Patent Application
20100058730
The present invention relates to a gas turbine power generation system and a method of detecting a calorific abnormality thereof.
An integrated coal gasification combined cycle (IGCC) system, which is a combination of a coal gasification furnace, a gas turbine facility, and a steam turbine facility, has been conventionally known (for example, see Patent Document 1).
In such an IGCC, the coal gasification furnace and the gas turbine are directly connected to each other through a gas purification facility. Consequently, the produced gas generated in the coal gasification furnace is directly used as fuel of the gas turbine, and therefore a calorific value variation occurring in the fuel gas generated in the coal gasification furnace appears directly as a variation of the output of the gas turbine.
Patent Document 1: Japanese Unexamined Patent Application, Publication No. Hei 6-288262
When a by-product gas is charged as fuel for a gas turbine, a calorimeter is provided in advance, and the range of variation of calorific value is determined based on detection values from this calorimeter. With this, a calorific abnormality is detected.
However, measurement devices such as the calorimeter are expensive and are therefore obstacles for reducing cost.
The present invention has been made for solving the above-mentioned problems, and it is an object thereof to provide an integrated coal gasification combined cycle system that can detect a variation in calorific value using existing measured values, without using a measuring device such as a calorimeter, and a method of detecting a calorific abnormality of the system.
In order to solve the above-mentioned problems, the present invention employs the following solutions.
A first aspect of the present invention is a method of detecting a calorific abnormality of a gas turbine power generation system including a step of defining an allowable variation range of a power generation output of a gas turbine with respect to a charged fuel amount or an allowable variation range of the charged fuel amount with respect to the power generation output of the gas turbine based on a charged fuel characteristic representing a relation between the fuel amount charged to a combustor of the gas turbine and the power generation output of the gas turbine at a target calorific value of fuel gas; and a step of detecting a calorific abnormality when an actually charged fuel amount or an actual power generation output of the gas turbine falls outside the allowable variation range.
In the gas turbine power generation system, when the fuel gas calorific value is set constant, there is a predetermined relation between the power generation output of the gas turbine and the fuel flow charged to a combustor. Therefore, using this relation, an allowable variation range of the fuel flow with respect to the power generation output of the gas turbine or an allowable variation range of the power generation output of the gas turbine with respect to the fuel flow is defined, which makes it possible to detect a calorific abnormality by determining whether an actually charged fuel amount or an actual power generation output of the gas turbine falls outside the allowable variation range or not.
According to such a method, a calorific abnormality is detected using measured values and the like that are used in existing systems. Consequently, a calorific abnormality can be detected with a simple configuration, without using a measuring device such as a calorimeter.
In the method of detecting a calorific abnormality of the gas turbine power generation system, a high-calorific-value abnormality may be detected when the actually charged fuel amount is lower than the lower limit value of the allowable variation range or the actual power generation output of the gas turbine is higher than the upper limit value of the allowable variation range in the process of detecting a calorific abnormality, and a low-calorific-value abnormality may be detected when the actually charged fuel amount is higher than the upper limit value of the allowable variation range or the actual power generation output of the gas turbine is lower than the lower limit value of the allowable variation range.
Since the low-calorific-value abnormality and the high-calorific-value abnormality are detected by whether or not an actually charged fuel amount or an actual power generation output of the gas turbine is lower than the lower limit value or higher than the upper limit value of the allowable variation range, respectively, the details of the calorific abnormality can be understood.
In the method of detecting a calorific abnormality of the gas turbine power generation system, the method may further include a step of reporting detection of a calorific abnormality when one is detected.
A second aspect of the present invention is a method of detecting a calorific abnormality of an integrated coal gasification combined cycle system including a step of defining, based on a relation between the amount of at least one of char, air, coal, and oxygen charged to a coal gasification furnace and a power generation output of a gas turbine, an allowable variation range of the power generation output of the gas turbine with respect to the charged amount or an allowable variation range of the charged amount with respect to the power generation output of the gas turbine; and a step of detecting a calorific abnormality when an actually charged amount or an actual power generation output of the gas turbine falls outside the allowable variation range.
In the coal gasification of the IGCC, in order to adjust the fuel gas calorific value to a target calorific value, the flow rates of char, air, coal, and oxygen charged to the gasification furnace are each controlled by feedback. When it is assumed that the calorific value of fuel gas thus generated is in agreement with a target calorific value, there is a predetermined relation between a flow rate of char, air, coal, and oxygen charged to the coal gasification furnace and a power generation output of gas turbine. Therefore, a calorific abnormality of fuel gas can be easily detected by detecting a disruption in the relation (balance) between the flow rate of at least one of the elements and the power generation output of the gas turbine. Thus, a calorific abnormality is detected using measured values and the like that are used in existing IGCCs. Consequently, a calorific abnormality of fuel gas can be easily detected by calculation, without using a measuring device such as a calorimeter.
A third aspect of the present invention is a method of detecting a calorific abnormality of an integrated coal gasification combined cycle system, wherein a difference between a target charging amount and an actually charged amount of at least one of char, air, coal, and oxygen to be charged to a coal gasification furnace is calculated, and a calorific abnormality is detected when the difference falls outside a previously determined allowable variation range.
In the IGCC, in order to adjust the calorific value of fuel gas in the coal gasification furnace to a target calorific value, the charged amounts of coal, oxygen, char, and air are controlled by feedback. On this occasion, the fuel gas calorific value varies when the actual flow rate of charged coal, oxygen, char, or air deviates from the respective target charging amounts by a predetermined value or more.
Accordingly, a calorific abnormality can be easily detected by determining a difference between a target flow rate of at least one of the variation factors and an actual flow rate and determining whether this difference falls outside a previously determined appropriate range or not.
In this case, a calorific abnormality is detected using measured values and the like that are used in existing IGCCs. Consequently, a calorific abnormality of fuel gas can be easily detected by calculation, without using a measuring device such as a calorimeter.
In the method of detecting a calorific abnormality of the above-mentioned integrated coal gasification combined cycle system, the method may further include a step of reporting detection of a calorific abnormality when one is detected.
A fourth aspect of the present invention is a gas turbine power generation system having a calorific abnormality detection device that defines an allowable variation range of a power generation output of a gas turbine with respect to a charged fuel amount or an allowable variation range of the charged fuel amount with respect to the power generation output of the gas turbine based on a charged fuel characteristic representing a relation between the fuel amount charged to a combustor of the gas turbine and the power generation output of the gas turbine at a target calorific value of fuel gas, and detects a calorific abnormality when an actually charged fuel amount or an actual power generation output of the gas turbine falls outside the allowable variation range.
A fifth aspect of the present invention is an integrated coal gasification combined cycle system having a calorific abnormality detection device that defines, based on a relation between the charged amount of at least one of char, air, coal, and oxygen charged to a coal gasification furnace and a power generation output of a gas turbine, an allowable variation range of the power generation output of the gas turbine with respect to the charged amount or an allowable variation range of the charged amount with respect to the power generation output of the gas turbine, and that detects a calorific abnormality when an actually charged amount or an actual power generation output of the gas turbine falls outside the allowable variation range.
A sixth aspect of the present invention is an integrated coal gasification combined cycle system having a calorific abnormality detection device that calculates a difference between a target charging amount and an actually charged amount of at least one of char, air, coal, and oxygen to be charged to a coal gasification furnace, and that detects a calorific abnormality when the difference falls outside a previously determined allowable variation range.
In addition, the above-described aspects can be used in any combination that is possible.
The present invention provides an advantage in that a variation in calorific value can be detected using existing measured values, without using a measuring device such as a calorimeter.
An integrated coal gasification combined cycle system according to a first embodiment of the present invention will be described with reference to
As shown in
A coal supplying facility 10 for supplying powdered coal to the coal gasification furnace 3 is disposed upstream of the coal gasification furnace 3. This coal supplying facility 10 includes a pulverizer (not shown) for pulverizing coal as raw material to powdered coal of several micrometers to several hundred micrometers in size. The powdered coal pulverized by this pulverizer is reserved in a plurality of hoppers 11.
The powdered coal reserved in each hopper 11 is fed to the coal gasification furnace 3 together with nitrogen supplied from an air separation device 15 at a predetermined flow rate.
The coal gasification furnace 3 includes a coal gasification portion 3a formed such that gas is forced to flow from the lower side to the upper side and a heat exchanging portion 3b connected downstream of the coal gasification portion 3a and formed such that gas is forced to flow from the upper side to the lower side.
The coal gasification portion 3a is provided with, from the lower side, a combustor 13 and a reductor 14. The combustor 13 is a portion for burning parts of powdered coal and char and thermally decomposing the residues and releasing them as volatile materials (CO, H2, and lower hydrocarbons). The combustor 13 employs an entrained bed, but may be a fluidized-bed type or a fixed-bed type.
The combustor 13 and the reductor 14 are provided with a combustor burner 13a and a reductor burner 14a, respectively. These burners 13a and 14a are supplied with powdered coal from the coal supplying facility 10.
The combustor burner 13a is configured to be supplied with air from an air pressure-raising device 17 together with oxygen separated in an air separator 15, as a gasifying agent. Thus, the combustor burner 13a is supplied with air whose oxygen content is regulated.
In the reductor 14, powdered coal is gasified by the high-temperature combustion gas from the combustor 13. With this, combustible gas serving as gas fuel such as CO or H2 is generated from coal. The coal gasification reaction is an endothermic reaction generating CO or H2 by the reaction of carbon in the powdered coal and char with CO2 and H2O in the high-temperature gas.
A plurality of heat exchangers (not shown) are installed in the heat exchanging portion 3b of the coal gasification furnace 3 to generate steam by obtaining sensible heat from the gas introduced from the reductor 14. The steam generated in the heat exchangers is mainly used for driving a steam turbine 7b. The gas passed through the heat exchanging portion 3b is introduced to a char-recovery device 20. This char-recovery device 20 includes a porous filter, and char mixed in the gas is recovered by being trapped by the filter when the gas passes through. The trapped char deposits in the porous filter and forms a char layer. In the char layer, Na and K contained in the gas are condensed, and, as a result, Na and K are also removed in the char-recovery device 20.
The thus recovered char is sent back to the combustor burner 13a of the coal gasification furnace 3 for reuse together with nitrogen separated in the air separation device 15. Na and K sent back to the combustor burner 13a together with the char are finally discharged from the lower side of the coal gasification portion 3a together with cinders of melted powdered coal. The melted and discharged cinders are quenched with water and crushed into glass-like slag. The piping for transferring nitrogen outputted from the air separation device 15 is provided with a regulation valve 61 for regulating the amount of nitrogen supplied to the combustor burner 13a. Furthermore, the piping for transferring char is provided with a flow rate gauge 62 detecting the flow rate of the char.
The gas passed through the char-recovery device 20 is sent to a combustor 5a of the gas turbine facility 5 as fuel gas via a gas purification facility 24 which is a facility for dedusting and desulfurization.
The gas turbine facility 5 includes the combustor 5a for burning gasified fuel, a gas turbine 5b driven by the fuel gas, and a turbo compressor 5c for supplying high-pressure air to the combustor 5a. The gas turbine 5b and the turbo compressor 5c are connected to each other via a rotary shaft 5d. Air compressed in the turbo compressor 5c is also introduced to the air pressure-raising device 17, aside from the combustor 5a.
The combustion exhaust gas passed through the steam gas turbine 5b is introduced to the exhaust heat recovery boiler 30.
The steam turbine 7b of the steam turbine facility 7 is connected to the same rotary shaft 5d as that of the gas turbine facility 5 to configure a so-called single-shaft combined system. The steam turbine 7b is supplied with high-pressure steam from the coal gasification furnace 3 and the exhaust heat recovery boiler 30. It is not limited to a single-shaft combined system; a separate-shaft combined system may also be employed.
A generator G outputting electricity from the rotary shaft 5d driven by the gas turbine 5b and the steam turbine 7b is disposed at the opposite side of the gas turbine facility 5, with the steam turbine facility 7 therebetween. The arrangement position of the generator is not limited to this position and may be any position that allows obtaining power generation output from the rotary shaft 5d.
The exhaust heat recovery boiler 30 generates steam with the combustion exhaust gas from the gas turbine 5b and also releases the combustion exhaust gas to the atmosphere from a chimney 35.
The operation of the integrated coal gasification combined cycle system 1 with the above-mentioned configuration will be described.
Coal as raw material is pulverized with a pulverizer (not shown) and is introduced to the hoppers 11 and reserved. The powdered coal reserved in the hoppers 11 is supplied to the reductor burner 14a and the combustor burner 13a together with nitrogen separated in the air separation device 15. Furthermore, the combustor burner 13a is supplied with not only powdered coal but also char recovered in the char-recovery device 20.
Air that is prepared by further raising the pressure of compressed air bled from the turbo compressor 5c of the gas turbine facility 5 with the air pressure-raising device 17 and adding oxygen separated in the air separation device 15 to the resulting pressure-raised air is used as the combustion gas of the combustor burner 13a. In the combustor 13, powdered coal and char are partially burned with the combustion air, and the residue is thermally decomposed to volatile materials (CO, H2, and lower hydrocarbons).
In the reductor 14, powdered coal that is supplied from the reductor burner 14a and char that has released volatile materials in the combustor 13 are gasified by high-temperature gas rising from the combustor 13 to generate combustible gas such as CO or H2.
The gas passed through the reductor 14 gives sensible heat to the heat exchangers while passing through the heat exchanging portion 3b of the coal gasification furnace 3 and generates steam. The steam generated in the heat exchanging portion 3b is mainly used for driving the steam turbine 7b.
The gas passed through the heat exchanging portion 3b is introduced to the char-recovery device 20 for recovering char. Na and K in the gas are condensed here and taken into char. The char containing the Na and the K is sent back to the coal gasification furnace 3.
The gas passed through the char-recovery device 20 is introduced to the combustor 5a of the gas turbine facility 5 and is burned together with the compressed air supplied from the turbo compressor 5c. With this combustion gas, the gas turbine 5b is rotated, and the rotary shaft 5b is driven.
The combustion exhaust gas passed through the gas turbine 5b is introduced to the exhaust heat recovery boiler 30, and steam is generated using the sensible heat of this combustion exhaust gas. The steam generated in the exhaust heat recovery boiler 30 is mainly used for driving the steam turbine 7b.
The steam turbine 7b is rotated by steam from the coal gasification furnace 3 and steam from the exhaust heat recovery boiler 30 and drives the same rotary shaft 5b as that of the gas turbine facility 5. The torque of the rotary shaft 5b is converted to power generation output by the generator G.
General control of fuel flow of the gas turbine facility in the above-described IGCC will be described with reference to
As shown in
A BPT (Blade Path Temperature) sensor 42 for measuring the exhaust gas temperature of the gas turbine 5b (hereinafter, referred to as “blade path temperature”) is disposed near the gas turbine 5b. In addition, an EXT sensor 43 for measuring the exhaust gas temperature at a ventilation duct (hereinafter, referred to as “exhaust gas temperature”) is disposed in the exhaust gas channel where the BPT sensor 42 is disposed at the further downstream side of the BPT sensor 42. These sensors may be used, for example, thermocouples. The temperature measured with the BPT sensor 42 and the EXT sensor 43 is given to the fuel flow control device 50.
The fuel flow control device 50 acquires state quantities relating to an operation state and a temperature state of the gas turbine as input signals and calculates a fuel flow command for controlling the fuel flow supplied to the combustor 5a based on these input signals. The above-mentioned state quantities relating to the operation state are, for example, an output of the generator G (see
The fuel flow control device 50 is configured by including, for example, a load limit control circuit 51, a temperature limit control circuit 52, a governor control circuit 53, and a low value selection circuit 54.
The load limit control circuit 51 acquires, for example, the power generation output as an input signal and calculates a load control signal controlling the fuel flow such that the power generation output coincides with a target value.
The temperature limit control circuit 52 acquires the blade path temperature BPT and the exhaust gas temperature EXT of the gas turbine 3 as input signals and calculates temperature control signals controlling fuel flows such that these temperatures do not exceed the respective temperature upper limits.
The governor control circuit 53 acquires the rotation velocity or rotation frequency of the gas turbine 3 as an input signal and calculates a governor control signal controlling a fuel flow such that the rotation velocity or rotation frequency of the gas turbine 3 coincides with a target value.
All of the control signals calculated by the load limit control circuit 51, the temperature limit control circuit 52, and the governor control circuit 53 are given to the low value selection circuit 54. The low value selection circuit 54 selects a control signal with the lowest value among these control signals and outputs the selected control signal as a fuel control signal CSO.
The fuel control signal CSO thus obtained by the fuel flow control device 50 is given to the fuel flow regulation valve 40, and the degree of opening of the fuel flow regulation valve 40 is regulated based on this fuel control signal CSO, followed by supplying fuel to the combustor 5a at an optimum flow rate.
A method of detecting a calorific abnormality of the IGCC according to this embodiment will be described.
First, in the calorific-value control of fuel gas of the IGCC, a target calorific value is set, and charging amounts of char, oxygen, coal, and air charged to the coal gasification furnace are controlled such that fuel gas with the target calorific value is generated. When it is assumed that the calorific value of fuel gas charged to the combustor 5a coincides with the target calorific value, there is a relation as shown in
In
In
Furthermore, in
In the IGCC, when the fuel gas calorific value is decreased lower than a target calorific value, since a desired power generation output of the gas turbine is not obtained even if the fuel gas is charged to the combustor 5a at a target flow rate obtained from the gas turbine power generation output, the fuel flow is increased to deviate upward from the allowable variation range shown in
With such a relation, in this embodiment, information about the fuel amount actually charged to the combustor 5a, such as a fuel control signal CSO, is monitored, and when a relation of this fuel control signal CSO with the gas turbine power generation output at that time falls outside the allowable variation range shown in
As shown in
As has been described above, in the IGCC and the method of detecting a calorific abnormality according to this embodiment, since a calorific abnormality is detected using existing control amounts, calorimeters are unnecessary, resulting in a decrease in cost.
An IGCC according to a second embodiment of the present invention and a method of detecting a calorific abnormality thereof will be described.
In the coal gasification furnace 3 of the IGCC, in order to adjust the calorific value of fuel gas to a target calorific value, the flow rate of each element, such as char, air, coal, and oxygen, that is charged to the coal gasification furnace 3 is controlled by feedback. Accordingly, if these flow rates deviate from the respective target flow rates, the calorific value of the fuel gas varies.
Specifically, in char, coal, and oxygen, the fuel gas calorific value increases when the flow rate is larger than a target flow rate. On the other hand, in air, the fuel gas calorific value decreases when the flow rate is larger than a target flow rate.
Consequently, in the second embodiment, a calorific abnormality is detected based on the charging amounts of calorific-value variation factors of char, air, coal, and oxygen, etc.
A case where a calorific abnormality is detected based on a charged char amount will be described.
In the calorific-value control of fuel gas in the IGCC, a target calorific value is determined, and the charging char amount is controlled so that the target calorific value is achieved. When it is assumed that the calorific value of fuel gas charged to the combustor 5a coincides with the target calorific value, there is a relation as shown in
In
The charged char amount can be detected with, for example, a flow rate gauge 62 (see
When the char amount charged to the coal gasification furnace 3 is decreased to a level lower than a target charging amount due to clogging of, for example, the piping for transferring char to the coal gasification furnace 3, the calorific value of the fuel gas is decreased. Therefore, even if a predetermined amount of fuel is charged to the combustor 5a, the corresponding desired power generation output of the gas turbine is not achieved, resulting in an increase of the charging fuel amount. Accordingly, in this case, a downward deviation from the allowable variation range shown in
For this reason, in the detection of a calorific abnormality of fuel gas, when the relation between the char amount charged to the coal gasification furnace 3 and the power generation output of the gas turbine falls outside the allowable variation range shown in
As shown in
One factor that causes a variation in the calorific value of fuel gas generated in the coal gasification furnace 3 is an irregular ratio of charging fuel (coal) to air (including oxygen). If the calorific value of fuel gas generated in the coal gasification furnace 3 is as planned, the ratio of the fuel and the air (hereinafter, referred to as “air ratio”) has a predetermined relation as shown in
In
When the coal amount charged to the coal gasification furnace 3 is decreased or when the air flow rate is increased, the calorific value of fuel gas is decreased, and an upward deviation from the allowable variation range shown in
For this reason, in the detection of a calorific abnormality of fuel gas, when a relation between the fuel amount charged to the coal gasification furnace 3 and the air flow rate falls outside the allowable variation range shown in
As shown in
In the above, an allowable variation range of the air flow rate with respect to the charged coal amount is determined by plotting charged coal amounts on the horizontal axis and air flow rates on the vertical axis, and a calorific abnormality is detected by whether an actual air flow rate falls inside this allowable variation range or not. However, as shown in
Thus, since a calorific abnormality is detected from a relation between the air flow rate and the charged coal amount, the calorific abnormality can be detected at an early stage with a simple configuration.
In the IGCC, in order to adjust the calorific value of fuel gas in the coal gasification furnace to a target calorific value, the charging coal amount is controlled by feedback. In this occasion, the calorific value of fuel gas is increased when the flow rate of actually charged coal (hereinafter, referred to as “actual charged coal amount”) is larger than a target charging amount (hereinafter, referred to as “target charging coal amount”), and is decreased when the actual amount is smaller than the target amount.
For this reason, a variation in calorific value is detected when a difference between the target charging coal amount and the actual charged coal amount falls outside the allowable variation range.
This makes it possible to detect a calorific abnormality at an early stage with a simple configuration, from a predetermined relation between the actual charged coal amount and the target charging coal amount.
As shown in
Here, the threshold ε9 is set to the lower limit value of the allowable variation range of the difference, and the threshold ε10 is set to the upper limit value of the allowable variation range of the difference.
In the IGCC, in order to adjust the calorific value of fuel gas in the coal gasification furnace to a target calorific value, the air flow rate is controlled by feedback. On this occasion, the calorific value of fuel gas is decreased when the flow rate of actually charged air (hereinafter, referred to as “actual air flow rate”) is larger than a target air flow rate, and is increased when the actual rate is smaller than the target rate.
For this reason, a variation in calorific value is detected when a difference between the target air flow rate and the actual air flow rate falls outside the allowable variation range.
This makes it possible to detect a calorific abnormality at an early stage with a simple configuration, from a predetermined relation between the air flow rate and the target air flow rate.
As shown in
In the IGCC, in order to adjust the calorific value of fuel gas in the coal gasification furnace to a target calorific value, the oxygen flow rate is controlled by feedback. On this occasion, the calorific value of fuel gas is decreased when the flow rate of actually charged oxygen (hereinafter, referred to as “actual oxygen flow rate”) is larger than a target oxygen flow rate, and is increased when the actual rate is smaller than the target rate.
For this reason, a variation in calorific value is detected when a difference between the target oxygen flow rate and the actual oxygen flow rate falls outside the allowable variation range.
This makes it possible to detect a calorific abnormality at an early stage with a simple configuration, from a predetermined relation between the oxygen flow rate and the target oxygen flow rate.
As shown in
In the IGCC, in order to adjust the calorific value of fuel gas in the coal gasification furnace to a target calorific value, the charging amount of char is controlled by feedback. In this occasion, the calorific value of fuel gas is increased when the flow rate of actually charged char (hereinafter, referred to as “actual charged char amount”) is larger than a target charging char amount, and is decreased when the actual charged amount is smaller than the target amount.
For this reason, a variation in calorific value is detected when a difference between the target charging char amount and the actual charged char amount falls outside the allowable variation range.
This makes it possible to detect a calorific abnormality at an early stage with a simple configuration, from a predetermined relation between the actual charged char amount and the target charging char amount.
As shown in
Here, the threshold ε15 is set to the lower limit value of the allowable variation range of the difference, and the threshold ε16 is set to the upper limit value of the allowable variation range of the difference.
As has been described above, according to the IGCC and the method of detecting a calorific abnormality according to this embodiment, a calorific abnormality is detected using existing control amounts, and therefore calorimeters are unnecessary, resulting in a decrease in cost.
In each of the above-described embodiments, it is possible to employ a configuration such that when a calorific abnormality is detected, for example, a system operator of the IGCC is informed. Informing means may be visual informing means by, for example, displaying the abnormality on a screen or lighting a lamp or audible informing means for informing the abnormality with sound, such as a buzzer or message.
In the method of detecting a calorific abnormality according to each of the above-described embodiments, when a parameter falls outside an allowable variation range, a calorific abnormality is reported. However, it may be detected whether the parameter deviates downward or upward from the allowable variation range. Furthermore, the result thereof may be reported.
Specifically, for example, in the calorific abnormality detection device shown in
| Number | Date | Country | Kind |
|---|---|---|---|
| 2006-305325 | Nov 2006 | JP | national |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/JP2007/071840 | 11/9/2007 | WO | 00 | 10/26/2009 |
