US3922859A - Control system for a power producing unit - Google Patents

Control system for a power producing unit Download PDF

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Publication number
US3922859A
US3922859A US465705A US46570574A US3922859A US 3922859 A US3922859 A US 3922859A US 465705 A US465705 A US 465705A US 46570574 A US46570574 A US 46570574A US 3922859 A US3922859 A US 3922859A
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Prior art keywords
vapor
set point
point value
temperature
pressure
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US465705A
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English (en)
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Oliver W Durrant
Robert R Walker
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Babcock and Wilcox Co
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Babcock and Wilcox Co
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Application filed by Babcock and Wilcox Co filed Critical Babcock and Wilcox Co
Priority to US465705A priority Critical patent/US3922859A/en
Priority to DE19752518353 priority patent/DE2518353A1/de
Priority to CA225,992A priority patent/CA1011198A/en
Priority to ES437201A priority patent/ES437201A1/es
Priority to AU80626/75A priority patent/AU484728B2/en
Priority to IT09419/75A priority patent/IT1028815B/it
Priority to JP50051606A priority patent/JPS6224608B2/ja
Priority to SE7505065A priority patent/SE407258B/xx
Priority to FR7513505A priority patent/FR2269633B1/fr
Priority to BE156002A priority patent/BE828640A/xx
Priority to GB17970/75A priority patent/GB1509743A/en
Priority to ZA00752786A priority patent/ZA752786B/xx
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Publication of US3922859A publication Critical patent/US3922859A/en
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
    • F01K13/00—General layout or general methods of operation of complete plants
    • F01K13/02—Controlling, e.g. stopping or starting
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
    • F01D—NON-POSITIVE DISPLACEMENT MACHINES OR ENGINES, e.g. STEAM TURBINES
    • F01D17/00—Regulating or controlling by varying flow
    • F01D17/20—Devices dealing with sensing elements or final actuators or transmitting means between them, e.g. power-assisted
    • F01D17/22—Devices dealing with sensing elements or final actuators or transmitting means between them, e.g. power-assisted the operation or power assistance being predominantly non-mechanical

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  • ABSTRACT [52] US. Cl. 60/665 [51 lnt. C1. F01K 13/02 A control system for a power producing unit arranged [58] Field of Search 60/660-667, f li g o eration including means for the rapid 6 652; 290/2; 4 loading and unloading of the unit and on-line variable pressure operation throughout a selected load range. [56] References Cited UNITED STATES PATENTS 14 Claims, 3 Drawing Figures 3,338,053 8/1967 Gorzegno ct a1.
  • This invention relates to a control system for power producing units and more particularly to a control system for fossil fuel fired electric power producing units such as found in modern central stations.
  • nuclear units come into operation, there are strong incentives for them to be base loaded because of their low incremental fuel cost and because of operating restrictions.
  • other units in the system must be capable of changing load frequently and rapidly, including complete shutdown during periods of low system demand.
  • Typical cycling units may, for example, be rated at between 400-600 MW with initial steam conditions of 2400 psig and 1000F.
  • the steam usually passes first through a high pressure turbine, thence through a reheater pass in the steam generator wherein the steam is raised to a hot reheat temperature of 1000F, thence through an intermediate pressure turbine and thence through a low pressure to a condenser.
  • the turbine valves are utilized to obtain short-term transient changes in steam flow to the turbine to thereby satisfy, temporarily, load changes, while firing is adjusted to maintain balance between energy input and output to and from the unit on a relatively long term steady state basis.
  • firing rate may be controlled to maintain a programmed gas temperature at a selected point in the boiler during start-up and low loads and by MW demand during on-line operation.
  • the demand for energy input to the unit is established to meet the requirements of various conditions such as, but not necessarily limited to load, steam pressure and temperature, by firing the boiler to meet the highest of these requirements, while the lower ranking demands are accommodated by control instrumentalities such as super heater division and super heater by-pass valves, and by steam and water attemerators.
  • the steam generating section and primary super heater of the boiler are maintained at set point pressure, thereby maintaining a relatively large amount of energy storage which may be borrowed from or added to to meet rapid load changes and reducing the amount of over firing or under firing required to satisfy load changes and to minimize start-up times.
  • FIG. 1 is a block diagram of the basic steam-water cycle of a power producing unit.
  • FIG. 2 is a block diagram of the air-gas cycle of the boiler shown in FIG. 1.
  • FIG. 3 is a block diagram of our invention as applied to the power producing unit illustrated in FIGS. 1 and 2.
  • FIG. 1 there is shown the elementary steamwater cycle for a more or less conventional generator-turbine generator power producing unit comprising a steam generator, or boiler, generally indicated at I and a turbine-generator unit generally indciated at 2, having a high pressure (HP) turbine 3, an
  • IP turbine 4 intermediate pressure (IP) turbine 4 and a low pressure (LP) turbine 5.
  • LP turbine 5 low pressure turbine 5.
  • IP intermediate pressure
  • LP low pressure
  • the HP turbine 3, IPturbine 5 drive a single generator 6, producing electric power transmitted therefrom by conductors 7, 8 and 9.
  • each turbine unit may be arranged to drive a separate generator all feeding into a common buss.
  • the particular arrangement of turbine-generator which may be used forms no part of the present invention.
  • FIG. 2 there is shown in elementary form the air-gas cycle for thesteam generator 1.
  • Air for combustion supplied by forced draft fan 21, passes through an air heater 22 and is discharged into furnace 19.
  • Fuel which may be oil, gas, coal, or a combination thereof, is discharged into furnace 19 from any conventional means (not shown, but schematically represented by line 23).
  • Flue gas leaving the economizer 18 may also be recirculated into the furnace 19 by gas recirculating fan 25 as one of controlling the temperature of the hot reheat steam discharged from reheater 11 within part or all of the nor mal operating range of the unit.
  • the rate of flow of recirculated gas is maintained in inverse proportion to the heat or energy input to the steam generator l.
  • the order shown in which the products of combustion pass over the several heating sections is not the exclusive order. The order may be, for example, primary superheater, secondary superheater, and reheater: or secondary superheater, primary superheater,
  • a by-pass system is provided around the primary and secondary superheaters comprising a conduit 26 having its inlet connected to the inlet of the primary superheater and its discharge opening into the condenser 12 which is arranged to receive and condense the steam transmitted through conduit 26 for return to the feedwater system. Further, as shown, provisions are made for diverting steam from the conduit 26, through a conduit 27, to the outlet of the secondary superheater 10 and from the conduit 26, through a conduit 28 to the outlet of the reheater. The diversion of substantially saturated steam into the superheated and hot reheat steam to the turbine provides a means for moderating the temperatures thereof as may be required during start-up and low load operations.
  • FIG. 3 the control system as applied to the power generating unit illustrated in FIGS. 1 and 2 is shown in block diagram form.
  • the control components so represented or hardware, as it is sometimes called, are commercially available and their operation well understood by those familiar with the art.
  • the primary controllers shown in FIG. 3 have been referred into FIGS. 1 and 2 as have the final control elements.
  • start-up In the operation of cycling units there are two types of start-up which may be defined as, cold start and hot start. Regardless of the boiler-turbine condition i.e. whether hot or cold or at an intermediate temperature, on-line operation can be reached most quickly by firing the boiler to satisfy the most citical requirement and satisfying the other requirements by auxiliary control instrumentalities.
  • start-up it may be assumed that the steam generating section and primary superheater of the boiler are at relatively high pressure and at saturation temperature whereas the secondary superheater and reheater are at relatively low temperature, under such conditions the most critical requirement is uperheated steam temperature, accordingly the boiler is fired to raise this temperature at the maximum allowable rate, and if necessary steam may be dumped to the condenser to maintain boiler pressure at the desired value.
  • the unit load demand signal may be established by an automatic load dispatch system as shown as 29, or by other automatic or manual means, inputing to a primary control signal generator 30, the purpose of which is to generate a feed forward control signal corresponding to the desired energy output of the power producing unit.
  • Also inputing into unit 32 is a signal corresponding to megawatts output generated in transmitter 34 which signal may be considered a feedback signal and the unit 32 generating an output demand signal as required to maintain equality between the two signals inputing thereto.
  • the primary control signal is also transmitted over line 31 to a Throttle Pressure Ramp Development Unit 35 provided with manually adjustable selectors 36, 38, and 37 whereby the minimum, maximum and rarnp throttle pressures respectively may be established.
  • max. throttle pressure may be set at 2400 psi
  • min. throttle pressure at 600 psi and the ramp set to vary the throttle pressure from 600 psi to 2400 psi from 20% full load to full load. That is to say, unit 35 develops a turbine throttle pressure demand signal transmitted over line 39, demanding, until the 20% load point is reached a constant pressure of 600 psi, and thence a throttle pressure increasing as load demand increases until the 70% load point is reached and thereafter to full load a constant pressure of 2400 psi.
  • Adjusters 36, 37 and 38 enable an operator to set, as desired, the minimum, and maximum throttle pressures and the load span covered by the ramp.
  • the steam flow demand signal transmitted over line 33 adjusts in parallel fuel flow control valve 40 and air flow control damper unit 41 to thereby maintain energy input to the unit in accordance with energy demand.
  • the steam flow demand signal is also transmitted over line 33 to turbine steam flow control valves 42 to maintain a rate of flow of steam to high pressure turbine 3 in accordance with steam flow demand.
  • the turbine valves will, for the min., and max. and ramp pressures heretofore described remain approximately 70% open from min. pressure to max. pressure as established at the 70% load point and thereafter proportionality as load demand increases. However, throughout the min.
  • control valves will modulate from the 70% open position to immediately satisfy demands for increasing or decreasing steam flow, but will be restored to the 70% open position as such changes in demand are satisfied by changes in firing rate. That is to say, transient changes in load demand are satisfied by borrowing from or giving to the energy storage in the boiler and the energy storage is then brought to its desired level by appropriate changes in the firing rate.
  • the throttle pressure demand signal is transmitted through line 39 to a Throttle Pressure and Sequence Unit 43, also receiving a signal proportional to actual throttle pressure generated in pressure controller 44 and generating an output signal transmitted along line 45 to position valve 46, located between primary superheater 20 and secondary superheater 10 as required to maintain throttle pressure at the desired value.
  • valve 46 acts as a down stream pressure regulator to maintain throttle pressure at the programmed value as established in unit 35.
  • the throttle pressure program control signal is also transmitted along line 39 to a Boiler Pressure Program Control Unit 47, also receiving a signal proportional to actual primary superheater outlet pressure generated in pressure controller 48, and generating an output signal, varying in functional relationship to turbine pressure, transmitted along line 49, which after various modifying devices is effective, through summing unit 50, to modulate the firing rate as required to maintain steam pressure at the primary superheater outlet at the desired value.
  • firing rate must be modified to maintain the most critical condition at desired value and maintain other conditions at desired value by various auxiliary control instrumentalities.
  • hot-start wherein boiler pressure through the primary superheater is at approximately the desired value
  • cold-start wherein boiler and turbine are at low temperatures.
  • the primary consideration is that mismatch between steam temperatures and turbine metal temperatures must be maintained within acceptable limits, while raising steam and metal temperatures as rapidly as possible to bring the unit on line in minimum time.
  • the unit is fired as required to maintain the condition, among the conditions such as, but not necessarily limited to throttle pressure, gas temperature at the steam outlets of the secondary superheater and reheater and superheated steam pressure, having the greatest demand at the programmed value.
  • a control signal upon valve 46 being unable to satisfy the demand for throttle pressure is transmitted through line 51 to a high signal selector 52 into which is also introduced a control signal, through line 53, proportional to the deviation in gas temperature from the programmed value and a control signal through line 54 proportional to the deviation in throttle pressure from the programmed value.
  • the highest of these signals is then transmitted through line 55 to summing unit 50 and effective to modify the firing rate as required to maintain the selected condition at the programmed value.
  • the gas temperature control signal, transmitted through line 33, is generated in a programming unit 56 which is responsive to the steam flow demand signal transmitted through line 33 and signal corresponding to actual gas temperature generated in temperature controller 57.
  • a programming unit 56 which is responsive to the steam flow demand signal transmitted through line 33 and signal corresponding to actual gas temperature generated in temperature controller 57.
  • the temperature controller 57 responds to the gas temperature at this point.
  • gas temperature can be used as an index of steam temperature only under startup and low flow conditions, conveniently the gas temperature controller 57 may be of the retractable type and withdrawn from the gas duct during operation of the unit in the normal operating range, when gas temperatures may be far in excess of the superheat and reheat steam temperatures.
  • Temperature Rate of Change Development Unit 59 responsive to manually set signals generated in stations 60, 61 and 62 establish a signal corresponding to initial desired steam temperature and increasing at an adjustable rate until corresponding in value to the desired on-line operation temperature.
  • the initial temperature is ordinarily set to give a desired temperature differential between steam and turbine metal temperatures and the rate of change set to increase steam temperature from initial to final value as required to maintain the difference between steam temperature and turbine metal temperature within prescribed limits.
  • the initial temperature may be 6001 the rate of change F per hour and the final temperature 10001
  • Control unit 64 generated an output signal corresponding to the difference between the signals generated in unit 59 and superheated steam temperature controller 63 which may further be modified by a feed forward signal generated in flow controller 65 responsive to the rate of air flow to the furnace 19.
  • the output signal from unit 64 controls saturated steam attemporator valve 66 introducing relatively cool steam into the superheated steam to thereby restore the steam temperature to the desired value.
  • the control signal generated in unit 64 is effective through control unit 67 to adjust the firing rate in an increasing sense.
  • the control arrangement is such that the signal values corresponding to the decrease in actual steam temperature below the programmed value is effective for modulating the firing rate, whereas only signal values corresponding to the increase in actual steam temperature above the programmed value is effective for modulating, by means of valve 66, the flow of saturated steam into the superheat steam.
  • superheated steam temperature may be controlled throughout the normal operating range by introducing water as required through water attemporator valve 68 responsive to a signal generated in unit 64 corresponding to deviation in actual superheated steam temperature from the programmed value (normally the final steam temperature as set in manual station 62).
  • Reheat steam temperature control is generally similar to that described for superheat steam temperature control.
  • a signal output from temperature ramp unit 59 through line 68 is transmitted to control unit 69 wherein it is compared with a signal corresponding to actual steam reheat temperature generated in temperature controller 70.
  • Also introduced into control unit 69 is the feed forward signal, transmitted along line 71, from air flow controller 65.
  • the output signal generated in control unit 69 is transmitted to a sequence controller 72, operating in sequence steam attemporator valve 73, gas recirculating control damper unit 74 and reheat water attemporator control valve 75. Similar to the operation of the superheat steam control instrumentalities, the steam attemporator is effective during certain start-up conditions when firing to maintain the most critical condition produces a high reheat temperature.
  • gas recirculation is effective to control reheat temperature, in general a rate of recirculation varying inversely with rating being required. At high ratings, when gas recirculation is reduced to a minimum, reheat steam temperature is effectively'controlled by means of water attemporator.
  • a control system for a power producing unit comprising a vapor generator and a turbine-generator supplied with vapor from said vapor generating unit
  • the combination comprising; a first means generating a first feed forward signal corresponding to the desired power output of the power producing unit, a second means responsive to said first feed forward signal generating a second feed forward signal proportional in value to said first feed forward signal modified by the difference between desired and actual power output of the power producing unit, a third means responsive to said second feed forward signal maintaining the rate of flow of vapor to the turbine proportional to said second feed forward signal, a fourth means responsive to said first feed forward signal maintaining the pressure of the vapor admitted to said turbine at a set point value varying in a first functional relationship to said first feed forward signal and a fifth means responsive to said first feed forward signal maintaining the pressure in said vapor generator at a set point value varying in a second functional relationship to said first feed forward signal.
  • said fifth means includes means venting vapor from said vapor generator as required to inhibit the pressure in said vapor generator from exceeding set point value.
  • said vapor generator is provided with fuel and air supply means and wherein said fifth means includes means adjusting the rates of fuel and air supplied said vapor generator as required to maintain the pressure in said vaporv generator in said second functional relationship to said first feed-forward signal.
  • said fourth means includes manually adjustable means establishing an initial set point value, a final set point value and the desired rate of change in set point value with the magnitude of said first forward signal from said initial set point value to said final set point value.
  • said vapor generator is provided with'a primary superheater, a secondary super-heater and a control valve for regulating the flow of vapor from the primary to the secondary superheater and wherein said turbine is provided with admission valves for regulating the flow of vapor into said turbine and wherein said third means includes means adjusting said admission valves as re.-
  • said fourth means includes means adjusting said control valve as required to maintain the pressure of the vapor on the inlet side of said admission valves at a set point value varying in functional relationship to said first feed forward signal.
  • a start-up system for a power producing unit comprising a vapor generator provided with fuel and air supply means, a primary and a secondary superheater and a reheater, and a turbine-generator comprising a high pressure unit supplied vapor from said secondary superheater, a lower pressure unit supplied vapor from said reheater and a condenser condensing vapor discharged from said lower pressure unit, the combination comprising; means selecting the one of a plurality of measured conditions in said power producing unit having the greatest deviation from set point value generating a control signal varying in functional relationship with said deviation, means responsive to said control signal adjusting the rates of fuel and air supplied said vapor generator as required to maintain said selected one of the plurality of measured conditions at set point value and auxiliary instrumentalities maintaining the other of said plurality of measured conditions at set point values.
  • a start-up system as set forth in claim 6 wherein said vapor generator is provided with a vapor by-pass from the vapor inlet of said secondary superheater to said condenser, one of said plurality of conditions is the vapor pressure at the vapor outlet of said primary superheater and one of said auxiliary instrumentalities includes means responsive to the deviation in said vapor pressure above set point value and means responsive to said last named means adjusting the rate of flow of vapor through said vapor by-pass to reduce said vapor pressure to set point value.
  • a start-up system as set forth in claim 6 wherein said vapor generator is provided with a vapor by-pass from the vapor inlet of said primary superheater to the vapor outlet of said secondary superheater, one of said plurality of conditions is the temperature of the vapor discharged from said secondary superheater and one of said auxiliary instrumentalities includes means responsive to the deviation in said vapor temperature above set point value, and means responsive to said last named means adjusting the rate of flow of vapor through said last named vapor by-pass to reduce said vapor temperature to set point value.
  • one of said plurality of conditions is the temperature or the vapor discharged from said reheater and one of said auxiliary instrumentalities includes means responsive to the deviation in said reheated vapor temperature above set point value, and means responsive to said last named means adjusting the rate of flow of vapor through said last named vapor by-pass to reduce said reheated steam temperature to set point value.
  • vaporgenerator is provided with a valve in the vapor conduit between said primary and secondary superheaters and one of said auxiliary instrumentalities includes means responsive to the deviation in pressure of the vapor at the inlet tosaid high pressure turbine from set point value. and means responsive to said last named means adjusting said valve to maintain said last named pressure at set point value.
  • said plurality of measured conditions includes pressure of the vapor at the inlet to said high pressure turbine, temperature of the flue gas in said vapor generator between said secondary superheater and said reheater, pressure of the vapor is said vapor generator at the outlet of the primary superheater and temperature of the vapor at the inlet to said high pressure turbine.
  • said one of a plurality of measured conditions is the temperature of the flue gas between said primary and secondary superheaters
  • said one of a plurality of measured conditions is the temperature of the flue gas between said primary and secondary superheaters, means responsive to said temperature generating a control signal varying in accordance with changes in said flue gas temperature from set point, means generating a feedforward signal varying in functional relationship with the desired power output from said power producing unit, means responsive to said feedforward signal raising said set point in functional relationship with increases in said feedforward signal, and means responsive to said control signal adjusting the rates of fuel and air supplied said vapor generator as required to maintain said flue gas temperature at set point.

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Control Of Steam Boilers And Waste-Gas Boilers (AREA)
  • Control Of Turbines (AREA)
  • Control Of Eletrric Generators (AREA)
  • Control Of Multiple Motors (AREA)
  • Discharge Heating (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
US465705A 1974-04-30 1974-04-30 Control system for a power producing unit Expired - Lifetime US3922859A (en)

Priority Applications (12)

Application Number Priority Date Filing Date Title
US465705A US3922859A (en) 1974-04-30 1974-04-30 Control system for a power producing unit
DE19752518353 DE2518353A1 (de) 1974-04-30 1975-04-25 Regelsystem fuer energieerzeuger
ES437201A ES437201A1 (es) 1974-04-30 1975-04-29 Perfeccionamientos en los sistemas de control para unidades productoras de energia.
AU80626/75A AU484728B2 (en) 1974-04-30 1975-04-29 Control system fora power producing unit
IT09419/75A IT1028815B (it) 1974-04-30 1975-04-29 Sistema di comando e controllo per unita di produzione di potenza
CA225,992A CA1011198A (en) 1974-04-30 1975-04-29 Control system for a power producing unit
JP50051606A JPS6224608B2 (enrdf_load_stackoverflow) 1974-04-30 1975-04-30
SE7505065A SE407258B (sv) 1974-04-30 1975-04-30 Reglersystem for en anleggning for alstring av elkraft med en anggenerator och en med anga fran denna matad turbogenerator
FR7513505A FR2269633B1 (enrdf_load_stackoverflow) 1974-04-30 1975-04-30
BE156002A BE828640A (fr) 1974-04-30 1975-04-30 Perfectionnements aux groupes generateurs d'energie
GB17970/75A GB1509743A (en) 1974-04-30 1975-04-30 Power producing units
ZA00752786A ZA752786B (en) 1974-04-30 1975-04-30 Improvements in or relating to power producing units

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US465705A US3922859A (en) 1974-04-30 1974-04-30 Control system for a power producing unit

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US3922859A true US3922859A (en) 1975-12-02

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US (1) US3922859A (enrdf_load_stackoverflow)
JP (1) JPS6224608B2 (enrdf_load_stackoverflow)
BE (1) BE828640A (enrdf_load_stackoverflow)
CA (1) CA1011198A (enrdf_load_stackoverflow)
DE (1) DE2518353A1 (enrdf_load_stackoverflow)
ES (1) ES437201A1 (enrdf_load_stackoverflow)
FR (1) FR2269633B1 (enrdf_load_stackoverflow)
GB (1) GB1509743A (enrdf_load_stackoverflow)
IT (1) IT1028815B (enrdf_load_stackoverflow)
SE (1) SE407258B (enrdf_load_stackoverflow)
ZA (1) ZA752786B (enrdf_load_stackoverflow)

Cited By (8)

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US4287430A (en) * 1980-01-18 1981-09-01 Foster Wheeler Energy Corporation Coordinated control system for an electric power plant
US20100077970A1 (en) * 2008-09-29 2010-04-01 General Electric Company Inter-stage attemperation system and method
US20120131917A1 (en) * 2010-11-30 2012-05-31 General Electric Company Methods and Systems for Loading a Steam Turbine
US20120255303A1 (en) * 2010-12-20 2012-10-11 Invensys Systems, Inc. Feedwater Heater Control System for Improved Rankine Cycle Power Plant Efficiency
CN104612767A (zh) * 2014-12-25 2015-05-13 中国电力工程顾问集团华东电力设计院 设定超高压缸冲转压力设定值的方法
US9316122B2 (en) 2010-12-20 2016-04-19 Invensys Systems, Inc. Feedwater heater control system for improved Rankine cycle power plant efficiency
WO2019205278A1 (zh) * 2018-04-28 2019-10-31 深圳大学 公交运行状态数据调整处理方法、智能终端及存储介质
US20220341588A1 (en) * 2021-04-25 2022-10-27 Southeast University Method for setting parameters of load feedforward controller for superheated steam temperature control

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JPS5833392Y2 (ja) * 1978-03-20 1983-07-26 三洋電機株式会社 ガス湯沸器の緩点火装置
DE3235909A1 (de) * 1981-03-06 1983-02-24 Clayton Manufacturing Co Regelungsvorrichtung fuer dampf- bzw. heisswasser-erzeugungsanlagen mit mehreren dampf- bzw. heisswasser-erzeugern
GB8528261D0 (en) * 1985-11-15 1985-12-18 Burgess Eng Ltd G N Sealing device
CN106524131B (zh) * 2016-09-23 2018-08-31 华北电力大学（保定） 一种火电机组蒸汽温度的前馈控制方法
CN114063437B (zh) * 2021-10-22 2023-08-08 北京京能科技有限公司 一种超临界机组再热器烟气挡板控制方法

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US3417737A (en) * 1966-09-20 1968-12-24 Foxboro Co Once-through boiler control system
US3545207A (en) * 1969-07-23 1970-12-08 Leeds & Northrup Co Boiler control system
US3561216A (en) * 1969-03-19 1971-02-09 Gen Electric Thermal stress controlled loading of steam turbine-generators
US3802189A (en) * 1972-01-13 1974-04-09 Leeds & Northrup Co Boiler-turbine control system

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US3338053A (en) * 1963-05-20 1967-08-29 Foster Wheeler Corp Once-through vapor generator start-up system
US3417737A (en) * 1966-09-20 1968-12-24 Foxboro Co Once-through boiler control system
US3561216A (en) * 1969-03-19 1971-02-09 Gen Electric Thermal stress controlled loading of steam turbine-generators
US3545207A (en) * 1969-07-23 1970-12-08 Leeds & Northrup Co Boiler control system
US3802189A (en) * 1972-01-13 1974-04-09 Leeds & Northrup Co Boiler-turbine control system

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4287430A (en) * 1980-01-18 1981-09-01 Foster Wheeler Energy Corporation Coordinated control system for an electric power plant
US20100077970A1 (en) * 2008-09-29 2010-04-01 General Electric Company Inter-stage attemperation system and method
US8904972B2 (en) * 2008-09-29 2014-12-09 General Electric Company Inter-stage attemperation system and method
US20120131917A1 (en) * 2010-11-30 2012-05-31 General Electric Company Methods and Systems for Loading a Steam Turbine
RU2592569C2 (ru) * 2010-11-30 2016-07-27 Дженерал Электрик Компани Способ и устройство для нагружения паровой турбины
US8843240B2 (en) * 2010-11-30 2014-09-23 General Electric Company Loading a steam turbine based on flow and temperature ramping rates
US9316122B2 (en) 2010-12-20 2016-04-19 Invensys Systems, Inc. Feedwater heater control system for improved Rankine cycle power plant efficiency
US9091182B2 (en) * 2010-12-20 2015-07-28 Invensys Systems, Inc. Feedwater heater control system for improved rankine cycle power plant efficiency
US20120255303A1 (en) * 2010-12-20 2012-10-11 Invensys Systems, Inc. Feedwater Heater Control System for Improved Rankine Cycle Power Plant Efficiency
CN104612767B (zh) * 2014-12-25 2016-03-16 中国电力工程顾问集团华东电力设计院有限公司 设定超高压缸冲转压力设定值的方法
CN104612767A (zh) * 2014-12-25 2015-05-13 中国电力工程顾问集团华东电力设计院 设定超高压缸冲转压力设定值的方法
WO2019205278A1 (zh) * 2018-04-28 2019-10-31 深圳大学 公交运行状态数据调整处理方法、智能终端及存储介质
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AU8062675A (en) 1976-11-04
JPS6224608B2 (enrdf_load_stackoverflow) 1987-05-29
GB1509743A (en) 1978-05-04
DE2518353A1 (de) 1975-11-13
SE7505065L (sv) 1975-10-31
JPS50152230A (enrdf_load_stackoverflow) 1975-12-08
FR2269633B1 (enrdf_load_stackoverflow) 1981-04-10
SE407258B (sv) 1979-03-19
ES437201A1 (es) 1977-05-16
CA1011198A (en) 1977-05-31
FR2269633A1 (enrdf_load_stackoverflow) 1975-11-28
BE828640A (fr) 1975-10-30
ZA752786B (en) 1976-12-29
IT1028815B (it) 1979-02-10

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