Patent Application
20140338362
The present invention relates to a gas-turbine cooling system and a gas-turbine cooling method with which a gas turbine is cooled by steam generated in an exhaust-heat recovery boiler.
Exhaust-heat recovery boilers provided in Gas-Turbine Combined Cycles (GTCC) and Integrated coal Gasification Combined Cycles (IGCC) generate steam for driving steam turbines by utilizing exhaust heat from gas turbines. Because gas turbines that achieve high-efficiency are subjected to high temperatures, from the viewpoint of equipment protection, it is necessary to cool transition pieces of gas-turbine combustors and other portions that reach high temperatures under unit operation. Thus, in order to cool gas turbines in the above-described power generation systems, not only is air used as a cooling medium but also steam generated in exhaust-heat recovery boilers is sometimes used as a cooling medium.
Patent Literature 1 discloses a technology with which, when an abnormality occurs during operation, cooling by steam is maintained by guiding high-pressure steam or medium-pressure steam from an exhaust-heat recovery boiler to a steam cooling system.
Patent Literature 2 discloses a technology that achieves both cooling control of high-temperature components, such as a combustor or the like, by means of steam and clearance control between rotor blades and a blade ring portion by means of steam.
{PTL 1} Japanese Unexamined Patent Application, Publication No. Hei 10-37711
{PTL 2} Japanese Unexamined Patent Application, Publication No. 2002-4807
Because medium-pressure steam of about 4.0 MPa to 5.0 MPa generated in an exhaust-heat recovery boiler satisfies the required cooling conditions of an object to be cooled (gas turbine), medium-pressure steam is used in many cases when steam generated in an exhaust-heat recovery boiler is used as a cooling medium.
On the other hand, because there is a demand to increase the flow of high-pressure steam generated in an exhaust-heat recovery boiler in order to improve the plant efficiency, it is necessary to keep the difference between the flow of the medium-pressure steam generated in the exhaust-heat recovery boiler and the flow of steam required for use in cooling the object to be cooled (gas turbine) as small as possible. Consequently, however, the medium-pressure steam flow may possibly be insufficient relative to the required steam flow for the object to be cooled, depending on the power generation load and fuel conditions.
Thus, it is conceivable to use a portion of the high-pressure steam generated in the exhaust-heat recovery boiler as a cooling medium; however, this involves additional processes of decreasing the temperature and pressure of the high-temperature, high-pressure steam, and thus, the plant efficiency may be deteriorated.
The present invention has been conceived in light of the above-described circumstances, and the present invention provides a gas-turbine cooling system and a gas-turbine cooling method with which a gas turbine can efficiently be cooled by using steam, without using high-pressure steam generated in an exhaust-heat recovery boiler and without decreasing the high-pressure steam generation.
In order to solve the above-described problems, a gas-turbine cooling system and a gas-turbine cooling method of the present invention employ the following solutions.
A gas-turbine cooling system according to a first aspect of the present invention includes a gas turbine; an exhaust-heat recovery boiler having a first system that generates first steam by means of heat exchange with exhaust heat from the gas turbine, a first drum that supplies water and steam to the first system, a second system that generates second steam having lower pressure than the first steam by means of heat exchange with the exhaust heat from the gas turbine, and a second drum that supplies water and steam to the second system; a first flow channel that connects the second system and a cooling system of the gas turbine and that supplies the second steam from the second system to the cooling system; and a second flow channel that connects the first drum and the second drum and that supplies saturated steam in the first drum from the first drum to the second drum.
With the gas-turbine cooling system according to the above-described first aspect, the water and steam in the second drum are supplied to the second system of the exhaust-heat recovery boiler, and the second steam is generated in the second system by means of heat exchange with the exhaust heat from the gas turbine. The second steam is supplied from the second system to the cooling system of the gas turbine via the first flow channel, thus cooling the gas turbine. In addition, the saturated steam in the first drum is supplied from the first drum to the second drum via the second flow channel. As a result, because the steam flow of the steam supplied from the second drum to the second system can be increased, the steam flow of the steam supplied from the second system to the cooling system of the gas turbine can also be increased.
The gas-turbine cooling system according to the above-described first aspect may have a configuration additionally including a steam-flow adjusting means for adjusting a steam flow of the saturated steam flow in the second flow channel based on a cooling state of the gas turbine.
With this configuration, because the steam flow of the saturated steam supplied from the first drum to the second drum via the second flow channel is changed in accordance with the cooling state of the gas turbine, it is possible to supply the saturated steam to the second drum in an appropriate flow for cooling the gas turbine. The outlet temperature of the gas turbine may be monitored and managed at the gas turbine, and the cooling situation of the gas turbine may indirectly be judged based on, for example, the steam flow or the like of steam exhausted from the cooling system of the gas turbine after cooling the gas turbine.
The gas-turbine cooling system according to the above-described first aspect may have a configuration including a gas-liquid separator that is provided so as to be downstream of the second flow channel and also so as to be upstream of the second drum or inside the second drum.
With this configuration, because the saturated steam supplied from the first drum to the second drum via the second flow channel is separated into water and steam by the gas-liquid separator, the separated steam can be supplied to the gas turbine cooling system, and thus, the gas turbine can be cooled by using steam that does not contain water. As a result, it is possible to prevent corrosion and erosion of the cooling system caused by steam containing water. In addition, because the water level in the second drum does not increase in a short period of time due to condensation of the steam, it is possible to suppress water-level fluctuations in the second drum.
A gas-turbine cooling method according to a second aspect of the present invention is a gas-turbine cooling method for a gas-turbine cooling system provided with a gas turbine; and an exhaust-heat recovery boiler having a first system that generates first steam by means of heat exchange with exhaust heat from the gas turbine, a first drum that supplies water and steam to the first system, a second system that generates second steam having lower pressure than the first steam by means of heat exchange with the exhaust heat from the gas turbine, and a second drum that supplies water and steam to the second system, the gas-turbine cooling method including a step of supplying the second steam from the second system to a cooling system of the gas turbine; and a step of supplying saturated steam in the first drum from the first drum to the second drum.
With the gas-turbine cooling method according to the above-described second aspect, a gas turbine can efficiently be cooled by using steam, without using high-pressure steam generated in an exhaust-heat recovery boiler and without decreasing quantity of generated high-pressure steam.
An embodiment according to the present invention will be described below with reference to the drawings.
An exhaust-heat recovery system and a gas-turbine cooling system according to the embodiment of the present invention are employed in a plant 1, for example, a Gas-Turbine Combined Cycle (GTCC), an Integrated coal Gasification Combined Cycle (IGCC), and so forth, having an exhaust-heat recovery boiler 2 and a gas turbine 3.
The gas-turbine cooling system is constituted of, for example, the exhaust-heat recovery boiler 2, the gas turbine 3, a medium-pressure steam pipe 19 (first flow channel) that supplies medium-pressure steam from a medium-pressure system 7 of the exhaust-heat recovery boiler 2 to the gas turbine 3, a steam supplying pipe 20 (second flow channel) that supplies saturated steam from a high-pressure drum 11 to a medium-pressure drum 12, and so forth.
Exhaust gas exhausted from the gas turbine 3 is supplied to the exhaust-heat recovery boiler 2 via an exhaust-gas supply channel 14. Then, the exhaust-heat recovery boiler 2 generates steam by means of heat exchange with heat of the exhaust gas (exhaust heat). As shown in
In the exhaust-heat recovery boiler 2, the reheating system 5, the high-pressure system 6, the medium-pressure system 7, and the low-pressure system 8 are sequentially disposed along the flow direction of the exhaust gas. The reheating system 5 includes a reheater, and steam extracted from a steam turbine 4 is supplied to the reheating system 5 via a cold reheat steam pipe 15 to be heated by the reheater of the reheating system 5. The steam heated at the reheating system 5 is supplied to the steam turbine 4 via a hot reheat steam pipe 16 and drives the steam turbine 4.
The high-pressure system 6 includes a high-pressure superheater and a high-pressure evaporator, and water from the high-pressure drum 11 is supplied to the high-pressure evaporator of the high-pressure system 6. The water supplied from the high-pressure drum 11 is heated by the high-pressure evaporator of the high-pressure system 6, thus generating steam. The generated steam is heated by the high-pressure superheater, thus generating high-pressure steam. The generated high-pressure steam is supplied to the steam turbine 4 via a high-pressure steam pipe 17 and drives the steam turbine 4.
The low-pressure system 8 includes a low-pressure evaporator and a low-pressure superheater, and water from the low-pressure drum 13 is supplied to the low-pressure evaporator of the low-pressure system 8. The water supplied from the low-pressure drum 13 is heated by the low-pressure evaporator of the low-pressure system 8, thus generating steam. The generated steam is superheated by the low-pressure superheater, thus generating low-pressure steam. The generated low-pressure steam is supplied to the steam turbine 4 via a low-pressure steam pipe 18 and drives the steam turbine 4.
The medium-pressure system 7 includes a medium-pressure evaporator and a medium-pressure superheater, and water from the medium-pressure drum 12 is supplied to the medium-pressure evaporator of the medium-pressure system 7. The water supplied from the medium-pressure drum 12 is heated by the medium-pressure evaporator of the medium-pressure system 7, thus generating steam. The generated steam is superheated by the medium-pressure superheater, thus generating medium-pressure steam. The entire flow or a portion of the generated medium-pressure steam is supplied to a cooling system of the gas turbine 3 via a medium-pressure steam pipe 19 and cools relevant portions. The cooling system of the gas turbine 3 is provided at, for example, high-temperature portions such as a tailpipe, a housing, and so forth of a combustor provided in the gas turbine 3. The required steam flow of the medium-pressure steam to be supplied from the medium-pressure drum 12 to the gas turbine 3 via the medium-pressure steam pipe 19 is adjusted based on the cooling state of the gas turbine 3. A control valve 25 is provided in the medium-pressure steam pipe 19, and the steam flow is adjusted therewith.
The outlet temperature of the gas turbine 3 is monitored and managed at the gas turbine 3, and the cooling state of the gas turbine 3 is indirectly judged based on, for example, the steam flow, temperature, pressure, and so forth of steam exhausted from the cooling system of the gas turbine 3 after cooling the gas turbine 3. For example, when the gas turbine 3 is judged to be insufficiently cooled, the control valve 25 is adjusted toward the open side, thus increasing the steam flow of the medium-pressure steam to be supplied to the cooling system of the gas turbine 3. On the other hand, when the gas turbine 3 is judged to be excessively cooled, the control valve 25 is adjusted toward the closed side, thus decreasing the steam flow of the medium-pressure steam.
The saturated steam is supplied from the high-pressure drum 11 to the medium-pressure drum 12 through the steam supplying pipe 20. In the case in which it is judged that the medium-pressure steam generated at the medium-pressure system 7 based on the water supplied from the medium-pressure drum 12 alone is insufficient relative to the steam flow required to cool the gas turbine 3, the saturated steam is supplied from the high-pressure drum 11 to the medium-pressure drum 12 via the steam supplying pipe 20. By doing so, the medium-pressure steam supplied to the cooling system of the gas turbine 3 can be supplemented with the steam supplied from the high-pressure drum 11 to the medium-pressure drum 12.
The steam used to cool the gas turbine 3 is, for example, supplied to the high-temperature reheat steam pipe 16 to be reused in driving the steam turbine 4.
With the gas turbine 3, a turbine is driven by combusting fuel gas, a main shaft coupled with a generator is rotated together with the turbine, and thus, the generator is driven and generates power. The fuel gas combusted in the gas turbine 3 is exhausted as exhaust gas. Because the gas turbine 3 reaches a high temperature due to the combustion of the fuel gas, the gas turbine 3 is cooled by a cooling medium in order to reduce the influence of the heat. As the cooling medium, for example, the steam generated in the exhaust-heat recovery boiler 2 is used.
With the steam turbine 4, the steam generated in the exhaust-heat recovery boiler 2 is supplied to drive the turbine. A main shaft of the steam turbine 4 is coupled with a generator and is rotated together with the turbine, and thus, the generator is driven and generates power. Note that, with regard to the generator, one generator may be coupled both with the gas turbine 3 and the steam turbine 4, or different generators may individually be coupled with the gas turbine 3 and the steam turbine 4.
In an example shown in
Next, the gas-turbine cooling system according to this embodiment will be described with reference to
In this embodiment, the steam supplying pipe 20 that connects the high-pressure drum 11 (first drum) and the medium-pressure drum 12 (second drum) is provided. As shown in
The control valve 21 of the steam supplying pipe 20 is opened and closed in accordance with instructions from the control valve 25 of the medium-pressure steam pipe 19. When cooling the gas turbine 3, in the case in which the steam generated at the medium-pressure system 7 is insufficient, the saturated steam in the high-pressure drum 11 is supplied to the medium-pressure drum 12 via the steam supplying pipe 20. The steam flow of the saturated steam to be supplied from the high-pressure drum 11 to the medium-pressure drum 12 is determined based on a steam flow flowing in the medium-pressure steam pipe 19.
For example, in the case in which it is judged that the medium-pressure steam generated at the medium-pressure system 7 based on the water supplied from the medium-pressure drum 12 alone is insufficient relative to the steam flow required to cool the gas turbine 3, the control valve 21 is adjusted toward the open side, thus increasing the steam flow of the saturated steam. On the other hand, when the gas turbine 3 is judged to be excessively cooled, the control valve 21 is adjusted toward the closed side, thus decreasing the steam flow of the saturated steam.
The flow flow meter 22 is provided in the steam supplying pipe 20 and measures the steam flow of the saturated steam flow in the steam supplying pipe 20. The orifice 23 is provided at a subsequent stage of the control valve 21 in the steam supplying pipe 20. With the orifice 23, it is possible to suppress a sudden decrease in the pressure at the control valve 21, and it is possible to decrease saturated water colliding with the control valve 21 due to the steam flow in the steam supplying pipe 20. As a result, it is possible to prevent breakage and corrosion of the control valve 21. Note that, in order to prevent trouble caused by water generated when decreasing the pressure of the saturated steam at the orifice 23, a baffle plate may be provided in a subsequent stage of the orifice 23.
The gas-liquid separator 24 is provided so as to be positioned downstream of the steam supplying pipe 20 and also so as to be upstream of the medium-pressure drum 12 or inside the medium-pressure drum 12. The gas-liquid separator 24 separates liquid and steam from the saturated steam flow in the steam supplying pipe 20. The steam/water separator 24 may employ any system, such as a system in which steam and liquid are separated by making a fluid pass through a metallic mesh or a corrugated plate, a system in which steam and liquid are separated by utilizing centrifugal force, and so forth. The steam obtained by the separation is directly supplied to the medium-pressure system 7 without modification, and the liquid obtained by the separation is temporarily stored in the medium-pressure drum 12.
In the case in which the gas-liquid separator 24 is not provided, a portion of the saturated steam supplied via the steam supplying pipe 20 condenses in the medium-pressure drum 12, and, consequently, in the worst conditions, there is a risk of the water level in the medium-pressure drum 12 suddenly increasing, depending on the supplied flow of the saturated steam. On the other hand, by providing the gas-liquid separator 24, the water level in the medium-pressure drum 12 is affected only by the liquid separated by the gas-liquid separator 24. Therefore, it is possible to minimize water-level fluctuations in the medium-pressure drum 12.
In addition, although the water level in the medium-pressure drum 12 is normally regulated by three factors (water level, supply water flow, and generated steam flow), in this embodiment, by measuring the steam flow of the saturated steam supplied from the high-pressure drum 11 to the medium-pressure drum 12, the same drum-water-level control as has normally been done can be performed for both the high-pressure drum 11 and the medium-pressure drum 12. In addition, as described above, because it is possible to minimize the water-level fluctuations in the medium-pressure drum 12 by providing the gas-liquid separator 24 upstream of the medium-pressure drum 12 or inside the medium-pressure drum 12, it is also possible to minimize operational fluctuations of the medium-pressure drum 12, caused by whether or not the saturated steam is supplied to the medium-pressure drum 12.
The operational effects of this embodiment will be described below.
In order to increase the total steam flow to be supplied to the cooling system of the gas turbine 3, it is conceivable to use, unlike this embodiment, the high-pressure steam generated at the high-pressure system 6, as in a plant 10 of a related art shown in
In addition, it is also conceivable to extract low-temperature saturated steam from the high-pressure drum 11 and to use it as cooling water for the gas turbine 3, instead of using the steam from the high-pressure system 6, which requires the temperature-decreasing process. However, saturated water is generated after extracting the saturated steam from the high-pressure drum 11 and decreasing the pressure thereof, and this generated water may cause damage to equipment and piping in the subsequent stages thereof, and thus, it is difficult to employ this method.
On the other hand, with this embodiment, the saturated steam from the high-pressure drum 11 is supplied to the medium-pressure drum 12 after decreasing the pressure thereof, and gas-liquid separation is performed in the medium-pressure drum 12. Then, the medium-pressure steam is used as the cooling steam for the gas turbine without changing the control of the medium-pressure drum 12 itself from the conventional method. At this time, the steam for cooling the gas turbine 3 can be increased without employing a design in which the high-pressure steam flow is suppressed and the medium-pressure steam flow is increased. Therefore, it is possible to provide an economical exhaust-heat recovery boiler 2 by increasing the medium-pressure steam flow and without having to suppress the high-pressure steam flow, whose contribution to the plant performance is high. In addition, because droplets and water in the form of mist contained in the cooling steam can be decreased, it is possible to avoid trouble such as heat shock and so forth in a transition piece of the cooling system and so forth, which are subjected to a high heat load. Note that, in this embodiment, although a case in which the high-pressure drum 11 and the medium-pressure drum 12 are connected, the saturated steam is supplied from the high-pressure drum 11 to the medium-pressure drum 12, and the steam flow generated at the medium-pressure system 7 is increased by using that steam has been described, the present invention is not limited to this example. For example, the present invention can also be employed in a system in which steam is supplied from the low-pressure drum 13 to other types of equipment. In this case, the steam flow generated at the low-pressure system 8 is increased by connecting the high-pressure drum 11 and the low-pressure drum 13 or by connecting the medium-pressure drum 12 and the low-pressure drum 13, and by supplying the saturated steam from the high-pressure drum 11 or the medium-pressure drum 12 to the low-pressure drum 13.
| Number | Date | Country | Kind |
|---|---|---|---|
| 2011-201856 | Sep 2011 | JP | national |
| Filing Document | Filing Date | Country | Kind | 371c Date |
|---|---|---|---|---|
| PCT/JP2012/073274 | 9/12/2012 | WO | 00 | 7/14/2014 |
