US3837167A - Control system for a two boiler, single turbine generator power producing unit - Google Patents

Control system for a two boiler, single turbine generator power producing unit Download PDF

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US3837167A
US3837167A US00367775A US36777573A US3837167A US 3837167 A US3837167 A US 3837167A US 00367775 A US00367775 A US 00367775A US 36777573 A US36777573 A US 36777573A US 3837167 A US3837167 A US 3837167A
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boiler
demand signal
flow
signal
reheat
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O Durrant
J Smith
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Babcock International Ltd
Elsag International BV
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Babcock and Wilcox Co
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Priority to US00367775A priority Critical patent/US3837167A/en
Priority to JP49064155A priority patent/JPS618328B2/ja
Priority to US05/495,314 priority patent/US3937024A/en
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Priority to JP58122490A priority patent/JPS5941605A/ja
Assigned to BABCOCK & WILCOX TRACY POWER, INC., A CORP. OF DE reassignment BABCOCK & WILCOX TRACY POWER, INC., A CORP. OF DE ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: BABCOCK & WILCOX COMPANY, THE, A CORP. OF DE
Assigned to ELSAG INTERNATIONAL B.V., A CORP. OF THE NETHERLANDS reassignment ELSAG INTERNATIONAL B.V., A CORP. OF THE NETHERLANDS ASSIGNMENT OF ASSIGNORS INTEREST. Assignors: BABCOCK & WILCOX TRACY POWER, INC., A CORP. OF DE
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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
    • F01K3/00—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein
    • F01K3/18—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters
    • F01K3/24—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by separately-fired heaters
    • F01K3/242—Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters with heating by separately-fired heaters delivering steam to a common mains

Definitions

  • such units may, for example, be rated at upwards of 1,000 MW requiring, at full load, over 6,000,000 pounds of primary steam per hour at 2,500 psig and 1,000F.
  • the steam 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 approximately 1,000 F., and thence through a low pressure turbine to a condenser.
  • the total output of the two steam generators is maintained primarily in accordance with the unit MW or energy demand as established by an automatic load dispatch system or otherwise.
  • the unit energy demand may be apportioned between the two steam generators as desired.
  • the output of one steam generator is limited, the output of the other steam generator is automatically increased as required to satisfy the unit energy demand.
  • the demand is reduced to be compatible with the total available output.
  • feedwater, fuel and air are supplied each steam generator primarily in accordance with the proportion of unit energy demand allocated to the steam generator.
  • the total reheat steam flow from the turbine is apportioned be tween the two steam generators primarily in accordance with the share of the unit energy demand allocated to the steam generator.
  • FIG. 1 is a block diagram of the basic steam-water flow cycle of a typical power producing unit having two single reheat steam generators supplying steam to a turbine.
  • FIG. 2A is a block diagram of the basic air-gas flow cycle of steam generator A shown in FIG. 1.
  • FIG. 2B is a block diagram of the basic air-gas flow cycle of steam generator B shown in FIG. 1.
  • FIG. 3 is a block diagram of the control system organization.
  • FIG. 4 is a logic diagram showing in detail the ratio control identified in FIG. 3 by the block 32.
  • FIG. 5 is a logic diagram showing in detail the feedwater flow control for each of the steam generators A and B identified in FIG. 3 by blocks 34A and 34B respectively.
  • FIG. 6 is a logic diagram showing in detail the firing rate control (fuel and air control) for each of the steam generators A and B identified in FIG. 3 by blocks 36A and 36B respectively.
  • FIG. 7 is a logic diagram showing in detail the reheat steam control identified in FIG. 3 by block 42.
  • FIG. 7A is a fragmentary logic diagram showing a modification of the reheat steam control illustrated in FIG. 7.
  • FIG. 1 we therein show the elementary steam-water cycle for a more or less typical two boiler-single turbine generator power producing unit comprising steam generators, or boilers as they are sometimes called, A and B, a common turbine generator unit generally indicated at 8 having a high pressure turbine 9 and a low pressure turbine 10.
  • both high pressure and low pressure turbines may drive a single generator 11, or each turbine may drive a separate generator both feeding into a common bus.
  • the particular arrangement of turbine and generator which may be used forms no part of our present invention.
  • Steam discharged from secondary superheaters 12A and 12B of steam generators A and B respectively passes through high pressure turbine 9, is then divided, part passing through reheater 13A and the remainder through reheater 138.
  • the hot reheat steam from reheater 13A and 13B then passes through low pressure turbine 10 and is discharged into condenser 14.
  • What is shown as a low pressure turbine may in actual practice be an intermediate pressure turbine and one or more low pressure turbines.
  • Condensate from condenser 14 is pumped by condensate pump 15 through low pressure heaters 16, heated by extraction steam from low pressure turbine 10, into the deaerating heater I7, also heated by extraction steam from low pressure turbine 10.
  • Feedwater for boiler A is drawn from the deaerating heater 17' by a boiler feed pump 18A and is discharged through high pressure heater 19A into boiler A having a furnace 20A, a primary superheater 21A and into secondary superheater 12A.
  • Feedwater for boiler B is also drawn from deaerating heater 17 by a boiler feed pump 18B and discharged through high pressure heater 193 into boiler B having a furnace 20B, primary superheater 21B and into secondary superheater 128.
  • FIGS. 2A and 2B are shown the air-gas cycles for boilers A and B respectively. The cycles are identical and in the interest of brevity that for boiler A only will be traced.
  • Components for the boiler A in FIG. 2A being identified by a number followed by the letter A and like components for the boiler B in FIG. 28 being identified by the same number followed by the letter B
  • air for combustion supplied by a forced draft fan 22A passes through air heater 23A and is discharged into furnace A.
  • Fuel which may be oil, gas, coal or a combination thereof, is discharged into the furnace 20A from any conventional supply means (not shown, but schematically represented by the line 24A).
  • the gasses of combustion, or flue gas, as it is commonly called, leaving the furnace pass through secondary superheater section 12A, reheater section 13A, primary superheater section 21A, air heater 23A and induced fan 25A whence they are discharged to the atmosphere through a stack (not shown).
  • Flue gas leaving the primary superheater 21A may also be recirculated into the furnace 20A by gas recirculating fan 26A as a means of partially or wholly controling reheat steam temperature.
  • the rate of flow of recirculated gas is maintained in inverse proportion to heat or energy input to the boiler.
  • 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, and reheater.
  • an economizer section may be included in the order at an appropriate place.
  • FIG. 3 shows, in block diagram, the organization of the control system.
  • the unit load demand may be established by an automatic load dispatch system, as shown at 28, or by other automatic or manual means. It is the purpose of this control to generate a control signal corresponding to the desired energy output as may be measured in MW, BTU or other energy units.
  • the control signal so generated is transmitted to a master controller 30 which may be any one of the several types now more or less common in the art. One particular suitable type being illustrated and described in Chapter ofthe 38th edition ofSteam published by The Babcock & Wilcox Company. It is the primary purpose of the master controller to generate, from the control signal established by the load dispatch system 28, a control signal to the steam generators whereby the actual energy output of the power producing unit will be maintained equal to the desired energy output.
  • the control signal generated in master controller 30 is transmitted to a ratio controller 32, the purpose of Y which is to apportion the total load demand between steam generators A and B as desired within the capabilities of the generators. That is to say, it divides the control signal from master controller 30 and establishes a first demand signal for the boiler A and a second demand signal for the boiler B.
  • the first demand signal as shown, is utilized in a feedwater control 34A and firing rate control 36A of boiler A.
  • the second demand signal is utilized in the feedwater control 348 and firing rate control 368 of boiler B.
  • the two demand signals generated in ratio control 32 are also transmitted to a reheat flow control 42, the purpose of which is to apportion the flow of reheat steam to boilers A and B primarily in proportion to boiler load.
  • FIGS. 4, 5, and 7 show the ratio, feedwater, firing rate and reheat flow control for boilers A and B.
  • conventional control logic symbols have been used.
  • the control components or hardware, as it is sometimes called, which such symbols represent, are commercially available ,and their operation well understood by those familiar with the art.
  • conventional logic symbols to avoid identification of the control system with any particular type of control, such as pneumatic, hydraulic, electronic, electric or a combination of these, as the invention may be incorporated in any one or a combination of these types.
  • the primary controllers shown in FIGS. 4, 5, 6 and 7 have been referenced into FIGS. 1, 2A, and 28 as have the final control elements.
  • the control signal corresponding to total boiler demand is transmitted to a multiplying unit 44, the output signal from which is transmitted to a difference unit 46. That portion of total boiler demand that each boiler should assume is established in ratio control station 48 which generates a control signal transmitted to multiplier 44.
  • the output signal from multiplier 44 is thus the demand signal to boiler A.
  • the boiler A demand signal is subtracted from the total boiler demand signal and the output signal therefrom is the boiler B, demand signal.
  • a difference unit 60A generates a signal proportional to the difference between the output signal of multiplier 44 and low signal selector 56A which is transmitted through direct proportional unit 64 to a summing unit 68.
  • a difference unit 603 generates a signal proportional to the difference between the output signal of difference unit 46 and low signal selector 568 which is transmitted through reverse proportional unit 66 to the summing unit 68.
  • both boilers A and B are carrying their assigned loads, i.e., if the output of neither one is limited, the output signal generated by summing unit 68 will be at neutral.
  • the output signal from summing unit 68 operates a transfer unit 70 and thereafter serves as the input signal to multiplier 44.
  • the demand signal to boiler B will be increased accordingly through operation of difference unit 46.
  • a constraint on the output of boiler B operates in similar fashion, the output signal from reverse proportional unit 66 operating through summing unit 68 and transfer unit 70 to increase the demand signal to boiler A and reduce the demand signal to boiler B until the output signal from difference unit 608 is at neutral.
  • the high signal selector 72 serves to pass to the unit load dispatch system 28 the higher of the two error signals generated in difference units 60A and 608. Accordingly, if the larger of the two signals indicating an unsatisfied demand on either boiler, from either difference unit 60A or 60B is reduced to zero by running back the unit load demand, the unsatisfied demand on both boilers will be reduced to zero.
  • feedwater temperature varies in a direct predictable functional relation to unit load.
  • feedwater temperature is a function of turbine load.
  • the relationship between feedwater temperature and actual steam flow entering the turbine, which in turn is equivalent to total feedwater flow to both boilers is directly related to the total turbine extraction flow to high and low pressure and deaerating feedwater heaters.
  • a lower feedwater temperature than that to be expected for the existing boiler demand hasa direct relationship to the existing lower steam flow to the turbine which in turn is equivalent to a lower required boiler feedwater flow.
  • the feedwater demand will be increased to reflect the actual increase in steam flow to the turbine that results from the increased extraction flow.
  • the rate of flow of feedwater to each boiler is maintained in direct proportion to boiler demand.
  • the control signal generated in ratio control 32 is transmitted to feedwater control valve 74A.
  • a feed back loop comprising flow transmitter 76A, difference unit 78A, integrating unit 80A and multiplying unit 82A maintains the actual feedwater flow equal to demand feedwater flow.
  • the signal generated by function generator 83A is compared to a signal generated by a temperature transmitter 84A, corresponding to actual feedwater temperature, in a difference unit 86A.
  • the output signal from difference unit 86A is transmitted to a multiplying unit 87A through a summing unit 88A and modifies the demand control signal in accordance with deviations in actual feedwater temperature from that to be expected for the then existing boiler demand.
  • the demand signals to boilers A and B are measures of the heat release required of the boilers to satisfy the energy output demanded of the power producing unit.
  • the heat release is directly related to the fuel BTU input to the boiler furnace.
  • the boiler demand signal thus adjusts fuel flow in parallel with air flow. It is recognized that for a given fuel and fuel BTU input the required combustion air flow remains essentially constant. Since the boiler demand signal is directly equated to energy output demanded and since the total cycle efficiency at each load is relatively constant and predictable our invention matches air flow directly to the boiler demand. Fuel flow is readjusted as required to maintain the superheater outlet temperatures of the two boilers equal and at turbine throttle temperature set point.
  • the boiler A demand signal is transmitted to final control element 91A, such as a damper drive unit, controlling the rate of flow of air supplied for combustion.
  • final control element 91A such as a damper drive unit, controlling the rate of flow of air supplied for combustion.
  • a feedback signal generated in flow transmitter 92A proportional to measured air flow,
  • the signal generated in transmitter 92A is transmitted to difference unit 93A, and the output signal through a proportional plus integral unit 132A serves to adjust the air flow damper 91A as required to maintain actual air flow equal to desired air flow.
  • a signal proportional to temperature error from set point and to the rate of change in superheater outlet temperature of boiler A is superimposed upon the demand signal in a sense opposite the direction of temperature change thereby compensating for momentary fluctuations in superheater outlet temperature.
  • a signal corresponding to superheater outlet temperature is generated in temperature transmitter 94A and transmitted to a proportional plus derivative unit 95A and thence to summing unit 96A.
  • the demand signal to boiler A also controls the rate of fuel flow to maintain the rate of fuel flow in required relationship to the rate of air flow.
  • the output signal from summing unit 96A is transmitted to final control element 97A, shown in FIG. 2A as a fuel control valve, the specific type of fuel flow control device employed depending upon the type of fuel.
  • a feedback loop comprising fuel flow transmitter 98A, difference unit 99A and proportional plus integral unit 100A maintains actual rate of fuel flow equal to the demand rate of fuel flow.
  • a push-pull control arrangement whereby the rate of fuel flow to the boiler having the higher superheater outlet temperature is decreased and simultaneously the rate of fuel flow to the other boiler is increased, thus maintaining the superheater outlet temperatures equal while adjusting, concurrently, the rate of fuel flow to both boilers in accordance with deviations in throttle steam temperature from set point.
  • a signal proportional to the difference between boiler A and boiler B superheater outlet temperatures is generated in a difference unit 122 and through a direct acting proportional unit 124 and a reverse acting proportional unit 125 is transmitted to summing units 105A and 1058 to bias the input signals to integral units 101A and 1018 in opposite directions.
  • Our invention comprehends proportioning the reheat steam from high pressure turbine 9 between boilers A and B in accordance with a feed forward signal derived from the demand signal to each boiler, thus, inferentially maintaining a reheat flow to each boiler proportional to primary steam generation.
  • the demand signal to boiler A positions final control element, a flow control valve, 107A.
  • the demand signal to boiler B positions flow control valve 1078.
  • reheat flow through boiler A and boiler B is measured by flow transmitters 109A and 109B respectively.
  • the primary elements of the reheat flow transmitters are shown schematically as orifices, our invention comprehends the use of any pressure drop varying in functional relationship with respect to flow, thus, to minimize unrecovered pressure loss the pressure drop through the reheater may be used, or a primary element such as a Venturi Tube or flow nozzle.
  • Known flow measuring means other than the type producing a pressure differential varying with flow might also be used.
  • both pressure and temperature of the reheat steam vary with reheat flow and the flow transmitters can be compensated for both these conditions by any suitable means.
  • the difference between actual reheat flow and programmed reheat flow through each boiler is determined by difference units 110A and 1108.
  • an actual reheat flow greater than the programmed reheat flow may be considered as generating a positive output signal from difference unit 110A or 1108 and vice versa.
  • the generated signals are transmitted to a difference unit 111.
  • the output signal generated therein through proportional plus integral unit 112, reverse and direct acting proportional units 113A. 1138 inputs to summing units 114A and 114B respectively.
  • the output signals from summing units 114A and 1143 are thus modified in opposite directions to position valves 107A and 107B in opposite directions to maintain equal differences between the actual reheat flows and programmed reheat flows. It is evident, if desired, the amount of readjustment allowed to maintain equal differences may be limited.
  • desired reheat temperature can be obtained by gas recirculation as shown in FIG. 1 supplemented, if required, by spray attemp'eration or other well known means.
  • the hot reheat temperature of a boiler exceeds set point
  • our invention comprehends increasing the reheat flow to that boiler while simultaneously decreasing the flow to the other; or if the hot reheat temperatures of both boilers exceed set point to increase the reheat flow to that boiler having the greater excess while simultaneously decreasing the reheat flow through the other boiler. This action thus tending to maintain the excess hot reheat temperatures from both boilers equal.
  • Temperature transmitters 115A and 1158 generate signals corresponding to the hot reheat temperatures of boilers A and B. These signals are compared in high signal selecting units 116A and 116B against set point signals. So long as the signal generated in transmitter 115A, for example, is less than set point unit 116A transmits the set point signal to a difference unit 117. When, however, the signal corresponding to hot reheat temperature exceeds the set point signal, it is transmitted to difference unit 117. Similarly, so long as the signal generated by transmitter 115B is below set point, the signal transmitted to difference unit 117 will be the set point signal, if, however, the signal generated in transmitter 1158 is greater than the set point signal it will be transmitted to difference unit 117.
  • the output signal from difference unit 116 will have a neutral value, such as zero, so long as both hot reheat temperatures are at or below set point.
  • unit 117 When, however, the hot reheat temperature of one boiler exceeds set point, unit 117 generates a signal in one sense, whereas if the hot reheat temperature of the other boiler exceeds set point, unit 117 will generate a signal in opposite sense. If the hot reheat temperatures of both boilers exceed set point, then unit 117 will generate an output signal having a sense, dependent upon which boiler has the greater hot reheat temperature and will have a value corresponding to the difference between the two hot reheat temperatures.
  • the signal generated in difference unit 117 is transmitted to a direct acting proportional unit 118A and a reverse acting proportional unit 118B.
  • These units through summing units 120A and 1208 serve to modify the feed forward signals for boilers A and B in opposite senses, thus effecting a positioning of valves 107A and 1078 in opposite directions, thus tending to maintain the hot reheat temperatures from both boilers below set point and further to maintain equal hot reheat temperatures from both boilers when both such temperatures are above set point.
  • An alternate arrangement, especially applicable if reheater absorption to load characteristic is such that reheat attemperators are seldom used and the two boilers are operated frequently with unbalanced steam flow and thus unbalanced reheater outlet temperature is to maintain reheater temperature control capability by biasing steam flow through the reheaters at all times a temperature difference occurs at the outlet of the two reheaters either above or below set point.
  • the high auctioneers 116A and 1168 are replaced by difference units 130A and 1308 developing a reheater outlet temperature error from set point for comparison in difference unit 117. Whenever either reheater outlet temperature error differs from the comparable error from the other boiler, the reheater steam flow will be increased through the reheater having the higher outlet temperature.
  • a control system for a two boiler single turbine power producing unit comprising, means generating a master demand signal corresponding to the total boiler output required to meet the desired output of said power producing unit, a ratio controller responsive to said master demand signal including means generating a first primary boiler demand signal for one of said boilers varying in predetermined ratio with the magnitude of said master demand signal and means generating a second primary boiler demand signal for the other of said boilers corresponding in magnitude to the difference between the magnitudes of said master demand signal and said first boiler demand signal.
  • control system as set forth in claim 1 further including means for adjusting said predetermined ratio between the magnitudes of said master demand signal and said first boiler primary demand-signal.
  • first and second means each include means inhibiting limiting the boiler output until said condition exceeds a first predetermined limit and thereafter adjusting said predetermined ratio as required to maintainsaid limiting condition within a second predetermined limit.
  • first and second means each include means generating a signal corresponding in magnitude to the limiting condition, and means limiting the primary boiler demand signal to the magnitude of said last named signal.
  • first and second means each include means generating a signal corresponding to the difference between the primary boiler demand signal and the limited boiler demand signal, means selecting the greater of the last named signals and means modifying said master demand signal responsive to said last named signal.
  • a control system as set forth in claim 6 further including means initially delaying the modification of said master demand signal for a specified increment of time.
  • a control system for a power producing unit comprising a boiler A and a boiler B supplying steam in parallel to a single turbine
  • the combination comprising, means generating a boiler A demand signal, means generating a boiler B demand signal, means responsive to the boiler A demand signal maintaining the rate of fuel supply to boiler A in functional relationship to the boiler A demand signal, means responsive to the boiler B demand signal maintaining the rate of fuel supply to boiler B in functional relationship to the boiler B demand signal and means modifying the functional relationship between said demand signals and the rates of fuel supply to boilers A and B in accordance with the integral with respect to time of deviations in turbine throttle steam temperature from set point.
  • a control system as set forth in claim 8 further including means modifying the functional relationship between the boiler A demand signal and the rate of fuel supply to boiler A in one sense and modifying the functional relationship between the boiler B demand signal and the rate of fuel supply to boiler B in opposite sense responsive to the difference in the steam temperatures of boiler A and boiler B whereby the steam temperature of boiler A is maintained in desired relationship to the steam temperature of boiler B.
  • a control system for a power producing unit comprising a boiler A supplying steam to the high pressure section of a turbine and reheat steam to the low pressure section of the turbine and a boiler B supplying steam to the high pressure section of said turbine and reheat steam to the low pressure section of said turbine in parallel with boiler A
  • the combination comprising, means generating a boiler A demand signal, means generating a boiler B demand signal, means responsive to the boiler A demand signal varying the rate of flow of reheat steam through boiler A in functional relationship to changes in the boiler A demand signal and means responsive to the boiler B demand signal varying the rate of flow of reheat steam through boiler B in functional relationship to changes in the boiler B demand signal.
  • a control system as set forth in claim further including means modifying the functional relationship between the boiler A demand signal and boiler A reheat flow in one sense and the functional relationship between the boiler B demand signal and boiler B reheat flow in opposite sense comprising, means generating a first signal corresponding to the difference between boiler A reheat flow and boiler A demand signal, means generating a second signal corresponding to the difference between boiler B reheat flow and boiler B demand signal, means generating a third signal corresponding to the difference between said first and second signals and means responsive to said third signal modifying the boiler A reheat flow in one sense and the boiler B reheat flow in opposite sense whereby the boiler A reheat flow is maintained in desired functional relationship to the boiler B reheat flow.
  • a control system as set forth in claim 11 further including means increasing the boiler A reheat steam flow upon the boiler A hot reheat steam temperature exceeding set point and simultaneously"decreasing the boiler B reheat steam flow and vice versa.
  • a control system as set forth in claim 12 further including means increasing the reheat steam flow through that boiler having the higher hot reheat steam temperature above set point and simultaneously decreasing the reheat steam flow through the other boiler.
  • a control system as set forth in claim 11 further including means increasing the boiler A reheat steam flow upon the boiler A hot reheat steam temperature exceeding the boiler B hot reheat steam temperature and simultaneously decreasing the boiler B reheat steam flow and vice versa.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Control Of Steam Boilers And Waste-Gas Boilers (AREA)
US00367775A 1973-06-07 1973-06-07 Control system for a two boiler, single turbine generator power producing unit Expired - Lifetime US3837167A (en)

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US00367775A US3837167A (en) 1973-06-07 1973-06-07 Control system for a two boiler, single turbine generator power producing unit
JP49064155A JPS618328B2 (is") 1973-06-07 1974-06-07
US05/495,314 US3937024A (en) 1973-06-07 1974-08-07 Control system for a two boiler, single turbine generator power producing unit
JP58122490A JPS5941605A (ja) 1973-06-07 1983-07-07 二ボイラ・一タ−ビン型発電装置用制御方式

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US3930367A (en) * 1974-10-23 1976-01-06 General Electric Company Fluid flow control system
US4275447A (en) * 1978-05-25 1981-06-23 Framatome Method of regulation of the water level in boilers or steam generators
US4559785A (en) * 1985-01-09 1985-12-24 Phillips Petroleum Company Boiler control
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US20110023487A1 (en) * 2008-02-26 2011-02-03 Alstom Technology Ltd Method for controlling a steam generator and control circuit for a steam generator
CN102042582A (zh) * 2010-11-29 2011-05-04 东北电力科学研究院有限公司 两炉一机中间再热机组再热器汽温及流量控制系统及方法
US20120040299A1 (en) * 2010-08-16 2012-02-16 Emerson Process Management Power & Water Solutions, Inc. Dynamic matrix control of steam temperature with prevention of saturated steam entry into superheater
US20140033715A1 (en) * 2011-04-29 2014-02-06 Shanxi Electric Power Research Institute Main stream temperature control system for large boiler
US9163828B2 (en) 2011-10-31 2015-10-20 Emerson Process Management Power & Water Solutions, Inc. Model-based load demand control
CN105114141A (zh) * 2015-09-18 2015-12-02 广东电网有限责任公司电力科学研究院 单元机组协调控制方法和系统
US9335042B2 (en) 2010-08-16 2016-05-10 Emerson Process Management Power & Water Solutions, Inc. Steam temperature control using dynamic matrix control
US9447963B2 (en) 2010-08-16 2016-09-20 Emerson Process Management Power & Water Solutions, Inc. Dynamic tuning of dynamic matrix control of steam temperature

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JPS54105342A (en) * 1978-02-07 1979-08-18 Mitsubishi Electric Corp Glow-discharge heating device
JPS61191801A (ja) * 1985-02-20 1986-08-26 株式会社日立製作所 発電プラントの制御システム
JPH0713526B2 (ja) * 1985-03-15 1995-02-15 株式会社日立製作所 火力発電プラント自動制御装置
US4805114A (en) * 1987-04-20 1989-02-14 Westinghouse Electric Corp. Economical dispatching arrangement for a boiler system having a cogenerative capability
US8161724B2 (en) * 2010-03-31 2012-04-24 Eif Nte Hybrid Intellectual Property Holding Company, Llc Hybrid biomass process with reheat cycle

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JPS618328B2 (is") 1986-03-13
JPS5031318A (is") 1975-03-27
JPS5941605A (ja) 1984-03-07
JPH0143201B2 (is") 1989-09-19

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