The APU is controlled by a control law that allows the APU speed to float within a selected range based on speed and electric power generators phase matching criteria that provides smooth power transfer between the APU and a main engine generator. The specific APU mechanical speed for a given temperature may be determined from a compressor map that identifies the optimum combination of pressure ratio, flow rate and efficiency for a given inlet temperature, and avoids running the APU near mechanical resonant vibration conditions.

Abstract: A method for transient fuel control for fuel delivery circuits for a plurality of connected gas turbines, the method includes: detecting a transient grid event based on an indication of at least one of a rapid change in a fuel command to the gas turbine or an acceleration of the turbine shaft; upon detection of the transient grid event, commanding a gas turbine controller to transfer the gas turbine to at least one intermediate load; adjusting a fuel split to maintain combustor stability during the transient grid event, and using a predetermined island load demand signal to apportion an island load demand among the connected gas turbine generators.

Abstract: Conventional auxiliary power units (APUs) may experience over-temperature shutdowns when attempting to start them at high altitudes. Further, such conventional APUs may also experience overspeed conditions when a generator load is removed during on-speed operations. A fuel control logic that controls the fuel flow cutback below the minimum blowout fuel schedule is provided. A temperature trim loop measures engine temperature to determine the onset of a possible over-temperature condition. The fuel flow may then be trimmed accordingly to correct this over-temperature onset. Further, when the onset of an overspeed condition is detected, such as when a generator load is removed, the fuel flow may be trimmed accordingly to correct this overspeed onset. The fuel control logic allows the control to find the individual minimum fuel flow for each fuel control without risking blowout of the APU itself.

Abstract: A method for predicting lean blow-outs (LBOs) in a gas turbine engine includes extracting a plurality of tones in pressure signals representative of pressure within monitored combustor cans, tracking a frequency of a hot tone in each monitored can, and utilizing the extracted tones and the tracked frequency to determine a probability of an LBO.

Abstract: Methods and systems for controlling a dynamic response in a gas turbine fuel control system are provided. The control system includes a component model adapted to regulate a fuel supply pressure for a gas turbine, a pressure sensor adapted to sense a pressure of fuel supplied to the gas turbine, and a feedback module including integral plus state feedback, the feedback module adapted to provide a positive feedback reference signal to the component model such that a response time of the gas turbine fuel control system to changes in fuel pressure is facilitated being reduced.

Abstract: A method and system are provided for calculating a marginal cost curve for a plant at a plant load range comprising a plurality of specified plant loads. The method includes providing a model used for controlling the plant. The model relates plant load and one or more given cost contributing factors. The marginal value for each of the one or more given cost contributing factors at each of the plurality of specified plant loads is determined using the model. A variable cost at each of the plurality of specified plant loads is determined by: (i) multiplying the marginal value of each of the one or more given cost contributing factors at each of the plurality of specified plant loads by a respective unit cost of each of the one or more given cost contributing factors, and (ii) if there are a plurality of given cost contributing factors, summing the results of (i) at each of the plurality of specified plant loads.

Abstract: A power generating system (20) includes a generator (22) and a combustion turbine (24) for driving the generator (22). The combustion turbine (24) may have a combustion turbine air inlet (30) for receiving an inlet airflow (25). The power generating system (20) may include an evaporative water cooler (26) or fogging evaporative system (26?) for cooling inlet airflow (25), and an inlet airflow temperature sensor (28) proximate or within the combustion turbine air inlet (30). The inlet airflow temperature sensor (28) may sense a drybulb temperature of the inlet airflow (25) proximate the air inlet (30). A controller (47?) is provided for controlling the cooling of inlet airflow (25) across transient load conditions of the power generating system (20?). This control may be based upon the sensed drybulb temperature used to calculate an approach temperature with respect to the inlet airflow (25?) that is compared to an approach temperature setpoint based on load.

Abstract: An apparatus and method are provided for controlling the ground windmilling of at least one of the spools in a gas turbine engine. Electrical power is supplied to a braking apparatus in one aspect. In another aspect, an oil system is powered during ground windmilling.

Abstract: The present application relates to fuel flow limit calculator (12) for use with a fuel control system (30) of an engine (10) comprising a fuel delivery means (28) and a compressor (16). The fuel control system (12) seeks to control the fuel/air ratio (FAR) near the weak extinction limit of the engine (10) as calculated by the fuel flow limit calculator (12). Both the static (PS3) and total (P3) pressure are measured at the exit of compressor (16). This enables a flow reference value (Q3) to be determined so that the air mass flow (W3) can be calculated and the limiting fuel/air ratio calculated. An advantage of the present invention is that it does not require stable combustion for satisfactory operation and allows the occurrence of preferential extinction within an annular combustor (22) to be beneficially utilised.

Abstract: A method of monitoring and controlling the combustion dynamics of a gas turbine engine system is provided. The system includes at least one gas turbine that includes at least one combustor can. The method includes receiving a signal from a gas turbine engine sensor that is indicative of combustion dynamics in at least one of the combustor cans, processing the received signal to determine a probability of lean blowout for at least one combustor can, and controlling the gas turbine engine system to facilitate reducing a probability of a lean blowout (LBO) event using the determined probability of lean blowout.

Abstract: A method and apparatus for operating a combined-cycle power system is provided. The system is coupled to an electric power grid. The system includes at least one electric power generator, at least one steam turbine coupled to the generator, at least one combustion turbine coupled to the generator, and at least one steam source that is in flow communication with the steam turbine. The method includes operating the system at a first power output level with the steam turbine and the combustion turbine being synchronized to an operating frequency of the grid, so that the steam turbine, the combustion turbine, and the grid are operating at a frequency substantially similar to a standardized grid frequency value. The method also includes sensing a grid frequency deviation away from the standardized grid frequency value.

Abstract: A method of controlling a gas turbine system (10) may include controlling an inlet guide vane position (98) to maintain a turbine (24) exhaust temperature at a corrected value that is a function of a compressor (12) inlet temperature and a turbine (24) normalized load. The method may include selecting the minimum value (138) of a part load tunable value, a part load maximum value and a fixed maximum value of a turbine (24) exhaust temperature for the corrected value. A corrected value setpoint may be determined (94) for the gas turbine system (10) operating at a part load condition where at least one of a fuel flow rate and the inlet guide vane position is controlled (98) so the corrected value does not exceed the corrected value setpoint. The corrected value may prevent a turbine (24) engine from exceeding its firing temperature during operation and ensure the engine operates within combustor dynamics and emissions limits.

Abstract: A method for controlling a combustor of an engine, the combustor having a fuel to oxidant ratio, the fuel to oxidant ratio being defined as a ratio of an amount of fuel supplied to the combustor divided by an amount of oxygen in an oxidant stream supplied to the combustor includes controlling the fuel to oxidant ratio of the combustor as a function of the amount of oxygen in the oxidant stream.

Abstract: The gas turbines of the present invention have multiple combustion chambers, and within each chamber are multiple fuel nozzles. Each nozzle has its own fuel control valve to control the fuel flowing to the nozzles. To minimize the pressure drop through the fuel control valves, multiple manifolds are employed. Each manifold supplies at least one fuel nozzle in multiple combustion chambers with fuel. The fuel control valves are mounted on the manifolds such that the weight of the fuel control valves and nozzles are carried by the manifolds, not the multiple combustion chambers. A plurality of thermocouples for measuring exhaust gas from said multiple combustion chambers are employed to sense gas exhaust temperature. In carrying out the methods of the present invention for tuning a gas turbine, it is essential to note that the most efficient gas turbine is one which has the least nitrous oxides, the least amount of unburned hydrocarbons, and the least amount of carbon monoxide for a specified energy output.

Abstract: In the gas-turbine engine control system having first and second control channels each inputting the outputs of speed sensors and controlling supply of fuel to the engine based on the inputted outputs, four outputs generated by the sensors are compared with each other to determine whether three of the four outputs are within a range that allows the three to be considered identical, and the three are then compared with a remaining one to determine whether the four outputs are within the range that allows the three to be considered identical to the remaining one, and based thereon, each of the four outputs is determined to be the output that is usable in the fuel supply control. With this, through the three-value comparison and the four-value comparison, when the high-pressure turbine speed sensor or the like is installed by plural numbers, it becomes possible to accurately select the sensor output(s) that is usable in the fuel supply control, thereby improving the control accuracy.

Abstract: In the gas-turbine engine control system having a first control inputting the outputs of sensors and controlling supply of fuel to the engine based on at least one of the inputted outputs, the first control channel includes a comparator inputting the outputs generated by the sensors and comparing change rates of the outputs with corresponding threshold values once every predetermined time period, and a transient/steady-state discriminator discriminating that the engine is in a transient state when the number of the outputs found to be equal to or greater than the corresponding threshold values are equal to or greater than a predetermined value, while discriminating that the engine is in a steady state when the number of times that the outputs are found to be smaller than the threshold values is more than half of number of comparison time.

Abstract: In a gas turbine control apparatus, a frequency analyzing section frequency-analyzes at least one of pressure oscillation in combustors of a gas turbine and acceleration oscillation of each of the combustors and outputs a first frequency analysis result as the result of frequency analysis for a plurality of predetermined frequency bands. A control unit controls at least one of a first fuel flow rate of fuel and a first air flow rate of air based on the first frequency analysis result for the plurality of frequency bands. The fuel and the air are supplied to the gas turbine.

Abstract: Relevant fuel-gas properties (XG) are measured on an ongoing basis while a gas turbine group is operating. The C2+alkane content of the fuel gas is of particular interest in this context, since it has a significant influence on the ignitability of the fuel gas in the combustion chamber. The operating parameters of the gas turbine group are acted on directly as a function of the measured fuel-gas properties. In particular, in the case of the example of a gas turbine group with sequential combustion, the distribution of the fuel mass flows ({dot over (m)}EV, {dot over (m)}SEV) between the combustion chambers (4, 8) of the gas turbine group is varied. Furthermore, if there is provision for inert media, such as water or steam, to be introduced, it is possible for the mass flow of inert media ({dot over (m)}ST) to be controlled as a function of the measured fuel properties.

Abstract: A fuel system includes a turbine engine, and an electric motor that are independently drivable relative to one another. The electric motor has a speed that is selectively controlled based upon a desired fuel flow. A centrifugal pump is driven by the turbine engine. The centrifugal pump provides a desired fuel pressure for the fuel system. A positive displacement pump is driven by the electric motor The positive displacement pump is in fluid communication with the centrifugal pump, for example in a series arrangement. The positive displacement pump meters a desired volume in response to the speed of the second drive assembly.

Abstract: A pump control system (20) for a pump (21) in a gas turbine engine (10) is described. The pump control system (20) comprises demand means (22) for providing a demand signal (23) relating to a required rate of fluid flow and/or pressure from the pump (21). The system also comprises sensing means (26) to sense at least one parameter of fluid downstream of the pump (21) and to provide at least one feedback signal (28) relating to the, or each, respective parameter. Comparator means (30) is provided for comparing the demand signal (23) with the, or at least one, feedback signal to provide a control signal (33) for controlling the pump.

Abstract: The present invention provides a multiple manifold fuel metering system with a separate motor, pump, and shut-off/purge valve for each manifold. The present invention may be used for metering fuel to any engine, especially a gas turbine engine. The fuel metering system of the present invention has the capability of independently controlling fuel flow during transitions in engine operation or allowing fuel to flow simultaneously through all manifolds to prevent blowout, optimizing combustion temperature distributions, or minimizing combustion emissions. Brushless DC variable speed electric motors may be used to drive pumps with highly accurate speed control to accurately control fuel flow rate to each of a plurality of manifolds of a fuel metering system. With brushless DC motors, motor speed may be controlled within a revolution for smoothing fuel delivery to an engine.

Abstract: One embodiment of the invention provides a turbine control system that adjusts the control thresholds of two-position valves, which provide propellant to the turbine, based on turbine load so as to compensate for increased turbine speed overshoot at low load and the increased turbine speed undershoot at high load. These two-position on-off modulated valves are used in a bang-bang (fully open or fully closed) regulation scheme to eliminate or minimize speed droop by using variable speed bounds implemented as a function of load.

Abstract: Methods of increasing lifetimes of components in a gas turbine engine. Ordinarily, components are replaced after they experience a certain number of thermal cycles, or a certain operating temperature limit is exceeded. Under one form of the invention, the components are not replaced at that time, but are subjected to increased cooling, which decreases the highest temperature reached in subsequent thermal cycles. Also, many components are replaced when acceleration of an engine falls below a target. In one form of the invention, the components are not replaced, but (1) scheduled fuel flow is increased and (2) compressor stall margin also increased, in order to attain the target acceleration.

Abstract: Conventional auxiliary power units (APUs) may experience over-temperature shutdowns when attempting to start them at high altitudes. Further, such conventional APUs may also experience overspeed conditions when a generator load is removed during on-speed operations. A fuel control logic that controls the fuel flow cutback below the minimum blowout fuel schedule is provided. A temperature trim loop measures engine temperature to determine the onset of a possible over-temperature condition. The fuel flow may then be trimmed accordingly to correct this over-temperature onset. Further, when the onset of an overspeed condition is detected, such as when a generator load is removed, the fuel flow may be trimmed accordingly to correct this overspeed onset. The fuel control logic allows the control to find the individual minimum fuel flow for each fuel control without risking blowout of the APU itself.

Abstract: A gas turbine engine with a single stage combustor includes an external premixer to provide premixed fuel/compressed air to the combustor as well as compressed air for dilution; and an automatic controller to provide feedback control of the compressed air flow and fuel flow to the premixer in accordance with actual power versus power demand. The fuel/compressed air mixture is combusted in a combustor and the combustion gases and dilution air are expanded in a turbine. The engine further includes a bleed valve under control of the controller for diverting sufficient compressed dilution air past the turbine to induce increased fuel flow and compressed air flow to the premixer for delivery to, and combustion of, the combustor to compensate for the power deficit due to the bled air, to provide selected minimum premixer exit velocities during engine operation.

Abstract: In order to regulate fuel flow to the combustor (36) of the combustion turbine engine (10) having a primary combustion zone (64) and at least one further combustion zone, the temperature of the inlet and outlet of the combustor (36) are determined, as are first and second values representing first and second properties, with the first property being one of: the total enthalpy rise in the combustor (36), the equivalence ratio of the combustor (36), the fuel/air ratio of said combustor (36), the fuel flow through the combustor, and the second property being one of: the enthalpy rise in the primary zone (64), the equivalence ratio of said primary zone (64), the fuel/air ratio of the primary zone(64); the temperature rise across the primary zone(64), or the fuel flow through the primary zone (64). The second property is determined from the first value and the current value of the ratio of the fuel to the primary zone (64) to the total fuel to the combustor (36).

Abstract: A method of operating a gas turbine engine combustion system at lower load conditions while maintaining required emissions levels is disclosed. The present invention includes multiple embodiments of axial, radial, and circumferential fuel staging within a can-type combustor having alternate ignition techniques of spark ignition or torch ignition.

Abstract: A method for determining an estimated operating parameter for a gas turbine including the steps of: determining an estimated operating parameter using an algorithm have an input from a sensor, wherein the algorithm includes a trim factor; determining a first trim factor based on a comparison of the first estimated operating parameter and the output of the sensor when a condition of the sensor is in a first mode, and during a subsequent determination of the estimated operating parameter, applying the first trim factor to subsequently determine the estimated operating condition if the condition of second sensor is in a second mode.

Abstract: Aspects of the invention relate to a method for facilitating the reduction of carbon monoxide emissions during part load operation of a turbine engine by holding high combustor temperatures. The combustor section of the turbine engine includes a plurality of combustors, each combustor having a pilot nozzle, a plurality of main nozzles circumferentially surrounding the pilot nozzle, and a premix ring. According to one aspects of the invention, a first pair of combustors are selected. Fuel can be substantially restricted from being supplied to the main nozzles and the premix ring of the selected combustors, while fuel continues to be supplied to the pilot nozzles of the selected combustors. Additional combustors can be selected and the supply of fuel can be selectively restricted as described above. The process can continue until there is substantially zero net power out of the engine.

Abstract: Apparatus and methods are provided through which a radio-frequency dielectric heater has a cylindrical form factor, a variable thermal energy deposition through variations in geometry and composition of a dielectric, and/or has a thermally isolated power input.

Abstract: A gas turbine apparatus has a combustor 2 for combusting fuel to produce a combustion gas, a turbine 1 which is rotated by the combustion gas, an electric generator 5 coupled to the turbine 1, and a fuel flow control valve 10 configured to change an opening thereof The gas turbine apparatus includes a first PID processing unit 16 to adjust the opening of the fuel flow control valve 10 so as to maintain a rotational speed of the turbine 1 substantially at a constant value, and a second PID processing unit 17 to adjust the opening of the fuel flow control valve 10 so as to maintain a temperature of a discharged combustion gas at temperatures lower than a predetermined temperature. The gas turbine apparatus has an electric power controller 21 to control electric power to be generated by the electric generator 5 based on output values of the first PID processing unit 16 and the second PID processing unit 17.

Abstract: According to the invention, during level automatic flight of the aircraft (A) at steady altitude, the preset value EPRt, common to all the turbojets (M1 to M4) and corresponding to a particular value of the ratio EPR of the gas pressures at the outlet and at the inlet of the turbojets, is converted into a preset value N1t related to the speed of rotation N1 of the fan of said turbojets and the fuel supply to all said turbojets is slaved to said preset value N1t.

Abstract: In a control method of a gas turbine engine, an engine controller 4 outputs a combustor power command FD based on an engine condition from an engine condition detector 3. Then, a combustion controller 6 determines each fuel flow rate based on the combustion power command FD. The combustor controller 6 overrides each fuel flow rate for a certain period, to realize smooth stage-process.

Abstract: Values such as a pressure for supplying fuel gas to a gas turbine, a pressure in a combustor casing of the gas turbine, an output of a generator connected to the gas turbine, and a controlled output for a flow rate control valve are detected by sensors. The detected values are input into a control device. A differential pressure across the flow rate control valve and a target value of the differential pressure are also input into the control device. The control device performs a desired arithmetic operation based on these input values to output a lift instruction for a pressure control valve.

Abstract: A turbine plant includes a steam turbine, a gas turbine connected to the steam turbine, a generator, and an analyzing apparatus. The steam turbine includes a high pressure steam turbine, an intermediate pressure steam turbine, and a low pressure steam turbine. The turbine plant is adapted to be driven by a selected one of natural gas and oil. The analyzing apparatus collects estimates of the steam turbine output based on the inlet steam pressure of the intermediate steam turbine with a correction value. The correction value is calculated including the influence of the difference between the gas fuel case and the oil fuel case. The analyzing apparatus estimates a gas turbine output by calculating the difference between the estimated steam turbine output and the total output of the turbine plant. The gas turbine is operated using the estimated gas turbine output.

Abstract: A gas turbine system composed of a gas turbine engine and a controller. The gas turbine engine includes an annular combustor, and a turbine driven by combustion gas from the annular combustor to rotate on a longitudinal centerline axis of the gas turbine engine. The annular combustor is comprised of an outer casing, a liner disposed in the outer casing, and a plurality of dilution air regulators introducing dilution air into the liner. The plurality of dilution air regulators are circumscribed about the longitudinal centerline axis and spaced apart at substantially equal intervals. The controller controls the plurality of dilution air regulators to individually adjust dilution air flows through the plurality of dilution air regulators into the liner.

Abstract: In a fuel control method for a combined plant, when the combined plant is just started or during a rated operation, a clutch is completely disengaged or engaged, and therefore, fuel is controlled in the same manner as in the prior art. In the meantime, before and after the clutch is engaged or disengaged, a target load set value is switched to an actual load in response to a signal from a clutch engagement or disengagement period detection unit as a trigger. In this manner, a sudden change in load that may occur when the clutch is engaged or disengaged never influences on a control system disposed downstream thereof.