Mitsubishi Heavy Industries Limited

Mitsubishi Hitachi Power Systems, Ltd.

Pebble Bed Modular Reactor (pty) Limited

Pebble Bed Modular Reactor Limited

Fuminori Fujii

Takashi Sonoda

Makoto Kato

Keisuke Yamamoto

Shinichi Yoshioka

Akihiko Saito

Ryuji Takenaka

Yoshifumi Masuda

Hitoi Ono

Satoshi Uchida

Yoshifumi Iwasaki

Katsuhiko Abe

Naoto Tochitani

Yoshinori Hyakutake

Wataru Akizuki

Hisashi Nakahara

Ryoichi Haga

Isamu Matsumi

Masahide Umaya

Naohiro Sumimura

Satoshi Tanimura

Masayuki Murakami

Hiroshi Tanabe

Sosuke Nakamura

Makoto Kishi

Kozo Toyama

Shinsuke Nakamura

Yasuo Fujishima

Masaru Takamatsu

Hikaru Katano

Keita Fujii

Yasutsugu Takata

Nobukazu Ishii

Koichiro Hirato

Takafumi Uda

Masahiro Matsubara

Shin Akazawa

A fuel control device includes a combustion temperature estimation value calculation unit that calculates a temperature estimation value when a mixture of fuel and inflow air is burned using an atmospheric condition, an opening degree command value of a valve that controls the amount of air that is mixed with the fuel and burned, and an output prediction value calculated on the basis of a fuel control signal command value used for calculation of a total fuel flow rate flowing through a plurality of fuel supply systems, a fuel distribution command value calculation unit that calculates a fuel distribution command value indicating a distribution of fuel output from the fuel supply systems based on the temperature estimation value, and outputs the fuel distribution command value, and a valve opening degree calculation unit that calculates each valve opening degree of a fuel flow rate control valve of the fuel supply systems.

Fuel control device, combustor, gas turbine, control method, and non-transitory computer-readable medium

Fuel control device, combustor, gas turbine, control method, and program

An IGV opening command value is corrected to calculate an actual opening equivalent value that indicates an approximate value of an actual opening. A temperature estimation value, for a case where a mixture of fuel and in-flowing air is combusted, is calculated using the actual opening equivalent value, atmospheric conditions, and an output from a gas turbine. A fuel distribution command value that indicates distribution of fuel output from a plurality of fuel supply systems is calculated on the basis of the temperature estimation value. The fuel distribution command value and a fuel control signal command value that indicates the total flow rate of fuel to be output to the plurality of fuel supply systems are acquired, and respective valve openings of fuel flow rate regulating valves of the fuel supply systems are calculated on the basis of the fuel distribution command value and the fuel control signal command value.

Fuel control device and control method for a combustor of a gas turbine

A combustor replacement method and a gas turbine plant capable of efficiently replacing a combustor using an existing facility. The combustor replacement method includes a step of separating, from a plurality of fuel supply systems, a first combustor that includes a plurality of nozzle systems connected to any of the plurality of fuel supply systems and supplied with fuel from the connected fuel supply systems, and removing the first combustor from a gas turbine plant. The method includes a step of attaching a second combustor that includes fewer nozzle systems than the first combustor to the gas turbine plant, and a step of providing communication between the fuel supply systems connected to the same nozzle system of the second combustor by a coupling pipe, and coupling the fuel supply systems and the second combustor.

Combustor replacement method and gas turbine plant

A valve control device is provided in a gas turbine having a combustor for generating combustion gas, a turbine driven by the combustion gas generated by the combustor, a flow rate regulating valve for regulating the flow rate of the fuel to be supplied to the combustor, and a pressure regulating valve disposed upstream of the flow rate regulating valve, for regulating the fuel pressure. The valve control device controls the opening degree of the valve. The valve control device includes a load decrease detection part which detects a load decrease of the gas turbine, and a pressure control part which controls the opening degree of the valve in accordance with the output of the gas turbine. The valve control device suppresses instability of the gas turbine output even when the load rapidly decreases.

Valve control device, gas turbine, and valve control method

To provide a method of controlling a turbine equipment and a turbine equipment capable of carrying out a starting operation of controlling a load applied to a speed reducing portion while complying with a restriction imposed on an apparatus provided at a turbine equipment. The invention is characterized in including a speed accelerating step (S) of increasing a revolution number by driving to rotate a compressing portion and a turbine portion by a motor by way of a speed reducing portion, a load detecting step (S) of detecting a load applied to the speed reducing portion by a load detecting portion, and a bypass flow rate controlling step (S) of increasing a flow rate of a working fluid bypassed from a delivery side to a suction side of the compressing portion when an absolute value of the detected load is equal to or smaller than an absolute value of a predetermined value and reducing the flow rate of the bypassed working fluid when equal to or larger than the absolute value of the predetermined value.

Method of controlling turbine equipment and turbine equipment

To provide a method of controlling a turbine equipment and a turbine equipment capable of carrying out a starting operation of controlling a load applied to a speed reducing portion while complying with a restriction imposed on an apparatus provided at a turbine equipment. The invention is characterized in including a temperature elevating step (S) of elevating a temperature of a working fluid flowing to the turbine portion, a flow rate increasing step (S) of increasing a flow rate of a working fluid bypassed from a delivery side to a suction side of the compressing portion when a temperature of the working fluid flowing to the turbine portion is elevated by a heat source portion, and a flow rate reducing step (S) of reducing the flow rate of the bypassing working fluid after an elapse of a predetermined time period after increasing the flow rate of the bypassing working fluid.

Provided is a gas turbine control device that is used in a generating facility including a gas turbine and a generator for generating power when at least rotational power of the gas turbine is transmitted, the gas turbine control device including a first control section for obtaining a first fuel control command for causing generator output to follow a generator output set value decided based on a demand load, where the first control section has a feedback control section (), and the feedback control section () includes a subtraction section () for calculating a deviation of the generator output with respect to the generator output set value, a PI control section () provided in a later stage of control than the subtraction section (), and a peak suppression section () for suppressing a peak in amplitude characteristics of the generator or a utility grid including the generator.

Gas turbine control device and generating system

A turbine mechanical output computation device computes a gas turbine mechanical output P from the following equation where Pe represents a generator effective power measured by a generator effective power wattmeter, N represents the rotational speed of a gas turbine measured by a gas turbine tachometer, J represents the moment of inertia of the gas turbine, and g represents gravitational acceleration. A combustion air amount controller controls the amount of combustion air based on the gas turbine mechanical output P.

Turbine mechanical output computation device and gas turbine control device equipped therewith

A combustion temperature high speed detection device is provided with a phase lead processing portion, thereby canceling out a detection lag of a temperature detector, and detecting the combustion gas temperature of a combustor at a high speed. The combustion temperature high speed detection device is also provided with a first-order lag filtering portion with a time constant of 0.25 second, a phase lag processing portion with a time constant of 10 seconds, a temperature change filtering portion with a cutoff frequency of 2 to 3 Hz, and a disturbance filtering portion including first-order lag filtering portions with different time constants and a high value selecting portion. Thus, high speed detection of the combustion gas temperature more suitable for a gas turbine system can be performed.

Combustion temperature high speed detection device

A pressure and flow control apparatus includes first to third pipes, fluid being supplied to the first pipe and outputted from the third pipe, a pressure control valve, a control valve, and a control unit. The pressure control valve is provided between the first and second pipes and opened or closed based on a first opening degree to control flow of the fluid from the second pipe to the third pipe. The control valve is provided between the second and third pipes and opened or closed based on a second opening degree to control flow of the fluid from the first pipe to the second pipe. The control unit determines the first opening degree, and determines the second opening degree based on the first opening degree and a pressure in the second pipe.

Pressure and flow rate control apparatus and plant system using the same

A pressurized fluidized bed combined electricity generation system for improving gas turbine output increases and prevention of surging is provided. This pressurized fluidized bed combined electricity generation system is a combined electricity generation system including a steam turbine; a pressurized fluidized bed boiler for generating steam for supply to the steam turbine by combusting air from an air supply system and fuel from a fuel supply system; a gas turbine driven by exhaust gas such as combustion gas from the pressurized fluidized bed boiler and air; and a compressor directly coupled to the gas turbine. In addition, this pressurized fluidized bed combined electricity generation system has a first bypass duct communicating between the outlet side of the compressor and the exhaust gas side of the gas turbine and having a switching valve; a second bypass duct communicating between the outlet side of the compressor and the inlet side of the gas turbine and having a switching valve; and a control device which receives measured pressure values of a pressure detector which measures the pressure at the outlet of the compressor. This control device controls the switching valves of the first and second bypass ducts based on the relationship between the degree of opening of the inlet variable guide vane of the compressor which is determined in advance and a surge limiting pressure. A part of the steam generated by the pressurized fluidized bed boiler is extracted, mixed in with the exhaust gas or the above-mentioned air, and supplied to the gas turbine. Air from the compressor is supplied as fuel for the pressurized fluidized bed boiler.

Pressurized fluidized bed combined electricity generation system

A pressurized fluidized bed combined electricity generation system for improving gas turbine output increases and prevention of surging is provided. This pressurized fluidized bed combined electricity generation system is a combined electricity generation system including a steam turbine; a pressurized fluidized bed boiler for generating steam for supply to the steam turbine by combusting air from an air supply system and fuel from a fuel supply system; a gas turbine driven by exhaust gas such as combustion gas from the pressurized fluidized bed boiler and the air; and a compressor directly coupled to the gas turbine. In addition, this pressurized fluidized bed combined electricity generation system has a first bypass duct communicating between the outlet side of the compressor and the exhaust gas side of the gas turbine and having a switching valve; a second bypass duct communicating between the outlet side of the compressor and the inlet side of the gas turbine and having a switching valve; and a control device which receives measured pressure values of a pressure detector which measures the pressure at the outlet of the compressor. This control device controls the switching valves of the first and second bypass ducts based on the relationship between the degree of opening of the inlet variable guide vane of the compressor which is determined in advance and a surge limiting pressure. A part of the steam generated by the pressurized fluidized bed boiler is extracted, mixed in with the exhaust gas or the above-mentioned air, and supplied to the gas turbine. Air from the compressor is supplied as fuel for the pressurized fluidized bed boiler.

Pressurized fluidized-bed combined cycle power generation system

A cleaning method for a flame detector of a gas turbine activating combustor, comprising branching control air for forcing a spark plug of an ignition system into the gas turbine activating combustor, and blowing the branched control air against the respective inner surfaces of light sensor glasses of a flame detector, thereby blowing off dust or soot from the glass.

Method and an apparatus for cleaning a flame detector of a combustor

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Kanagawa, Japan

Fuminori Fujii