IPC분류정보
국가/구분 |
United States(US) Patent
등록
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국제특허분류(IPC7판) |
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출원번호 |
US-0354830
(2003-01-30)
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발명자
/ 주소 |
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출원인 / 주소 |
- Wylie Inventions Company, Inc.
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대리인 / 주소 |
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인용정보 |
피인용 횟수 :
61 인용 특허 :
4 |
초록
▼
A combined cycle process for generating electric power wherein the working fluid fed to the steam turbine train is water above its critical pressure and temperature.Preferred embodiments include: reheating steam side streams extracted from the steam turbine train in the heat recovery unit and feedin
A combined cycle process for generating electric power wherein the working fluid fed to the steam turbine train is water above its critical pressure and temperature.Preferred embodiments include: reheating steam side streams extracted from the steam turbine train in the heat recovery unit and feeding the reheated steam side streams back into the steam turbine train; firing supplemental fuel gas in the gas turbine exhaust gas stream flowing through the heat recovery unit at one or more points to increase the power output of the steam turbine train; and diverting part of the condensate stream around the economizer tubes in the heat recovery unit to a separate heat exchanger where the diverted condensate stream is heated with steam side streams extracted from the steam turbine train.
대표청구항
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1. A combined cycle process for generating electric power that includes a steam turbine train, one or more gas turbines, and a heat recovery unit, the process comprising the steps of:a) condensing an exhaust steam stream emitted from the steam turbine train via an exit point near the downstream end
1. A combined cycle process for generating electric power that includes a steam turbine train, one or more gas turbines, and a heat recovery unit, the process comprising the steps of:a) condensing an exhaust steam stream emitted from the steam turbine train via an exit point near the downstream end of the steam turbine train to form a condensate stream, preheating the condensate stream in a preheater, conveying the preheated condensate into economizer tubes in the top section of the heat recovery unit and further heating the preheated condensate, then conveying the condensate stream to a de-aerating drum where a small vent gas stream is withdrawn from the condensate stream, withdrawing the de-aerated condensate stream from the de-aerating drum and compressing it to a pressure that is above the critical pressure of water (which is 3206.2 psia), conveying the compressed condensate stream to primary heating tubes in the heat recovery unit and heating the compressed de-aerated condensate stream to a temperature that is above the critical temperature of water (which is 705.4 F) to form a super critical water working fluid stream, and conveying the super critical water working fluid stream from the heat recovery unit into an entrance to the steam turbine train located near the upstream end of the steam turbine train;b) burning fuel gas in the one or more gas turbines each turbine driving and electric generator, and each producing a gas turbine exhaust gas stream, combining and conveying the gas turbine exhaust gas streams into the heat recovery unit, where the gas stream flows first over the primary heating tubes and then over the economizer tubes in the heat recovery unit transferring heat from the gas turbine exhaust gas stream to the condensate stream to raise the temperature of the condensate stream to a temperature that is above the critical temperature of water (which is 705.4 F) to form the super critical water working fluid stream that is conveyed into the steam turbine train. 2. The process of claim 1 wherein the steam turbine train also includes one or more side stream steam extraction outlets, and each side stream steam outlet has a corresponding reheated side steam side stream inlet on the steam turbine train that is downstream of the corresponding steam side stream outlet, and wherein the process comprises the additional steps of:a) extracting one or more steam side streams from the steam turbine train via the steam side stream outlets;b) conveying the steam side streams to reheat tubes located in the heat recovery unit so that the gas turbine exhaust gas stream flows first over the reheat tubes and then over the economizer tubes to reheat steam side streams; andc) conveying the reheated steam side streams into the steam turbine each via the reheated steam side stream inlet corresponding to the side stream outlet. 3. The process of claim 2 wherein the heat recovery unit includes facilities for feeding, controlling, and firing fuel gas streams into the gas turbine exhaust gas stream in the heat recovery unit at one or more points in the heat recovery unit, and the process includes the added step of feeding, controlling, and burning streams of fuel gas in the gas turbine exhaust gas stream at one or more points in the heat recovery unit. 4. The process of claim 3 wherein one of the fuel gas feed points is near the gas turbine exhaust gas stream inlet to the heat recovery unit. 5. The process of claim 4 wherein all the fuel gas fired in the heat recovery unit is fed into the heat recovery unit at the feed point that is near the gas turbine exhaust gas stream inlet to the heat recovery unit. 6. A combined cycle process for generating electric power that includes 1) a steam turbine train that drives an electric generator, and the steam turbine train has an upstream end where water working fluid enters and a downstream end where exhaust steam is discharged, 2) one or more gas turbines each driving an electric generator and e ach producing a gas turbine exhaust gas stream, 3) a heat recovery unit that includes primary tubes, reheat tubes and economizer tubes, and 4) the steam turbine train includes one or more steam side stream outlets, and each steam side stream outlet has a corresponding reheated steam side stream inlet that is downstream of its corresponding steam side stream outlet, and 5) the heat recovery unit includes facilities for feeding, controlling, and firing fuel gas streams into the gas turbine exhaust gas stream in the heat recovery unit at one or more points in the heat recovery unit; wherein the process comprises the steps of:a) firing fuel gas in the one or more gas turbines to drive the turbine generators and produce power, combining the gas turbine exhaust gas streams and conveying the combined gas turbine exhaust stream into the heat recovery unit via an inlet to the heat recovery unit where the gas stream flows first over the primary heating tubes and the reheat tubes and then over the economizer tubes;b) condensing an exhaust steam stream emitted from the steam turbine train near the downstream end of the steam turbine train to form a condensate stream, preheating the condensate stream, dividing the pre-heated condensate stream into a first part condensate stream and a second part condensate stream, conveying the first part condensate stream into economizer heat exchange tubes in the heat recovery unit where the first part condensate stream is heated by the gas turbine exhaust gas stream flowing through the heat recovery unit first over the primary heating tubes and reheat tubes and then over the economizer tubes;c) conveying the second part condensate stream to a bypass condensate preheater where the second part condensate stream is further heated using steam side streams extracted from the steam turbine train as the heat source;d) conveying the first part condensate stream from the economizer tubes and the second condensate stream from the second condensate preheater to a de-aerator drum where a vapor stream is withdrawn from the condensate, and the de-aerated condensate stream is withdrawn from the flash drum and compressed to a pressure that is above the critical pressure of water (which is 3206.2 psia);e) conveying the compressed condensate stream from the de-aerator drum to the primary heat exchange tubes in the heat recovery unit where the condensate stream is heated by the gas turbine exhaust gas stream flowing over the primary heating tubes through the heat recovery unit to a temperature that is above the critical temperature of water (which is 705.4 F) to form a super critical water working fluid stream;f) conveying the super critical water working fluid stream from the heat recovery unit into an inlet on the steam turbine train located near the upstream end of the steam turbine train;g) extracting one or more steam side streams from the steam turbine train using a steam side stream outlet for each side stream, conveying the steam side streams to reheat tubes in the heat recovery unit wherein the steam side streams are reheated by heat transferred from the gas turbine exhaust gas streams flowing over the reheat tubes, conveying the reheated steam side streams from the reheat tubes into the steam turbine train through the reheated steam side stream inlet corresponding the steam side stream outlet;h) feeding, controlling and firing one or more fuel gas streams in the gas turbine exhaust gas streams in the heat recovery unit in proximity to the primary and reheat heat exchange tubes. 7. The process of claim 6 wherein the ratio of the mass flow rate of gas turbine exhaust gas flowing over the economizer heat exchange tubes to the mass flow rate of condensate flowing in the economizer heat exchange tubes in the heat recovery unit is maintained higher than about 4.3. 8. The process of claim 7 wherein the ratio of mass flow rate of gas turbine exhaust gas flowing over the economizer heat exchange tubes to mass flow rate o f condensate flowing in the economizer heat exchange tubes is maintained at a specified ratio above about 4.3 by adjusting the rate of flow of the second condensate stream part that is diverted from the economizer tubes to the condensate preheater. 9. The process of claim 6 wherein the temperature of the super critical water working fluid stream that exits the heat recovery unit and is conveyed to the steam turbine train is maintained at a specified temperature that is above the critical temperature of water (which is 705.4 F) by adjusting the flow rates of the fuel gas streams that are fired in the heat recovery unit. 10. The process of claim 3 wherein the power generating capacity of the steam turbine generator train can be varied by a factor of ten.
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