JP6413145B2 - Gas turbine equipment, control device therefor, and control method for gas turbine equipment - Google Patents

Description

  The present invention relates to a gas turbine facility using a mixed gas of a plurality of gases having different calorific values per unit amount as a fuel, a control device therefor, and a control method for the gas turbine facility.

  In the liquefied natural gas (hereinafter referred to as LNG (Liquefied Natural Gas)) tank, a part of the LNG is evaporated to become boil-off gas (hereinafter referred to as BOG (Boil Off Gas)). This BOG is discharged out of the LNG tank in order to increase the pressure in the LNG tank.

  In the technique described in Patent Document 1 below, natural gas (hereinafter referred to as NG (Natural Gas)) in which LNG from an LNG tank is forcibly vaporized by a vaporizer and the above-described BOG are mixed. Gas is used as fuel for the gas turbine. In this technology, a calorimeter detects the calorific value of a mixed gas that accompanies changes in the flow rate of the BOG, etc., and based on the detection result, a gas having a predetermined calorific value is supplied into the mixed gas. Sudden changes in heat input are suppressed.

JP 2002-188460 A

  It often takes time to detect the calorific value of a gas with a calorimeter. For this reason, in the technique described in Patent Document 1, when the change in the calorific value of the mixed gas can be detected by the calorimeter, the mixed gas after the calorific value change may already be supplied to the gas turbine. . Therefore, the technique described in Patent Document 1 has a problem that the gas turbine may not be stably operated.

  Then, an object of this invention is to provide the technique which can carry out stable operation of gas turbine equipment, even if the emitted-heat amount of mixed gas changes.

A control device for a gas turbine facility as one aspect according to the invention for solving the above-described problems,
In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine. A receiving unit that receives information indicating a situation upstream from a mixing location of the natural gas and the boil-off gas; and a control amount calculation unit that determines a control amount of the regulator according to the upstream situation indicated by the information; , that having a, and an output unit for outputting a command indicating the control amount of the control amount calculation unit is determined to the control. The regulator includes a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine. The reception unit receives a flow rate of the boil-off gas upstream from the mixing location as at least part of the information. The control amount calculation unit is configured according to the heat input amount of the gas turbine, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the flow rate of the boil-off gas. A fuel control amount calculation unit that determines the control amount is provided.

The calorific value of the mixed gas of the natural gas and the boil-off gas changes when the situation on the upstream side of the mixing location of the natural gas and the boil-off gas changes. That is, the amount of heat generated by the mixed gas changes after the upstream situation change occurs. In the control device, the control amount of the regulator is determined according to information indicating the upstream situation. Therefore, in the said control apparatus, even if the emitted-heat amount of mixed gas changes, the fluctuation | variation of the gas turbine heat input amount or the combustion gas inlet temperature of a turbine can be suppressed.
The boil-off gas is a facility for supplying natural gas, and its calorific value per unit amount is almost constant. For this reason, if the flow rate of the boil-off gas can be grasped, the calorific value of the unit gas mixture, which is the calorific value per unit quantity of the mixed gas, and the calorific value of the mixed gas supplied per unit time to the gas turbine. The amount of heat input to the gas turbine can be estimated. Therefore, the control device receives the flow rate of the boil-off gas, and determines the control amount of the fuel control valve based on the amount of heat input to the gas turbine determined according to the flow rate of the boil-off gas. Therefore, in the said control apparatus, even if the unit mixed gas calorific value changes with the fluctuation | variation of the flow volume of boil-off gas, the fluctuation | variation of a gas turbine heat input can be suppressed.

  Here, in the control device for the gas turbine equipment, the output unit responds to the information whose content has changed from the time when the reception unit has received the information whose content has changed due to a change in the situation on the upstream side. The command indicating the control amount may be output after a predetermined time.

  In the control device, the regulator can be operated in accordance with the timing at which the mixed gas after the calorific value changes flows into the gas turbine.

  Further, in the gas turbine equipment control apparatus having the fuel control amount calculation unit, the fuel control amount calculation unit is a fuel that is a control amount of the fuel control valve that is determined without being based on information indicating the upstream state. A fuel base control amount calculation unit for obtaining a base control amount, a gas turbine heat input amount calculation unit for obtaining the gas turbine heat input amount according to the flow rate of the boil-off gas, and the fuel base control amount according to the gas turbine heat input amount A fuel coefficient generation unit that outputs a correction coefficient for correcting the fuel base and a correction unit that corrects the fuel base control amount using the correction coefficient output from the fuel coefficient generation unit.

A control device for a gas turbine facility as another aspect according to the invention for solving the above-described problems,
In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine. A receiving unit that receives information indicating a situation upstream from a mixing location of the natural gas and the boil-off gas; and a control amount calculation unit that determines a control amount of the regulator according to the upstream situation indicated by the information; And an output unit that outputs a command indicating the control amount obtained by the control amount calculation unit to the controller. The adjuster includes an intake air adjuster that adjusts a flow rate of the air supplied to the gas turbine, and the control amount calculation unit is determined according to a flow rate of the boil-off gas. An intake control amount calculation unit that determines the control amount of the intake air regulator based on a heat input amount of the gas turbine that is a calorific value of the mixed gas supplied to the engine. In this case, the intake control amount calculation unit includes an intake base control amount calculation unit that calculates an intake base control amount that is a control amount of the intake regulator that is determined based on information indicating the upstream state, and the boil-off gas A gas turbine heat input calculation unit for obtaining the gas turbine heat input according to the flow rate of the gas turbine, a heat input change rate calculation unit for obtaining a heat input change rate that is a change amount per unit time of the gas turbine heat input, and the input An intake coefficient generation unit that outputs a correction coefficient for correcting the intake base control amount according to a heat change rate, and the intake base control amount is corrected using the correction coefficient output by the intake coefficient generation unit. And a correction unit.

  In the control device, the flow rate of the boil-off gas is received, and the control amount of the intake air regulator is determined based on the amount of heat input to the gas turbine determined according to the flow rate of the boil-off gas. Therefore, in the said control apparatus, even if the unit mixed gas calorific value changes with the fluctuation | variation of the flow volume of boil-off gas, the temperature change of the combustion gas inlet_port | entrance of a turbine can be suppressed.

  In any one of the above-described control devices for the gas turbine equipment, the accepting unit accepts equipment status upstream from the mixing location as at least part of the information, and the control amount computing unit The control amount of the regulator may be determined based on a heat input amount of the gas turbine that is a calorific value of the mixed gas supplied to the gas turbine per unit time, which is determined according to a situation.

  The calorific value of the mixed gas of the natural gas and the boil-off gas changes when the equipment status upstream from the mixing location of the natural gas and the boil-off gas changes. That is, the heat generation amount of the mixed gas changes after a change in the upstream equipment situation occurs. In the control device, the control amount of the regulator is determined according to the upstream equipment situation. Therefore, in the said control apparatus, even if the emitted-heat amount of mixed gas changes, the fluctuation | variation of the gas turbine heat input amount or the combustion gas inlet temperature of a turbine can be suppressed.

  In any one of the above-described control devices for the gas turbine equipment, wherein the reception unit receives the flow rate of the boil-off gas, the reception unit receives a facility situation upstream from the mixing location as at least part of the information. The control amount calculation unit is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment situation after the change for a predetermined time from the time when the equipment situation changes. The control amount of the regulator may be determined based on a certain amount of heat input to the gas turbine, and the control amount may be determined in accordance with the flow rate of the boil-off gas after the predetermined time has elapsed from the time when the equipment status has changed. .

In the control device for the gas turbine equipment according to any one of the above, wherein the accepting unit accepts the upstream equipment situation, the regulator includes a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine. The control amount calculation unit includes a fuel control amount calculation unit that determines the control amount of the fuel control valve, and the fuel control amount calculation unit is determined based on information indicating the upstream state. A fuel base control amount calculation unit for obtaining a fuel base control amount that is a control amount for the fuel adjustment, and a correction coefficient for correcting the fuel base control amount according to the facility status received by the reception unit are output. You may have a fuel coefficient generation | occurrence | production part and the correction | amendment part which correct | amends the said fuel base control amount using the said correction coefficient which the said fuel coefficient generation | occurrence | production part output.
Moreover, the control apparatus of the gas turbine equipment as further another aspect which concerns on the invention for solving the said problem,
In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine. A receiving unit that receives information indicating a situation upstream from a mixing location of the natural gas and the boil-off gas; and a control amount calculation unit that determines a control amount of the regulator according to the upstream situation indicated by the information; And an output unit that outputs a command indicating the control amount obtained by the control amount calculation unit to the controller. The said reception part receives the installation condition upstream from the said mixing location as at least one part of the said information. The control amount calculation unit determines the control amount of the regulator based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Determine. The regulator includes a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine. The control amount calculation unit includes a fuel control amount calculation unit that determines the control amount of the fuel control valve. The fuel control amount calculation unit includes a fuel base control amount calculation unit that obtains a fuel base control amount that is a control amount of the fuel adjustment that is determined based on information indicating the upstream state, and the reception unit receives the fuel control amount calculation unit A fuel coefficient generation unit that outputs a correction coefficient for correcting the fuel base control amount according to a facility situation, and a correction that corrects the fuel base control amount using the correction coefficient output by the fuel coefficient generation unit Part.

  In the control device for the gas turbine equipment according to any one of the above, wherein the accepting unit accepts the upstream equipment status, the regulator includes an intake air regulator that regulates a flow rate of the air supplied to the gas turbine. The control amount calculation unit includes an intake control amount calculation unit that determines the control amount of the intake air regulator, and the intake control amount calculation unit is determined based on information indicating the upstream state. An intake base control amount calculation unit that obtains an intake base control amount that is a control amount of the intake controller, and a correction coefficient for correcting the intake base control amount according to the facility status received by the reception unit And a correction unit that corrects the intake base control amount using the correction coefficient output from the intake coefficient generation unit.

In the control device for the gas turbine equipment according to any one of the above, wherein the accepting unit accepts the equipment status on the upstream side, in order to supply the boil-off gas to the gas turbine as equipment upstream from the mixing location. A plurality of gas compressors for boosting the boil-off gas are provided, and the reception unit receives the number of operating units of the plurality of gas compressors as the equipment status, and the control amount calculation unit includes the control unit The control amount of the regulator may be determined according to the number of operating gas compressors.

The gas turbine equipment as one aspect according to the invention for solving the above problems is as follows:
The control device according to any one of the above, the gas turbine, and the regulator.

The control method of the gas turbine equipment as one aspect according to the invention for solving the above-mentioned problems,
In a control method for gas turbine equipment, comprising: a gas turbine using a mixed gas of natural gas and boil-off gas as fuel; and a regulator for adjusting a flow rate of the fuel or air supplied to the gas turbine. A receiving step for receiving information indicating a situation upstream from a mixing location of natural gas and the boil-off gas; and a control amount calculating step for determining a control amount of the regulator according to the upstream situation indicated by the information; And an output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller. In this case, the regulator has a fuel regulating valve that regulates the flow rate of the fuel supplied to the gas turbine. In the reception step, the flow rate of the boil-off gas at the upstream side of the mixing location is received as at least a part of the information. The control amount calculation step is based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to a flow rate of the boil-off gas. A fuel control amount calculation step for determining a control amount is included.

  The calorific value of the mixed gas of the natural gas and the boil-off gas changes when the situation on the upstream side of the mixing location of the natural gas and the boil-off gas changes. That is, the amount of heat generated by the mixed gas changes after the upstream situation change occurs. In this control method, the control amount of the regulator is determined according to information indicating the upstream situation. Therefore, in this control method, even if the calorific value of the mixed gas changes, fluctuations in the gas turbine heat input amount or the combustion gas inlet temperature of the turbine can be suppressed.

  Here, in the gas turbine equipment control method, in the output step, the upstream situation has changed, and the content has changed since the information having been changed is received in the receiving step. The command indicating the control amount may be output after a predetermined time.

The control method of the gas turbine equipment as another aspect according to the invention for solving the above problem is
In a control method for gas turbine equipment, comprising: a gas turbine using a mixed gas of natural gas and boil-off gas as fuel; and a regulator for adjusting a flow rate of the fuel or air supplied to the gas turbine. A receiving step for receiving information indicating a situation upstream from a mixing location of natural gas and the boil-off gas; and a control amount calculating step for determining a control amount of the regulator according to the upstream situation indicated by the information; And an output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller. In this case, the regulator has an intake air regulator that regulates the flow rate of the air supplied to the gas turbine, and the control amount calculation step is determined according to the flow rate of the boil-off gas. An intake control amount calculation step for determining the control amount of the intake air regulator based on a heat input amount of the gas turbine that is a calorific value of the mixed gas supplied to the turbine per unit time may be included. In this case, the intake control amount calculation step corresponds to a step of obtaining an intake base control amount that is a control amount of the intake regulator determined based on information indicating the upstream state, and a flow rate of the boil-off gas. The step of obtaining the heat input amount of the gas turbine, the step of obtaining a heat input change rate that is a change amount per unit time of the gas turbine heat input amount, and correcting the intake base control amount according to the heat input change rate. And a step of correcting the intake base control amount using the correction coefficient output by the intake coefficient generation unit.

  Further, in any of the above gas turbine equipment control methods, in the accepting step, as at least a part of the information, an equipment status upstream from the mixing location is accepted, and in the control amount calculating step, The control amount of the regulator may be determined based on the amount of heat input to the gas turbine, which is a calorific value of the mixed gas supplied to the gas turbine per unit time, which is determined according to equipment conditions.

In the control method of the gas turbine equipment that accepts the equipment status on the upstream side in the acceptance step, the regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine, The control amount calculation step includes a fuel control amount calculation step for determining the control amount of the fuel adjustment valve, and the fuel control amount calculation step is determined based on information indicating the upstream state. A fuel base control amount calculating step for obtaining a fuel base control amount that is a control amount of the fuel, and generating a fuel coefficient for outputting a correction coefficient for correcting the fuel base control amount in accordance with the equipment status received in the receiving step And a correction step of correcting the fuel base control amount using the correction coefficient output in the fuel coefficient generation step.
Moreover, the control method of the gas turbine equipment as another aspect which concerns on the invention for solving the said problem,
In a control method for gas turbine equipment, comprising: a gas turbine using a mixed gas of natural gas and boil-off gas as fuel; and a regulator for adjusting a flow rate of the fuel or air supplied to the gas turbine. A receiving step for receiving information indicating a situation upstream from a mixing location of natural gas and the boil-off gas; and a control amount calculating step for determining a control amount of the regulator according to the upstream situation indicated by the information; And an output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller. In the receiving step, the equipment status on the upstream side from the mixing location is received as at least part of the information. In the control amount calculation step, the control amount of the regulator is determined based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Determine. The regulator includes a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine. The control amount calculation step includes a fuel control amount calculation step for determining the control amount of the fuel control valve. The fuel control amount calculation step is received in the fuel base control amount calculation step for obtaining a fuel base control amount that is a control amount of the fuel control valve determined based on the information indicating the upstream state, and the reception step. A fuel coefficient generation step for outputting a correction coefficient for correcting the fuel base control amount according to the facility status, and the fuel base control amount is corrected using the correction coefficient output in the fuel coefficient generation step. And a correcting step.

  In the control method for the gas turbine equipment according to any one of the above, wherein the regulator receives the equipment status on the upstream side in the acceptance step, the regulator adjusts the flow rate of the air supplied to the gas turbine. The control amount calculation step includes an intake control amount calculation step for determining the control amount of the intake air regulator, and the intake control amount calculation step is not based on information indicating the upstream state. An intake base control amount calculation step for obtaining an intake base control amount that is a control amount of the intake air regulator determined by the correction unit, and a correction coefficient for correcting the intake base control amount in accordance with the equipment status received by the reception unit May be included, and a correction step of correcting the intake base control amount using the correction coefficient output in the intake coefficient generation step.

In the control method of any of the above gas turbine equipment, wherein the equipment status on the upstream side is received in the reception step, in order to supply the boil-off gas to the gas turbine as equipment upstream from the mixing location A plurality of gas compressors for boosting the boil-off gas are provided, and in the receiving step, as the equipment status, an operating number of the plurality of gas compressors is received, and in the control amount calculating step, The control amount of the regulator may be determined according to the number of operating gas compressors.

  According to the present invention, the gas turbine equipment can be stably operated even if the calorific value of the mixed gas changes.

It is explanatory drawing which shows the structure of the gas turbine installation and fuel supply installation in 1st embodiment which concerns on this invention. It is a functional block diagram of the control apparatus of the gas turbine equipment in 1st embodiment which concerns on this invention. It is a graph which shows the relationship between the correction coefficient for correct | amending the gas turbine heat input and fuel base control amount in 1st embodiment which concerns on this invention. It is a graph which shows the relationship between the heat input change rate in 1st embodiment which concerns on this invention, and the correction coefficient for correct | amending an intake base control amount. It is a timing chart which shows the change of various parameters accompanying the time change of the gas turbine equipment in a first embodiment concerning the present invention. It is explanatory drawing which shows the structure of the gas turbine installation and fuel supply installation in 2nd embodiment which concerns on this invention. It is a functional block diagram of the control apparatus of the gas turbine equipment in 2nd embodiment which concerns on this invention.

  Hereinafter, various embodiments of gas turbine equipment according to the present invention will be described in detail with reference to the drawings.

"First embodiment"
1st Embodiment of the gas turbine equipment which concerns on this invention is described using FIGS.

  As shown in FIG. 1, the gas turbine facility 1 of the present embodiment includes a gas turbine 10, a generator 30 that generates electric power by driving the gas turbine 10, a fuel line 21 through which fuel supplied to the gas turbine 10 flows, A fuel control valve 31 as a regulator for adjusting the flow rate of the fuel flowing through the fuel line 21, an intake air regulator (IGV) 35 as a regulator for adjusting the flow rate of air supplied to the gas turbine 10, and fuel adjustment And a control device 100 that controls the operation of the valve 31 and the intake air regulator 35.

  The gas turbine 10 includes an air compressor 11 that compresses air A, a combustor 14 that burns fuel in the air compressed by the air compressor 11 to generate combustion gas, and a turbine 15 that is driven by the combustion gas. Have.

  The air compressor 11 includes a compressor rotor 12 that rotates about an axis, and a compressor casing 13 that rotatably covers the compressor rotor 12. The turbine 15 includes a turbine rotor 16 that rotates about an axis, and a turbine casing 17 that rotatably covers the turbine rotor 16. The compressor rotor 12 and the turbine rotor 16 are located on the same axis, and are connected to each other to form a gas turbine rotor 18. The compressor casing 13 and the turbine casing 17 are connected to each other to form a gas turbine casing 19. The rotor of the generator 30 is connected to the gas turbine rotor 18. The power generation amount of the generator 30 is detected by the output meter 41 as the actual output of the gas turbine 10.

  The above-described fuel line 21 is connected to the combustor 14. A fuel adjustment valve 31 is provided in the fuel line 21. The intake air regulator (IGV) 35 includes a plurality of inlet guide vanes 36 provided on the suction port side of the compressor casing 13 and a guide vane driver 37 that changes the opening degree of the plurality of inlet guide vanes 36. .

  A mixed gas from the fuel supply facility 5 is supplied to the fuel line 21 as fuel. The fuel supply facility 5 includes an LNG tank 50 that stores liquefied natural gas (hereinafter referred to as LNG (Liquefied Natural Gas)), an LNG line 51 through which LNG from the LNG tank 50 flows, and an LNG pump that boosts the LNG. 61, a vaporizer 62 that heats and vaporizes the LNG boosted by the LNG pump 61, an NG line 52 through which natural gas (hereinafter referred to as NG (Natural Gas)) that is vaporized LNG flows, and an LNG tank 50 A BOG line 53 through which boil off gas (hereinafter referred to as BOG (Boil Off Gas)) generated in the inside flows, a plurality of BOG compressors 63 for boosting the BOG, and a fuel supply line through which a mixed gas of BOG and NG flows. And.

The LNG tank 50 and the vaporizer 62 are connected by the LNG line 51 described above. The LNG pump 61 is provided in the LNG line 51. The LNG line 51, LNG calorimeter 71 for detecting the unit LNG heating value _{H N} is the amount of heat generated per unit amount of LNG flowing here is provided. In addition, the NG line 52, NG flow meter 72 is provided for detecting the flow rate _{F N} of NG flowing here.

  The aforementioned BOG is a gas in which part of the LNG has evaporated due to natural heat input to the LNG in the LNG tank 50. This BOG is substantially composed of only methane having the lowest boiling point among methane, methane, propane and the like constituting LNG.

The BOG line 53 includes a BOG suction line 54 that connects the LNG tank 50 and the suction ports of the plurality of BOG compressors 63, and a BOG discharge line 55 that connects the discharge ports of the plurality of BOG compressors 63 and the NG line 52. Have. The BOG suction line 54 or the LNG tank 50 is provided with a pressure gauge 73 that detects the internal pressure. The plurality of BOG compressors 63 are driven when the pressure detected by the pressure gauge 73 exceeds a predetermined level. The BOG discharge line 55, BOG flow meter 74 is provided for detecting a flow rate _{F B} of BOG flowing here.

  Both the BOG discharge line 55 and the NG line 52 are connected to the fuel supply line 56. Therefore, the mixed gas of BOG and NG flows through the fuel supply line 56 as described above. A connection point between the BOG discharge line 55 and the NG line 52 and the fuel supply line 56 is a mixed point 57 of BOG and NG. The fuel supply line 56 of the fuel supply facility 5 is connected to the fuel line 21 of the gas turbine facility 1.

As shown in FIG. 2, the control device 100 of the gas turbine equipment 1 includes a reception unit 110 that receives various data, a control amount calculation unit 120 that obtains control amounts of the fuel adjustment valve 31 and the intake air regulator 35 that are regulators, An output unit 140 that outputs the control amount obtained by the control amount calculation unit 120 to the regulator, and a BOG heat generation amount generation unit 119 that outputs a unit BOG heat generation amount H _B that is a heat generation amount per unit amount of BOG. Have.

The reception unit 110 includes an actual output reception unit 111 that receives the actual output of the gas turbine 10 detected by the output meter 41, a target output reception unit 112 that receives a target output of the gas turbine 10 from the host device, and an NG flow meter 72. and NG rate acceptance unit 113 for accepting a detected NG flow _{F N,} the LNG heating value reception unit 114 that receives the unit LNG calorific value _{H N} detected by the LNG calorimeter 71, BOG flow rate detected by the BOG flow meter 74 having a BOG flow rate acceptance unit 115 that accepts F _B, the.

As described above, BOG is substantially composed only of methane. In the fuel supply facility 5, the pressure of BOG flowing from the BOG discharge line 55 to the fuel supply line 56 is substantially constant. Therefore, in the fuel supply facility 5, the unit BOG heat generation amount H _B that is the heat generation amount per unit volume of the BOG flowing through the fuel supply line 56 is substantially constant. Therefore, in this embodiment, the BOG heat value generating portion 119, and is stored in advance unit BOG calorific _{H B.}

  The control amount calculation unit 120 includes a fuel control amount calculation unit 121 that calculates the control amount of the fuel adjustment valve 31 and an intake control amount calculation unit 131 that calculates the control amount of the intake regulator 35.

Fuel control amount calculation unit 121 includes a fuel based control amount calculation unit 122 for determining the fuel-based control amount, the gas turbine heat input calculation unit 125 for obtaining the gas turbine heat input H _GT corresponding to the BOG flow rate F _B, fuel based control A coefficient generation unit 126 that outputs a correction coefficient k for correcting the amount; and a correction unit 127 that corrects the fuel base control amount using the correction coefficient k output from the coefficient generation unit 126.

  The fuel base control amount is a fuel control amount that is determined based on information indicating a situation upstream of the BOG / NG mixing point 57, that is, on the LNG tank 50 side of the fuel supply line 56. In other words, the fuel-based control amount is a fuel control amount that is determined based on information indicating a situation downstream of the BOG / NG mixing point 57. The fuel-based control amount calculation unit 122 includes, for example, a deviation calculation unit 123 that calculates a deviation between the actual output and the target output, and a PI control amount calculation unit 124 that calculates a PI (Proportional Integral) control amount based on the deviation. Have. The fuel base control amount calculation unit 122 obtains a fuel control amount in which the actual output approaches the target output, and further includes a fuel control amount in which the combustion gas inlet temperature in the turbine 15 is equal to or lower than a set upper limit temperature. You may ask for it. In this case, the minimum fuel control amount among the plurality of fuel control amounts is set as the fuel base control amount.

The gas turbine heat input amount _HGT is a calorific value of the mixed gas supplied to the gas turbine 10 per unit time. Gas turbine heat input calculation unit 125, a BOG flow rate _{F B} detected by the BOG flow meter 74, and the unit BOG calorific value _{H B} outputted from the BOG heat value generating unit 119, which is detected by the NG flowmeter 72 NG and the flow rate _{F N,} obtained by the detected unit LNG calorific _{H N} in LNG calorimeter 71.

The coefficient generator 126 has a function or map indicating the relationship between the gas turbine heat input amount _HGT and the correction coefficient k. Coefficient generating unit 126, the function or using a map, determine the correction coefficient k gas turbine heat input calculation unit 125 corresponds to the gas turbine heat input H _GT obtained. In the present embodiment, the relationship between the gas turbine heat input amount _HGT and the correction coefficient k is such that the correction coefficient k gradually decreases as the gas turbine heat input amount _HGT increases as shown in FIG. . In this relationship, when the gas turbine heat input amount H _GT is the predetermined heat amount H _GT 0, the correction coefficient k is “1”. Further, in this relationship, when the gas turbine heat input amount H _GT is larger than the predetermined heat amount H _GT 0, the correction coefficient k is smaller than “1”, for example, “0.9”, and the gas turbine heat input amount H _GT is If less than the amount of heat H _{GT 0} appointments, the correction coefficient k becomes larger than "1", for example "1.1".

  The correction unit 127 is a multiplier that multiplies the fuel base control amount obtained by the fuel base control amount calculation unit 122 by the correction coefficient k output from the coefficient generation unit 126.

The intake control amount calculation unit 131 and the intake base control amount calculation unit 132 that calculates the intake base control amount, and the heat input change rate that calculates the heat input change rate dH _GT that is the change amount per unit time of the gas turbine heat input amount H _GT A calculation unit 135, a coefficient generation unit 136 that outputs a correction coefficient j for correcting the intake base control amount, a correction unit 137 that corrects the intake base control amount using the correction coefficient j output by the coefficient generation unit 136, Have.

  As with the fuel base control amount, the intake base control amount is determined based on information indicating the situation upstream of the BOG / NG mixing point 57, that is, on the LNG tank 50 side of the fuel supply line 56. It is. The intake base control amount calculation unit 132 is determined by, for example, the rotational speed of the gas turbine rotor 18, the combustion gas inlet temperature in the turbine 15, and the like.

Coefficient generating unit 136 of the intake air control amount calculation unit 131 has a function or a map showing a relationship between heat input change rate dH _GT and the correction coefficient j. The coefficient generation unit 136 uses this function or map to obtain a correction coefficient j corresponding to the heat input change rate dH _GT obtained by the heat input change rate calculation unit 135. In the present embodiment, the relationship between the heat input change rate dH _GT and the correction coefficient k is such that, as shown in FIG. 4, when the heat input change rate dH _GT is a positive value, the heat input change rate dH _GT is pre- Up to a predetermined value dH _GT 1 (positive value), the correction coefficient j is “1” and is constant, and when the heat input change rate dH _GT exceeds a predetermined value dH _GT 1, the heat input change rate dH _GT As the value increases, the correction coefficient j gradually increases. Further, when the heat input change rate dH _GT is a negative value, the relationship between the heat input change rate dH _GT and the correction coefficient j is such that the heat input change rate dH _GT is a predetermined value dH _GT 2 (negative until the value), the correction coefficient j is constant at "1", when the heat input rate of change _{dH GT} is smaller than the value _{dH GT} 2 predetermined, as the heat input rate of change _{dH GT} becomes smaller, the correction coefficient j Is a gradually decreasing relationship.

  The correction unit 137 of the intake control amount calculation unit 131 is a multiplier that multiplies the intake base control amount obtained by the intake base control amount calculation unit 132 by the correction coefficient j output from the coefficient generation unit 136.

  The output unit 140 outputs a valve opening degree output unit 141 that outputs a valve opening degree that is a control amount to the fuel adjustment valve 31 and an IGV opening state that is a control amount to the intake air regulator (IGV) 35. And an IGV opening output unit 142 that outputs the degree.

  Next, operation | movement of the gas turbine equipment 1 demonstrated above is demonstrated.

In the fuel supply facility 5, the number of operating BOG compressors 63 changes depending on the situation. When number of operating BOG compressor 63 is changed, as a result of BOG flow rate F _B of the mixed gas flowing through the fuel line 21 of the gas turbine equipment 1 is suddenly changed, the unit amount of the mixed gas flowing through the fuel line 21 of the gas turbine equipment 1 The calorific value of the unit mixed gas, which is the calorific value per unit, changes suddenly. When the unit gas mixture calorific value changes suddenly, the gas turbine output changes abruptly, which hinders stable operation of the gas turbine 10. In particular, when the calorific value of the unit gas mixture increases abruptly, the combustion gas inlet temperature in the turbine 15 increases abruptly and the turbine 15 and the combustor 14 may be damaged. For this reason, in many gas turbine facilities 1, various control is performed according to the change of the calorific value of unit gas mixture.

  Here, the case where the calorimeter detects the unit gas mixture calorific value and controls the gas turbine equipment based on the output from the calorimeter will be considered.

For example, reduced number of operating BOG compressor 63, as a result, BOG discharge line 55 of the fuel supply system 5, and a gas turbine equipment 1 of the fuel line 21 flows flow _{F B} of BOG and rapidly decreased. If the valve opening degree of the fuel adjusting valve 31 of the gas turbine system 1 is constant, the mixed gas flowing through the fuel line 21, the BOG unit calorific small while the flow rate F _B decreases rapidly, the unit heating value is large NG of for flow F _N rapidly increases, the unit mixed gas heating value is rapidly increased. Therefore, even if the flow rate of the mixed gas flowing into the combustor 14 is constant, the gas turbine heat input amount _HGT increases rapidly.

  As described above, when the calorimeter detects the unit gas mixture calorific value of the mixed gas flowing through the fuel line 21, the calorimeter outputs a change in the unit gas mixture calorific value because of the long detection time of the calorimeter. At that time, the mixed gas after the calorific value change may be supplied to the gas turbine 10 in some cases. In this case, no matter what control is performed based on the output from the calorimeter, it is impossible to cope with a sudden change in the calorific value of the unit gas mixture.

Therefore, the control device 100 according to the present embodiment recognizes the change in the unit gas mixture calorific value before the mixed gas after the calorific value change is supplied to the gas turbine 10, and responds to this change with the fuel supply facility. 5, information indicating the situation on the upstream side of the mixed portion 57 of NG and BOG in 5 is received. Specifically, the receiving unit 110 of the control device 100 of the present embodiment, as the information indicating the upstream conditions than mixed portion 57, BOG flow meter the flow rate _{F B} of BOG flowing BOG discharge line 55 of the fuel supply system 5 Accept from 74 (acceptance process). Furthermore, the receiving unit 110 receives the flow rate _{F N} of NG flowing in the NG line 52 of the fuel supply system 5 from NG flow meter 72, LNG unit calorific value _{H N} of LNG flowing in the LNG line 51 of the fuel supply system 5 calorimetry Accept from a total of 71 (acceptance process).

The fuel control amount calculation unit 121 in the control device 100 obtains a fuel control amount based on various data received by the reception unit 110 (fuel control amount calculation step). Specifically, the gas turbine heat input operation unit 125 of the fuel control amount calculation unit 121, based on the information receiving unit 110 has received, determining the gas turbine heat input H _GT (gas turbine heat input calculation step). The gas turbine 10 is supplied with a mixed gas composed of BOG and NG. For this reason, the gas turbine heat input amount calculation unit 125 obtains the heat generation amount of BOG supplied to the gas turbine 10 per unit time and the heat generation amount of NG supplied to the gas turbine 10 per unit time. by adding, obtaining the gas turbine heat input H _GT. Calorific value of BOG supplied per unit time to the combustor 14 obtains the BOG flow rate _{F B} detected by the BOG flow meter 74, by a unit BOG calorific value _{H B} outputted from the BOG heat value generating unit 119 It is done. Further, the heating value of NG is supplied to the combustor 14 per unit time is determined and NG rate _{F N} detected by the NG flowmeter 72, by the detected unit LNG calorific _{H N} in LNG calorimeter 71 It is done.

The amount of heat generated per unit amount of LNG does not change rapidly unless new LNG flows into the LNG tank 50 after LNG is stored in the LNG tank 50. The amount of heat generated per unit amount of LNG in the LNG tank 50 changes slowly according to the amount of BOG generated in the LNG tank 50. For this reason, even if it takes some time to detect the calorific value in the LNG calorimeter 71, the unit LNG calorific value H _N output from the LNG calorimeter 71 and the actual unit LNG calorific value H _N at the present time There is almost no difference. Therefore, using the unit LNG calorific value H _N detected by the LNG calorimeter 71 and the NG flow rate F _N detected by the NG flow meter 72, the calorific value of NG supplied to the gas turbine 10 per unit time. Even if the fuel control amount is determined based on this, control delay does not become a problem.

Further, the unit BOG heat generation amount H _B which is the heat generation amount per unit volume of the BOG is substantially constant as described above. Therefore, if it is possible to recognize the BOG flow rate F _B, can be obtained the heating value of the BOG to be supplied to the gas turbine 10 per unit time. Therefore, in the present embodiment, the unit BOG heat generation amount H _B output from the BOG heat generation amount generation unit 119 and the BOG flow rate F _B detected by the BOG flow meter 74 are used per unit time. Next, the calorific value of BOG supplied to the gas turbine 10 is obtained. Thus, in the present embodiment, without using the heating value detected by the calorimeter, with a BOG flow rate F _B of the upstream side of the mixing portion 57 of the NG and the BOG, the gas turbine 10 per unit time Since the heat generation amount of the supplied BOG is obtained, control delay does not become a problem even if the fuel control amount is determined based on this.

That is, in the present embodiment, the unit calorific value of the mixed gas flowing through the fuel line 21 of the gas turbine facility 1 is set upstream of the mixing point 57 of NG and BOG before the unit calorific value of the mixed gas changes. It determined using the BOG flow rate _{F B} or the like. In this embodiment, the unit calorific value of the mixed gas and the flow rate of the mixed gas flowing through the fuel line 21 are supplied to the gas turbine 10 per unit time before the unit calorific value of the mixed gas changes. The heat generation amount of the mixed gas, that is, the gas turbine heat input amount _HGT is obtained.

When the gas turbine heat input amount calculation unit 125 obtains the gas turbine heat input amount H _GT , the coefficient generation unit 126 of the fuel control amount calculation unit 121 calculates the gas turbine heat input amount H _GT described with reference to FIG. 3 and the correction coefficient k. using the relationship, obtaining the correction coefficient k corresponding to the gas turbine heat input H _GT gas turbine heat input calculation unit 125 is determined (fuel coefficient generating step).

The correction unit 127 of the fuel control amount calculation unit 121 multiplies the fuel base control amount obtained by the fuel base control amount calculation unit 122 of the fuel control amount calculation unit 121 by the correction coefficient k to correct the fuel base control amount. This is output as a fuel control amount (correction step). Coefficient generating unit 126 of the fuel control amount calculation unit 121, as the gas turbine heat input H _GT increases, the outputs of the correction coefficient k gradually decreases, BOG flow rate F gas turbine heat input with decreasing _B When _HGT is increased, the correction unit 127 outputs the fuel base control amount that has been reduced by the correction as the fuel control amount.

  The valve opening output unit 141 outputs a valve opening command indicating the valve opening of the fuel control valve 31 corresponding to the fuel control amount from the fuel control amount calculation unit 121 to the fuel control valve 31 (output process).

The intake control amount calculation unit 131 of the control device 100 obtains an intake control amount based on various data received by the reception unit 110 (intake control amount calculation step). Specifically, the heat input change rate calculation unit 135 of the intake control amount calculation unit 131 calculates the gas turbine heat input amount H _GT per unit time when the gas turbine heat input amount H _GT is obtained by the gas turbine heat input amount calculation unit 125. determining heat input change rate dH _GT is a change amount (heat input rate of change calculation step). The coefficient generation unit 136 of the intake control amount calculation unit 131 uses the relationship between the heat input change rate dH _GT and the correction coefficient j described with reference to FIG. 4 to determine the heat input change obtained by the heat input change rate calculation unit 135. A correction coefficient j corresponding to the rate dH _GT is obtained (intake coefficient generation step).

  The correction unit 137 of the intake control amount calculation unit 131 corrects the intake base control amount by multiplying the intake base control amount obtained by the intake base control amount calculation unit 132 by the correction coefficient j, and uses this as the intake control amount. Output (output process).

  The IGV opening output unit 142 outputs an IGV opening command indicating the IGV opening of the intake controller (IGV) 35 according to the intake control amount from the intake control amount calculation unit 131 to the intake controller 35.

Here, as described above, reduced number of operating BOG compressor 63, as a result, the flow rate F _B of BOG flowing BOG discharge line 55 of the fuel supply system 5 is rapidly decreased, as shown in FIG. 5 at time t0, the rapid decrease of the flow rate _{F B} of BOG flowing BOG discharge line 55 is detected by the BOG flow meter 74.

When BOG is to time T3 from the position BOG flow meter 74 is provided up to the combustor 14, any if not controlled with respect to rapid reduction of the BOG flow rate _{F B,} time BOG flow meter 74 detects t0 At time t3 after time T3, the gas turbine heat input amount _HGT rapidly increases as indicated by a two-dot chain line in FIG.

Therefore, in the present embodiment, the valve opening degree output unit 141 of the control device 100 outputs a valve opening degree command to the fuel control valve 31 before reaching the scheduled time t3 when the gas turbine heat input amount _HGT rapidly increases. Specifically, the time from when the valve opening degree of the fuel control valve 31 is changed to when the gas turbine heat input amount _HGT is changed according to this change is defined as T1. Valve opening output unit 141 of this embodiment, the BOG flow rate _{F B} is changed, the BOG flow rate _{F B} from time t0 receiving unit 110 has received after (T3-T1) time time t1, BOG flow rate the valve opening command of a fuel control amount based on the change of the F _B outputs to the fuel control valve 31. When the fuel adjustment valve 31 receives this valve opening command, the fuel adjustment valve 31 has an opening corresponding to the fuel control amount indicated by the valve opening command. In this case, in the present embodiment, with respect to the proliferation of BOG flow rate F gas turbine heat input H _GT by rapid decrease of _B, since deals with the control amount of reduced by correcting the fuel base control quantity as the fuel control amount, the fuel regulating valve 31 The opening degree of the valve becomes smaller, and the flow rate of the mixed gas supplied to the gas turbine 10 decreases.

As a result, in the present embodiment, the flow rate of the mixed gas flowing into the combustor 14 is reduced at the scheduled time t3 when the gas turbine heat input amount _HGT rapidly increases. Therefore, in this embodiment, also the calorific value of the mixed gas is varied, it is possible to suppress variation in the gas turbine heat input H _GT.

As described above, even if the valve opening degree of the fuel control valve 31 is changed in order to reduce the flow rate of the mixed gas flowing into the combustor 14 at the scheduled time t3 when the gas turbine heat input amount _HGT rapidly increases. , if the heat input rate of change dH _GT is a variation per unit time of the gas turbine heat input H _GT is larger than the opening change amount per unit time of the fuel adjusting valve 31 is shown by a dashed line in FIG. 5 Thus, the gas turbine heat input amount _HGT temporarily increases. When the gas turbine heat input amount _HGT increases, the combustion gas inlet temperature of the turbine 15 increases.

In this embodiment, larger than the value dH GT ₁ that heat input change rate dH _GT was predetermined positive value that is the amount of change per unit time of the gas turbine heat input H _GT, corrects the intake air base control quantity The intake control amount is made larger by. For this reason, in this embodiment, in this case, the IGV opening of the intake air regulator 35 is increased, the flow rate of the air flowing into the combustor 14 is increased, and the rise in the combustion gas inlet temperature of the turbine 15 can be suppressed. it can. Further, in the present embodiment, when the heat input change rate dH _GT is a negative value and smaller than the predetermined value dH _GT 2, that is, when the gas turbine heat input amount H _GT rapidly decreases, the intake base control An intake control amount is obtained by reducing the amount by correction. For this reason, in this embodiment, in this case, the IGV opening of the intake air regulator 35 is reduced, the flow rate of air flowing into the combustor 14 is reduced, and the decrease in the combustion gas inlet temperature of the turbine 15 is suppressed. it can.

IGV opening degree output unit 142 of the controller 100, before reaching the scheduled time t3 the gas turbine heat input _{H GT} is rapidly increased, with respect to the intake controller 35, outputs the IGV opening command showing the intake control quantity of the aforementioned To do. Specifically, the time from when the IGV opening of the intake air regulator 35 changes until the amount of air flowing into the combustor 14 changes due to this change is defined as T2. IGV opening degree output unit 142 of the present embodiment, BOG flow rate _{F B} is changed, this BOG flow rate _F (T3-T2) from the time t0 accepting unit 110 has accepted the _B time after the time t2, the intake air control An IGV opening command indicating the amount is output to the intake air regulator 35. As a result, in the present embodiment, the flow rate of the air flowing into the combustor 14 increases at the scheduled time t3 when the gas turbine heat input amount _HGT rapidly increases. Therefore, in the present embodiment, it is possible to suppress an increase in the combustion gas inlet temperature of the turbine 15 with increasing gas turbine heat input H _GT.

  The timing (t1) for outputting the valve opening command and the timing (t2) for outputting the IGV opening command are determined according to the times T1, T2, and T3 described above. These times T1, T2, and T3 vary depending on the gas flow rate. For this reason, in order to output the opening degree command at an accurate timing, it is preferable to obtain the gas flow rate from the flow rate of each gas and determine the times T1, T2 and T3 using this gas flow rate. However, when accuracy regarding the output timing of the opening degree command is not required, each time T1, T2, T3 may be treated as a predetermined fixed value.

Above, in this embodiment, also the calorific value of the mixed gas is changed in advance to predict changes in the gas turbine heat input H _GT, according to the gas turbine heat input H _GT, the valve of the fuel regulating valve 31 opens and it controls the degree, it is possible to suppress a change in the actual gas turbine heat input H _GT. Furthermore, in the present embodiment, even if the calorific value of the mixed gas is changed in response to changes in the gas turbine heat input H _GT predicted in advance, since also controls IGV opening degree of the intake regulator 35, the turbine 15 Variations in the combustion gas inlet temperature can be suppressed. Therefore, according to this embodiment, even if the calorific value of the mixed gas changes, the gas turbine equipment 1 can be stably operated.

In the present embodiment, the relationship used for the coefficient generating unit 136 of the intake air control amount calculation unit 131 defines the correction coefficient j, as described with reference to FIG. 4, the heat input rate of change dH _GT positive In the case of the value, when the heat input change rate dH _GT exceeds a predetermined value dH _GT 1, the correction coefficient j gradually increases as the heat input change rate dH _GT increases. Further, when the heat input change rate dH _GT is a negative value, when the heat input change rate dH _GT becomes smaller than a predetermined value dH _GT 2, the correction coefficient j increases as the heat input change rate dH _GT becomes smaller. Is a gradually decreasing relationship. For this reason, in this embodiment, as described above, even if the calorific value of the mixed gas changes, fluctuations in the combustion gas inlet temperature of the turbine 15 can be suppressed. However, for the purpose that the relative increase in the BOG flow rate F calorific value of the mixed gas with decreasing _B, suppress an increase in the combustion gas inlet temperature of the turbine 15, the relationship is a two in FIG. 4 As indicated by the dotted line, when the heat input rate of change dH _GT is a negative value, the correction coefficient j may be constant at “1” for any value.

In the present embodiment, the intake control amount is corrected according to the heat input change rate dH _GT . However, the intake control amount may be corrected according to the gas turbine heat input amount H _GT . In this case, the correction unit 137 corrects the intake control amount to increase as the gas turbine heat input amount _HGT increases.

Further, in this embodiment, the variation of BOG flow rate F _B, although both of the fuel control amount and the intake air control amount and a correction target, only one of them may be corrected. However, when only the intake air control quantity and corrected, as described above, it is preferable to correct accordingly the intake air control quantity in the gas turbine heat input H _GT.

"Second embodiment"
A second embodiment of the gas turbine equipment according to the present invention will be described with reference to FIGS. 6 and 7.

  As shown in FIG. 6, the gas turbine equipment 1a of this embodiment is the same as the gas turbine equipment 1 of the first embodiment except for the control device 100a. The fuel supply facility 5 for supplying fuel to the gas turbine facility 1a includes a control device 80, and notifies the control device 100a of the gas turbine facility 1a of the number of operating BOG compressors 63. The control device 80 of the fuel supply facility 5 receives a signal indicating whether or not it is operating from each of the plurality of BOG compressors 63. Based on the signal from each BOG compressor 63, the control device 80 of the fuel supply facility 5 notifies the control device 100a of the gas turbine facility 1a of the number of operating BOG compressors 63.

  As shown in FIG. 7, the control device 100a of the gas turbine equipment 1a includes a reception unit 110a, a control amount calculation unit 120a, an output unit 140, and a BOG heat generation amount generation unit 119, like the control device 100 of the first embodiment. . However, the reception unit 110a and the control amount calculation unit 120a of the present embodiment are different from those of the first embodiment.

  The reception unit 110a of the present embodiment is similar to the reception unit 110 of the first embodiment in that the actual output reception unit 111, the target output reception unit 112, the NG flow rate reception unit 113, the LNG heat generation amount reception unit 114, and the BOG flow rate reception unit. 115. Furthermore, the reception unit 110a of the present embodiment receives a facility status reception unit 116 that receives the number of operating BOG compressors 63 from the control device 80 of the fuel supply facility 5 as the facility status upstream of the BOG / NG mixing portion 57. Have

  Similar to the control amount calculation unit 120 of the first embodiment, the control amount calculation unit 120a of the present embodiment includes a fuel control amount calculation unit 121a and an intake control amount calculation unit 131a. Similar to the fuel control amount calculation unit 121 of the first embodiment, the fuel control amount calculation unit 121a of the present embodiment includes a fuel base control amount calculation unit 122, a gas turbine heat input amount calculation unit 125, a coefficient generation unit 126, and a correction unit. 127. Further, the fuel control amount calculation unit 121a of the present embodiment generates a second coefficient that generates a correction coefficient k for correcting the fuel base control amount in addition to the first coefficient generation unit 126 that is the coefficient generation unit 126. And a coefficient switching unit 129 that outputs only one of the correction coefficient k from the first coefficient generation unit 126 and the correction coefficient k from the second coefficient generation unit 128 to the correction unit 127.

  The second coefficient generation unit 128 has a function or map indicating the relationship between the number of operating BOG compressors 63 and the correction coefficient k. The second coefficient generation unit 128 obtains a correction coefficient k corresponding to the number of operating BOG compressors 63 sent from the control device 80 of the fuel supply facility 5 using this function or map. In the present embodiment, the relationship between the number of operating BOG compressors 63 and the correction coefficient k is a relationship in which the correction coefficient k gradually decreases as the number of operating units decreases.

When the number of operating BOG compressors 63 decreases, as described in the first embodiment, the flow rate of BOG flowing through the BOG discharge line 55 decreases rapidly, and the mixed gas flowing through the fuel line 21 of the gas turbine equipment 1a , while the flow rate F _B of BOG unit calorific less rapidly decreases to flow F _N of the unit heating value is large NG increases sharply, the unit mixed gas heating value is rapidly increased. Therefore, the gas turbine heat input amount _HGT increases rapidly. Therefore, the relationship between the operation quantity and the correction coefficient k of the BOG compressor 63 used in the second coefficient generating unit 128, in order to suppress the increase of the gas turbine heat input H _GT with decreasing working volume, utilization number less Accordingly, the correction coefficient k is gradually reduced.

  The coefficient switching unit 129 is a second correction period from the time when the number of operating BOG compressors 63 received by the equipment status receiving unit 116 is changed until a predetermined time elapses, from the second coefficient generating unit 128. The correction coefficient k is output to the correction unit 127. Further, the coefficient switching unit 129 outputs the correction coefficient k from the first coefficient generation unit 126 to the correction unit 127 during the first correction period excluding the second correction period.

  As in the intake control amount calculation unit 131 of the first embodiment, the intake control amount calculation unit 131a of the present embodiment is an intake base control amount calculation unit 132, a heat input change rate calculation unit 135, a coefficient generation unit 136, and a correction unit. 137. Further, the intake control amount calculation unit 131a of the present embodiment generates a second coefficient for generating a correction coefficient j for correcting the intake base control amount in addition to the first coefficient generation unit 136 which is the coefficient generation unit 136. And a coefficient switching unit 139 that outputs only one of the correction coefficient j from the first coefficient generation unit 136 and the correction coefficient j from the second coefficient generation unit 138 to the correction unit 137.

  The second coefficient generation unit 138 of the intake control amount calculation unit 131a also has a function or map indicating the relationship between the number of operating BOG compressors 63 and the correction coefficient j. The second coefficient generation unit 138 obtains a correction coefficient j corresponding to the number of operating BOG compressors 63 sent from the control device 80 of the fuel supply facility 5 using this function or map. In this embodiment, the relationship between the number of operating BOG compressors 63 and the correction coefficient j is such that when the number of operating units is equal to or less than a predetermined number, the correction coefficient j gradually increases as the number decreases. is there.

  The coefficient switching unit 139 of the intake control amount calculation unit 131a also outputs the correction coefficient j from the second correction period and second coefficient generation unit 138 to the correction unit 137, and generates the first correction period and first coefficient generation. The correction coefficient j from the unit 136 is output to the correction unit 137.

  Next, operation | movement of the gas turbine equipment 1a of this embodiment is demonstrated.

  When the number of operating BOG compressors 63 decreases due to a failure of the BOG compressor 63, a sudden change in the state of the LNG tank 50, or the like, the control device 80 of the fuel supply facility 5 recognizes this, and the fuel supply facility 5 Is notified to the control device 100a of the gas turbine equipment 1a.

  When the equipment status receiving unit 116 of the control device 100a in the gas turbine equipment 1a receives the operating number of the BOG compressor 63 from the control device 80 of the fuel supply facility 5 (receiving process), the operating number is calculated as the fuel control amount calculating unit 121a. Of the second coefficient generator 128 and the second coefficient generator 138 of the intake control amount calculator 131a. Furthermore, the equipment status receiving unit 116 notifies the coefficient switching unit 129 of the fuel control amount calculation unit 121a and the coefficient switching unit 139 of the intake control amount calculation unit 131a that the number of operating BOGs has changed.

  When the second coefficient generation unit 128 of the fuel control amount calculation unit 121a receives the number of operating BOG compressors 63, the second coefficient generation unit 128 uses the relationship between the number of operating units and the correction coefficient k to calculate a correction coefficient k corresponding to the received number of operating units. Obtain (fuel coefficient generation process).

  The coefficient switching unit 129 of the fuel control amount calculation unit 121a has a second correction period from the time when it is received that there is a change in the number of operating units until a predetermined time elapses, and the correction coefficient from the second coefficient generation unit 128. k is output to the correction unit 127. Therefore, the correction unit 127 multiplies the fuel base control amount by the correction coefficient k from the second coefficient generation unit 128, corrects the fuel base control amount, and outputs this as the fuel control amount (correction). Process).

As described above, the second coefficient generation unit 128 outputs the correction coefficient k that gradually decreases as the number of operating units decreases. Therefore, when the gas turbine heat input H _GT increases with a decrease in production volume, the correction unit 127 outputs the obtained by reducing the fuel based control amount by correcting a fuel control amount.

  The valve opening output unit 141 outputs a valve opening command indicating the valve opening of the fuel control valve 31 corresponding to the fuel control amount from the fuel control amount calculation unit 121a to the fuel control valve 31 (output process). When the number of operating BOG compressors 63 decreases, the fuel control amount from the fuel control amount calculation unit 121a decreases, so the valve opening of the fuel control valve 31 decreases, and the mixed gas supplied to the gas turbine 10 decreases. The flow rate decreases.

Accordingly, in this embodiment, also the calorific value of the mixed gas by a change in number of operating BOG compressor 63 is varied, it is possible to suppress variation in the gas turbine heat input H _GT.

  Similarly to the second coefficient generation unit 128 of the fuel control amount calculation unit 121a, the second coefficient generation unit 138 of the intake control amount calculation unit 131a receives the number of operating BOG compressors 63, Is used to obtain a correction coefficient j corresponding to the received number of operating units (intake coefficient generation step). Further, the coefficient switching unit 139 of the intake control amount calculation unit 131a also elapses a predetermined time from the time when it is received that the number of operating units has been changed, similarly to the coefficient switching unit 129 of the fuel control amount calculation unit 121a. The correction coefficient j from the second coefficient generation unit 138 is output to the correction unit 137 until the second correction period. For this reason, the correction unit 137 of the intake control amount calculation unit 131a multiplies the intake base control amount by the correction coefficient j from the second coefficient generation unit 138 to correct the intake base control amount, Output as control amount (correction step).

As described above, the second coefficient generation unit 138 of the intake control amount calculation unit 131a outputs the correction coefficient j that gradually increases as the number decreases when the number of operating units is equal to or less than the predetermined number. For this reason, when the number of operating units becomes equal to or less than a predetermined number due to a decrease in the number of operating units and the gas turbine heat input amount _HGT increases, the correction unit 137 of the intake control amount calculation unit 131a performs the intake base control by correction. The larger amount is output as the intake control amount.

  The IGV opening output unit 142 outputs an IGV opening command indicating the IGV opening of the intake controller (IGV) 35 according to the intake control amount from the intake control amount calculation unit 131a to the intake controller 35 (output process) ). When the number of operating BOG compressors 63 is equal to or less than the predetermined number, the intake control amount from the intake control amount calculation unit 131a increases. In this case, the IGV opening of the intake air regulator (IGV) 35 is The flow rate of the air flowing into the combustor 14 increases and the increase in the combustion gas inlet temperature of the turbine 15 is suppressed.

  Therefore, in this embodiment, even if the calorific value of the mixed gas fluctuates due to a change in the number of operating BOG compressors 63, fluctuations in the combustion gas inlet temperature of the turbine 15 can be suppressed.

  In the first correction period after the elapse of a predetermined time from the time when the number of operating BOG compressors 63 received by the facility status receiving unit 116 has changed, the coefficient switching unit 129 of the fuel control amount calculating unit 121a includes: The correction coefficient k from the first coefficient generation unit 126 is output to the correction unit 127. Further, during this first correction period, the coefficient switching unit 139 of the intake control amount calculation unit 131 a also outputs the correction coefficient j from the first coefficient generation unit 136 to the correction unit 137.

Therefore, in the first correction period, the gas turbine equipment 1a of the present embodiment operates in the same manner as the gas turbine equipment 1 of the first embodiment. Therefore, in this first correction period, for example, reduced driving amount of BOG compressor 63 running slightly, or if the BOG flow rate _{F B} is reduced, the unit LNG heating value _{H N} or NG flow _{F N} is even when some variation, it is possible to suppress variation in the gas turbine heat input H _GT.

  In this embodiment, the timing at which the valve opening output unit 141 outputs a valve opening command indicating the fuel control amount corrected by the correction coefficient k from the second coefficient generating unit 128 to the fuel control valve 31. These are the same as the timing (t1) for outputting the valve opening degree command described with reference to FIG. 5 in the first embodiment. In the present embodiment, the timing at which the IGV opening output unit 142 outputs an IGV opening command indicating the intake control amount corrected by the correction coefficient j from the second coefficient generation unit 138 to the intake air regulator 35. These are the same as the timing (t2) for outputting the IGV opening command described with reference to FIG. 5 in the first embodiment. However, in this case, the time T3 required to determine the output timing of the opening degree command is the time from the BOG reaching the combustor 14 from the discharge port of the BOG compressor 63.

  Here, in the present embodiment, the number of operating BOG compressors 63 is adopted as the equipment status upstream of the BOG / NG mixed portion 57. However, any facility that is upstream of the BOG / NG mixing point 57 and that changes the unit calorific value of the mixed gas flowing through the fuel line 21 in accordance with a change in the state of the facility can be used. The situation may be used.

Further, in the present embodiment, in response to both the plant condition of the BOG flow rate F _B and the upstream side, it corrects the control amount of the control. However, of the plant condition of the BOG flow rate F _B and the upstream side, in accordance with only the upstream side of the plant condition, the control amount of the controller may be corrected. In this case, in the fuel control amount calculation unit 121a of this embodiment, the gas turbine heat input amount calculation unit 125, the first coefficient generation unit 126, and the coefficient switching unit 129 are unnecessary, and these can be omitted. Further, in this case, in the intake control amount calculation unit 131a of the present embodiment, the heat input change rate calculation unit 135, the first coefficient generation unit 136, and the coefficient switching unit 139 are unnecessary, and these can be omitted. Further, when the control amount of the regulator is corrected only in accordance with the upstream equipment situation, a calorimeter that detects the unit calorific value of the mixed gas is provided in the fuel line 21, and the actual output exemplified in the above embodiments is provided. In addition, the base control amount may be determined according to the unit gas mixture calorific value detected by the calorimeter.

  Further, in the present embodiment, both the fuel control amount and the intake control amount are set as correction targets for changes in the upstream equipment situation, but only one of them may be set as a correction target.

  1, 1a: Gas turbine equipment, 5: Fuel supply equipment, 10: Gas turbine, 11: Air compressor, 14: Combustor, 15: Turbine, 21: Fuel line, 30: Generator, 31: Fuel control valve ( Regulator), 35: intake regulator (regulator), 41: output meter, 50: LNG tank, 51: LNG line, 52: NG line, 53: BOG line, 54: BOG suction line, 55: BOG discharge line 56: Fuel supply line, 57: Mixing location, 61: LNG pump, 62: Vaporizer, 63: BOG compressor, 71: LNG calorimeter, 72: NG flow meter, 73: Pressure gauge, 74: BOG flow meter 80: control device (for fuel supply equipment), 100, 100a: control device (for gas turbine equipment), 110, 110a: reception unit, 120, 120a: control amount calculation unit, 121, 121a: Charge control amount calculation unit, 122: Fuel base control amount calculation unit, 125: Gas turbine heat input calculation unit, 126, 136: Coefficient generation unit (first coefficient generation unit), 127, 137: Correction unit, 128, 138: Second coefficient generation unit, 129, 139: coefficient switching unit, 132: intake base control amount calculation unit, 140: output unit, 141: valve opening output unit, 142: IGV opening output unit

Claims (17)

In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
A reception unit that receives information indicating a situation on the upstream side from the mixing location of the natural gas and the boil-off gas;
In accordance with the upstream situation indicated by the information, a control amount calculation unit that determines a control amount of the regulator;
An output unit that outputs a command indicating the control amount obtained by the control amount calculation unit to the controller;
Have
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
The reception unit receives the flow rate of the boil-off gas upstream from the mixing location as at least part of the information,
The control amount calculation unit is configured according to the heat input amount of the gas turbine, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the flow rate of the boil-off gas. A fuel control amount calculation unit for determining a control amount;
Control device for gas turbine equipment. In the control apparatus of the gas turbine equipment according to claim 1 ,
The fuel control amount calculation unit
A fuel base control amount calculation unit for obtaining a fuel base control amount that is a control amount of the fuel control valve that is determined without being based on information indicating the upstream state;
A gas turbine heat input calculating unit for obtaining the gas turbine heat input corresponding to the flow rate of the boil-off gas;
A fuel coefficient generator that outputs a correction coefficient for correcting the fuel base control amount according to the gas turbine heat input amount;
A correction unit that corrects the fuel base control amount using the correction coefficient output by the fuel coefficient generation unit;
Having
Control device for gas turbine equipment. In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
A reception unit that receives information indicating a situation on the upstream side from the mixing location of the natural gas and the boil-off gas;
In accordance with the upstream situation indicated by the information, a control amount calculation unit that determines a control amount of the regulator;
An output unit that outputs a command indicating the control amount obtained by the control amount calculation unit to the controller;
Have
The regulator includes an intake air regulator that regulates a flow rate of the air supplied to the gas turbine;
The control amount calculation unit is configured according to the heat input amount of the gas turbine, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the flow rate of the boil-off gas. An intake control amount calculating section for determining the control amount;
The intake control amount calculation unit
An intake base control amount calculation unit for obtaining an intake base control amount that is a control amount of the intake regulator determined without being based on information indicating the upstream state;
A gas turbine heat input calculating unit for obtaining the gas turbine heat input corresponding to the flow rate of the boil-off gas;
A heat input change rate calculating unit for obtaining a heat input change rate that is a change amount per unit time of the gas turbine heat input amount;
An intake coefficient generating unit that outputs a correction coefficient for correcting the intake base control amount according to the heat input change rate;
A correction unit that corrects the intake base control amount using the correction coefficient output by the intake coefficient generation unit;
Having
Control device for gas turbine equipment. In the control apparatus of the gas turbine equipment as described in any one of Claim 1 to 3 ,
The accepting unit accepts equipment status upstream from the mixing location as at least part of the information,
The control amount calculation unit determines the control amount of the regulator based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Define
Control device for gas turbine equipment. In the control apparatus of the gas turbine equipment as described in any one of Claim 1 to 3 ,
The accepting unit accepts equipment status upstream from the mixing location as at least part of the information,
The control amount calculation unit is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status after the change for a predetermined time from the time when the equipment status changes. Based on the amount of heat input to the gas turbine, the control amount of the regulator is determined, and the control amount is determined according to the flow rate of the boil-off gas after the predetermined time has elapsed since the time when the equipment status has changed.
Control device for gas turbine equipment. In the control apparatus of the gas turbine equipment according to claim 4 or 5 ,
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
The control amount calculation unit includes a fuel control amount calculation unit that determines the control amount of the fuel control valve,
The fuel control amount calculation unit
A fuel base control amount calculation unit for obtaining a fuel base control amount that is a control amount of the fuel adjustment determined without being based on information indicating the upstream state;
A fuel coefficient generation unit that outputs a correction coefficient for correcting the fuel-based control amount according to the facility status received by the reception unit;
A correction unit that corrects the fuel base control amount using the correction coefficient output by the fuel coefficient generation unit;
Having
Control device for gas turbine equipment. In a control apparatus for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
A reception unit that receives information indicating a situation on the upstream side from the mixing location of the natural gas and the boil-off gas;
In accordance with the upstream situation indicated by the information, a control amount calculation unit that determines a control amount of the regulator;
An output unit that outputs a command indicating the control amount obtained by the control amount calculation unit to the controller;
Have
The accepting unit accepts equipment status upstream from the mixing location as at least part of the information,
The control amount calculation unit determines the control amount of the regulator based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Set
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
The control amount calculation unit includes a fuel control amount calculation unit that determines the control amount of the fuel control valve,
The fuel control amount calculation unit
A fuel base control amount calculation unit for obtaining a fuel base control amount that is a control amount of the fuel adjustment determined without being based on information indicating the upstream state;
A fuel coefficient generation unit that outputs a correction coefficient for correcting the fuel-based control amount according to the facility status received by the reception unit;
A correction unit that corrects the fuel base control amount using the correction coefficient output by the fuel coefficient generation unit;
Having
Control device for gas turbine equipment. In the control device of the gas turbine equipment according to any one of claims 4 to 7 ,
The regulator includes an intake air regulator that regulates a flow rate of the air supplied to the gas turbine;
The control amount calculation unit includes an intake control amount calculation unit that determines the control amount of the intake air regulator,
The intake control amount calculation unit
An intake base control amount calculation unit for obtaining an intake base control amount that is a control amount of the intake regulator determined without being based on information indicating the upstream state;
An intake coefficient generation unit that outputs a correction coefficient for correcting the intake base control amount according to the facility status received by the reception unit;
A correction unit that corrects the intake base control amount using the correction coefficient output by the intake coefficient generation unit;
Having
Control device for gas turbine equipment. In the control device of the gas turbine equipment according to any one of claims 4 to 8 ,
A plurality of gas compressors that increase the pressure of the boil-off gas in order to supply the boil-off gas to the gas turbine are provided as equipment upstream from the mixing location,
The reception unit receives an operating number of the plurality of gas compressors as the equipment status,
The control amount calculation unit in accordance with the稼働台speed of the gas compressor, defining said control amount of the control,
Control device for gas turbine equipment. A control device according to any one of claims 1 to 9 ,
The gas turbine;
The regulator;
A gas turbine facility comprising: In a control method for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
An accepting step of receiving information indicating a situation upstream from the mixing location of the natural gas and the boil-off gas;
A control amount calculation step for determining a control amount of the regulator in accordance with the upstream state indicated by the information;
An output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller;
Run
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
In the receiving step, as at least a part of the information, the flow rate of the boil-off gas on the upstream side of the mixing location is received,
The control amount calculation step is based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to a flow rate of the boil-off gas. Including a fuel control amount calculation step for determining a control amount,
Control method of gas turbine equipment. In a control method for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
An accepting step of receiving information indicating a situation upstream from the mixing location of the natural gas and the boil-off gas;
A control amount calculation step for determining a control amount of the regulator in accordance with the upstream state indicated by the information;
An output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller;
Run
The regulator includes an intake air regulator that regulates a flow rate of the air supplied to the gas turbine,
The control amount calculation step is based on a gas turbine heat input, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to a flow rate of the boil-off gas. Including an intake control amount calculation step for determining a control amount;
The intake control amount calculation step includes:
A step of determining the intake air based control amount is a control amount of the intake regulator determined not based on the information indicating the status of the upstream,
A step of determining the gas turbine heat input in accordance with the flow rate of the BOG,
And obtaining a heat input rate of change is a change amount per unit time of the gas turbine heat input,
Corresponding to the entering thermal change rate, and outputting a correction coefficient for correcting the intake air base control quantity,
A step of correcting the intake base control amount using the correction coefficient the intake coefficient generating unit has output,
Including
Control method of gas turbine equipment. In the control method of the gas turbine equipment according to claim 11 or 12 ,
In the receiving step, as at least a part of the information, the equipment status on the upstream side from the mixing location is received,
In the control amount calculation step, the control amount of the regulator is determined based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Define
Control method of gas turbine equipment. In the control method of the gas turbine equipment according to claim 13 ,
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
The control amount calculation step includes a fuel control amount calculation step for determining the control amount of the fuel control valve,
The fuel control amount calculation step includes:
A fuel base control amount calculation step for obtaining a fuel base control amount that is a control amount of the fuel control valve determined without being based on the information indicating the upstream state;
A fuel coefficient generation step of outputting a correction coefficient for correcting the fuel base control amount according to the facility status received in the reception step;
A correction step of correcting the fuel base control amount using the correction coefficient output in the fuel coefficient generation step;
including,
Control method of gas turbine equipment. In a control method for gas turbine equipment, comprising: a gas turbine that uses a mixed gas of natural gas and boil-off gas as fuel; and a regulator that adjusts a flow rate of the fuel or air supplied to the gas turbine.
An accepting step of receiving information indicating a situation upstream from the mixing location of the natural gas and the boil-off gas;
A control amount calculation step for determining a control amount of the regulator in accordance with the upstream state indicated by the information;
An output step of outputting a command indicating the control amount obtained in the control amount calculation step to the controller;
Run
In the receiving step, as at least a part of the information, the equipment status on the upstream side from the mixing location is received,
In the control amount calculation step, the control amount of the regulator is determined based on a gas turbine heat input amount, which is a calorific value of the mixed gas supplied per unit time to the gas turbine, which is determined according to the equipment status. Set
The regulator has a fuel regulation valve that regulates a flow rate of the fuel supplied to the gas turbine;
The control amount calculation step includes a fuel control amount calculation step for determining the control amount of the fuel control valve,
The fuel control amount calculation step includes:
A fuel base control amount calculation step for obtaining a fuel base control amount that is a control amount of the fuel control valve determined without being based on the information indicating the upstream state;
A fuel coefficient generation step of outputting a correction coefficient for correcting the fuel base control amount according to the facility status received in the reception step;
A correction step of correcting the fuel base control amount using the correction coefficient output in the fuel coefficient generation step;
including,
Control method of gas turbine equipment. In the control method of the gas turbine equipment according to any one of claims 13 to 15 ,
The regulator includes an intake air regulator that regulates a flow rate of the air supplied to the gas turbine,
The control amount calculation step includes an intake control amount calculation step for determining the control amount of the intake air regulator,
The intake control amount calculation step includes:
An intake base control amount calculation step for obtaining an intake base control amount that is a control amount of the intake regulator determined without being based on information indicating the upstream state;
An intake coefficient generation step of outputting a correction coefficient for correcting the intake base control amount according to the facility status received by the reception unit;
A correction step of correcting the intake base control amount using the correction coefficient output in the intake coefficient generation step;
including,
Control method of gas turbine equipment. In the control method of the gas turbine equipment according to any one of claims 13 to 16 ,
A plurality of gas compressors that increase the pressure of the boil-off gas in order to supply the boil-off gas to the gas turbine are provided as equipment upstream from the mixing location,
In the reception step, as the equipment status, an operation number of the plurality of gas compressors is received,
In the control amount calculation step, depending on稼働台speed of the gas compressor, defining said control amount of the control,
Control method of gas turbine equipment.

Images