Virtual sensor systems and methods for estimation of steam turbine sectional efficiencies
원문보기
IPC분류정보
국가/구분
United States(US) Patent
등록
국제특허분류(IPC7판)
G06F-003/01
G01L-007/18
G01L-015/00
G06F-007/02
G01L-003/26
F01D-017/08
F02C-001/06
F01K-007/04
F01K-007/22
F01K-013/02
출원번호
US-0163979
(2011-06-20)
등록번호
US-9194758
(2015-11-24)
발명자
/ 주소
Mazzaro, Maria Cecilia
D'Amato, Fernando Javier
Kumar, Jitendra
Badami, Vivek Venugopal
Balasubramaniam, Mahalakshmi Shunmugham
Nagathil, Roopesh Bhaskaran
출원인 / 주소
General Electric Company
대리인 / 주소
Cusick, Ernest G.
인용정보
피인용 횟수 :
0인용 특허 :
8
초록▼
Systems and methods of estimating an efficiency of a section of a steam turbine are disclosed. The systems and methods include determining a set of measurement data obtained directly from a set of sensors on the steam turbine, determining a set of derived data relating to measurements that cannot be
Systems and methods of estimating an efficiency of a section of a steam turbine are disclosed. The systems and methods include determining a set of measurement data obtained directly from a set of sensors on the steam turbine, determining a set of derived data relating to measurements that cannot be obtained directly from the set of sensors, and estimating the efficiency of the section using the set of measurement data and the set of derived data. The systems and methods disclosed use physics-based models combined with nonlinear filtering techniques to estimate steam turbines' efficiencies when physical sensors are not available. These models capture the behavior of different components of the power plant, including all steam turbine sections, admission and crossover pipes, flow junctions, admission and control valves.
대표청구항▼
1. A system comprising: at least one computing device configured to estimate an efficiency of a section of a steam turbine by performing actions including: determining a set of measurement data obtained directly from a set of sensors on the steam turbine, via a processor, wherein the measurement dat
1. A system comprising: at least one computing device configured to estimate an efficiency of a section of a steam turbine by performing actions including: determining a set of measurement data obtained directly from a set of sensors on the steam turbine, via a processor, wherein the measurement data includes: a steam temperature and pressure at a first section inlet, a steam temperature and pressure at a second section inlet, a metal temperature at a second section outlet and a steam temperature and pressure at a third section admission pipe;determining a set of derived data relating to measurements that cannot be obtained directly from the set of sensors, via the processor, wherein the set of derived data includes: a first section main steam flow, a second section main steam flow, a packing steam flow, a third section admission pipe steam flow, a steam pressure and temperature at the first section outlet, a steam temperature and a crossover pipe pressure at the second section outlet; andestimating the efficiency of the second section, via the processor, using the set of measurement data and the set of derived data,wherein the first section has a pressure that is greater than a pressure of the second section. 2. The system of claim 1, wherein the estimated efficiency of the second section comprises a ratio of an actual enthalpy drop within the second section to an enthalpy drop corresponding to an isentropic expansion. 3. The system of claim 2, wherein the enthalpy drop within the second section comprises a difference between an enthalpy at an inlet of the second section and an enthalpy at an outlet of the second section. 4. The system of claim 1, wherein the second section comprises a low pressure, high pressure or intermediate pressure section of the steam turbine. 5. A system comprising: at least one computing device configured to estimate an efficiency of an intermediate pressure (IP) section of a steam turbine by performing actions including: receiving measured data from at least one sensor on the steam turbine, via a processor, wherein the measured data includes: a steam temperature and pressure at a high pressure (HP) section inlet, a metal temperature at an IP section outlet; a steam temperature and pressure at an IP section inlet, and a steam temperature and pressure at a low pressure (LP) section admission pipe;using at least one algorithm, via the processor, to calculate at least one of the following: an HP section main steam flow, an IP section main steam flow, a packing steam flow, an IP section admission steam flow, a steam pressure and temperature at the HP section outlet, a crossover pipe steam temperature and a crossover pipe pressure at the IP section outlet; andcalculating an estimated IP efficiency of the IP section, via the processor, using the measured data from the sensors and the calculated values from the at least one algorithm, wherein the estimated IP efficiency comprises a ratio of an actual enthalpy drop within the IP section to an enthalpy drop corresponding to an isentropic expansion. 6. The system of claim 5, wherein the actual enthalpy drop within the IP section comprises a difference between an enthalpy at an inlet of the IP section and an enthalpy at an outlet of the IP section. 7. The system of claim 6, wherein the enthalpy at the IP section inlet and the enthalpy at the IP section outlet are calculated using the following formulas: h1stωpk+hHRHωHRH=(ωpk+ωHRH)hIPbowl hIPexωIP=hXO(ωIP+ωLPad)=hLPadωLPad wherein, h1st denotes an enthalpy in the HP section of the steam turbine, hHRH denotes an enthalpy downstream of a reheater, hXO denotes an enthalpy in a crossover pipe, hLPad denotes an enthalpy at the IP section admission area, ωpk denotes a packing leakage steam flow, ωHRH denotes a flow downstream of the reheater, wIP denotes a steam flow at the IP section inlet, ωLPad denotes a steam flow at the IP section admission area, and hIPexid denotes an enthalpy at the IP section outlet, corresponding to an isentropic expansion. 8. The system of claim 5, wherein the at least one algorithm includes a model to calculate the HP main section steam flow and the IP main section steam flow as a function of an IP section inlet steam pressure, an IP section inlet steam temperature, an IP section exhaust metal temperature, and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 9. The system of claim 5, wherein the at least one algorithm includes a model to calculate a steam leakage flow as a function of the HP main section steam flow, the IP main section steam flow, and at least one of: packing geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 10. The system of claim 5, wherein the at least one algorithm to calculate the LP admission steam flow uses values determined from a set of temperature and pressure sensors upstream and downstream of an LP admission valve, and wherein the LP admission steam flow is further a function of at least one of: pipe geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 11. The system of claim 5, wherein the at least one algorithm includes a model to calculate a crossover pipe pressure at an exhaust of the IP section, wherein the crossover pipe pressure is a function of a pressure downstream of an LP admission valve, a derived LP admission steam flow and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 12. The system of claim 5, wherein the at least one algorithm includes a model to calculate a crossover pipe temperature at an exhaust of the IP section, wherein the crossover pipe temperature is a function of a metal temperature at the IP section exhaust, the crossover pipe geometry and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 13. A system comprising: a steam turbine;a set of sensors connected to the steam turbine; andat least one computing device configured to estimate an efficiency of an intermediate pressure (IP) section of the steam turbine by performing actions including: receiving measured data from the set of sensors, wherein the measured data includes: a steam temperature and pressure at a high pressure (HP) section inlet, a metal temperature at an IP section outlet; a steam temperature and pressure at an IP section inlet, and a steam temperature and pressure at a low pressure (LP) section admission pipe;using at least one algorithm to calculate at least one of the following: an HP section main steam flow, an IP section main steam flow, a packing steam flow, an IP section admission steam flow, a steam pressure and temperature at the HP section outlet, a crossover pipe steam temperature and a crossover pipe pressure at the IP section outlet; andcalculating an estimated IP efficiency of the IP section using the measured data from the sensors and the calculated values from the at least one algorithm, wherein the estimated IP efficiency comprises a ratio of an actual enthalpy drop within the IP section to an enthalpy drop corresponding to an isentropic expansion. 14. The system of claim 13, wherein the actual enthalpy drop within the IP section comprises a difference between an enthalpy at an inlet of the IP section and an enthalpy at an outlet of the IP section. 15. The system of claim 14, wherein the enthalpy at the IP section inlet and the enthalpy at the IP section outlet are calculated using the following formulas: h1stωpk+hHRHωHRH=(ωpk+ωHRH)hIPbowl hIPexωIP=hXO(ωIP+ωLPad)=hLPadωLPad wherein, h1st denotes an enthalpy in the HP section of the steam turbine, hHRH denotes an enthalpy downstream of a reheater, hXO denotes an enthalpy in a crossover pipe, hLPad denotes an enthalpy at the IP section admission area, ωpk denotes a packing leakage steam flow, ωHRH denotes a flow downstream of the reheater, wIP denotes a steam flow at the IP section inlet, ωLPad denotes a steam flow at the IP section admission area, and hIPexid denotes an enthalpy at the IP section outlet, corresponding to an isentropic expansion. 16. The system of claim 13, wherein the at least one algorithm includes a model to calculate the HP main section steam flow and the IP main section steam flow as a function of an IP section inlet steam pressure, an IP section inlet steam temperature, an IP section exhaust metal temperature, and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 17. The system of claim 13, wherein the at least one algorithm includes a model to calculate a steam leakage flow as a function of the HP main section steam flow, the IP main section steam flow, and at least one of: packing geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 18. The system of claim 13, wherein the at least one algorithm to calculate the LP admission steam flow uses values determined from a set of temperature and pressure sensors upstream and downstream of an LP admission valve, and wherein the LP admission steam flow is further a function of at least one of: pipe geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 19. The system of claim 13, wherein the at least one algorithm includes a model to calculate a crossover pipe pressure at an exhaust of the IP section, wherein the crossover pipe pressure is a function of a pressure downstream of an LP admission valve, a derived LP admission steam flow and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift. 20. The system of claim 13, wherein the at least one algorithm includes a model to calculate a crossover pipe temperature at an exhaust of the IP section, wherein the crossover pipe temperature is a function of a metal temperature at the IP section exhaust, the crossover pipe geometry and at least one of: steam path geometry, natural deterioration of turbine components over time, mechanical deterioration of the turbine components over period of time, operational conditions of the turbine, and instrument drift.
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이 특허에 인용된 특허 (8)
Mazzola Mario A. (Ballston Lake NY) Farineau Thomas J. (Schohane NY) Schlottner George (Delanson NY) Brinkman Earl H. (Schenectady NY), High pressure/intermediate pressure section divider for an opposed flow steam turbine.
Hernandez, Nestor; Gazzillo, Clement; Boss, Michael J.; Parry, William; Tyler, Karen J., Turbine systems and methods for using internal leakage flow for cooling.
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